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Utt©1r1'<aid1alr1ld Power Corporatio1J1 ltd. (A. GovL of Uttarakhand Undertaking)

CIN : U40109UR2001 SGC025867 Email ID: g'fJdr~ahoo.co.in Website: www.uocLorq

/UPCL/RM/B-21 Dated: .. 'J.~ -11-2019

BEFORE THE UTTARAKHAND ELECTRICITY REGULATORY COMMISSION

INDEX

IN THE !WATTER OF: ANNUAL REVENUE REQUIREMENT (ARR) PETITION FOR THE FINANCIAL YEAR 2020-21 ALONGWITH TARIFF DETERMINATION FOR FY 2020-21, TRUE - UP FOR FY 2018-19 AND ANNUAL PERFORMANCE REVIEW FOR FY 2019-20.

AND

IN THE MATTER OF: UTTARAKHAND POWER CORPORATI0Nm LIMITED.

I s. 1'> T ... .:-,. a}.

' 1

2

3

4

........... Petitioner

I Particulars Page No. i

Petition A-E

Affidavit verifying the accompanying petition F-G

Detailed ARR and Tariff Petition 1-182

Formats 183-328

J& (Naveen Kumar Gupta)

Director (Finance)

'ft~ llSffi ~ 'T'f< ml.' i30lT 'l<Ff', ~ '16, ~-248001, ~: 91-135-2768895 'Victoria Cross Vijeta Gabar Singh Urja Bhawan", Kanwali Road, Dehradun-248001. Phone: 91-135-2768895

File No ....... . Case No ...... .

BEFORE THE UTTARAKHAND ELECTRICITY REGULATORY COMMISSION

In the matter of: ANNUAL REVENUE REQUIREMENT (ARR) Petition for the Financial Year 2020-21 ALONGWITH TARIFF DETERMINATION FOR FY 2020-21, TRUE- UP FOR FY 2018-19 AND ANNUAL PERFORIV!ANCE REVIEW FOR FY 2019-20.

And

In the matter of: Uttarakhand Power Corporation Limited.

........... Petitioner

The humble applicant most respectfully showeth:

1. Specific Legal Provision under which Petition is being filed:

(i) Section 64 (1) of the Electricity Act, 2003 requires the

Distribution Licensee to make an application before the State

Commission for determination of retail sale of electricity in

accordance with the Regulations framed by the State Commission

in the matter.

(ii) As per clause-25.1 of the Distribution and Retail Supply of Licence

issued to UPCL, UPCL is required to prepare and submit to the

Hon'ble Commission, the following information by not later than

30th November every year:

> A statement showing full details of its expected aggregate

revenue and cost of service.

> In case there is any difference between expected aggregate

revenue and expected cost of service, any proposal for Tariff

revisions to eliminate such difference.

(ii) As per Regulation-43 (4) of the UERC (Conduct of Business)

Regulations, 2014, the Distribution Licensee is required to

file before the Hon'blc Commission on or before 30th

November every year, the ARR and Tariff Petition in

accordance with UERC Tariff Regulations,2018.

/\

(iii) On the Multi-Year Tariff Petition of UPCL for the control

period from FY 2019-20 to 2021-22, Hon'ble Commission

passed an order on 27-02-2019 as per the provisions of

UERC Tariff Regulations,2018.

(iv) As per Regulation 12 of the UERC Tariff Regulations,2018,

the Distribution Licensee is required to file an application

before the Hon'ble UERC for Annual Performa nee Review

(APR) by 30th November every year. The APR inter-alia,

includes the following:

? A comparison of the Audited Performance of the

applicant for the previous financial Year with the

approved forecast for such previous financial Year and

truing - up of Expenses and Revenue.

'? Revision of estimates for the ensuing financial year, if

required, based on Audited financial result for the

previous financial year.

(v) As per Regulation 16 of the UERC Tariff Regulations,2018,

the Distribution Licensee is required to file an application

before the Hon'ble Commission for determination of Tariff

along with the petition for APR under Regulation 12.

(vi) As per the provisions of UERC (Conduct of Business)

Regulations, 2014, the above petition should be submitted

under affidavit after approval of Board of Directors.

(vii) TI1is ARR and Tariff Petition for FY 2020-21 is being filed in

compliance of the above provisions of law and in-accordance

with the procedure specified in UERC (Conduct of Business)

Regulations, 2014 and UERC Tariff Regulations, 2018.

2. Limitation:

As per section-64(3) of the Electricity Act, 2003 read with clause-25 of

Distribution and Retail Supply of Licence issued lo the Petitioner, Regulation -

43(4) of the UERC (Conduct of Business) Regulations, 2014, Regulation -

10(1), Regulation 12 and Regulation - 16 of the Tariff Regulations, the ARR

and Tariff Petition for FY 2020-21 should have been filed before the Hon'ble

Commission on or before 30th November, 201 D. Thus, this petition is within (' time limit as specified under the Jaw. 1L

)"'""> ' //

3. Facts of the Case:

s. No.

l

2

3 4 5 6 7 8 9

10

11

12

13

14

15

16

The detailed ARR and Tariff Petition for FY 2020-2 l is attached herewith. The

summary of the petition is as follows:

Particulars 2018-19 2019-20

2020-21 (Actual) (Revised (Projected) estimate)

Energy at State Periphery (MU) 13837.49 14412.20 14808.12 Energy at Distribution Periphery 13803.71 14210.43 14600.80 (MU) Billed Energy (MU) 11826.68 12185.44 12556.69 Distribution Loss (%) 14.32% 14.25% 14.00% Collection Efficiency (%) 97.44% 99.05% 99.10%

. .

Capital Expenditure (Rs. Cr.) 795.04 1158.79 745.36 Capitalization (Rs. Cr.) 937.73 937.06 977.22 Power Purchase Cost (Rs. Cr.) 5872.78 6021.70 6379.52

.. Other Cost (Rs. Cr.) 659:21 817.36 1065.32 Previous years adjustments: I 194.67 305.31 -Surplus/ (Gap) (Rs. Cr.) Net ARR (Rs. Cr.) 6337.32 6533.75 7444.84

-Revenue at Existing Tariff (Rs. 6211.19 6546.10 7062.37 Cr.) Revenue (Gap)/Surplus (Rs. Cr.) (126.14) 12.35 (382.4 7) Total Gap to be recovered in FY 2020-21 along with carrymg (543.83) cost (Rs. Cr.) Total ARR to be recovered in FY

7606.20 2020-21 (Rs. Cr.) Increase in Tariff Required in FY

7.70% (Rs.5.62 per unit to Rs. 6.06 per unit) 2020-2 l

This petition is being filed as per approval granted by the Board of Directors of

the Petitioner Company.

4. Cause of Action:

This petition is being filed before the Hon'ble Commission in compliance of the

provisions of the Electricity Act, 2003 read with the provisions of Distribution

and Retail Supply Licence of UPCL and UERC (Conduct of Business) Regulations,

2014 and UERC Tariff Regulations, 2018.

5. Ground of Relief:

The gap between expected revenue and Annual Revenue Requirement

for FY 2020 - Z 1 of the Petitioner Company is Rs 543.83 Cr. To recover this

gap, a hike in existing Tariff has been proposed @ 7.70% before the Hon'ble

Commission.

6. Details of Remedies Exhausted:

As the Hon'ble Commission is the Appropriate Authority to consider the

matter, no remedies has been sought from any other Forum / Court /

Authority etc.

7. l\1atter not previously filed for pending with any other court:

As the Hon'ble Commission is the Appropriate Authority to consider the

matter, the application is being filed only before the Hon'ble Commission

and no other application is pending in the matter with any other Court.

8. Relief sought:

The Petitioner prays that the Hon'ble Commission may:

a) admit the accompanying AR~ and Tariff Petition; b) approve true-up of expenses and revenue for FY 2018-19 based on

the audited accounts of the said year; · c) approve various controllable and uncontrollable parameters

alongwith ARR for FY 2020-21; d) approve the change (increase) in retail tariffs for FY 2020-21 as

proposed; e) approve the terms and conditions of tariffs and various matters as

proposed in the petition; f) pass suitable orders for implementation of the tariff proposals for FY

2020-21 for maldng it applicable from April 1, 2020 onwards; g) condone any inadvertent omissions/ errors/ shmtcomings and

permit Petitioner to add/ change/modify/ alter this filing and make further submissions as may be required at future date; and

h) pass orders, as the Hon'ble Commission may deem fit and proper keeping in view the facts and circumstances of the case.

9. Interim Order, if any, prayed for:

No prayer for interim order has been made.

10. Details of Index:

IS ~o I

2

4

Particulars

Petition

Affidavit verifying the accompanying petition

Detailed ARR and Tai;iff Petition

Formats

Page No

A-E

F-G

···--+-~1-182 ··-j 183-328 ·.

~---~----------------··---·---'-----.

11. Particulars of fee remitted:

Application fee amounting to Rs. 38,03,100.00 (Rs. 5 for every Rs. 1,00,000.00 of ARR claimed) only is being deposited through Demand Draft No. URS 569299, dated 29-11-2019 of PNB, Kanwali Road, Dehradun favouring Secretary, Uliarakhand Electricity Regulatory Commission, Dehradun.

1 Z. List of enclosures:

S.No.

1

2

3

4

Particulars I

Page No.

Petition I A-E

Affidavit verifying the accornpanyiitg petition F-G -

Detailed ARR and Tariff Petition 1-182

Formats 183-328

For and on behalf of Uttarald1and Power Corporation Limited

~ N.,,-, (Naveen Kumar Gupta)

Director (Finance)

Verification

I --

I, Naveen Kumar Gupta S/ o Shri Pa wan Kumar, aged 51 years, working as Director (Finance) -- Uttarald1and Power Corporation Limited, \/CV Gabar Singh Bhawan, Dehradun do hereby verify that the contents of Paras 1 to J 2 are derived from official records, which are true to my personal lmowledge and that I have not suppressed any material fact.

/.

Q r---,.­(Naveen Kumar Gupta) Director (Finance)

Uttarald1and Power Corporation Limited

Certificate No.

Certificate Issued Date

Account Reference

Unique Doc. Reference

Purchased by

Description of Documen\

Property Description

Consideration Price (Rs;)

First Party

Second Party

Stamp Duty Paid By

Stamp Duty Amount(Rs.)

INDIA NON JUDICIAL

Government of Uttarakhand

e-Stamp

IN-UK94981640605916Q

13-Dec-2018 10:35 AM

NONACC (SV)/ uk1260004/ DEHFlAbUN/ UK-DH

SUB1N-UKUK1260004915520608437490

UTTARAKHAND POWER CORPORATION LTD

Article Miscellaneous

NA

0 (Zero)

UTTARAKHAND POWER CORPORATION LTD

NA

UTTARAKHANC :oow 10 (Ten only)

AFFIDAVIT VERIFYING THE PETITION . :"··uu. uu uu .......................... u .. Please wnte or type below this line .•..•.•. ~ ......•...... : .............•...•... ~ .

t Naveen Kumar Gu_pta S/o Shri Pawan Kumar, aged 5] years, working as Director (Finance) - Uttarakhand Povvmi Corpon1tion Limited, VCV Cab.1r Singh Bhavvan, Dehradl1n, the deponent named above do hereby solemnly affinl1.

and stale on oath as under: 1. Thnt the deponent is t!w Director (Finance) of Uttanoikhancl Pm,ver Corporation Limited who is authorized as

per resolution of the company ;:md is acquainted with the facts deposed to belovv. 2. L the deponent named above do hereby verify that the contents oft-he paragraph No.-1 of the affidavit ancl

those of th(~ paragraph No.···l lo J 2 of the accompanying petition are based on the perusal of records ,vhich j belief to Lx~ true m1d verify lhnt no part of this affidavit is false and nothing material has been conn:'aled.

I

1;~r<s of th.:: c0.-:ific2;,c Lil" ::::.:,i111,1,\-:,1l fcui!·,uSty

Deponent

{J):::-, (Naveen Kumar Gupta)

Director (Finance) Uttarakhand Po1ver Corporatior\ Limited

I, ~.'fr~:tc\ (iliY\,_Q1\~\~ Advocate, do l1ereby declare that the person

making this affidavit is known to me through the perusal of records and I am satisfied that he is

the same person alleging to be deponent himself.

( .......... ~ ....... ) Advocate )

V,V· iS-'130 o0

Solemnly affirmed before me on this .J.a .. day of JI /I 7 by the deponent who has been identified by the aforesaid advocate.

I have satisfied myself by examining the deponent that he understood the contents of the affidavit

whicl1 has been read over and explained to him. He has also been explained about section 193 of

Indian Penal Code that whoever intentionally gives false evidence in any of the proceedings of the

Commission or fabricates evidence for purpose of being used in any of the proceedings shall be

liable for punishment as per law.

(Notary Public)

UTIARAKHAND POWER CORPORATION LIMITED

C3'ij {t{Sf O$ qp:j { cbl {q)"{~R @o

PETITION FOR TRUE-UP OF FY 2018-19, ANNUAL

PERFORMANCE REVIEW OF FY 2019-20, ANNUAL

REVENUE REQUIREMENT FOR FY 2020-21 ALONG

WITH TARIFF DETERMINATION FOR FY 2020-21

SUBMITIED TO:

UTIARAKHAND ELECTRICITY REGULATORY

COMMISSION

'

1

Table of Contents

Al: INTRODUCTION ......................................................................................... 8

PERFORMANCE OF UPCL IN THE PAST....... .. ............ 8

MAJOR SCHEMES IMPLEMENTED W .R.T. DISTRIBUTION WORl<S ............. ,, .. , .. , .. ,. . .... , .. 12

KEY FACTORS IMPACT!l<G THE FINMCIAL SUBSTAil<IBILI1Y OF U PCL ............................... 16

OVERVIEW OF THE TARIFF PETITION FOR FY 2020·21............. .. .......................... 28

A2: TRUE-UP FOR FY 2018-19 ....................................................................... 30

El<ERGY SALES .......................... .

POWER PURCHASE EXPENSES .................................. , ....... .

RPO STATUS AND COMPLIANCE ........................................... .

DISTRIBUTION LOSSES ..

OPERATION AND MAINTENANCE EXPEfl.JSES . , , , . , , . , , .. , ...... , , , . , , , ,

EMPLOYEE EXPENSES ......... , ...... , .......... , ..

A&G EXPENSES ..................................................... .

R&M EXPENSES .................................................. ..

CAPITAL COST OF ASSETS AND Fif\JANCING ................ ,,.,,

INTEREST AND FINANCE CHARGES .............. ..

DEPRECIAT!Ofj ..

INTEREST Of\! WORKING CAPITAL ............ .

RETURN ON EQUI1Y ............ .

BAD AND DOUBTFUL DEBTS WRITTEN OFF ........ , ..... , .. , .. ,., ..... .

NON·TARIFF INCOME (NT!) ................................ ..

REVENUE FROM TARIFF ................................................. .

························· 30 .. . 31

.. ............. 33 .. ............... 33

.... 34 ................ 34

.. ........... 35

............. 36

.. ... 37

.. ... 38 .... 39

.. ..................... 40

.. ... 41 .......... 41

.. ................. 42

............. 43 SHARIIIJG Of GAINS AND LOSSES ON ACCOUNT OF CONTROLLABLE FACTORS .. , ............ , , , , , , 43

ARR Al<D REVENUE GAP FOR FY 2018·19............................. .. ............... 45

REVENUE GAP WITH CARRYING COST .................................................................... 45

A3: ANNUAL REVENUE REQUIREMENT (ARR) AND DETERMINATION OF

TARIFF FOR FY 2020·21 .......................................................................... 47

E!IJERGY SALES, CONNECTED LOAD AND NUMBER OF COIIJSUMERS ........ ~8 DISTRIBUTIOIIJ Loss TRAJECTORY''.'' .... ' ...... '' ......... 52 COLLECTIOIIJ EFFICIEIIJCY, .......... ,,., ....... ,, .. , ... , .......... , . 54

RELIABIL11Y INDICES., ........ ,, ........ , .... , .... , .... , ............. ,., .... ,, .... , ............. 54

POWER PROCUREMENT PLAN .............. ., ................................ .. .................... 54

PROCUREMENT OF POWER AND LiTTARAKHAND'S ALLOCATED SHARE .. .

BROAD APPROACH FOR PROJECTING POWER AVAIU\BILI1Y ....... ,., ... ,,

TRANSMISSION LOSSES ........... , .......... , .. , .. ,,, .......... .

PROCUREMENT OF DEFICIT POWER AND ADJUSTMEf\lT OF SURPLUS POVVER ..... .

ENERGY BALANCE., ....................... , ...... , ... .

POWER PURCHASE COST ......................... , ............... , ....... .

RENEWABLE PURCHASE 0BLIGATIOIIJ ..... , .... , , ., ,.

INTER-STATE Af\JD IIIJTRA-STATE TRANSMISSION CHARGES ...... ..

CAPITAL EXPENDITURE PLAN AND RELATED EXPEJIJSES,.,.,, .. ,, ... .

CEflJTRAL SECTOR SCHEMES , .......................................... ..

OTHER WORKS.

PROPOSED CAPITAL EXPEflJDITURE AND CAPITALIZATIOJIJ . , .. ,

I<

.. ..... 55

55

62 62

.. 62 " ... 62

.. '" 66 .. " .. 67 "" ... 72

.. ... " 75 79

...... 98

2 J

---------- ---- -- ----- - --- - ___ ,, __________ "_ ---

GROSS FIXED ASSETS (GFA) AND CAPITAL WORKS IN PROGRESS (CWIP) ...................... 99

INTEREST ON LOAN CAPITAL. .............................................................................. 99

INTEREST ON CONSUMER SECURITY DEPOSIT (CSD) ................................................ 101

RETURN Or< EQUITY (RoE) ............................................................................... 101

OPERATION AND MAINTENANCE EXPENSES............. . .............. 102

MANPOWER PLM .......................................................................................... 103

PROJECTION OF EMPLOYEE COSTS ....................................................................... 103

PROJECTION OF ADMINISTRATIVE AND GENERAL EXPENSES (A&G) .............................. 104

PROJECTION OF REPAIR AND MAINTENANCE EXPENSES (R&M) ................................... 108

PROJECTED OPERATION AND MAINTENANCE EXPENSES ............................................. 108

DEPRECIATIOIS ............................................................................................. 109

INTEREST ON WORKING CAPITAL ........................................................................ 109

Nori-TARIFF INCOME (NT!) ............................................................................. 110

PROVISION FOR BAD DEBTS ............................................................................. 110

IMPACT OF TRANSFER SCHEME BETWEEN U PPCL AND UPCL ........................................ 111

ANNUAL REVENUE REQUIREMENT FOR FY 2020-21 .................................................. 111

REVENUE PROJECTIONS .................................................................................... 112

REVENUE AT EXISTING TARIFF ............................................................................ 112

REVENUE GAP FOR FY 2020-21 AT EXISTING TARIFF ................................................ 113

REVENUE AT PROPOSED TARIFF rn FY 2020-21 ...................................................... 113

A4: OPEN ACCESS CHARGES ........................................................................ 115

WHEELING CHARGES ..... ,., .......................... ,.,, .......... ,, ............. ,,,, .......... ,,, ....... 115

CROSS SUBSIDY SURCHARGE ............................................................................ 116

ADDITIONAL SURCHARGE ................................................................................. 117

AS: TARIFF PROPOSAL ................................................................................. 119

A6: PRAYER ................................................................................................... 146

A7: COMPLIANCE STATUS OF THE DIRECTIVES ISSUED BY HON'BLE UERC IN ITS TARIFF ORDER FOR FY 2019-20 ............................................... 147

3

--·. -------·-·-------- -- ---

List of Tables

TABLE 1: l<EY PERFORMANCE INDICATORS .. .. ...................... 8 TABLE 2: DISTRIBUTION LOSS (IN%) ...................................................................... 9 TABLE 3: REVENUE COLLECTION ............................................................................. 10 TABLE 4: PRODUCTIVITY AND RATE OF RETURN ...................................................... 10 TABLE 5: PERFORMANCE RATING OF UPCL ............................................................... 11 TABLE 6: ACTUAL ENERGY SALES IN FY 2018-19 (MUS) ........................................... 31 TABLE 7: ACTUAL POWER PURCHASE COST FOR FY 2018-19 (RS. CR.) ...................... 32 TABLE 8: VARIATION IN THE POWER PURCHASE COST FOR FY 2018-19 (RS. CR.) ...... 32 TABLE 9: RENEWABLE PURCHASE OBLIGATION (RPO) STATUS FOR FY 2018-19 ......... 33 TABLE 10: ACTUAL DISTRIBUTION LOSS FOR FY 2018-19 (IN MUS) .......................... 33 TABLE 11: NORMATIVE EMPLOYEE EXPENSES FOR FY 2018-19 (RS. CR.) ................... 34 TABLE 12: EMPLOYEE EXPENSES FOR FY 2018-19 (RS. CR.) ...................................... 35 TABLE 13: A&G EXPENSE FOR FY 2018-19 (RS. CR.) ................................................ 36 TABLE 14: R&M EXPENSES FOR FY 2018-19 (RS. CR.) .............................................. 37 TABLE 15: OPERATION AND MAINTENANCE EXPENSES FOR FY 2017-18 (RS. CR.) ...... 37 TABLE 16: MEANS OF FINANCE FOR NET ASSETS CAPITALIZED DURING FY 2018-19

(RS. CR.) ........................................................................................................ 37 TABLE 17: INTEREST EXPENSES ON CAPITAL LOANS FOR FY 2018-19 (RS. CR.) ......... 38 TABLE 18: TOTAL INTEREST CLAIMED FOR TRUING-UP OF FY 2018-19 (RS. CR.) ........ 39 TABLE 19: VARIATION IN THE INTEREST EXPENSES FOR FY 2018-19 (RS. CR.) .......... 39 TABLE 20: PROPOSED DEPRECIATION FOR FY 2018-19 (RS. CR.) .............................. 39 TABLE 21: VARIATION IN THE DEPRECIATION FOR FY 2018-19 (RS. CR.) .................. 39 TABLE 22: INTEREST ON WORKING CAPITAL FOR FY 2018-19 (RS. CR.) .................... 40 TABLE 23: VARIATION IN THE INTEREST ON WORl<ING CAPITAL FOR FY 2018-19 (RS.

CR.) ............................................................................................................... 41 TABLE 24: COMPUTATION OF RETURN ON EQUITY FOR FY 2018-19 (RS. CR.) ............ 41 TABLE 25: RECONCILIATION OF NON -TARIFF INCOME WITH AUDITED ACCOUNTS (RS.

CR.) ............................................................................................................... 42 TABLE 26: NON-TARIFF INCOME FOR FY 2018-19 ..................................................... 43 TABLE 27: REVENUE FROM SALE OF POWER IN FY 2017-18 (RS. CR.) ........................ 43 TABLE 28: ADDITIONAL REVENUE FROM SALE FOR FY 2018-19 (RS. CR.) .................. 44 TABLE 29: SHARING OF GAINS AND LOSSES (RS. CR.) ............................................. 44 TABLE 30: GAIN/ LOSS CLAIMED AS PART OF TRUING-UP FOR FY 2018-19 (RS. CR.). 44 TABLE 31: AGGREGATE REVENUE REQUIREMENT FOR TRUE-UP OF FY 2018-19 (RS. CR.)

····················································································································· 45 TABLE 32: REVENUE GAP FOR FY 2018-19 (RS. CR.) ................................................ 45 TABLE 33: REVENUE (GAP)/SURPLUS FOR FY 2018-19 ALONG WITH CARRYING COST

(RS. CR.)........... .. ...................... 46 TABLE 34: ENERGY SALES FOR CONSUMER CATEGORIES DURING FY 2013-14 TO FY

2018-19 (MU) ................................................................................................. 48 TABLE 35: CAGR FOR ENERGY SALES TO CONSUMER CATEGORIES ........................... 49 TABLE 36: PROJECTED ENERGY SALES (MU) FOR FY 2019-20 AND FY 2020-21 AND

GROWTH RATE CONSIDERED ........................................................................... 50 TABLE 37: PROJECTED CONTRACTED LOAD (l<W) FOR FY 2019-20 AND FY 2020-21

ALONG WITH THE GROWTH RATE CONSIDERED ................................................ 51 TABLE 38: PROJECTED NUMBER OF CONSUMERS FOR FY 2019-20 AND FY 2020-21

ALONG WITH THE GROWTH RATE CONSIDERED ................................................ 52 TABLE 39: PROPOSED LOSS TRAJECTORY ................................................................ 53 TABLE 40: PROPOSED COLLECTION EFFICIENCY ...................................................... 54 TABLE 41: TARGETS FOR FY 2020-21 FOR URBAN FEEDER OF THE PETITIONER .......... 54 TABLE 42: TARGETS FOR FY 2020-21 FOR RURAL FEEDER OF THE PETITIONER .......... 54 TABLE 43: ENERGY REQUIREMENT FOR FY 2020-21 (RS. CR.) ................................... 55 TABLE 44: PROJECTED AVAILABILITY FROM UJVNL STATIONS FOR FY 2020-21 (MU). 56

4

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TABLE 45: PROJECTED AVAILABILITY FROM NTPC STATIONS FOR FY 2020-21 (MU) .... 57 TABLE 46: PROJECTED AVAILABILITY FROM NHPC STATIONS FOR FY 2020-21 (MU) ... 57 TABLE 47: PROJECTED AVAILABILITY FROM NPCIL STATIONS FOR FY 2020-21 (MU) ... 58 TABLE 48: PROJECTED AVAILABILITY FROM SJVNL STATIONS FOR FY 2020-21 (MU) .. 58 TABLE 49: PROJECTED AVAILABILITY FROM THDC STATIONS FOR FY 2020-21 (MU) .. 58 TABLE 50: PROJECTED AVAILABILITY FROM UREDA STATIONS AND !PPS FOR FY 2020-

21 (MU) ......................................................................................................... 59 TABLE 51: DETAILS OF UPCOMING STATIONS DURING FY 2020-21 ........................... 60 TABLE 52: PROJECTED POWER AVAILABILITY FROM UPCOMING STATIONS DURING FY

2020-21 (MU) ................................................................................................. 61 TABLE 53: SUMMARY OF ENERGY AVAILABILITY FOR FY 2020-21 (MU) ...................... 61 TABLE 54: ENERGY BALANCE AT STATE PERIPHERY FOR FY 2020-21 (MU) ................. 62 TABLE 55: RATE OF FREE POWER FOR FY 2020-21 (RS./l<WH) .................................. 66 TABLE 56: RENEWABLE PURCHASE OBLIGATION (RPO) FOR FY 2020-21.. .................. 66 TABLE 57: TRANSMISSION CHARGES FOR FY 2020-21 (RS. CR.) ............................... 67 TABLE 58: POWER PURCHASE SUMMARY FOR FY 2020-21.. ....................................... 67 TABLE 59: DISTRICT-WISE DETAILS OF EXISTING ELECTRICITY DISTRIBUTION

INFRASTRUCTURE OF UTIARAKHAND (AS ON 30-10-2019) ................................ 73 TABLE 60: CAPEX SUMMARY FOR FY 2019-20 AND FY 2020-21 (RS. CR.) ................... 74 TABLE 61: PROPOSED YEAR-WISE EXPENDITURE OF CENTRAL SCHEMES (RS. CR.) .... 76 TABLE 62: FUNDING MECHANISM OF DDUGJY FOR UTIARAKHAND ............................ 76 TABLE 63: ANNUAL FUNDING PLAN FOR DDUGJY SCHEME (RS. CR.) .......................... 77 TABLE 64: FUNDING MECHANISM OF IPDS FOR UTIARAl<HAND ................................. 77 TABLE 65: ANNUAL FUNDING PLAN FOR IPDS WORl<S .............................................. 78 TABLE 66: CAPITAL EXPENDITURE PROPOSED FOR LOAD GROWTH DURING 3RD

CONTROL PERIOD (RS. CR.) ............................................................................ 81 TABLE 67: SUBSTATIONS CONSTRUCTED/UNDER CONSTRUCTION DURING FY 2018-19

..................................................................................................................... 81 TABLE 68: ANNUAL FUNDING PLAN FOR CONSTRUCTION OF 33/11 KV SUBSTATION

AND LINES ..................................................................................................... 82 TABLE 69: YEAR WISE DETAILS OF PTW CONNECTIONS ........................................... 82 TABLE 70: ANf"UAL FUNDING PLAN FOR RELEASE OF PTW CONNECTIONS ................. 83 TABLE 71: YEAR WISE EXPENDITURE ON INSTALLATION OF METERS ......................... 83 TABLE 72: ANNUAL FUNDING PLAN FOR INSTALLATION OF METERS .......................... 83 TABLE 73: YEAR WISE EXPENDITURE ON INSTALLATION OF NEW BREAKERS ............. 84 TABLE 74: ANNUAL FUNDING PLAN FOR INSTALLATION OF NEW BREAKERS ............... 84 TABLE 75: YEAR WISE EXPENDITURE ON INSTALLATION OF CSS 990 KVA ................. 84 TABLE 76: ANNUAL FUNDING PLAN FOR INSTALLATION OF CSS 990 l<VA ................... 84 TABLE 77: YEAR WISE EXPENDITURE ON LAYING DOWN LT LINES FOR NEW

CONNECTIONS ................................................................................................ 85 TABLE 78: ANNUAL FUNDING PLAN FOR LAYING DOWN LT LINES FOR NEW

CONNECTIONS ................................................................................................ 85 TABLE 79: CAPITAL EXPENDITURE PROPOSED FOR LOSS REDUCTION (RS. CR.) ......... 85 TABLE 80: YEAR WISE EXPENDITURE FOR INSTALLATION OF AMR METERS ................ 87 TABLE 81: ANNUAL FUN DING PLAN FOR INSTALLATION OF AMR METERS ................... 87 TABLE 82: YEAR WISE EXPENDITURE ON LAYING OF LT ABC ..................................... 87 TABLE 83: ANNUAL FUNDING PLAN FOR LAYING OF LT ABC ...................................... 87 TABLE 84: YEAR WISE EXPENDITURE ON REPLACEMENT OF DEFECTIVE METERS ........ 88 TABLE 85: ANNUAL FUNDING PLAN FOR REPLACEMENT OF DEFECTIVE METERS ......... 88 TABLE 86: YEAR WISE EXPENDITURE ON REPLACEMENT WITH PRE-PAID METERS ...... 88 TABLE 87: ANNUAL FUNDING PLAN FOR REPLACEMENT WITH PRE-PAID METERS ........ 89 TABLE 88: ANNUAL EXPENDITURE DETAILS ............................................................. 89 TABLE 89: ANNUAL FINDING PLAN FOR LAYING OF 11 KV AND 331<V CONDUCTOR IN

FOREST AREA ................................................................................................. 89 TABLE 90: ANNUAL EXPENDITURE DETAILS ............................................................. 89 TABLE 91: ANNUAL FINANCING PLAN FOR LAYING OF 11 KV AND 33 KV UG CABLES .. 90

5

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______ ,, _____ ·- --------- ·--- .. --- ---

TABLE 92: CAPITAL EXPENDITURE PROPOSED FOR SYSTEM RELIABILITY & SAFETY IMPROVEMENT(RS. CR.) ................................................................................. 90

TABLE 93: YEAR WISE EXPENDITURE ON INSTALLATION OF ADDITIONAL TRANSFORMERS ............................................................................................. 90

TABLE 94: CAPACITY WISE DETAIL ON INSTALLATION OF ADDITIONAL TRANSFORMERS ............................................................ 91

TABLE 95: ANNUAL FUNDING PLAN FOR INSTALLATION OF ADDITIONAL TRANSFORMERS ............................................................................................. 91

TABLE 96: YEAR WISE EXPENDITURE ON INSTALLATION OF PROTECTION SYSTEM ..... 91 TABLE 97: ANNUAL FUNDING PLAN FOR INSTALLATION OF PROTECTION SYSTEM ...... 92 TABLE 98: YEAR WISE EXPENDITURE ON INSTALLATION OF POLES AND GUARD WIRES,

RECONDUCTORING OF LINES, ETC. (RS. CR.) ................................................... 92 TABLE 99: ANNUAL FUNDING PLAN FOR INSTALLATION OF POLES, GUARD WIRES,

RECONDUCTORING OF LINES, ETC. (RS. CR.) ................................................... 92 TABLE 100: CAPITAL EXPENDITURE PROPOSED FOR CREATION OF INFRASTRUCTURE

FACILITIES AND OTHER MISCELLANEOUS WORKS (RS. CR.) .............................. 93 TABLE 101: YEAR WISE EXPENDITURE FOR INSTALLATION OF METER TESTING

EQUIPMENT (RS. CR.) ..................................................................................... 93 TABLE 102: ANNUAL FUNDING PLAN FOR INSTALLATimJ OF METER TESTING

EQUIPMENT (RS. CR.) ..................................................................................... 94 TABLE 103: YEAR WISE EXPENDITURE FOR INSTALLATION OF CONSUMER CARE

CENTRES, E-PAYMENT OF BILLS AND CASH COLLECTION CENTRES .................... 94 TABLE 104: ANNUAL FUNDING PLAN FOR INSTALLATION OF CONSUMER CARE CENTRES,

E-PAYMENT OF BILLS AND CASH COLLECTION CENTRES .................................... 94 TABLE 105: CAPITAL EXPENDITURE FOR RENOVATION, CAPACITY AUGMENTATION AND

MODERNIZATION OF WORKSHOPS ................................................................... 95 TABLE 106: YEAR WISE EXPENDITURE ON NON-RAPDRP IT EXPEl~SES ...................... 97 TABLE 107: ANNUAL FUNDING PATIERN ON NON-RAPDRP IT EXPENSES .................... 97 TABLE 108: YEAR WISE EXPENDITURE ON MISCELLANEOUS WORKS ......................... 98 TABLE 109: ANNUAL FUNDING PATIERN ON MISCELLANEOUS WORKS ...................... 98 TABLE 110: PROPOSED CAPITAL EXPENDITURE AND CAPITALISATION FOR 3"° CONTROL

PERIOD (RS. CR.) ........................................................................................... 99 TABLE 111: SOURCE OF FUNDING FOR CAPITALISATION (RS. CR.) ........................... 99 TABLE 112: PROPOSED GFA AND CWIP (RS. CR.) ..................................................... 99 TABLE 113: INTEREST OF NORMATIVE LOAN BALANCE AND ADDITIONS (RS. CR.) .... 100 TABLE 114: APPROVED REPAYMENT SCHEDULE FOR REC OLD LOANS (RS. CR.) ........ 100 TABLE 115: INTEREST OF NORMATIVE LOAN BALANCE AND ADDITIONS (RS. CR.) .... 100 TABLE 116: PROJECTED CONSUMER SECURITY DEPOSIT (RS. CR.) ........................... 101 TABLE 117: PROJECTED RETURN ON EQUITY (RS. CR) ............................................. 101 TABLE 118: NET EMPLOYEE ADDITION AND GROWTH FACTOR ................................. 103 TABLE 119: PROJECTED EMPLOYEE COSTS (RS. CR.) ............................................... 104 TABLE 120: ADDITIONAL PROVISIONING FOR DATA CENTRE (RS. CR.) ..................... 106 TABLE 121: PROJECTED A&G EXPENSES FOR FY 2019-20 AND FY 2020- (RS. CR.) ..... 107 TABLE 122: PROJECTED REPAIR AND MAINTENANCE EXPENSES (RS. CR.) ................ 108 TABLE 123: OPERATING AND MAINTENANCE EXPENSES (RS. CR.) ............................ 108 TABLE 124: PROPOSED DEPRECIATION FOR FY 2019-20 AND FY 2020-21 (RS. CR.) .. 109 TABLE 125: PROJECTED INTEREST ON WORKING CAPITAL (RS. CR) ......................... 110 TABLE 126: PROJECTED NON-TARIFF INCOME (RS. CR.) .......................................... 110 TABLE 127: ARR FOR FY 2019-20 AND FY 2020-21 (RS. CR.) ................................... 112 TABLE 128: CATEGORY-WISE REVENUE FORECAST FOR. FY 2020-21 AT EXISTING

TARIFF .......................................................................................................... 112 TABLE 129: REVENUE GAP FOR FY 2020-21 (RS. CR) ............................................... 113 TABLE 130: PROJECTED REVENUES FOR FY 2020-21 AT PROPOSED TARIFFS ............. 113 TABLE 131: CUMULATIVE REVENUE GAP BY THE END OF FY 2020-21 ON ACCOUNT OF

TARIFF REVISION................. .. .......... 114 TABLE 132: WHEELING CHARGES FOR OPEN ACCESS CONSUMERS DURWG FY 2020-21

... 116

6

------,-,. --- ··------

TABLE 133: PROPOSED WHEELING CHARGES FOR FY 2020·21 ................................. 116 TABLE 134: PROPOSED CROSS-SUBSIDY SURCHARGE FOR FY 2020·21 (RS. PER UNIT)

.................................................................................................................... 117 TABLE 135: CATEGORY-WISE AND SLAB·WISE EXISTING TARIFF V!S·A·VIS PROPo'SED

TA RIFF .. . . .. .. . .. . .. .. .. . . .. .. . . . .. . . .. .. .. .. .. .. .. . . .. .. . . .. .. .. .. .. .. .. . .. .. .. .. .. . .. .. . .. .. . .. .. . ........... 119

7

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I n

1.1 As per the provisions of the Uttar Pradesh Reorganization Act 2000, enacted by the Parliament of India, the State of Uttaranchal came into existence on November 9, 2000. Section 63(4) of the above Reorganization Act allowed the Government of Uttaranchal (hereinafter referred to as "GoU" or "State Government") to constitute a State Power Corporation at any time after the creation of the State.

1.2 GoU, accordingly, established the Uttaranchal Power Corporation Limited (hereinafter referred to as UPCL/Petitioner) under the Companies Act, 1956, on February 12, 2001 and entrusted it with the business of transmission and distribution in the'State. Subsequently, from April 1, 2001, all works pertaining to the transmission, distribution and retail supply of electricity in the area of Uttaranchal were transferred from UPPCL to UPCL, in accordance with the Memorandum of Understanding dated March 13, 2001, signed between the Governments of Uttaranchal and Uttar Pradesh.

1.3 Subsequently, the Uttarakhand Electricity Regulatory Commission (UERC, hereinafter referred to as the Commission) was constituted by Government of Uttarakhand, vide Notification 03/9-3- URJA/2002 dated 1st January, 2002 under the Electricity Regulatory Commission Act, 1998. The State Government also subsequently created a new company "Power Transrnisslon Corporation of Uttaranchal Limited", now renamed as "Power. Transmission Corporation of Uttarakhand Limited (PTCUL) to undertake the business of transmission within the State, with effect from June 1, 2004. Since then Uttarakhand Power Corporation Ltd. (UPCL) a company wholly owned by the Government of Uttarakhand became the sole distribution licensee engaged in the business of distribution and retail supply of power in the State of Uttarakhand.

1.4 UPCL provides the quality & reliable power supply of electricity to all the consumers spread over the 13 Districts of Uttarak.hand i.e. Dehradun, Pauri, Tehri, Haridwar, Pithoragarh, Almora, Nainital, Uttarkashi, Udharn Singh Nagar, Rudraprayag, Chamoli, Bageshwar & Champawat.

Performance of UPCL in the Past

1.5 Since the incorporation of UPCL, the company has been continuously undertaking various measures and initiatives for improvement of electricity supply to the consumers and at the same time provide power at affordable rates to the consumers within the State. This can only be achieved by overall improvement in both technical and financial parameters of the utility. It is submitted that si nee the incorporation of UPCL, the consumer base has grown from 8.4 lacs to 24.27 lacs i.e. 6.54cl/o p.a. Inspite of a difficult terrain \1vhere the small consumer nurnbers and load are spread far across, the Petltioner has been able to reduce its distribution losses from 26.65% in FY 2001-02 to 14.32% in FY 2018-19.Some of the key performance indicators are summarized below:

Tabte i: Key Performance Indicc-1tors

2 Load MW 1466 6533 345.63% ----~--"---·"--·

3 Energy Input MU 3038.8 13,803.71 354.25%

4 Energy Sold MU 2,229.09 11,826.68 430.56%

5 Billing Efflciency % 73.35% 85.68% 16.80%

6 Distribution Losses % 26.65% 14.32% -46.27%

7 Collection Efficiency % 75.23% 97.44% 29.52%

8 AT&C Losses % 44.82% 16.52% -63.14%

9 Share Capital Rs. Cr. 5.00 1428. 91 284. 782%

10 Turnover Rs. Cr. 668.8

6218.61 829.82% 2002-03 ------

11 Gross Fixed Assets Rs. Cr. 1083.98 5864. 59 441.02% --·------__ ,,,, ___ ,, ~-·----·--

12 Receivables for sale

Rs. Cr. 682.06 1677.87 146.00% of ~vver

13 33/11 kV Substation !lo. 137 346 152.55% ·----14

Capacity of 33/ l lkV MVA 776 4613.65 494.54%

Substation ---~-~--··-----15

11/0AkV Distribution !lo. 20728 74493 259.38%

Transformers ---Capacity of 11/0.4 kV

16 Distribution MVA 1220 4513.08 269.92% Transformers ____ ,, ____

17 33 kV Line Km. 2389 5362 124.45%

18 11 kV Line Krn. 21576 43512 101.66%

19 LT Line Krn. 32617 64480 97.68<\/o

Improvement in Billing Efficiency I Reduction in Distribution Loss

1.6 Hon'ble Commission in its Tariff Order for FY 2003-04 read with Tariff Order for FY 2007-08 had estimated the distribution losses of UPCL for FY 2002-03 as 44.32%. Hon'ble Commission in its Tariff Order for FY 2018-19 trued up the expenses and revenue of UPCL for FY 2017-18 and approved the distribution losses for this year as 14.50%. The details of year wise distribution losses may be shown as follows:

Tab!e 2.: Distribution Loss (in °/o)

2003-04

2004-05 36.32(Vo 36.63% 26.66%

2005-06 32.32% 33.38% 28.37%

2006-07 28.32% 32.84% 29.73%

2007-08 24.32% 30.98% 29.65% -·---2008-09 22.32% 3L02% 28.01%

--·----- --·-2009-10 20.32% 25.09% 24.53%

2010-11 19.00% 22.72% 21.61 %

2011-12 18.00% 21.27% 19.96%

2012-13 17.00% 21.70% 20.50% -----2013-14 16.00% 20.66% 19.18%

2014-15 15.50% 19.06% 18.53%

2015-16 15.00% 18.81 % 18.01 % c---------·----------·---+-----------+---2016-17 15.00% 17.10% 16.68%

9

\,Q~ -·

------------------ ---.,-- - ------- ------------ ----- -

In1provement in Revenue Collection

1.7 Revenue Collection per unit has also improved from 2007-08 onwa,·ds on account of higher collection and reduction in dist,·ibution loss. The yea,· wise revenue collected per unit of input energy is as provided in table below:

Table 3: Revenue Collection

2007-08 6,732.05 1,149.20 1. 71 100.00% 1. 71

2008-09 7,631.44 1,655.51 2.17 120. 30% 1.80

2009-10 8,280.09 1,958.24 2.36 123.62% 1.91

2010-11 9,249.42 2,515.57 2.72 138.38% 1.97

2011-12 10,310.64 2,927.57 2.84 141.33% 2.01 ------- -------- -----

2012-13 10,789.11 3,468.73 3.22 153.51% 2.09

2013-14 11,216.31 3,876.51 3.46 160.15% 2.16 ----

2014-15 11,888.23 4,183.88 3.52 160.52%± 2.19 ----

2015-16 12,559.60 5,242.86 4.17 176. 75% 2. 36 ------

I 2016-17 12,688.46 5,572.90 4.39 18/;L 56% 2.33 ----- -----

2017-18 13,213.73 6,031.44 4.56 200. 74% I 2.27 ---·--- --·-·----------··-·--- ·---- ____ ,, _______

2018-19 13,803.71 6,376.41 4.62 204.06% 2.26

CAGR of Improvement 2.26%

1.8 The above analysis shows that within the past perios startin from FY 2007-08, the Petitioner improved its Revenue Collection @ 2.26% p.a. (net of Tariff hike).

Improvement in Productivity

1.9 The improvement in productivity may be explained with the help of the following analysis:

Table 4: Productivitv and Rate of Return

A 1------4-------

2008-09

2009·-10

252.97

503. 68

B

0.10

C

7,631.44 -------+--

0.21 8,280.09

D (B*C) E (D/A)

73.48 29.04% --------·-----,

170.67 33.88% -------~------~------------~--

10

-- ----- -- -- ---- ---- ----.,-- ----l

_ __j

2010-11 768.67 0.26 9,249.42 238. 99 31.09%

2011-12 1,070.61 0.30 10,310.64 311.38 29.08%

2012-13 1,327.58 0.39 10,789.11 417.91 31.48%

2013-14 1,626.25 0.45 11,216.31 505. 90 31.11%

2014-15 2,090.42 0.49 11,888.23 577 .12 27.61%

2015-16 2,622.34 0.65 12,559.60 822.21 31.35%

2016-17 2,860.63 0.62 12,688.46 789.50 27.60%

748.97 22.99% 2017-18

3,258.18 0.57 13,213.73

2018-19 4,089.02 0.56 13,80].71

768.41 18.79% -- -· --

Total 20470.35 5424.54 26.50°/o

Average Rate of Return on Investments- 5424.54/20470.35= 26.50%

1.10 The above analysis shown that the average rate of return on the investments made from FY 2008-09 to FY 2018-19 is 26.50%.

Performance Rating of UPCL

1.11 It is also worthwhile to mention here that Ministry of Power, Go! is evaluating the performance of Power Distribution Utilities from FY 2011-12. The yea1·-wise rating assigned to the Petitioner in this evaluation is as below:

2017-18

2016-17

2015-16

2014-15

2013-14

2012-13

2011-12

80.26

Table 5: Performance Rating of UPCL

A+ 7 of 41 (State 3,d

in the Country)

Very High Operational and Financial Performance

Ca abi!it

4 of 41 (State 211d Very High Operational and 82.1 Financial Performance

in the Country) +--------+--------+----------+------'C"'-aQabilit

Very High Operational and

A+

81.2 A+

67.7 A

67.50 A

55.3 B+

29 c+

4 of 41 (State 2'd in the Country)

7 of 40( State 3'' in the Countr

7 of 40 (State 4th

in the Countr

Position not declared

29 of 39

Financial Performance Capability

High Operational and Financial Performance Ca ability

High Operational and Financial Performance Capabilit

Moderate Operational and Financial Performance

Capability Low Operational and Financial

Performance ~a ability

11

l

1.12 It is clear from the above that there is continuous improvement in the performance of the Petitioner and the Petitioner within a period of 5 years converted its position from "Low Operational and Financial Performance Capability" to "Very High Operational and Financial Performance Capability" through its efforts and performance.

Major Schemes Implemented w.r.t. distribution works

1.13 UPCL has in the past as well as is currently implementing various capital schemes for providing 24X7 uninterrupted and quality power to the consumers within the State. A large number of works including electrification of the un­electrified households, strengthening of the distribution network, modernization of the systems, computerization and technological upgradation of the system and process, etc. are under various stages of implementation. Successful implementation of these works and schemes has helped the utility in delivering quality and reliable power to its consumers in the past and shall continue to do the same on sustainable basis in future as well. Also completion of DDUGJY scheme and Saubhagya scl1eme has ensured power to all consumers in the State.

1.14 A brief snapshot of the various schemes being undertaken by the Petitioner in the present as well as those undertaken in the past along with their current status is provided below:

A. APDRP (Accelerated Power Development & Reform Program)

1.15 As a part of distribution reforms, GD! launched APDP (Accelerated Power Development Program) in 2001 which was later rechristened as APDRP (Accelerated Power Development and Reforms Program) during the 10th Five Year Plan. APDRP Scheme was sanctioned in Uttarakhand by Ministry of Power, Go!, New, Delhi in November'2002 vide OM No. F-7/127/2002 dated 27/11/2002 for all six circles of the states. The main objectives of the program were Improving Financial Viability, Reduction of AT&C losses, Improving Customer Satisfaction, Increasing reliability of Power Supply & Transparency through I.T. Applications.

Significant achievement of APDRP implementation in UPCL

• APDRP implementation resulted in AT&C loss reduction from 52.98% in F.Y. 2003-04 to 37.12% in FY 2007-08

Improvement in Collection Efficiency from 66.72 % in F.Y. 2003-04 to 89.38 % in FY 2007-08

Strengthening of electrical network under APDRP helped UPCL in catering to the growing demand of UPCL from 3038.80 MU in FY 2001-02 to6732.05 MU in FY 2007-08 which was majorly due to development of industrial estate by Govt. of Uttarakhand and 24x7 supply in rural areas.

B. Raj iv Gandhi Gram in Viduytikaran Yojana (RGGVY)

1.16 Rajiv Gandhi Gramin Viduytikaran Yojana (RGGVY) for Uttarakhand was sanctioned in the F.Y. 2005-06 in 10th Plan. As per Government of India, Ministry of Power O.M. no. 44/19/2004-D(RE) dated 18/03/2005, 90% capital subsidy was provided for overall cost of the projects. This scheme of "Rural Electricity Infrastructure and Household Electrification" was aimed at

---------·---

/

'

12

theachivement of the National Common Minimal Programme (NCMP) goal of providing access to electricity to all households.

c. Restructured - Accelerated Power Development & Reform Program (R­APDRP)

1.17 To continue the support to distribution reforms during the 11th Five Tear Plan, GO! has continued R-APDRP (Restructured APDRP) with revised terms and conditions. The R-APDRP primarily aims at reducing Aggregate Technical and Commercial (AT&C) losses in urban areas. It is a necessary condition of the scherne that the utilities would need to demonstrate performance improvement for availing financial benefits provided under the scheme. This wou Id require collection of accurate data and measurement of loss reduction performance. Data integrity and performance measurement pose many challenges for the state power utilities. This problem can be surmounted only by:

setting up reliable and "no manual touch" systems for data collection; and

adoption of Information Technology in the areas of energy accounting.

Projects under the R-APDRP program are divided into 2 parts:-

Part-A shall include the projects for establishment of baseline data and IT applications for energy accounting/ auditing & IT based consumer service centres,

Part-B shall include regular distribution strengthening projects.

R-APDRP Part-'A 'implementation

1.18 UPCL always emerged one of the leading states in achieving each &every milestone of R-APDRP Part-A implementation from concept to commissioning phases of the program across the country, the credit of best implementation of the program goes to proper planning at the inception level with timely preparation of Detailed Project Reports, appointment of IT Consultant & IT Implementation Agency, Readiness of Data Center/Customer Care Center & other GIS & Meter related activities.

Some of the best practices adopted by UPCL at the inception level are:­

./ Creation of dedicated team at the inception level,

./ proper civil infra at site offices for IT setup, / focus on 0\1Vn premises instead of rented to avoid re-work, ./ involvement of field units at the initiation level by entrusting them duties of

Ring-Fencing & Metering, connecting nearest office on own RF back-bone, ./ Training by core team till the last person involved in business process at

each office . ./ Coordination among different states for best practice & problem sharing.

1.19 R-APDRP town areas caters to approx .. 28% (6.79 Lacs) of Consumer base (24.27 Lac Mar-19) covered under selected 31 towns, commercial modules developed have been implemented all across the utility (including non-RAPDRP areas also) in an integrated manner which has resulted in extending benefits of R-APDRP across length and breadth of state & ,·esultecl in optimum utilization of

13

L_

----- -------------------------- ---------- - -

IT investments done in the program & brought uniformity in UPCl.'s all business processes.

Significant achievement of R-APDRP Part-A implementation

1.20 R-APDRP implementation provided the integrated IT backbone to UPCL wherein UPCL started from the scratch as all the billing applications before R-APDRP were running In different islands and are based on manual processes including human Interventions & errors. UPCL implemented all rnandatory modules & running them satisfactorily in the integrated manner.

1.21 R-APDRP resulted in bringing transparency & accountability in the system, focused monitoring at the feeder level, enabled accurate rneasu rement of reliability of power, improved consumer services through 24x7 customer care center 1 strict monitoring over consumer requests & applications for New Service Connections & provision of multiple bill payments options to consumers. With the impact of implementation the AT&C losses of the towns are reduced in all 31 towns.

1.22 Feeder wise consumer availability through R-APDRP enabled UPCL to participate in the "Urja Mitra- Outage Management System" of RECTPCL. With the ROBUST IT backbone UPCL is planning to have "Smart Metering" project in near future. UPCL is also envisaging to use the same IT system for "11 kV Rural Feeder Audit" & monitoring through "National Power Portal" to meet the commitment done under "UDAY" with the assistance of RECTPCL where in modern installation at Rural Feeders is in progr·ess by M/s Analogies Ltd, Central Implementing Agency appointed by M/s RECTPCL.

R-APDRP Part-B implementation

Scheme Coverage

• 31 Towns of population more than 10,000 (Population covered - 18.87 lac)

Aimed at strengtl1ening of distribution infrastructure.

Expected Outcomes

• Improved system reliability due to installation of additional sub-stations, transformers and feeder strengthening,

Reduction in losses due to installation of Aerial Bunch Cable/ installing meter outside the consumer premises.

• Reduction of 1 °/o AT&C loss results into saving equivalent to Rs. 67 Cr.

System readiness to cater to the future load growth.

SCADA compatibility for Dehradun Town.

D. UJALA - Unnat Jyoti By Affordable LEDs for All

1.23 UJALA scheme aims to promote efficient use of energy at the residential level; enhance the awareness of consumers about the efficacy of using energy

14

--- --------·-- ---- ------ ·----- __J

efficient appliances and aggregating demand to reduce the high initial costs thus facilitating higher uptake of LED lights by residential users. The scheme was initially labeled DELP (Domestic Efficient Lighting Program) and was re­launched as UJALA.

E.UDAY - Ujjwal Assurance Discom Yojana MoU signed on 31st March-2016

1.24 UPCL participated in the Ujwal DISCOM Assurance Yojana(UDAY) for operational improvement in the Company.

1.25 The difference of actuals and approved values is being claimed in this petition as true-up of expenses and revenue for FY 2018-19.

1.26 No financial assistance has been provided to UPCL under the scheme.

F. DDUGJY - Deen Dayal Upadhyaya Gram Jyoti Yojana

1.27 This scheme has been launched by Government of India with the intent to provide round the clock power to the rural households and adequate power to Agriculture Consumers. The earlier scheme for rural electrification viz. Rajiv Gandhi Grameen Vidyutikaran Yojana (RGGVY) has been subsumed in the new scheme as its rural electrification component.

G. IPDS ( Integrated Power Development Scheme)

1.28 Govt. of India has launched Integrated Power Development Scheme (IPDS) for the urban areas with the following components:

Strengthening of Sub-transmission and Distribution network in urban areas including provisioning of solar panels on Govt. buildings including Net-metering.

Metering of feeders/ distribution transformers / consumers in urban areas and,

IT enablement of distribution sector and strengthening of distribution network, as per CCEA approval dated 21.06.2013 for completion of the targets laid down under R-APDRP for 12th and 13th Plans by subsuming R­APDRP in IPDS and carrying forward the approved outlay for RAPDRP to IPDS.

1.29 Power Finance Corporation Limited (PFCL) has been designated by Go! as the Nodal Agency for the programme.

Scheme Coverage

36 Towns of population less than 10,000 (Population Covered - 2.43 lac)

Dehradun Town for Solar Roof Top

Sanctioned Cost: Rs. 191.63 Cr. for system strengthening work

Expected Outcomes

AT&C loss reduction

15

~-----·-·------~-------------------·------·--··

~--------- -----------

Improved quality and reliability of supply

Accurate & Reliable Energy auditing

Strengthening of Sub-transmission and Distribution network.

Sola,- panels on Govt. buildings.

Metering of distribution transformers/feeders/consumers in urban area.

H.IPDS IT Phase-II, ERP implementation, AMI & Undergrounding are the other projects which are being taken up by UPCL under IPDS under the guidance of Nodal Agency, PFC.

I. Saubhagya for achieving 100% households has been successfully implemented by UPCL under the guidance of Nodal Agency, REC.

Key factors impacting the financial substainibility of UPCL

16

___ '.:"....._""' __

1. Category wise pending receivables (Rs Cr) from consumers along with ageing schedule

5.96 0.43 0.01 4.60 48.33 No11-D0mestic 0.77 1.16 3.72 3.59 0.00 I 0.00 ' 30.21 J 39.45 LT Industry 0.00 0.00 0.36 0.00 0.00 0.00 3.30 I 3.67 i HT Indust1·y 0.00 0.00 0.00 4.41 0. 00 83.29 187. 05 274. 76 Mixed Load 0.00 0.00 0.05 0.12 0.00 0.00 0.00 0.18

1 Private Tube-wells 0.18 0.27 0.20 I 0.00 0.00 0.00 1.59 2.24 Public Lamps 0.22 I 0.33 o.43 I 0.00 0.00 0.00 0.21 1.19 Public Water Works 0.05 0.07 2.92 0.00 0.00 16.00 5.36 24.39 Govt. Irrigation System 0.00 0.00 8.29 0.00 4. 71 11. 71 0.00 24.72 Railway Traction 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sub-total 5.18 7.78 23.12 8.56 4.73 115.60 253.95 418. 93 Electricity Distribution Circle (Urban), Dehradun

Domestic 0.00 0.00 0.00 0.24 J 0.00 5.81 17.02 ' 23.07 Non-Domestic o.os i 0.07 0.00 1. 70 0.00 1. 91 3.36 7.08

LT Industry 0.00 0.00 0.00 0.11 0.00 0.28 1.15 1.53

1 HT Industry 0.10 0.15 0.00 0.00 0.00 0.00 0.00 , 0.24

2 Mixed Load 0.14 0.21 0.10 0.00 0.27 0.00 0.00 1 0.73 Private Tube-wells 0.00 0.00 0.02 0.00 0.02 0.01 0.10 0.16

'fi l.

Public Lamps 0.00 0.00 0.04 0.00 1.92 0.00 0.00 1.96

Public Water Works 0.00 0.00 0.00 2.55 o.oo I 0.00 8.49 11.04

Govt. Irrigation System 0.00 0.00 0.00 0.00 0.00 0.26 0.00 0.25

i Railway Traction 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ! 0.00

\YI 17

Electricity Distribution Circle, Srinagar

Domestic 2.77 4.16 7.10 3.87 32.14 6.93 23.49 80.46 Non-Domestic · 1.45 2.18 0.00 0.00 14.86 7.19 26.72 52.39 LT Industry 0.15 ! 0.22 0.10 0.18 0.87 0.27 2.14 3.92 HT Industry 3.18 4.77. 8.13 7.75 0.00 0.00 56.26 80.10 Mixed Load 0.04 0.06 0.00 0.00 0.21 I 0.00 0.00 0.30 3 Private Tube-wells 0.00 ! 0.01 0.01 0.00 0.01 0.03 0.00 ! 0.06 Public Lamps 0.52 0.78 2.03 0.00 0.00 0.00 0.02 3.35 Public Water Works 0.00 0.00 14.45 0.00 0.00 0.00 6.37 20.81 Govt. Irrigation System 0.00 0.00 0.00 0.00 0.00 0.00 -2.59 -2.58

I . I . 0.00 I y Ra, way T1·act1on ·--- 0.00 0.00 0.00 0.00 0.00 0.00 0.00

---· Sub-total

r12: 12.17 31.82 11.80 48.08 14.41 112.40 238.81

I Electricity Distribution Circle, Roorkee + Hard war

! Domestic 20.22 30.32 ilS.19 1

34.63 0.00 15.88 200.81 350. 04

I

Non-Domestic 0.00 0.00 0.00 6.61 2.17 9.40 96.46 114.65 LT Industry 0.00 0.00 0.00 0.92 0.84 0.00 16.43 ! 18.19

' HT Industry o.oo I 0.00 0.00 0.00 19. 71 0.00 0.00 19.72

I

4 I Mixed Load 0.00 0.00 o.oo I 0.52 0.00 0.00 0.04 1 0.57

Private Tube-wells 0.00 0.00 12.90 . 7.45 1.68 9.04 24.02 55.09

I

Publlc Lamps 1.10 1.65 5.37 0.00 0.00 0.00 0.00 8.13 Public Water Wo1·ks 0.00 0.00 0.00 0.00 0.00 4.67 0.00 4.67 Govt. Irrigation System 0.61 0.92 0.00 o.oo I 10.46 1.72 0.00 13. 70 Railway Traction 0.00 0.00 0.14 0.00 0.00 0.04 0.00 0.18

Sub-total 21. 93 , 32.89 66.60 50.13 34.87 40. 76 337. 75 584.93 '

18 I

J

Electricit Distribution Circler Haldwani

Domestic 0.00 1.32 2.43 14.64 19.06

Non-Domestic 0.00 0.25 0.00 0.00 0.66 10.03 I 10.93

LT Industry 0.00 0.00 0.00 0.00 0.00 0.18 1.20 I 1.38

HT Industry 0.93 1.40 0.00 0.00 1.54 0.90 18.10 22.87

Mixed Load 0.00 0. 00 0.02 0.00 0.21 0.00 0.00 0.23 5

Private Tube-wells 0.03 0.04 0.00 0.00 ' 0.00 0.00 0.12 0.18

Public Lamps 0.64 0.96 2. 13 0.00 0.00 o.oo I 0.71 4.44

Public \1\/ater Works 2.78 4.17 5.39 0. 00 0.00 o.oo I 16.06 28.41

Govt. Irrigation System 4.94 7.41 1.24 o. 00 12.60 0.00 29.47 . 55.67

Railway Traction 0.00 . 0.00 o.oo I o. 00 0.00 0.00 0.00 0.00

Sub-total 9.59 14.38 9.03 I o. 01 15.67 4.17 90.33 143.18

Electricity Distribution Circle, Rudrapur + Kashipur

Domestic 2.34 3.51 0.00 13.36 0.00 15, 11 13.70 48.03

Non-Domestic o.oo I 0.00 0.00 0.00 o.oo 10.81 19.46 30.26

LT Industry 0.00 o.oo I 0.00 4.55 0.00 0.00 0.00 4.55

HT Industry 0.00 0.00 0.00 0.00 0.00 0.00 ·86. 12 ·86. 12

6 \ Mixed Load 0.00 0.00 0.00 0.00 0.00 0.00 ·0.83 ·0.84

j Private Tube-wells 0.58 0.87 7.21 8.31 10.41 14.10 43.36 84.84 '

Public Lamps 0.00 0.00 23.92 I 0.00 0.00 0.00 0.00 23.92

Publlc Water Works 0.46 0.69 o.oo I o.oo I 0.00 5.79 9.3s I 16.32

Govt. Irrigation System o.oo I 0.00 11.30 o.oo I 5.84 3.68 o.oo I 20.82

Railway Traction o.oo I 0.00 0.00 o.oo I 0.00 0.00 0.00 o.oo 1

Sub-total 3.39 5.08 42.43 26.22 16.24 49.50 ·1.06 141.80

'7' 7 Electricity Distribution Circle,

'\ 5\ ~.,.-, Ran ikh et+ Pith roga rh \ ,:-. .. ../

19

Non-Domestic 2.35 5.83 5.44 4.47 46.93

LT Industry 0.12 0.18 0.09 0.00 0.02 0.19 2.46 3.06

HT Industry 0.02 0.02 0.00 0.08 0.00 0.00 0.16 0.28

Mixed Load I

0.19 0.21 0.39 I 0.24 · 0.121 0.01 0.00 1.16 I ·---0.09 ! Private Tube-wells 0.01 0.02 0.05 0.05 0.04 0.02 0.28 ·

Public Lamps 0.00 0.00 1.82 0.00 0.07 0.00 0.00 1.90

Public Water Works 1.99 ' 2.98 2.52 0.00 0.00 0.00 25.50 33.00

Govt. Irrigation System L81 1

2.72 6.94 0.00 3.28 2.03 5.48 22.26

Railway Traction 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 I

84.16 1 Sub-total 7.89 11.84 20.34 I 9.41 14.24 9.49 157.37

Total UPCL I Domestic 31.04 46.56 65.32 54.92 38.45 53.52 327.69 617.51

Non-Domestic 4.61 6.92 9.81 18. 79 22.47 34.43 204.66 I 301. 69

LT Industry 0.27 0.40 0.56 5. 76 1.-73 0.91 26.67 36.29

HT Industry 4.23 ' 6.34 8.14 12.25 21.26 84.19 115.44 I 311.85

Mixed Load 0.31 0.46 0.38 0.65 1.08 0.01 -0.56 2.33 8

12.17 I 69.27 ' Private Tube-wells 0.81 1.21 20.38 15.82 23.21 142. 85

Public Lamps 2.48 3.72 35.74' 0.00 1. 99 0.02 0.94 . 44.88

~Public Water Works 5.27 I 7.91 25.28 2.56 0.00 26.45 71.17 138.64 I ------

1.37 I Govt. Irrigation System 11.05 27.77 0.00 36.90 19.41 32.35 134.85

Railway Traction o.oo I 0.00 0.14 0.00 0.00 · 0.04 0.00 0.18

Total 56.39 84.58 193.51 110.74 136.04 242.19 907.63 1731.08

20

0

'\c . ~

\ s . ./

A total of Rs 1731.08 Cr is yet to be received from consumers in ARR of rvRs 6500 Cr. This impacts the financial conclitlon of UPCL

severely as, as per the UERC's methodology the collection effeicincy is not factored in the revenue as net billed revenue is considered while determining gap

2. High Loss feeders identified in RAPDRP Towns

2 LAND HORA 88.55 39.00 83.00

3 GADARPUR 80.97 42.00 83.00 65.14

4 JASPUR 79.45 48.00 91.00 56.32

5 LAKSAR 76.82 65.00 76.00 50.60

6 KASHIPUR 54.96 73.00 74.00 45.98

7 JOSHIMATH 59.28 60.00 94.00 43.60

8 KICHHA 48.63 65.00 95.00 38.25

9 HALD WAN! 56.56 73.00 85.00 37.95

10 RUDRAPUR 42.16 67.00 96.00 35.68

11 UTTARKASHI 47.25 66.00 98.00 35.32

12 VIKASNAGAR 55.31 79.00 83.00 34.43

13 SITARGANJ 42.28 75.00 88.00 34.00

14 GOPESHWAR 44.45 76.00 88.00 33.12

15 KOTDWAR 41.14 79.00 88.00 30.48

16 PAURI 46.42 75.00 97.00 27.25

17 ROORKEE 45.76 75.00 97.00 27.25

18 RAMNAGAR 42.21 80.00 91.00 27.20

19 BAZPUR 63.89 73.00 100.00 27.00

20 TANA KP UR 57.02 83.00 89.00 26.13

21 HARIDWAR 49.31 86.00 88.00 24.32

22 TEHRI 46.94 85.00 91.00 22.65

23 KHA TI MA 68.02 79.00 100.00 21.00

24 PITHORAGARH 48.85 79.00 100.00 21.00

25 RANIKHET 32.85 87.00 91.00 20.83

I

21

'I I

27 SRINAGAR 56.45 81.00 100.00 19.00

28 DEHRADUN 35.5 84.00 97.00 18.52

29 R!SHIKESH 33.85 85.00 97.00 17.55

30 ALM ORA 38.58 87.00 96.00 16.48

31 MUSSOORIE 26.28 87.00 97.00 15.61 ···----

3. Cases under arbitration

a) Part A List of Appeals/Applications against Arbitration Award.

1

2

UPCL V /s Himlayan Hydro Power Limited

UPCL V/s M/s Yamuna Gas and Chemicals

1 EE, D11arcl1ula Hlgh Court,

Nainltal

1. UPCL, section 34 application Under Arbitration & Conciliation Act, 1996 is pending before Hon'ble High Court, Nainital.

2. Himlayan Hydro Power Limited, execution petition ls pending befo1·e ADJ (Commerical) Court ..

UPCL, section 34 ADJ application Under

Rs. 51,72,504 deposited before Hon'ble ADJ (Commerical) Court Dehradun as directed by

Shri. Naresh Pant before Hon'ble Higl1 Cou1·t, Nainitail

&

Hon'ble High Court, Shri S.M.Jain before ADJ 1'

Nainital dated 05.11.2019 (Commercial) court, Dehraudn

!

Secondary Arbitration & Conciliation Shri S.M.Jain before ADJ , 1 works Division, (Commerial) Act, 1996 is pending 1 Cr. (Approx)

i DDun before Hon'ble ADJ (Comme1·ial) Court

, Court ',:(Commercial) Court, Dehraudnl'

'I Dehi-adun

L_L.. ________ c __ -1 ______ J_ _____ L..D_e_11_r_ad_u_,_' ______ c_ __________ c_ __________ ~

(I 22 '--1 7'""

3

4

5

I UPCL Vs A to z

M/s Uttar Bharat Ltd

UPCL V/s M/s litco

1

1

4

Roorkee Circle

C.E, Commercial

High Court, Nainital

ADJ (Commerlal)

EE, Bageshwar Court Test Almora

I Secondary !works Division i 3

Del1radun

ADJ (Commerial)

Court Dehradun I S. E, Rural,

__ I """ C C,d

~-~------~-

1. UPCL1 appeal is pending before Hon'ble High Court, Nainital.

2. A to Z, execution petition is pending befo1·e ADJ (Commerical) Court, Del11·adun.

Both tl1e party have flied section 34 application Unde1· Arbitration & Conciliation Act, 1996 which are pending before ADJ (Commerlal) Court Dehradun

1. UPCL section 34 applications Under Arbitration & Conciliation Act, 1996 is pending before Hon'ble ADJ (Commei-lal) Court Dehradun.

2. M/s Jitco, execution petitions is pending before ADJ (Commerical) Court ..

Rs. 26, 76,476 is deposited before Hon'ble District jug de, Roshanbad, Haridwar as per the Hon'ble High Court, Nainital stay order as a condition of depositing of 50% of disputed amount.

Hon'ble Arbitrator vide Award dated 29.09.2017, Awarded only 1.19 Cr. in the claim petition.

Total allowed clalm against filed claim of Rs. 8.14 Cr. is Rs. 1.19 Cr.

30 Cr. (Approx upto 31.01.2019)

Shri. Naresh Pant before Hon'ble High Court, Nalnitail

&

Shri P.K.Agarwal before

Shri Anurag Sharma,

Shrl Yakesh Anand, Senior, Advocate

Shri Anurag Sharma, Advocate

23

1. DNC section 34

application Under Honble Arbitration Communication Arbitration & Awarded Rs. 11

[ (55.0 lac. Matter) conciliation Act, 1996 1,21,21,887.00 in favor of

' ADJ is pending before ADJ UPCL out of vvhich Rs I (Commerial) (Commerial) Court 57,20.000 has already 'I

6 1 CBSC Haldwani Court Dehradun recovered by UPCL and

·1 Dehradun Remaining Rs. 64,01,887 I

2. UPCL, execution has to be recovered from 1 ,

I ~:;~t;~nAi;jending M/s DNC with 8% interest. I I

Shri S.M.Jain

. I (Co111111erical) Court.. -------i I

I ~c-c---c-;--=-:c:-----~--+------t-----+~V;iJ~a~y;K~u;m~aa,r~Ci=hcia~u~h~a~n~, -::t-----------~--t---------:'_1\-Vijay Kumar appeal is pending before Honble Arbitration in \ Chauhan V/s UPCL High Court, Nainital for passed Awards by whicl1

I

. hearing in respect of in Agreement No.22 it · 'I agreement no. rejected the claim of Rs.

agreement no 12,66,561/- of Shri Vijay 23/ECDH/2008-09 dated Chauhan, However

I

High court, 02.03.2009, accepted the claim of Rs. Nainital 2,78,085/- with effect

& from 08.11.2018 along .

1

& with 8% interest and in 2 ECD, Haldwani " h Vljay Kumar Chau an Agreement no 23 it

. District Court, section 34 application rejected the claim of ~s.

. Rudrapur Under Arbitration & 14,95,214/- of Shri V1Jay

I

Conciliation Act, 1996 is Chauhan, However pending before District accepted the claim of Rs. Court, Rudrapur for l,43,717/- with effect

· hearing in respect of from 31.10.2010 along

I agreement no with 8% . interest 22/ECDH/200S-09 dated

7

25.02.2009,

: Shri Bharit Singh, Advocate in Rudrapur

And

Shri Mahesh Lal Advocate in Almora

24

ADJ

1 Ti-ansmission EE Store,

(Commerial)

8 Udhyog Ltd. 2 Court Conciliation Act, 1996 is

Dehradun Dehradun pending before ADJ Approx. 4 Cr Shri S.M.Jaln, Advocate

(Commerial) Court Dehradun for hearing

UPCL V/s M/s UPCL section 34 BHEL application Under

ADJ Arbitration &

9 1 EE, EDD(R) (Commerial)

Conciliatlon Act, 1996 is Harldwar Court

pending before ADJ Dehradun

(Commerial) Court

Shri S.M.Jain, Advocate

Approx. 7.54 Cr

Dehradun for hearing

Total 14

b) Part B List of pending Arbitration cases.

ADJ M/s ICOMM petitions are

1 M/s !COMM Ltd, 2

S.E/ EE, RE, (Commerial) pending befoer ADJ 18.20 Cr. (Approx) Shri S.M.Jain

Hyde1·abad Del1radu11 (Commerial) Court Court Dehradun Dehradun for hearing

Arbitraion is pending

BTC Industries Pvt EE, EDD, Retd District before Hon'ble Arbitator

2 Ltd

1 Rudrapur Judge Shri. Shri K.D.Bl1att (Retd Dist.

Rs 5,86,31,803/- Shri Anurag Sharma

K.D.Bhatt Jugde) for hearing.

25

SRF 1 L:EDD, Retd Justice before Hon'ble Arbitator

'---+--------+--- 1,_p_u_r __ '-I-r-s-ha_d_H_u_s_sa_i_n--+-S-h_r_i -Ir_s_h __ a_d_H_u_s_s_a-in (Retd ' -- Dist. Jugde) for hearing.

4

M/s Kotdwar Steels and lOothersVs. UPCL and others

Total

1

5

Rs 42 lac (Approx) Shri Pyush Garg

Rs 32.46 Cr

A total of 19 cases are under litigation In various forums against which a significant amount of receivables are pending as provided against

each each case in the table above. This revenue has impacted the financial position of UPCL tremendously.

4. Pending Arrears across various divisions

Hon'ble Commission in its Tariff Order dated 27-02-2019 for FY 2019-20 had inter-alia directed the petitioner to liquidate and finalize

atleast 5% of the Not Billed/ Stop Billed (NB/SB) cases. The petitioner issued directions to its field officers from ti me to time but the

desired results could not be achieved due to shortage of manpower. The present status of NB/SB cases is as follows:

2 EDC, (U) Deh1·adun 13,023 49.37

3 EDC, Tehri 14,586 42.30

4 EDC, Srinagar 10,633 49.87

5 EDC, Karnprayag 13,344 8.93

6 EDC, Roorkee 17,723 174.62

7 EDC, Haridwar 11,120 130.06

/'.~' V, 26 !>--'------------------------------------------------

8 EDC, Haldwani 6,826 104.95

!

9 EDC, l<ashipur 10,673 45.05

10 EDC, Ranikhet 16,280 18.83

11 EDC, Rudrapur 16,701 87.70

12 EDC Pithoraga,·h 10,053 10.31

13 Others 1,241 6.14

Total UPCL 1,55,448 779.19

The above status does not include the cases which have been identified by the field units as permanently disconnected but the final bill is still to be issued. With a view to achieve the desired results as per the direction of Hon'ble Commission, the petitioner has decided to engage an outside agency for finalization of the above NB/SB cases. This will help the petitioner for liquidation of such NB/SB cases. Preparation of tender document is in the process and the part - I of the tender has been targeted to be opened by 31-12-2019. The award of the work has been targeted by 31-01-2020 and the work has been targeted to be completed by 31-01-2021.

As can be seen from above arrears to the amount of Rs 779.19 Cr are pending which is equivalent to 1808 MU of power to be procured by UPCL (assuming PP cost of INR 4.31/kwh proposed in ARR of FY 2020-21). These arrears have a huge impact on the paying capacity of UPCL and the severely impacts the cashflow position. The UERC's methodolgy to consider the normative trajectory for collection efficiency rather than actual is hurting the financial position of UPCL. Therefore, it is requested that while truing up, the Commission consider the

actual collection efficiency wl1ile determining the revenue from sale of power.

27

Overview of the Tariff Petition for FY 2020-21

1.30 The Hon'ble Commission vide its Order dated May 6, 2013 issued the Order on approval of Business Plan for UPCL for the first Control Period FY 2013-14 to FY 2015-16 and Tariff for FY 2013-14. Further, the Commission had issued the Tariff Orders for FY 2014-15 and FY 2015-16 vide its Orders dated April 10, 2014, April 11, 2015.

1.31 Subsequent to the con1pletion of the first Control Period, the Commission notified the Uttarakhand Electricity Regulatory Commission (Terms and Conditions for Determination of Multi Year Tariff) Regulations, 2015 (hereinafter referred to as "UERC Tariff Regulations, 2015") on September 10, 2015 for determination of tariff from FY 2016-17, i.e. April 1, 2016 onwards up to FY 2018-19, i.e. March 31, 2019 (2"' Control Period).In line with the Tariff Regulations, 2015 vide its Order dated April 5, 2016, the Commission issued the Order on approval of Business Plan for· UPCL for the Second Control Period from FY 2016-17 to FY 2018-19 and Tariff for FY 2016-17 (hereinafter referred to as MYT Or·der, 2016). On March 29, 2017 the Commission issued Tariff for FY 2017-18 along with true· up for FY 2015-16. Further, the Commission issued Tariff for FY 2018-19 along with true-up pf FY 2016-17 on March 21, 2018.

1.32 The Hon'ble Commission has notified the Uttarakhand Electricity Regulatory Commission (Terms and Conditions for Determination of Multi Year Tariff) Regulations, 2018, in short, "UERC Tariff Regulations, 2018" on September 14, 2018 which are applicable for determination of tariff from FY 2019-20 onwards and upto FY 2021-22, i.e. from April 1, 2019 to March 31, 2022 (herein referred to as the "3rd Control Period"). Subesequent to the notification of UERC Tariff Regualtions, 2018 the Commission issued the Order on approval of Business Plan for UPCL for the Third Control Period from FY 2019-20 to FY 2021-22 and Tariff for FY 2019-20 (hereinafter referred to as MYTOrder, 2019).

1.33 As per clause 16(2) of UERC Tariff Regulations, 2018 the Petitioner is required to make an application for determination of tariff for second year of the Control Period, i.e. FY 2020-21 in this case along with the Multi Year Tariff Petition for the 3'' Control Period under Regulation 10.

1.34 Therefore, the Petitioner respectfully submits this application for true-up of FY 2018-19 along with the APR of FY 2019-20, ARR for each year of the 3'' Control Per-iod and Tariff for FY 2020-21.

1.35 The present petition has been prepared in accordance with the fo\lovving acts, policies and regulations issued by the Hon'ble Commission:

a) Electricity Act 2003;

b) Provisions of National Electricity Policy

c) Provisions of National Tar·iff Policy

d) UERC (Terms and Conditions for Dete,·mination of Multi Year· Tariff)

Regulations, 2015

e) UERC (Terms and Conditions for Determination of Multi Year Tariff)

Regulations, 2018

1.36 The Petitioner prays that the Hon'ble Commission may:

------ ---------- -----------~-

1---------- ----- --a) admit the accompanying Tariff Petitlon;

b) approve true-up of expenses and revenue for FY 2018-19 based on the

audited accounts of the said year;

c) approve the Annual Revenue Requirement (ARR) for the FY 2020-21;

d) approve the revision in retail tariffs for FY 2020-21 as proposed;

e) approve the terms and conditions of tariffs and various matters as

proposed in the petition;

f) pass suitable orders for implementation of tl1e tariff proposals for FY 2020-

21 for making it applicable from April 1, 2020 onwards;

g) determine the ARR by taking into account the financial implications of the

various factors as described above

h) condone any inadvertent omissions/errors/shortcomings and permit

Petitioner to add/change/modify/alter this filing and make further

subn1issions as may be required at future date; and

i) pass orders, as the Hon'ble Commission may deem fit and proper keeping

in view the facts and circumstances of the case.

29

2. 1 Hon'ble Commission vide its Order dated March 21, 2018 determined the expenses and 1·evenues for FY 2018-19 based on the past actuals and historical trends in line with the provisions of the UERC Tariff Regulations, 2015.

FY 2018-19 is complete and the audited accounts for the financial year are

available. In this section, the Petitioner has therefore proposed truing-up for the various expenses and revenue based on the Audited Accounts for FY 2018-19 as part of this Petition in line with Regulation 12 (3) of UERC °Tariff Regulations 2015 which provides as under:

"(3) The scope of the Annual Performance Review shall be a comparison of the actual performance of the Applicant with the approved forecast of Aggregate Revenue Requirement and expected revenue from tariff and charges and shall comprise of following:

a) A comparison of the audited performance of the applicant for the previous financial year with the approved forecast for such previous financial year and truing up of expenses and revenue subject to prudence check including pass through of impact of uncontrollable factors;

b) Categorisation of variations in performance with reference to approved forecast into factors within the control of the applicant (controllable factors) and those caused by facl"ors beyond the control of the applicant (un-controllable factors).

c) Revision of estimates for the ensuing financial year1 if required, based on audited financial results for the previous financial vear;

d) Computation of the sharing of gains and losses on account of controllable factors for the previous year."

2.3 The computation of revenue and expenses for FY 2018-19 under various heads along wlth the relevant records and supporting documents wlth reasons and

justifications for such calculations under each head have been elaborated in this

Chapter. The head-wise details of costs with justification are enumerated below:

Energy Sales

2.4 The Petitioner has recorded actual sales of 11826.68 MUs in FY 2018-19 as against the approved sales of 11853.72 MUs by the Hon'ble Commission its Order dated March 21, 2018.

2.5 In pursuance to the directions laid by the Hon'ble Commission in the previous

Tariff 01~ders, the Petitioner has 111ade concerted efforts towards metering all existing unmetered consumers. The Petitioner has reduced the number of

unmetered consumers to nil and therefore, no sales is recorded in the billing

ledger against unmetered consumers for FY 2018-19. The actual energy sales of 11826.68 MUs across all consumer categories is against metered consumers

30

----------

and therefore recasting of sales for FY 2018-19 is not required as considered in

the past years for adjustment of sales on unmetered consumers.

2.6 The table below provides a comparison of the approved category-wise sales for FY 2018-19 with the category-wise actual sales in FY 2018-19:

Table 6: Actual Energy Sales in FY 2018~19 (MUs)

2 Non-domestic incl. Commercial RTS - 2 $ 1319. 74 1301. 34

52.63 49. 16

368.60 190. 13 (178.47) 3 Public Lam ,s (RTS - 3)

Private Tubewe!l/Pum Sets RTS - 4 * Government Irrigation S stern RTS - 5) 161.23 154.42 (6.81)

398.41 411.07 12.66

0.00 7

Public Water Wo r_ls,=s--'("R'-'T-"S'---__.,_6L) -----+----=c_c_=----+----'-''=-'-'-----+ Industrial Consumers RTS - 7

LT Industry 329.92 309.93 (19.99)

-+--'--'H~T~Industry --~--------- 6062.82 6355. 76 292. 94

8 Mixed Load (RTS - 8 186. 78 177.75 (9. 03)

23.45 27.91 4.46

11853.72 11826.68 (27.03) 9 _ Railway Traction (RTS - 9) --------+-

10 Total $ includes Extra State Supply '1'includes sales in RT5-4A category

Power purchase expenses

2.7 Power purchase expenses for FY 2018-19 have been claimed in line with the methodology adopted by the Hon'ble Commission. Detailed approach is

mentioned below:

a) Power purchase expenses are computed as per the actual bills received

from the generating companies as reflected in the audited annual

accounts. b) Energy purchased through UI Overdrawal during the yea,- is considered

towards state consumption.

c) Revenue received towards energy charges for UI underdrawal has been

reduced from the power purchase cost.

d) Rate of state royalty power has been considered as per actuals. The

Commission in its Tariff Order dated March 21, 2018 had observed that,

'The Commission is also of the view that while carrying out the truing up

for the ensuing years, cost of free power shal/be considered as that

provided in the audited accounts by the Petitioner subject- to the ceiling

limitof weighted average cost of power available to UPCL from the hydro

generating stations". Therefore, the Petitioner has considered the rate of free power for FY

2018-19 same as the rate booked in audited accounts for FY 2018-19.

e) Hon'ble Central Electricity Regulatory Commission has revised the Tariff of

various central generating stations vide tariff orders issued for the

respective plants. Accordingly, any arrear amount paid/ received during FY

2018-19 has also been considered for such stations.

31

I l_

f) Water Tax for FY 2018-19 is included i11 the cost of power from UJVNL

generating stations.

g) The Power Purchase cost also contains Rs 47.09 Cr as surplus approved

for UJVNL that was to be adjusted in FY 2018-19

h) Transmission charges payable to Power Grid Co1·poration of India Limited

(PGCIL) and Power Transmission Corporation of Uttarakhand Limited

(PTCUL) are taken on the basis of transmission charges paid to the

respective company for the year. The amount claimed against PTCUL

includes the SLDC Charges. The PTCUL amount also includes incentive and

adjustment bills paid during FY 2018-19. The arrear amount on account of

UJTP of approx .. Rs. 99 Cr has been considered under the head of PTCUL.

i) Rs 62.90 Cr approved by the Commission for FY 2018-19 against UITP in

the Tariff Order of FY 2019-20 has also been considered

j) Late Payment Surcharge of Rs. 2.54 Cr paid to generating companies has

been excluded from the total power purchase cost of FY 2018-19

k) The Petitioner has also adjusted the revenue frnm sale of surplus power

outside the State which has been reduced from the total power purchase

expenses.

2.8 The details of actual power purchase expenses are as follows:

Table 7: Actual Power Purchase Cost for FY 2018-:LD (Hs, Ci,)

PO\•ver Purchase. as per acco un:cts:.....c( iccn.::cl..::u.::dc.:.i n"g"-fc.r.::e::.ec:p..::o.cw..::ec.r,_) ______ .J-..._5..::3..::0..::3..::·c:.26

Late Payment Surcharge 2.54 c..... __ ...._ _____ .c..._ ________ ~, .. -----------+-----__j

Revenue frorn sale of power outside State 138.37 Gross Power Purchase Cost · ·-------------+--5-1_6_2_._3_5__,

--+------' Transmission and Other Cost

/;cld: PGCJL (inc. Open acce:.:s chai"(i<:'S) -~---------------4------,

Less: Cost i-c>tVii't"U\ unp appmvc'd in (Y 20./9-20

k ci: P!CU! . SLOC

L'T.:co:-t-ca._l ._P.co.-w'-'eC'.'rC."..P,,,uc.rc=.hc.a=.s=.e=-cC:-occscct _______________ ,...L_~-~.?-~-· 7_8_

2.9 The table below provides the variation in the power purchase expenses

approved by the Commission in the Tariff Order of FY 2018-19 against the expenses now claimed by the Petitioner as per the audited accounts of FY 2018-19 and various other norms specified by the Commission.

Tab!e 8: Vc:;dat[on it1 the Power purchase cost for FY 2018-· 19 (Rs. Ct·.)

Power purchase expenses including Transmission 5545.62* 5872.78* (327.16)

c.....C_h_a_r.cg_e_s _________ ~--------~---------··-- 1 __________ _

''Includes Rs 62.90 Cr for UITP approved in Tariff Order of FY 2019-20 for Pf 2018-19

- I

RPO Status and Compliance

2.10 As per UERC (Tariff and other Terms for· Supply of Electricity from Renewable Energy Sources and non-fossil fuel based Co-Generating Stations). Regulations, 2018 1 the Petitioner is required to purchase a minimum percentage of its total electricity requirement for own consumption excluding consumption met from hydro sources of power from renewable energy sources under renewable purchase obligation during each financial year.

2.11 For FY 2018-19, the Petitioner was required to meet a target 10.25% towards

non-solar RPO and 6.75% for solar RPO. The Petitioner in FY 2018-19 has been able to fulfill the past unmet RPO as well as RPO ta1·get for the year.

A

B

i.

ii.

C

D

E

1'abie 9: Renewable purchase obligation {RPO} Status for FY 2018-19

Total Power Purchase at State Periphery exdudin H dro MU

6488.55

RPO Target(%) 10. 25% 6. 75%

RPO Target of Current Year (MU) 665.08 437.98

Backlog of previous year (MU)

Total RPO Target (MU) 665.08 437.98

Total Power Purchase to rneet RPO Target MU) 853.67 388.38

Total Unmet Target_______ --t-__ (188.59) -t--- ·---.·

Adjsutrnent of Non-Solar against solar as per 49

_60

UERC RE Reg_t}lations _2018 ___ _ _______ ----+---------->

49.60

Total Unmet Target at the end of FY 2018-19

2.12 As per 2nd Prnvision of Regulation 9(1) of RE Regulation, 2018, 15% of target

of solar RPO of the year can be met out through non-solar power. As UPCL is having surplus non-solar power of 188.59 MU and deficit in solar of 49.60 MU.

Since 49.60 MU is less than 15% of the target i.e 65.70 MU (15% of 437.98 MU) therefore, the target of solar and non-solar RPO has been achieved by the

end of FY 2018-19.

Distribution Losses

2.13 For FY 2018-19, the Petitioner has achieved a distribution loss of 14.32% as

against the distribution loss target of 14.50% approved by the Commission for

FY 2018-19 in its Tariff Order of FY 2018-19 dated March 21, 2018. The calculation for distribution loss is shown in table below:

T2ble 10-: Actua! Distribution Loss for FY 2018-19 (in MUs)

Sales

Input energy at the Di scorn Periphery

Distribution Loss

Distribution Loss(%) ·---·---·--------------'----

11826.68

13803.71

1977.03

14.32%

l_

2.14 Therefore, in line with the Regulation 14(1) of UERC Tariff Regulation, 2015, the

Petitioner has computed the sharing of gain on account of over-achievement of

distribution loss trajectory laid down by the Cornrnission in relevant section.

2.15 The Petitioner humbly submits that it has been making significant efforts to reduce distribution losses and has shown substantial year-on-year improvement as highlighted in Chapter 1. The reduction in distribution loss during FY 2018-19 has been 0.85% over FY 2017-18 actual loss of 15.17% which has been difficult

considering high sales growth in LT consumers on account of rural

electrification.

2.16 In view of the significant reduction in distribution loss achieved for FY 2018-19, the Petitioner requests the Comrnission to consider actual losses achieved in FY 2018-19 for the purpose of truing-up.

Operation and Maintenance expenses

2.17 Operation and Maintenance (O&M) expenses includes Employee Cost, Administration and General Expenses and Repair and Maintenance expenses.

Employee expenses

2.18 As per audited accounts for FY 2018-19, actual gross and net employee expenses of Rs. 412.57 Cr. and Rs. 341.58 Cr. respectively are recorded. It is submitted that this amount is inclusive of actual payment of Rs. 29.19 Cr.

towards the arrears of Seventh Pay Commission revision and enhanced pension.

2.19 Based on the methodology adopted by the Commission in the previous Tariff

Orders and the UERC Tariff Regulations, 2015, the Petitioner has recomputed the normative gross employee expenses for FY 2018-19. The opening EMPn-1

has been considered as Rs. 351.76 Cr. (closing gross employee expense) as approved by the Commission during truing up of FY 2017-18. CPI inflation has

been considered as the average increase in the Consumer Price Index for the preceding three years. As the number of employees have reduced by the end of 31.03.2018 on account of retirements, the growth factor has been considered

as zero. Actual capitalization rate as per the audited accounts have been considered for arriving at the normative employee cost.

2.20 It is submitted that an additional amount on account of enhanced pension paid in FY 2018-19 is included in the audited accounts. This enhanced pension is on account of pay revision in third time sca!e for employees who retired in between 01.01.1996 and 20.07.2010. Since enhanced pension was not a part of the base employee expenses and is a statutory liability for the Petitioner 1 the same has been considered additionally in FY 2018-19. The Hon'ble Commission is requested to consider the same as provided in the table below:

Ta.b!c :U.: Normative Employee Expenses fov rY 2018-19 (Rs. Cr,)

I

r 1--3_·_ .. _-+-C-:c'--'PI=Inflation {3 years average) _____ _

Gross Employee Expenses 5.35% 4.28% ----

4. EMPn = {EMPn-1) x {l+Gn) x 371.79 366.82 1 +CPiinflation}

5. Capitalisation Rate 17.44°!\i 17.21% 6. Less: Erf!ployee Expenses Capitalised 64.78 63. 12

_7_. ____ Net Employee Expenses 306.62 303. 70 -45.19 29.19

351.80 332.89

U.:__. _ Enhanced impact of pay Revision L~ I Total E~ployee Expenses

-~ .. ---~~--~---------~---

2.21 As detailed in Table 12 below, UERC had approved Rs. 351.80 Cr. under Employee Expenses head (including the impact of Seventh Pay Commission). As against the same, the revised employee expenses have been computed as Rs. 332.89 Cr. by the Petitioner. The reduced claim for employee cost is mainly due to revision in the gross normative employee eXpenses used for computing the normative employee expenses in FY 2018-19, lower growth in CPI inflation and no increase in number of employees during FY 2018 .. 19.

Table 12: Emptoyee R:xpenses for FY 20:1.8-19 (Rs. Cr,)

"The Commission would carry out the truing up for FY 2018-19 based on the actual impact of VII Pay Commission including arrears and no sharing of gains and losses on this account would be allowed."

2.22 Therefore, the Petitioner has separately worked out the variation between normative and actual employee expenses after excluding the actual arrears paid on account of Seventh Pay Commission as per the provisions of "Sharing of Gains and Losses" prescribed in the UERC Tariff Regulations 2015 (further detailed in relevant paragraph).

A&G expenses

2.23 The actual gross and net A&G expenses incurred by the Petitioner for FY 2018-19 were Rs 62.68 Cr and Rs. 47.48 Cr respectively.

2.24 It is submitted that the consumer base of UPCL has been consistently rising and the utility has been making consistent efforts to improve the quality and reliability of power supply in the State. The Petitioner has been incurring expenditure to improve the overal! customer experience by moving towards a citizen-centric model. To implement these measures, the expenses incurred by Petitioner have been rising.

2.25 The actual A&G expense consists of cost of data centre and other expenses relating to R .. APDRP projects. These expenses are primarily towards annual

35

maintenance charges for the software and hardware installed under the various R-APDRP works, facility management system (FMS) etc.

2.26 Since the cost ,·elates to the R-APDRP works implemented by the Petitioner and

operational cost relating to these works were not included as pa,·t of the overall project cost, these expenses are being borne by the Petitioner over and above the normative A&G expense. Also 1 it is submitted that the above costs have been incurred recently post the commissioning of RAPDRP works and therefore

the same are not included as part of the base year A&G expense used for 2nr1

Control Period, FY16 to FY19.

2.27 Since there has been observed a significant increase in actual A&G expenses of FY 2018-19, the A&G expenses have been considered based on actuals of FY 2018-19 as per audited accounts rather than on normative basis. It is humbly submitted that the A&G expenses may be approved based on actuals on account of increase in costs based on factors detailed above.

Table 13: AlI1G Expense fot FY 2018-19 (Rs. Cr.)

1 Rent Rates & Taxes

2 Electricity and Water

3 Insurance

4 Communication

5 P1·inting and stationery

6 Travelling and Convey~nce ·

7 Legal & Professional -t-----------~·

8 Fees & Subscription

9

10

11

12

Statutory Auditors Remuneration- Audit fees

Departmental Training

Advertisement and Promotion

Miscellaneous Expenses f-------a-~-~-----~-----

Other debit to Revenue A/c, 13 Compensation expenses to

staff & outsiders, etc. Bandwidth, Software Licence

14 f-------a-R~~newal Charqes

15 U.E.R.C. Fees

16 AMC of Hardware 1-----J------------·<

Less: Expenses charged to Capital WlP _____ _

Total

R&M expenses

----~ 27.29

0.65 0.65

6.96 6.96

0.17 0.17

2.15 2.15 ---+--~--~--

1.86

7.04

9.45

0.10

0.06

0.14

4.93

6.43

4.66

11.25

3.30

3.54

(15.21)

1.86

7.04

9.45

0.10

0.06

0.14

4.93

6.43

4.66

11.25

3.30

3.54

(15.21) ~ --+---------1--------- ··-·--

47.48 ~-7.48_ -· 19.69__

2.28 The actual R&M expense of UPCL as per the audited accounts for FY 2018-19 is

Rs.137.66 Cr.

- ---- ------------ ------------------------------- -

2.29 The Commission had disallowed capitalisation worth INR 96 Cr in FY 2016·17 and Rs 391 C,· in FY 2017-18 on account of non-submission of clearance certificates by Electrical Inspector. The Petitioner shall submit the pending Electrical Inspector certificates against remaining HT works capitalized in FY 2016·17, FY 2017·18 and net addition in FY 2018-19 during the course of this tariff proceedings.

2.30 In absence of actual GFA on account of disallowance, the Petitioner has followed similar approach as followed while submitting A&G expenses i.e. based on actuals. It is humbly requested that actual R&M expenses based on audited annual accounts may be approved by the Commission in the True-up.

Table 14: R&M Expenses for FY 2018-19 (Rs. Cr.}

2.31 Table 15 below summarizes the O&M expenses approved by the Commission in the Tariff Order of FY 2018-19 against the O&M expenses now claimed by the Petitioner for FY 2018·19.

Table 15: Opc::raUon and Maintenance Expenses for FY 2017-1.8 (Rs. Cr.)

1. f\Jet Employee Expenses 351.80 341.58 332.89

2. Net Administrative and Genera!

27. 79 47.48 47.48 Expenses

3. Repair and Maintenance 125. 98 137.66 137.66

4. Total O&M Expenses 505.57 526.71 518.02 ---·---·-·-

Capital cost of Assets and Financing

2.32 For the purpose of computing the opening of Gross Fixed Assets (GFA) for FY 2018-19, the Petitioner has considered the closing GFA of Rs. 4616.42 Cr based on the actual capitalization in FY 2017-18 as per audited accounts.

2.33 Further, in FY 2018·19 the Petitioner has a net asset addition of Rs. 937.73 Cr.

As already mentioned in Para 2.29, UPCL shall provide the pending Electrical Inspector certificates of previous years and net addition in FY 2018-19 during

the course of tariff proceedings. The Petitioner thus, humbly requests the

Commission to reconsider the closing GFA of FY 2017-18 and approve net capitalization of Rs. 937.73 Cr for FY 2018-19.

2.34 The means of finance for the capitalization of net fixed assets during FY 2018· 19 is as provided in the table below:

Ta.bfe 16: Means of Finance for !\let Assets Capitalized during r-Y 2018-19 (Rs. Cr.)

37

Interest and Finance Charges

2.35 The interest expenses claimed for true-up of FY 2018-19 has been considered as per the audited accounts of FY 2018-19 after considering the following

adjustments:

a) Interest on REC (Old) loans has been taken in accordance with the re­

scheclulement package of REC (Old) loans determined by the Commission

in Tariff Order for FY 2009-10 dated 23•d October 2009 issued by UERC.

b) Government Guarantee fees is considered as per audited accounts.

c) Interest on consumer security deposit has been claimed as per the actual

interest paid.

d) The Petitioner has not considered interest on GPF as per audited accounts.

However, the Petitioner prays to the Hon'ble Commission to allow Rs.

35.08 Cr. interest on GPF as part of interest expense as this is the

statutory liability of the Petitioner. The Government of Uttarakhand (GOU)

in the past has refused to provide support to UPCL on account of interest

on GPF. It may be noted that GOU is already bearing the terminal liability

of the old employees unlike other states. In case the Hon'ble Commission

is of the opinion that interest on GPF has to be borne by the State

Governrnent 1 it may issue suitable advisory to the GOU in this regard.

e) Provision for interest on PFC loans towards R-APDRP Part A and Part B

have been excluded as these loans shall be converted to grants after

successful implementation of the works.

f) other financial and bank charges have been considered after reducing the

interest on overdraft/ short term loans.

g) Actual interest accrued during the year has been claimed which is net off

capitalisation as given in Table 17 following table.

Table 17: lnt21··est Expenses on Cnp·ital Loans for f::y './.Olfl-19 (Rs, Cr.}

Net Interest Expenses as per Accounts Les~s~: __

Interest on GPF f------ ---- ---·-----

Interest on Old REC Loans

Interest on Consumer Security Deposits

213.27

35.08

11.49

46.09

Guar ~n~_ee_F_ee__ ~-- _J_0_4 ___ . I11terest on Bank 5h01 t Term Loan/ Overdraft 41 02

Bank-Cha1ges & Other C~inm1ss1~11 - - 3_5_2 ___ 1 ~et Inter~st Expense Claimed towards Capitalized Assets , 73.04 -~

2.36 Therefore, tl1e total interest cost for FY 2018-19 claimed for the purpose of true-up is as provided in table below:

Table 18: Total Interest daimed for Truing-up of t;:;Y 2018-19 (Rs, Cr.}

Interest on Capital Loans

Interest on Old REC Loan 18.33

Guarantee Fee 3.04

Interest on Consumer Security Deposit (as per 46

.09 paid basis) _______________ -,------------------------1

3.52 . ··-----·-+-----------------

Interest and Finance Charges

Total Interest Claimed 144.02 ________ _J

2.37 The table below details the variation in the Interest expenses approved by the Commission in the Tariff Order for FY 2018-19 against the interest expenses

now claimed by the Petitioner.

Table t9: Variation in the Interest Expenses for FY 2018-19 (Rs. Cr.)

Depreciation

2.38 For the purpose of depreciation, the Petitioner has considered the closing GFA as per actual net capitalization in FY 2018-1_9. The rate of depreciation as per audited accounts has been applied on the average assets for FY 2018-19 after reducing the value of grants and consumer contribution/ deposit works.

2.39 The computation of depreciation for the purpose of true-up for FY 2018-19 is

detailed in table below:

Table 2.0: Proposed Depreciation for FY 201S-:l9 (Rs. Cr.)

Opening GFA

Less: Grants

Depreciable opening GFA

Net addition during the year

Closing GFA

-~eprecfation rate

Depreciation

4616.42

2447.01

2169.41

367.66 2537.07

5.21%

122.60

2.40 The table below details the variation in the depreciation approved by the Commission in the Tariff Order for FY 2018-19 against the depreciation now

claimed by the Petitioner.

Table 2:J.: \fadation in the Depreciation for r~v 2018-19 (Rs, Cr.)

39

-- ------------- -------------------·---- -------1

Interest on Working Capital

2.41 The interest on working capital has been calculated in line with the rnethodology

prescribed in the UERC Tariff Regulations, 2015. As per the UERC Tar·iff Regulations 2015, Working Capital for· a distribution licensee shall be cornputed as under:

"33. Interest on Worl<ing Capital Rate of interest on 1,vorking capital shall be on normative basis and shall be equal to the State Bank Advance Rate (SBAR) of State Bank of India as on the date on which the application for determination of tariff is made.

( 2) Distribution:

a) The Distribution Licensee shall be allowed interest on the estimated level of working capital for the financial year, computed as follows:

(I) Operation and maintenance expenses for one month;

(ii) Maintenance spares@ 15°/o of operation and mar"ntenance expenses; plus

(iii) Two months equivalent of the expecl'ed revenue from sale of electricitv at the prevailing tariffs;

(iv) Capital required to finance such shortfall in collection of current dues as mav be allowed by the Commission; rninus

(v) Amount held as security deposits under clause (a) and clause (b) of sub­section (1) of Section 47 of the Act (ram consumers and DistribuUon Svstem Users; minus

(vi) One month equivalent of cast of power purchased, based on the annual potNer procurement plan."

2.42 The detailed working for deten-nining the interest on working capital is provided in the table below:

1~abte 22.: Interest on V\f'odtin\J Caµ[ta[ for FY 7..0\8· "19 (R.s, Ct·,)

Maintenance@ 15% of O&fvl expenses 77.70

Receivables (2 months) 1056.22 I Capital required to finance such shortfall 111 collect1on of cu1 rent dues 63 37 -J Less. Amount held as secu11ty deposits i_ 801 25 -

_!_ mon.!!2....9~~va\en.!._9~ _f9_st _ _.]

1

__ 500 ~-- __ [

Working Capital Requirement . ··---·-------------··(61.~-----~

l Rate of inter~st@ SBAR . .. _ ______ . 13 .. 70% ___ ,

_!_nter_est on W()rki~-~apital ____________________ __J__ _______ _:-______ ]

2.43 As per the nonnative working capital norm, the working capital requirement was negative. Therefore, the Petitioner has not claimed any amount under Interest on Working Capital. Further, it is submitted that the actual interest on working capital incurred is Rs. 41.02 Cr. as the amount towards overdraft facility is primarily utilized for the purpose of availing the maximum rebate from

the generators.

2.44 Since the actual interest on working capital is higher than the normative as also shown in the table below, the Petitioner has proposed the sharing mechanism as per the provisions of "Sharing of Gains and Losses" in UERC Tariff Regulations in the relevant section.

Table 23: Variation in the Interest on Working Capital fo, FY 2018-l9 (Rs. Cr.)

Return on Equity

2.45 The Petitioner has computed the Return on Equity (RoE) in accordance with the Regulation 26 of the UERC Tariff Regulations, 2015.

2.46 For FY 2018-19, return on equity has been calculated based on actual equity

invested in the business. Return on Equity has been calculated based on the closing equity apprnved in true-up of FY 2017-18 including the net capitalisation disapprnved on account of Electricial Inspector Certificate

2.47 Return on equity has been calculated on average equity during the FY 2018-19

as per the rate of return specified in the Regulations i.e. 16.50%.

Tabfe 24: Computation of Return on Equity fo1- i~v 20:l8-:t9 (Rs. Cr.)

1 Opening equity 474. 19 591. 51 Additions during

41.81 110.30 2 the iear

3 Deletion 0.00 0.00

4 Closing Equity 516.00 701.81 ·~~··~·

5 .. Average 495. 10 646.66

6 RoE (%) 16.50% 16.50% 7 ~~(in Rs Cr.)

,---,---

78.24 106.70 28.46

Bad and doubtful debts written off

2.48 Annual provisioning towards bad & doubtful debts is an accepted method of accounting and considering the peculiarity of retail supply of electr·icity

business, the same has also been recognized by the State Regulatory

Comrnissions. The amount, if any, written off towards bad debts is only

41

----------·---,--, -----~----

- ------------- ------------- ----------

adjusted against the accumulated provisions in the books, irrespective of the actual amount of bad debts during any particular financial year.

2.49 Considering the geographical spread of the large consumer base across the State including a large part of the same prevailing in the difficult terrain and hilly region and the problem of ,-ealizing energy dues from retail consumers, the Petitioner requests the Commission to allow provision for bad and doubtful debts on actual basis.

2.50 The Commission in the MYT Order, 2016 did not allow for any provisioning of bad debts for earlier years. In line with the approach followed by Commission in the previous Tariff Order, the Petitioner has not included any amount on account of provisioning of bad debts in the ARR but 1·equest the Commission to approve the actual amount written off during FY 2018-19.

Non-Tariff Income (NTI)

2.51 Non-Tariff Income includes incomes from non-tariff sources such as Income from investments, delayed payment surcharge, etc. As per the UERC Tariff Regulations 2015, non-tariff income is required to be adjusted for determination of the ARR.

2.52 The Petitioner has adjusted the non-tariff income recorded in accounts to additionally account for delayed payment surcharge, which form a part of the revenue from sale of power to consumers in the audited accounts. The wheeling charges and cross subsidy surcharge have been considered as part of revenue from sale of power.

2.53 NT! as proposed by the Petitioner have been reconciled with the actual NT! as per the audited accounts of FY 2018-19 in Table 25 along with the rationale for the adjustments.

Table 2S: Reconciliation of Non -Tariff Income with audited accounts (Rs, Cr.)

osits Income from staff welfare a.~ct~·iv_i~ti_e_s _____ +-____ 0_._1_7 __ Rebate/Incentive 6.00 6.00

Miscellaneous recei ts -------+----~7~·~37~-·-·- I._~-~-- 7.37 Material Cost Variance 21.57 8.46 Sub-Total 92.52 79.41 Add: (Other Adiustments) Dela ed Pa ment Surcharge

------,----1-G_s_._o_o _______ ··-·--·· ·-1-6-s-. oo Total 257 .52 ___ ~--~2~4~4_,~4~1~--~

2.54 For material cost variance, out of the total Rs. 21.57 Cr., contribution from grants (Rs. 13.11 Cr.) has been deducted from the overall claim in line with the methodology adopted by the Corn mission in its previous Tariff Orde1·s.

2.55 As per the audited annual accounts, the total non-tariff income for FY 2018-19 works out to be Rs. 257.52 Cr. as against Rs. 244.41 Cr. approved by the Commission.

Table 26: Non-T,uiff Income for FY 2.018-19

Revenue from Tariff

2.56 An amount of Rs. 6218.61 c,·. against revenue from sale of power is recorded in the audited accounts for FY 2018-19. As also detailed in the section for non­tariff income delayed payment surcharge has been included as part of non-tariff income. Further, as also detailed in Para 2. 7k) the Petitioner has reduced the overall power purchase cost with the revenue recovered from sale of surplus power of Rs. 138.37 Cr. while claiming overall power purchase cost. Therefore, the revenue from sale of power within the State has been adjusted for Rs. 138.37 Cr.

2.57 Further, revenue of ~ Rs 295.95 Cr in form of Additional Energy Charge approved in the Order dated October 25, 2019 against increase in Power Purchase Cost for FY 2018-19 has been considered as part of the revenue for FY 2018-19.

2.58 Accordingly, the revenue as per the audited accounts has been adjusted for such other income elements which have been consider·ed under other ARR heads Le. non-tariff income, power p.urchase cost, etc. as given below:

Table 2.7: R.evenue from Sale. of Povver in FY 2017-18 (Rs. Cr.)

1 Revenue as per accounts 6218.61

2 Add: Revenue frorn Additional Energy Charge 295.95

Less:

2 Delayed Payment Surcharge 165.00

3 Revenue from Extra-State Supply 138.37

4 Revenue from sale of power 6211.19

Sharing of Gains and Losses on account of Controllable factors

2.59 As per the UERC Tariff Regulation, 2015,

"14 (1)Tlie approved aggregate gain and loss to the Applicant on account of controllable factorssha/1 be dealt with in the following manner:

a) 1/3rd of such gain or loss shall be passed on os a rebate or allowed to be recovered in tariffs over such period as may be specified in the Order of the Commission;

b} The balance arnount of such gain or loss may be utilized or absorbed by the Applicant."

2.60 Hence, in accordance with UERC Tariff Regulations, 2015, the O&M expenses, IoWC and Distribution Losses are controllable factors and any gain/loss on

43

-- --·-------·----

account of controllable factors is to be dealt in accordance with the provisions of Regulations 14 of the above mentioned regulation.

2.61 As discussed in the O&M section, the normative employee expenses have been considered and actual A&G and R&M expenses have been considered. Therefore, sharing mechanism has been done only with respect to employee

expenses.

2.62 In case of interest on working capital, the Petitioner has incurred on actual expense of Rs. 41.02 Cr. against normative interest which is nil.

2.63 The Petitioner in FY 2018·19 has over·acheived the distribution trajectory laid

down by the Commission. As a result, the Petitioner has calculated the gain to be borne by the Petitioner as shown below:

Tab!e 28: Additional Revenue- from Sale for FY 201B -19 (Rs, Cr.)

1 Actual Sales (MU) 11826.68

2 Approved Distribution Loss Level (%) 14.50%

3 Actual Energy Input at T·D Interface (MU) 13803. 71

4 Sales at Actual Energy Input with 14.50% Loss (MU) 11802. 18

5 Loss of Sales (MU) 24.51

6 Revenue at Existing Tariff (Rs. Cr.) 6211.19

7 ABR (Rs./kWh) 5.25

8 Additional Revenue due to higher distribution losses (Rs. Cr.) 12.87 9 Losses to be borne by the Petitioner {2/3 of {8) (Rs. Cr.) 8.58 ----~--------~

2.64 In accordance with the UERC Regulations, 2015 the gain and loss sharing statement with respect to performance parameters is shown below:

Employee expenses

loWC

Total

Distribution Loss

Table 29: S11c1rirt9 of Gains and Losses (Rs. Cr.)

341.58 332.89 (8. 69) (2. 90)

41.02 0.00 (41.02) (13.67)

(49.70) (16.57)

14.32% 14.40% 12.87 4.29

(5.79)

(27.35)

(33.14)

8.58

2.65 Accordingly, the net impact of the gain/ loss required to be considered as part of the ARR is as below:

Table 30: Ga!n/ Loss claimed as part of ·rruing-up for ~::y 2:018-:\.0 Uts. Cr.)

----«----------·-·- ---

,,i 44 .

------------··---·- --------------~~-- -"--------J

---·--·· --- ·---------- --- ----·----·

in ARR) -------------------·--------+-----~-----;

4.29 Revenue on overachievernent of loss (after sharing)

Total share to be recovered in ARR (12.28)

ARR and Revenue Gap for FY 2018-19

2.66 Based on the above submission, the summary of expenses and revenue for true-up for FY 2018-19 is presented below:

Table 31: Aggregate Revenue Requirement for True-up of FY 2018-19 (Rs. Cr.)

Power Purchase Cost 4932.43 5123.81

Adjustment of Free Power (Excess Allowed) (100.74) (100.74)

Truing up of UJVl1 Ltd. (47.09) 0.00

TransmissiOn Charges

PGCIL Transmission Charges 388.08 437.10

PTCUL Transmission Charges 192.46 311.88

SLDC Charges 16.84

Interest on Loan 138.47 144.02 --------------+--------

Depreciation 142.42 122.60

O&M expenses 505.57 518.02

Interest on Working Capital 0.00 0.00

Return on Equity ____________ f-___ 78~-~2~4----+--1~0~6~-~7~0---I Sharing of Gains and !:_o_s_s_e_s _________

1 ____ 0_.o_o ___ -.; ____ 1_2._2_s __ -1

Aggregate Revenue Requirement 6246.68 6675.66

Less: [\Jon-Tariff Income 155.26 244.41 ----------~ ---·---------+-------

Add: True up impact Gap/(surplus) 64.78 64.78

Previous year adjustment (158. 71) (158. 71)

Net Revenue Requirement 5997.50 6337.32

Tab!e 32: Revenue Gap for FV 201.S-19 {Rs. C1-.)

1. Net Revenue Requirement 5997.50 6337.32 ----

2. Revenue from sale of power 6013.19 5915.24

Revenue on account of Additional Energy 295.95 3. Charge imposed by Comrnission in Order

dated October 21, 2019 ----

4. Revenue Gap/(Surplus) (15.69) 126.14

2.67 The Petitioner requests tile Commission to approve the revenue gap of Rs. 126.14 Cr. for FY 2018-19 along with carrying cost.

Revenue Gap with Carrying Cost

2.68 The Petitioner has computed the revenue surplus for FY 2018-19 along with

carrying cost as given in the table IJelow:

45

Table 33: Revenue (Gap}/Surplus for rv 2018-19 along with carrying cost (Rs. Cr.)

Opening Gap/(Surplus) 134.78 f--------------~----+--------+---------1-·----

Addition during tile year [Gap/(Surplus)] 126.14 ----------+-------+-------+-----

Closing gap 126.14 134. 78 -------------+--- --r------;--------

Average gap 63.07 134.78

Interest rate (Rate@IoWC) 13.70% 13.70% Cai--ry-in_g __ -co_s_t -·--·-----·----,---~ --+--18A6-

f---C-lo_s_i n_g_g_a_p_i_n~cl-u~d ,.-n_g_c_a-rr-y~i n_g_c_o_s_t ----+/--134.78 153. 2 4 --~-

2.69 The proposed revenue gap on account of truing-up for FY 2018-19 along with carrying cost as detailed above is Rs. 153.24 at the beginning of FY 2020-21 and has been dealt with while determining the overall revenue gap for FY 2020-21 in the Chapter 3. Accordingly, the Petitioner requests the Hon'ble Commission to consider this revenue gap of Rs. 153.24 at opening of FY 2020-21 while determining the ARR for FY 2020-21.

(J t:1;>'46

[ __ -----~··-·--- -~ -,------------··- ---,-/--~!

( I Revenue Requirernent

) and determination of tariff 02

3.1 The Hon'ble Commission has notified tl1e Uttarakhand Electricity Regulatory Commission (Terms and Conditions for Determination of Multi Year Tariff) Regulations, 2018, in short, "UERC Tariff Regulations, 2018" which are to be applicable for determination of tariff from FY 2019·20 onwards and upto FY 2021· 22, i.e. from April 1, 2019 to March 31, 2022 (herein referred to as the "3'" Control Period").

3.2 Subesequent to the notification of UERC Tariff Regualtions, 2018 the Commission issued the Order on approval of Business Plan and Annual Revenue Requirement for UPCL for the Third Control Period from FY 2019·20 to FY 2021·22 and Tariff for FY 2019-20 (hereinafter referred to as MYT Order, 2019).

3.3 As per clause 16(2) of UERC Tariff Regulations, 2018 the Petitioner is required to make an application for determination of tariff for second year of the Control Period, i.e. FY 2020·21 in this case along with the Multi Year Tariff Petition for the 3rd Control Period under Regulation 10.

3.4 As a result, in this section the Petitioner has summarized the ARR for the Fy 2020-21, second year of the Control Period based on the various financial parameters listed out in clause 69(2) of the UERC Tariff Regulations, 2018 and shall comprise of the following:

a) Cost of power purchase

b) Transmission charges;

c) System Operation Charges i.e. Fee and Charges paid to NLDC/RLDC/SLDC

d) Interest and Finance charges on loan capital and on consumer security

deposit;

e) Depreciation, including and amortisation of intangible assets;

f) Lease Charges

g) Operation and Maintenance expenses;

h) Interest on working capital; and

i) Return on equity capital;

j) Income-tax; k) Provision for bad and doubtful debts

3.5 Net Revenue Requirement from sale of electricity for a distribution licensee is Aggregate Revenue Requirement, as above, minus;

a) Non-tar·iff income;

b) Income from wheeling charges recovered from open access customers~

c) Income from Other Business, to the extent specified in these Regulations;

d) Receipts on account of cross-subsidy surcharge from open access

consumers; and

47

e) Receipts from additional surcharge on charges of wheeling from open

access consumers.

f) Any revenue subsidy or grant received from the State Government other

than the subsidy under Section 65 of the Electricity Act, 2003.

3.6 Accordingly, the subsequent section deals with projection of all the aforementioned components.

Energy Sales, Connected Load and Number of Consumers

3. 7 Based on the actual energy sales data for past years, Uttarakhand has had five year CAGR (Compounded Annual Growth Rate) of 5.46% in terms of consolidated energy consumptionduring FY 2013-14 to FY 2018-19, as shown in the following table:

Table 34: Energy sates fo,· consumer categories during PY 2013-14 to FV :2018-.19 (MU)

::.•. ' 1 . .'·,...,,.'.

1 RTS-1: Domestic 2106.20 2274.01 2391.15 2486.15 2741.53 2849.20 2 RTS-2: Non-Domestic 995. 76 1069.93 1121.03 1178.02 1235.23 1301.34

RTS -3: Govt. Public 471.12 533.45 551.52 590.25 614.66 Utilities (RTS-3: 441.66 3

Publi_c_Lamps)_._ RTS-4: Private Tube-

239.75 298.45 331. 98 350.49 271.37 190.13

wells/Pumping sets 4

RTS-5: LT &HT Industry 7

LT Industr --- ______113!. 6 6 304. 79 282.32 300.13 302.21 309.93 ---HT Industr 4804. 91 5066.49 5437.27 5508.03 5858.07 6355.76

8 RTS-6: Mixed Load 177.60 185.68 186.78 178.11 182.43 177. 75 -··-- --- -~-RTS-7: Railway 11.49 14.70 14.16 19.23 27. 73 27. 91 Traction

9

10 Total 9065.02 9685.16 10298.14 10571.69 11208.82 11826.68

3.8 It has been observed that the year-on-year growth in sales have remained ~5.50% each year except FY 2016-17 where the growth has been 2.7%. The lower growth in sales during FY 2016-17 was largely due to external reasons i.e. Central Government policies and decisions. However, during FY 2018-19 the state witnessed revived growth of an average 5.51%. Therefore, for the purpose of projecting the sales for FY 2019-20 and FY 2020-21, the Petitioner has also considered a mix of long to medium term trend in energy consumption along with adjustments on account of past abnormalities and impact of recent developments and economic conditions that would have a bearing on the future consumption in select consumer categories.

Projection of Energy Sales - Adjusted Trend Analysis (CAGR) Method

3.9 For projecting the category-wise energy sales of FY 2019-20 and FY 2020-21, the Petitioner has considered the t1·end of actual sales in the past six years (FY 2013-14 to FY 2018-19).

3.10 Additionally, the number of unmetered consumers have reduced to nil and therefore, the Petitioner has done away with re-casting sales fo1· FY 2018-19 in line with the approach followedlast year for the purpose of projections.

OAS I r--/

L _____ ---------------------·--·---·~----------------- ·---------------·-"

3.11 In line with the methodology adopted by the Commission in the past, the Petitioner has adopted the CAGR approach to project the sales in each consumer category while excluding any outliers (relative to the trend) observed in the growth rates over the period of 5 years.According to this method, Compound Annual Growth Rates (CAGRs) were calculated from the past figures for each category, corresponding to different lengths of time in the past five years, along with the year-on-year growth rates from FY 2013-14 to FY 2018-19. The Petitioner has also considered the seasonality effect on consumption, current economic conditions and enhancement of connected load while selecting the growth rate.

3.12 Detailed past growth trends in each consumer category is considered as explained below:

Tabie 35: CAGR for Energy Sales to Consumer Categories

~w, (•l:- . ' ' - . - . 1 RTS-1: Domestic 6.23% 5.80% 6.02% 7.05% 3.93%

2 RTS-2: Non-Domestic 5.50% 5.02% 5.10% 5.10% 5.35%

3 RTS -3: Govt. Public Utilities (RTS- 2.22% 1.22% 2.71% 0.78% -14.22% 3: Public Lamps) - -· -

4 RTS-4: Private Tube-wells/Pumping sets

-5.59% -11.90% -18.43% -28.28% -32.24%

4A RTS-4A: Agriculture Allied Services 0.00% 0.00% 141.34% 233.35% 71.34_°!£_

5 RTS -3: Govt. Public Utilities (RTS- 8.18% 9.44% 3.07% 3.17% -6.81 %

.. 5: Governm5~nt Irrigation System) -

6 RTS -3: Govt. Public Utilities (RTS- 6.98% 6: Public Water Works)

6.74% 5.81% 7.15% 11.94%

7 RTS-5: LT &HT Industrv !------------"-

LT Industry --.... ~- 1.50% 0.42% 3.16% 1.62% 2.55% -/-IT Industrv 5.75% 5.83% 5.34% 7.42% 8.50%

L____..§__ RTS-6: Mixed Load 0.02% -1.09% -1.64% -0.10% -2.57%

9 RTS-7: Railvvav Traction 19.43% 17.39% 25.37% 20.48% 0.66%

10 Total 5.46°/o 5.12°/o 4. 72°/o 5. 77010 5.51°/o

3.13 The approach followed for estimating the sales of respective consumer categories for FY 2018-19 and subsequent years of the 3rd Control Period has been described below:

RTS-1: Domestic Category

3.14 The sales growth during FY 2018-19 in domestic category is observed to be 3.93°/o. Owing to the economic slowdon, reduction in consumption etc. the Petitioner has opted for a conservative growth rate and has considered the growth rate same as that of latest year for projection of sales under domestic category for FY 2019-20 and FY 2020-21

RTS-2: Non-Domestic

3.15 In this category, the sales growth has been range bound (5-6%) as per the CAGR computed for various time intervals. Therefore, the sales for RTS-2 Non-Domestic category has been projected based on 4 year CAGR of 5.02% for FY 2019-20 and FY 2020-21.

49

-----------------------

-------------

RTS-3: Govt. Public Utilities

3.16 In Tariff Order dated March 21, 2018, the Hon'ble Commission had merged three categories of public lamps, govt. irrigation system and public water works to create a single new category of Govt. Public Utilities. The Petitioner has therefore, independently analyzed the growth rates for each of these categories in the past years. The Petitioner has considered 5 year CAGR rate for Govt Puublic Utilities and 3 year CAGR for GIS and PWCC category. The rates considered have been mentioned in the table below

RTS-4: Private Tubewells / Pumpsets (including RTS-4A)

3.17 On an overall basis (RTS 4 and RTS 4A), there has been a decline in the consumption in this category in the last 3 years. Also, the actual consumption has remained range bound in this category. Therefore, the Petitioner has considered a nominal increase of 2.00% for FY 2019-20 and FY 2020-21 for RTS-4 category.

RTS-5: LT & HT Industry

3.18 For RTS·S Industrial category · LT industry, it is observed that the 3 / 5 year growth in sales is minimal. Further in the q·o·q growth has been observed at 11.60%

3.19 For HT industries, it is observed that the growth in sales during FY 2018-19 was 8.50%. However, the growth observed in the 1st quarter of FY 2019-20 has been subdued at 2. 16°/o. The Petitioner has considered a concervative grm,vth rate of 2.16%, latest observed in the recent quarter, for both LT & HT category owing to factors such as economic slowdown, open access etc.

RTS-6: Mixed Load

3.20 Sales for RTS·S Mixed Load category has been projected to grow at nominal level of 2.00% for FY FY 2019-20 and FY 2020-21 on account of negative growth rate observed in FY 2018-19.

RTS-7: Railway Traction

3.21 Sales for RTS-9 Railway Traction has been considered at a conse1·vative level of 2.00°/o due to anomlalies observed in the growth rate observed in previous years

3.22 Based on the growth rates considered across various categories as discussed above, the projected energy sales for FY 2019-20 and FY 2020·21 for each consumer category is as below:

Tab!e 36: Projected Energy Sales (MU) for FY 2019-20 and FY 2020··2.1 and grnwth rate considered

1 RTS-1: Dornestic 2849.20 3.93% 2961.10 307l.39

2 RTS-2: f\Jon-Domestlc 1301.34 5.02% 1366.63 1435.19

3 RTS -3: Govt. Public Utilities 49.16 2.22% 50.25 51.37 (RTS-3: Public Lam s

·---·

4 RTS-4: Private Tube- 179. 79 2.00%) 183.38 187.05

~ells/P.~_m1pinq sets ___ 4A RTS-4A: Agricul.~ure All~- 10.35 2.00% 10.55 I 10 7§]

(

',)" 50 j;-.. ,

--· --··-~-· ---

Services RTS -3: Govt. Public Utilities

5 (RTS-5: Government 154.42 3.07% 159.17 164.05 Irr~qation S stem

6 RTS -3: Govt. Public Utilities 411.07 RTS-6: Public Water Works 5.81 °/o 434.94 460.20

7 RTS-5: LT &HT Industry -LT Industr 309.93 2.16% 316.62 323.46 HT Industr 6355.76 2.16% 6493.03 6633. 26

8 RTS·6: Mixed Load 177. 75 2.00% 181.30 184.93 9 RTS-7: Rai!wa Traction 27.91 2.00% 28.47 29.04

10 Total 11826.68 12185.44 12556.69

Projection of Contracted Load and No. of Consumer

3.23 Similar to the energy sales projection method, past growth trends in connected load/number of consumers have been analysed category-wise for forecasting. Adjusted Trend Analysis Method (which has been explained in energy sales CAGR method projections) has been used to forecast.

3.24 For making projections of connected load and number of consumers, the actual connected load/number of consumers for FY 2018·19 for each consumer category is taken as the base, i.e. the chosen growth rate is applied over the actual connected load/number of consumers for FY 2018·19 to make projections for each category for FY 2019·20 and FY 2020·21

3.25 The projected contracted load for FY 2019·20 and FY 2020·21 for each consumer category is detailed below:

Table 37: Projected Contracted Load (l<V\/) for FY 2019-20 and FY 2020-21 along with the growth rate considered

2 1058631 4.00% 1100976 1145015

3 RTS -3: Govt. Publlc Utilities

17380 4.00% 18075 18798 RTS-3: Public La11112s}

4 RTS-4: Private Tube-183939 \•vells/Pum lng sets 5.36% 193792 204173

4A RTS-4A: Agriculture Allied 4188 Services 4.00% 4356 4530

RTS -3: Govt. Publlc Utilities 5 (RTS-5: Government Irrigation 65867 5.09% 69218 72739

s stem

6 RTS -3: Govt. Public Utilities 100994 2.00% 103014 105074 (RTS·6: Public Water Works

7 RTS·5: LT &HT Industry LT Industrv 221216 4.59% 231372 241995 HT Industry 1678375 4.06% 1746526 1817444

8 RTS·6: Mixed Load 54612 2.00% 55704 56818 9 RTS-7: Railway Traction 15000 2.00% 15300 15606

11 Total 6532993 6796436 7070620

3.26 The projected number of consumers for FY 2019·20 and FY 2020·21 for each consumer category is detailed below:

51

/'-~

~-----·-------.-·----·------·--··-·---·-·---·-··-··

Table 38: Projected number of consumers for FY 2019-20 and FY 2020-21. along with the growth rate considered

4

4A

249865 RTS -3: Govt. Public Utilities

1876 RTS-3: Public Lamps) ----,-------1

RTS-4: Private Tube­wells/Pum inq sets

34630

103

6.59%

4.00% 1951 2029 ----4------+------

5.33% 36477 38422

4.00% 107 111 RT5-4A: Agriculture Allied Services +----+.c===---------+---------+------+------1----

5

6

7

8 9 10 11

RTS -3: Govt. Public Utilities (RTS-5: Government Irrigation S stem

1841 4.85% 1930 2024

RTS -3: Govt. Public Utll\ties ~---·1_7_8_2..,f -··· _9._ 23% 1946 2125 (RTS-6: Public Water Works) • _ _ --···-

RTS-5: LT &HT Industry ____ +-------+-·-----+------+-------!

~~ J?n~'::st~y -·--·------ -~1~~~~0~5~~+----~··-~2_7:-::1 -;-~~~~~_,_ ____ ! ;~1c!-~--1 RTS-6: Mixed Load 75 1.10% 76 77 ------RTS-7: Railwa Traction 2 0.00% 2 2

RTS-8: Tern orary Supp.!Y_____-+------+-----0_.~0_0_%-+- ----~0+ _______ 0_1 Total 2427249 2581381 2745323

Distribution Loss trajectory

3.27 As discussed previously in Chapter 2, the distribution loss level achieved by the Petitioner in FY 2018-19 was 14.32%, a reduction of 0.85% over the past year actual distribution loss. Even after such significant reduction in distribution losses over the years, the Petitioner is being penalized for non-achievement of distribution loss at the time of truing-up for the past years on account of loss trajectory set by the Commission

3.28 In its previous Petitions, the Petitioner has been submitting that the distribution loss targets approved by the Commission for the period from 2003-04 to 2017-18 are very high and unrealistic as the same have not been set based on the past year actual losses.

3.29 As per Regulation 9 of the UERC MYT Regulations 2018 the tr·ajectory fo1· distr·ibution loss is to be considered on past performance of distribution licensee and in respect of the base year. The regulations specify the following:

"Specific Trajectory for Certain Variables

(1) The Commission shall stipulate a trajectory for certain variables having regard to the past performance as a/so the performance of similarly situated licensees/generating companies: Provided that the variables for which a trajectory shall be stipulated, shall include but shall not be limited to,.

!-~---------_£),

./··J/52 J '

·-·~·-·-··---·-·------·~---··-·-· --

3.30 For the 3rd Control Period, the Commission has finalised the loss trajectory for each year. UPCL requests the Commission to take into account the fact that loss reduction below 15% is very difficult to achieve going forward. However, UPCL would continue to undertake measures and prudent capital expenditure which would help in reducing the distribution loss further. For the purpose of FY 2019· 20 and FY 2020-21, the Petitioner has considered the same loss targets as approved by the Commission in MYT Order 2019 since the Petitioner has over­acheoved the target in FY 2018-19. The Oistribution loss trajectory has been proposed as provided in the following table:

Table 39: Proposed Loss Trajectory

3.31 In view of the fact that UPCL has already achieved sub 15% loss levels, further reduction of distribution loss would be difficult and slow down considerably during the subsequent years. Also, the electrification of large number· of rural consumers under the Saubhagya scheme shall further restrict the reduction in distribution loss levels. However, efforts are being made continuously by the Petitioner to reduce distribution loss to the desired permissible level. Few of these initiatives have also been taken during the past Control Period and shall continue in the Third Control Period as well. Some of these initiatives include:

a) Installation of Capacitor· Bank at 33/11 KV substations

b) Replacement of Mechanical Meters with Electronic Meters

c) Replacement of Oefective Meters to reduce the percentage of defective meters

d) 100% metering of consumers has been completed. Increase in meter reading.

e) Implementation of AMR & Laying of LT ABC

f) LT Ariel Bunch Cable is being laid in theft prone areas.

g) Prepared metering has been made mandatory for new temporary LT connections, for advertisements / hoardings and for Government connections upto 25 l<w.

h) Monitoring of high loss feeders by officers

i) Checking of consumer billing by Internal Audit Wing to detect errors / omissions/ malafides.

j) Implementation of R·APDRP Part A & Part B scheme

k) Installation of Double metering in selected 11 KV & 33 l<V consumers

I) Underground cabling of HT & LT electrical network in Haridwar Kumbh Area and proposal for arterial roads of Dehradun.

m) Procurement of High value consumer management system (HVCMS)

3.32 The Petitioner in the current petition has projected the energy requirement for FY 2020-21 based on the loss trajectory proposed above.

53

Collection efficiency

3.33 It is submitted that UPCL has achieved collection efficiency of 97.44% during FY 2018-19 as against the approved target of 99.00% for FY 2018-19 by the Commission. With the continuation of its efforts, the Petitioner proposes the collection efficiency as shown in the following table in libe with that approved by the Commission in MYT Order 2019.

Table 40: Proposed Collection Efficiency

Reliability Indices

1.1 The Petitioner has also proposed the revised target level of reliability indices for FY 2020-21 as required under the provisions of Regulations 73(2)(d) of the UERC Tariff Regulations, 2018 as follows:

Tab!e 41.; Targets for PY 2020-21 for Urban Feeder of the Petitim1e1'

2. SAIDI (Min,/day)

Table 42: Targets for FY 2020-21 for Rural Feeder of the Petitioner

1.2 The Commission is requested to approve the above reliability indices for the 3'' Control Period. Details of reliability indices during previous year are also enclosed in Format 17.1 to 17.3 of the annexures.

Power Procurement plan

3.34 The Petitioner procures power from various sources to meet its energy requirement for sale to various categories of consumers. This quantum of power purchase requirement is decided based on the expected sale of energy by the Licensee and the targeted loss levels.

3.35 The energy sale for each year is grossed up by the distribution loss level for the year, to arrive at the required quantum of power purchase foi- that year at the Discorn periphery in the following 111anner:

,.,.I

3.36 Based on the sales and distribution loss projected for the FY 2020-21 and also detailed above in this Chapter, the projected energy requirement at the State periphery for each year of the FY 2020-21 is as below:

----- -- ------ ----

Table 43: Energy Requirernent for FY 202.0-21. (Rs. Cr.)

Proposed Sales

Proposed Distribution Loss

Energy Requirement at Discorn periphery

14.00%

14600.80

3.37 Against the above ascertained requirement, the availability of power from the various sources based on long-term PPAs during FY 2020-21 is detailed hereunder,

Procurement of Power and Uttarakhand's Allocated Share

3.38 UPCL procures power from central generating stations and other external sources apart from the power made available from the state generating stations operated by UJVNL and some other IPP's. A fixed share of power is allocated from the central sector generating station to meet its energy requirements. Moreover, Uttarakhand also receives a quantum of electricity from the unallocated share of the central generating station at diffe,-ent intervals during a year. Being hydro dependent, the surplus power during summer months is banked with other states to meet the deficit during winter months. Any demand-supply during the year gap is met through various short-term sources and other trading sources.

3.39 The major external and internal sources from which power is procured by the UPCL are:

a) NTPC

b) NHPC

c) NPCIL

d) SJVNL

e) THDC

f) UJVNL

g) UREDA

h) State gas generating stations

i) Co-generation stations

j) Independent Power Producers (IPPs)

k) other Renewable Sources

I) Short-term power arrangements: Banking, open market purchase etc.

Broad Approach for Projecting Power Availability

3.40 Uttarakl1and has firm allocated share in Central Sector Generating Stations (CSGS) of National Thermal Power Corporation (NTPC), National Hydroelectric Power Corporation (NHPC), Tehri Hydro Development Corporation (THDC), Satluj Jal Vidyut Nigam Limited (SJVNL) and Nuclear Power Corporation Limited (NPCIL).

55

------·----···--·-------···-----

3.41 The Petitioner has estimated the energy availability from these generating stations to UPCL at Ex-Bus. For estimating the energy availability, the Petitioner has considered average of actual month wise gross generation in last 3 years (i.e. FY 2016-17, FY 2017-18 and FY 2018-19) of each station. This has been done to account for the seasonality effect of energy availability from different stations. Further, the normative auxiliary consumption and average allocation i.e. firm share and unallocated quota of last two years from each station has been applied for projecting the share of power availability to UPCL from Thermal Power Stations during FY 2020-21. In case of aberration in generation from a generating station during any year or month due to non-functioning or maintenance, shut­down, etc., the same has been excluded for the purpose of projections.

3.42 For stations which have not been operational for complete 3 years, the average of the actual monthly generation during the years in which such stations have been fully operational has been considered. For new and upcoming stations, Uttarakhand's expected entitlement from each station has been considered using the normative technical norms.

3.43 The Petitioner has considered the actual station-wise PGCIL losses in FY 2018-19 to project the availability from central generating stations at Ex-Bus for FY 2020-21.

A vai/abi/ity from UJVNL Stations

3.44 The Petitioner has estimated the monthly availability from UJVNL's 9 Large Hydro Plants, Maneri Bhali-11 and Small Hydro Pla11ts of UJVNL based on average of actual month wise net generation of last 3 years (FY 2016-17, FY 2017-18 and FY 2018-19). The availability from UJVNL stations at Ex-bus for FY 2020-21 is tabulated below:

Table 44: l>rojected avatfabi!fty from U.JVNL Stations for FV 2020-21 (MU)

Large Hydro 166 232 298 270 292 314 266 170 182 194 151 175 2711

Maneri Bali-II 70 139 198 174 185 178 105 55 42 36 35 48 1265

Small Hydro 17 18 18 15 16 15 6 13 18 17 15 18 187

Sub-Total 253 389 515 459 494 508 377 239 242 248 201 240 4163

A vai/abi!ity from NTPC Stations

3.45 The Petitioner has projected the monthly availability from NTPC stations of Singrauli, Unchahar- I, II & Ill, NCT Dadri II, Rihand STPS I, II & III, l<ahalgaon-11 and Jhajjar Aravalli based on allocation sharing using the first 6-month actual data, normative auxiliary consumption and share of Uttarakhand from each station.

3.46 The monthly generation projection for Gas Power Plants like Anta, Auraiya & Dadrl has been done based on average of actual month wise net generation of last 3 years (FY 2016-17, FY 2017-18 and FY 2018-19).

3.47 The availability from NTPC's hydro power station l<oldam has been projected by the Petitioner based on average of actual month wise generation of last 3 years (FY 2016-17, FY 2017-18 and FY 2018-19).

(1 ~.;;. 56

3.48 The availability from NTPC stations at Ex bus fo,- FY 2020-21 has been tabulated below:

Table 45: P!'ojected availability from NTPC Stations for FY 2020 .. 21 (t"IU)

Singrauli 49 59 57 61 58 61 63 64 64 67 61 63 FG Unchahar-1 20 19 16 23 15 14 12 15 18 21 20 22 F G Unchahar-2 9 9 8 11 8 9 7 8 7 10 8 8

F G Unchahar-3 6 7 6 9 6 7 6 7 7 8 7 7

F G Unchahar-4 7 13 11 13 14 10 9 11 13 15 15 16 --------

NCTDadri:2 5 5 2 2 1 1 1 ~1

1 1 1

Rihand-1 STPS 23 27 24 31 25 27 28 25 27 21 25

Rihand-2 STPS 21 19 21 27 23 23 24 23 24 23 22 22 ---

Rihand-3 STPS 28 30 27 27 26 26 19 27 27 29 26 27 Kahalgaon-II 19 17 15 15 14 13 16 18 18 15 14 15

Jhajjar Aravali 8 9 10 3 2 2 2 4 4 3 5 6

Koldam (Hydro) 9 21 32 40 40 23 11 7 6 5 5 6

Anta Gas 0 1 1 0 2 2 2 1 0 2 1 2

726

215

101

82

147

22

309

274

318

187

57

203

15 ---

Auraiya Gas 2 2 1 1 2 1 1 0 0 1 1 1 12 Dadri Gas 8 9 6 5 4 4 4 5 6 3 5 5 64 Sub Total 216 247 235 269 239 223 203 217 220 228 211 225 2734

Availability from NHPC Stations

3.49 The Petitioner has projected the monthly energy availability from NHPC stations of Salal, Tanakpur, Chamera- I, II & III, Uri I & II, Dulhasti, Dhauliganga, Sewa-II, and Parbati Stage III based on the average of actual month wise generation of last 3 years (FY 2016-17, FY 2017-18 and FY 2018-19).

3.50 The Petitioner has also projected the energy availability from free power share of Tanakpur and Dhauliganga based on last 3 years average (FY 2016-17, FY 2017-18 and FY 2018-19 of actual monthly generation.

3.51 In case of monthly energy availability from Kishanganga HEP, the Petitioner has considered the energy at Ex bus as last year's actual.

3.52 The availabil'1ty from NHPC stations at Ex Bus for FY 2020-21 has been tabulated in the table below:

Table 46~ Projected availability fro111 NHPC Stations for FY 2.020-21 (MU)

Sala! 3 5 6 6 6 5 2 1 1 1 1 2 39 Tanakpur 0 0 1 1 1 2 1 1 0 0 0 0 9

Chamera I 7 9 11 13 13 8 4 2 2 2 4 5 80

Charnera II 3 4 5 3 3 2 1 1 1 1 1 1 26

Chamera III 5 8 9 9 8 6 3 2 1 1 1 2 55

Uri 11 12 11 11 10 6 3 3 3 3 =ii_~~92 Dhauliganga 3 5 8 9 9 7 4 2 2 1 2 54

_ ___::_i___ - - --- ----·

57

r-9' ,,--,

• Dulhasti 11 17 16 13 14 14 12 7 6 4 5 126

Sewa II 4 3 2 3 3 2 1 1 1 1 3 4 28 ~ -~

Url II 9 10 10 9 8 6 3 3 2 2 4 7 74

Parbati Ill 2 3 5 8 8 4 2 1 1 () 0 0 36

Kishanganga 3 2 3 3 2 2 0 () l 1 1 1 17 --·-- ~ - ,- -

Sub-Total 60 80 86 89 87 63 38 26 20 19 29 39 63~

Availability from NPCIL Stations

3.53 The Petitioner has projected the monthly availability from Narora and Rajasthan Atomic Power Plants based on the average of actual month wise generation of last 3 years (FY 2016-17, FY 2017-18 and FY 2018-19).

3.54 The availability from NPCIL stations at Ex Bus for FY 2020-21 has been tabulated below:

Table 47: Projected availability from NPCIL Stations for FY 2020··21 (MU)

• Narora APP 13 13 12 13 13 9 13 16 16 14 13 16 161

Rajasthan APP 15 17 19 15 15 11 10 13 14 15 12 11 166

Sub-Total 28 29 31 28 28 21 22 29 30 28 25 27 327 - -··-

Availability from SJVNL Stations

3.55 The Petitioner has projected the monthly availability from Nathpa Jhakri station and Rampur HEP based on 2-year average (FY 2016-17 and FY 2017-18) of actual month wise generation.

3.56 The availability from NPCIL stations at Ex Bus for FY 2020-21 as given below:

Table 48: Projected availabiiity from SJVNL Stations for FY 2020-21 {t'111U)

Rampur 13 26 27 14 215 Sub-Total 18 37 49 47 36 19 12 10 9 8 9 294

Availability from THDC Stations

3.57 The Petitioner has projected the monthly availability from Tehri HEP-I and l(oteshwar based on last 3 years average (FY 2016-17, FY 2017-18 and FY 2018-19) of actual month wise net generation

Koteshwar Sub-Total

Table 49: Projected availability from THDC Stations for t~Y 2020-21 (MU}

10 10 6

13 22 18 6

14 7

17 6 7 79

14 16 190

L.----·--··------------------~-------- ---.~------------··- ·-·

L

.. J!:_S

Availability from Vishnu Prayag, GVI( Srinagar & Rajwakti St-IP Hydro Electric Project

3.58 The Petitioner has free power share from Vishnuprayag, GVI< Srinagar HEP and Rajwakti SHP in addition to NHPC (Dhauliganga and Tanakpur) and THDC plants. The Petitioner has projected the monthly availability from Vishnuprayag and GVK station based on 3 years average (FY 2016·17, FY2017·18 and FY 2018·19) of actual month wise net generation.

3.59 The Petitioner has projected the monthly availability from Rakwakti SHP based on 3 years average (FY 2016·17, FY2017·18 and FY 2018·19) of actual month wise net generation.

Availability from UREDA Stations and Independent Power Producers (IPP) Stations:

3. 60 The Petitioner has estimated the monthly availability from URE DA and !PP stations (except for solar roof top, Solar IPPs, Gama & Shravanti generators) based on p,·evious 3 years average (FY 2016·17, FY 2017-18 and FY 2018·19) of actual month wise gross generation, normative auxiliary consumption and share of Uttarakhand from each station.

3.61 The availability from Gama and Shravanti Gas Plants Petitioner has considered the energy at Ex Bus as last year's actua I.

3.62 The availability from small Solar IPPs and PV rooftop systems which have commissioned recently has been estimated by the Petitioner by considering last year's actuals.

3.63 The energy availability at Ex Bus for FY 2020·21 has been shown below:

Table 50: P..-ojected 1-\vailability from UREDA Stations and IPPs for FY 2020-21 (MU)

UREDA 0.1 0.2 0.3 0.4 0.4 0.4 0.5 0.3 0.3 0.2 0.2 0.1

Rajwakti Him Urja 1 1 2 1 2

SHP 2 3 2 2 1 1 1

~ ~

Greenko Budhfl Hydro Power Pvt 14 32 40 45 47 33 17 8 5 5 3 5

Ltd Debal 1 1 2 2 2 3 3 2 1 1 1 1

Loh a rKhet 1 1 2 2 3 3 3 2 1 1 1 1 --~~---- -Gunsola Hydro

Agunda Tl1atl 1 1 1 2 2 2 2 1 1 1 1 1

Bhilangana( Swasti )

5 7 11 14 15 15 9 5 3 2 1 3

Vanala 2 3 4 5 5 5 5 3 2 2 2 2

Birahi Ganga 1 1 2 4 5 5 3 2 1 1 1 1

Himalayan Hydro 1 1 1 1 1 1 1 1 0 0 0 0

Pvt. Ltd.·Tanga --~-- - ~ -- --Uttar Bharat Sarju

0 1 2 3 3 3 3 2 1 1 1 1 ]]

Utta1- Bharat 0

Sarju·III 0 1 3 3 3 3 21 1 1 1 1

59

·----·

(i I J, '-..:. ,-

3.4

19

254

18

20

13

90

42

24

8

22

19

Co-Generation

Co-Gen: RBNS Sugar Mil/

5 0 0 0 0 0 0 3 9 8 8 9 --------~-·--

oj Co-Gen: Ut:tam 4 0 0 0

Sugar Mills 0 0 3 5 6 6 6

Co-Gen: Lakshmi 9 2

Sugar Mills 0 0 0 0 0 5 9 10 9 10

Solar Plants

Solar !PP 37 37 37 28 29 29 3S 27 26 25 23 38 Solar Rooftop 0 0 0 0 0 0 1 1 1 1 3 Gas Plants

Gama gas plant 65 67 60 66 65 47 63 0 26 39 24 55 Shravanti gas

62 76 73 60 45 plant 62 102 81 86 61 66 61

Other IPPs

Sasan 65 59 58 53 4s 1 50 58 65 64 66 60 64 Sub Total 280 297 305 297 281 271 319 219 249 234 211 269

New stations

3.64 There are several new projects that are expected to be commissioned during FY 2020-21. For these stations, projections of energy availability have been done as detailed below:

a) The expected COD has been taken from various sources like latest CEA reports, PPA signed with the generation companies and as per infom1ation made available by the generators as shown below;

Table 51: Details of Upcoming Stations during FY 2020-2.1

Meja Thermal Apr-20 13

Tanda II Apr-20 26

UREDA Solar Apr -20

2020-21 SECI Solar Oct-20

200

200

SECI Non-Solar Oct-20 100

Vyasi (UJV11) ( 120MVV) Dec-20 120

Tapovan Vishnugad (NTPC) (520 MW) Dec-20 83.2

b) Power availability has been considered as approved by the commission in MYTorder 2018-19

c) Since the commissioning of Beta Gas Plant has been delayed, the Petitioner has not considered additional energy availability from the plant for the entire control period.

42

30

5'1

372

7

576

834

708

3204

3.65 The estimated availability from upcoming stations at Ex Bus for FY 2020·21 has been projected as under:

Table 52: Projected Power Availability from Upcoming Stations during FY 2020-21 (MU)

NTPC

Meja-I Unit-II 16 14 14 13 I 12 12 14 16 16 16 15 16

Tanda-Il TPS 16 15 14 13 12 12 14 16 16 16 15 16

Tapovan 7 6 8 8 7 Vishnu ad

11 11 9 6 5 5 7

UREDA

UREDA Solar 25 301 2s I 131 22 I 241 30 1 241 241 20 19 29

SECI

SEC! Solar 15 17 16 7 13 14 17 14 14 11 11 17

SECI Non-Solar 9 11 10 5 8 9 11 9 9 7 7 11

UJVNL

174

174

91

286

167

105

Vyasi 28 26 33 34 30 44 45 37 26 20 20 27 371

Total 116 119 124 93 105 126 142 124 111 95 91 123 1368

3.66 On the basis of the above-mentioned projections from external and internal

sources of Uttarakhand (excluding short-term purchase), the energy to be

procured from all sources (at Ex Bus) by the Petitioner has been projected as summarized in table below:

Table 53: Summary of Energy Availability for FY 2020-21 (MU)

1. llHPC 634.53

2. SJVNL 293.66

3. THDC 189.83

4. NTPC 2733.68

5. NPCIL 327.19 ----

6. UJVNL 4163.15

7. UREDA & I PP Hydro 581.09

8. Co-Generation 125.75

9. State Gas stations 1409. 98

10. Sasan 708.30

11. Solar (IPPs & Rooltop) 379.25

12. Upcoming Stations 1368.03

13. State Royalty Power 1062.60

14. Total Power purchase from firm sources

13977.06

6:l

·--------·----·-----------------------

I

~----------~-~ - ----~---~---

Transmission losses

3.67 The intra-state transmission losses have been considered as 1.40% for FY 2020-21 based on the losses as approved by the Hon'ble Commission in the MYT order.

3.68 The Inter-state transmission losses for the Control Period have been considered based on average yearly losses for FY 2018-19.

Procurement of deficit power and adjustment of surplus power

3.69 The availability from the existing stations and upcoming stations shall not be sufficient to meet the increasing demand of the state. Therefore, the Petitioner has to rely on other sources to meet the demand of the state. Accordingly, the Petitioner has projected monthly purchase of power through open market in power deficit months for FY 2020-21.

Energy Balance

Table 54: l':nergy Balance at State Periphe1·y for FY 2020-:J..i (MU)

Tota! Energy Availability at 1008 1255 1434 1418 1460 1378 1197 915 934 917 819 980 State Periphery

Finn Sources 1008 1255 1434 1418 1460 1378 1197 915 934 917 819 980

Non-Finn Sources 0 0 0 0 0 0 0 0 0 0 0 0 -----·----

Energy Requi1·ement at 1140 1207 1351 1329 1301 1264 1211 1201 1230 1241 1176 1157 State Periphery

PTCUL Losses 1.40% 1.40% 1.40% 1.40% 1.40% 1.40% 1.40% 1.40°/() 1.40% 1.40% 1.40% l.40%

Energy

Requirement at 1124 1190 1332 1310 1283 1246 1195 1184 1213 1223 1160 1140 Discom Periphery

Distribution Losses 14% 14% 14% 14% 14% 14% 14% 14% 14% 14% 14% 14% ----·--·---

Energy Sales 967 1024 1145 1127 1104 1072 1027 1018 1043 1052 997 981

Energy Deficit/ 132 -48 -83 -89 --159 -114 15 286 296 323 357 177

(Surplus)

Power Purchase Cost

3.70 The cost of power available from various sources. has been projected by UPCL considering the following approach:

13714

13714

0

14808

14601

14%

12557

1094

L.- ------·---------- ----····--·--··----·----- --------·-

L

Cost of Power fron1 UJVNL stations

3.71 For UJVNL's Large Hydro stations and MB-II, the Petitioner has considered AFC in FY 2019-20 based on the actual Half yearly data and multiplied it by 2 to project it for the complete year and used an escalation rate of 4°10 per annum to arrive at AFC for UJVNL stations for FY 2020-21.

3.72 For small stations, the Petitioner has considered AFC in FY 2019-20 based on the actual Half yearly data and multiplied it by 2 for the complete year and used an escalation rate of 4% per annum to arrive at AFC for UJVNL stations for FY 2020-21.

3.73 The variable and other cost Charges in FY 2019-20 based on the per unit ,·ate of the actual Half yearly data which is then multiplied by the total energy to project the variable and other cost for the complete year and used an escalation rate of 4% per annum to arrive at variable and other cost for UJVNL stations for FY 2020-21.

3. 74 Arrear cost is not included and will be considered in the true-up for next year.

3.75 The Petitioner has considered cess, water tax in FY 2020-21 in the other cost based on actuals.

Cost of power from NTPC Stations

3.76 It is submitted that the Tariff Orders for NTPC stations for the Control Period FY 2019-24 are still to be issued by the CERC. Therefore, in absence of approved AFC for these stations, the cost of power available from NTPC stations has been projected based on the following assumptions:

a) The Petitioner has considered AFC in FY 2019-20 based on the actual Half yearly data and multiplied it by 2 to project it for the complete year and used an escalation rate of 4% per annum to arrive at AFC for NTPC stations for FY 2020-21.

b) The variable and other cost Charges in FY 2019-20 based on the per unit rate of the actual Half yearly data which is then multiplied by the total ener·gy to project the variable and other cost for the complete year and used an escalation rate of 4°10 per annum to arrive at variable and other cost for NTPC stations for FY 2020-21.

c) Arrear cost is not included and will be considered in the true-up.

3.77 The cost of power available from NTPC Koldam Hydro Station has been projected based on the following assumptions:

a) The Petitioner· has consider·ed AFC in FY 2019-20 based on the actual Half yearly data and multiplied it by 2 to project it for the complete year and used an escalation rate of 4°/o per annum to arrive at AFC for station for FY 2020-21.

b) The variable and other cost Charges in FY 2019-20 based on the per unit ,·ate of the actual Half yearly data which is then multiplied by the total energy to project the variable and other cost for the complete year and

63

used an escalation rate of 4°10 per annum to arrive at variable and other

cost for station for FY 2020-21.

c) Arrear cost is not included and will be considered in the true-up for next

year.

Cost of power from NNPC Stations

3.78 Similar to the case mentioned in case of NTPC stations, the tariff orders for NHPC stations have also not been issued by CERC. Therefore, the cost of power available from NHPC stations has been projected based on the following assumptions:

a) The Petitioner has considered AFC in FY 2019-20 based on the actual Half yearly data and multiplied it by 2 to project it for the complete year and

used an escalation rate of 4°10 per annum to arrive at AFC for NHPC

stations for FY 2020-21.

b) The variable and other cost Charges in FY 2019·20 based on the per unit rate of the actual Half yearly data which is then multiplied by the total

energy to project the variable and other cost fo1· the complete year and used an escalation rate of 4°10 per annum to arrive at variable and other

cost for NHPC stations for FY 2020·21.

c) Arrear cost is not included and will be considered in the true-up.

Cost of power from NPCIL Stations

3.79 In absence of the relevant Tariff Orders, the cost of power available from NPCIL stations has been projected based on the following assumptions:

a) The variable and other cost Charges in FY 2019-20 based on the per unit

rate of the actual Half yearly data which is then multiplied by the total energy to project the variable and other cost for the complete year and

used an escalation rate of 4°10 per annum to arrive at variable and other

cost for NPCIL stations for FY 2020-21.

b) Arrear cost is not included and will be considered in the true-up.

Cost of power from TNDC Stations

3.80 The cost of power available from THDC stations has been projected based on the following assumptions:

a) The Petitioner has considered AFC in FY 2019-20 based on the actual Half yearly data and multiplied it by 2 to project it for the complete year and used an escalation rate of 4°10 per annum to arrive at AFC for THDC

stations for FY 2020-21.

b) The variable and other cost Charges in FY 2019-20 based on the per unit rate of the actual Half yearly data which is then multiplied by the total energy to project the variable and other cost for the complete year and

64

used an escalation rate of 4°10 per annum to arrive at variable and other cost for THDC stations for FY 2020·21.

c) Arrear cost is not included and will be considered in the true·up for next year.

Cost of power from SJVNL Stations

3.81 The cost of power available from SJVNL stations has been projected based on the following assumptions:

a) The Petitioner has considered AFC in FY 2019·20 based on the actual Half yearly data and multiplied it by 2 to project it for the complete year and used an escalation rate of 4% per annum to arr_ive at AFC for SJVNL stations for FY 2020·21.

b) The variable and other cost Charges in FY 2019·20 based on the per unit rate of the actual Half yearly data which is then multiplied by the total energy to project the variable and other cost for the complete year and used an escalation rate of 4°10 per annum to arrive at variable and other cost for SJVNL stations for FY 2020·21.

c) Arrear cost is not included and will be considered in the true·up for next year.

Cost of power procured fro1n Co-Gen, Gas based stations, Other IPPs, Private Projects

3.82 The Petitioner has considered AFC in FY 2019·20 based on the actual Half yearly data and multiplied it by 2 to project it for the complete year and used an escalation rate of 4°10 per annum to arrive at AFC for Co-Gen, Gas based stations, other IPPs, Private Projects for FY 2020·21.

3.83 The variable charge and other cost for Co·Gen, Gas based stations, other IPPs, Private Projects is based on the per unit rate of the actual Half yearly data which is then multiplied by the total energy to prnject the variable and other cost for the complete year and used an esca!ation rate of 4°10 per annum to arrive at variable and other cost for for FY 2020·21.

3.84 Arrear cost is not included and will be considered in the true-up for next year.

3.85 Cost for Solar Rooftop and UREDA plants has not been projected, as the actual power purchase cost from these sources is zero because no bills were raised in Hl of FY 2019·20. As the bills are not raised regularly the cost towards these sources could not be accounted for and shall be considered at the time of true·up.

3.86 No quantum of power has been assumed from Meja Thermal I on account of higher variable cost. The Petitioner would be planning to procure power from the same as and when required. However, the fixed cost has to be given by the Petitioner which has been considered.

65

Cost of Free power

3.87 The cost of free power has been calculated separately !01· each year based on the approach adopted by the Commission in its earlier Tariff orders. The rate of state royalty power has been considered equal to the average rate of power procured by the Petitioner from large hydel stations. Based on the said approach the rate of free power has been projected as under:

Table 55: Rate of free power for- FY 2020-21 (Rs-./kWh}

1 Dhauliganga 126.59 35.08

2 Tanakpur 39.44 10.93

3 Tehri 374. 59 103. 81

4 Koteshwar 145.81 40.41

5 Vishnu Prayag 227.57 63.06 ~~-----·-- ~~-.,~-

6 GVK Srinagar 147.12 40.77

7 Sub-Total 1061.11 294.06

Cost of power from new stations

2.77

2.77

2.77

2.77

2.77

2.77

2.77

3.88 For projects which are under development, the rate has been considered based on a provisional tariff of Rs. 4.00/kWh, similar to the rate approved by the Commission in the Tariff Order of FY 2019-20.

Renewable Purchase Obligation

3.89 As per UERC (Tariff and other Terms for Supply of Electricity from Renewable Energy Sources and non-fossil fuel based Co-Generating Stations) Regulations, 2018, the Petitioner is required to purchase a minimum percentage of its total electricity requirement for own consumption excluding consumption met from hydro sources of power from renewable energy sources under renewable purchase obligation during each financial year.

3.90 The Petitioner has studied the energy requirement and existing capacity from solar and non-solar renewable sources. Based on the Renewable-energy Purchase Obligation (RPO) targets for FY 2020-21, after accounting for the renewable power available from various sources, through REC is shown below:

B

C

Table 56: Renewable purchase obligation (RPO) for ~-::y ;~oZ0··'.%1.

10.25% 7.25% 10.25%

RPO TMget (MU) 796.42 563.32 824.48

8.75%

703.83

0 Tota\ Power Purchase to meet

683_80 379

_25

RPO Tar et 746. 26 833.09

F Past Unmet brought forward O O 112.61 184.07 -·-~~-+.~---~~C---· .

E UnmetTarget 112.62 184.07 ~. 78~22 J129.26

c_G_~--~-tal Unmet_T_a~rg~e_t~-~~· 190.84_ __5_4_.8_1_.

66

·-·-·-·-,.-,;;.,_:

3.91 In absence of physical power available from renewable sources the unmet RPO target is proposed to be met by purchasing REC from open market at the rate of Rs. 1.50 per kWh

Inter-state and Intra-State Transmission Charges

3 .92 The transmission charges for the Control Period have been projected based on the following methodology which is in line with the approach of the Commission:

a) Actual inter-state transmission charges without arrear for first six months of FY 2019--20 have been used to compute the average per unit rate of PGCIL transmission charges by dividing the total amount paid to PGCIL by the total units wheeled through PGCIL network from April 2019 to September 2019. The computed rate of in FY 2019--20 has been escalated at 5°/o per annum fo arrive at the inter-state transmission rate for FY 2020--21. The total PGCIL transmission charges have been computed considering the escalated per unit transmission charge and projected total units required to be wheeled through PGCIL network in FY 2020--21. The Petitioner requests the Commission to consider the same as per actuals in

the True-up of FY 2020--21

b) For intra-state transmission and SLDC charges for FY 2020--2021, the Petitioner has considered the ARR approved in PTCUL MYT Order 2019. The Petitioner requests the Commission to consider PTCUL and SLDC Charges as approved in the current tariff proceedings.

c) The Table below details transmission charges projected for FY 2020--21:

Table 57: Transmission charges for FY 2020-2.1 (Rs. Cr.)

PGCIL Charges 373.37

PTCUL & SLDC Charges 415.45 e---------------+--------

Total Transmission Charges 788.82 --~----~------~

Total Power Purchase Cost for FY 2020-21

3.93 The summary of power purchase cost and quantum (at Ex Bus) for the FY 2020--21 based on the above methodology is summarized in the table below:

"fable 58: Power Ptn-chase Summary for f=y 2020-21

Mus Rs. Cr. Rs./kWh

Tanakpur 8.63 5.59 6.48

67

~~--~---·-~-~~.~.·--~-~----

Mus Rs. Ci-. Rs./kWh 80.43 17.09 2. 13 Chamera I

Chamera II 26.06 ----- --,------·-·-

Chamera III 54.68

91.71 54.23

Uri ,~~~--------------1------~---+­

Dhauliganga Dulhasti ----- 125.57

Sewa II 27.69

Uri II 73.65

Parbati III 35.95

Kishanganga 17.43

6.15 ·---

28.95

17.89

18.56

72.47 17.35

43.69

25.29

6.81 Sub-Total 634.53 266.23

---

2. 36

5.29

1.95 3.42

5.77

6.27 5.93 7.04

3.91 4.20

t-S_JV_N_L _____________ -t-·-----------·- bl---_-----, Nathpa lhakri 79.09 20.88 2.64 Rampur Equity Power 214.57 97.93 4.56

Sub-Total 293.66 118.81 4.05 -----------------t---·---------t-------;----·--.j

1-------------------1---------THDC Tehri HEP I 110.74 46.46 4.20

1--------------·--+----·---=~~1-----=~--+-----· Koteshwar 79.09 43.43 5.-19 Sub-Total 189.83 89.89 4.74

--------------t--------------1 >-----·-------------

NTPC

726.45 150.58 2.07 Singrauli ----------·-­FG Unchahar-1

F G Unchahar-2

-----·-------t------- ·--·-----

FG Unchahar-3 F G Unchahar-4

NC T Dadri:2

Rihand·l STPS

Rihand·2 STPS

Rihand·3 STPS

Kahalgaon-II

Jhajjar Aravali

Koldam (Hydro)

Anta Gas

Auraiya Gas Dadri Gas Sub-Total

214.89 105.01 4.89 ---------·

49.06 4.88 ----1------------f---.-----··I

100. 60 82. 12 41.91 5. 10

----------+-- ··--------146.99 80.75 5.49

22.09 10.02 4.54

309. 33 65.39 2.11

273.96 46.30 1. 69

318.48 83.03 2.61

186.54 62.90 3.37

57.04 43.52 7.63

203.25 118. 16 5.81

15.26 20.93 13.71 12.20 24.75 20.28 64.47 54.96 8.52

2733.68 957.27 3.50

NPCIL l-----------------+----------~~~1----~~·------

Naro1·a APP 160.74 42.09 2.62 1--------------------

Rajasthan APP ·-··-----------i------- _1_6_6_.4_5-t-____ 5_7_.8_2....,-______ 3_._4_7-t Sub-Total 327.19 99.91 3.05

--j-·---·------t----·-- ------

Total CSGS =-t 4,178.90 1532.rn ===~

. ···- ·=~-==j ------- -- ----·---~·--·-~-------- ·- - ~s _ _j

Mus Rs. Cr. Rs./kWh

Dhakrani 86.59 23.34 2.70 f------------------t-----------+-------+-

Dha!ipur 149.46 30.28 2.03

Chi bro 574.00 88.14 1.54

Khodri 293.67 50.14 1.71 Kulhal 99.24 21.15 2.13

f-·--------------··---t------------1-------+-48.65 Ramganga 203.54 2.39

----Tiloth 382.90 57.61 1.50 ----

721.00 97.99 1. 36 --------------+--

Chilla Khatima 200.45 51.44 2.57

Sub-Total 2710.85 468.64 1.73

Maneri Bhali II 1265.23 377.53 2.98

Small Hydro Sub-Total 187.07 38.60 2.06

Total UJVNL 4163.15 884.77 2.13 ,,,---·------

UREDA

SHPs ± Sub Total 3.38 0.00 0.00

-· ·~---··-----+-- -----+-------,

IPP Hydro ··----------i--t-----------+----- --+--Rajwaktl Him Urja SHP 20.92 Greenko Budhil Hydro P-ower p\1t Ltd ... 1 _, 253.82

7.07 3.64 99.09 3.90

Debal 1 chamoli hydro 17.81 7.13 4.00 LoharKhet ( parvatiya power) 19.69 7.88 4.00

6.09 4.63 36.21 4.00

Gunsola Hydro Agunda Thati 13.17 ---------t----------+--------+--

Bhilangana(Swasti) 90.47 Vanala 41.93 21. 76 5.19

10.53 4.31 13.63 6.10

Birahi Ganga 24.41 f----~-----· -----+--------~~1--------1--

Sadu II 22.33 Uttar Bharat Sarju lll 19.42 11.65 6.00

Gangani 40.09 18.77 4.68 Badlyar 15.13 7.93 5.24 Sub-Total 579.20 247.75 4.28

f--~--~---------f---------~f------+-­Co-Generation

RBNS Sugar Mill 41.77 15.28 3.66 Uttam Sugar Mills 29.90 10.88 3.64 Lakshmi Sugar Mills 54.08 19.64 3.63 Sub-Total 125.75 45.80 3.64

Gas

Gama 575. 77 436.05 7.57 Shravantl 834.22 757.40 9.08 Sub-To-ta-,~------- ----f-- 1409.98 1193.45 8.46 >---------------·-+---~----·------··------~--- -------~

69

~' /

---------- ----------- ---

Mus Rs. Cr. Rs./kWh Solar

-"RV Akash Ganga solar power ltd 2.57 1.29 5.01 Metro Frozen 1.21 ,--- 0.60 4.95

Jay Ace Technologies l.86 1.10 5.89 ----

UJVNL Dhakrani 2.42 1.67 6.89 UJVNL khodari 7.11 4.90 6.89 Madhav Infra 19.50 15.70 8.05 Purshotam Industries Ltd.-1 1.07 0.86 8.04

Purshotam lndustries Ltd.-II 1.24 1.00 8.02 Purshotam Ispat-I 1.34 1.10 8.20 ,-----~--~-------+----------+-- ------+--------; Vivaan Solar Pvt. Ltd. 4.22 2.95 6.99 Eastman International 0. 98 0. 69 7. 03 Purshotarn !spat-II l.27 1.05 8.28 R.C. Energy 1.26 0.88 6.98

t-------1 Advika Energy 1.46 0. 98 6.67

A.R. Solar Power-I 1.42 0.72 5.03 f-cA~. R~.-S~o~l-a-r~P-o_w_e-r-~1~1---------t-------- 1. 53 0. 77 5. 01 f-c--~---~---------·· ---

Devishi Renewal energy 21.53 10.61 4.93

Devishi Solar power 21.71 10.76 4.95 f---------+

Eminet Solar power 21.20 10.75 5.07 , ______ _, Sunworld Energy pvt 20.24 10.28 5.08 Emami Power Ltd. 30.53 15.64 5.12

----------,--- ---Hydro Power Engineers 1.53 0.76 4.99

--~f---------+-----f--Impex India 3.77 1.88 4.98 Technique Solalre Invest 7.93 4.05 5.11 Makin Developers Pvt. Ltd 1.63 ,---- 0.86 5.28

Ballupur solar power pvt.Ltd 15.53 7.98 5.14 Chudiala Solar power project pvt. 16.13 8.41 5.22

----+--------+---------j Shakumbhari solar power project pvt

Ltd I Bindookharak solar power project pvt ltd

15.94 8.38 5.26

8.29 4.36 5.27

Bhagwanpur solar projects pr!vate ltd __ +------ ____ 8_._3_2+--- ___ 4.43-+ _____ 5_._32 PL sunrays power limited 17.02 8.97 5.27 -------+------ ,----PL surya vidyut ltd 16.68 8.34 5.00 PL solar Renewable ltd 16.01 8.12 5.07

Haridwar solar projects pvt lt~---+--------1_6_._1_3+--- ____ 7_._9_9--+-' _____ 4._9_5--; Haridwar solar projects pvt ltd 2 16.57 8.19 4.94

l--------~~-~-------1---·---·---+--------+-----------{ Sunheti solar power proj pvt ltd 7.79 4.09 5.25 AB Renewable Energy pvt ltd 7.61 4.01 5.27

Canal Bank Solar pv plant Dhakrani 10.06 6.11 6.07 e--------------'-1----~~--~1-------~~1-----~------'1------~---c--1

Canal Bank Solar pv plant Dhalipur 11.22 6.87 6.12 Canal Top Solar pv plant Dhalipur 1.03 0.66 6.35

6c3kpattllar canal Bank 6.89 4.28 6.22

Sub-Total 371.77 203.01 5.46

Solar Rooftop I

___ s-:::u-=b=--T-=o=-t-a __ 1 ___ ·-_-_-_-_-=-=-~-----=----_------+------- 7.48 l===-_4 ___ 0_1~ 5.36

L _________ ------------- --- ______ ,,,,_ ---

Other Large Private

Meja Thermal I Sasan ----·

Sub-Total

Total IPP

New Stations

Meja Therrnal II

Tanda II Vyasi

Tapovan Vishnugad

SEC! Solar

SECI Non-Solar

UREDA Solar

Sub-Total

Mus Rs. Cr.

0.00 14.67 708. 30 130.27

708.30 144.94

3205.87 1838.96

173.80 69.52

174.29 69.72 370.74 148. 30

90.68 36.27

167.49 67.00 104.68 41.87 286. 35 114. 54

1368.03 547.21

--·- ----·--

126.59 35.08 State Royalty Pow~-------t---·------~-t-----~ Dhauliganga

Tanakpur 39.44 Tehri 374. 59 Koteshwar 145.81

Vishnu Prayag 227.57 147. 12 GVK Srinaga_r _____ ··---·----+- _______ _

Sub-Total

Total Power Purchase from Firm

Sources

Open Market Purchases & UI __ _

1061.11

13977.06

1141.87 Open Market Purchase --------------+----

Sub-Total 1141.87

Total Purchase 15118.93

Transmission Charges

PGC!L Charges

PTCUL Charges

Total Transmission charges ---------

Cost towards purchase of REC

Total Power Purchase Cost (inc 15118.93

10.93 103.81

40.41 ·----

63.06 40.77

---· 294.06

----

5097.10

456. 75 456.75

5553.85

373.37 415.45 788.8

--·-

36.85

6379.52

Rs./kWh

1.84 2.05

5.74

4.00

4.00 4.00 4.00 4.00

4.00 4.00

4.00

----·--

2.77

2.77 2.77 2.77

·--··-2.77 2.77

-·--·

2.77

3.65

4.00 4.00

3.67

-----

4.22 trans. Charges)_

-------~---------~------~---

71

-------·--- ----

Capita! Expenditure Plan and related expenses

3.94 As per Regulation 8(1) (c) (v) of the UERC Tariff Regulations, 2018, the Distribution licensee is required to submit the Capital Investment Plan for the entire Control Period considering the sales/demand forecast 1 power procurement plan, distribution loss trajectory, targets for quality of supply, etc. Further, the investment plan is also required to include yearly phasing of capital expenditure along with the source of funding, financing plan and corresponding capitalisation schedule

"c) The Business Plan for the Distribution Licenses shall be for the entire control period and shall, interalia, contain-

(v}Capital investment plan considering the sales/demand forecast, power procurement plan, distribution loss trajectory, targets for quality of supply, etc. The capital investment plan shall be consistent with the perspective plan drawn by the State Transmission Utility (STU}, and the investment plan should also include yearly phasing of capital expenditure along with the source of funding, financing plan and corresponding capitalisation schedule;

{vi) The appropriate capital structure of each scheme proposed and cost of financing (interest on debt and return on equity}, terms of the existing loan agreements, etc;

3.95 The revised Capital expenditure plan for the FY 2019-20 and FY 2020-21 is provided as follows

3.96 The proposed capital expenditure plan is summarized as part of this Petition as various parameters including depreciation, return on equity, interest, etc. are derived based on the proposed capital investment for FY 2019-20 and FY 2020-21.

1.3 District-wise details of existing electricity distribution infrastructure of Uttarakhand (as on 30-10-2019) is detailed in the following table:

72

Table 59; Dlstrk:t-1Nise Details of exist[l!1g =iec>,::ddty Distribution Inft·astructr...a·e of: ut·~~n·akhand (as on 30-10-2019)

1 1 Dehradun - - - I 62 I 123 I 1018.50 I 8071 I 909.96

2 Uttarkhashi - - - 11 20 I 88.15 I

1748 I

73.09

3 Pauri - - - 31 50 228.00 5925 271.52

4 Tehri - - - 14 27 I 150. 00 3904 153.23

5 Chamoli 3 5 38 16 23 114.00 2111 82.28

6 Rudraprayag - - - 7 8 51.00 1796 58.80

Total Garhwal Zone 3 5 I 38 141 251 1649.65 23555 1543.55

Haridwar Zone

7 I Haridwar I 1* I 2 30 61 I 128 I 1179 18333 I 1095.27

Kumaon Zone

8 j Nainital I I I

30 I

53 I

392. DO I 5898 I 529. 06 U.S.Nagar I

9 j (Kashipur, Sazpur I I I 22 I 48 I 394.50 6543 I 380.74 Jaspur)

----

10 I Almora - ----r~- -~1 - r~:z5 1 45~- -160.00- 4221 I 147.56

11 I Bageshwar I - -

I -

I 9

I 13 47.50 1737 I 56.54

Total Kumaon Zone I 0 0 0 87 159 994.00 18399 I 1113.90

Rudrapur Zone

r 12 I U.S.Nagar . (Rudrapur, Sitarganj) I

32 67 609.50 9075 573.87

13 I Pithoragarh - - - 18 29 134.50 3570 122.36

14 I Cl1ampawat - - - 7 11 47.00 1561 64.13

Total Rudrapur Zone 0 0 0 57 107 791.00 14206 760.36

Total UPCL 4 7 68 346 645 4613.65 74493 4513:os

*Now transferred to PTCUL

( 73

r, $

' --··-------· -·----- --------- ------- ---

I

Revised Capital Expenditure proposed during FY 2020-21

3.97 To achieve the anticipated load growth and targeted loss reduction, UPCL has carried out a detailed analysis of capital investment required for FY 2020-21 years. The analysis is based on various technical and physical requirements carried out by UPCL staff followed by discussions at various levels and review by senior management. UPCL capital expenditure plan is worked out after studying the requirement at various levels as we\1 as the historical trends. The costs are calculated considering the historical t,·ends and Stock issue rates (SIR) of UPCL for FY 2018-19 with suitable escalations for FY 2019-20 and FY 2020-21. The total capital Investment proposed by UPCL for the Control Period FY 2019-20 and FY 2020-21 is sumamrized below:

Table 60: Capex Surnmary for fY 2019-20 and PY 2020-21 (Rs. Cr.)

R-APDRP Part A 1

2 ------------------1------+---·--+----l

R·APDRP Part B

3 IPDS

4 DDUGJY ---

5 SAUBHAGYA

II Other Works

A. 1

2

3

4

5

6

7

Load Growth

New Substation projects

Augmentation of Existing Substations

Release of Me\lv PTW Connections

Installation of meters for giving new connections

Installation of breakers (new)

CSS 990 kVA where two t1·ansformers are installed at the same place

Laying of LT \lnes for new connections

Sub Total-Load Growth

B. Loss Reduction

8 Implementation of AMR ---+-R-e~p~l-a c_e_m_e .. nt_o __ f _M_e_c-ha-,-1 i-cci I M eter5 with Electronic

Meters and Installation of Electronic meters in un­metered connections

9

10

11 I

Laying of 11kV & 33kV Covered conductor for

forest area ---------+---Laying of LT ABC Cable in theft prone areas

Replacement of defective single phase and three phase meters

138.38 0.00

134.48 56.54

319.58 84.53

57.01 0.00

100.00 80.00

33.00 36.30

16.50 21.78

1.60 1.21

7.43 8.17

40.25 44.27

198.78 191.73

6.05 ---

9.01

126.00 172.43

17.99 15.16 ---

4.46 6.20

12

13

14

Pre-paid meters ---·--·--~ -----t-------r----Installation of 11kV & 33kV underground cab\es 42.00 36.27 -------Sub Total- Loss Reduction 196.50 239.07

--·-C.

138.38

191.02

404.11

57,01

180.00

69.30

38.28

2.81

15.60

84.52

390.51

6.05 ~-i 9.01

298.43

33.15

10.66

--~78.22_] 435.57

15

System Reliability and Safety Improvement

Additional Tra1lsfOrnlers installation with 75.00 88. 77 163. 77

associated 11\<V & LT lines_~-------r--------t--~----t~ 15.00 LT Protection System on Transformer

----+---------~-16 34.01 49.01

17 Safety measures 8.70 9.57 18.27 ·----··-~----------~-

I ---- -----~~----------~----~---·

18 Smart Grid projects for industrial areas 0.00 5.00 5.00

Sub Total - system Reliability and Safety Im rovement

98.70 137.35 236.05

D. Creation of infrastructure facilities & miscellaneous works

Procurement of Sub-station and high value 19 consumer meter testing and diagnostics 5.00 18. 70 23.70

equi rnent

20 Consumer care centres, E-payment of bills and Cash collection centres

1.19 1.19 2.38

21 Miscellaneous (IT &R&M of Workshops & other) 0.00

A. Non R·APDRP (IT Expenses) 2.80 9.88 12.68

B. R&M/Capacity Augmentation of Workshops 4.00 4.00 8.00

C. Other misc. works 2.37 2.37 4.74

Sub Total- Creation of infrastructure 15.36 36.14 51.50 facilities & miscellaneous works

23 Grand Total 1158.79 745.36 1904.15

3.98 The deployment of capital investment is proposed mainly under two following verticals:

, Central Sector Schemes

Other schemes proposed for load growth, !oss reduction, system strengthening, etc.

Central Sector Schemes

3.99 The Government of India has revamped old schemes and launched some new central sector schemes for the power sector during the previous control period. These schemes are in various stages of implementation in Uttarakhand and the capital expenditure for these schemes have been proposed in line with the timelines and commitments with the Central Government.

Figure 1: Various Central Sector Scheme being implemented in the State

R-APDRP Part A

R-APDRP Part B

IPDS DDUGJY

Central Sector Schemes

Saubhagya

# UDAY is being implemented for operational turnaround of UPCL

UDAY"

75

-------------------~-----~-

Table Gl: Proposed Year-wise expenditure of Central schemes (Rs. Cr,)

R-APDRP Part B 138. 38 0.00 138.38

IPDS 134.48 56.54 191.02

DDUGJY 319.58 84.53 404.11

SAUBHAGYA 57.01 0.00 57. 01

3.100 The Central Schemes RAPDRP Part B and DDUGJY have been envisaged to be completed by FY19-20 respectively while IPDS scheme including ERP Implementation, etc. are expected to continue upto end of the 3rd Control Period. The Saubhagya scheme has been completed in FY 2018-19 however some balance payment is expected to be made in FY 2019-20.

DDUGJY

3.101 The Government of India has launched the scheme "Deendayal Upadhyaya Gram Jyoti Yojana" for rural electrification. The erstwhile Rajiv Gandhi Grameen Vidyutikaran Yojana (RGGVY) scheme for village electrification and providing electricity distribution infrastructure in the rural areas has been subsumed in the DDUGJY scheme. Rural Electrification Corporation is the Nodal Agency for implementation of DDUGJY.

3.102 The financial support under the scheme for Utta1·akhand is as follows:

Table 62: Funding n1echanisn1 of DDUGJY for Uttarakhand

Go!

Utility

Loan (Fis/ Banks)

Additional Grant from Gol on achievement of prescribed milestones

Maximum Grant by Gol (including additional grant on achievement of prescribed milestones)

Grant

Own Fund

Loan

Grant

Grant

85

5

10

50% of tota I loan corn ponent (10%) i.e. 5%

90%

3.103 The total outlay and the details of the scheme were provided in the Business Plan Petition submitted last year

3.104 UPCL has successfully completed electrification of all 94 revenue villages identified under DDUGJY. Out of these, most of the villages are now connected to the grid while some of the villages were electrified using off-grid solution of solar.

3.105 The complete feeder segregation and electrification of remaining hamlets had been completed in March 2019.

3.106 In FY 2019·20 and FY 2020·21, the Petitioner proposes to continue with remaining works under metering and system strengthening for improving rural supply.

3.107 The overall expenditure under this scheme is proposed to be completed by FY 2019-20. The proposed capital expenditure in FY 2020-21 is as under:

Table 63: Annuaf Funding Plan for DDUGJY Scheme (Rs. Cr.)

Debt 10 8.45

2020·21 Equity-State Govt. 5 4.23

Grant 85 71.85

Total Capex 84.53

IPDS

3.108 Indian government has launched Integrated Power· Development Scheme (IPDS) for the Urban areas with the following components:

a) Strengthening of Sub-transmission and Distribution network in urban areas including provisioning of solar panels on Govt. buildings including Net metering.

b) Metering of feeders/ distribution transformers/ consumers in urban areas

c) IT enablement of distribution sector and strengthening of distribution network, as per Cabinet Committee for Economic Affairs (CCEA) approval dated 21.06.2013 for completion of the targets laid down under R·APDRP for 12th and 13th Plans by subsuming R·APDRP in IPDS and cart'ying forward the approved outlay for RAPDRP to IPDS.

3.109 The funding plan under the scheme is as under:

Table 64: Funding mechanism of IPDS for Uttarakhand

Go!

Discom Contribution*

Lender (Fis/ Ba nks)/Discom's own fund

Grant

own Fund

Loan/own fund

------~-----<----Additional Grant from Gal on achievement of prescribed milestones

Maximum Grant by GoI (including additional grant on achievement of prescribed milestones)

Grant

Grant

85

5

10

50% of total loan/own fund (10%) i.e. 5%

90%

,,../\1/inimum contribution by Discom(s) shall be 5% in case of Special Category States. However, Discom(s) contribution can go up to 15% in case of Special Category States, if tliey do not intend to avail loan. In case, the Discom(s) do not avail loon, the maximum eligible additional grant would still be 5% in case of Special Cotegmy States on achievement of prescribed milestones. The loon component would be provided

by PFC or by oilier Fis/ Banks,

77

--- ----·--- ------ ------·---------- --- ------

3.110 The Petitioner has proposed capital expenditure under IPDS du,·ing FY 2020-21 keeping in view the current progress and works being proposed in the future

3.111 The annual funding plan for IPDS works is as follows:

Table 65: Annual funding plan for lPDS works

Debt 10 5.65 2020-21 Equity-State Govt. 5 2.83

Grant 85 28.06 Total 56.54 _____________ ___J _________ ~

SAUBHAGYA

3.112 Pradhan Mantri Sahaj Bijli Har Ghar Yojana - 'Saubhagya' is a scheme launched by the Hon'ble Prime Minister on 25th September, 2017. Under Saubhagya free electricity connections to all households (both APL and poor families) in rural areas and poor families in urban areas will be provided. There are around 4 Crore un-electrified households in the country, and they are targeted for prnviding electricity connections by December 2018. Rural Electrification Corporation (REC) has been designated as nodal agency for the Saubhagya scheme. Under the Saubhagya scheme, DISCOMs will organize camps in villages/cluster of villages to facilitate on-the-spot filling up of application forms including release of electricity connections to households.

3.113 The scope of SAUBHAGYA scheme is:

• Providing last mile connectivity and electricity connections to all un­electrified households in rural areas. Providing Solar Photovoltaic (SPV) based standalone system for un­electrified households located in remote and inaccessible villages / habitations, where grid extension is not feasible or cost effective.

• Providing last mile connectivity and electricity connections to all remaining economically poor un-electrified households in urban areas. Non-poor urban housel1olds are excluded from this scheme.

3.114 In Uttarakhand, the Saubhagaya scheme was launched on 9th March 2018 by Chief Minister of Uttarakhand along with Union Minister of State in Dehradun. The scheme has been implemented completely by March 2019. The capex envisaged in FY 2019-20 is on account of balance payment to be made in FY 2019-20

3.115 During the FY 2020-21 no capital expenditure has been envisaged under this scheme

R-APDRP

3.116 Restructured Accelerated Power Development and Reforms Programme (R­APDRP) was launched with the objective of establishing reliable and automated systems for sustained loss reduction. For this, the scheme proposed sustained collection of accu1-ate baseline data and adoption of IT in the areas of energy accounting along with regular distribution strengthening projects.

3.117 The scheme covered urban areas - towns and cities with population of more than 10,000 (for special category States). Projects under the scheme were to be taken up in two parts.

3.118 Part-A was to include the projects for establishment of baseline data and IT applications for energy accounting/auditing and IT based consumer service centres such as consumer indexing, GIS mapping, metering of DTs & feeders, SCADA/DMS (only in the project area having more than 4 lacs population and annual input energy of the order of 350 MU) etc.

3.119 Part-B was for renovation, modernization and strengthening of 11 kV level substations, transformers, re-conducting of lines at 11kV level and below, load bifurcation etc.

3.120 The funding pattern of the scheme was envisaged as under:

a) Go! to provide 100% Loan for part A of the R-APDRP schemes which shall include projects for establishing Base Line data and IT applications for energy accounting/ auditing and IT based consumer services etc.

b) Go! to provide up to 90% (for special category States) Loan for Part B of the R-APDRP schemes which shall include regular distribution strengthening projects.

c) The entire loan from Gal was to be routed through PFC/REC (Fis) for the respective schemes funded by them.

d) The counterpart funding was to be done by PFC/REC (Fis) as per its prevailing policy.

3.121 Under R-APDRP Part-B, physical work is near completion. The financial closure of the scheme is under progress.

Other Works

3.122 The deployment of capital investment for other works are divided under the following broad heads:

a) Growth Development Plan to meet the load growth:

(i) Construction of New substations and augmentation of existing substations

(ii) Laying of LT lines

(iii) Installation of breakers (new)

(iv) Installation of CSS 990 l<VA where two transformers are installed at the same place

(v) Release of New PTW Connections

(vi) Installation of meters for giving new connections

b) Loss reduction

(i) Implementation of AMR (other than R-APDRP)

(ii) Laying of llkV & 33kV Covered conductor for forest area

(iii) Laying of lll<V ABC

(iv) Installation of Double metering in selected 11 KV & 33 l<V consumers

79

(v) Laying of LT ABC Cable in theft prone areas

(vi) Installation of prepaid meters

-----"-'"" ---

(vii) Replacement of defective single phase and three phase meters

(viii) Installation of 11kV & 33kV underground cables

c) System Reliability & Safety improvement

(i) Additional Transformers installation with associated 11 l(V

(ii) Installation of LT protection system on the transformers, fencing of transformers, installation of poles and guard wires1 reconductoring of lines, etc

(iii) Safety Measures

(iv) Smart Grid projects for industrial areas

(v) Implementation of ABT Meters

d} Creation of infrastructure facilities & other misc. Works:

(i) Procurement of Sub-station and consumer meter testing equipment.

(ii) Consumer care centres, E-payment of bills and Cash collection centres

(iii) New and emerging technologies and miscellaneous works like, new vehicles, office infrastructure, IT infrastructure, etc.

3.123 For improving the performance of UPCL in terms of meeting the load growth, ,-eduction of losses and reliability of supply, a detailed Capital Investment Plan has been worked out for the FY 2020-21. The summary of capex for FY 2019-20 and FY 2020-21 has already been provided in the table at the beginning of the section. The Capex Plan under other works proposes an investment of Rs_ 604.29 Crores. The deployment of Capex is proposed under the following four benefit centers:

a) Load growth~ 191.73 Crores b) Loss reduction ~ 239.07 Crores c) System reliability & safety improvement~ 137.35 Crores d) Creation of infrastructure facilities & other misc. works~ 36.14 Crores

3.124 For improving the performance of UPCL in terms of meeting the load growth, reduction of losses and reliability of supply, a Capital Investment Plan has been worked out for the FY 2020-21. The Capex Plan under other works proposes an investment of Rs. 604.29 Crores. The deployment of Capex is proposed under the following four benefit centers:

Capital Expenditure of load Growth

3.125 A year-on-year growth rate of around 4% has been considered for load growth by the Petitioner according to the sales projections. To achieve this anticipated load growth an investment of Rs. 191.73 Cr. has been proposed for FY 2020-21 as shown below:

----~-"------

Table 66: Capital Expenditure proposed for load growth during 3rd Control Period (Rs. C.-.J

Construction of New 100 80 180 Substation

Release of New PTW 33.00 36.30 69 Connections

Installation of meters for 16.50 21.78 38

giving new connections

1.60 1.21 3

Installation of new breakers --···---

CSS 990 kVA where two 16 transformers are installed at 7.43 8.17 the same place

Laytng of LT lines for new 40.25 44.27

85 connections

198.77 191.73 391

Sub-Total

3.126 The detailed scheme wise details along with material inputs are as follows:

Construction of 33/11 kV Substation

3.127 Construction of the · substations is essential for meeting the load growth. Currently, 16 substations as listed below are under various stages of execution.

Table 67: Substations constructed/under construction during FY 2018-19

1 Arya Nagar (Haridwar) 2xl0/2.60 734.16 604.43 100% 82.33%

2 Sector-5, SIDCUL

2xl0/4.00 810.33 621.20 100% 76.66 (Haridwar)

3 Chaka-Laser (Tehri

2X3/20 404.62 252.44 80% 63.39% Garhwal) -------

4 Maroda Saklana (Tehri

1X3/20 456.67 358.10 90% 78.42% Garhwal)

5 Gangapur (US __ Nagar) 2x5/4 412. 71 224.10 95% 54.30%

6 Arakot (Uttarkashi) 2x3/14 505.16 54.38 40% 10.76%

7 Sarnigad (Uttarkashi) 2x3/!.20 344.04 39.78 65% 11.56%

8 Sankari (Uttarkashi) 2x3/16 555.00 47.52 35% 8.56%

9 IP-2, SIDCUL(Haridwar) 2xl0/1 745.34 435.52 80% 58.43%

10 Si ka nda rpur( Ha r!_dw a r) 2xl0/6 840.51 325.37 50% 38. 71 %

11 Chauras (Tehri) 2x3/0.40 458.60

12 Khari 2x3 MVA/1

440.52 36.13 50% 8.20% Km.

13 Gular-Kaudiya!a 2x3 MVA/21

360.56 25% Km.

14 Askot 2x5 MVA/ 10

610.19 210.03 55% 34.42% l<m. LILO

15 Madrnanley 2x5MVA/3.l 426.80 114.05 96% 26.72%

l<m. LILO

16 Takula 2x5 MVA/ 374.12 40%

81

1"?-::

------ -------------

3.128 For future projections, various round of meetings were held with operations/ field staff and overloaded places we,·e identified for construction of new 33/11 kV substations.

3.129 The total cost of Rs. 180 Cr includes the cost of electrical works, the cost of incoming 33 l<V lines and outgoing 11 KV lines, the cost of land and the cost of switch house building as well as allied civil works. New Sub-stations are expected to be commissioned in FY 2020-21 at Kichha, Laltaro, Jagdishpur, Thalisain and Nanda ki Chowki. Escalation of costs has been assumed after analysis of escalation of cost in previous years.

3.130 The annual funding plan for construction of 33/11 l(V Substation is as per the following table:

Table 68: Annual Funding Plan for Construction of 33/11 lcV substation and lines

2019-20 Equity-State Govt. 30

Total 100.00

Debt 70 56.00

2020-21 Equity-State Govt. 30 24.00

Total 80.00

Release of PTW Connections

3.131 In order to aid the state's agriculture production as well as help in proper accounting of the energy used by the agriculture sector with reduction of unauthorized use of energy & over loading of the system.

3.132 The year wise detail of connections to be released and the projected expenditure to execute t11e same is as per the following table:

Table 69: Year wise details of PTW connections

I I-::. ::.. • •

2019-20

2020-21 1200 36.30

2021-22 1100 36.60

Total 3500 105.90

3.133 The annual funding pattern for undertaking capital expenditure under this head is as follows:

---·· ------- ------------

Table 70: Ar111ual funding plan for release of PTW connections

2019-20 Equity-State Govt. 30 9.90

Total 33.00 ~~~

Debt 70 25.41

2020-21 Equity-State Govt. 30 10.89

Total 36.30 ----~---~·

Installation of meters for giving new connections

3.134 The number of consumers of UPCL has increased from 18.90 lacs in FY 2014-15 to 24.27 lacs in FY 2018·19. This number is projected to increase to 25.81 lacs in FY 2019·20 and 27.45 lacs in FY 2020· 21.

3.135 Since the new connections cannot be given without meters and meters are the most integral part of the revenue cycle management function of the utility, UPCL proposes to install around 2.2 lacs single phase meters in the three-year period.

3.136 The year wise detail of the physical progress and expenditure projected to be incurred is as follows:

Table 71: Yeat· wise expenditure on installation of meters

2019·20 100000 16.50

2020·21 120000 21.78

Total 220000 38.28

Table 72: Annual Funding Plan for installation of meters

2019·20 Equity-State Govt. 30 4.95 -~~

Total 16.50

Debt 70 15.25

2020·21 Equity-State Govt. 30 6.53 ~~---Total 21.78

Installation of New Breaker·s

3.137 The Petitioner proposes to install around 35 33kV new breakers for additional feeders or where breaker is not available & around 35 11kV new breakers in FY 2019·20 (RE) and FY 2020-21.

3.138 The year wise detail of the quantity and expenditure projected to be incurred is as follows:

83

Table 73: Vear wise expenditure on it1stallation of new breakers

2019-20 25 20 f---------+---·--·-----·------

2020-21 10 15 c---------j----·--·----t---·--------+-

Total 35 35

Table 74: Annual Funding Plan for installation of new breakers

2019-20 Equity-State Govt. 30

Total

Debt 70 --·--

2020-21 Equity-State Govt. 30 Total

CSS 990kVA where two transformers are installed at the same place

1.60

1.21

0.48

1.60

0.85

0.36

1.21

3.139 The Petitioner proposes to install around 20 CSS in FY 2019-20 as per revised estimates and 20 CSS in FY 2020-21 where two transformers are installed at the same place. The additional expenditure on account of these works is given in the table below:

Table 75: Year wise expenditure on installation of CSS 990 !<VA

2019-20 20 7.43

2020-21 20 8.17

Total 40 15.60

Table 76: Annual Funding Plan for installation of CSS 990 kVA

2019-20 Equity-State Govt. 30 2.23

Total 7.43 -+------- --T-------·--Debt 70 5.72

-------·---+----------2020-21 Equity-State Govt. 30 2.45

8.17

Laying of LT Lines for new connections

3.140 The Petitioner proposes to lay down new lll<V and LT lines for new connections. Based on the number of new connections, the Petitioner has estimated the requirement of laying down lll<V and LT line for the FY 19-20 (RE) and FY 2020-21. The additional expenditure on account of these works is given in the table below:

------- ------·---

Table 77: Year wise Gxpenditure 011 laying down LT Lines for new connections

2019·20 154 308 40.25 f--------+------------+----·------+-·

2020·21 154 308 44.27

Total 308 624 84.52

3.141 The annual funding pattern for capital expenditure under this head is as follows:

Table 78: Annual Funding Plan for Laying down LT Lines for new connections

2019·20 Equity-State Govt. 30 12.07

Total 40.25

Debt 70 30.99

2020·21 Equity-State Govt. 30 13.28

Total 44.27

Capital Expenditure of Loss Reduction

3.142 The Petitioner has reduced its distribution losses significantly in the last 3 years with 16.68% in FY 2016·17 and 15.17% in FY 2017·18 respectively to 14.32% in FY 2018·19. For FY 2019·20 and FY 2020·21, the Petitioner has proposed aggressive loss reduction targets in line with the Commission. In order to realise this, the Petitioner shall be required to undertake capital expenditure of Rs. 239.07 Cr. spread over various FY 2020·21 as shown below:

Table 79: Capital Expenditure proposed for loss reduction (Rs. Cr.)

Implementation of AMR (Other than R·APDRP)

Laying of 1 lkV & 33kV Covered conductor for forest area

Laying of LT ABC Cable in the~ prone areas

Replacement of defective single phase and three phase meters

Pre-paid meters

Installation of llkV & 33kV underground cables

Sub-Total

6.05

9.01

126.00 172.43

17.99 15.16

4.46 6.20

42.00 36.27

196.50 239.07

3.143 The detailed scheme wise details along with material inputs are as follows:

Implementation of AMR

6.05

9.01

298.43

33.15

10.66

78.27

435.57

3.144 With the advent of IT based applications for billing of consumers, one of the technologies that has shown quick results and improved efficiencies is the Automated Meter Reading technology.

85

---------------------------------------------~'

('-~

3.145 The meter reading of the consumers is automatically transmitted to the servers located in the head office of the utility through a modem and a sim card. This removes the necessity of meter readers thus not only saving the utility in man power costs but more importantly it results in very accurate meter reading and therefore higher collections and realizations. AMR technology also reduces chances of theft of electricity and collusion of meter readers with consumers. It also has built in a!ert features to communicate immediately a case of tampering and facilitate detailed analysis of consumption and load pattern.

Benefits of Automated Meter Reading (AMR)

a) Increased Data Security: Automatic meter reading provides increased performance in the data collection. It also helps in avoiding reading errors and missing meter readings. It also keeps offs from manual data entry because of which a potential source of error is eliminated.

b) Reduced cost over the lifetime of the AMR: The financial benefits of automatic meter reading last over the lifetime of the AMR system.

c) Improved cash flow budgeting and management: In AMR, the billing is on real­time basis and is based on actual consumption. Therefore, estimated bills are no longer necessary. There shall also be a potential for enhanced revenue as inaccurate meters shall be replaced.

d) Improved customer service: with accurate data available on real time basis, there is no need for estimates and adjusted billing. The monitoring of demand and consumption can be done closely.

e) Detection of thefts: There is an ability to detect tamper events and outage occurrences.

f) Remote monitoring: With AMR, there is a provision of remotely connect or disconnect power supply through meter. Also, monitoring of voltage at each premise to know conditions when to operate capacitor switches or regulators.

g) Reduced operational cost: this saves the utility providers the expense of periodic trips to each physical location to read meter thereby reducing the operational cost.

3.146 UPCL is implementing AMR in a phased manner to cover all its high value consumers. The project cost for installing 10000 meters in FY 2019-20 has been estimated as Rs 6.05 Cr as per revised estimates (including the cost of hardware and software).

3.147 It has been calculated that after the installation of meters, the unrecorded consumption would be accounted for, due to which there shall be at least 1 % increase in sales and hence the revenue. The payback period for installing such automated meters has been estirnated as 2 years & 5 month~. i.e. the entire cost of project shall be recovered in 2 years & 5 months by additional revenue that the Discom shall earn by installing the meters.

3.148 The physical progress and capital expenditure to be incurred under this scheme during the current business plan period is given in the following table:

86

l

---- --·---- -------- ------- ----~-----·--

Table 80: Year Wise Expenditure for installation of AMR meters

+·Hiilil!illi 6.os I 2019-20

3.149 The annual funding pattern for capital expenditure under this head is as follows:

Table 81: Annual Funding Plan for installation of AMR Meters

2019-20 Equity-State Govt. 30 1.82

Total 7.62 ~~---~ --~----------

Laying of LT ABCable

3.150 Laying of LT ABC in theft prone areas prevents hooking of the network by the consumers resulting into reduction in theft. It also helps in decreasing the techn'ical losses and breakdowns; therefore, this activity reduces losses and improves quality and reliability of supply.

3.151 UPCL has identified the high theft areas and proposes to lay around 2500 km of LT ABC fo1· the control period FY19-20 and FY 2020-21 respectively to reduce theft.

3.152 The year wise detail of the physical progress and expenditure projected to be incurred is as follows:

Yab!e 82: Year wise expenditure on laying of LT ABC

Total 298.43

3.153 The annual funding pattern for capital expenditure under this head is as follows:

Table 83: Annual Funding Plan for Laying of LT ABC

2019-20 Equity-State Govt. 30 37.80

Total 126.00

Debt 70 120. 70 ----- -----

2020-21 Equity-State Govt. 30 51.73 ---

Total 172.43

87

I~

Replacement of Defective meters

3.154 Replacement of defective meters is required in 01·de1· to avoid average estimation of energy consumption which leads to inaccurate realisation and also hides inefficiencies and cases of theft. Electronic meters can record several parameters thus enabling the utility and its consumers to be more aware of the consumption patterns and enable greater flexibility and accuracy in billing. Therefore, ,·eplacement of defective meters with new electronic meters will help in accu,·ate energy recording and accounting and reduction in losses.

3.155 UPCL proposes to replace around 75000 single phase meters and 5000 three phase meters in the.FY 2020-21.

3.156 The revised estimate for FY 2019·20 and FY 2020·21 of the expenditure projected to be incurred is as follows:

Table 84: Year Wise Expenditure on replacement of defective r11eters

2020·21 75000 nos. 5000 nos. 15.16

Total 33.15 ---·---- --~ -----·-----

Table 85: Annual Funding Plan fm· replacement of defective meters

2019·20 Equity-State Govt. 30 5.40

Total 17.99

Debt 70 10.61

2020·21 Equity-State Govt. 30 4.55

Total 15.16

Installation of Pre-paid Meters

3.157 UPCL proposes to install around 2000 three phase and 10000 single phase pre­paid meters in FY 2020·21. The revised estimate for FY 2019-20 and detail of the expenditure projected in FY 2020·21 to be incurred on pre-paid meters along with in-home display unit (keypad) suitable for prepayment meters is as follows:

Table 86: Year wise expenditure on replacement with Pre-paid rneters

2019·20 1000 9000

2020·21 2000 10000 6.20

Total 3000 19000 ~=~---~--------~--------~ 10.66

---------~--

3.158 The annual funding pattern for capital expenditure under this head is as follows:

C 8s r·I

----------------·-----··-------·-··----------,-,------+ .. -··--

---------------------------------

Table 87: Annual Funding Plan for Replacement with Pre-paid meters

2019-20 Equity-State Govt. 1.34 1.34

Total 4.46 1---- ------t---------~-~---·-·----------t--------~~

Debt 4.34 4.34

2020-21 Equity-State Govt 1.86 1.86

Total 6.20

Laying of lll<V and 33i<v conductor in the Forest Area

3.159 UPCL had planned to lay the 11 kV and 33kV conductor in the forest areas of around 25 kms. during the control period FY19-20-FY21-22 for which the total cost in FY 2020-21 will be Rs. 9.01 Cr.

3.160 The detailed year wise expenditure has been shown in the table below:

Table 88: Annual Expenditure Details

0HW@IUM ;i,,Mil,lli:ffii 2020-21 so

Total

Table 89: Annual Finding Plan for Laying of 11 kV and 33kV conductor in Forest Area

2019-20 Equity-State Govt.

Total

Debt 70 6.30

2020-21 Equity-State Govt. 30 2.70

Total 9.01 -------------------~------·------~

Laying of 11i<V and 33 l<V Underground Cables

3.161 UPCL has planned to spend on 150 km of 11 kV underground cabling during the control period. The Petitioner proposes to lay 50 km of 11 kV and 25 km of 33 kV underground cabling in FY 2020-21. The estimated cost of laying the cable is as described below:

Table 90: Annual Expenditure Details

Total 78.27

89

Table 91: Annual Financing Plan for Laying of l.1 kV and 33 kV UG c.-1bles

Debt 70 29.20

2019·20 Equity-State Govt. 30 12.60

Total 42.00

25.39 Debt 70

2020·21 Equity-State Govt. 30 10.88

Total 36.27 ---····--~-----~ -----

Capital Expendit"ure for System Reliability & Safety Improvement

3.162 During FY 2020·21, UPCL proposes to further strengthen the network, introduce new technologies to enhance customer satisfaction in terms of safe and reliable supply of electricity. To achieve this an investment as shown below l1as been proposed under the following works:

Table 92: Capital Expenditure proposed for system reliability & safety improvement (Rs. Cr.)

Additional Transformers 88.77 163.77 installation with associated 75.00 llkV & LT lines

LT Protection System on 15.00 34.01 49.01

Transformer 8.70 9.57 18.27

Safety measures

Smart Grid projects for industrial 0.00 5.00 5.00

areas 98.70 137.35 236.05

Sub-Total

Installation of additional distribution transformers

3.163 Installation of additional transformer becomes necessary to avoid overloading of DTs due to load growth. Overloaded transformers also increase technical losses and breakdowns and therefore, investment for installation of new transformers reduces losses and improves quality and reliability of supply.

3.164 UPCL projects to install around 5100 nos. of additional transformers during FY19· 20·FY21·22 with varying capacities to further increase the reliability and quality of supply of its consumers.

3.165 The year wise detail of the expenditure projected on additional transformers along with associated 1 lkV and LT lines to be incurred is as follows:

Table 93: Year wise Expenditure on installation of additional transfonners

---=--=---·--"--_ .. ____ l_.7_0_0 ____ J ;\ll••:i"~;1 /~ 90

//

--- ----a·-------- ------- -------

·ii,1·111,iii,MHI 163.771

3.166 The capacity wise detail of the additional transformers projected to be incurred is as follows:

Table 94: Capacity wise detail on installation of additional transformers

3.167 The annual funding pattern for capital expenditure under this head is as follows:

Table 95: Annual Funding Plan for Installation of Additional Transformers

Debt 70

2019-20 Equity-State Govt. 30

Total

Debt 70

2020-21 Equity-State Govt. 30

Total

Safety & Protection related - Installation of LT protection system on the transformers and fencing of transformers

52.50

17.50

75.00

62.14

26.63

88.77

3.168 Protection systems on transformers are necessary for reducing the damage rate of transformers and increasing the reliability of supply. The Petitioner proposes to install up to 100 kVA transformers with LT fuse set and TPMO and above 100 kVA transformers with ACB and earth fault relay. In addition, UPCL proposes to construct fencing around the transformers to increase the safety.

3.169 The year wise detail of the physical progress and expenditure projected to be incurred is as follows:

Table 96: Year wise expenditure on installation of protection system

Total

3.170 The annual funding pattern for capital expenditure under this head is as follows:

91

Table 97: /.\nnual Funding P!ar1 for installation of protection system

2019-20 Equity-State Govt. 30

Total ------~ Debt 70

2020-21 Equity-State Govt. 30

Total ---------.. ··-·-··

Safety & Protection related - Installation of poles and guard wires, reconductoring of lines, etc.

4.50

15.00

23.80

10.20

34.01

3.171 UPCL proposes to replace old low length poles with high length poles, reconductoring and strengthening of LT/11 kV lines, installation of guard wires at crossings and over residential buildings, etc. to increase safety of the consumers and reduce breakdowns. In addition, the Petitioner proposes to undertake earthing of 33/11 kV and 11/0.5 kV substations during FY 2019-20 (RE) and FY 2020-21.

3.172 The yea,· wise detail of expenditure projected to be incurred is as follows:

Table 98: Vear wise expenditure on fnstaHation of po!es and guard wires, reconductoring of lines, etc. (Rs. Cr.)

18.27

3.173 The annual funding pattern for capital expenditure under this head is as follows:

Table 99: Annual Funding Plan for Installation of poles, guard wires, 1·econductodng of lines, etc. (Rs. Cr.)

Debt 70 6.09

2019-20 Equity-State Govt. 30 2.61

Total 8.70

Debt 70 6.70

2020-21 Equity-State Govt. 30 2.87

Total 9.57

----·-----

Capital Expenditure for Creation of .Infrastructure Facilities & Other Miscellaneous Works

3.174 During the 3rd Control Period FY19·20 to FY21·22, UPCL proposed to create state-of-the-art infrastructure, renovation, capacity augmentation and modernization of workshops etc. for ensuring backend infrastructure to meet its targets. To achieve this, a revised estimate of Rs. 36.14 Crores has been proposed for FY 2020-21 under the following works:

Table 100: Capital Expenditure proposed for creation of infrastructure facilities and other miscellaneous works (Rs. Cr.)

Procurement of Sub-station and high value consumer meter testing and dia nostics e ui ment Consumer care centers, E-payrnent of bills and Cash

Non-R ·APDR P IT Ex enses R&M/Capacfty Augmentation of Worksho s Other misc. works

Sub-Total

5.00 18.70

1.19 1.19

2.80 9.88

4.00 4.00

2.37 2.37

15.36 36.14

Procurement of Sub-station and consumer meter testing equipment

23.70

2.38

0.00

12.68

8.00

4.74

51.50

3.175 Testing the meters and verifying its accuracy and checking for any abnorn,alities is very important for any Utility. UPCL is planning to introduce the system for checking and testing of substation and consumer meters on site. This will help in easier resolution of consumer grievance related to meter accuracy, proper energy accounting, and reduction in theft and increase in revenues.

3.176 This will include 4-meter testing vans with all required testing equipment. Also, hand held meter testing instruments will also be purchased to check the accuracy of the consumer meters on site. This will help in faster resolution of consumer complaints regarding fast or inaccurate meters and also help in theft detection.

3.177 UPCL proposes to invite competitive bids for procurement of this system and according to the initial discussions with the vendors cost of Rs. 18.70 Cr. is projected during FY 2020·21

3.178 The year wise physical progress and capital expenditure projected for execution of this scheme is summarized as under:

Table lOi: Year wise expenditure for installation of meter testing equipment (Rs. Cr.)

2019·20 5.00

2020·21 18.70

Total 23.70

3.179 The annual funding pattern for capital expenditure under this head is as follows:

93

--- ------··------"------------------------------ -------

Table 102: Annual funding plan for installation of meter testing equipment (Rs. Cr.)

2019-20

2020-21

Debt

Equity-State Govt.

Total

Debt

Equity-State Govt.

Total

70 3.50

30 1.50

-------------t--5.00

70 13.09

30 5.61

18.70 --~----------

Consumer care centres, E-payment of bills and Cash collection centres

3.180 UPCL is planning to improve its collection efficiency by increasing the number of cash collection centres, introducing online bill payment options, increase consumer care centres, etc. This will also lead to increase in consumer satisfaction also.

3.181 UPCL proposes to invite competitive bids for procurement of this system and according to the initial discussions with the vendors, cost of Rs. 1.19 Cr is projected during in FY 2020-21.

3.182 The year wise physical progress and capital expenditure projected for execution of this scheme is summarized as under:

Table 103: Year wise expenditure for instalfation of Consmner care centrns, !'::·,payment of bills and Cash collection centres

2019-20

2020-21

Total

1.19

1.19

2.38

3.183 The annual funding pattern for capital expenditure under this head is as follows:

Table 104: Annual funding plan for installation of Consumer care centres, lt:-payrnent of bills and Cash collection centres

Debt 70 0.83

2019-20 Equity-State Govt. 30 0.36

Total 1.19

Debt 70 0.83

2020-21 Equity-State Govt. 30 0.36

f---------------~-----------1---------Total

Other Miscellaneous Works modernization of workshops

1.19

Renovation, Capacity Augmentation and

,,0, 94 I //

// ---------···---

3.184 The Workshops undertake the task of repair of transformers, allocation of the core and tank of the transformers to the repairer firms and disposal of the uneconomical transformers through cut and crush. Presently, the workshops cater to DTs from 16kVA to 630 kVA only.

3.185 The renovation, capacity augmentation and modernization of the workshops shall not only increase the productivity in terms of the DTs but also help in establishing state-of-the-art facility for overhaul of the power transformers.

3.186 The salient features of the capital expenditure proposed are as follows:

a) Establishment of New Workshop at Kirtinagar in the premises of 33/11 kV substation which shall help in timely disposal of the damaged transformers which otherwise are brought to the Workshop at Rishikesh and Dehradun. This shall not only save time cost incurred in carriage of these transformers but shall also help relieve the workshops at Rishikesh and Dehradun which too face severe space constraints.

b) Renovation and capacity augmentation of Electricity Workshop in Rishikesh which has a limited capacity due to non-availability of sufficient space. The civil renovation work along with the installation of new tools and plants shall help cater the demand of repaired transformers in the vicinity and also from the hills.

c) Renovation and capacity augmentation of Electricity Workshop, Roorkee which is the largest in the region. The repair of the overhead crane and its capacity augmentation to 25 tonnes has already been initiated in FY 2018-19.

d) Renovation and capacity augmentation of Electricity Workshop, Dehradun which receives damaged transformers from the Garhwal Hills and Dehradun district. The existing infrastructure needs to be upgraded along with establishment of new facilities like heating oven, overhead crane, testing equipment etc. for improving productivity.

e) On similar lines, renovation and expansion of civil ·infrastructure needs to be undertaken in Electricity Workshops at Haldwani, Kashipur and Rudrapur

3.187 A summary of the expenditure under renovation, capacity augmentation and modernization of workshops is given in the table below:

Table 105: Capital Expenditure for renovation, capacity augmentation and modernization of workshops

1

a

b

Establishment of New Workshop at Kirtinagar in the remises of 33/11 KV substation

Development of Land, Road and all the related Infrastructure like Scrap Stores, material stores, Testing room Office etc. Establishment of all the facilities for Repair of Transformers­Testing Equipment, Tools and Plants like power operated overhead Cra~1e, Heating Oven, Windin Machine etc.

50.00

50.00

95

2

a

b

3

a

b

4

a b

C

d

e) 5

a)

b)

c)

d)

e)

f)

6

a) b)

c)

d)

e)

Renovation and capacity augmentation at Electricity Worksho , Rishikesh

Renovation and ex ansion of Civil Infrastructure

Establishment of all the facilities for augmenting Repair of Transformers like Testing Equipment1 Tools and Plants like

ower operated overhead Crane1 Heatin Ovens etc. Renovation and capacity augmentation at Electricity Worksho , Roorkee

Renovation and expansion of Civil Infrastructure

Procurement of a new 2 Tonnes capacity power operated overhead Crane Renovation and capacity augmentation at Electricity Worksho , Dehradun (i)Renovatlon of the roof and floor and expansion of Civil Infrastructure including construction of new testing room. (ii)Renovation of floor, roof, plastering, painting, electricity wiring etc. of the old store handed over to Workshop, Dehradun including construction of Store for scrap and new material, testin room etc.

Procurement of a new heatin oven Construction of 2 no's oil storage tanks with a capacity of 15 Kl each for storage of old and used /fresh transformer oils.

Procurement of Testlng equipment and other tools like Transformer Test Bench, ratio meters etc. Procurement of a new power operated overhead Crane for the old store handed over to Worksho Electricity workshop, Haldwani

Renovation and expansion of civil infrastructure

Multi meter with case

Motorised Transformer Oil Testing Set (0-60 KV) complete

Welding Set

Winding machine No. LT with installation and commissioning, Windin machine No. H.T. with installation and commissioning

I\Jew Heating Oven

Electricity workshop, J<ashipur

Renovation and expansion of civil infrastructure Allen Key Set 1S! Mark 02 nos. Tray made of MS Sheet 24 SWG of size lmter x O. 2 mtr. X 0.15 mtr. 2 nos. Cutting Pliers 8"and 2 nos Nose Pilers 6"

Chain Tackle 3 Ton Best Quality, Chain Tackle 5 Ton Best ua!it

f) 2 nos. High Insulation Rubber mat of size 2 mtr. X 1 mtr. X 3mm

g) Crimping Too! Manually 25 mm to 400 mm

h) Paper Cutting Machine Hand operated Up 40" Long

i) Trolly made of MS Sheet with Wheel for T/F size 1 mtr.x3mtr./H draulic Hand al!et truck u to 2 Ton

j) Turn ratio meter (Analog Type),Multipul Spanner set

k) 1HP Monoblock Pump and SHP Tube well pump 1-~--+

I) Motorised Transformer Oil Testing Set (0-60 KV) complete

7 Electricity worl<shopr Rudrapur

35.00

35.00

30.00

8.00

50.00

13.00

5.00

20.00

20.00

14.00

10.00

25.00

6.00

a)

b)

c)

d)

e)

f)

g)

h)

i)

i)

8

Renovation and expansion of civil infrastructure Allen Key Set 151 Ma1·k

02 nos.Tray made of MS Sheet 24 SWG of size imter x 0.2 mtr. X 0.15 mtr. 2 nos. Cutting Pliers 8"and 2 nos Nose Pliers 6"

Chain Tackle 3 Ton Best Quality, Chain Tackle 5 Ton Best Quality 2 nos.High Insulation Rubber mat of size 2 mtr. X 1 mtr. X

3mm Crimping Too\ Manually 25 mm to 400 mm

Paper Cutting Machine Hand operated Up 40" Long

Trol!y made of MS Sheet with Wheel for T/F size 1 mtr.x3mtr./H draulic Hand allet truck u to 2 Ton Turn ratio meter (Analog Type),Mu\tipul Spanner set

Grand Total

20.00

7.00

400.00

Other Miscellaneous Works - Non-R-APDRP Part A (IT Expenses) funded through internal resources

3.188 As mentioned earlier, the Petitioner is undertaking certain capital expenditure funded through internal resources for the maintaining the IT backbone of the utility and implementing new initiatives such as setting up video conferencing facility, upkeep of DC & DR hardware including implementation cost etc. The details of capital expenditure being proposed as below:

Table 106: Year wise expenditw·e on non-RAPDRP IT expenses

DC & DR IT Hardware renewal 8.40

Red Hat and other soltware 1.20 1.32

licenses

Video Conferendng Setup 1.60 0.16

Total 2.80 9.88

3.189 For this, the Petitioner has proposed the following funding plan:

2019-20

2020-21

['able 107: Annual Funding Pattern on non-RAPDRP IT expenses

Debt

Equity-State Govt.

Total

Debt

Equity-State Govt.

70

30 ----

70

30

1.96

0.84

2.80

6.92

2.96

97

I"/

Other miscellaneous works like, new vehicles, office infrastructure, IT infrastructure, etc.

3.190 UPCL is a!so planning to procure new vehicles, increase office infrastructure, etc. the Petitioner has proposed a nominal capital expenditure of Rs. 2.37 Cr for FY 2020-21.

3.191 The year wise physical progress and capital expenditure projected for execution of this scheme is summarized as under:

Table 108: Year wise expenditure on miscellaneous works

2019-20 2.37 2020-21 2.37

Total 4.74

3.192 The annual funding pattern for capital expenditure under this head is as follows:

Table 109: Annual Funding Pattern on miscellaneous works

2019-20 Equity-State Govt. 30 0.71 Total 2.37 Debt 70 1.66

2020-21 Equity-State Govt. 30 0. 71 Total 2.37

Proposed Capital expenditure and Capitalization

3.193 Based on the capital expenditure discussed for various schemes in the above paras, the proposed total capital expenditure for FY 2019-20 (RE) and FY 2020-21 works out to out to Rs 1158.79 Cr and Rs 745.36 Cr respectively.

3.194 The Petitioner has estimated that the new expenditure incurred towards central schemes as discussed above in FY 2019-20 will be capitalized in the ratio of 60:40 in FY 2019-20 and FY 2020-21 respectively in line with the Commission's approach followed by the Petitioner in previous petition

3.195 The balance capital expenditu,·e of non-central schemes is split into 40%, 40% and 20% in the subsequent years. Additionally, the opening CWIP at the beginning of FY 2019-20 has been estimated to be capitalised in the ratio similar to non- central schemes

3.196 The summary of proposed capital expenditure and the capitalization for the respective years is detailed in the table below:

--- ------ ·---

Table 110: Proposed Capital Expenditure and Capitalisation for 3rd Control Pe1·iod (Rs. c,·.)

FY 2019-20 1158. 79 937.06

FY 2020-21 745.36 977.22

Total 1904.15 1914.28

3.197 The means of finance (debt, equity and grant) for the total capitalization proposed for FY 2019-20 and FY 2020-21 is detailed in the table below:

FY 2019-20

FY 2020-21

Total

Table 111: Source of funding for Capitalisation (Rs. Cr.)

937.06 505.46 302.12

977.22 327.21 455.00

1914.28 832.67 757.12

129.48

195.00

324.48

Gross Fixed Assets (GFA) and Capital works in Progress (CWIP)

3.198 The GFA has been projected based on the capital expenditure and capitalisation proposed above. Opening GFA for FY 2019-20 has been arrived based on the opening GFA and actual capitalization for FY 2018-19 as detailed in previous Chapter- for true-up of FY 2018-19. The opening CWIP of FY 2019-20 has been taken equivalent to the closing CWIP as per the audited accounts of FY 2018-19.

3.199 The capital expenditure and capitalization for FY 2019-20 and FY 2020-21 has been considered as per discussed above in the previous section. Accordingly, the opening and closing GFA for FY 2019-20 and FY 2020-21 have been computed as summarized in the table below:

Table 112: Proposed Gf-A and CWIP (Rs. Cr.)

A Opening GFA 5554.15 6491.21

B Opening CWIP 663. 75 885.48 ----C Total Capex 1158. 79 745.36

D Capitalization 937.06 977.22

E Closing GFA (E=A+D) 6491.21 7468.43

F CWIP at the end of

885.48 653.62 the ear F=B+C-D)

Interest on Loan Capital

3.200 For computing the interest on capital loan for the FY 2020-21, the Petitioner has considered the revised closing balance of FY 2018-19 based on addition in FY 2018-19 as detailed out in Chapter 2 - True-up of FY 2018-19. Further, the closing balance of FY 2018-19 has been considered as opening for FY 2019-20. Subsequently, the proposed capitalisation of FY 2019-20 is added to arrive upon closing balance of FY 2019-20 which becomes the opening balance for FY 2020-21

99

3.201 Further, new loans for FY 2019-20 and FY 2020-21 has been considered as per the means of funding of capitalization detailed in the previous section while the repayment has been considered equivalent to the depreciation for FY 2019-20 and for FY 2020-21 in line with the UERC Tariff Regulations, 2018. Interest on Loan has been considered at rate of interest of 11°/0 1 similar to actuals incurred in FY 2018-19 and in line with the existing arrangement of loans with REC and PFC and other financial institutions. Loan-wise details has also been furnished in distribution formats submitted along with this Petition.

3.202 The proposed interest cost on capital loans for FY 2019-20 and FY 2020-21 has been computed as per the details provided in table below:

Table 113: Interest of Normative Loan Balance and additions (Rs. Cr.)

' ' Opening Normative Loan balance 868.17 997.16

Additions 302.12 455.00

Repayment 173.12 201. 30

Closing Nonnative Loan Balance 997.16 1250.86

Average Normative Loan 932.66 1124.01 I

Rate of interest(%) 11% 11%

Interest on Loan 102.59 123.64

3.203 In addition, the Petitioner has considered interest against REC (Old Loans) during each year of the Control Period as per the repayment schedule laid down in Tariff Order for FY 2009-10 dated 23rd October 2009 and as shown in the table below.

Table 1.14: Approved Repayment Schedule for REC Old Loans (Rs. Cr.)

3.204 The Petitioner has also considered Rs. 3.52 Cr. for FY 2019-20 and FY 2020-21 against financial expenses towards other financial and bank charges which is in line with the actual amount paid in FY 2018-19. The Petitioner has also claimed Guarantee fee of Rs 3.04 Cr. in each year which is equivalent to the guarantee fee as per the audited accounts for FY 2018-19.

3.205 The Petitioner has not included any interest on GPF loan in the interest claimed for FY 2018-19 and similar approach has been adopted for FY 2019-20 and FY 2020-21.

3.206 The total claim for interest expense for FY 2019-20 and FY 2020-21 is as provided in the table below:

table 115: Interest of Normative Loan Balance and Additions (Rs. Cr.}

Interest on Capital Loans 102.23

Other Financial and Bank charges 3.52 3.52

Guarantee Fee -------------+-3.04 3.04

----1----

I n t ere st on REC Old loans 11.49 11.49 '-'--'----'---'------~'------'-------'---

t--9,, 100

/ --~.;;-

il®M%if Total Interest

tlHhE·~#f#ifHf¥~ I 120.64 141.69

Interest on Consumer Security Deposit (CSD)

3.207 Addition in consumer security for FY 2019· 20 and FY 2020·21 has been projected based on the increase in number of employees projected and the average amount of consumer deposit per consumer added in FY 2018·19

3.208 Interest on CSD has been determined at the weighted average rate of interest calculated for FY 2018-19 as per audited annual accounts

3.209 The proposed interest on consumer security deposit for FY 2019·20 and FY 2020· 21 is as detailed in table below:

Table 116: Projected Consumer Security Deposit (Rs. Cr.)

Addition ________ ·+---

Closing

Average CSD

Interest Rate %

Inte,·est on CSD

Return on Equity (RoE)

901. 97

871.54

5.75%

50.13

966. 70

934.33

5.75%

53.74

3.210 As per Regulation 26(2) of UERC Tariff Regulations, 2018, Return on equity is to be calculated on post tax basis at 16.50% as mentioned below:

"(2) Return on equity shall be computed on at the base rate of 15.5% for thermal generating stations, transmission licensee, SLDC and run of the river hydro generating station and at the base rate of 16.50% for the storage type hydro generating stations and run of river generating station with pondage and distribution licensee on a post-tax basis.''

3.211 Accordingly, the Petitioner has computed RoE at 16.50% on opening equity for FY 2019-20 and FY 2020·21.

3.212 The opening equity for FY 2019-20 has been arrived based on the closing equity for FY 2018-19 as per the revised calculation of equity as shown in the true up section (Chapter 2) for FY 2018-19. The addition in equity each year during FY 2019-20 and FY 2020·21 is based on the proposed funding of capitalization as per the details provided in the previous section of capital expenditure and capitalization.

3.213 The table below details the computation of return on equity for FY 2019-20 and FY 2020-21:

Table 117: Projected Return on Equity (Rs. Cr)

101

- --- ------- ---- ---------------- ------·-- ,,,_

Closing Equity 831.29 1026.29 Average Equity 766.55 928.79 Rate of Return(%) 16.50% 16.50% Return on equity 126.48 153.25

Operation and Maintenance expenses

3.214 According to UERC (Terms and Conditions of Multi Year Tariff) Regulations, 2018, O&M ('Operation & Maintenance') expenses for the nth year shall comprise of the following components, namely

e) R&M,,: Repairs and maintenance expenses

f) EMP,,: Salaries, wages, pension contribution and other employee costs

g) A&G,,: Administrative and general expenses including insurance charges if any

wherein, O&M,, = R&Mn + EMP,, + A&G,,

3.215 Clause 84 (3) of the UERC (Terms and Conditions of Multi Year Tariff) Regulations, 2018 specifies the method for calculation of above components for the nth year as follows:

"EMP,, = (EMPn-1) x (1 +G,,) x (1 +CPiinflaUon)

R&M,, = K x (GFAn-1) x (1 +WPiinflation) and

A&Gn = (A&Gn-1) x (1 +WPiinflation) + Provision

Where -

• EMPn-1 - Employee Costs for the (n-1)th year;

•A&Gn-1 - Administrative and General Costs for the (n-1)th year;

Provision: Cost for initiatives or other one-time expenses as proposed by the Distribution Licensee and validated by the Commission.

, 'K' is a constant specified by the Commission in %. Value of K for each year of

the control period shall be determined by the Commission in the MYT Tariff order based on licensee's filing, benchmarl<ing of repair and maintenance expenses,, approved repair and maintenance expenses vis-ii-vis GFA

approved by the Commission in past and any other factor considered appropriate by the Commission;

, CPiinflation - is the average increase in the Consumer Price Index (CPI) for

immediately preceding three years;

• WPiinflation - is the average increase in the Wholesale Price Index (CPI) for immediately preceding three years;

, GFA,,-1 - Gross Fixed Asset of the distribution licensee for then-1th year;

• Gn is a growth factor for the nth year and it can be greater than or less than

zero based on actual performance. Value of Gn shall be determined by the Commission in the MYT tariff order for meeting the additional manpower require,nent based on licensee's filings, benchmarking, and any other factor that the Commission feels appropriate:

----- ,-------------------- ------ ---- ______________ ,, ____ _

Provided that repair and maintenance expenses determined shall be utilised towards repair and maintenance works only, 11

Manpower Plan

3.216 Electricity distribution business has been a manpower intensive in view of the several activities including upkeep of wires and substations, metering, billing and collection, etc. Technically trained manpower comprising of skilled linemans, engineers, supervisors 1 and managers etc. is required in every area of the distribution sector. Therefore, the challenges with respect to manpower planning are many fold. Some of these challenges include lack of adequate and skilled manpower 1 difficulties associated with recruitment process, impact on consumer tarlff, etc.

3.217 UPCL has a total of 2750 regular employees (as on 30-09-2019). The Petitioner realises that rapid growth in power sector and energy sales in Uttarakhand requires additional capacity building. Despite an increase in consumer base and overall operations of the Petitioner in the past years, it is submitted that the overall manpower has declined leading to difficulties in operations. Owing to shortage in staff in the recent years, UPCL has recruited personnel from the Uttarakhand Purv Sainik Kalyan Limited (UPNL) on a contractual basis to fill a major portion of the vacant posts which are within the total number of sanctioned posts. The details of the recruitment and retirements during the period have been provided in the formats

3.218 Based on the above manpower plan, the summary of proposed recruitment and retirement along with opening and closing employees in the FY 2019-20 and FY 2020-21 has been provided in the table below:

Table 1.18: Net Employee Addition and Growth Factor

Opening number of employees

Add: Recruitment

Less: Retirement

Closing number of employees

Growth Factor

Projection of Employee Costs

2779 2750

70 1019

99 135

2750 3634

0% 33%

3.219 As specified in Clause 84 (3) of Uttarakhand Electricity Regulatory Commission (Terms and Conditions for· Multi Year Tariff Tariff) Regulations, 2018, employee costs for the nth year and also for the year preceding the Control Period will be calculated as per the method given below.

EMP, = (EMP,-1) X (l+G,) X (l+CPiinflation) "Where - EMPn-1c Employee Costs for the (n-l)th year; CPI inflation: is the average increase in the Consumer Price Index (CPI) for immediately preceding three yearsi Gn is a growth factor for the nth yearand it can be greater than or less than zero based on the actual performance. Value of Gn shall be determined by the Commission in the MYT tariff order for meeting the additional manpower

103

requirement based on Distribution Licensee's filings, benchmarking and any other factor that the Commission feels appropriate."

3.220 Employee costs consist of four main components - net existing employee costs, net employee costs for new recruitment1 training and development cost and retirement expenses.

3.221 For projecting the employee cost for FY 2020-21 and subsequent years of the Control Period, the Petitioner has adopted the following approach and based on the following factors:

a) The opening normative gross employee cost (EMP,-1) for FY 2019-20 has

been considered as Rs. 366.82 which is the normative gross employee cost of FY 2018-19 (EMP,-1) as determined in the Chapter 2 above.

b) Escalation factor: CPI inflation for FY 2019-20 and FY 2020-21 has been

considered as 4.21 °/01 which is the average increase in CPI for preceding three years till the base year (FY 2016-17 to FY 2018-19)

c) Growth Factor: Gn factor for each year of has been considered based on the net addition is employees as discussed in the table above.

d) Actual Capitalisation of 17.21% has been considered for each year

e) The balance amount of arrears towards seventh pay and expenditure on

account of enhanced pension have been separately considered.

3.222 Based on the above methodology, the Petitioner has proposed the employee cost for FY 2020-21 as detailed in the table below:

Table 119: Projected Employee Costs (Rs. Cr.)

1 EMPn·t 366. 82 382.26

2 G, 0% 33%

3 CPI Infiation 4.21% 4.21%

---------4 EMPn 382.26 529.73

5 Capitalisation Rate 17.21% 17.21%

6 Less: Employee Expenses

65.78 91.15 Capitalised

7 Net Employee Expenses 316.48 438.57 -~--

8 Impact of Seventh Pay

29.19 29.19 Commission

9 Total Employee Expenses 345.67 467.76

Projection of Administrative and General Expenses (A&G)

3.223 According to Clause 84 (3) of Uttarakhand Electricity Regulatory Commission (Terms and Conditions fm Multi Year Tariff) Regulations, 2018, administrative and general expenses for the nth year and also for the year preceding the Control Period will be calculated as per the method given below.

/1 l/ 104 ('-./ /~

----.. ~-·-------- -----·---~----- --~

"A&G,, cc (A&Gn-1) x (1+WPiinflation) + Provision "Where - A&Gn-1: Administrative and General Costs for the (n-1) th year; WPI inflation: is the average increase in the Wholesale Price Index (WPI) for immediately preceding three years; Provision: Cost for initiatives or other one­time expenses as proposed by the Distribution Licensee and validated by the Comrn ission. "

3.224 Administrative and general expenses consist of two main components - existing expenses, new initiatives and 'Provision'.

3.225 The Petitioner has considered a similar approach as considered for employee expenses for projecting the A&G expenses and in line with the methodology followed by the Commission

3.226 An escalation factor i.e. WP! inflation of 2.33% (which is the average increase in WP! for the immediately preceding three-year period between FY 2016-17 to FY 2018-19) has been applied for FY 2019-20 and FY 2020-21 to arrive at the normative A&G expense for subsequent years. It is submitted that while the regulations specify average WP! increase in the last three years, due to a negative inAation of 3.85%, the average of last three years would result in a near zero inflation (0.34%) which is neither justified or rationale considering the increase in consumers, employees as well as distribution network in the recent past as well as during the Control Period. Therefore, the Petitioner requests the Hon'ble Commission to exclude the aberrations in growth while projecting the A&G expenses. Capitalization of 24.26% based on actual capitalization rate of FY 2018-19 (as also discussed in Chapter 2 on True-up of FY 2018-19) has been considered for each year. Additional expenditure on account of License fee has been considered, in line with the Commission's methodology.

3.227 In addition to the normative A&G expenses, it is submitted that there are few new expenses which are not included in the expenditure of base year and shall be incurred for the first time. The details of the same were provided in the MYT Petition last year. In the MYT Order, the Commission had approved some expenditure towards cost of data centre and other new initiatives being implemented by the Petitioner in the current/ subsequent years. Therefore, the Petitioner has proposed an additional 'Provision' needed for activities that shall be introduced although introduced in FY 2019-20, first year of the 3rd Control Period such as mobile based billing, ERP implementation etc. under the R-APDRP scheme, same will also be incurred in FY 2020-21. These additional expenses are being proposed over and above the recurring cost already being incurred against facility management system, AMC of hardware, license renewal, bandwidth charges in the previous years.

3.228 Since the new initiatives were not implemented in FY 2018-19, the Petitioner has considered the revised Gross A&G for FY 2018-19 accordingly determined the Normative Gross A&G for FY 2019-20 and FY 2020-21 in line with the Commission's prescribed methodology. Additional expenditure of RS 46 Cr towards data centre and other new initiatives, the details of which have been provided in the table below shall be incurred in FY 2020-21. It is requested that the Commission approves the same as the expenditure shall be done for the benefit of the consume,-.

105

---------·-·-----·-----

3.229 In addition to the above-mentioned cost, the Petitioner has implemented Android based billing from FY 2018-19 in view of high manpower requ·,rement in meter and billing related activities. Also, considering the severe shortage of manpower 1

Android based billing would be very effective in long-term. The Android based billing is being implemented for all categories of consumers except the high value consumers across the State of Uttarakhand. The system would not only help in reducing the overall cost associated with metering and billing activities but also increase the accuracy in meter reading, regularize the process for meter reading and better management of manpower to other activities.

3.230 The detailed list of additional expenses being proposed as provision in subsequent years under A&G expenses are provided in the table below:

Table 120: Additional Provisioning for Data Centre (Rs. Cr.)

FMS Cost of !TIA for all the IT

1 FMS cost of !TIA hardware, software and network

3.13 installed at DC/DR/CCC and field offices under RAPDRP and IPDS

2 Diesel bills Diesel Consumption Bills for DG Set 0.01

at DC & DR

3 GIS Software support ATS Cost for GIS software of ESRI 1.32

4 DC & DR AMC for civil infra AMC for Infrastructure at DC 1.50

5 M/s Fluent grid (Tech. Support

Manpower Cost 1.00 Service)

6 DC IT Hardware AMC AMC for IT Hardware 0.25

7 IBM Software License Renewal ATS Cost for IBM suite 0.93

8 Cyber Security Audit Cyber Security Audit of DC & DR infra 0.07

9 DR IT Hardware AMC AMC for IT Hardware 1.25 --·--

10 M/s Fluent grid (ATS) ATS Cost For M-Power Suite (MBC &

0.68 other CA Application)

11 ATS for NA & MOM ATS Cost for NA and MDM modules 0.42

Replacement & Upgradation of End of 12 Replacement & Upgradation of End Life IT Hardware at DC & DR after Yr. 7.20

of Life IT Hardware at DC & DR 2020

13 Antivirus

Antivirus license renewal 0.28

14 Red Hat and other software licenses

Software ATS 1.32

Communication system of UPCL

1

2

3

4

5

-~----~----- -----·--·--·--------Bandwidth PRI Lines & Toll free

Expenditure on MPLS ( BSNL, Airtel)

Expenditure on Internet Leased Line (Vodafone, PGCIL, BSNL)

Telephone/GPRS/SMS 0.36

Network Connectivity for Offices & SCADA

3.52 __ _, _____ _ Internet Connectivity 0.24

-~-----+----------------'·--·--SIM SMS charges for meter rno_d_e_n_1_s___,_ __ 0.14

0.5<'1

SIM SMS charges for moderns

SMS Broadcast Charges L_ ___ _L_ __ _ SMS Gateway Charges -~--~------------~-----

S\ 106 1'--v

---·-- ------··----- ---··---- ·---- - -- ·------

---------------------- -- --- -- ---- ----- ------ - -- -- -------

Operational/Commercial activities handled by IT

1 M/s TDS Pvt Ltd ( Mobile based Mobile Billing as O&M expense 10.40 billing_

2 Consumer AMR Capital Expenditure AMR setup for KCC/Open access 1. 51

bt M/s Allied consumers and DSM interface points

3 Consumer AMR annual operational O&M for AMR of KCC/Open access 1.70

exr2:enditure b'{ M/s Allied consumers and DSM interface points

4 M/s Cy Future (IT Operation) IT Operations Engineers Cost 1.50

5 Customer Service Centre expenses CSC Manpower Cost 1.39

Miscellaneous IT and related works

1 Insurance for DC/DR/SCADA MISC Exp for Insurance 0.02

2 vc Setup for UPCL HQ and Field 1.00

Video Conferencing Setu offices

3 Petty IT works Misc. IT Expense, LAN/WAN work etc. 0.40

4 Other professional charges Misc. Operational (F&A) 0.01

5 M/s Wi ro for ERP Consultanc ERP Consultanc & PMA Char es 0.41

6 Website upgradation Addition of chatbot, online recharge 0.30 and website maintenance activit)"

SCADA 1 AMC of SCADA IT hardware 0.19

2 AMC of SCADA field equipment 0.84 RTU/FRTU/DCPS

3 FMS of SCADA/~- 0.80 - -

4 M/s Siemens Ltd Manpower Cost for SCADA 1.62 0 erations

Total 46.23

3.231 The details of total A&G expenses projected for FY 2019-20 and FY 2020-21 are

shown in the table below.

Table 121: Projected A&G Expenses for FY 2019-20 and FY 2020·· (Rs. Cr.)

1. A&Gn-1 29.13 29.81

2. WPI Inflation 2.33% 2.33%

3. Gross A&G Expenses 29.81 30.50

4. Capitalization rate 24.26% 24.26%

5. Less: A&G expenses capitalized 22.58 23.10

6. Net A&G Expenses 46.23 46.23

Provision (Data Centre& new 7. initiatives)

3.00 3.25

8. Total A&G Expenses 71.81 72.58

107

-------···-··-·--··--··-··-----· --·--··--·-···-··---

Projection of Repair and Maintenance Expenses (R&M)

3.232 As per Clause 84 (3) of Uttarakhand Electricity Regulatory Commission (Terms and Conditions of Multi Year Tariff) Regulations, 2018, repair and maintenance expenses for the nth year and also for the year preceding tl1e Control Period will be calculated as per the method given below.

"R&Mn = K x (GFAa,1) X (1+WPiinflation) Where -'K' is a constant specified by the Commission in %. Value of/( for each year of the control period shall be determined by the Commission in the MYT Tariff order based on Distribution Licensee's filing, benchmarking of repair and maintenance expenses, approved repair and maintenance expenses vis-21-vis GFA approved by the Commission in past and any other factor considered appropriate by the Commission; GFAn-1: Gross Fixed Asset of the Distribution Licensee for the (n-1}th year."

3.233 Total R&M expenses have been projected for FY 2019-20 (RE) and FY 2020-21 based on the provisions of the regulations and method adopted by the Hon'ble Commission in previous tariff orders.

3.234 The Petitioner has considered revised K factor at the rate of 3.06% as per the approved by the Commission in the MYT Order for FY 2019-20 and FY 2020-21:

3.235 The 'K' factor has been applied to the opening GFA for FY 2019-20. A WP! inflation of 2.33% has been considered similar to approach followed in A&G expenses above. The Petitioner requests the Hon'ble Commission to adjust the inflation rate considered for any abnormalities in the past WP! growth rate.

3.236 The details of total R&M expenses projected for FY 2019-20(RE) and FY 2020-21 are shown in the table below.

Table 12.2: Projected Repair and Maintenance Expenses (Rs. Cr,}

GFAn-1 5554. 15 6491.21

K Factor 3.06% 3.06%

WPI Inflation 2.33% 2.33%

Normative R&M Expense 173,92 203,26

Projected Operation and Maintenance Expenses

3.237 Based on the detailed discussion on the various components of O&M expense as detailed above, the summary of projected operation and maintenance expenses for is given in the table below.

Table 123: Operating and Maintenance Expenses (Rs. Cc)

Net Employee Costs

Net Administrative & General Ex enses A&G

Repair and Maintenance (R&M)

345.67 467.76

71.81 72.58

1 173~~--2_0_3_.2_6_

/'-10/)08

~-----·-·--·-··-·--·-·--··--·----·--·---·--·--·----, ',-~,--..

Depreciation

3.238 The Petitionei- has computed depreciation based on the projected gross fixed assets for FY 2019·20 and FY 2020·21. Depreciation has been calculated based on the depreciation rate determined on the basis of by the Commission in the UERC Tariff Regulations, 2018. Asset-wise depreciation details have been provided in the Formats provided along with the Petition

3.239 The average depreciation rate of 5.21 % has been applied on the average GFA for each year computed as per actual capitalization for FY 2018·19 and proposed capitalization for FY 2019·20 and FY 2020·21. Assets created from grants and deposit works have been excluded for the purpose of depreciation as per the provisions of the UERC Tariff Regulations, 2018. The table below details the depreciation projected by the Petitioner for FY 2019·20 and each year of FY 2020· 21.

Table 124: Proposed Depreciation for FY 2019-20 and FY 2020-21 (Rs. Cr.)

Opening GFA (without grant and deposit)

Additions

Grant/deposit work in addition

f\Jet Additions (Additions- Grant)

Closing GFA (without grant and deposit)

Average rate of depreciation

Depreciation

Interest on Working Capital

3107.13

937.06

505.46

431.60

3538. 73

173.12

3538. 73

977.22

327.21

650.00

4 WC. 73

5.21%

201.30

3.2~0 A;, ;>.:r ciausc 33 (}) (a) of the UERC Tariff Regulations, 2018, the distribution licensee shall be allowed an interest on the estimated level of working capital for the financial year, computed as follows:

a) Operation and maintenance expenses for one month;

b) Maintenance spares @ 15% of operation and maintenance expenses; plus

c) r,vo months' equivalent of the expected revenue from sale of electricity at the prevailing tariffs; ·

d) Capital required to finance such shortfall in collection of current dues as may be allowed by the Commission; minus

e) Amount held as security deposits under clause (a) and clause (b) of sub· section (1) of Section 47 of the Act from consumers and Distribution Syste1n Users; minus

f) One-month equivalent of cost of power purchased, based on the annual power procurement plan.

109

3.241 As per clause 33 of the UERC Tariff Regulations, 2018 rate of interest on working capital shall be on normative basis and shall be equal to the State Bank Advance Rate (SBAR) of State Bank of India as on the date on which the application for determination of tariff is made.

3.242 Based on the above, the utility has calculated interest on working capital considering the above parameters and taking interest rate as 13.70% for FY 2019-20 and FY 2020-21, which is the prevailing SBAR. The detailed computation of interest on working capital is provided hereunder:

Table 125: Projected interest on Worki11g Capital (Rs. Cr-)

One-month O&M expense

Maintenance spares@ 15% of O&M

2 months of expected revenue at .-.2revailing tariff Capital required to finance shortfall in collection of current dues

Amount held as security deposit

49.28

88.71

1088. 96

62.07

871.54 f------------------+-----One month of Power Purchase cost 501.81

(84.32) . Working Cap!tal_ Requirement -~-------+----~--'--+--13.70% 1 nte rest rate ( State B~ n k_A_d_v_a_n_ce_R_a_te_)--+ _______ ,__

Interest on working capital 0.00

Non-Tariff Income (NTI)

• ' 61.97

111.54

1337.96

72.25

934.33

531.63

117.76

13. 70%

16.13

3.243 Non-Tariff income for FY 2019-20 and FY 2020·21 has been projected on the same levels as actuals of FY 2018-19.

3.244 The table below details the projection of Non-Tariff income for FY 2019-20 and the FY 2020-21:

IWUMifi#

Provision for Bad Debts

3.245 As per UERC Tariff Regulations, 2018, clause 31(1) the Commission may allow a provision for bad and doubtful debts up to one percent (1%) of the estimated annual revenue of the distribution licensee, subject to actual writing off bad debts by it in the previous years.

3.246 It is submitted that the Commission has not been approving any additional write­off during the truing-up of recent years. In the Tariff Order for FY 2018-19 under Clause 3.3.3 Provisions for Bad and Doubtful Debts, the Commission had stated the following:

"The Commission has already allowed the Petitioner a total provision of Rs. 333. 75 Crore till FY 2008-09 which also includes the opening balance of the provision inherited from UPPCL. Even considering the actual write off debt of Rs.

110

----------------

230.44 Crore WI FY 2016-17, the Petitioner is still left with a provision of about Rs. 103.31 Crore. The closing debtors of UPCL as on 31.03.2016 were lD the tune of Rs . . 1,789.05 Crore as per the Commercial Diary of UPCL. Hence, the provision available with UPCL is to the extent of 5.77% for FY 2016-17 of the existing debtors and any additional provision is not allowable in accordance with the Regulations as referred above. 11

1.2 In view of the above stated details, the Hon'ble Commission is requested to allow 1 % of the ARR towards provision for Bad and Doubtful Debts during the FY 2020-21 at the time of true-up.

Impact of transfer scheme between UPPCL and UPCL

3.247 As per the initial agreement between UPPCL and UPCL, the normative value of the opening GFA had been agreed at Rs. 1,058.18 Crs. The value recognised was normative va!ue and not the cost of acquisition of these assets, the Commission didn't find any merit for considering opening GFA as Rs. 1,058 Crs.

3. 248 As per the Commission, since the Govt. took over the liabilities of UPCL even before the transfer scheme was finalized, the Commission decided to fix the opening value of Gross fixed assets as Rs. 508 Crs.

3.249 The Uttarakhand government by order dated 27th April 2012 approved the transfer scheme of assets and liabilities to be executed between UPPCL and UPCL, however, the Commission didn't take cognisance of the same citing that the scheme hasn't been notified.

3.250 UPCL filed the petition in ATE challenging the Commission order, but Hon'ble ATE as per order dated 18'" May 2015 directed UPCL to take up the matter with State Government for issuance of notification on transfer of assets to Uttarakhand from UP.

3.251 The Govt of UP and Uttarakhand in a State Level meeting decided on final settlement on any pending transactions between both sides. The reference letter is provided as Annexure.

3.252 Since the APTEL Order asked that the transfer scheme has to be notified by the State Government, efforts to address the same have been started.

3.253 The Petitioner humbly requests the Commission to allow for the recovery on account of difference in opening GFA of ~550 Cr (Rs 1058 Cr- 508 Cr) against the transfer scheme finalised by UERC, by way of a surcharge.

3.254 The Petitioner has taken up the matter with UPPCL and Govt. of Uttarakhand and the necessary documents shall be submitted during the course of tariff proceedings.

Annual Revenue Requirement for FY 2020-21

3.255 In light of the components discussed above, the ARR proposed by Petitioner for FY 2020-21 along with revised estimate for FY 2019-20 is provided in the Table below:

111

Table 127: ARR for FY 2019-20 and FY 2020-2.1. (Rs, Cr.)

Power purchase expenses

Transmission charges -PGCIL charges

Transmission charges -PTCUL charges

O&M

Employee

A&G

R&M

Interest & Finance charges & Security Deposit

Depredation

Interest on working capital ---Return on Equity (RoE) Total Annual Revenue Requirement (ARR)·

Less: Non- Tariff Income (NTI)

Add: True up impact Gap/(surplus) Net Annual Revenue Requirement (ARR)

Revenue Projections

Revenue at Existing Tariff

5279.49

475.85 266.36

345.67

71.81 173. 92 170.77 173.12

0.00 126.48

7083.47

244.41

(305.31) 6533.75

5590.69 373.37

415.45

467.76 72.58

203.26

195.43 201.30 16.13

153.25 ---7689.24

244.41

7444.84

3 .256 The Petitioner has projected the categorf-wise revenue for FY 2020-21 based on the existing fixed and variable tariff approved by the Commission in Tariff Order dated February 27, 2019 and additional energy charge approved by the Commission in Order dated October 25, 2019 for each category as shown in the table below:

Table 128: Category-wise Revenue Forecast for FY 2020-2:t at Existing Tariff

RTS-1: Domestic 3077.39 1362.05 4.43

RTS-2; Non-Domestic 1435.19 923.26 6.43

RTS-3: Govt. Publfc Utilities 675.62 402.24 5.95

RTS-4; Private Tube Wells 197.81 40.29 2.04

RTS-5: Industry 6956.72 4213.49 6.06

LT Industry 323.46 192.87 5.96

HT Industry 6633.26 4020.62 6.06

RTS-6: Mixed Load 184.93 103.28 5.58

RTS-7: Railway Traction 29.04 17. 74 6.11

Total 12556.69 7062.37 5.62

Note: Revenue includes charges on account of continuous supply surcharge, voltage surcharge & rebate and Too tariff,

Revenue Gap for FY 2020-21 at existing tariff

3.257 The Net Aggregate Revenue Requirement for FY 2020-21 is worked out as Rs. 7444.84 Cr. and the projected revenue at the existing tariff has been computed as Rs. 7062.37 (Inclusive of revenue on account of additional energy charge). The standalone revenue gap for the FY 2020-21 is working out to be Rs 382.47 Cr at existing tariff.

3.258 The table below details the standalone revenue gap for FY 2020-21:

Table 129: Revenue Gap for FY 2020~21 (Rs. Cr)

Net ARR 7444.84 C--------~-------+-------~--'

Revenue at existing tariff 7062.37

(Gap)/Surplus (382.47)

3.259 As can be seen from the above, existing tariff rates are not sufficient to meet the projected expenditure for FY 2020-21 thus there is a need for revision in tariff.

3.260 Therefore, it is proposed to recover the gap of Rs 382.47 Cr along with the gap on account of true-up for FY 2018-19 including carrying cost of Rs 153.24 Cr, by way of tariff hike in FY 2020-21.

Revenue at proposed tariff in FY 2020-21

3.261 It is proposed to recover the entire gap in FY 2020-21 by way of tariff revision. The Table below details the summary of the revenue from the various consumer categories at the proposed tariff, the schedule of which is provided in the next section. Slab-wise details of revenue at proposed tariffs have been furnished in Form: F-14 ('Revenue from Proposed Tariff for ensuing year') of the 'Distribution Formats' given by the Hon'ble Commission.

Table 130: Projected Revenues for FY 202.0-21 at Proposed Tariffs

RTS-1: Domestic 3077.39 1523.35 4.95

RTS-2: Non-Domestic 1435. 19 1014.37 7.07

RTS-3: Govt. Public Utilities 675.62 435.07 6.44

RTS-4: Private Tube Wells 197.81 42.52 2. 15

RTS-5: Industry 6956. 72 4458. 13 6.41

LT Industry 323.46 209.81 6.49

HT Industry 6633.26 4248.32 6.40

RTS-6: Mixed Load 184. 93 112.91 6.11

RTS-7: Railway Traction 29.04 19.86 6.84

Total 12556.69 7606.20 6.06

Note: Revenue includes charges on account continuous supply surcharge, voltage surcharge & rebate and ToD tariff

113

--------- -----·- ---- ----

Based on the revision in larirr the revenue gap at the cfosing of Pf 2020-21 has been determined as fof/01vs:

Table 131: Cumulative revenue gap by the end of FY 2020-21 on account of tariff revision

Opening _Gap 0.00 134. 78 153. 24 Addition 126.14 0.00 382.47 Additional revenue on account

0.00 of tariff revision 0.00 (543.83)

Closing Gap 126.14 134. 78 (8.13) Average Gap 63.07 134. 78 72.56 Rate of Interest (Equivalent to

13.70"% 13.70% 13.70% Intere?t on Working Ca ital Carrying cost 8.64 18.46 9.94 Closing gap for the year 134. 78 153.24 (1.82)

114

A4: Open Access Charges

4.1 Hon'ble Commission vide its Tariff Order dated February 27, 2019 determined the open access charges for FY 2019-20 which shall be applicable on consumers seeking open access through the distribution system.

4.2 In this regard, the Hon'ble Commission had determined the wheeling and cross subsidy surcharge as per the provisions of the UERC (Terms and Conditions of Intra State Open Access) Regulations, 2015 and its subsequent amendments.

4.3 In line with the methodology followed by the Hon'ble Commission, the Petitioner is proposing the open access charges for FY 2020-21 based on the ARR and Tariff Proposed in this Petition.

Wheeling Charges

4.4 Regulation 20(2) of UERC (Terms and Conditions of Intra State Open Access) Regulations, 2015 and its subsequent amendment provides:

"Wheeling charges payable to distribution licensee, by an open access customer for usage of its system shall be as determined as under:

Wheeling Charges= (ARR-PPC-TC) / (PLSD X365) (Rs. /MW/Day)

Where,

ARR=Annua/ Revenue Requirement of the distribution licensee for the relevant year

PPC= Total Power Purchase Cost of distribution licensee for the relevant year

TC = Total transmission charges paid by distribution licensee for State and Inter-State transmission system for the relevant year

PLSD= Total Peak load served by the concerned distribution system for the previous year Provided where Open Access is a flowed up to contracted load, embedded open access consumer shall pay wheeling charges as determined by the Commission in the following manner:

WC Embedded consumer= WC - [FC*0.85*12*1000/365] (in Rs. /MW/day)

Where,

WC Embedded consumer= Net wheeling charges for embedded consumers

WC= Wheeling charges as determined by the Commission in accordance with the methodology specified in Regulation 20(2) contained in Chapter 5 of these regulations.

FC= Fixed/demand charges in Rs/kVA/month as per rate schedule approved in the Tariff Order for the relevant year. For the purpose of conversion of kVA into kW power factor of 0. 85 has been taken.

Note: In case Wheeling Charges for Embedded consumer worked out as above becomes negative, such charge shall be zero.

Provided that wheeling charges shall be payable on the basis of Approved Capacity.

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Provided where open access is allowed beyond the contracted load, embedded open access consumer shall pay wheeling charges for the excess load as determined by the Commission in the following manner:

WC For excess load allowed~ (ARR-PPC-TC) / (PLSD X365) (Rs. /MW/Day)"

4.5 In accordance to the methodology provided in the Regulations, the proposed wheeling charges for consumers availing open access during FY 2020-21 are computed as below:

Table 132: Wheeling Charges for Open Access Consumers during FY 2020-21

A Proposed ARR for FY 2020-21 Rs. Cr. 7,444.84

Less:

B Power ~Purchase Cost Rs. Cr. 5,590.69

C Transmission Cost Rs. Cr. 788.82

D Wheeling ARR (A-B-C) Rs. Cr. 1065.32

E Peak Load Served by the distribution system MW 2,251

Wheeling Charges for FY 2020-21 Rs. /MW/day 12,969 D/ E*365

F

4.6 In case of embedded open access consumers who have been allowed open access up to the contracted load, the wheeling charges are proposed as under:

Table 133: Proposed Wheeling Charges for FY 2:020-21

Wheeling Charges for FY 2020-21

Fixed Charges

Wheeling Charges for Embedded Consumers for FY 2020-21 (WC -[FC*0.85* 12*1000 /365])

Intra-State Transmission Loss

Distribution Loss

Rs. /MW/day

Rs.

KVA/month

Rs.

/MW/day

Cross Subsidy Surcharge

12969 12969

350 445

3188

1.40% 1.40%

14.00% 14.00%

12969

90

10454

1.40%

14.00%

4.7 Regulation 22(2) of the UERC (Terms and Conditions of Intra State Open Access) Regulations, 2015 and its subsequent amendment provides the formula for determination of cross subsidy surcharge which is as below:

(2) The cross-subsidy surcharge for such short-term open access consumers shall be determined in accordance with the following formula:

S=T-C

Where,

~·

S is the Cross-Subsidy Surcharge;

Tis the retail tariff payable by the relevant category of such consumers;

C is the average cost of supply of distribution licensee.

4.8 In accordance with the above formula specified in the regulations, the proposed cross subsidy surcharge for various categories of consumers is as below:

Table 134: Proposed Cross-Subsidy Surcharge for FY 2020-21 (Rs. Per unit)

Proposed Tariff for relevant category 7.22

Less: Average Cost of Supply 6.06 6.06

Cross Subsidy Surcharge 1.17 1.33

Additional Surcharge

4.9 Regulation 23 of the of UERC (Terms and Conditions of Intra State Open Access) Regulations, 2015 provides for charging of Additional Surcha,·ge:

"(1) Any consumer, receiving supply of electricity from a person other than the distribution licensee of his area of supply, shall pay to the distribution licensee an additional surcharge on the charges of wheeling, in addition to wheeling charges and cross-subsidy surcharge, to meet out the fixed cost of such distribution licensee arising out of his obligation to supply as provided under sub-section ( 4) of Section 42 of the Act.

(2) This additional surcharge shall become applicable only if the obligation of the licensee in terms of power purchase commitments has been and continues to be stranded or there is an unavoidable obligation and incidence to bear fixed costs consequent lD such a contract. However, the fixed costs related to network assets would be recovered through wheeling charges.

(3) The distribution licensee shall submit to the Commission, on six monthly bases, a detailed calculation statement of fixed cost which the licensee is incurring towards his obligation to supply.

The Commission shall scrutinize the statement of calculation of fixed cost submitted by the distribution licensee and obtain objections, if any, and determine the amount of additional surcharge.

Provided that any additional surcharge so determined by the Commission shall be applicable on prospective basis on all open access consumers.

(4) Additional surcharge determined on per unit basis shall be payable, on monthly basis, by the open access consumers based on the actual energy drawn during the month through open access"

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4.10 Consumers shifting to open access impact the power off take of the utility from the generating stations. Such consumers should be liable to pay an additional surcharge to meet the fixed cost of the distribution licensee arising from the obligation to supply. Absence of suitable additional surcharge levied to the open access consumer would result in undue burdening on the other licensee consumers. Therefore, the Petitioner requests the Hon'ble Commission to propose an appropriate methodology for determining the additional surcharge for FY 2020-21.

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A riff Proposal

5.1 The tariff proposal has been formulated by the Petitioner with an attempt to keep the impact on the consumers to the minimum possible and at the same time not defer a large portion of recovery on the tariff in the coming years. Also, the provision of the Section 61(g) of the Electricity Act, 2003 states that the appropriate Commission should be guided by the objective that the tariff progressively refiects the efficient and prudent cost of Supply of electricity. The key highlights of the proposed tariff are as under:

(i) Slight change has been made in tariff of BPL consumers

(ii) Number of slabs under Domestic category has been reduced to two: 0-100 kwh and above 100 kWh with same fixed charges

(iii) Independent Advertisement Hoardings sub category under Non- Domestic is proposed to be merged with Non-Domestic Sub-category of Load 25 KW and below.

(iv) Increase in the Fixed/ Demand charges are higher as compared to energy charges on account of substantial fixed cost thereby making tariff more cost reflective

(v) Introduced a new category for RTS-8: Electric Vehicles Charging System in accordance with the direction of GoU with single part tariff at the Average Cost of Supply. In absence of data no revenue has been considered.

(vi) Increase in all other categories has been proposed in line with the Tariff Policy and the Proposed ARR to be recovered in FY 2020-21

(vii) With a view to address the problems regarding implementation of tariff being faced by the person who take single point bulk supply and the end consumers, the condition of single point bulk supply has been revised in­line with the provisions of tariff order issued by Hon'ble UPERC for FY 2019-20.

(viii) Abolition of Grace Period during payment of Delayed Payment Surcharge

(ix) Modifications in Prepaid Metering scheme

5.2 Accordingly, the tariff proposal for each of the tariff category and slab is given below vis-a-vis the existing tariff.

Table :1.35: Category-wise and Slab-wise Existing Tariff vis-a-vis Proposed Tariff

RTS-1: Domestic

1.1 Life line Consumers 18/Connection 1.61 Rs/kWh

0.22 Rs/kWh 18/Connection 1.90 Rs/kWh

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1.2 Other Domestic Consumers

-----

(i) Upto 100 55/connection

2.75 0.39 Rs/kWh 75/connection 3.26 Rs/kWh

Units/month Rs/kWh (ii) 101~200

85/connection 3.55 0.39 Rs/kWh

Units/month Rs/kWh

(iii) 201-400 145/connectlon

4.90 0.39 Rs/kWh 135/connection 5.25 Rs/kWh Units/month Rs/kWh

(iv) Above 400 230/connection 5.65 0.39 Rs/kWh Units/month Rs/kWh

1.3. Single Point Bulk 75 4.40 0.39 Rs/kWh 85 4.85 Rs/kWh Supply above 75 kW Rs/kW /month Rs/kWh Rs/kW/month

RTS-lA: Snowbound ·---·

1.61 Domestic 18/connection

Rs/kWh 1.61 Rs/kWh

Non-Domestic upto 1 18/connection

1.61 25/Connection 1.61 Rs/kWh kW Rs/kWh

Non-Domestic above 1 18/connection

2.36 2.36 Rs/kWh kW & upto 4 kW Rs/kWh

Non-Domestic above 4 30/connection 3.51 40/connection 3.51 Rs/kWh

kW Rs/kWh

RTS-2: Non-Domestic

1. (i) Government/Municipal Hospitals (ii) Government/Government Aided Educational Institutions (iii) Charitable Institutions registered under the Income Tax Act, 1961 and whose income is exempted from tax under this Act

1.1 Upto 25 kW 65 4.50

0.56 Rs/kWh 90

5.00 Rs/kWh Rs/kW/month Rs/kWh Rs/kW /month

1.2Above 25 kW 75 4.25

0. 53 Rs/kVAh 100

4.80 Rs/kVAh Rs/kVA/month Rs/kVAh Rs kVA/month

2. Other non-Domestic/Cornmercia I Users 2.1 Small shops (Load upto 4 KW & 70 4.70

0.56 Rs/kWh 80

4.85 Rs/kWh consumption upto 50 Rs/kW /month Rs/kWh Rs/kW /month units m -2.2 Upto 25 kW other 75 5.60

0.56 Rs/kWh 90

6.45 Rs/kVAh than above Rs/kW/month Rs/kWh Rs/kV A/month

2.3 Above 25 kW 75 5.45

0.53 Rs/kVAh 90

6.15 Rs/kVAh Rs/kVA/month Rs/kVAh Rs/kVA/month 3. Single Point Bulk 75 5.50

0.53 Rs/kVAh 90

6.20 Rs/kVAh Supply ab_ove 50 kW Rs/kVA/month Rs/kVAh ·------· Rs/kVA/month ·---· 4.0 Independent

90 6.10 Advertisement ~ Rs/kW/month Rs/kWh

0.56 Rs/kWh Hoardin s RTS-3: Govt. Public Utilities

1. Metered (Urban) 60 5.20

0.47 Rs/kVAh 100

5.80 Rs/kVAh Rs/kVA/month Rs/kVAh Rs/kVA/month

2. Metered (Rural) 50 5.20

0.47 Rs/kVAh 90

5.80 Rs/kVAh Rs/kVA/month Rs/kVAh Rs/kVA/month RTS-4: Private Tube-wells/ Pumping sets

1. Metered 1.95 0.18 Rs/kWh 2.15 Rs/kWh Rs/kWh

RTS-4A: Agriculture Allied Activities

1. Metered 1.95 0.18 Rs/kWh 2.15 Rs/kWh Rs kWh ·-------

RTS-5: LT & HT Industr

L ,------·

J:.120 ,/

LT Industries-Contracted load upto 75kW (100 BHP) ·--1.2 LT Industries (Upto 145 4.35

0.53 Rs/kWh 180

4.80 Rs/kVAh 25 kW) Rs/kW /month Rs/kWh Rs/kVA/month

1.3 LT Industries (above 145 4.00 0.50 Rs/kVAh

180 4.40 Rs/kVAh

25kW & upto 75 kW) Rs/kVA/montt, Rs/kVAh Rs/kV A/month

HT Industries (above 75 l<W/SSl(VA)

2.1 Contracted load u to 1000 kVA

300 Rs/kV A of 3.95 350 Rs/l<V A of

1- Load factor upto 40% billable Rs/kVAh

O. 50 Rs/kVAh billable demand 4.40 Rs/kVAh demand

2-Load factor above 300 Rs/kV A of

4.35 350 Rs/kV A of billable O. 50 Rs/kVAh 4.75 Rs/kVAh 40% demand Rs/kV Ah billable demand

2.2 Contracted load above 1000 kVA ---

360 Rs/kV A of 3.95 445 Rs/kV A of

1- Load factor upto 40% billable Rs/kVAh

a.so Rs/kVAh billable demand 4.40 Rs/kVAh demand

2-Load factor above 360 Rs/kVA of 4.35 445 Rs/kVA of

40% billable

Rs/kV Ah a.so Rs/kVAh

billable demand 4.75 Rs/kVAh

demand

RTS-6: Mixed Load

Mixed Load Single Point 80 5.05 110 Bulk Supply above 75

Rs/kW /month Rs/kWh 0.49 Rs/kWh

Rs/kW /month 5.70 Rs/kWh

kW includin MES RTS-7: Railway Traction

Railway Traction 250 4.40

0.49 Rs/kWh 320

5.00 Rs/kVAh Rs kVA/month Rs kVAh Rs kVA month

RTS-8: Electric Vehicle Charging Station Electric Vehicle Charging

6.00 Rs/kWh Station

Prepaid metering Scheme

The Petitioner proposed the Prepaid Metering Scheme as follows:

(i) The option of Pre-paid metering shall be available for all categories of consumers upto 25 kW load under LT category. Prepaid Metering shall be mandatory for new Temporary LT connections, for Advertisements/Hoardings and for Government connections upto 25 kW.

Prnvided that the option of prepaid metering shall not be available to the Seasonal industries covered under Rate Schedule RTS-5.

(ii) There shall be a minimum recharge of Rs. 100 and the maximum limit of recharge shall be Rs. 15,000 for both single phase and three phase connections. Validity of the recharge shall be continued till the amount is available in the account of the consumer. Any recharge shall be allowed only when the 20-digit special meter reading code shall be made available by the consumer.

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(iii) As regards the charging for testing of meter, the Petitioner shall recover the amount as approved by the Commission under Schedule of Miscellaneous Charges directly from such prepaid consumers as is done for post-paid consumers and shall not be charged from the recharge amount.

(iv) In case, the consumer opting for Prepaid Metering have outstanding arrears, the Petitioner shall adjust 20% of the past arrears or 50% of the recharge amount, whichever is higher from the recharge voucher, subject to the maximum of the outstanding arrears. Further, the maximum limit of recharge as mentioned above, shall not be applicable in case of consumers having outstanding arrears and accordingly, such consumers having past arrears will have to take minimum recharge of more than 20% of the outstanding arrears.

(v) The Petitioner shall make necessary provisions to provide friendly credit hours/limit to the consumers, in order to ensure uninterrupted supply to the consumer in the event of expiry of the balance during non-working hours, i.e. night time or during holiday, so as to provide reasonable time to the consumer to procure the recharge voucher at the next possible working hours or working day. However, the charges for the electricity consumed between expiry of balance during non-working hours and subsequent recharge voucher shall be adjusted from the recharge voucher.

(vi) All the Prepaid meters will be provided with an alarm to indicate low credit.

(vii) As per the guiding principles and Section 47(5) of the Electricity Act, 2003, the Petitioner shall not charge any security deposit as is required in post-paid connections but price equivalent to the material cost, i.e. cost of meter and associated equipment's shall be cl1arged as material security which shall be returned after adjusting for the depreciation at the time of permanent disconnection. The approved material security deposit (except for BPL domestic consumers) for FY 2020-21 shall be Rs. 5000/- for single phase connection and Rs 10,000/- for three phase connection. BPL domestic consumers shall....!);,_ exempted for payment of material security deposit.

(viii) The consumer shall be allowed only one transfer from post-paid to prepaid or otherwise in a financial year.

(ix) Voltage rebate/surcharge, low power factor surcharge and excess load penalty shall not be applicable for prepaid connections.

A rebate of 4% of Energy Charges for Domestic Category and 3% of Energy Cha,·ges for other categories shall be applicable as per tariff schedule for the consumers availing this scheme and the rebate shall only be applicable after installation and operationalization of Prepaid meters.

Provided that no rebate shall be applicable on (i) of Para 1 of RTS-8, i.e. Temporary Supply for Illumination/Public Address/ceremonies and festivities/functions/ temporary shops not exceeding 3 months.

Provided further that the fixed charge in respect of other domestic consumers [(1.1) and (1.2) of para 2 of the RTS -1] shall be Rs 75/kW/month.

------·-----------------~ -------~

Provided furthe;r that the energy charge in re~ect of BPL domestic consumers sha]\. be as follows:

Upto 60 units per month

61 - 100 units per month

Above 100 units per month

Rs. 1. 90/kWh

Rs. 3, 26/kWh

Rs. 5.25/kWh

Provided further that in case consumers covered under para 2(1.2) (a) of Rate Schedule RTS - 2 consumes more than 50 units in a month, the energy charge for first 50 units shall be Rs. 4.85/kWh and the remaining units shall be charged at the energy charge as specified for consumers covered under para

2(1.2) (b) of Rate Schedule RTS - 2.

Provided further that Gaushalas/Gausadans having load upto 2 kW covered under Rate Schedule RTS -1 shall be charged at the rates as specified in Rate

Schedule RTS - 1 irrespective of their monthly consumption.

Provided further that consumers having contracted load upto 2 kW and consumption upto 200 kWh per month and who are using some portion of the

premises for non-domestic purposes covered under Rate Schedule RTS-1 shall be charged at the rates as specified in Rate Schedule RTS- 2 ..

(x) The solar water heater rebate shall be adjusted as follows:

a) The rebate for first month of implementation of prepaid metering scheme

shall be credited immediately on the first recharge. Thereafter, rebate shall be credited on monthly basis if recharge is done every month.

b) In case recharge is not being done on monthly basis, then based on the·

capacity of Solar Water Heater installed by the consumer, solar water heater rebate would be credited for all the past months for which the rebate

was due either at the time of recharge or when the consumer approaches UPCL,

Abolition of Grace Period

(i) Regulations, 2007 as amended from time to time, delivery of electricity bill to the consumer should be effected atleast 15 days before the due date for payment of the bill.

(ii) On the representation of the consumers regarding delay in delivery of electricity bills by the petitioner, Hon'ble Commission in its Tariff Order dated 12-07-2006 ordered that till such time that UPCL is able to streamline its bill making and distribution system to Commission's satisfaction, grace period of 15 days beyond the last date payment printed on the bill will be available to all consumers without any Delayed Payment Surcharge.

123

(iii) As per direction of Hon'ble Commission, the petitioner is 1·egularly allowing 15 days grace period beyond the due elate to the consumers. In this connection, it is submitted that the petitioner has improved its billing and distribution system tremendously, the details of which are as follows:

a. At the time of passing of order by the Hon'ble Commission allowing the grace period, the entire billing of the petitioner was outsourced to the agencies situated in Meerut & New Delhi. Now the entire billing is In-house, and the billing system is established at Corporate Office.

b. For almost all domestic consumers having load upto 25 kW, billing is either being done through Spot Billing Machine (SBM) or through mobile based billing where on the spot delivery is given after the generation of the bills at site. So, there is no delay in delivering such bills.

c. For system generated bills of other categories (key consumers), bills are generated through petitioners software and instant sms is given to consumers on generation of the bills. This billing is also made available on the website of the petitioner i.e. at www.upcl.org from where consumers can download their own bills. Bills are also delivered through e-mail and in hardcopy to these consumers.

(iv) Keeping in view the improvement in the billing and bill distribution system, Hon'ble Commission is requested to kindly abolish the grace period and provide in the Rate Schedule that the Delayed Payment Surcharge shall be levied after the due date of the bill.

124

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PROPOSED. RATE SCHEDULE FOR FY 2020-21

General Conditions of Supply

1. Character of Service

i) Alternating Current 50 Hz., single phase, 230 Volts (with permissible variations) up to a load of 4 kW.

ii) Alternating Current 50 Hz, three phase, 4 wire, 400 Volts or above (with permissible variations) for loads above 4 kW depending upon the availability of voltage of supply.

2. Conditions for New Connections

i) Supply to new connections of more than 75 kW (88 kVA) and up to 2550 kW (3000 kVA) shall be released at 11 kV or above, loads above 2550 kW (3000 kVA) and up to 8500 kW (10000 kVA) shall be released at 33 kV or above and loads above 8500 kW (10000 kVA) shall be ,-eleased at 132 kV or above.

ii) All new connections shall be given with meter conforming to CEA Regulations on Installation and Operation of Meters.

iii) All new 3 phase connections above 4 kW shall be released with Electronic Tri­vector Meter having Maximum Demand Indicator.

iv) All new Single Point Bulk Connection shall be given only for Load of more than 75 kW.

v) Consumers having motive loads of more than 5 BHP shall install Shunt Capacitor of appropriate rating and conforming to BIS specification.

vi) All new connections at HT/EHT should be released only with 3 phase 4 wire meters.

3. Point of Supply

Energy will be supplied to a consumer at a single point.

4. Billing in Defective Meter (ADF/IDF), Meter Not Read/Not Accessible (NA/NR) and Defective Reading (RDF} Cases

In NA/NR cases, the energy consumption shall be assessed and billed as per average consumption of last one-year average consumption (as per the Electricity Supply Code) which shall be subject to adjustment when actual reading is taken. Such provisional billing shall not continue for more than two billing cycles at a stretch. Thereafter, the licensee shall not be entitled to raise any bill on provisional basis. In case of Appear defective meter (ADF) Identified defective meter (IDF) and Reading defect (RDF) cases, the consumers shall be billed on the basis of the average consumption of the past three billing cycles immediately preceding the date of the meter being found or being reported defective (as per the Electricity Supply Code). These charges shall be leviable for a maximum period of three months or two billing cycle in case of bi-monthly billing only during which time the licensee is required to replace the defective mete,·. Thereafter, the licensee shall not be entitled to raise any bill without correct meters.

The checking and replacement of defective meter cases namely IDF and ADF and defective reading cases namely RDF shall be done by the licensee in accordance with Regulation 3.1.4 of the Electricity Supply Code.

5. Billing in case of domestic metered consumers in rural/hilly areas whose meters are not being read

125

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For cases relating to domestic metered consumers in rural/hilly areas1 where meter reading is either not being taken regularly or taken randomly over delayed interval of time, the provisional billing under these circumstances for such consumers shall be done at the normative levels of consumption as given below, which shall be subject to annual adjustment based on actual meter reading.

Cateaorv Normative Consumntion Domestic /Rural-Hillv Areas) 30 kWh/kW /month Domestic (Rural-Other Areas) 50 kWh/kW/month

For this purpose, the contracted load shall be rounded off to next whole number. Billing on this basis is subject to annual adjustment and the licensee is to ensure meter reading of such consumers at least once a year.

6. Billing in New Connection or conversion from unmetered to metered Cases

For cases, such as new connections or conversion of unmetered to metered connection, where past reading is not available, the provisional billing shall be done at the normative levels of consumption as given below, which shall be subject to adjustment when actual reading is taken.

·-_ .. _" Cateaorv Normative Cansumntion

Domestic (Urban) 100 kWh/kW/month Domestic /Rural-Hillv Areas) 30 kWh/kW /month Domestic /Rural-other Areas) 50 kWh/kW/month __ Non-domestic /Urban) 150 kWh/kW /month Non-domestic (Rural) 1 o o kWh/kW/ man th --Private Tube Wells 60 kWh/BHP/month Industrv LT Industry 150 kWh/kW/month HT Industrv 150 kVAh /kVA /month

For this purpose, the contracted load shall be rounded off to next whole number. Billing on this basis shall continue only for a maximum period of 2 billing cycles, during which the licensee should ensure actual reading. Thereafter, the licensee shall not be entitled to raise any bill without correct meter reading. In all other categories, 1st bill shall be raised only on actual reading.

7. Delayed Payment Surcharge (DPS) (for all categories except PTW)

In the event of electricity bill rendered by licensee, not being paid in full, a surcharge of 1.25% on the principal amount of the bill which has not been paid, shall be levied from the original due date for each successive month or part thereof until the payment is made in full without prejudice to the right of the licensee to disconnect the supply in accordance with Section 56 of the Electricity Act, 2003. The licensee shall clearly indicate in the bill itself the total amount, including DPS, payable for different dates after the due date.

8. Solar Water Heater rebate

If consumer installs and uses solar water heating system, rebate of Rs. 100/­p.m. for each 100-litre capacity of the system or actual bill for that month whichever is lower shall be given subject to the condition that consumer gives an affidavit to the licensee to the effect that he has installed such system, which the licensee shall be free to verify from time to time. If any such claim is found to be false, in addition to punitive legal action that may be taken against such consumer, the licensee will recover the total rebate allowed to the consumer with 100% penalty and debar him from availing such rebate for the next 12 months.

9. Prepaid Metering

·Prepaid metering scheme approved by the Commission in this Order shall be

126

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applicable. A rebate of 4% of energy charges for Domestic category (RTS-1 and RTS-lA) and 3% of energy charges for Other LT consumers shall be allowed to the consumers under the Prepaid Metering Scheme from the date of installation and operationalisation of Prepaid Meters. However, no rebate shall be applicable on RTS-8, i.e. Temporary Supply. Solar water rebate as provided above in the Rate Schedule shall be applicable on prepaid consumers also subject to fulfilment of conditions provided therein.

10. Rebate/surcharge for availing supply at voltage higher/lower than base voltage

(i) For consumers having contracted load upto 75 kW/88 kVA - If the supply is given at voltage above 400 Volts and upto 11 kV, a rebate of 5% would be admissible on the Energy Charge.

(ii) For consumers having contracted load above 75 kW/88 kVA - In case the supply is given at 400 Volts, the consumer shall be required to pay an extra charge of 20% on the bill amount calculated at the Energy Charge.

(iii) For consumers having contracted load above 75 kW/88 kVA - In case of supply at 33 kV the consumer shall receive a rebate of 2.5% on the Energy Charge.

(iv) for consumers having contracted load above 75 kW/88 kVA and receiving supply at 132 kV and above, the consumer shall receive a rebate of 7.5% on the Energy Charge.

(v) All voltages mentioned above are nominal rated voltages.

(vi) No rebate or surcharges would be applicable on consumers having pre-paid connections.

11. Low Power Factor Surcharge (not applicable to Domestic, PTW categories and also to other categories having kVAh based Tariff)

(i) On the consumers without Electrnnic Tri Vector Meters who have not installed shunt capacitors of appropriate ratings and specifications, a surcharge of 5% on the current energy charges shall be levied.

(ii) On consumers with Electronic Tri Vector Meters, a surcharge of 5% on current energy charges will be levied for having power factor below 0.85 and upto 0.80 & a surcharge of 10% of current energy charges will be levied for having power factor below 0.80.

(iii) No surcharge would be applicable on consumers having pre-paid connections.

12. Excess Load/Demand Penalty (Not applicable to Domestic, Snow bound and PTW categories)

In case of consumers where electronic meters with MDI have been installed, if the maximum demand recorded in any month exceeds the contracted load/demand, charges for· such excess load/demand shall be levied equal to twice the normal rate of fixed/demand charge as applicable. Such excess load penalty shall be levied only for the rnonth in which maximum demands exceeds contracted load. However, no excess load penalty would be applicable on consumers having pre-paid connections.

Example:

(i) For consumers where fixed charges on the basis of contracted load/demand have been specified:

Contracted load 30 kW, Maximum Demand 43 kW,

Excess Demand 43-30=13 kW, Rate of Fixed Charges= Rs. 70/kW

Fixed Charges for contracted load = 30 x 70=Rs. 2100

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Fixed Charges for excess load = 13x (2 x70) =Rs. 1820

Total Fixed Charges= 2100 +1820= Rs. 3920

(ii) For industrial consumers billed on billable demand:

Contracted demand 2500 kVA, Maximum Demand 2800 kVA, Billable Demand =2800 kVA

Excess Demand =2800-2500=300 kVA, Rate of Demand Charges= Rs. 445/kVA

Demand Charges for contracted demand =2500 x 445=Rs. 1112500

Demand Charges for excess demand= 300x (2 x 445) =Rs. 267000

Total Demand Charges= 887500+213000= Rs. 1379500

13. Single Point Bulk Supply for Domestic, Non-Domestic and Mixed Load Categories

(i) Single Point Bulk Supply connection shall only be allowed for Sanctioned/Contracted Load above 75 kW with single point metering for further distribution to the end users. However, this shall not restrict the individual owner/occupier from applying for individual connection.

(ii)The person who has taken the single point supply shall be responsible for all payments of electricity charges to the Licensee and shall charge/ collect not more than 5% additional charge on the tariff as specified for single point bulk supply of the concerned categor_y_of consumers. The 5% additional charge shall be towards facilitating supply of electricity to the individual members to recover its expenses towards supply of electricity_,_.Jlli;tribution loss, electrical maintenance in its supply area, billing, accounting and audit etc. The Licensee shall ensure that tariff being charged from end consumer does not exceed as specified hereinabove.

(iii) The person who has taken the single point supply shall also be deemed to be an agent of Licensee to undertake distribution of electricity for the premises for which single point supply is given under seventh proviso to section 14 of the Electricity Act, 2003 and distribution licensee shall be responsible for compliance of all provisions of the Act and Rules & Regulations thereunder within such area.

(iv) Single Point Bulk Supply under "Domestic" shall only be applicable for Residential Colonies/Residential Multi-storeyed Buildings including common facilities (such as Lifts, Common Lighting and Water Pumping system) of such Residential Colonies/Residential Multi-storeyed Buildings. In case these Residential Colonies/Residential Multi-storeyed Buildings also have some shops or othe,- commercial establishments, the tariff of Mixed Load shall be applicable for such premises subject to conditions provided in the Rate Schedule of Mixed Load Category.

(v) Single Point Bulk Supply Under "Non-Domestic" shall only be applicable for Shopping Complexes/Multiplex/Malls.

14. Rounding off

(vi) The contracted load/demand shall be expressed in whole number only and fractional load/demand shall be rounded up to next whole number.

Example:

Contracted/Sanctioned Load of 0.15 kW shall be reckoned as 1 kW for tariff

--------------

- _,_,_,_,_,,, _____ ._, ___ ,, ____ . ___ ,,_,,_ ----·-----------·-

purposes. Similarly, contracted/sanctioned load of 15.25 kW/kVA shall be

taken as 16 kW/kVA.

(vii)AII bills will be rounded off to the nearest rupee.

15. Other Charges Apart from the charges provided in the Rate of Charge and those included in the

Schedule of Miscellaneous Charges, no other charge shall be recovered from the consumer unless approved by the Commission.

129

-------

B.Ta riffs

RTS-1: Domestic ·-

1. Ap plicability

This schedule shall apply to supply of power to:

(i) Residential premises (including premises of Depa Pensioners of UPCL, PTCUL and UJVN Ltd.) for ligh domestic purposes including common facilities (s

rtmental Employees & t, fan, power and other uch as Lifts, Common

Lighting and Water Pumping system)

ial Colonies, Residential (ii) Single Point Bulk Supply above 75 kW for Resident Multi-storeyed buildings where energy is exclusiv purpose including common facilities (such as Lifts Water Pumping system) of such Residential Co

ely used for domestic , Common Lighting and Ion i es/Residential Multi-

storeyed Buildings

, Church, etc. (only for of worship which have Hall, Dormitories, etc.

mises of Departmental

(iii) Places of worship, i.e. Mandir, Masjid, Gurudwara standalone places of worship and not for the places other facilities such as Dharamshala, Community attached with it)Residential premises(including pre Employees & Pensioners of UPCL, PTCUL and UJVN L and other domestic purposes including common f Common Lighting and Water Pumping system)

td.) for light, fan, power acilities (such as Lifts,

having contracted load upto 2 re using some portion of

(This rate schedule shall also be applicable to consumers kW as also consumption upto 200 kWh/month and who a

ernises mentioned above for non-domestic purposes. Howe or such premises is above 2 kW or consumption is more he entire energy consumed shall be charged under the ap such load is segregated and separately metered.)

the pr load f then t unless

2. R ate of Charge

Description

1) Do mestic

1.1) Li ~·

Below kW an

1.2) 0

fe line consumers

Poverty Line and Kutir Jyoti having load up to 1 d consumption up to 60 units per month

ther Domestic Consumers

Up to 100 units per month

Above 100 units per month

2) Sin gle Point Bulk Supply

ver, if either contracted than 200 kWh/month,

propriate Rate Schedule

Fixed Charges*

8.00 1 Rs/Co n/Month

75 Rs/C on/Month

135 Rs/ Con/Month

85 Rs/ l<w/Month

Energy Charges

1.90 Rs/kWh

3.26 Rs/kWh

5.25 Rs/kWh

4.85 Rs/kWh *Fixed Charges in case of other domestic consumers for the month sha II be charged at the rates

ent to the total consumption in the month. equival

Gy/ (//

130

---- ----- ·-----.. ~--·-·-·-·----··-·--·----~-- ----- - --·"- ' '

1----RTS-1A: Snowbound

1. Applicability

This schedule shall apply to supply of power to:

(i) Domestic and non-domestic consumers in snowbound areas.

(ii) This Schedule applies to areas notified as snowbound/snowline areas by the

concerned District Magistrate.

2. Rate of Charge

Descri tion f-cc-c------= 1) Domestic

Fixed Char es

2) Non-domestic up __ t~o~l~k~W~--------J 25 Rs/Con/Month c---~~--------j

3) Non-domestic more than lkW & up to 4 kW

4) Non-Domestic more than 4 kW 40 Rs/Con/Month 3.51 Rs/kWh =~=~~~-----~~=~=~==~~====~~ 3. All other conditions of this Schedule shall be same as those in RTS-1.

131

----- ··--·--·

RTS-2: Non-Domestic

1.Applicability

This schedule should apply to supply of power to: 1.1 (i) Government/Municipal Hospitals

(ii) Government/Government Aided Educational Institutions (iv) Charitable Institutions registered under the Income Tax Act, 1961

and whose income is exempted from tax under this Act 1.2Small Non-Domestic Consumers with connected load upto 4 kW and consumption

upto SO units per month. 1.30ther Non-Domestic Users including single point bulk supply above 75 kW for

shopping complexes/multiplex/malls including common facilities (such as lifts, common lighting and water pumping system). Independent Advertisement Boards/Hoardings - All commercial (road side / roof top or on the side of the buildings etc.) standalone independent advertisement hoardings such as private advertising sign posts/ sign boards/ sign glows/flex that are independently metered through a separate meter.

2. Rate of Charge

S. No. Description Fixed Energy

Charges charges

(i) Government/Municipal Hospitals (ii) Government/Government Aided Educational Institutions (iii) Charitable Institutions registered under the Income Tax Act, 1961 and whose income is

1.1 exempted from tax under this Act

Rs. 90.00 (a) Up to 25 kW /kW

Rs. 5. 00 /kWh

Rs. 100.00 Rs. 4.80 (b) Above 25 kW /kVA /kVAh

Other Non-Domestic Users Small Non-Domestic Consumers with contracted load up to 4 kW and consumption up to 50 units Rs. 80/kW Rs. 4.85/kWh oer month* ·~

(b) Others up to 25 kW not covered in 1.2(a) Rs. 90.00 Rs.6.45/kWh

1.2 kW above

- ------ ------·-Rs.90.00 Rs. 6.15

( c) Above 25 kW /kVA /kVAh

1.3 Single Point Bulk Supply** Rs. 90/ kVA Rs. 6.20/

kVAh * If consumption exceeds 50 umts/month, then on the entire energy consumed tariff as per sub-category .1.2(b) shall be charged ** For loads above 75 l<W for shopping comp/exes/multiplex/malls

3. Other Conditions 3.1 ToD Meters shall be read by Meter Reading Instrument (MRI) only with

complete dump with phasor diagram, Tamper Reports, full load survey reports etc. shall be downloaded for the purpose of complete analysis.

3.2AII consumers above 25 kW shall necessarily have ToD Meters.

~t --- __L _____ ~

132

-·---------------------- --------- -- -- -·-- -------------------------

3.3 No meter shall be read at zero load or very low load. Licensee shall carry appropriate external load and shall apply the same, wherever, necessary to

take MRI at load.

3.4Copy of MRI Summary Report shall be provided along with the Bill. Full MRI Report including load survey report shall be provided on demand and on

payment of Rs. 15/ Bill.

133

---------·----------

RTS-3: Govt. Public Utilities -----------1. Applicability

This schedule shall apply to supply of power to:

(i) Public lamps including street lighting system, traffic control signals, lighting of

public parks, etc. The street lighting of Harijan Bastis and villages are also

covered by this Rate Schedule.

(ii) State Tube wells, World Bank Tube wells, Pumped Canals and Lift irrigation

schemes, Laghu Dal Nahar etc.,

(iii) Irrigation system owned and operated by any Government department.

(iv) Public Water Works, Sewage Treatment Plants and Sewage Pumping Stations

functioning under Jal Sansthan, Jal Nigam or other local bodies and Plastic

Recycling Plants.

2. Rate of Charge

Category Fixed Charges* Energy Charge ------+----------,

Urban (Metered) Rs. 100/kVA/month Rs.5.80/kVAh ------'------'---------"

Rural (Metered) Rs. 90/kVA/month Rs.5.80/ kVAh -~--------·-.... _,_ ------'-----'------"

* The Urban and Rural differentiation will apply only for supply of power to 1(1) & 1(iv) above.

3. Maintenance Charge for Public Lamps

In addition to the "Rate of Charge" mentioned above, a sum of Rs. 10/- per light point per month shall be charged for operation and maintenance of street lights covering only labour charges where all material required will be supplied by the local bodies. However, the local bodies will have the option to operate and maintain the public lamps themselves and in such case no maintenance charge will be charged.

4. Provisions of Street Light Systems

In case, the maintenance charge, as mentioned above, is being charged then the labour involved in the subsequent replacement or renewals of lamps shall be provided by the licensee but all the material shall be provided by the local bodies. If licensee provides material at the request of local body, cost of the same shall be chargeable from the local body.

The cost involved in extension of street light mains (including cost of sub-stations if any) in areas where distribution mains of the licensee have not been laid, Will be paid for by the local bodies.

134

L_ ___________ _

RTS-4: Private Tube Wells/ Pumping Sets -1. Applicability

This schedule shall apply to supply of power to private tube-wells/pumping sets for irrigation purposes and for incidental agricultural processes confined to chaff cutter, thrasher, cane crusher and rice huller only. However, the tariff applicable for RTS-4 shall only be applicable if such incidental agricultural processes are being carried out for agricultural produce of the connection sanctioned for irrigation purposes.

2. Rate of charge

Category

RTS 4: PTW (Metered)

Fixed Charges Rs. /BHP/Month

Nil

3. Payments of bills and Surcharge for Late Payment

Energy Charges Rs. /kW~h--1

2.15

The bill shall be raised for this category twice a year only, i.e. by end of December (for per-iod June to November) and end of June (for period December to May). The bill raised in December may be paid by the consumer either in lump-sum or in parts (not more than four times) till 30th April next year for which no DPS shall be levied. Similarly, bill raised in June may be paid by 31st October without any DPS. In case consumer fails to make payment within the specified dates, a surcharge @ 1.25% per month for the period (months or part thereof) shall be payable on the outstanding amount.

135

\

~-----------,-------------------------------------------------~

RTS-4A: Agriculture Allied Activities

1. Applicability

This schedule shall apply to supply of power for use in nurseries growing plants/saplings, polyhouses and other units growing fiowers/vegetables and fruits including mushroom cultivation which doesn't involve any kind of processing of product except for storing and preservation.

2. Rate of charge

Category Fixed Charges Energy Charges

Rs. /BHP/Month Rs. /kWh RTS 4(A): Agricultural

Nil 2.15 Allied Services

0-} 136

----~·----~-----

RTS-5: LT and HT Industry

1.Applicability

This schedule shall apply to supply of power to: (i) Industries and /or processing or agro-industrial purposes 1 power loom as

well as to Arc/Induction Furnaces, Rolling/Re-rolling Mills, Mini Steel Plants and to other power consumers not covered under any other Rate Schedule.

(ii) (ii) The vegetable, fruits, floriculture & Mushroom integrated units engaged in processing, storing and packaging in addition to farming and those not covered under RTS-4A shall also be covered under this Rate Schedule.

2.Specific Conditions of Supply

(i) All connections shall be connected with MCB (Miniature Circuit Breaker) or Circuit Breaker/ Switch Gear of appropriate rating and BIS Specification.

(ii) The supply to Induction and Arc Furnaces shall be made available only after ensuring that the loads sanctioned are corresponding to the load requirements of tonnage of furnaces. The minimum load of 1 Tonne furnace shall in no case be less than 400 kVA and all loads will be determined on this basis. No supply will be given for loads below this norm.

(iii) Supply to Steel Units shall be made available at a voltage of 33 kV or above through a dedicated individual feeder only with check meter at sub-station end. Difference of more than 3%, between readings of check meter and consumer meter(s), shall be immediately investigated by the licensee and corr·ective action shall be taken.

(iv) Supply to all new connections with load above 1000 kVA should be released on independent feeders only with provisions as at (iii) above.

Fixed /Demand Description Energy Charge Charge

per month 1. LT Industry having contracted load up to 75kW _(100 BHP)

1.1 Contracted load up to 25 kW Rs. 4.80/kWh Rs.180 /kW/ of contracted load

1.2 Contracted load more than 25 Rs. 4.40 /kVAh Rs. 180/kVA/ of

kW contracted load 2. HT Industry having contracted load

Load Factor# Rs./ above SSkVA/75 kW (100 BHP) kVAh

2.1 Contr·acted Load up to 1000 up to 40% 4.40 Rs.350/kVA of kVA Above 40% 4.75 billable demand

Up to 40% 4.40 2.2 Contracted Load More than Rs. 445/kVA of 1000 kVA Above 40% 4.75 billable demand

--- ~~

* Billable demand shall be the actual maximum demand or 80 % of the contracted load whichever is higher.

137

-------------------------------.. "-

#For tan ff purposes Load Factor(%) would be deemed to be ~

{ Consumption (excluding the energy received through open access) during the billing period}x 100 ________ {

M aximum demand or Contracted Demand whichever is less x No. of hours in the billing period}

Prov ided that in cases where maximum demand during the month occurs in a period n open access is being availed by the consumer, then maximum demand for the

ose of computation of load factor shall be that occurring during the period when pen access is being availed.

whe

purp no o

3.Time of Day Tariff

( i) The rates of energy charge given above for LT industry with load more than 25 kW and HT indystry shall be subject to ToD rebate/surcharge

( ii) ToD Meters shall be read by Meter Reading Instrument (MRI) only with complete dump with phasor diagram, Tamper Reports, full load survey reports etc. shall be downloaded for the purpose of complete analysis and bills shall be raised as per ToD rate of charge.

(ii i) No meter shall be read at zero load or very low load. Licensee shall carry appropriate external load and shall apply the same, wherever, necessary to take MRI at load.

( i v) Copy of MRI Summary Report shall be provided along with the Bill. Full MRI Report including load survey report shall be provided on demand and on payment of Rs. 15/ Bill.

( v) ToD Load shall be as under:

Season /Time of a d

Win ters 01.10 t o 31.03

Sum mers 01.04 t o 30.09

Morning Peak hours

0600-0900 hrs.

Normal Evening Peak hours Hours

0900-1800 1800-2200 h,-s.

hrs. 0700-1800

1800 -2300 hrs. hrs.

Tl 1e, ToD Rate of Energy Charges shall be as under:

For

For LT Industrv Energy Charge during

Normal Hours I Peak Hours I Off-oeak Hours Rs. 4.40/kVAh I Rs.6.60/ kVAh I Rs.3.75/kVAh ----

HT Industr

Off-peak Hours

2200-0600 hrs.

2300-0700 hrs.

Load Factor* -+---'N~o~rm_a_l_H_o_u_rs--+--~-~--+-~~~ k Hours

Uo to ~4~0~0~Yo~------+-~R~s~A~-~4~0~/l~<V~A~h~+---'===~=-+-~=~5/kVAh Abov ~e_4~0~0,l~o ____ ---~_R_s_A_._7_5~/_kV_A_h~---~--~_R_s_.4_.05/kVAh

* Load Factor shall be as defined in Clause 2 above

4.Seaso nal Industries

w here a consumer having load in excess of 18 kW (25 BHP) and ToD meter and pply of energy for declared Seasonal industries during certain seasons or limited avails su

period in

-·-·-·--·---- - --- --

the year, and his plant is regularly closed down during certain months of the

_sL138

r,,,, ---------------~----------------·----~----~

financial year, he may be levied for the months during which the plant is shut down (which period shall be referred to as off-season period) as follows:

(i) The tariff for 'Season' period shall be same as "Rate of Charge" as given in this schedule.

(ii) Where actual demand in 'Off Season' Period is not more than 30% of contracted load, the energy charges for "Off-Season" period shall be same as energy charges for "Season" period given in Rate of Schedule above. However, the contracted demand in the "Off Season" period shall be reduced to 30%.

(iii) During 'Off-season' period, the maximum allowable demand will be 30% of the contracted demand and the consumers whose actual demand exceeds 30% of the contracted demand in any month of the 'Off Season' will be denied the above benefit of reduced contracted demand during that season. In addition, a surcharge at the rate of 10% of the demand charge shall be payable for the entire 'Off Season' period.

Terms and Conditions for Seasonal Industries (i) The period of operation should not be more than 9 months in a financial

year. (ii) Where period of operation is more than 4 months in a financial year, such

industry should operate for at least consecutive 4 months. (iii) The seasonal period once notified cannot be reduced during the year. The

off-season tariff is not applicable to composite units having seasonal and other categories of loads.

(iv) Industries in addition to sugar, ice, rice mill, frozen foods and tea shall be notified by Licensee only after prior approval of the Commission.

5.Factory Lighting

The electrical energy supplied under this schedule shall also be utilised in the factory premises for lights, fans, coolers, etc. which shall mean and include all energy consumed for factory lighting in the offices, the main factory building, stores, time keeper's office 1 canteen, staff club, library, creche, dispensary, staff welfare centres1

compound lighting, etc.

6.Continuous and Non-continuous supply (i) Continuous Process Industry as well as non-continuous process industrial

consumers connected on either independent feeders or industrial feeder can opt for continuous supply. For industrial feeder, all connected industries will have to opt for continuous supply and in case any consumer on industrial feeder does not wish to opt for continuous supply, all the consumers on such feeder will not be able to avail continuous supply. Such Industrial consumers who opt for continuous supply shall be exempted from load shedding during scheduled/unscheduled power cuts and during restricted hours of the period of restriction in usage approved by the Commission from time to time, except load shedding t·equired due to emergency breakdown/shutdown.

(ii) Consumers who are existing Continuous Supply Consumers shall continue to remain Continuous Supply Consumers and they need not apply again for seeking continuous supply. Such consumers shall pay 10% extra energy charges, in addition to the energy charges given above, w.e.f. April 01, 2020 till March 31, 2021. However, in case of any pending dispute with UPCL in the matter of continuous supply on certain feeders, those consumers will have to apply afresh, for availing the facility of continuous supply, by April 30, 2020.

139

(iii) The new applicants for continuous supply of power (including those who are applying afresh as per above) can apply for seeking the continuous supply option at any time during the year. However, continuous supply surcharge for such consumers shall be applicable with effect from May 1, 2020 till March 31, 2021. UPCL shall provide the facility of continuous supply within 7 days from the date of application, subject to fulfilment of Conditions of Supply.

(iv) In case of re-arrangement of supply through independent feeder, UPCL shall provide the facility of continuous supply from the date of completion of work of independent feeder subject to fulfilment of Conditions of Supply and the Continuous Supply Surcharge on such consumers shall be applicable from the date of energisation of aforesaid independent feeder till 31st March 2021, irrespective of actual period of continuous supply option.

(v) In case of a new consumer (new connection) opting continuous supply, 10% extra energy charges as Continuous Supply Surcharge shall be applicable from the date of new connection till 31st March 2021, irrespective of the actual period of continuous supply.

(vi) The existing consumers availing continuous supply option, who wish to discontinue the continuous supply option granted to them earlier, will have to communicate, in writing, to UPCL latest by April 30, 2020 and they shall continue to pay continuous supply surcharge along with the tariff approved in this Order till April 30, 2020. Further, in this regard, if due to withdrawal by one consumer from availing continuous supply option on a particular feeder, supplying to other continuous supply consumers as well, the status of other continuous supply consumers on that feeder is affected, then UPCL shall inform all the affected consumers in writing, well in advance.

(vii) The Continuous Supply Surcharge shall not be applicable on the power procured by the industrial consumers through open access.

(viii) UPCL shall not change the status of a continuous supply feeder to a non­continuous supply feeder.

(ix) UPCL/PTCUL shall take up augmentation, maintenance and overhauling works on top priority, especially in the sub-stations where circuit breakers, other equipment, etc. are in dilapidated condition and, thereby, shall ensure minimisation of interruptions of the continuous supply feeders.

(x) UPCL/PTCUL shall carry out periodical preventive maintenance of the feeders supplying to continuous supply consumers. The licensees shall prepare preventive maintenance schedule, in consultation with continuous supply consumers, well in advance, so that such consumers can plan their operations accordingly.

(xi) The Licensee should show the energy charges and continuous supply surcharge thereon separately in the bills.

?.Demand Charges for HT Industry

If the minimum average supply to any HT Industry Consumers is less than 18 hours per day during the month, the Demand Charges applicable for such HT Industry Consumer shall be 80% of the approved Demand Charges for HT Industry.

----------- -- -------~------------------

RTS 6: Mixed Load ----1. Applicability

This schedule applies to single point bulk supply connection of more than 75 kW

where the supply is used predominantly for domestic purposes (with more than 60%

domestic load) and also for other non-domestic purposes. This schedule also applies to

supply to MES.

2. Rate of Charge

The following rates shall apply to consumers of this category

I Fixed Charges I Energy Charges

[ Rs.110/kW/month l Rs.5.70/kWh

3. Other conditions

Apart from the above, other conditions of tariff shall be same as those for RTS-1

consumers. However, excess load penalty shall be applicable as per clause 12 of General

Conditions of Supply.

141

L

RTS 7: Railway Traction

1. Applicability

This schedule applies to Railways utilizing power for traction purposes.

2. Rate of Charge

Tl1e following rates of energy and demand charge shall apply to this category:

3. Other conditions

Apart from the above, other conditions of tariff shall be same as those for General

HT Industries under RTS-5 consumers except applicability of ToD tariff and surcharge for

continuous supply.

142

----··-----

(A) Temporary Supply

1. Applicability

RTS-8: Temporary Supply

(i) This schedule shall apply to temporary supplies of light, fan and power loads for all purposes including illumination/public address/ceremonies and festivities/functions/ temporary shops not exceeding three months.

(ii) This schedule shall also apply for power taken for construction purposes including civil work by all consumers including Government Departments. Power for construction purposes for any work / project shall be considered from the date of taking first connection for the construction work till completion of the work/ project.

However, use of electricity through a permanent connection sanctioned for premises owned by the consumer for construction, repair or renovation of existing building, shall not be considered as unauthorised use of electricity as long as the intended purpose/use of the building/apartments being constructed is same/permissible in the sanctioned category of the connection.

2. Rate of Charge

The rate of charge will be corresponding rate of charge in appropriate Schedule Plus 25%. The appropriate rate schedule fo1· the temporary supplies for cane crusher upto 15 BHP given for maximum period of four (4) months will be RTS-5.

143

RTS 8: Electric Vehicle Charging System

1. Applicability

a. Applicable to Charging Stations for E-Rickshaw/ E-Vehicle on Single Point Delivery

b. Tariff applicable for charging of batteries of E-Rickshaw / E-Vehicle at premises other

than at Charging Stations meant for the purpose shall be the same as applicable for

the relevant category of connection at such premises from which the E-Rickshaw / E­

Vehicle is being charged.

2. Rate of Charge

The following rates of energy and demand charge shall apply to tl1is category:

Demand Char

144

··-------------"

Schedule of Proposed Miscellaneous Charges

1

2.

3.

d) Maximum Demand CT o erated Meters

e) Tri-vector Meters/ HT Meters with CT/PT Ammeters and Volt Meters S ecia! Meters Initial Testing of Meters

Subsequent testing and insta!!ation other than initial testin Disconnection and Reconnection of supply on consumers request or non-payment of bill (for any disconnection or reconnection. the char e will be 50°/o a. Consumer having load above 100 BHP/75 kW b. Industrial and non-domestic consumers up to 100 BHP/75 kW

,~-----1- c. All other categories of consumers Re lacement of Meters

4

5

a. Installation of Meter and its subsequent removal in case of Tern orar Connections

b. Changing of position of Meter Board at the consumer's re uest Checking of Capacitors (other than initial checkin on consumer's re uest: a. At 400 V / 230 V b. At 11 kV and above

Per meter 50.00 Per meter 75.00 Per meter 170.00

Per meter 350.00

Per meter 1000.00

Per meter~-+----6~5=.o~o~. Per meter 335. 00 Per meter NIL

Per meter BO.OD

Per job 600.00

Per job 400.00

Per ·ob 200.00

Per job 75.00

Per job 100.00

Per ·ob 150.00 Per 'ob 300.00

145

A6: Prayer

1.3 The Petitioner prays that the Hon'ble Commission may:

a) admit the accompanying Tariff Petition;

b) approve true-up of expenses and revenue for FY 2018-19 based on the

audited accounts of the said year;

c) approve the Annual Revenue Requirement (ARR) for the FY 2020-21;

d) approve the revision in retail tariffs for FY 2020-21 as proposed;

e) approve the terms and conditions of tariffs and various matters as

proposed in the petition;

f) pass suitable orders for implementation of the tariff proposals for FY 2020-

21 for making it applicable from April 1, 2020 onwards;

g) determine the ARR by taking into account the financial implications of the

various factors as described above

h) condone any inadvertent omissions/errors/shortcomings and permit

Petitioner to add/change/modify/alter this filing and make further

submissions as may be required at future date; and

i) pass orders, as the Hon'ble Commission may deem fit and proper keeping

in view the facts and circumstances of the case.

146

----··--- -- ·---··-------

7: Compliance status of the directives issued by Hon'bie UERC in its Tariff order for FY 2019-20

GROUP A- Regular Compliances

8.1.1 Performance Report

The Commission directs the Petitioner to submit the

1. monthly as we!I as quarterly status report as per the directions of the Commission by 10th of following month/quarter without fail.

2.

8.1.8 Reliability Indices

The Commission directs the Petitioner to submit the monthly report on Reliabi\ity Indices on regular basis.

Monthly/Quarterly, I.e. by 10th of the month/quarter following month/ quarter.

monthly report on Reliability Indices

(i) The commercial performance monitoring report in the prescribed formats for tl1e month of June 2019 has been submitted to the Hon'b\e Commission vide UPCL's letter no. 3201/UPCL/RM/UERC-10, dated 04-10-2019.

(ii) Division wise quarterly targets for NA/NR / IDF/ADF/RDF/Mechanical Meters/Ghost consumers have been submitted to the Hon'ble Commission vide UPCL's letter no. 2553/UPCL/RM/CPM, dated 9-08-2019. These targets are as follows:

NR cases 4.62% 3.21% 2.18% 0.87% IDF cases 2.95% 2.58% 2.24% 2.07% ADF cases 0.00% 0.00% 0.00% 0.00% RDF cases I 2.02% 2.03% 2.03% 2.05% Mechanical 40,064 25,052 11,297 0 Meters

Ghost 0 0 0 .0

Consumers

It is submitted that Steps have been taken at Corporate Office to ensure that the said report is timely submitted to the Hon'ble Commission on regular basis. The report for the month of August, 2019 has been submitted to the Hon'ble Commission vide UPCL's letter no. 3347/UPCL/RM/M-SSM, dated 18-10-2019. The details of SAIFI, SAIDI & MAIFI are as follows:

147

3.

8,2.1 Scrutiny of KCC Data

The Commission directs UPCL to constitute a cell in Monthly i.e. by 15th of the its commercial wing for following month. analysis and monitoring of KCC data including low load factor cases, mete1· tamper cases etc. The Commission directs UPCL to submit the report on analysis and

April, 18 35 23 1120 643 9 7

May, 18 49 29 1631 883 10 8

June, 18 47 33 1326 904 11 11

July, 18 49 35 1350 986 11 11

August, 18 45 31 1303 917 11 11 September, 18 43 30 1704 965 9 8 October, 2018 34 23 1182 762 6 7 November, 27 16 825 462 6 6 2018 December,18 28 19 848 486 6 6 January,19 33 24 1098 654 7 6 February, 19 32 23 1157 658 7 6 March,19 28 20 890 506 7 5 April 1 19 34 25 1244 677 9 6 May,19 48 32 1906 950 11 7

June, 19 49 37 1819 1116 11 9 July,19 63 41 1566 996 30 12 August, 19 43 32 1471 809 11 9

Alter due approval from Hon'ble UERC, UPCL vide its letter no. 1674/UPCL/CE/CCP-Il/14/2018-19 (Mobineers)/Part-(b), dated 01-03-2019 awarded the work for one-year monthly meter data analysis through various reports of 8000 consumers to M/s Mobineers Info Systems Pvt. Ltd., New Delhi. The data analysis shall cover the following attributes:

a. Tamper analysis by way of PT missing, CT short, CT open, CT interchange /reversal, voltage imbalance, current imbalance, neutral disturbed, power failure, magnetic tamper, transactions, 35 KV spark Test, Cover open temper, high voltage/ frequency surges.

b. Percentage slots for which demand is less than a given percentage when demand is available. (Default 5%)

c. Percenta e black out slots when ower is available.

~48

monitoring of KCC monthly basis by every month. 2.25.1.3)

Group B- Quarterly

data on 15th of

(Refer

8.1.9 Voltage wise Cost of Supply

The Commission directs the 4. Petitioner to expedite the Quarterly report

activities with regards to Voltage wise Cost of Supply and submit quarterly report on the status of same.

d. Current month consumption Vs last month consumption or current month consumptlon Vs that of same month last year is less than given percentage (Default 20%).

e. Contract demand violation. f. Number of slots for which power factor is less than or more than or in between for a

given value. g. Consumption vis-a-vis usage index for the industry (process) wise, based on the data

provided. Process wise load factor will be provided to vendor. h. Ratio of Average/ contracted demand, maximum/ contracted demand, average/

maximum demand, average demand shall be calculated for the number of months as specified tlme to time.

i. Double meter /Main meter/ Independent feeder meter/ Net Off meter/ Bi-directional meter/ ABT meter comparison difference of load survey data for every 30 minutes/ 15 minutes slot on per day & per month basis demand and consumption is more than given percentage (Default 3%) for entire months.

j. Consumption comparison of main meter with check meter/other end meter in terms of KWH, KVAH, MO on each & every month is to be complied checked and if difference of main meter w.r.to check meter/other end meter is more /less than the standardised value or as fixed by UPCL the check-out list is to be submitted.

k. Any other comparison, detail, analysis, report etc in desired format of UPCL from time to time for desired period and in desired timeline shall mandatorily be provided by the contractor.

l. Complete analysis of all the consumers' along with reports, recommendations/ comments in deslred formats complete in all respect shall be submitted by bidder not later than 25th of ever month.

(i) The work of metering has been completed at all 33 kV and 11 kV T-points.

(ii) In compliance of dlrectlon issued by Hon'ble Commission, it is submitted that UPCL has evolved a methodology for computation of voltage wise and category wise cost of service which has been submitted to the Hon'ble Commission vide UPCL's letter no. 2719/UPCL/RM/C-15, dated 22-08-2019 seeking in - principle approval of the Hon'ble Commission.

(iii) As per direction of Hon'ble Commission issued in the meeting held on 27-08-2019, UPCL vide its letter no. 3481/UPCL/RM/C-15, dated 31-10-2019 submitted the details of losses on 33 KV industrial feeders under EDD, Bhagwanpur, as follows:

149

8.1.10 Demand Side Management Measures

The Commission directs the 5. Petitioner to submit the

report on various Demand Side Management measures at regular quarterly intervals to the Commission.

Quarterly report

1

2

3

4

132 KV Chudiyala

33/11 Raipur

132

KV

KV Sl1agwanpur

33/11 KV Raipur

Substation, 33 KV Uttaranchal Steel Feeder

Substation, 33 KV Everest Feeder

Substation, 33 KV NPIL Feeder

Substation, 33 KV Shiv Shakti Feeder

2.33%

3.80%

3.53%

0.13%

2.19% 2.60%

0.79% 0.78%

-3.23% -0.92%

0.11% 0.27%

(i) Upto March, 2017, 38.845 lacs LED bulbs were distribution in the State. Out of which 2.02 lacs

7W LED bulbs to BPL consumers & 1.98 lacs 7W LED bulbs to other domestic co'nsumers, having consumption upto 100 units have been distributed on subsidized rates.

(ii) Distribution of 9W LED bulbs, 20W LED Tube Light & SOW Energy Efficient Ceiling Fans has also been initiated ln the State w.e.f. 10th April, 2017 onwards. The status of distribution is as

follows:

73771 899 376

June, 17 89892 1865 688

Jul 17 51633 1999 141

Au ust, 17 93605 3914 711

Se tember 17 95476 4885 595

,) !'-~150

8.1.16 NB & SB Cases

The Commission directs the Petitioner to liquidate and Quarterly report

6, finalise at least 5% of the NB/SB cases in each

I quarter and submit quarterly report before the Commission. In absence of the same, action under the

October, 17 November 17 December 17

November, 18 December, 18 Januar , 19 Februar ,19

Total

80530 77352 75387

108243 66282

198655 96085 82110 34959 41370

120570 43576 47569 34696 29236 29492 37745 31548 17089 12564 15139 29847 27142 23607 23986

1809532

2487 158 828 37

1544 33 2169 336 1206 137 11636 230

267 51 595 227

2975 783 17 45

181 62 78 20 21 8 31 50 7 0

42 98 2 48 0 0

10 0 8 0 0 0

102 75 12 242 0 39

00 08 38103 5221

(i) UPCL vide its letter no. 1330/UPCL/RM/C-15, dated 29-04-2018 directed all the field officers to comply with thls direction of Hon'ble Commission i.e. liquidation and finalization of at least 5% of NB/SB cases in each quarter.

(ii) The status of NB/SB cases for the month of June,2019 has been submitted to the Hon'ble Commission vide UPCL's letter no. 3201/ UPCL/ RM/ UERC-10, dated 04-10-2019. The said status ls as follows:

Total no. of cases as on 31-03-2018 160669

;±:J 151

•

7.

8.

provisions Act/Rules/Regulations may be Initiated against the Petitioner.

8.1.23 Location of Installation of Meters

The Commission directs the Petitioner to submit quarterly status report with regards to shifting of meters for all divisions to the Commission.

8.2.2 Collection efficiency

The Commission directs UPCL to make efforts to achieve the collection efficiency targets approved by the Commission and a/so submit the details of number of defaulting consumers disconnected and amount of arrears realized within one month

Quarterly report

Quarterly, i.e., within 1 month of the end of each quarter.

No. of cases added during the year 13711

No. of cases finalized during the year 12880

Total no. of cases as on 31-03-2019 161500

No. of cases added 01-04-2019 to 24-08-2019 : 12478

No. of cases finalized 01-04-2019 to 24-08-2019 : 9910 (6.14%)

Total no. of cases as on 24-08-2019 : 173978

UPCL vide its letter no. 1330/UPCL/RM/C-15, dated 29-04-2019 directed a!l the field officers to comply with this direction of Hon'b!e Commission I.e. shifting of the meters to the safer location in or around the premises of the consumers.

(i) Hon'ble Commission vide its Tariff Order dated 27-02-2019 approved the target of collection efficiency for FY 2019-20 as 99.05%.

(ii) In view of additional energy charge approved by the Hon'ble Commission vide Its order dated 25-10-2019 for the period from 01-10-2019 to 31-03-2020, UPCL vide its letter no. 3513/UPCL/RM/L-17, dated 5-11-2019 fixed/revised the division wise targets of billing efficiency, collection efficiency, AT&C Losses and revenue collection for FY 2019-20. The summary of these targets is as follows:

> Input Energy: 14,273.83 MU

> Billed Energy: 1205.03 MU

> Assessment including Electricity Duty, Green Energy: Rs. 7423.27 Cr.

n 1s2 ~

quarter. Cess and Delayed Payment Surcharge

Grau C- within 15 da s to 45 da s

9.

I 8.1.41 Management

Inventory

The Petitioner ls directed to submit the following details within one month of the date of Order failing which appropriate action will be

Within one month of the date of Order i.e. by 3pt March, 2019.

;,.- Collection including Electricity Duty,

Green Energy Cess and Delayed Payment Surcharge: Rs. 7423.27 Cr.

Billing Efficiency; 87.61%

Col!ection Efficiency: 100%

AT&C Losses: 12.39%

Collection per Input Energy: Rs. 5.20 p.u.

(iii) Monitoring of above collection targets is being done at Corporate Office and on the basis of energy received during the previous month, revenue collection targets for the next month are being communicated to the field units by Corporate Office.

(iv) UPCL vide its letter no. 4542/MD/UPCL/I-7, dated 01-05-2019 also fixed the monthly targets of the officers at various levels for checking of consumers, study of consumers as vigilance checks.

(v) For recovery of outstanding arrears, it is submitted that the connections of defaulting consumers are being disconnected and notices under Section 3 & 5 of the Uttarakhand (U.P. Government Electricity undertakings (Dues Recovery) Act, 1958) Adaptation and Modificatlon order, 2002 are being Issued regularly and the same shall be taken-up more promptly for ensuing early recovery of outstanding arrears.

The desired information is as follows:

(i) The list of Inventory as on 31-03-2017 has been submitted to the Hon'ble Commission vide UPCL's letter no. 1670/UPCL/RM/C-14, dated 21-04-2018.

(li) Accounting -policles with respect to measurement of inventory (which ls also mentioned in Pare 7 under Note no. 28 of Annual Financial Statement of UPCL for FY 2017-18) is as under:

{) ~ 153 ~/

a) List of inventory as on 31.03.2017.

b) The accounting

c)

d)

e)

policles adopted in measuring inventories, including the cost formula used;

Basis on which inventories issued: FIFO/LIFO/etc. and reason for choosing the same.

Whether any inventory classification has been carried out by UPCL ln compliance to the direction given by the Commission vide its letter dated 07.05.20187 If yes, the same may be submitted and if no, reason for the same may be furnished?

Whether the inventories are verified physically? If yes, the periodicity of the same, along with the report of last physlcal verification. If physical verification is not being conducted reasons for tl1e same?

1. The Inventory of Stores & Spares are being held both for use in Capital works, and partly for O&M works and not for sale. Therefore, Accounting Standard (AS) 2, "Valuation of Inventories" is not applicable.

2. Stores & Spares at the centralized store are accounted for at Issue Price. Issue price is fixed at in the beginning of the Financial Year on the basis of FOR destination rate (Including all taxes) and Price Variation for the immediately preceding year plus10% annual variation (increasing) and 3% Storage & handling cost of Stores wings. Issues from Centralised stores are valued at Issue Price. At Decentralized stores, the Stores and Spares are accounted for at cost. Issues from Decentralized Stores are valued by using FIFO method. Inventories of Miscellaneous Scrap and empties are not valued being insignificant.

3. Any shortage/excess of materials found during the plwsical verification at the year-end are first shown as material short/excess pending Investigation till the finalization of investigation and thereafter any excess, if established, is shown under the head of income. Similarly, shortages are either recovered from staff concerned or charged to the profit and loss account as the case may be.

4. Shortage/loss due to theft or any other reason are first debited to the head "Misc. Advance" against staff and are shown as Current Assets tlll the finalization of enquiry/settlement of the

case.

(iii) Basis on which inventories are issued:

Stores & Spares at the centralized store are accounted for at Issue Price. Issue Price is chosen in order to ensure/maintain consistency in valuation of issues during the whole accounting year. This also helps in enabling preparation of estimates across all the units of UPCL in a uniform and consistent manner without any variation/deviation. Issues from Decentralized Stores are valued by using FIFO method.

(iv) Inventory classification has not been done in respect to the inventories lying in the stores. Reason of not carrying out inventory classification is simply that It had not being carried out in past in the organization or erstwl1ile UPSEB.

(v) Yes, the centrallzed inventories are physically verified and inventories of all stores and sub store centers against centralized stores wing of UPCL are physically verified once in a financial year.

Ii ct 154 :;.---

10.

f) Practice followed by UPCL to record the inventory count during the intervening period, i.e. between the date of physical verification and close of financial year for the purpose of taking the inventory values in its books of accounts.

8. 2.3 Procurement of Deficit Energy

UPCL ls directed to submit a comprehensive plan as to how it intends to meet the deficit for the next Control Period within one month of the date of Order. (Refer 3.6.14)

Within 1 month from the date of order, i.e. by 3pt March, 2019.

Physical verification reports of all centralized store centers/sub-store centers against store wing of UPCL, as carried out in financial year 2016-17 were submitted to the Hon'ble Commission vide UPCL's letter no. 1670/UPCL/RM/C-14, dated 21-04-2018.

(vi) Day to day record of each inventory transaction is kept at store MIS. Accordingly, at the tlme of each transaction, verification of inventory ls also carried out.

(i) It is submitted that UPCL has prepared projection of demand upto the year 2021-22. Further, in order to cater increasing demand, UPCL has tied up long term PPAs with Central Sector Generating Stations and UJVN Ltd. It ls further to apprise the Hon'ble Commission that apart from catering demand from these long term PPAs any additional demand is being catered by Short Term purchase through DEEP Portal and Exchange only. The year wlse status of projected power procurement is as follows:

Availability Firm Sources

Procurement to meet RPO throu h DEEP Portal

Banking*

Deficit/Surplus

Short Term- Tied UP through DEEP Portal

IEX

Net Deficit(-)/ Sur lus +

12940.44

154.67

206.98

(914.99) 542. 60(Apr to

Jun 19)

372.39

0.00

91.02% 13679.67

1.09%

1.46% 77.09

6.440/o i (815.75)

3.82% 611.81

2.62% 203.94

0.00% 0.00

93.87% 14542.58 97.36%

0.53% 12s.40 I 0.86%

5.600/o (265.84) 1.78°/o

4.20% 199.38 1.33%

1.40% 66.46 0.44

0.00% 0.00 0.00% i

f1; 155

1

8.2.6 Power Purchase Plan to meet the Deficit

The Petitioner is directed to prepare its power purchase plan for the next three years and initiate the bidding process to meet the deficit, if any. The Petitioner is directed to submlt an action plan in this regard within 15 days of the date of Order. The Petitioner is also directed to ensure compliance of the Regulations issued by the Com mission from time to time, failing which any consequent liablllty would be to the account of the Petitioner. (Ref'er 5.5.1)

Within 15 days from the date of order, i.e. by 15th March, 2019.

Group D- Com liance b A ril 30, 2019

*Note: Banking power as shown above is only the premium on the banked energy and is tentative. Moreover~ the returning period of the banked power by UPCL may vary as per the prevailing situation at that time.

(ii) The above plan has been submitted to the Hon'ble Commlssion vide UPCL's letter no. 3481/UPCL/RM/C-15, dated 31-10-2019.

Submission is same as mentioned at para 10 above.

/"'. ;:,t 156 . :;;;..--

1

8.1.20 Billing and Collection System

The Petitioner is directed to complete the '.vorks of bill collection fa::illties and integration of all CSCs in the State latest by April 30, 2019, in absence of which, stern action under the provision::; of the Act/Rules/Regulations Latest by 3Qth ApdJ. 2019 would be initiated against it. Moreover, the Commission directs the Petitioner to make widespread pu:Jlicity/ Advertisement/workshop of the bill collection facilities & list of VLEs operating in the vicinity of various electricity Sub-division/division officers of UPCL across the State.

The status of works for providing consumer facilities at different locations across the state as on 31-08-2018 has been submitted to the Hon'ble Commission vide UPCL's letter no. 3450/UPCL/RMC/M­Misc., dated 12-09-2018. The updated details are as follows:

A: status of construction of Bill Collection Centre:

(i) Package-A (Garhwal Zone): Under this package, Collection centre facilities were to be provided in 52 Centres of 04 Electricity Distribution Circles. At 20 centres the work is completed and ln remaining 23 centres more than 50%work is complete. In 09 centres less than SO% work is complete whereas in remaining centres the work is in progress and completion of 06 centres is expected to be completed by 31.12.2019 and 03 centres by 15-01-2020.

(ii) Package-B (Haridwar Zone): Under this package, Collection centre facilities were to be provided in 22 Centres of 02 Electricity Distribution Circles and all the 22 centres work is completed.

(iii) Package-C (Kumaun Zone): Under this package, Collection centre facilities were to be provided in 65 Centres of 03 Electricity Distribution Circles. At 26 centres the work is completed and in remaining 11 centres the work is in progress and completion of these remaining centres is expected by 31-12-2019. While in remaining 28 centres, contractor has not been turned-up. In this connection, UPCL vide its letter no. 875/C(C&P-1)/27/2017-2018 (Package-CJ/National, dated 27-07-2019 issued notice to the contractor - M/s National Construction 1 Rudrapur to show cause for non-completion of work in tlme. In turn, the contractor vide his letter no. 0/02/NC, dated 28-07-2019 submitted its reply in the matter. Presently, the matter ls under examination in view of the factual position and reply submitted by the contractor. The final decision in the matter shall be taken in due course.

(iv) Package-D (Rudrapur Zone); Under this package, Collection centre facllities were to be provided in 18 Centres of 02 Electricity Distribution Circles. The work has been completed at all the 18 centres.

B: Compliance against bill collection facilities: i. With a view to improve the existing bill collection system, UPCL had flied a petition before the

Hon'b!e Commission for revision of transaction charges of the CSC Limited and reward scheme for VLEs. Hon'b!e Commission vide its order dated 23-03-2018 approved the

ro osal as follows:

157

3

4

s

6

(a) Transaction charges shall be increased from Rs. 4 to Rs. 8 per electricity bill collected by csc.

(b) Reward scheme for CSC VLEs as follows:

From 101 to 200 Nos. Rs. 1 per bill (apart from transaction charges of Rs.

8 From 201 to 3 00 Nos. Rs. 2 per bill (apart from transaction charges of Rs.

8)

From 301 to 400 Nos. Rs. 3 per bill (apart from transaction charges of Rs. 8)

From 401 to 500 Nos. Rs. 4 a art from transaction char es of Rs. 8

Above 500 Nos. Rs. 5 apart from transaction char es of Rs. 8

: ,i. UPCL is taking all the measures to promote the payment of Electricity Bill by the consumers to be paid through the CSC Counters by sending the Bulk SMS to the all consumers whose mobile nos. are registered with UPCL consumer data base.

iii. UPCL is Inviting the llmited quotation tender to print the flex and vinyl sheet boards to fix at all bi!J collection centers. The basic purpose is to create awareness among consumers regarding the services provided by UPCL. Also, the UPCL ls getting printed pamphlets displaying the information regarding the electricity bill payment facility through the CSC without paying any

charges by the consumer.

iv. At the ,level of M/s CSC, the promotional activities are being conducting by the district level manag.ers wl1ich include the awareness of the CSC vendors about the increase in CSC charges and introduction of new incentives/scheme for collection of the Electricity bill payment.

v. District Level Managers of M/s CSC are conducting workshops at the block levels to promote

d] 158 -

13.

8.1.22 Departmental Employees

The Commission directs the Petitioner to submit the bills of all the departmental employees for FY 2017-18 within 2 months of the date of the Order before the Commission.

Within 2 months of the date of the Order i.e. by 30th April 2019.

Within 2 months of the date of the Order i.e. by 30th April 2019.

the services being provided by CSC to the UPCL consumers for payment of electricity bill.

vi. UPCL and M/s CSC both are conducting the promotional activities and making the efforts to increases nos. of transactions. The table of transaction below shows that the no. of transactions and amount collected are increasing every month.

Month

November 18 December, 18 Januar 19 Februar ,19

ust,19 tember,19

Status of CSC Transactions Active CSC Counters

Nos. 605 734 899

1,167 1,162 1,123 1,258 1258 1325 1325 1484 1722 1722 1857 1797 1811

Transaction Transaction Amount Count Nos. Rs. in lakh

10,592 66.41 14,683 100.27 15 962 126.09 18,617 143.92 17,784 143.06 20,416 142.03 24,147 170. 02 23 700 164.38 23,421 170.37 32,806 234.16 20,936 128. 66 31,994 197.85 26,975 190.18 35,438 283.83 31864 285.21 34075 304.23

(i) As per direction issued by the Hon'ble Commission in the meeting held on 27-08-2019, the employee wise details of electricity consumption for the period from 01-01-2018 to 30-06-2019 have been submitted to the Hon'ble Commission vide UPCL's letter no. 3481/UPCL/RM/C-15, dated 31-10-2019.

(ii) The summary details of billing are as follows:

159

Grau

14.

Commission directs the Petitioner to reconcile the figures of departmental employees in the commercial data as well as that claimed for ca)culation of employee expenses and submit the same to the Commission within 2 months of the date of the Order. As regards the concession provided to these consumers, the Petitioner is directed to show the same separately as expenses in its accounts.

liance b Ma 31, 2019 3 Months

8.1.6 Fixed Register

Assets

The Commission directs the Petitioner to submit the Fixed Asset Register

Within 3 months from the date of order, i.e. by 31th May, 2019.

1 Employees and pensioners I 3777 70305 19318351 274.78 80428280 of UPCL

2 Family pensioners of UPCL 993 23441 5360703 228.69 9050264

3 Employees and pensioners 1670 31569 10160942 321.86 43204330 of UJVNL

4 Employees and pensioners 600 10927 4286414 392.28 18296477 of PTCUL

Total 7040 136242 39126410 287.18 150979351

(iii) Presently, we are facing difficulty ln reconciliation of the figures of departmental employees as shown ln Commercial Diary as well as the information maintained in HR Section. However, UPCL is in process to evolve the mechanism for such reconciliation which will be completed in due course

of time.

(iv) Instructions have been issued to the concerned officers to bi/I all the departmental employees and pensioners of UPCL, UJVNL and PTCUL on the basis of rates approved for domestic category from 01-04-2018. They have also been directed to book the concession provided to them fn the books of accounts in a separate head of accounts.

(i)

(ii)

The Fixed Assets Register fo1· the period from FY 2013-14 to FY 2015-16 has been submitted to the Hon'ble Commission vide UPCL's letter no. 1774/UPCL/RM/C-14, dated 28-04-2018. These registers for the FY 2016-17 have . been submitted vide UPCL's letter no. 1199/UPCL/RM/C-14, dated 15-05-2018. Tl1ese registers for FY 2017-18 have been submitted to the Hon'ble Commission vide UPCL's letter no. 3720/UPCL/RM/C-15. dated 25-11-2019.

The Fixed Assets Registers for the period upto FY 2012-13 had already been submitted to the Hon'ble Commission. These re isters were ot pre ared throu h a consultin firm i.e. M/s L.B.

s 160 _.-

updated upto FY 2017-18 within 3 months from the date of this Order.

8.2.11 Analysis of Current Liabilities

The Petitioner is directed to carry out the age-wise analysis of its current liabl!ities outstanding as on 31.03.2018 and based on the ageing analysis

15. determine how much of the same would be required to be discharged and how much excess provision exists in the same so that the same may be reversed and submit the same to the Commission within 3 months from the date of Order. (Refer 7. 5.1. 2)

Within 3 months from the date of order, i.e. by 31t11 May 1 2019.

l6. 8.2.12 Avera e Within 3 months from the

Jha & Co., Chartered Accountants, Kolkata. (iif) The work of preparation of fixed assets register for FY 2017-18 to FY 2019-20 was awarded to

M/s. RSA & Co. Chartered Accountants, on 13-03-2019. The work of preparation of fixed assets register for FY 2018-19 is in progress.

(i) The age wise position of creditors for power purchase as on 31-03-2018 and 31-03-2019 is as follows:

Age 3 to 6 months Rs. 91.35 Cr. Rs. 182.38 Cr.

Age more than 6 months Rs. 1131.67 Cr. Rs. 1427.66 Cr.

Total Rs. 2259.91 Cr. Rs. 3049.60 Cr.

As per direction of Hon'ble Commission in the meeting held on 27-08-2019, UPCL vide its letter no. 3481/UPCL/RM/C-15, dated 31-10-2019 submitted the details of trade payables as on 31-03-2019 having the age more than six months as follows:

UJVNL 52.65 UJVNL - Water Tax 126.31

Cess/Royalty 243.86

State Royal Power Free Power 1004. 84 GRAND TOTAL 1427.66

(i) On the basis of Annual Accounts for FY 2017-18 (Audited) and 2018-19 (Audit) the average

161

The Petitioner is directed to submit within 3 months, an action plan to Improve its collection period. (Refer 7.5.5.1)

date of order, i.e. by 31th May, 2019.

collection period is computed as fol!ows:

2017-18

Receivables for sale of power (Rs. 1521.51. Cr.) x no. of days in a year (365) I annual revenue (Rs. 5781.30 Cr.)

= 96 days

2018-19

Receivables for sale of power (Rs. 1677.87 Cr.) x no. of days in a year (365) / annual revenue (Rs. 6218.61 Cr.)

= 98 days

(ii) With a view to increase the average collection period, UPCL vide its letter no. 3513/UPCL/RM/L-17, dated 5-11-2019 fixed/revised the division wise targets of billing efficiency, collection efficiency, AT&C Losses and revenue collection for FY 2019-20. The summary of these targets ls as follows:

>'" Input Energy: 14,273.83 MU

>- Billed Energy: 1205.03 MU

> Assessment including Electricity Duty, Green Energy: Rs. 7423.27 Cr.

Cess and Delayed Payment Surcharge

> Collection including Electricity Duty,

Green Energy Cess and Delayed Payment Surcharge: Rs. 7423.27 Cr.

> Billing Efficiency: 87.61%

> Collection Efficiency: 100%

> AT&C Losses: 12.39%

0--162

Collection per Input Energy:

(iii) Monitoring of above collection targets is being done at Corporate Office and on the basis of energy received during the previous month, revenue collection targets for the next month are being communicated to the field units by Corporate Office.

(iv) UPCL vide its letter no. 4542/MD/UPCLjI-7, dated 01-05-2019 also fixed the monthly targets of the officers at various levels for checking of consumers, study of consumers as vigilance checks.

(v) For recovery of outstanding arrears, it is submitted that the connections of defaulting consumers are being disconnected and notices under Section 3 & 5 of the Uttarakhand (U.P. Government Electricity undertakings (Dues Recovery) Act, 1958) Adaptation and Modification order, 2002 are being issued regularly and the same shall be taken-up more promptly for ensuing early recovery of outstanding arrears.

Group F- Compliance by June 30, 2019 and/or Submission of Report by July 15, 2019

17,

8.1.4 AT&C Losses

The Commission directs the Petitioner to submit the division wise target distribution losses for FY 2018-19 and actual distributfon losses for FY 2018-19 by June 30, 2019.

The Commission directs the Petitioner to submit the division wise actual collection efficiency achieved durin FY 2018-19

Latest by 3Qth June, 2019

Latest by 3Qth June, 2019

(i) The desired Information has been submitted to the Hon'ble Commission vide UPCL's letter no. 2720/UPCL/RM/C-15, dated 22-08-2019.

(ii) The division wise targets of distribution losses and AT&C !asses for FY 2018-19 were fixed vide UPCL's letter no. 1660/UPCL/RM/N-42, dated 20-04-2018 and no. 4412/UPCL/RM/N-42, dated 14-12-2018. The summary of these targets vis - a -vis actual is as follows:

~ 163 /

8.1.13 Replacement of Improperr Non-Functionalr Stop/Stuck up defective or IDF Meters

The Petitioner is directed to restrict percentage defective meters (IDF) to 3% ln plain as well as ln hilly areas of the State by 30.06.2019, failing which the concerned Chief Engineer (Distribution), Superintending Engineer (Distribution), Executive Latest by 3Qth June 2019 Engineer (Distribution) & Executive Engineer (Test) shal! be held responsible for non-compllance of the Commission's directions and appropriate action under the Act/Rules/Regulations would be initiated. The Commission directs Company Secretary of UPCL to issue a copy of these directions to concerned officers, as mentioned hereinabove, for information and necessary compliance.

(i) UPCL vide its letter no. 1330/UPCL/RM/C-15, dated 29-04-2018 had directed all the field officers to comply with this direction of Hon'b!e Commission _i.e. to restrict percentage of IDF meters to 3%. Later on, division wise quarterly targets of IDF meters were fixed as follows:

•• l l!ii

2.58%

(li) The above ta~ets were submitted to the Hon'ble Commission vide UPCL's letter no. 2553/UPCL/RM/CPM, dated 9-08-2019.

(iii) The status of defective meters is as follows:

As on 31-03-2018 As on 31-03-2019 As on 31-10-2019

: 3.37% : 3.52% : 3.71%

20.

8.1.14 Replacement of Mechanical Meters

The Commission directs the Petitioner to ensure complete replacement of Mechanical Meters by Electronic Meters well before 30.06.2019, failing which the concerned Chief Engineer (Distribution), Superintending Engineer (Distribution), Executive Engineer (Distribution) shal\ be held responsible for non­compliance of tfie Commission's directions and Latest by 30th June 2019 appropriate action under the Act/Rules/ Regulations would be initiated. The Commission directs Company Secretary of UPCL to issue a copy of these directions to concerned officers, as mentioned hereinabove, for information and necessary compliance.

8.1.21 Transfer of Distribution Business from UJVN Ltd. to UPCL

The Commission directs the

Latest by 15th July, 2019

(i) UPCL vide its letter no. 1330/UPCL/RM/C-15, dated 29-04-2018 directed all the field officers to comply with this direction of Hon'ble Commission i.e. to ensure complete replacement of mechanical meters by electronic meters before 30-06-2019. Later on, division wise quarterly targets for replacement of mechanical meters were fixed as follows:

(ii) The above targets were submitted to the Hon'ble Commission vide UPCL's letter no. 2553/UPCL/RM/CPM, dated 9-08-2019.

(iii) The status of mechanical meters is as follows:

(i)

(ii)

As on 31-03-2018 As on 31-03-2019 As on 30-06-2019

71,382 : 48,224 : 38,786

Hon'ble UERC initiated Suo - moto proceedings in the matter on 19-06-2018 under Section 142 and Section =146 read with Section 149 of The Electricity Act, 2003 for violation of Section 12(b) of the Electricity Act, 2003 and non-compliance of the directions of the Commission issued vide its Tariff Order dated 29.03.2017.

Giving final opportunity, the Hon'ble Commission directed the Managing Directors of both the

~ 165

-~

Petitioner to complete the taking over/handing over of balance 382 connections by June 30, 2019 and submit the compliance report in the matter by July 15, 2019, falling which appropriate action shall be initiated against the concerned Nodal Officers responsible for the same in accordance with the provisions of the Act/Regulations.

utilities to personally ensure the compliance in to latest by 30.09.2018 and submit compliance report before the Commission latest by 10.10.2018.

(iii) Concerned Superintending Engineer (Distribution) has been directed to take action in the matter.

The compliance in the matter has been submitted to the Hon'ble Commission vide UPCL's Jetter no.

3841/UERC/UJVNL, dated 17·10·2018. The updated status in the is as follows:

In 1st Phase 131 nos. connections under Dakhpathar Circle have been transferred and accordingly billing of the same have been started.

1. In Koti Colony 30 nos. consumers have been transferred and metered. Energy is also

being accounted for. 2. In Dhakrani region 12 nos. consumers have been transferred which were outside the

premises of Dhakrani UJVN Ltd. and have been connected with UPCL network. 3. In Dhal'tpur region 114 nos. consumer have been transferred & metered, and their

billing has been started. 4. In Kulhal region 32 nos. consumer have been transferred & metered, and their billing

has been started. 5. In Dakpathar region 1450 nos. consumers have been transferred & metered and their

billing has been started. 6. Energy meters at 11/0.4 Kv S/s for JMR to assess the energy transferred to UPCL has

been installed at following feeders:

(a) Kati Colonv (b) Kui11al Irrigation Colony (c) Dhalipur Irrigation Colony (d) Lower Lakhwar Colony Dakhpathar

(e) Sub-Station No. 03 of Dakhpathar

Further to inform that UPCL has taken over all the 1769 connections about which the requisite details are provided by UJVN Ltd. and for remaining consumers it 'rs ensured that the same will be taken care of as and when UJVN Ltd. will provide the necessary documents. In this connection, UJVN Ltd. has been intimated vide letter no. 1371/EDDV/UJVNL dt. 30.05.2019 and has also been requested to

Grou

8.2.9 Replacement of Mechanical Meters

The Commission directs the Petitioner to ensure complete replacement of Mechanical Meters by Electronic Meters well before 30.06.2019, failing which the concerned Chief Engineer (Distribution), Superintending Engineer (Distribution), Executive Engineer (Distribution) shall be held responsible for non­compliance of the Commission's directions and appropriate action under Latest by 30th June, 2019 the Act/Rules/ Regulations would be initiated. The Commission directs Company Secretary of UPCL to issue a copy of these directions to concerned officers, as mentioned hereinabove, for info1·mation and necessary compliance. (Refer 7.2.2.1)

liance b Au ust 31, 2019 6 Months

8.1.7 Bad &Doubtful 22. Debts

provide the details of the remaining consumers to expedite the transfer process.

( i) UPCL vide its letter no. 1330/UPCL/RM/C-15, dated 29-04-2018 directed all the field officers to comply with this direction of Hon'ble Commission i.e. to ensure complete replacement of mechanical meters by electronic meters before 30-06-2019. Later on, division wise quarterly targets for replacement of mechanical meters were fixed as follows:

(ii)

(iii)

The above targets were submitted to the Hon'ble Commission vide UPCL's letter no. 2553/UPCL/RM/CPM, dated 9-08-2019.

The status of mechanical meters rs as follows:

As on 31-03-2018 As on 31-03-2019 As on 30-06-2019

71,382 : 48,224 : 38,786

1. In compliance of direction issued by the Hon'ble Commission, UPCL floated the tender for "Engagement of consultant for Audit of Receivables for Sale of Power" which was published in the newspapers on 16-10-2018. Al\ the 41 distribution

167

The Commission directs the Petitioner to submit the audit report" of receivables identifying and classifying the same in detail within 6 months from the date of this Order. The Commission sl1all consider writing off of bad debts only upon submission of the same at the time of truing up.

I s.2.s Bad and Doubtful Debts

23. The Commission directs UPCL to submit the list of industries (both LT &HT) on whom the arrears are due having age more than 5

Within 6 months from the date of order, i.e. by 31th August, 2019

Within 6 months from the date of order1 i.e. by 3i5t August, 2019.

Within 6 months from the date of order, i.e. by 3pt August, 2019.

divisions were covered under the tender.

2. The tender was initially scheduled to be opened on 6-11-2018, however due to lack of sufficient participation the part - 1 of the tender was opened on 30-11-2018. Only two CA firms submitted their bid i.e. M/s R. K. Patel & Co. and M/s Singh Agarwal & Associates, Lucknow and the part - 1 of both the bidders was opened but only

one firm i.e. M/s Singh Agarwal & Associates1 Lucknow qualified and the firm was issued Lo! vide UPCL's letter no. 259/ UPCL/ CE/CCP-Il/22/2018-19(Singh), dated 24-06-2019.

3. M/s Singh Agarwal & Associates, Lucknow vide his letter dated 09-07-2019 shown his inability to perform this project and accordingly UPCL vide its O.M. No. 401/UPCL/CE/CCP-Il/22/2018-19, dated 05-08-2019 finally scrapped the above tender.

4. The matter was discussed ln the meetings of the Audit Committee and tl1e Audit Committee in the meetlng held on 19-06-2019 inter-alia, directed as follows in the matter:

"Audit of Receivables of five divisions with largest receivables should be conducted by some Internal Auditors. This should be effectively monitored, and action taken be reported by Sep. 2019."

5. Tendering process was again initiated and UPCL vide letter no. 2867/UPCL/RM/N-20, dated 06-02-2019 awarded the work of Audit of Receivables in respect of the five distribution divisions having largest receivables as on 31-03-2019. The work has been targeted to be completed within three months.

(i) Concerned officers have been asked to provide the desired information vide letter no. 1330/ UPCL/RM/C-15, dated 29-04-2019.

(ii) Arrears against Railway Traction as on 31-03-2019 are of Rs 18. 14 lakh.

(iii) The connection wise details in respect of Government Connections like Public Lamps, Public Water Works and Government Irrigation are being collected from the field units and based on these details GoU has been requested for payment of the electricity dues to UPCL. During

i' ?--168

UPCL is also directed to reconcile the dues pending with railways within 6 months of the date of the Order and submit the comp!lance before the Commission.

UPCL is also directed to raise the issue of pending dues on Government connections like Public Lamps, Public Water Works and GIS and settle the dues before the end of FY 2019-20.

UPCL ls also directed to submit the consumer wlse details of bad debts written off within one month from the end on each quarter. (Refer 4.2.3)

Before the end of FY 2019-20

Within 1 month from the end of each quarter.

Grau tember 30, 2019

8.1.12 Status of NA/NR, IDF/ADF/RDF

The Commission directs the 24. Petitioner to reduce the

percentage NA/NR cases to below 2% in the entire State latest by 30.09.2019, failing which the concerned Chief Engineer

Latest by 30th September 2019

Government Irrigation System

Public Water Works

Total 289.13

(i) UPCL vide its letter no. 1330/UPCL/RM/C-15, dated 29-04-2018 had directed all the field officers to comply with this direction of Hon'ble Commission i.e. to restrict percentage of IDF meters to 3%. Later on, division wise quarterly targets of NA/NR cases were fixed as follows:

169

25.

(Distribution), Superintending Engineer (Distribution), Executive Engineer (Distribution) & Executive Engineer (Test) shall be held responsible for non-compliance of the Commission's directions and appropriate action under the Act/Rules/ Regulations would be initiated. The Commission directs Company Secretary of UPCL to issue a copy of these directions to concerned officers, as hereinabove, information and compliance.

mentioned for

necessary

8.1.40 Conductor Augmentation

The Petitioner is directed to identify such feeders/spans \Vhere the power distribution network is on GI wire and replace them with the ACSR or better conductors latest by 30.09.2019 and submit a compliance report under affidavit on the same.

The Petitioner is also di1·ected to prepare and submit an action Ian for

Latest by 30th September, 2019

Latest by 30th June, 2019

(ii) The above targets were submitted to the 2553/UPCL/RM/CPM, dated 9-08-2019.

Status of NA/NR cases are as follows

As on 31-03-2018 3.54% As on 31-03-2019 4.25% As on 31-10-2019 3.75%

4.64% 4.16% 4.73%

(i) UPCL vide its letter no. 1330/UPCL/RM/C-15, dated 29-04-2018 directed all the field officers to comply with this direction of Hon'ble Commission i.e. to identify such feeders/spans where the power distribution network is on GI wire and replace them with the ACSR or better conductors.

(il) Most of the places have already being identified and approval for execution of work has been given to the field units as per details mentioned hereinbelow:

1. EDD, Pauri

2. EDD, Kotdwar

3. EDD, Ramnagar

4. EDD, Tehri

5. EDD, Vikasnagar

6. EDD, Sitarganj

n ~ 170

26.

checking and refurbishment of protection systems at various 33/11 kV substations latest by 30.06.2019.

8.2.10 Energy Audit

The Petitioner is directed to provide/maintain the

1 metering system at each feeder, 'T' points, DTs and consumers in its distribution network for effective energy auditing and accounting. The Petitioner is directed to submit compliance report in this regard by 30.09.2019, failing which appropriate action may be taken against the Petltioner in accordance with the Act/Rules/Regulations. (Refer 7.3)

Latest by 3Qth September, 2019

7. EDD, Pithoragarh

(i) Metering has been completed at all 33 kV substations upto 11 kV and are being maintained.

(ii) 11.602 DTs have been metered under IPDS/R-APDRP scheme and are being maintained.

Grou I- Compliance to be submitted a Ion with next Tariff Petition

8.2.7 Details for changing the threshold level for

27. applicability of Along with kVah based tariff Petltion. for LT Industry and Non-Domestic

next Tariff

In the ARR and Tariff Petition for FY 2020-21, UPCL has not proposed such conversion from Kwh to kVAh billing.

171

28.

The Commission directs the Petitioner to submit the complete detalls for changing the threshold level for applicablllty of kVAh based tariff for LT Industry and Non-Domestic category including consumption in kWh and kVAh, revenue assessed from such consumers, their Maximum demand, etc. in lts next Tariff Petition and the Commission will take a view based on details submitted by the Petitioner. (Refer 6.1.3.1)

8.2.8 Miscellaneous Charges

The Commission directs the Petitioner to submit the complete details for I increasing the Miscellaneous Charges, i.e. reasons and justification for Increase and annual revenue at current level of miscellaneous charges in the next Tariff Petition. (Refer 6.1.3. 9)

Along with Petition.

next Tariff

The desired information has been provided in the Tariff Petition for FY 2020-21.

I}

~ ;.,-- 172

8.1.36 Impact of VII Pay Commission

The Commission directs the Petitioner to submit the

29 · details of VII Pay

I

I 30.1

I

Commission arrears paid to its employees In FY 2018-19 in the true up of FY 2018-19.

8.1.25 Water Tax

The Petitioner is directed to submit all the relevant information along with the supporting documents for substantiating the actual expenses incurred on account of Water Tax for FY 2018-19 along with its proposals for True up.

Grau J - General

Along with Petition.

Along with Petition.

next Tariff

next Tariff

The complete information in respect of employee expenses has been provided in the Tariff Petition for FY 2020-21 in the chapter of true-up of expenses and revenue for FY 2018-19.

The said information has been provided in the ARR and Tariff Petition for FY 2020-21.

.$ 173

'/

8.1.2 Sales

The Petitioner is directed to instruct its field offices to carry out the corresponding corrections in sales also in cases where billing is

3 withdrawn. In future if such instance comes to the knowledge of the Commission, punitive action under Section 142 of the Electricity Act, 2003 may be taken against the errant officers of UPCL.

8.1.3 Load Shedding

The Commission directs the Petitioner to obtain the prior approval of the Prior approval Commission for load Commission shedding to be carried out continuously for certain number of hours in a day for 15 or more days.

of the

(ii)

1.

2.

(i) UPCL vide its letter no. 1313/UPCL/RM/C-14, dated 04-04-2018 directed all its concerned field officers to carry out the corresponding corrections in sales (units) In cases where sales/ billing (Rs.) is withdrawn. The instructions to this effect had also been circulated to the field officers

vide UPCL's O.M. No. 392/ ;:iq1cb1fa/31sfr. 3Wf. (:i:rR-~3ITT\'i'r), dated 01-07-2017.

(ii) UPCL vide its letter no. 1330/UPCL/RM/C-15, dated 29-04-2018 again directed all the field officers to comply with the direction of the Hon'ble Commission and special care has been taken at the time of finalization of commercial diary for FY 2018-19.

(iii) Before finalization of commercial diary for FY 2018-19, necessary corrections have been made in the same.

(l) In this connection, it is submitted that no load shedding has been carried out by UPCL in any area continuously for certain number of hours in a day for 15 or mare days. Prior approval of Hon'ble Commission shall be obtained as and when required as per direction of Hon'ble Commission.

It is also relevant to mention here that UPCL has also prepared a policy on power cuts. This

policy was approved by the Board of UPCL in the meeting held on 23-07-2015 and also submitted to the Hon'b)e Commission. The policy is as follows:

*11 ~ I '"1 ci: = ii cITTt men ~ or;fr <'Fl' is!VPn I

men <'Fl' 1JiiT =TITT i'r 31fuq, i?Pr. = ci; ~ 3!~c!T frcn: ~ / fiRRuT ITT ci;

=T or 1?Pr ~ 311q1acb1e1H ft~ (Emegency Conditions) ii = ii ~

~ R"'ffafum- J:IT~ ci, ~ <'Fl' is!VPfr

/1...Y ' 174

8.1.5

33.

Power Purchase Quantum and Cost

2.

3.

4.

5.

~ WJcr • 'PT :flTcr 'i ffl BR ~ ~ ITT qfcq3f'x! ~

~ WJcr • 'PT :flTcr ffl qfcq ~ ~ ~ ITT ~

::,11~'1fl1q5 'J'fUT[ 17cf = ~ cfi 1,c."l:f ~ ~ 'PT ~ R'1 cfi C/il-il1il5lc1 17cf "\i'i .Afrrrm q\'\ ~ 31lc1"1il5cil cfi ~ ~ (YRilli'FI) &R1 WR-T ~ q\'\

~ 'ff fwrr ;:;nit,n I -mq cfi cyq5 ~ q\'\ 3nfsr it 3f'x! AfiJmf q\'\ ~ it 3Tls!'rfi'rq, 'J'fUTf ~ ~ q;i\crr c/i fwl m~ ~ ~ I

3. wn ~;mci ,'4M c'fm ~ imNi 'ff i:rrNa 3RClclTi'i 17ci ~ ~o1-'f 1:l"'i: ~ WJc[ ~rm '1tt q\'\ ~ I

4. fcr,m ofr ITT it c1, 11,m i:;q; A<Tci ~ it ~ ~ 14 ITTt 'ff 3W[q, '1tt q\'\ ~I

w1T ~ ~ "lW ii ~ 3ITTlcf 18 ~ ~ ~ 31T'lfc\ ":"ji"1f&kl q\'\ ~ I

(i) Necessary approval shall be obtained from the Hon'ble Commission wherever the actual [ quantum and cost of power purchases during any quarter of FY 2018-19 will exceed by more than 5% of the quantum and cost of power purchases as approved by the Hon'ble Commission in its tariff order dated 27-02-2019 for FY 2019-20.

rovided to the

175

Commission, the Petitioner to seek prior approval of the Commission, in case the variation in power purchase quantum or total power purchase cost in any quarter exceeds by more than 5% of the approved power purchase quantum and cost for the respective quarter worked out on pro­rata basis from the total approved quantum and cost for FY 2019-20, failing which, the Commission may disallow power purchases so made while Truing up the ARR for FY 2019-20.

Tl1e Commission directs the Petitioner that it should neither overdraw power at frequency below 49. 90 Hz nor resort to load shedding due to improper procurement planning. Further, any drawal below 49. 90 Hz shall not be allowed by the Commission.

approval Commission

Hon'ble Commission vide UPCL's letter no. 2816/UPCL/UERC/PP details, dated 31-08-2019 as follows:

"Hon'ble UERC vide tariff order dated 27.2.2019 has approved the Quarterly Power Purchase Quantu and Cost for FY 2019-20 as under: -

July-September 3868.84 1365.71 October-December 3670.60 1295.73 January-March 3512.26 1239.84 Total 14663.32 5176.19

As per above details the total quantum and cost of power purchased allowed for the first quarter of FY 2019-20 is 3611. 61 MU & 1274.91 Cr. respectively. Hence total quantum of power and cost allowed in the first quarter, considering the 5% variation as allowed in the tariff order, is 3792.19 MU and 1338. 65 Crore respectively.

During first quarter the details of provisional quantum of power purchased and cost incurred are as follows:

B Power purchased through short term tender in the first quarter 227.40

C Non-solar power procured to fulfil Non-Solar RPO targets 58.51 27.73 D Net Banking Payable -299. 75 0.00 E Net UI -4.99 27.32 F Net Purchase through JEX -197.74 -54.23 G Total 3835.21 1514.05

With regard to the Short-Term Tender purchase as mentioned above at s. no. B, it is to inform that

:I.' I 176 -

1

8.1.11 Deficit/Surplus Power

I The Commission directs the

I Petitioner to bank the

34. surplus energy available

I

during the months of April 2019 to September 2019 and withdraw the same in the months of October 2019 to March 2020.

Hon'bfe Commission vide Tariff Order for Pf 2019-20 has already allowed the purchase in the month of Aprl/1 May and June 2019.

Further with regard to the RPO power as mentioned at C above1 it is to inform that Hon'ble Commission vide Tariff Order for FY 2019-20 has already allowed the purchase of RE Power/REC in FY 2019-20.

It is also to inform to the Hon'ble Commission that UJVN Ltd. is frequently deviating from its day-ahead schedule consequently the actual generations of their plants are not matching with scheduled generation. The unpredicted generation from UJVN Ltd. had adversely affected UPCL. Eventually, on one hand, the generation was sold in JEX at a lower price and on the other hand, UPCL had to bear additional unwarranted financial burden of Rs. 27. 32 Cr. on account of variation in real time generation from UJVN Ltd. Moreover, the average rate of power purchase from the firm sources in the first quarter has been more than the approved rate resulting into higher overall cost against power purchase.

Considering the above facts, Hon'b!e Commission is requested to kindly approve the quantum and power purchase cost in the first quarter of FY 2019-20. "

(i) The banking plan for FY 2019-20 has been submitted to the Hon'ble Commission vide UPCL's letter no. 2348/UPCL/Com/D&A/MD, dated 22-07-2019 and letter no. 3481/UPCL/RM/C-15, dated 31-10-2019. The details of the said banking plan are as follows:

32.40 Actual -130.09 Actual -214.55 Actual

-75.81 Actual -186.00 Actual -118.92 Actual

0.00 Actual November 19 121.22 Actual /Pro· ected December 19 221.29 Pro ·ected Januar 20 297. 92 Pro ·ected Februar 20 182.68 Pro ·ected March 20 76.84 Pro ·ected

Sc 177 \

.

1

8.1.17 Outstanding Arrears

I The Commission directs the ·1 Petitioner to make sincere

35. efforts in mobilizing its ·1 resources throughout tl1e

year for collection of ; Arrears under a structured I receivable management ' programme besides taking

corrective actions a ainst

Apart from above firm banking, UPCL is banking power on day ahead basis under "As and When" Mode and the same will be utilized during deficit month.

(ii) It is also worthwhile to mention here that as on 31-03-2019, energy to the tune of 95.29 MU were balance to be receive from M/s APPCPL and as against the same 37.97 MU have been received in the month of April and May, 2019. The plan to receive the balance energy is as follows:

November 5.60 December 14.56 January 14.56 February 13.63 March 8.97 Total 57.32

(iii) The above energy details have been included "in the bank"ing plan as mentioned at para (i) above.

(i) In view of additional energy charge approved by the Hon'b!e Commission vide its order dated 25-10-2019 for the period from 01-10-2019 to 31-03-2020, UPCL vide its Jetter no. 3513/UPCL/RM/L-17, dated 5-11-2019 fixed/revised the division wise targets of billing efficiency, collection efficiency, AT&C Losses and revenue collection for FY 2019-20. The summary of these targets is as fa/Jaws:

Input Energy: 14,273.83 MU

Billed Energy: 1205.03 MU

Assessment including Electricity Duty, Green Energy: Rs. 7423.27 Cr.

Q.. i;,- 178

8.1.18 Status of KCC Consumers

The Commission directs the Petitioner that KCC

36, consumers having less load factor should be closely monitored and average consumption pattern and abnormality in consumption

attern shou\ d be checked

Cess and Delayed Payment Surcharge

>- Collection including Electricity Duty,

Green Energy Cess and Delayed Payment Surcharge: Rs. 7423.27 Cr.

r Billing Efficiency: 87.61%

r Collection Efficiency: 100%

/'" AT&C Losses: 12.39%

>- Col!ection per Input Energy: Rs. 5.20 p.u.

(ii) Monitoring of above collection targets is being done at Corporate Office and on the basis of energy received during the previous month, revenue co!!ection targets for the next month are being communicated to the field units by Corporate Office.

(iii) UPCL vide its letter no. 4542/MD/UPCL/I-7, dated 01-05-2019 also fixed the monthly targets of the officers at various levels for checking of consumers, study of consumers as vigilance checks.

(iv) For recovery of outstanding arrears, it is submitted that the connections of defaulting consumers are being disconnected and notices under Section 3 & 5 of the Uttarakhand (U.P. Government Electricity undertakings (Dues Recovery) Act, 1958) Adaptation and Modification order, 2002 are being issued regularly and the same shall be taken-up more promptly for ensuing early recovery of outstanding arrears.

Submission is same as mentioned at para 3 above.

SJ/ 179

duly analysed, The Commission also directs the Petitioner to check KCC consumers who are repeatedly exceeding their sanctioned /contracted demand and take corrective action in such cases.

8.1.19 Status of Revenue realisation per unit sold

The Commission directs the Petitioner to ensure that tl1e data furnished in Commerdal Performance Monitoring report should match with its Commercial Diary, i.e. CS-4 data and tile Petitioner should ensure that in all future submissions of Commercial Performance Monitoring reports the Average Realisation Ral-2 should be calculated on the basis of recoveries on account of Realisation Against energy dues only and the realisation shown should exclude recoveries from duties/cess, etc. Further, the realisation against energy dues should clearly bifurcate realisation against current dues & realisation

Formats of Commercial D"rary have been revised so as to include the information as desired by Hon'ble Commission. Now the Information is being provided to the Hon'b!e Commission as per their direction.

Q_ 180 /

38.

against past dues, failing which appropriate action shall be initiated against the Petitioner/Ucensee.

I 8, 1.35 Bad Debt

The Commission directs the Petitioner to account its billing adjustment and writing off the bad debts properly in accordance with the accounting policies.

I s.2.4 Depreciation

The Commission directs the 39. Petitioner to claim

40.

depreciation in line with its practice followed in the accounts. (Refer 4.2.2.1.2)

8.2.13 Collection Efficiency Ratio

The Commlssion directs UPCL to submit a plan to demonstrate as to how it wlll work in the direction of improving its actual collection even d urlng initial quarters during a financial year so that the gap between the actual collection efficienc and the

As per accountlng policies

I Billing adjustment and writing off of bad debts are being accounted for in the accounts in accordance ] with the accounting policy. Further, any amount of billing which has to be withdrawn by UPCL at the direction of Hon'ble Courts/ Forums or if found not correct is adjusted from the provision for bad and doubtful debts. This Is as per accounting practices in other Discerns.

Deprecation in the Tariff Petition for FY 2019-20 had been claimed as per direction of Hon'ble Commission. This practice will also be followed in future.

(i) Hon'ble Commission vide its Tariff Order dated 27-02-2019 approved the target of collection efficiency as 99.05%.

(ii) In view of additional energy charge approved by the Hon'ble Commission vide its order dated 25-10-2019 for the period from 01-10-2019 to 31-03-2020, UPCL vide its letter no. 3513/UPCL/RM/L-17, dated 5-11-2019 fixed/revised the division wise targets of billing efficiency, collection efficiency, AT&C Losses and revenue collection for FY 2019-20. Tl1e summary of these targets is as follows:

,- Input Energy: 14,273.83 MU

,- Billed Energy: 1205.03 MU

I/ 181

collection efficiency approved by the Commission may be brought to minimum. (Refer 7.5.5.2)

r Assessment Including Electricity Duty, Green Energy: Rs. 7423.27 Cr.

Cess and Delayed Payment Surcharge

r Collection including Electricity Duty,

Green Energy Cess and Delayed Payment Surcharge: Rs. 7423.27 Cr.

> Billing Efficiency: 87.61%

r Collection Efficiency: 100%

> AT&C Losses: 12.39%

> Collection per Input Energy: Rs. 5.20 p.u.

(iii) Monitoring of above collection targets is being done at Corporate Office and on the basis of energy received durlng the previous month, revenue collection targets for the next month are being communicated to the field unlts by Corporate Office.

(iv) UPCL vide its letter no. 4542/MD/UPCL/I-7, dated 01-05-2019 also fixed the monthly targets of the officers at various levels for checking of consumers, study of consumers as vigilance checks.

(v) For recovery of outstanding arrears, it ls submitted that the connections of defaulting consumers are being disconnected and notices under Section 3 & 5 of the Uttarakhand (U.P. Government Electricity undertakings (Dues Recovery) Act, 1958) Adaptation and Modification order, 2002 are being issued regularly and the same shall be taken-up more promptly for ensuing early recovery of outstanding arrears.

182

INDEX OF FORMATS

Formats for Distribution

S. No, Format No. Description

1 Form: F-1 Summary of Annual Revenue Requirement

2 E.9rm: F-2.1 Customer Sales Forecast

3 Form: F-2.;:: No of Consumers Forecast

4 Form : F-2 .. ,) Load Forecast

5 Form: F-2.ll Distribution Losses

6 fQr.m: F-2.5 Energy Distribution

7 fQJ:n:i.~Q Availability of Power (Power Purchased at Ex Bus)

8 Form: F-2.7 Detail of UI Charge and Additional UI Charge Payable/ Receivable for Overdrawal / Underdrawal from Central Generating Stations

9 Form: F-2.8 Energy Balance

10 Form: F-2.9 Power Purchase Expenses

11 Form: F-3 Details of Transmission and Load Dispatch Charges

12 Form: F-4 Operations and Maintenance Expenses

13 Form: F- 4.1 Employee Expenses

14 Form: F-4.2 Repair & Maintenance Expenditure

15 FQCm: F-4_._.;l Administration & General Expenses

16 Form: f- 5.1 Statement of Gross Fixed Asset Base & Financing Plan

17 Form: F- 5.2 Statement of Asset wise Depreciation

18 Form: F- 5.3 Statement of Depreciation

19 Form: F-5.4 Contributions, Grants and subsidies towards Cost of Capital Assets

20 Form: F- 6.1 Statement of Capital Expenditure

21 Form: F- 6.2 Statement of Capital Works-in-Progress

22 Form: F- 6.J Details of Capital Cost and Financing Structure

23 Fann: F-6.4 Statement of Capital Works-in-Progress

24 Fo1:sn: F-p.5 Break-up of Construction/Supply/Service Packages

25 1~orm: F-6.6 Element wise Break-up of Project/Asset/Element Cost for Distribution System

26 Form _F-6. 7 Statement of Additional Capitalisation after COD

27 Fp_rm: F-S).8 Financing of Additional Capitalisation

28 form: F-6.9 Incidental Expenditure during Construction

29 Form: F-6.10 Statement of De-capitalisation

30 Form: F- 7 .1 Details of Financial Packages

31 For-n1: F- 7.2 Draw Down Schedule for Calculation of IDC & Financing Charges

32 Form: F- 7.3 Statement of Outstanding Loans

33 Fo1·m: F- 7.4 Calculation of Weighted Average Interest Rate of Interest on Actual Loans *

Page 183

INDEX OF FORMATS

Formats for Distribution

S. No. Format No. Description 34 Fo1-m: F- 7.5 Calculation of Interest on Normative Loan

35 Form: F-8 Details of Interest on Working Capital

36 Form: F-9 Provision for Bad Debts

37 Forr:.i.1 :. f-9A Scheme wise detail of capital expenditure

38 l'orm: F-10 Return on Equity

39 f"orm_: F-10, 1 Details of Additional RoE

40 fonn: F-11 Details of Non-Tariff Income

41 Forni: F-12 Income from Wl1eeling Charges

42 Form: F-13 Revenue from Sale of Power at Existing Tariffs

43 Form: F-14 Revenue from Sale of Power at Proposed Tariffs

44 Forni: F-i.5 Collection Efficiency

45 Form: F-16 Summary of Truing Up

46 Fonn: F-17.1 System Average Interruption Frequency Index (SAIFI)

47 1~9rm: f-17.2 System Average Interruption Duration Index {SAIDI)

48 Fo1·m: F-P.;i. Momentary Average Interruption Frequency Index (MAIFI)

49 Form: F'-18.1 Shunt Capacitor Addition/ Repair Program

50 Form: ..f-lS.7 Electrical Accidents

51 Form: F-18.3_ Abstract of Outages due to feeder tripping

52 Form: F-l.8.4 Category wise Load Shedding carried out during the year

53 i~orn, · F-18.5_ Overloaded Feeders

54 Form: F-18.6 Failure of Transformers

55 i:·onn : 18.7 Overloaded Distribution Transformers (DTRs) -··

56 Form: F-i.8,8 Ageing Schedule of Receivables

57 1:orm: F- 1 S.9 Status of Metering

58 Form: F-18.1Q Release of Customer Bills

59 Form : F 18.11 Number of Pending Service Connection Application

Page 184

Name of Distribution Licensee Licensed Area of Supply

Form: F-1

Summary of Annual Revenue Requirement

S. No. Item

Exoenditure 1 Power Purchase Exnenses 2 Water Tax 3 Additional Cost to meet RPO 4 Transmission Charaes-PGCIL 5 Transmission Charaes-PTCUL 6 SLDC Charaes 7 Interest on Loan 8 Interest on Consumer Securitv Oer.osit 9 Guarantee Fee 10 Deoreciation 11 O&M Exoenses

11.l Emolovee Exoenses 11.2 A&G Exnenses 11.3 R&M Exnenses 12 Adiustment anainst sharinn of nains/losses 13 Interest on Workino Canital 14 Return on Eouitv 15 Provision for bad and doubtful debts

Anareaate Revenue Reauirement 16 Less: Non-Tariff Income 17 Add: True un imoact Gan/(surolus) 18 Previous vear adiustment

Net Annual Revenue Renuirement 19 Revenue at existina tariffs 20 Revenue /Surnlus)/Gan

Uttarakhand Power Corporation Limited Uttarakhand

FY 2018-19 FY 2019-20

I Actuals t Audited) Estimated

5023.07 5400.74

437.10 509.73 311.88 266.36

144.02 142.42

122.60 143.38

332.89 374.02 47.48 33.99

137.66 143.95 12.28 0.00 - -

106.70 90.11 - -

6675.66 7104.70 244.41 250.00

64.78 -305.31 -158.71 0.00

6337.32 6549.39 6211.19 6592.52

126.14 -43.13

Figures in Crores

FY 2020-21

Proiected

5590.69

373.37 415.45

195.43

201.30

467.76 72.58

203.26 0.00

16.13 153.25

-7689.24

244.41 0.00 0.00

7444;84 7062.37

382.47

r. \1 10 / Page 185

Name of Distribution Licensee Licensed Area of Supply

Form: F-2.1

Customer Sales Forecast

FY2018-19

Consumer Category & Consumntion Slab

HT HT industrv Mixed Load Railwa" tracr1on Sub-total LT Domestic Non-Domestic PTW and Allied Services Govt.Public utilities LT Industrv Sub-total Total

FY2019-20

Consumer Category & Consumntion Slab

HT HT Industrv Mixed Load Railwav traction Sub-total LT Domestic Non-Domestic PTW and Allied Services Govt.Public utilities LT Industrv Sub-total Total

Ape

526.48 12.78

2.01 541.27

194.06 100.01

4.68 48.25 22.13

369.13 910.40

Ape

537.85 13.04

2.05 552.94

201.68 105.03

4.77 50.51 22.61

384.60 937.54

Uttarakhand Power Corporation Limited Uttarakhand

May Jun Jul

540.88 543.03 527.17 13.31 14.83 14.94

2.51 2.62 2.71 556.70 560.47 544.82

215.45 241.83 286.00 114.46 132.67 140 .00

4.72 70.94 12.11 49.74 47.64 52.88 22.99 25.23 25.63

407.36 518.31 516.62 964.06 1078.78 1061.44

May Jun Jul

552.56 554.76 538.55 13.58 15.12 15.24

2.56 2.67 2.76 568.70 572.55 556.56

223.91 251.32 297.23 120.21 139.32 147.03

4.81 72.36 12.36 52 .11 49.92 55.38 23.49 25.78 26.19

424.53 538.70 538.17 993.23 1111.25 1094.73

Aug

541.11 15.58

2.41 559.10

278.18 126.59

4.02 47,04 24.48

480.30 1039.40

Aug

552.79 15.89

2.46 571.15

289.10 132.94

4.10 49.30 25.01

500.45 1071.60

IMU.

Sep Oct Nov Dec Jan Feb Mac Total

518.13 551.91 534.95 512.73 539.39 523.34 496.65 6355.76 1<1.11 13.31 12.35 15.59 17.44 18.69 14.83 177. 75

2.27 2.14 2.17 2.26 2.17 2.36 2.28 27.91 534.51 567.36 549.47 530.58 558.99 544.38 513.76 6561.42

282.52 254.83 231.03 207.71 222.40 214.75 220.45 2849.20 121.03 68.17 96.91 93.55 106.55 98.32 103.08 1301.34

4.10 4.15 3.94 60.37 12.89 3.53 4.69 190.13 41.28 45.87 50.09 62.47 60.94 52.35 56.12 614.66 26.15 27.17 27.76 27.68 29.05 26.04 25.59 309.93

475.08 400.19 409.74 451.77 431.83 394.99 409.93 5265.26 1009.58 967.55 959.21 982.35 990.82 939.38 923.70 11826.68 .. Petitioner

IMU'

Sep Oct Nov Dec Jan Feb Mac Total

529.32 563.83 546.50 523.80 551.04 534.64 507 .38 6493.03 14.39 13.57 12.60 15.91 17.79 19.06 15.13 181.30

2,32 2,19 2.21 2.30 2.21 2.41 2.33 28.47 546.03 579.59 561.31 542.01 571.03 556.11 524.83 6702.80

2.93.62 264.83 240.10 215.37 231.13 223.19 229.11 2961.10 127.10 71.59 101.73 93.24 111.89 103.25 108.26 1366.63

4.18 4.23 4.02 61.57 13.15 3.60 4.79 193.93 43.27 48.15 52.53 65.64 63.81 54.92 58.83 644.36 26.72 27.76 28.36 28.28 29.68 26.60 26.14 316.62

494.88 416.57 426.80 469.60 449.66 411.56 427.13 5482.64 1040.91 996.16 988.11 1011.61 1020.69 967.67 951.96 12185.44

Page 186

Name of Distribution Licensee Licensed Area of Supply

Customer Sales Forecast

FY2020-21

Consumer Category & Consum'"'tion Slab

HT HT Industr,, Mixed Load Railwav tra--tion Sub-total LT Dom<>stic Non-nomestic PTW and Allied Services Govt.Public utilities LT Industrv Sub-total Total Total

Ape

549.47 13.30

2.0':c' 564,86

209.60 110.30

4.87 52.88 23.10

400.75 965.61

Uttarakhand Power Corporation limited Uttarakhand

May Jun Jul

564. 50 566.74 550.19 13.85 15.42 15.54

2.61 2.73 2.82 580.96 584.89 568.55

232. 70 261.19 308.90 126.24 146.31 154.40

4.91 73.81 12.60 54.60 52.31 58.01 24.00 26.33 26.75

442.44 559.95 560.67 1023.40 1144.84 1129.21

Aug Sep

564.73 540.76 16.? 1 14.67

2.51 2.36 583.45 557.79

300.46 305.15 139.61 133.47

4.18 4.26 51.68 45.36 25.55 27.30

521.48 515.54 1104.93 1073.33

(MU)

Oct Nov oec Jan Feb Mac Total

576.01 558.30 535.11 562. 94 546.19 518.33 6633.26 13.84 12.85 16.22 18.14 19.44 15.43 184. 93

2.23 2.26 2.35 2.25 2.46 7.38 29.04 592.08 573.41 553.68 583.34 568.08 536.14 6847.23

275.23 249.53 224.35 240.21 231.95 238.11 3077 .39 75.18 106.88 103.17 117.51 108.43 113.69 1435.19

4.32 4.10 62.80 13.41 3.67 4.88 197.81 50.55 55.10 68.98 66.82 57.63 61.69 675.62 28.36 28.98 28.89 30.3? ?7.18 26.71 323.46

433.64 444.60 488.19 468.27 428.86 445.07 5709.47 1025.73 1018.01 1041.88 1051.60 996.94 981.21 12556.69

Page 187

Name of Distribution Licensee Licensed Area of Supply

Form: F-2.2

No of Consumers Forecast

FY201S-19

Consumer Category & Consumntion Slab

HT HT lndustrv Mixed Load Railwav traction Sub-total LT Domestic Non-Domestic PTW & Allied services Govt.Public utilities LT Industrv Sub-total Total

FY2019-20

Consumer Category & Con.,umntion Slab

HT HT Industry Mixed Load Railway traction Sub-total LT Domestic Non-Domestic PTW Govt.Public utilities LT Industrv Sub-total Total

Ape

2059 71

2 2132

1953218 236800

32665 4924 9758

2237365 2239497

Ape

2106 75

2 2183

2135161 ?51197

34884 5526

10783 2437550 2439733

Uttarakhand Power Corporation Limited Uttarakhand

May Jun Jul

2059 2065 2069 71 72 72

2 2 2 2132 2139 2143

1964484 1982959 1995010 236049 237837 237934

32820 32870 32897 5010 5096 5217 9608 9615 9644

2247971 2268377 2280702 2250103 2270516 2282845

May Jun Jul

2112 2118 2124 75 75 75

2 2 2 2189 2195 2201

2146160 2157216 2168328 252536 253882 255235

35035 35187 35339 5552 5579 5606

10809 10836 10863 2450093 2462700 2475372 2452282 2464895 2477574

Aug

2066 72

2 2140

2014763 238903

32980 5271 9850

2301767 2303907

Aug

2130 75

2 2207

2179498 256596

35492 5633

10890 2488110 2490317

Fiaures in No.)

Sep Oct Nov Dec Jan Feb Mac

2071 7079 2036 7048 2051 JOSS 2100 72 74 75 75 75 74 75

2 2 2 2 2 2 2 2145 2155 2113 2125 2128 2134 2177

2028256 2042798 2064891 2082994 2089689 2101015 2P4219 239578 240545 242374 243940 245353 246783 249865

33241 33346 33442 33729 33646 34020 34733 5291 5318 5474 53cl 5426 5449 5499 9895 9880 9861 10070 10157 10208 10756

2316261 2331887 2356042 2376094 2384271 2397475 2425072 2318406 2334042 2358155 2378219 2386399 2399609 2427249

Pet1t1one1· (\

Page 188 '~ Fiqures in No.)

Sep Oct Nov Dec Jan Feb Mar

2136 2142 7148 2154 2160 2167 2173 75 75 76 76 76 76 76

2 2 2 2 2 2 ' 2214 2220 2226 2232 2238 2244 2251

2190725 2202010 2213354 2224755 2236215 2247735 2259314 257964 259339 260721 262111 263508 264913 266325

35646 35801 35956 36112 36269 36426 36584 5661 5688 5716 5744 577? 5800 5828

10917 10944 10971 10999 11026 11053 11081 2500913 2513782 2526718 2539720 25527901 2565926 2579131 2503127 2516002 2528944 2541952 25550281 2568171 2581381

Petitwner

!~' il_ '"s..J.... j~.

Page 139

Name of Distribution Licensee Licensed Area of Supply

Form: F-2.2

No of Consumers Forecast

FY2020-21

Consumer Category & Consumotion Slab

HT HT Industrv Mixed Load Railwa" traction Sub-total LT Domestic Non-Domestic PTW Govt. Public utilities LT Industrv Sub-total Total

Ape

2179 76

2 2257

2270952 267744

36742 5856

11108 2592403 2594660

Uttarakhand Power Corporation limited Uttarakhand

May Jun Jul

2185 2191 2198 76 76 76

2 2 2 2263 2269 2276

2282650 2294409 2306228 269171 270606 272049

36902 37062 37222 5885 5914 5942

11136 11163 11191 2605744 2619154 2632633 2608007 2621423 2634909

Aug

2204 76

2 2282

2318108 273499

37384 5971

11219 2646181 2648463

(figures in No )

Sep Oct Nov Dec Jan Feb Mac

2210 2216 2223 2229 2235 7242 2248 76 76 76 76 77 77 77

2 2 2 2 2 7 2 2288 2295 2301 2308 2314 2320 2327

2330050 2342052 2354117 2366244 2378433 2390685 2403000 274957 276422 277896 279377 280866 282363 283869

37546 37709 37872 38036 38201 38367 38533 6001 6030 6060 6089 6119 6149 6179

11247 11275 11302 11331 11359 11387 11415 2659799 2673488 2687247 2701077 2714978 2728951 2742996 2662088 2675783 2689548 2703384 2717292 2731272 2745323

Petitioner

I

Page 190

Name of Distribution licensee Licensed Area of Supply

Form: F-2.3 Load Forecast

FY201S-19

Consumer Category & Consum.-tion Slab

HT HT Industrv Mixed Load Railwav traction Sub-total LT Domestic Non-Domestic PTW & Allied services Govt.Public utilities LT Industrv Sub-total Total

FY2019-20

Consumer Category & Consumntion Slab

HT HT Industry Mixed Load Railway traction Sub-total LT

Domestic Non-Domestic PTW Govt.Public utilities LT Industrv Sub-total Total

Ape

1647?06 48682 15000

1710888

2949806 1051175

173209 175993 215647

4565830 6276718

Ape

1683951 54702 15025

1753678

3143047 1062097

188942 184738 222045

4800868 6554546

Uttarakhand Power Corporation Limited Uttarakhand

May Jun Jul

1657442 1662124 1666090 46911 47511 47511 15000 15000 15000

1719353 1724635 1728601

2969332 2971828 3004090 1048048 1043104 1027584

174334 174715 178658 175183 175410 175990 210657 209566 205950

4577554 4574623 4592271 6296907 6299258 6320872

May Jun Jul

1689546 1695159 1700791 54793 54883 54974 15050 15074 15099

1759388 1765117 1770864

3153336 3163660 3174017 1065574 1069062 1072562

189761 190583 191409 185236 185736 186237 222877 223712 224551

4816784 4832753 4848776 6576172 6597870 6619640

Aug

1666177 47511 15000

1728688

2992608 1014998

177699 178821 207891

4572016 6300704

Aug

1706442 55064 15124

1776631

3184408 1076073

192239 186740 225392

4864852 6641483

Fi~ures in No.'

Sep Oct Nov Dec Jan Feb Ma,

1667716 1681265 1684445 1677536 1661337 1665499 1678375 47511 47781 45921 46060 46060 43542 54612 15000 15000 15000 15000 15000 15000 15000

1730227 1744046 1745366 1738596 1722397 1724041 1747987

2994275 3017921 3050351 3071946 3085108 3108433 3132791 1008830 1020826 1033082 1037990 1048111 1052279 1058631

180380 180895 181619 183068 182245 184554 188127 181078 181752 180351 179802 180914 181941 184241 209120 209228 210417 215205 216164 217612 221216

4573682 4610621 4655820 4688011 4712542 4744819 4785006 6303909 6354667 6401186 6426607 6434939 6468860 6532993

Petitioner

(Figures in No )

Sep Oct Nov Dec Jan Feb Mac

1712111 1717800 1723507 1729233 1734978 1740743 17'16526 55155 55247 55338 55429 55521 5561? 55704 15149 15174 15199 15224 15250 15275 15300

1782416 1788221 1794044 1799887 1805749 1811630 1817530

3194832 3205292 3215785 3226312 3235875 3247471 3?58103 1079596 1083130 1086676 1090234 1093803 1097384 1100976

193072 193909 194749 195593 196441 197292 198148 187245 187751 188259 188768 189280 189792 190307 226237 227085 227936 228790 229648 230508 231372

4880982 4897167 4913405 4929698 4946046 4962448 4978906 6663399 6685387 6707449 6729585 6751794 6774078 6796436

Petitioner

Page 191

-- --- --------

Name of Distribution Licensee Licensed Area of Supply

Form: F-2.3 Load Forecast

FY2018-19

FY2020-21

Consumer category & Consumntion Slab

HT

HT Industrv Mixed Load Railwav traction Sub-total LT Domestic Non-Domestic PTW Govt.Public utilities LT Industr" Sub-total Total

Ape

1752329 55796 15325

1823450

3268769 1104581

199006 190823 232239

4995418 6818868

Uttarakhand Power Corporation limited Uttarakhand

May Jun Jul

1758151 1763992 1769853 55888 55981 56073 15351 15376 15401

1829390 1835348 1841327

3279470 3290206 3300977 1108197 1111825 1115464

199869 200735 201605 191341 191860 192381 233110 233983 234860

5011986 5028610 5045289 6841376 6863958 6886616

Aug Sep

1775733 1781632 56166 56259 15427 15452

1847325 1853343

3311784 3322626 1119116 1122780

202479 203357 192904 193429 235741 236624

5062024 5078815 6909349 6932158

Oct Nov Dec

1787552 1793491 1799449 56351 56445 56538 15478 15503 15529

1859381 1865438 1871516

3333503 3344416 3355365 1126456 1130143 1133843

204238 205124 206013 193955 194483 195012 237511 238401 239294

5095663 5112567 5129527 6955043 6978005 7001043

Jao Feb

1805428 1811426 56631 56725 15555 15580

1877613 1883731

3366350 3377370 1137555 1141279 706906 207802 195544 196077 240191 241091

5146545 5163619 7024158 7047350

(Figures in No )

Mac

1817444 56818 15606

1889869

3388427 1145015 208703 196611 241995

5180751 7070620

Petitioner

r, \\

1'--,i/J /

Page 192

Name of Distribution Licensee

Licensed Area of Supply

Form: F-2.4

Distribution Losses

FY 2018-19

IS. No. Voltage Level

1

FY 2019-20

S. No. Voltage Level

1

FY 2020-21

S. No. Voltage Level

l

'

I I

I

Uttarakhand Power Corporation Limited

Uttarakhand

Energy Energy Sent to Direct Sale Input lower network

13803.71 11826.68

I I I I I I

Energy Energy Sent to Input lower network

Direct Sale

14210.43 12185.44

I I I I I

Energy Energy Sent to Direct Sale

Input lower network

14600.80 12557

I I I I I I

Total Total Output Losses

14.32%

I I I I

Total Total Output

Losses

14.25%

I I I I

Total Tota[ Output

Losses

14.00%

I I

I I

(MU\ Total

Total Total Total Losses Losses Losses (O/o

Total Technical Commercial (% of

(% of of Energy Energy Ener~· Loss

In-ut\ Loss InnuT\

I I I I

(MU' , o~a1

Total Total Losses Losses Total Losses(% Total

{%of (% of Technical of Energy

Commercial Energy Energy Loss

Input) Loss Input)

I I

(MU\ !Ota1

Total Total Losses Losses Total Losses (O/o Total

{% of (%of Technical Commercial Energy Loss

of Energy Loss

Energy . .. Input) Ir.put)

I

Page 193

Name of Distribution Licensee Licensed Area of Supply

Form: F-2.5

Energy Distribution

FY 2018-19

Source of Power (Station wise)

NHPC Sal al Tanakour Chamera I Chamera II

Chamera III Uri Dhaulioanoa Dulhasti Sewa II Uri II Parbati Ill Kishanoanoa Sub-Total

SJVNL Nathoa Jhakri Ramour Eauirv Power Ramour Free Power Sub-Total

THDC Tehri HEP I Koteshwar Sub-Total

NTPC Sinorau/i

Installed Capciity

UK Share

(MW) (%)

690 1.21% 94 3.89%

540 3.53% 300 2.44%

231 6.14% 480 3.48% 280 6.10% 390 6.14% 120 6.20% 240 5.35% 520 6.14% 330 0.00%

1500 1.34% 412 11.82% 412 0.00%

1000 16.04% 400 19.01 %

2000 5.13%

Uttarakhand Power Corporation Limited Uttarakhand

Energy Sent Inter-State Out (ESO) Transmissio Units received at State from the n -Losses periphery (MU)

station (MU) (%)

39.02 3.2% 37.79 10.55 3.7% 10.16 85.61 3.4% 82.70 19.92 3.8% 19.16

51.97 3.9% 49.96 101.45 3.4% 98.03

50.44 3.7% 48.55 117.60 3.7% 113.26

27.00 3.5% 26.05 75.97 3.4% 73.41 28.48 3.2% 27.58

4.63 0.0% 4.63 612.65 591.27

43.02 4.2% 41.19 197.21 3.7% 189.84

0.00 0.0% 0.00 240.22 231.04

106.07 4.4% 101.35 76.80 4.4% 73.45

182.86 174.80

655.17 5.3% 620.76

s ' -Page 194

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESQ) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU) station (MU) (%)

F G Unchahar-l 420 8.69% 219.85 4.6% 209.80 F G Unchahar-2 420 3.97% 105.35 4.4% 100.69 F G Unchahar-3 210 6.55% 70.42 4.5% 67.27 F G Unchahar-4 500 4.67% 31.08 5.1% 29.48 N CTDadri:2 980 0.34% 4.79 3.3% 4.63 Rihand-1 STPS 1000 4.23% 239.43 5.2% 226.93 Rihand-2 STPS 1000 3.73% 218.67 5.2% 207.27 Rihand-3 STPS 1000 4.39% 248.82 5.3% 235.67 Kaha!aaon-II 1500 0.00% 148.09 3.4% 143.05 Jhaiiar Aravali 1500 1.03% 36.42 3.6% 35.12 Sinarauli SHEP 8 0.18% 0.25 0.0% 0.25 Koldam (Hvdro) 800 6.92% 188.06 3.1% 182.28 Barh STP I 0 0.00% 0.00 0.0% 0.00 Barh STP II 0 0.00% 0.00 0.0% 0.00 North Karanoura 0 0.00% 0.00 0.0% 0.00 Sinarauli STPS lII 0 0.00% 0.00 0.0% 0.00 Anta Gas 419 5.83% 5.10 6.1% 4.79 Auraiva Gas 663 5.45% 4.99 4.4% 4.77 Dadri Gas 830 4.74% 42.02 3.5% 40.56 Sub-Total 2218.49 2113.30

NPCIL Narora APP 440 5.67% 143.32 4.7% 136.60 Raiasthan APP 440 6.05% 174.49 5.3% 165.22 Sub-Total 317.80 301.82 1otal CSGS 357?.03 3412.23 UJVNL Larqe Hvdro Dhakrani 34 75.00% 100.35 0.0% 100.35 Dhalinur 51 75.00% 164.86 0.0% 164.86 Chi bro 240 75.00% 603.50 0.0% 603.50 Khodri 120 75.00% 265.40 0.0% 265.40 Kulhal 30 80.00% 110.88 0.0% 110.88 Ramaanca 198 100.00% 183.60 0.0% 183.60 Tiloth 90 100.00% 422.84 0.0% 422.84 Chilla 144 100.00% 613.75 0.0% 613.75 Khatima 41 100.00% 225.51 0.0% 225.51 UJVNL Receivable 0 0.00% 0.00 0.0% 0.00

,Ci •'--;;?" Page 195

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESQ) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

Sub-Total 2690.69 2690.69

Maneri Bhali II 304 100.00% 1284.73 0.0% 1284.73

Small Hydro Mohd. Pur 9 100.00% 52.24 0.0% 52.24 Pathri 20 100.00% 114.25 0.0% 114.25 Kanchauti 0 0.00% 0.00 0.0% 0.00 Chhirkila 0 0.00% 0.00 0.0% 0.00 Kulaoarh 0 0.00% 0.00 0.0% 0.00 Relaaad 0 0.00% 0.00 0.0% 0.00 Dunao SHP 1.5 MW 0 100.00% 4.88 0.0% 4.88 Surinqarh 0 0.00% o.oo 0.0% 0.00 Saoteshwar 0 0.00% 0.00 0.0% 0.00 Gauri 0 0.00% 0.00 0.0% 0.00 Pandukeshwar 0 0.00% 0.00 0.0% 0.00 Taleshwar 0 0.00% 0.00 0.0% 0.00 Chharandev 0 0.00% o.oo 0.0% o.oo Kotabaah 0 0.00% 0.00 0.0% 0.00 Harsil 0 0.00% o.oo 0.0% 0.00 Pilanaad 2 100.00% 5.10 0.0% 5.10 Tharali 0 0.00% 0.00 0.0% 0.00 Uraam 0 100.00% 5.80 0.0% 5.80 Soneoravaa 0 0.00% 0.00 0.0% 0.00 Badrinath 0 0.00% o.oo 0.0% o.oo Ti!wara 0 100.00% 0.00 0.0% o.oo Taoovan 0 0.00% 0.00 0.0% 0.00 Jumma 0 0.00% o.oo 0.0% 0.00 Ga/ooi 3 100.00% 5.96 0.0% 5.96 Ka!iaanaa 0 0.00% 0.00 0.0% 0.00 Sub-Total 188.22 188.22 Total UJVNL 4163.64 4163.64 UREDA SHPs UREDA: Bhikuriva Gardh 1 100.00% o.oo 0.0% 0.00 Ramoarh 0 100.00% 0.00 0.0% 0.00 Barar + Garaun 1 100.00% 0.00 0.0% 0.00 Surinaarh 1 100.00% 0.00 0.0% 0.00

Page 196

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESQ) Transrnissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

Santeshwar 0 100.00% 0.00 0.0% 0.00

Gauri 0 100.00% 0.00 0.0% 0.00

Taleshwar 1 100.00% 1.74 0.0% 1.74

Chharandev 0 100.00% 1.01 0.0% 1.01

Kotabaoh 0 100.00% 0.00 0.0% 0.00

Harsil 0 100.00% 0.00 0.0% 0.00

Tharali 0 100.00% 0.00 0.0% 0.00

Badrinath 1 100.00% 0.04 0.0% 0.04

UREDA: Kanoload SHP 0 0.00% 0.00 0.0% 0.00

UREDA: Lathi SHP 0 0.00% 0.00 0.0% 0.00

UREDA: Barsol SHP 0 100.00% 0.00 0.0% 0.00

UREDA: Milkhet SHP 0 100.00% 0.00 0,0% 0.00

Sub Total 2.80 2.80

UREDA Solar Solar Plant Dehra Dun 0 100.00% 0,00 0.0% 0.00

Sub Total 0.00 o.oo UREDA Biomass Avni Bio Ener'""" 0 0.00% 0.00 0.0% 0.00

Sub-Total 0.00 0.00

IPP Hvdro Raiwakti Him Uria SHP 5 88.00% 21.24 0.0% 21.24

Hanuman Ganna SHP 5 100.00% 0.00 0.0% 0.00

Greenko Budhil Hvdro Power Pvt Ltd 70 100.00% 262.24 4.4% 250.70

Debal chamoli hvdro 5 100.00% 15.79 0.0% 15.79

LoharKhet ( narvativa nower) 5 100.00% 21.72 0.0% 21.72

Gunsola Hvdro Aaunda Thati 3 100.00% 12.95 0.0% 12.95

Bhilanaana(Swasti'I 23 100.00% 89.58 0.0% 89.58

Vanala 15 100.00% 49.97 0.0% 49.97

Motiohat 5 100.00% 5.33 0.0% 5.33

Rishinanoa 13 100.00% 0.00 0.0% 0.00

Birahi Ganna 7 100.00% 24.81 0.0% 24.81

Tanaa !HHPL1 5 100.00% 5.12 0.0% 5.12

HHL: Jalandharioad 0 0.00% 0.00 0.0% 0.00

HHL: Sivannad 0 0.00% 0.00 0.0% 0.00

HHL: Kakoranad 0 0.00% 0.00 0.0% 0.00

Sariu II 13 100.00% 26.43 0.0% 26.43

Uttar Bharat Sariu III 11 100.00% 21.74 0.0% 21.74

Page 197

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESQ) Transmissio Units received at State

(MW) (%) from the n losses periphery (MU)

station (MU) (%)

Ganaani 8 100.00% 39.35 0.0% 39.35 Badivar 5 100.00% 15.61 0.0% 15.61 Sub-Total 611.88 600.33

Co-Generation RBNS Suqar Mill 19 100.00% 44.35 0.0% 44.35 Uttam Suaar Mills 13 100.00% 26.41 0.0% 26.41 Lakshmi Suaar Mills 20 100.00% 47.05 0.0% 47.05 Sub0 Total 117.82 117.82

Gas Gama 104 100.00% 400.82 0.0% 400.82 Beta 107 100.00% 0.00 0.0% 0.00 Shravanti 214 100.00% 822.52 0.0% 822.52 Sub-Total 1223.35 1223.35

Solar RV Akash Ganaa solar oower ltd 2 100.00% 2.40 0.0% 2.40 Metro Frozen 1 100.00% 1.15 0.0% 1.15 Jav Ace Technoloaies 2 100.00% 1.88 0.0% 1.88 UJVNL (1.466) Dhakrani 1 100.00% 2.35 0.0% 2.35 UJVNL (4.398lkhodari 4 100.00% 6.07 0.0% 6.07 Redwoods 2 100.00% 0.00 0.0% 0.00 Madhav Infra . 12 100.00% 18.94 0.0% 18.94 Purshotam Industries Ltd.-! @7. 71 1 100.00% 1.07 0.0% 1.07 Purshotam Industries Ltd.-Il @7.73 1 100.00% 1.26 0.0% 1.26 Purshotam Isoat-I @7.96 1 100.00% 1.42 0.0% 1.42 Vivaan Solar Pvt. Ltd. 4 100.00% 3.93 0.0% 3.93 Eastman International 1 100.00% 0.93 0.0% 0.93 Purshotam Isoat-Il @7.88 1 100.00% 1.34 0.0% 1.34 R.C. Enermr 1 100.00% 1.20 0.0% 1.20 Advika Enernv 1 100.00% 1.35 0.0% 1.35 A.R. Solar Power-I @5.670 1 100.00% 1.42 0.0% 1.42 A.R. Solar Power-II @5.690 1 100.00% 1.47 0.0% 1.47 Devishi Renewal enerav 13 100.00% 20.44 0.0% 20.44 Devishi Solar nower 13 100.00% 20.70 0.0% 20.70 Eminet Solar oower 13 100.00% 21.22 0.0% 21.22 Sunwor!d Enerav ovt 13 100.00% 20.10 0.0% 20.10

Page 198

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

Emami Power Ltd. 20 100.00% 29.55 0.0% 29.55 Hvdro Power Enoineers 1 100.00% 1.44 0.0% 1.44 Imnex India 2 100.00% 3.55 0.0% 3.55 Techninue So!aire Invest 5 100.00% 7.35 0.0% 7.35 Makin Develooers Pvt. Ltd 1 100.00% 1.55 0.0% 1.55 Balluour solar oower ovt.Ltd 10 100.00% 15.11 0.0% 15.11 Chudiala Solar oower oroiect ovt. 10 100.00% 15.23 0.0% 15.23 Shakumbhari solar oower oroiect ovt Ltd 10 100.00% 15.12 0.0% 15.12 Bindookharak solar nower nroiect ovt ltd 5 100.00% 8.01 0.0% 8.01 Bhanwanour solar nroiects nrivate ltd 5 100.00% 8.04 0.0% 8.04 PL sunravs oower !lmited 10 100.00% 15.99 0.0% 15.99 PL surva vidvut ltd 10 100.00% 15.72 0.0% 15.72 PL solar Renewable ltd 10 100.00% 15.39 0.0% 15.39 Haridwar solar oroiects ovt ltd 1 10 100.00% 15.84 0.0% 15.84 Haridwar so!ar nroiects nvt ltd 2 10 100.00% 15.94 0.0% 15.94 Sunheti solar nower r.roi nvt ltd 5 100.00% 7.43 0.0% 7.43 AB Renewable Enerov ovt ltd 5 100.00% 7.79 0.0% 7.79 Canal Bank Solar ov olant Dhakrani 7 100.00% 9.38 0.0% 9.38 Cana! Bank So!ar ov olant Dha!icur 8 100.00% 9.65 0.0% 9.65 Canal Ton Solar nv nlant DhaJinur 1 100.00% 0.41 0.0% 0.41 Daknatthar canal Bank (4.5 MW'I 5 100.00% 6.64 0.0% 6.64 Sub-Total 355.77 355.77

Solar Rooftoo EDC DEHRADUN 0.95 0.0% 0.95 EDC SRINAGAR 0.66 0.0% 0.66 EDC TEHRI 0.00 0.0% 0.00 UDC DEHRADUN 0.03 0.0% 0.03 EDC HAR!DWAR 1.17 0.0% 1.17 EDC ROORKEE 6.33 0.0% 6.33 EDC HALDWAN! 0.12 0.0% 0.12 EDC KASHIPUR 0.00 0.0% 0.00 EDC RANIKHET 0.00 0.0% 0.00 EDC RUDRAPUR 3.35 0.0% 3.35 EDC PITHORAGARH 0.00 0.0% 0.00 Sub-Total 12.61 12.61

Other Larae Private

Page 199

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transrnissio Units received at State

(%) from the n Losses periphery (MU) (MW)

station (MU) (%)

Meia Thermal I 660 1.97% 0.00 0.0% 0.00 Sasan 3722 2.66% 723.68 4.4% 691.82 Sub-Total 723.68 691.82 Total !PP 3047.90 3004.49

State Royalty Power Dhaulioanoa 280 12.00% 130.36 4.4% 124.62 Tanaknur 94 12.00% 40.90 4.4% 39.10 Tehri 1000 12.00% 379.07 4.4% 362.38 Koteshwar 400 12.00% 145.77 4.4% 139.36 Vishnu Pravaa 400 12.00% 214.27 4.4% 204.84 GVK Srinaaar 330 12.00% 151.69 4.4% 145.01 Raiwakti Him Ur'a SHP 5 0.00% 2.36 0.0% 2.36 Sub-Total 1064.43 1017.68 Total Power Purchase from Firm Sources 11847.99 11598.03 Onen Market Purchases & UI 845.12 4.4% 807.91 Bankina Received -26.77 4.4% -25.59 UI Net drawal 1621.86 4.4% 1550.46 Tender Purchases 599.91 4.4% 573.50 !EX /Net Purchasesl 0.00 0.0% 0.00 Reactive Payables Ooen Market Purchase (Extra) Sub-Total 3040.12 2906.29 Total Purchases 14888.12 14504.32 Less: -Bankino Payable 813.74 4.0% 781.19 UI Underdrawal 0.00 4.0% 0.00 Reactive Units Receivables 0.00 4.0% 0.00 Sub-Total 813.74 781.19

l ·1 State Consumntion I 14074.38 13723.Lll

Page 200

------'""""""""'-·········--·--------

Name of Distribution Licensee Licensed Area of Supply

Form: F-2.5

Energy Distribution

FY 2019-20

Source of Power (Station wise)

NHPC Sala I Tanaknur Chamera I Chamera II

Chamera III Uri Dhauliaanaa Dulhasti Sewa II Uri II Parbati III Kishanaanaa Sub-Total

SJVNL Nathoa Jhakri Ramnur Enuitv Power Ramour Free Power Sub-Total

THDC Tehri HEP I Koteshwar Sub-Total

NTPC Sinarauli F G Unchahar-I F G Unchahar-2

Installed Capciity

UK Share

(MW) (%)

690 1.21% 94 3.89%

540 3.53% 300 2.44%

231 6.14% 480 3.48% 280 6.10% 390 6.14% 120 6.20% 240 5.35% 520 6.14% 330 0.00%

1500 1.34% 412 11.82% 412 0.00%

1000 4.04% 400 7.01%

2000 5.13% 420 8.69% 420 3.97%

Uttarakhand Power Corporation Limited Uttarakhand

Energy Sent Inter-State Out (ESQ) Transmissio Units received at State from the n losses periphery (MU)

station (MU) (%)

43.10 4.2% 41.28 14.21 4.2% 13.62 89.96 4.2% 86.18 30.65 4.2% 29.36

63.36 4.2% 60.69 91.09 4.2% 87.26 74.03 4.2% 70.92

120.43 4.2% 115.37 34.57 4.2% 33.11 81.32 4.2% 77.90 41.28 4.2% 39.55 17.43 4.2% 16.70

701.42 671.94

100.24 4.2% 96.03 238.34 4.2% 228.33

0.00 0.0% 0.00 338.59 324.36

115.48 4.2% 110.62 80.04 4.2% 76.68

195.52 187.30

712.96 4.2% 683.00 213.98 4.2% 204.99

97.74 4.2% 93.63

Page 201

Installed Energy Sent Inte;-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

F G Unchahar-3 210 6.55% 80.70 4.2% 77.31

F G Unchahar-4 500 4.67% 146.99 4.2% 140.81

N CTDadri:2 980 0.34% 16.77 4.2% 16.07

Rihand·l STPS 1000 4.23% 302.29 4.2% 289.58

Rihand-2 STPS 1000 3.73% 266.53 4.2% 255.33

Rihand-3 STPS 1000 4.39% 313.55 4.2% 300.37

Kahalaaan-11 1500 1.90% 186.54 4.2% 178.70

Jhaiiar Aravali 1500 1.03% 66.96 4.2% 64.14

Sinorauli SHEP 8 2.16% 0.00 0.0% 0.00

Kaldam /Hvdro' 800 6.92% 229.35 4.2% 219.71

Barh STP I 0 0.00% 0.00 0.0% 0.00

Barh STP II 0 0.00% 0.00 0.0% 0.00

North Karannura 0 0.00% 0.00 0.0% 0.00

Sinnrauli STPS III 0 0.00% 0.00 0.0% 0.00

Anta Gas 419 5.83% 11.28 4.2% 10.80

Aura"i\ra Gas 663 5.45% 12.24 4.2% 11.72

Dadri Gas 830 4.74% 57.54 4.2% 55.12

Sub-Total 2715.40 2601.29

NPCIL Narora APP 440 5.67% 184.46 4.2% 176.71

Raiasthan APP 440 6.05% 193.10 4.2% 184.99

Sub-Total 377.56 361.70

Total CSGS 4328.49 4146.59

UJVNL Larae Hvdro DhakranI 34 75.00% 105.42 0.0% 105.42

Dhalinur 51 75.00% 152.23 0.0% 152.23

Chi bro 240 75.00% 677.51 0.0% 677.51

Khodri 120 75.00% 294.85 0.0% 294.85

Kulhal 30 80.00% 108.75 0.0% 108. 75

Ramaanr1a 198 100.00% 226.96 0.0% 226.96

Tiloth 90 100.00% 386. 75 0.0% 386. 75

Chilla 144 100.00% 722.62 0.0% 722.62

Khatima 41 100.00% 214.96 0.0% 214.96

UJVNL Receivable 0 0.00% 0.00 0.0% 0.00

Sub Total 2890.06 2890.06

Maneri Bhali II 304 100.00% 1313.50 0.0% 1313.50

Page 202

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

Small Hvdro Mohd. Pur 9 100.00% 53.53 0.0% 53.53 Pathri 20 100.00% 121.17 0.0% 121.17 Kanchauti 0 0.00% 0.00 0.0% 0.00 Chhirkila 0 0.00% 0.00 0.0% 0.00 Kulanarh 0 0.00% 0.00 0.0% 0.00 Relaaad 0 0.00% 0.00 0.0% 0.00 Dunao SHP 1.5 MW 2 100.00% 2.09 0.0% 2.09 Surinnarh 0 0.00% 0.00 O.D% 0.00 Saoteshwar 0 0.00% 0.00 0.0% 0.00 Gauri 0 0.00% 0.00 0.0% 0.00 Pandukeshwar 0 0.00% 0.00 0.0% 0.00 Ta!eshwar 0 0.00% 0.00 0.0% 0.00 Chharandev 0 0.00% 0.00 0.0% 0.00 Kotabanh 0 0.00% 0.00 0.0% 0.00 Harsil 0 0.00% 0.01 0.0% 0.01 Pilanqad 2 100.00% 2.47 0.0% 2.47 Tharali 0 0.00% 0.00 0.0% 0.00 Uraam 3 100.00% 5.19 0.0% 5.19 Sonenravao 0 0.00% 0.00 0.0% 0.00 Badrinath 0 0.00% 0.01 0.0% 0.01 Tilwara 0 100.00% 0.00 0.0% 0.00 Taoovan 0 0.00% 0.00 0.0% 0.00 Jumma 0 0.00% 0.00 0.0% 0.00 Galooi 3 100.00% 7.35 0.0% 7.35 Kallaanqa 4 0.00% 0.00 0.0% 0.00 Sub-Total 191.81 191.81 Total UJVNL 4395.38 4395.38 UREDA SHPs UREDA: Bhikuriva Gardh 1 100.00% 0.00 0.0% 0.00 Ramqarh 0 100.00% 0.01 0.0% 0.01 Barar + Garaun 1 100.00% 0.04 0.0% 0.04 Surinaarh 1 100.00% 0.00 0.0% 0.00 Santeshwar 0 100.00% 0.00 0.0% 0.00 Gauri 0 100.00% 0.00 0.0% 0.00 Taleshwar 1 100.00% 0.82 0.0% 0.82 Chharandev 0 100.00% 0.36 0.0% 0.36 Kotabaah 0 100.00% 0.00 0.0% 0.00 Harsil 0 100.00% 0.05 0.0% 0.05

Page 203

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

Tharali 0 100.00% 0.22 0.0% 0.22 Badrinath 1 100.00% 0.03 0.0% 0.03 UREDA: Kanoload SHP 0 0.00% 0.00 0.0% 0.00 UREDA: Lathi SHP 0 0.00% 0.00 0.0% 0.00 UREDA: Barsol SHP 0 100.00% 0.00 0.0% o.oo UREDA: Milkhet SHP 0 100.00% 0.00 0.0% o.oo Sub Total 1.53 1.53 UREDA Solar Solar P!ant Dehra Dun 0 100.00% 0.00 0.0% 0.00 Sub Total 0.00 o.oo UREDA Biomass Avni Bio Enerm, 0 0.00% 0.00 0.0% 0.00 Sub-Total o.oo 0.00

IPP Hvdro Raiwakti Him Uria SHP 5 88.00% 23.51 0.0% 23.51 Hanuman Ganoa SHP 5 100.00% 0.00 0.0% 0.00 Greenko Budhil Hvdro Power Pvt Ltd 70 100.00% 210.02 4.2% 201.19 Debal chamoli hvdro 5 100.00% 18.97 0.0% 18.97 LoharKhet r narvativa nower) 5 100.00% 23.16 0.0% 23.16 Gunsola Hvdro Aaunda Thati 3 100.00% 14.85 0.0% 14.85 Bhi!anoanarswasti~ 23 100.00% 100.58 0.0% 100.58 Vanala 15 100.00% 50.05 0.0% 50.05 Motiahat 5 100.00% 0.00 0.0% 0.00 Rishioanoa 13 100.00% 0.00 0.0% 0.00 Birahi Ganaa 7 100.00% 26.12 0.0% 26.12 Tanoa (HHPLl 5 100.00% 0.00 0.0% 0.00 HHL: Jalandharioad 0 0.00% 0.00 0.0% 0.00 HHL: Sivanaad 0 0.00% 0.00 0.0% 0.00 HHL: Kakoraaad 0 0.00% 0.00 0.0% 0.00 Sariu II 13 100.00% 27.11 0.0% 27.11 Uttar Bharat Sariu III 11 100.00% 20.41 0.0% 20.41 Ganaani 8 100.00% 45.87 0.0% 45.87 Badivar 5 100.00% 17.69 0.0% 17.69 Sub-Total 578.33 569.51

Co-Generation RBNS Suaar Mill 19 100.00% 45.19 0.0% 45.19 Uttam Suoar Mills 13 100.00% 29.86 0.0% 29.86 Lakshmi Suaar Mills 20 100.00% 44.87 0.0% 44.87

Page 204

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

Sub-Total 119.92 119.92

Gas Gama 104 100.00% 575.77 0.0% 575.77

Beta 107 100.00% 0.00 0.0% 0.00

Shravanti 214 100.00% 1180.84 0.0% 1180.84 Sub-Total 1756.61 1756.61

Solar RV Akash Ganoa solar nower ltd 2 100.00% 2.57 0.0% 2.57

Metro Frozen 1 100.00% 1.21 0.0% 1.21 Jav Ace Techno!onies 2 100.00% 1.86 0.0% 1.86

UJVNL /1.4661 Dhakrani 1 100.00% 2.42 0.0% 2.42

UJVNL /4.398lkhodari 4 100.00% 7.11 0.0% 7.11

Redwoods 2 100.00% 0.00 0.0% 0.00

Madhav Infra 12 100.00% 19.50 0.0% 19.50

Purshotam Industries Ltd.-I @7.71 1 100.00% 1.07 0.0% 1.07

Purshotam Industries Ltd.-II @7.73 1 100.00% 1.24 0.0% 1.24

Purshotam Isoat-I @7.96 1 100.00% 1.34 0.0% 1.34

Vivaan Solar Pvt. Ltd. 4 100.00% 4.22 0.0% 4.22

Eastman International 1 100.00% 0.98 0.0% 0.98

Purshotam Isnat-II @7.88 1 100.00% 1.27 0.0% 1.27

R.C. Enerm, 1 100.00% 1.26 0.0% 1.26

Advika Enernv 1 100.00% 1.46 0.0% 1.46

A.R. Solar Power-I @5.670 1 100.00% 1.42 0.0% 1.42

A.R. Solar Power-II @S.690 1 100.00% 1.53 0.0% 1.53

Devishi Renewal enerqv 13 100.00% 21.53 0.0% 21.53

Devishi Solar oower 13 100.00% 21.71 0.0% 21.71

Eminet Solar oower 13 100.00% 21.20 0.0% 21.20

Sunworld Enerov nvt 13 100.00% 20.24 0.0% 20.24

Emami Power Ltd. 20 100.00% 30.53 0.0% 30.53

Hvdro Power Ennineers 1 100.00% 1.53 0.0% 1.53

Imnex India 2 100.00% 3.77 0.0% 3.77

Technique Solaire Invest 5 100.00% 7.93 0.0% 7.93

Makin Develoners Pvt. Ltd 1 100.00% 1.63 0.0% 1.63

Balluour solar oower ovt.Ltd 10 100.00% 15.53 0.0% 15.53

C11udiala Solar nower nroiect nvt. 10 100.00% 16.13 0.0% 16.13

Shakumbhari solar nower oroiect nvt Ltd 10 100.00% 15.94 0.0% 15.94

Bindookharak solar nower nroiect nvt ltd 5 100.00% 8.?9 0.0% 8.29

Bhaowanpur solar nrolects nrivate ltd 5 100.00% 8.32 0.0% 8.32

Page 205

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

PL sunravs oower limited 10 100.00% 17.02 0.0% 17.02 PL surva vidvut ltd 10 100.00% 16.68 0.0% 16.68 PL solar Renewable ltd 10 100.00% 16.01 0.0% 16.01 Haridwar solar nroiects pvt ltd 1 10 100.00% 16.13 0.0% 16.13 Haridwar solar oroiects ovt ltd 2 10 100.00% 16.57 0.0% 16.57 Sunheti solar power proi ovt ltd 5 100.00% 7.79 0.0% 7.79 AB Renewable Enerm, ovt ltd 5 100.00% 7.61 0.0% 7.61 Canal Bank Solar ov olant Dhakrani 7 100.00% 10.06 0.0% 10.06 Canal Bank Solar ov plant Dhaliour 8 100.00% 11.22 0.0% 11.22 Canal Too Solar nv nlant Dhalipur 1 100.00% 1.03 0.0% 1.03 Dakoatthar canal Bank (4.5 MWl 5 100.00% 6.89 0.0% 6.89 Sub-Total 371.77 371.77

Solar Rooftoo EDC DEHRADUN 0.50 0.0% 0.50 EDC SRINAGAR 0.34 0.0% 0.34 EDC TEHR! 0.00 0.0% 0.00 UDC DEHRADUN 0.02 0.0% 0.02 EDCHARIDWAR 0.63 0.0% 0.63 EDC ROORKEE 4.14 0.0% 4.14 EDC HALDWAN! 0.04 0.0% 0.04 EDC KASHIPUR 0.00 0.0% 0.00 EDC RAN!KHET 0.00 0.0% 0.00 EDC RUDRAPUR 1.83 0.0% 1.83 EDC P!THORAGARH 0.00 0.0% 0.00 Sub-Total 7.48 7.48

Other Larae Private Meia Thermal I 660 1.97% 29.57 4.2% 28.33 Sasan 3722 2.66% 662.91 4.2% 635.05 Sub-Total 692.47 663.37 Total IPP 3528.13 3490.20 Uocomina Stations Meia Thermal II 660 1.97% 0.00 . 0.00 Tanda II 1320 1.97% 0.00 . 0.00 Bhvunder Ganaa 24 100.00% 0.00 . 0.00 Khairo Ganqa 3 100.00% 0.00 . 0.00 Vvasi 120 100.00% 0.00 . 0.00 Taoovan Vishnuqad 520 16.00% 0.00 . 0.00 Tehri Pumn Storaae 1000 5.00% 0.00 . 0.00

Page 206

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESQ) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

Vishnuqad 400 15.00% 0.00 - 0.00 Melkhet 24 100.00% 0.00 - 0.00 SEC! Solar 200 100.00% 0.00 - 0.00 SECI Non-Solar 100 100.00% 0.00 - 0.00 UREDA Solar 200 100.00% 0.00 - 0.00 Sub-Total - -

State Rovaltv Power Dhauliaanaa 280 12.00% 151.40 4.2% 145.04 Tanaknur 94 12.00% 51.42 4.2% 49.26 Tehri 1000 12.00% 352. 73 4.2% 337.91 Koteshwar 400 12.00% 139.48 4.2% 133.62 Vishnu Pravao 400 12.00% 226.50 4.2% 216.98 GVK Srinaaar 330 12.00% 157.28 4.2% 150.67 Raiwakti Him Uria SHP 5 12.00% 2.22 0.0% 2.22 Sub-Total 1081.04 1035.71 Total Power Purchase from Firm Sources 13333.04 13067.88 Ooen Market Purchases & UI Bankina Received 0.00 4.2% 0.00 UI Net drawal 0.00 4.2% 0.00 Tender Purchases 0.00 4.2% 0.00 IEX (Net Purchases! . 0.00 4.2% 0.00 Reactive Pavables 686.95 4.2% 658.08 Ooen Market Purchase ( Extra l 707.25 0.0% 677.53 Sub-Total 1394.20 1335.61 Total Purchases 14727.24 14403.49 Less: -Bankina Pavable 0.00 0.0% 0.00 UI Underdrawal 0.00 0.0% 0.00 Reactive Units Receivables 0.00 0.0% 0.00 Sub-Total 0.00 o.oo

I I State Consumntion I I 14727.241 14210.43

Page 207

Name of Distribution Licensee Licensed Area of Supply

Form: F-2,5

Energy Distribution

FY 2020-21

Source of Power (Station wise)

NHPC Sal al TanakDUr Chamera I Chamera II

Chamera III Uri Dhauliaanoa Dulhasti Sewa II Uri II Parbati III Kishanaanoa Sub-Total

SJVNL Nathoa Jhakri Rampur Eauitv Power Ramour Free Power Sub-Total

THDC Tehri HEP I Koteshwar Sub-Total

NTPC Sinqrauli F G Unchahar-I F G Unchahar-2

Installed Capciity

UK Share

(MW) (%)

690 1.21% 94 3.89%

540 3.53% 300 2.44%

231 6.14% 480 3.48% 280 6.10% 390 6.14% 120 6.20% 240 5.35% 520 6.14% 330 0.00%

1500 1.43% 412 11.63% 412 0.00%

1000 3.84% 400 6.81%

2000 5.22% 420 8.72% 420 4.08%

Uttarakhand Power Corporation Limited Uttarakhand

Energy Sent Inter-State Out (ESO) Transmissio Units received at State from the n Losses periphery (MU)

station (MU) (%)

38.50 4.2% 36.88 8.63 4.2% 8.27

80.43 4.2% 77.05 26.06 4.2% 24.96

54.68 4.2% 52.38 91. 71 4.2% 87.85 54.23 4.2% 51.95

125.57 4.2% 120.29 27.69 4.2% 26.53 73.65 4.2% 70.55 35.95 4.2% 34.44 17.43 4.2% 16.70

634.53 607.87

79.09 4.2% 75.77 214.57 4.2% 205. 55

0.00 0.0% 0.00 293.66 281.32

110.74 4.2% 106.09 79.09 4.2% 75.76

189.83 181.85

726.45 4.2% 695.92 214.89 4.2% 205.86 100.60 4.2% 96.38

Page 208

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

F G Unchahar-3 210 6.67% 82.12 4.2% 78.67 F G Unchahar-4 500 6.16% 146.99 4.2% 140.81 N CTDadri:2 980 0.44% 22.09 4.2% 21.16 Rihand-1 STPS 1000 4.33% 309.33 4.2% 296.33 Rihand-2 STPS 1000 3.84% 273.96 4.2% 262.45 Rihand-3 STPS 1000 4.46% 318.48 4.2% 305.10 Kahalaaon-II 1500 1.90% 186.54 4.2% 178. 70 Jhaiiar Aravali 1500 0.88% 57.04 4.2% 54.64 Sinqrauli SHEP 8 2.16% 0.00 0.0% 0.00 Koldam (Hvdrol 800 6.78% 203.25 4.2% 194.71 Barh STP I 0 0.00% o.oo 0.0% 0.00 Barh STP II 0 0.00% 0.00 0.0% 0.00 North Karanoura 0 0.00% 0.00 0.0% 0.00 Sinqrauli STPS Ill 0 0.00% 0.00 0.0% 0.00 Anta Gas . 419 5.52% 15.26 4.2% 14.62 Auralva Gas 663 5.14% 12.20 4.2% 11.69 Dadri Gas 830 4.41% 64.47 4.2% 61.76 Sub-Total 2733.68 2618.80

NPCIL Narora APP 440 5.38% 160.74 4.2% 153.99 Raiasthan APP 440 5.66% 166.45 4.2% 159.45 Sub-Total 327.19 313.44 Total CSGS 4178.90 4003.29 UJVNL larqe Hydro Dhakrani 34 75.00% 86.59 0.0% 86.59 Dhaliour 51 75.00% 149.46 0.0% 149.46 Chibro 240 75.00% 574.00 0.0% 574.00 Khodri 120 75.00% 293.67 0.0% 293.67 Kulhal 30 80.00% 99.24 0.0% 99.24 Ramoanoa 198 100.00% 203.54 0.0% 203.54 Tiloth 90 100.00% 382.90 0.0% 382.90 Chilla 144 100.00% 721.00 0.0% 721.00 Khatima 41 100.00% 200.45 0.0% 200.45 UJVNL Receivable 0 0.00% 0.00 0.0% 0.00 Sub-Total 2710.85 2710.85

Maneri Bhali II 304 100.00% 1265.23 0.0% 1265.23

(\

(~ Page 209

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

Small Hvdro Mohd. Pur 9 100.00% 52.90 0.0% 52.90 Pathri 20 100.00% 120.99 0.0% 120.99 Kanchauti 0 0.00% 0.00 0.0% 0.00 Chhirkila 0 0.00% 0.00 0.0% 0.00 Kulaaarh 0 0.00% 0.00 0.0% 0.00 Relaqad 0 0.00% 0.00 0.0% 0.00 Dunao SHP 1.5 MW 2 100.00% 2.39 0.0% 2.39 Surinoarh 0 0.00% o.oo 0.0% 0.00 Saoteshwar 0 0.00% 0.00 0.0% 0.00 Gauri 0 0.00% 0.00 0.0% 0.00 Pandukeshwar 0 0.00% 0.00 0.0% 0.00 Taleshwar 0 0.00% 0.00 0.0% 0.00 Chharandev 0 0.00% 0.00 0.0% 0.00 Kotabaqh 0 0.00% 0.00 0.0% 0.00 Harsil 0 0.00% 0.01 0.0% 0.01 Pilanaad 2 100.00% 1.78 0.0% 1.78 Tharali 0 0.00% 0.00 0.0% 0.00 Uraam 0 100.00% 2.43 0.0% 2.43 Soneoravao 0 0.00% 0.00 0.0% 0.00 Badrinath 0 0.00% 0.13 0.0% 0.13 Tilwara 0 100.00% o.oo 0.0% 0.00 Taoovan 0 0.00% 0.00 0.0% 0.00 Jumma 0 0.00% 0.00 0.0% 0.00 Galoai 3 100.00% 6.45 0.0% 6.45 Kal\aanoa 0 0.00% 0.00 0.0% 0.00 Sub-Total 187.07 187.07 Total UJVNL 4163.15 4163.15 UREDA SHPs UREDA: Bhikurlva Gardh 1 100.00% 0.00 0.0% 0.00 Ramqarh 0 100.00% 0.01 0.0% 0.01 Barar + Garaun 1 100.00% 0.08 0.0% 0.08 Surinaarh 1 100.00% 0.00 0.0% 0.00 Santeshwar 0 100.00% 0.00 0.0% 0.00 Gauri 0 100.00% 0.00 0.0% 0.00 Taleshwar 1 100.00% 1.69 0.0% 1.69 Chharandev 0 100.00% 0.69 0.0% 0.69 Kotabaah 0 100.00% 0.00 0.0% 0.00 Harsil 0 100.00% 0.21 0.0% 0.21 ~

~ Page 210

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO} Transmissio Units received at State

(MW) (%} from the n losses periphery (MU)

station (MU) (%)

Tharali 0 100.00% 0.29 0.0% 0.29 Badrinatl1 1 100.00% 0.40 0.0% 0.40 UREDA: Kanoload SHP 0 0.00% 0.00 0.0% 0.00 UREDA: Lathi SHP 0 0.00% 0.00 0.0% 0.00 UREDA: Barsol SHP 0 100.00% 0.00 0.0% 0.00 UREDA: Milkhet SHP 24 100.00% 0.00 0.0% 0.00 Sub Total 3.38 3.38 UREDA Solar Solar Plant Dehra Dun 0 100.00% 0.00 0.0% 0.00 Sub Total 0.00 0.00 UREDA Biomass Avni Bio Enerqv 0 0.00% 0.00 0.0% 0.00 Sub-Total 0.00 0.00

IPP Hvdro Raiwakti Him Uria SHP 5 88.00% 19.43 0.0% 19.43 Hanuman Ganaa SHP s 100.00% 0.00 0.0% 0.00 Greenko Budhil Hvdro Power Pvt Ltd 70 100.00% 253.82 4.2% 243.16 Debal chamoli hvdro s 100.00% 17.81 0.0% 17.81 LoharKhet ( parvativa oowerJ 5 100.00% 19.69 0.0% 19.69 Gunsola Hvdro Aaunda Thati 3 100.00% 13.17 0.0% 13.17 Bhllanaana( Swasti J 23 100.00% 90.47 0.0% 90.47 Vanala 15 100.00% 41.93 0.0% 41.93 Motiahat 5 100.00% 0.00 0.0% 0.00 Rishioanoa 13 100.00% 0.00 0.0% 0.00 Birahi Ganaa 7 100.00% 24.41 0.0% 24.41 Tanoa (HHPLl 5 100.00% 0.00 0.0% 0.00 HHL: Jalandharinad 0 0.00% 0.00 0.0% 0.00 HHL: Sivanaad 0 0.00% 0.00 0.0% 0.00 HHL: Kakoraaad 0 0.00% 0.00 0.0% 0.00 Sar'iu II 13 100.00% 22.33 0.0% 22.33 Uttar Bharat Sariu III 11 100.00% 19.42 0.0% 19.42 Ganoani 8 100.00% 40.09 0.0% 40.09 Badivar 5 100.00% 15.13 0.0% 15.13 Sub-Total 577.71 567.04

Co-Generation RBNS Suaar Mill 19 100.00% 41.77 0.0% 41.77 Uttam Suaar Mills 13 100.00% 29.90 0.0% 29.90 Lakshmi Suoar Mills 20 100.00% 54.08 0.0% 54.08

, O Page 211 '~

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (O/o) from the n Losses periphery (MU)

station (MU) (%)

Sub-Total 125.75 125.75

Gas Gama 104 100.00% 575.77 0.0% 575.77 Beta 107 100.00% 0.00 0.0% 0.00 Shravanti 214 100.00% 834.22 0.0% 834.22 Sub-Total 1409.98 1409.98

Solar RV Akash Ganqa solar power ltd 2 100.00% 2.57 0.0% 2.57 Metro Frozen 1 100.00% 1.21 0.0% 1.21 Jav Ace Technoloaies 2 100.00% 1.86 0.0% 1.86 UJVNL (1.466) Dhakrani 1 100.00% 2.42 0.0% 2.42 UlVNL ( 4.3981khodari 4 100.00% 7.11 0.0% 7.11 Redwoods 2 100.00% 0.00 0.0% 0.00 Madhav Infra 12 100.00% 19.50 0.0% 19.50 Purshotam Industries Ltd.-I @7.71 1 100.00% 1.07 0.0% 1.07 Purshotam Industries Ltd.-II @7.73 1 100.00% 1.24 0.0% 1.24 Purshotam Isoat-I @7 .96 1 100.00% 1.34 0.0% 1.34 Vivaan Solar Pvt. Ltd. 4 100.00% 4.22 0.0% 4.22 Eastman International 1 100.00% 0.98 0.0% 0.98 Purshotam Isoat-II @7.88 1 100.00% 1.27 0.0% 1. 27 R.C. Enerav 1 100.00% 1.26 0.0% 1.26 Advika Enernv 1 100.00% 1.46 0.0% 1.46 A.R. Solar Power-I @5.670 1 100.00% 1.42 0.0% 1.42 A.R. Solar Power-II @5.690 1 100.00% 1.53 0.0% 1.53 Devishi Renewal ener"" 13 100.00% 21.53 0.0% 21.53 Devishi Solar oower 13 100.00% 21.71 0.0% 21.71 Eminet Solar nower 13 100.00% 21.20 0.0% 21.20 Sunworld Enerav ovt 13 100.00% 20.24 0.0% 20.24 Emami Power Ltd. 20 100.00% 30.53 0.0% 30.53 Hvdro Power Ennineers 1 100.00% 1.53 0.0% 1.53 Imnex India 2 100.00% 3.77 0.0% 3.77 Techniaue Solaire Invest 5 100.00% 7.93 0.0% 7.93 Makin Developers Pvt. Ltd 1 100.00% 1.63 0.0% 1.63 Balluour solar oower ovt.Ltd 10 100.00% 15.53 0.0% 15.53 Chudiala Solar oower oroiect ovt. 10 100.00% 16.13 0.0% 16.13 Shakumbhari solar oower nroiect ovt Ltd 10 100.00% 15.94 0.0% 15.94 Bindookharak solar oower oroiect ovt ltd 5 100.00% 8.29 0.0% 8.29 Bhaowannur solar nroiects nrivate ltd 5 100.00% 8.32 0.0% 8.32

Page 212

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

PL sunravs Power limited 10 100.00% 17.02 0.0% 17.02 PL surva vidvut ltd 10 100.00% 16.68 0.0% 16.68 PL solar Renewable ltd 10 100.00% 16.01 0.0% 16.01 Haridwar solar oroiects pvt ltd 1 10 100.00% 16.13 0.0% 16.13 Haridwar solar oroiects nvt ltd 2 10 100.00% 16.57 0.0% 16.57 Sunheti solar oower oroi ovt ltd 5 100.00% 7.79 0.0% 7.79 AB Renewable Enernv ovt ltd 5 100.00% 7.61 0.0% 7.61 Canal Bank Solar nv 11\ant Dhakrani 7 100.00% 10.06 0.0% 10.06 Canal Bank Solar ov olant Dhaliour 8 100.00% 11.22 0.0% 11.22 Canal Top Solar ov plant Dhaliour 1 100.00% 1.03 0.0% 1.03 Dakoatthar canal Bank r 4.5 MWI 5 100.00% 6.89 0.0% 6.89 Sub-Total 371.77 371.77

Solar Rooftoo EDC DEHRADUN 0.50 0.0% 0.50 EDC SRINAGAR 0.34 0.0% 0.34 EDC TEHRI 0.00 0.0% 0.00 UDC DEHRADUN 0.02 0.0% 0.02 EDC HARIDWAR 0.63 0.0% 0.63 EDC ROORKEE 4.14 0.0% 4.14 EDC HALDWANI 0.04 0.0% 0.04 EDC KASHIPUR 0.00 0.0% 0.00 EDC RANIKHET 0.00 0.0% 0.00 EDC RUDRAPUR 1.83 0.0% 1.83 EDC PTTHORAGARH 0.00 0.0% 0.00 Sub-Total 7.48 7.48

.

Other Larae Private Meia Thermal I 660 1.97% 0.00 0.0% 0.00 Sasan 3722 2.66% 708.30 4.2% 678.54 Sub~Total 708.30 678.54 Total IPP 3204.38 3163.95 Uocomina Stations Meia Thermal II 660 1.97% 173.80 - 166.50 Tanda II 1320 1.97% 174.29 - 166.97 Bhvunder Ganoa 24 100.00% 0.00 - 0.00 Khairo Ganaa 3 100.00% 0.00 - 0.00 Vvasl 120 100.00% 370. 74 - 370. 74 Tapovan Vishnuqad 520 16.00% 90.68 - 86.87 Tehri Pumo Storaqe 1000 5.00% 0.00 - 0.00

Page 213

Installed Energy Sent Inter-State

Source of Power (Station wise) Capciity UK Share Out (ESO) Transmissio Units received at State

(MW) (%) from the n Losses periphery (MU)

station (MU) (%)

Vishnuoad 400 15.00% 0.00 - 0.00 Melkhet 24 100.00% 0.00 - 0.00 SEC! Solar 200 100.00% 167.49 - 160.45 SECI Non-Solar 100 100.00% 104.68 - 100.28 UREDA Solar 200 100.00% 286.35 - 286.35 Sub-Total 1 368.03 1-338.15

State Royalty Power Dhaulioanaa 280 12.00% 126.59 4.2% 121.27 Tanakour 94 12.00% 39.44 4.2% 37.78 Tehri 1000 12.00% 374.59 4.2% 358.85 Koteshwar 400 12.00% 145.81 4.2% 139.68 Vishnu Pravao 400 12.00% 227.57 4.2% 218.00 GVK Srinaaar 330 12.00% 147.12 4.2% 140.93 Raiwakti Him Uria SHP 5 12.00% 1.49 0.0% 1.49 Sub-Total 1062.60 1018.01 Total Power Purchase from Firm Sources 13977.06 13686.55 Ooen Market Purchases & UI Bankinq Received 0.00 0.0% 0.00 UI Net drawal 0.00 0.0% 0.00 Tender Purchases 0.00 0.0% 0.00 IEX r Net Purchases\ 1141.87 4.2% 1093.88 Reactive Pavables 0.00 0.0% 0.00 Qnen Market Purchase (Extra\ 0.00 0.0% 0.00 Sub-Total 1141.87 1093.88 Total Purchases 15118.93 14780.43 Less: -Bankina Pavable 0.00 0.0% 0.00 UI Underdrawal 0.00 0.0% 0.00 Reactive Units Receivables 0.00 0.0% 0.00 Sub-Total 0.00 0.00

I I

State Consumntion I 15118.93 I 14808.12

Page 214

Name of Distribution Licensee

Licensed Area of Supply

Form: F-2.6

Availability of Power (Power Purchased at Ex Bus) FY201S-19

Details of the stations NHPC Salal Tanaknur Chamera I Chamera II Chamera III Uri Dhaulinanna Dulhastl Sewa II Uri II Parbati III Kishannanna Sub-Total

SJVNL Nathr::a Jhakri Rampur Eauitv Power

Ramour Free Power Sub-Total

THDC Tehri HEP I Koteshwar Sub-Total

NTPC Sinarauli F G Unchahar-I F G Unchahar-2 F G Unchahar-3 F G Unchahar-4 NC T Oadri:2 Rihand-1 STPS Rihand-2 STPS Rihand-3 STPS Kahaloaon-Il Jhaiiar Aravali Slnorauli SHEP

Ao,

2.38 0.00 4.46 2.35 3.78

10.38 2.29 9.61 2.71 8.55 1.20 0.00

47.70

3.78

9.00 0.00

12.78

6.31 5.04

11.35

40.37 21.41

9.29 3.90 0.00 2.40

14.19 22.35 24.64 17.42

5.84 0.04

Uttarakhand Power Corporation Limited

Uttarakhand

Mav

3.79 0.10 6.79 4.29 7.19

12.29 4.81

17.71 1.77

10.73 2.45 0.00

71.93

6.89

16.45 0.00

23.34

5.06 4.39 9.45

50.32 19.99 8.77 4.24 0.00 1.82

21.80 13.48 24.22 12.28

5.65 0.04

Jun

5.67 0.74 9,66 4.61 8.49

10.43 7.97

15.99 1.34

10.40 4.26 1.23

80.79

14.22

33.45 0.00

47.67

6.91 6.49

13.40

43.42 17.09

9.45 6,55 0.00 0.45

19.81 10.79 19.70 10.52 12.40

0.04

Jul Auo

6.09 5.88 0.90 1.50

13.23 14.00 0.00 0.00 6.68 6.59

12.16 11.01 6.69 6.93 9.78 10.55 2.04 2.52 7.35 7.15 5.31 6.48 0.00 0.00

70.24 72.60

0.00 0.00

33.28 27.29 0.00 o.oo

33.28 27.29

6.13 15.47 5.58 12.12

11.72 27.59

48.23 55.76 28.66 16.48 11.95 12.15 10.94 7 .11

0.00 0.00 0.00 0.00

26.02 22.17 21.55 20.69 26.23 23.59 12.54 13.39

0.00 0.00 0.00 0.00

(Figures in MU

Sen Oct Nov Dec I Jan Feb Mac Total

4.66 2.03 1.47 1.07 1.29 2.10 2.59 39.02 2.15 1.75 0.97 0.54 0.66 0.63 0.61 10.55 9.51 6.49 3.56 2.49 2.27 6.26 6.88 85.61 0.00 0.87 1.83 1.17 1.08 1.68 2.04 19.92 4.79 3.72 2.86 1.58 1.22 2.09 2.99 s·:_.97 5.59 4.34 5.91 3.89 4.56 8.69 12.21 lCl.45 6.79 4.01 3.11 2.11 1.77 1.61 2.36 50.44

11.42 10.44 8.88 6.47 4.82 5.19 6.74 117.60 1.65 1.27 1.43 0.73 1.29 4.75 5.52 27.00 4.23 3.35 4.52 2.95 3.31 5.61 7.81 75.97 4.43 2.02 1.61 0.73 0.00 0.00 0.00 28.48 0.00 0.43 0.41 0.63 0.52 0.50 0.90 4.63

55.22 40.72 36.55 24.36 22.79 39.11 50.65 612.65

I 0.00 2.08 4.31 3.34 2.90 2.46 3.04 43.02

26.75 13.95 9.94 7.65 6.72 5.71 7.03 197.21 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

26.75 16.03 14.24 10.99 9.62 8.17 10.06 240.22

l.1.36 5.98 8.23 9.69 11.48 9.00 10.45 106.07 8.15 3.83 4.77 5.79 7.22 5.96 7.46 76.80

19.51 9.81 12.99 15.48 18.70 14.96 17.91 182.86

63.54 59.52 61.35 65.59 57.29 52.56 57.70 655.17 17.35 16.55 19.29 17.36 17.07 16.26 12.34 219.85 15.13 7.07 8.67 6.79 6.54 5.54 4.00 105.:35

7.50 5.64 6.12 5.75 5.13 4.35 3.20 70.4 7 0.00 0.00 0.00 4.48 10.84 9.18 6.59 31.08 0.00 0.02 0.03 0.02 0.03 0.02 0.01 4.79

20.43 20.08 19.44 16.081 23.27 18.74 17.40 239 .43 20.96 20.67 18.89 21.60 17.18 16.74 13.76 218.67 20.61 11.33 20.96 21.73 22.85 18.02 14.93 248.82 11.34 12.44 13.48 14.66 12.99 10.10 6.92 148.09

0.00 0.94 2.68 2.44 2.36 2.28 0.82 36.42 0.00 0.00 0.00 0.00 0.02 0.04 0.05 0.25

(1 4-. ~ Page215

Details of the stations Anc Mau Jun Jul Aun Sen Oct Nov Dec Jan Feb Mac Total

Koldam rH----;--;-dro) 6.30 11.49 27.21 34.52 38.05 25.01 11.61 8.24 6.21 5.68 6.33 7.41 188.06

Barh STP I 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Barh STP II 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

North Kararl;.,ura o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00

Sinnrauli STPS III 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Anta Gas 0.00 0.20 0.24 0.00 0.00 0.13 0.33 1.35 0.00 2.35 a.so 0.00 5.10

Auraiva Gas 0.00 0.90 0.00 0.31 0.96 0.37 0.97 0.93 0.03 0.00 0.51 0.00 4.99

Dadri Gas 6.45 9.26 3.55 3.33 0.48 2.41 0.58 1.23 3.33 1.19 4.91 5.30 42.02

Sub-Total 175.60 184.48 181.23 224.27 210.81 204.78 167.75 182.67 186.07 184.80 166.10 149.94 2218.49

NPCIL Narora APP 9.41 10.40 13.14 10.32 9.83 9.72 13.15 16.77 16.80 8.71 8.59 16.48 143.32

Raiasthan APP 18.77 20.35 19.33 10.14 10.21 5.62 10.98 16.90 17.68 17.63 13.23 13.65 174.49

Sub-Total 28.18 30.75 32.47 20.47 20.04 15.34 24.12 33.67 34.47 26.34 21.82 30.13 317.80

Total CSGS 275.62 319.93 355.55 359.96 358.34 321.60 258.42 280.12 271.39 262.24 250.16 258.69 3572.03

UJVNL Larne H"dro Dhakranl 4.78 4.99 7.77 10.55 15.06 14.87 12.84 6.67 4.05 3.52 6.85 8.38 100.35

Dhalinur 5.99 9.11 12.66 17.97 24.21 23.02 21.13 11.52 7.78 6.80 11.04 13.63 164.86

Chibro 23.45 34.75 47.94 68.90 104.66 91.16 67 .09 35.67 25.23 21.88 3! .53 45.24 603.50

Khodri 10.38 15.51 21.92 31.20 42.08 38.46 30.45 16.80 11.17 9.53 16.77 21.13 765.40

Kulhal 4.61 6.46 8.97 12.16 11.67 15.18 14.33 8.23 6.28 5.67 7.92 9.40 110.88

Ramqanna 2.87 35.26 8.15 -0.13 -0.17 -0.13 -0.11 2.09 33.30 66.27 6.54 29.65 183.60

Tlloth 27.81 53.34 60.59 36.08 8.06 59.01 58.35 36.73 25.73 10.77 19.68 26.69 422.84

Chilla 46.93 57.17 80.49 46.97 28.52 45.75 59.37 50.80 48.24 50.60 47.41 51.51 613.75

Khatlma 13.89 18.00 21.63 22.00 28.62 28.37 25.50 13.94 10.62 12.18 14.25 16.50 215.51

UJVNL Receivable 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sub-Total 140.71 234.60 270.14 245.68 262.72 315.71 288.95 182.45 172.39 187.23 167.98 222.12 2690.69

Maneri Bhali II 60.71 113.46 199.09 188.79 199.88 186.67 103.15 56.63 42.91 35.72 38.41 59.29 1284.73

Small H--;-;-dro Mohd. Pur 4.72 5.29 4.68 4.48 4.48 4.17 1.03 2.93 5.52 5.34 4.45 5.15 52.24

Pathri 9.73 13.08 13.17 12.20 9.54 8.11 2.14 6.80 10.36 10.00 8.31 10.80 114.25

Kanchauti 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Chhirklla 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00

Kulanarh 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Relanad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Dunao SHP 1.5 MW 2.36 0.02 0.00 0.04 0.21 0.50 0.31 0.33 0.30 0.27 0.27 0.28 4.88

Surinqarh o.oo 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sa"teshwar o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Gauri 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Pandukeshwar 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Taleshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Chharandev 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Kotabaqh o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00

Harsll 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Pilanr•ad 0.42 0.36 0.60 0.05 -0.01 -0.01 0.05 0.44 0.69 0.97 1.00 OSJ 5.10

Tharali 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Urnam 0.89 0.98 0.69 0.09 0.00 0.00 0.45 0.92 0.32 0.15 0.53 0.79 5.80

Sonenra~ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Badrinath 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Tilwara 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Tanovan 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Jurnma 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Page 216

Details of the stations Anc Mav Jun Jul Aun Sen Oct Nov Dec Jan Feb Mac Total

Galooi 0.49 0.41 0.04 0.00 0.04 0.48 1.04 0.86 0.70 0.68 0.61 0.60 5.96

Kalioanna 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sub-Total 18.60 20.15 19.18 16.86 14.24 13.25 5.02 12.27 17.90 17.42 15.18 18.15 188.22

Total UJVNL 220.03 368.21 488.42 451.34 476.84 515.63 397.12 251.35 233.21 240.37 221.57 299.56 4163.64

UREDA SHPs UREOA: Bhikuriva Gardh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Ramoarh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Barar + Garaun 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Surinnarh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Saoteshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Gauri 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 :J.00

Taleshwar 0.08 0.09 0.15 0.20 0.16 0.19 0.30 0.27 0.31 0.00 0.00 0.00 1. 74

Chharandev 0.04 0.01 0.05 0.09 0.10 0.05 0.01 0.15 0.11 0.11 0.28 0.00 1.0 l

Kotabanh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Harsil 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Tharali 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00

Badrinath 0.00 0.04 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.04

UREDA: Kanoload SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

UREDA: lathi SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

UREDA; Barsol SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

UREDA: Milkhet SHP 0.00 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00

Sub Total 0.13 0.14 0.19 0.30 0.26 0.24 0.31 0.42 0.42 0.11 0.28 0.00 2.80

UREDA Solar Solar Plant Dehra Dun 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sub Total o.oo o.oo 0.00 0.00 0.00 0.00 o.oo o.oo o.oo o.oo 0.00 o.oo o.oo

UREDA Biomass Avni Bio Enero" 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sub-Total 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

IPP Hvdro Raiwakti Him Uria SHP 0.98 1.20 1.66 2.01 7.38 2.27 2.57 2.32 1.59 1.35 1.29 1.61 21.24

Hanuman Ganoa SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Greenko Budhil Hydro Power Pvt Ltd 11.50 28.28 42.30 44.04 46.88 35.46 20.20 9.51 6.39 4.40 5.70 7.59 262.24

Debal ,chamoli h"dro 0.52 0.86 1.41 1.35 0.39 2.67 7.87 1.67 1.17 0.80 0.80 1.28 15.79

loharKhet I narvafr1a oower\ 0.82 0.87 1.79 2.24 7.67 2.74 3.06 1.96 1.36 1.05 1.17 1.99 71.72

Gunsola H"dro Anunda Thati 0.62 0.80 0.92 1.58 1.11 1.55 1.82 1.16 0.82 0.65 0.80 1.B 12.95

BhilanaanafSwasti\ 3.58 6.55 10.96 13.86 15.32 15.61 9.16 4.78 3.07 1.45 0.54 4.70 89.581

vanala I 1.89 2.66 4.49 6.96 5.78 6.06 7.12 4.59 2.94 2.22 7.25 3.03 49.97

Motiqhat 1.18 1.91 2.24 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.33

Rishinanna 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Birahi Ganaa 0.74 0.98 1.35 4.37 4.78 4.33 3.00 1.49 0.90 0.69 0.88 1.30 74.81

Tanoa (HHPL) 1.15 1.83 2.13 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.17

HHL: Jalandharinad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

HHL: Si11annad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

HHL: Kakoranad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sariu II 0.63 0.60 1.88 3.27 3.53 3.29 3.69 2.66 1.67 1.21 1.50 2.52 26.43

Uttar Bharat Sariu III 0.60 0.48 1.27 3.20 2.59 3.30 3.24 1.98 1.33 1.06 1.16 1.53 21.74

Gannani 2.65 3.64 3.59 3.84 3.56 4.66 4.59 3.30 ) .41 1.84 2.17 3.10 39.35

Badi"ar 0.77 0.90 1.17 1.32 1.45 1.72 1.77 1.62 1.15 0.85 1.23 1.67 15.61

Sub~Total 27.61 51.55 77.17 88.05 90.44 83.66 63.06 37.02 24.79 17.57 19.50 31.46 611.88

Page 217

Details of the stations An, Mav Jun Jul Aun Sea Oct Nov Dec Jan Feb Mac Total Co-Generation RBNS Suqar Mill 7.93 0.00 0.00 o.oo 0.00 0.00 0.00 1.93 8.65 8.47 8.32 9.05 44.35 Uttam Sunar Mills 6.45 0.00 0.00 0.00 0.00 0.00 0.00 1.97 3.10 5.78 4.78 4.33 26.41 Lakshmi Suqar Mills 11.28 0.48 o.oo o.oo o.oo 0.00 0.00 0.00 6.21 10.07 9.38 9.64 47.05 Sub-Total 25.65 0.48 0.00 0.00 0.00 o.oo o.oo 3.90 17.96 24.33 22.48 23.01 117.82

Gas Gama 50.73 64.24 58.43 21.57 -0.14 -0.15 63.36 -0.14 75.97 38.54 23.90 54.53 400.82 Beta 0.00 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 Shravanti 94.02 119.30 97.02 49.50 -0.20 ·0.19 133.21 28.02 54.16 95.91 74.91 76.86 822.52 Sub-Total 144.75 183.54 155.45 71.07 -0.34 -0.34 196,57 27.89 80.12 134.45 98.81 131.39 1223.35

Solar RV Akash Ganga solar power ltd 0.24 0.27 0.25 0.18 0.15 0.18 0.23 0.17 0.16 0.15 0.15 0.76 2.40 Metro Frozen 0.12 0.13 0.11 0.10 0.08 0.09 0.11 0.08 0.08 0.07 0.07 0.12 1.15 Ja" Ace Technolonies 0.20 0.20 0.18 0.15 0.13 0.12 0.19 0.13 0.14 0.13 0.12 0.70 1.88 UJVNL 11.466 l Dhakrani 0.22 0.24 0.21 0.18 0.15 0.18 0.24 0.19 0.19 0.16 0.16 0.23 2.35 UJVNL f 4.398)khodari 0.48 0.37 0.46 0.51 0.30 0.48 0.71 0.58 0.57 0.48 0.45 0.69 6.07 Redwoods 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Madhav Infra 1.95 2.03 1. 66 1.50 1.23 1.47 1.85 1.43 1.34 1.26 1.21 2.00 18.94 Pursnotam Industries Ltd.-I @7.71 0.10 0.10 0.09 0.08 0.06 0.08 0.11 0.09 0.08 0.08 0.07 0.12 1.07 Purshotam Industries Ltd.-II @7.73 0.12 0.12 0.11 0.10 0.07 0.10 0.13 0.10 0.10 0.09 0.08 0.14 1.26 Purshotam Isnat-I @7.96 0.14 0.14 0.13 0.11 0.08 0.11 0.14 0.12 0.11 0.10 0.09 0.16 1.42 Vivaan Solar Pvt. Ltd. 0.37 0.38 0.35 0.29 0.23 0.31 0.40 0.32 0.31 0.28 0.26 0.45 3.93 Eastman International 0.10 0.10 0.08 0.07 0.06 0.07 0.09 0.07 0.07 0.06 0.06 0.10 0.93 Purshotam Ispat-II @7.88 0.13 0.13 0.12 0.10 0.08 0.10 0.13 0.11 0.11 0.09 0.09 0.15 1.34 R.C. Ener 0.11 0.13 0.12 0.10 0.07 0.08 0.11 0.10 0.10 0.08 0.08 0.12 1.20 Advika Enernv 0.13 0.16 0.14 0.11 0.08 0.10 0.12 0.10 0.10 0.09 0.09 0.14 1.35 A.R. Solar Power~I @5.670 0.13 0.16 0.15 0.12 0.10 0.12 0.14 0.10 0.10 0.07 0.09 0.14 1.47 A.R. Solar Power-II @5.690 0.16 0.14 0.15 0.12 0.11 0.12 0.13 0.09 0.10 0.09 0.10 0.14 1.47 Devishi Renewal enerm,. 1. 96 2.13 1.92 1.64 1.25 1.59 1.93 1.50 1.46 1.48 1. 79 2.28 20.44 Devishi Solar riower 1.97 2.14 1.93 1.65 1.25 1.60 1.99 1.53 1.47 1.51 1.31 2.32 20.70 Eminet Solar nower 2.07 2.31 1.92 1.84 1.32 1.79 2.00 1.60 1.47 1.42 1.30 2.18 21.22 Sunworld Enerqv pvt 1.98 2.19 1.84 1.71 1.28 1.65 1.85 1.49 1.39 1.34 1.25 2.12 20.10 Emami Power Ltd. 2.71 3.03 2.70 2.35 7.06 2.21 2.97 2.32 2.10 2.06 2.05 2.98 29.55 Hvdro Power 'Enaineers 0.13 0.17 0.14 0.12 0.10 0.12 0.14 0.11 0.09 0.09 0.09 0.15 1.44 Imnex India D.33 0.39 0.34 0.22 0.25 0.29 0.36 0.27 0.25 0.25 0.24 0.35 3.55 Technlaue Solaire Invest 0.73 0.74 0.69 0.52 0.47 0.56 0.73 0.56 0.56 0.49 a.so 0.80 7.35 Makin Developers Pvt. Ltd 0.14 0.17 0.15 0.12 0.11 0.12 0.15 0.11 0.11 0.10 0.11 0.16 1.55

Ballunur solar nower ovt.Ltd 1.34 1.53 1.49 1.22 1.03 1.11 1.44 1.13 1.11 1.09 1.01 1.62 15.11 Chudlala Solar power project

1·ovt. 1.36 1.53 1.48 1.22 1.04 1.12 1.48 1.15 1.13 1.09 1.02 1.64 15.23 Shakumbhari solar power loroiect ovt Ltd 1.29 1.52 1.49 1.22 1.04 1.11 1.47 1.15 1.12 1.08 1. 01 1.64 15.12 Bindookharak solar power

loroiect ovt ltd 0.73 0.83 0.77 0.64 0.56 0.60 0.77 0.63 0.57 0.57 0.50 0.86 8.01 Bhagwanpur solar projects

lnrivate ltd 0.73 0.82 0.78 0.64 0.56 0.60 0.80 0.62 0.57 0.57 0.51 0.85 8.04 PL sunravs oower limited 1.42 1.56 1.39 1.30 1.02 1.30 1.50 1. 28 1.25 1.18 1.03 1.75 15.99 PL surva vidvut ltd 1.35 1.50 1.34 1.25 1.02 1.28 1.44 1.30 1.26 1.23 1.02 1.72 15.72 PL solar Renewable ltd 1.31 1.54 1.42 1.29 1.00 1.26 1.37 1.15 1.23 1.11 0.99 1.72 15.39

Page 218

Details of the stations Anc Mav Jun Jul Auq Sen Haridwar solar projects pvt ltd 1 1.45 1.62 1.57 1.26 1.10 1.17 Haridwar solar projects pvt ltd 2 1.42 1.63 1.53 1.27 1.12 1.19

Sunheti solar nower nro; ovt ltd 0.72 0.77 0.64 0.59 0.50 0.56

AB Renewable Enerav nvt ltd 0.80 0.81 0.69 0.56 0.51 0.54 Canal Bank Solar pv plant Dhakrani 0.99 0.97 0.89 0.72 0.59 0.66 Canal Bank Solar pv plant Dl1aliour 0.76 0.83 0.74 0.68 0.59 0.87 Canal Top Solar pv plant Dhalinur 0.12 0.01 0.00 0.00 0.00 0.00 Dakpatthar canal Bank (4.5 MW; 0.55 0.55 0.55 0,51 0.44 0.56 Sub-Total 33.08 36.09 32.72 28.35 23.19 27.55

Solar Roofton EDC DEHRADUN 0.05 -0.11 -0.04 0.00 0.26 0.29 EDC SRINAGAR 0.07 0.06 0.06 0.04 0.04 0.05 EDC TEHRI 0.00 0.00 0.00 0.00 o.oo 0.00 UDC DEHRADUN 0.00 0.00 o.oo 0.00 0.00 0.00 EDC HARIDWAR 0.11 0.11 0.10 0.08 0.06 0.08 EDC ROORKEE 0.42 0.40 0.40 0.35 0.28 0.34 EDC HALDWANI 0.02 0.02 0.01 0.01 0.01 0.01 EDC KASHIPUR 0.00 o.oo 0.00 0.00 0.00 0.00 EDC RANIKHET 0.00 0.00 0.00 0.00 0.00 0.00 EDC RUDRAPUR 0.29 0.32 0.28 0.23 0.16 0.24 EDC PITHORAGARH 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total 0.95 0.80 0.82 0.72 0.82 I..02

Other Larne Private Meia Thermal I 0.00 0.00 0.00 0.00 0.00 0.00 Sasan 65.24 61.42 60.05 53.57 48.13 56.02 Sub-Total 65.24 61.42 60.05 53.57 48.13 56.02 Total IPP 297.42 334.02 326.39 242.05 162.50 168.14

State Rovaltv Power Dhaulinanna 5.24 10.39 16.58 21.66 22.26 21.36 Tanaknur 0.43 1.68 3.95 4.12 5.99 7.48 Tehrl 18.84 15.37 20.69 28.26 73.30 53.03 Koteshwar 8.99 7.97 11.47 12.33 26.19 17.81 Vishnu Pravao 8.16 20.81 35.19 31.20 34.48 31.42 GVK Srinaaar 4.50 8.53 15.92 25.52 28.20 26.29 Raiwakti Him Uria SHP 0.11 0.13 0.18 0.22 0.26 0.25 Sub-Total 46.26 64.89 103.99 123.31 190.68 157.65 Total Power Purchase from Firm Sources 839.32 1087.05 1274.36 1176.66 1188.36 1163.02

Open Market Purchases & UI Bankinn Received 0.00 0.00 0.00 0.00 0.00 0.00 UI Net drawal -3.46 21.29 20.29 25.27 -24.64 -19.28 Tender Purchases 15.26 19.81 19.39 115.89 213.79 /45.90

Oct Nov Dec Jan

1.57 1. '.) 1 1.11 1.12

1.55 1.25 1.13 LP

0.73 0.58 0.55 0.51

0.75 0.61 0.55 0.55

0.89 0.72 0:71 0.62

1.10 0.83 0.80 0.67

0.00 0.01 0.05 0.06

0. 71 0.57 0.57 0.47 34.52 27.47 26.29 25.04

0.13 0.06 0.15 0.15 0.07 0.06 0.06 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.10 0.09 0.08 0.07 0.44 0.33 0.32 0.281 0.01 0.01 0.01 0.001 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.29 0.25 0.23 0.22 0.00 0.00 0.00 0.00 l..04 a.so 0.86 0.75

0.00 0.00 0.00 0.00 61.88 63.07 66.77 64.46 61.88 63.07 66.77 64.46

357.39 160.58 217.21 266.70

10.71 6.20 4.44 3.55 6.36 3.62 1.82 1.77

23.44 24.95 30.01 34.08 7.63 8.23 10.14 12.24

18.46 9.89 7.60 6.13 14.91 7.70 5.55 4.45

0.29 0.26 0.18 0.15 81.80 60.85 59.75 62.38

1094.74 752.90 781.56 831.69

37.?0 165.80 195.27 194.40 -18.99 0.96 2.79 1.87 23.73 195.78 207.43 192.11

Feb

1.01

1.03

0.46

0.54

0.59

0.70

0.06

0.45 23.23

-0.03 0.03 0.00 0.00 0.16 0.30 0.00 0.00 0.00 0.19 0.00 0.66

0.00 58.30 58.30

223.25

3.30 1.86

26.39 10.06

5.10 4.50 0.14

51.35

746.33

157.32 -18.08 173.61

Mac Total

1.66 15.84

1. 71 15.94

0.82 7.43

0.87 7.79

1.02 9.38

1.06 9.65

0.10 0.41

0.71 6.64 38.25 355.77

0.05 0.95 0.10 0.66 0.00 0.00 0.00 0.03 0.13 1.17 2.46 6.33 0.00 0.1.2 0.00 0.00 0.00 0.00 0.64 3.35 0.00 0.00 3.37 12.61

0.00 0.00 64.76 723.68 64.76 T-'3.68

292.24 3047.90

4.66 130.36 1.82 40.90

30.70 379.07 12. 71 145.77

5.83 214.27 5.62 151.69 0.18 2.36

61.53 1064.43

912.02 11847.99

' 95.P 845.12 -14.79 -?6.771 199.17 1621.861

/;

?·Page219

Details of the stations ADC Mav Jun Jul Aua Seo Oct Nov Dec Jan Feb Mac Total IEX (Net Purchases\ 262.47 135.16 87.53 291.19 44.00 -18.77 -3.82 -41.41 -12.08 -12.28 -21.62 -110.44 599.91 Reactive Pavables 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00

Ooen Market Purchase (Extra• Sub-Total 274.27 176.25 127.21 432.34 233.15 207.85 38.12 321.13 393.41 376.11 291.23 169.06 3040.12 Total Purchases 1113.59 1263.30 1401.57 1609.00 1421.51 1370.86 1132.86 1074.03 1174.96 1207.79 1037.56 1081.08 14883.12 Less: Bankinn Pavable 0.00 0.00 72.50 256.95 231.81 195.30 15.52 41.67 0.00 o.oo 0.00 0.00 813.74 UI Underdrawal 0.00 0.00 0.00 0.00 o.oo 0.00 o.oo 0.00 0.00 o.oo 0.00 0.00 0.00 Reactive Units Receivables 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 Sub-Total 0.00 0.00 72.50 256.95 231.81 195.30 15.52 41.67 0.00 0.001 0.00 0.00 813.74

State Consumntion 1113.59 1263.30 1329.0S 1352.05 1189.70 1175.57 1117.34 1032.36 1174.96 1207.791 1037.56 1031.08 14074.33

/"'

~ '/

Page 220

Name of Distribution Licensee Licensed Area of Supply

Form: F-2.6

Uttarakhand Power Corporation Limited Uttarakhand

Availability of Power {Power Purchased at Ex Bus) FY2019-20

Details of the stations Ao, Mav Jun Jul NHPC Salal 5.14 5.50 6.05 5.89 Tanaknur 1.49 1.68 1.90 1.95 Chamera I 11.75 10.59 11.91 14.16 Chamera II 4.72 5.22 5.44 5.66 Chamera III 8.05 8.10 10.08 10.33 Uri 11.95 12.40 11.95 10.54 Dhaulinanna 6.00 8.23 11.25 12.07 Dulhasti 13.30 12.32 12.82 14.60 Sewa II 5.73 5.55 3.36 3.45 Uri II 10.36 11.10 10.45 11.11 Parbati Ill 2.46 3.08 5.17 9.45 Kishanrianoa 2.57 2.21 2.54 2.84 Sub-Total 83.51 85.98 92.91 102.05

SJVNL Nathna Jhakri 7.75 11.10 16.53 17 .10 Ramnur Eauitv Power 17.79 25.33 37.34 38.60 Ramour Free Power 0.00 o.oo o.oo 0.00 Sub-Total 25.54 36.43 53.86 55.70

THDC Tehri HEP 1 9.66 9.84 8.36 7.48 Koteshwar 7.30 8.31 7.70 6.24 Sub-Total 16.96 18.15 16.06 13.72

NTPC Sinnrauli 52.85 56.28 51.06 49.79 F G Unchahar·I 14.12 17.44 14.18 14.63 F G Unchahar-2 6.01 8.39 3.97 8.42 F G Unchahar-3 4.49 5.47 4.69 5.84 F G Unchahar-4 6.59 13.23 11.08 13.40 NC T Dadri:2 0.05 0.05 a.oz 2.63 Rihand-1 STPS 18.91 22.86 16.96 13.34 Rihand-2 STPS 15.73 18.77 12.78 8.92 Rihand-3 STPS 18.38 19.57 19.03 19.08 Kahaloaon-Il 7.77 8.94 9.96 10.62 Jhaiiar Aravali 0.22 1.26 1.04 1.40 Sinorauli SHEP 0.01 0.06 0.04 0.05 Koldam !Hvdrol 14.65 19.27 33.12 45.34 Barh STP I 0.00 0.00 0.00 0.00 Barh STP II 0.00 o.oo 0.00 0.00 North Karanpura 0.00 0.00 0.00 0.00 Sinarauli STPS III 0.00 0.00 0.00 0.00 Anta Gas 0.48 2.22 0.15 0.01 Auraiva Gas 0.00 0.23 0.69 0.78 Dadri Gas 6.74 4.41 3.08 0.75

AUD

6.14 1.95

13.86 2.56 9.68 8.57

12.24 13.60

4.28 10.11 10.58

1.68 95.25

16.09 36.36

0.00 52.45

13.19 8.09

21.27

56.45 22.85 10.48

7.04 14.09

0.02 23.03 12.57 20.90 12.45

0.89 0.00

45.19 0.00 0.00 0.00 0.00 0.01 4.78 4.17

(Fir ures in MU' Sea Oct Nov Dec Jan Feb Ma, Total

5.63 2.20 1.20 0.95 1.02 1.49 1.88 43.10 2.00 1.37 0.63 0.39 0.38 0.?7 0.22 14.21 8.60 4.30 2.45 1.89 2.02 3.76 4.66 89.96 0.45 1.34 1.18 0.86 0.78 1.06 1.38 30.65 6.99 3.27 1. 93 1.28 1.11 1. 04 1.51 63.36 7.04 3.13 3.21 2.72 3.24 6.56 9.77 91.Cl~

11.30 4.20 2.42 1.74 1.43 1.38 1.76 74.03 13.84 12.25 7.43 5.69 4.49 4.56 5.52 120.43

1.38 0.86 0.83 0.67 1.14 3.41 3.92 34.57 7.46 2.73 2.60 2.02 2.50 4.36 6.51 8L32 5.20 1.98 1.25 0.77 0.45 0.40 0.49 41.28 2.21 0.43 0.41 0.63 0.51 a.so 0.90 l / .43

72.10 38.05 25.54 19.63 19.08 28.80 38.52 701.42

14.72 4.85 2.98 2.41 2.14 2.12 2.46 100.24 33.41 14.44 9.26 7.36 6.37 5.55 6.52 238.34

o.oo 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 48.13 19.29 12.24 9.77 8.50 7.68 8.99 338.59

15.96 6.96 7.24 8.74 10.42 8.52 9.11 115.48 8.92 4.40 4.50 5.55 6.66 5.74 6.63 80.04

24.89 11.36 11.73 14.29 17.09 14.26 15.74 195.52

43.07 66.50 67.83 67.82 70.76 64.16 66.40 712.96 12.67 13.40 16.10 20.00 22.77 21.99 23.83 213.98

5.13 7.76 8.90 8.60 11.17 9.27 9.62 97.74 3.SS 7 .26 8.37 8.26 9.24 8.12 8.04 80.70

10.22 8.89 10.68 13.27 15.11 14.60 15.31 146.99 0.03 1.53 2.00 3.68 2.64 1.65 2.47 16.77

17.67 34.34 33.61 30.60 33.95 26.40 30.61 302. 79 11.06 32.26 30.87 32.67 31.08 29.84 29.98 266.53 18.71 24.01 35.04 34.01 36.71 33.27 34.83 313.55 10.26 20.80 23.41 '3.31 19.51 19.19 19.82 186.54

0.91 4.63 10.75 9.82 6.81 12.28 16.95 66.96 0.00 -0.01 -0.02 -0.03 -0.03 -0.03 -0.03 0.00

31.99 10.89 7.00 5.68 5.25 5 .12 5.86 219.35 o.oo 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.00 ? .09 0.79 0.00 1.83 0.96 1.73 11.28 2.44 0.97 0.32 0.02 0.76 0.52 0.74 12.24 9.49 4.42 5.26 6.22 2.94 5,01 5.05 S7.54

/':

i~ _ "-:f...::, Page 221

Details of the stations Aoc Mav Jun Jul Aun Seo Oct Nov Dec Jan Feb Mac Total Sub-Total 167.01 198.44 181.84 195.01 234.94 178.53 239.73 260.89 264.43 270.50 252.35 271.73 2715.40

NPCIL Narora APP 15.95 16.65 15.79 16.39 16.26 15.85 12.62 15.69 16.32 13.83 12.98 16.14 184.46 Raiasthan APP 15.06 21.51 20.51 21.25 21.22 19.56 9.75 13.25 13.91 14.5"1 11.91 10.63 193.10 Sub-Total 31.01 38.16 36.30 37.64 37.48 35.40 22.37 28.95 30.22 28.37 24.89 26.77 377.56 Total CSGS 324.04 377.16 380.97 404.11 441.39 359.06 330.81 339.35 338.34 343.54 327.97 361.74 4328.49 UJVNL Larne Hvdro Dhakrani 10.77 10.56 10.70 14.43 14.65 14.41 10.20 5.17 3.54 2.64 3.77 4.58 105.42 Dhalinur 16.73 16.31 16.30 16.84 15.76 16.70 16.63 9.59 7.07 6.03 6.94 7.33 152.23 Chlbro 68.36 61.51 74.44 103.56 100.29 86.10 54.41 30.67 23.54 20.95 74.39 29.30 677.51 Khodri 29.60 28.25 32.16 42.26 41.10 37.69 25.21 14.29 10.51 9.16 11.03 13.59 294.85 Kulhal 10.91 10.74 12.95 12.82 10.29 10.03 11.59 7.11 5.74 5.53 5.54 5.49 108.75 Ramoanna 4.25 0.28 55.69 2.15 -0.16 ·0.15 1.55 1.19 37.14 67.97 30.18 26.88 226.96 Tiloth 44.21 45.13 44.31 28.06 4.28 42.57 58.38 36.67 26.45 17.02 18.24 21.43 386.75 Chllla 54.43 73.19 68.81 73.00 63.02 67.77 67.79 56.17 54.29 51.66 39.20 53.29 7?.7,62 Khatlma 11.83 23.19 22.25 24.70 26.13 26.07 20.53 9.33 13.35 13.23 11.54 12.83 214.96 UJVNL Receivable 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total 251.08 269.16 337.62 317.82 275.36 301.19 266.29 170.20 181.62 194.19 150.82 174.72 2890.06

Maneri Bhali II 104.20 155.27 196.68 185,51 173.78 176.77 105.19 55.35 42.50 35.93 34.63 47.69 1313.50

Small Hvdro Mohd. Pur 4.99 4.86 4.64 4.73 3.90 5.45 1.33 3.36 5.25 5.29 4.50 5.23 53.53 Pathri 10.84 11.69 11.81 11.74 8.22 13.05 3.30 8.34 11.10 10.78 9.30 11.00 121.17 Kanchauti 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 o.oo o.oo 0.00 Chhirkila 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Kulaaarh 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 Relanad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Dunao SHP 1.5 MW 0.22 0.01 o.oo 0.39 0.27 0.00 0.21 0.25 0.21 0.20 0.18 0.16 2.09 Surinaarh 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 o.oo Saoteshwar 0.00 o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Gauri 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 Pandukeshwar 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 o.oo o.oo 0.00 0.00 o.oo Taleshwar 0.00 o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Chharandev 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Kotabaah 0.00 o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Harsil 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.01 Pilanaad 0.49 0.41 0.20 o.oo 0.06 0.00 0.02 0.15 0.23 0.33 0.37 0.21 2.47 Tharali 0.00 0.00 0.00 o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Uraam 1.02 0.99 1.11 a.so 0.03 0.00 0.15 0.31 0.11 0.16 0.35 0.47 5.19 Soneoravao 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Badrinath 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.00 0.00 o.oo 0.01 Tilwara 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo o.oo Tanovan 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 o.oo 0.00 Jumma 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Galoni 0.52 0.47 0.42 0.47 0.79 0.76 0.83 0.71 0.64 0.65 0.56 0.54 7.35 Kaliaanna 0.00 o.oo 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 o.oo o.oo o.oo Sub-Total 18.07 18.44 18.17 17.83 13.26 19.26 5.84 13.12 17.54 17.41 15.25 17.62 191.81 Total UJVNL 373.36 442.87 552.47 521.16 462.40 497.21 377.32 238.67 241.65 247.54 200.70 240.03 4395.38 UREDA SHPs UREDA: Bhikuri"a Gardh 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo o.oo Ramoarll 0.00 o.oo 0.00 o.oo 0.00 0.00 0.01 0.00 0.00 0.00 0.00 o.oo 0.01

Page 222

Details of the stations Ao, Mav Jun Jul Aua Sea Oct Nov Dec Jan Feb Ma, Total Barar + Garaun 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.01 0,00 0.00 0.01 0.00 0.04 Surinnarh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Saoteshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 Gauri 0.00 0.00 0.00 0.00 o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 Taleshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.19 0.20 0.09 0.03 0.02 0.82 Chharandev 0.00 0.00 0.00 0.00 0.00 0.00 0.08 0.07 0.05 0.05 0.10 0.01 0.3(:, Kotabaqh o.oo 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 Harsil 0.00 0.00 0.00 0.00 0.00 o.oo 0.02 0.01 0.01 0.01 0.01 0.01 0.05 Tharali 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.04 0.03 0.01 0.04 0.06 0.72 Badrinath 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.00 0.00 0.00 0.00 0.00 0.03 UREDA: Kanoload SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 UREDA: Lathi SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 UREOA: Barsol SHP 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 o.oo UREDA: Milkhet SHP 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 Sub Total 0.00 0.00 0.00 0.00 0.00 0.00 0.50 0.32 0.28 0.16 0.18 0.09 1.53 UREDA Solar Solar Plant Dehra Dun 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 Sub Total 0.00 0.00 o.oo 0.00 0.00 0.00 o.oo o.oo o.oo 0.00 o.oo 0.00 0.00 UREDA Biomass Avni Bio Enerov 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total o.oo 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00

IPP Hvdro Raiwakti Him Uria SHP 2.15 1. 90 2.23 2.27 2.28 2.41 2.69 2.31 1.62 1. 79 1.12 1.25 23.51 Hanuman Ganaa SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Greenko Budhil Hvdro Power Pv 24.21 26.71 28.41 44.14 43.24 0.00 16.71 8.03 5.47 4.51 3.17 5.43 710.02 Debal chamoli hvdro 1.80 1.69 1.69 2.86 2.34 0.93 2.74 1.63 1.10 0.78 0.58 0.81 18.97 LoharKhet r narvativa nower'l 2.62 1.90 1.50 2.67 2.89 2.81 2.77 1.77 1.25 0.97 0.86 1.15 13.16 Gunsola H"dro Aounda Thati 1.64 1.12 1.06 1.90 1.90 2.04 1.68 1.01 0.70 0.57 0.54 0.73 14.85 Bhilanaana( Swasti l 9.84 9.11 12.36 15.91 15.03 15.67 8.81 4.68 3.11 1.93 0.99 3.13 100.58 vanala 4.22 4.47 5.20 8.27 6.54 4.42 5.21 3.12 2.09 2.37 1.96 2.23 50.05 Moti hat 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 Rishiaanoa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Birahi Ganna 2.47 2.32 1.99 3.82 3.69 4.31 2.77 1.53 0.97 0.74 0.68 0.82 26.12 Tanoa ( HHPLI 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 HHL: Jalandhariaad o.oo 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 HHL: Sivanaad 0.00 0.00 0.00 0.00 0.00 o.oo o.oo o.oo 0.00 0.00 0.00 0.00 0.00 HHL: Kakoraoad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sariu II 2.90 2.03 1.58 3.72 3.68 2..83 3.36 2.41 1.42 1.00 0.94 1.24 27.11 Uttar Bharat Sariu III 1.59 1.05 0.97 2. 73 3.13 3.10 2.85 1.70 1.07 0.73 0.67 0.82 20.+1 Ganaani 4.25 6.02 5.29 4.91 4.41 5.35 4.70 3.03 2.23 1.75 1.67 2:26 45.87 Badivar 1.77 1.82 1.72 1.88 1.64 1.69 1.84 1.50 1.07 0.81 0.84 1.11 17.69 Sub-Total 59.47 60.13 63.99 95.09 90.78 45.57 56.11 32.71 22.11 17.37 14.01 20.99 578.33

Co-Generation RBNS Sunar Mill 8.04 0.00 0.00 0.00 0.00 o.oo 0.00 2.89 8.90 8.36 8.09 8.92 45.19 Uttarn Suoar Mills 3.63 0.00 0.00 0.00 0.00 0.00 0.00 2.85 5.09 6.27 5.83 6.19 29.86 Lakshmi Suoar Mills 2.21 0.00 0.00 0.00 0.00 0.00 0.22 4.51 8.75 9.98 9.30 9.89 44.87 Sub-Total 13.88 o.oo o.oo o.oo o.oo o.oo 0.22 10.24 22.74 24.62 23.22 25.00 119.92

Gas Gama 65.50 66.56 59.87 66.36 64.59 46.61 63.36 o.oo 25.97 38.54 23.90 54.53 515.77 Beta 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Shravanti 127.18 130.26 106.89 103.15 134.84 115.45 133.21 28.02 54.16 9 5. 91 74.91 76.86 1130.84 Sub-Total 192..68 196.82 166.76 169.51 199.43 162.05 196.57 28.02 80.12 134.45 98.81 131.39 1756.61

r,

,~ Page223

Details of the stations An, Ma" Jun Jul Auo Sen Oct Nov Dec Jan Feb Mac Total

Solar RV Akash Ganoa solar oower ltd 0.27 0.26 0.27 0.21 0.22 0.21 0.23 0.17 0.16 0.15 0.15 0.26 2.57 Metro Frozen 0.13 0.13 0.13 0.09 0.10 0.11 0.11 0.08 0.08 0.07 0.07 0.12 1.21 Jav Ace Technoloqies 0.21 0.23 0.21 0.16 0.15 o.oo 0.19 0.13 0.14 0.13 0.12 0.20 1.86 UJVNl '1.4661 Ohakrani 0.23 0.25 0.23 0.17 0.19 0.18 0.24 0.19 0.19 0.16 0.16 0.23 2.42 UJVNL f4.398lkhodari 0.67 0.72 0.67 0.49 0.54 0.55 0.71 0.58 0.57 0.48 0.45 0.69 7 .11 Redwoods o.oo 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Madhav Infra 2.01 2.02 1.94 1.35 1.46 1.62 1.85 1.43 1.34 1.26 1.21 2.00 19.50 Purshotam Industries Ltd.-I @7. 0.11 0.11 0.10 0.08 0.12 0.00 0.11 0.09 0.08 0.08 0.07 0.12 1.07 Purshotam Industries Ltd.-lI@ 0.14 0.15 0.12 0.09 0.11 0.00 0.13 0.10 0.10 0.09 0.08 0.14 1. 24 Purshotam lsoat-I @7.96 0.13 0.13 0.13 0.11 0.12 o.oo 0.14 0.12 0.11 0.10 0.09 0.16 1.34 Vivaan Solar Pvt. Ltd. 0.42 0.43 0.38 0.30 0.34 0.34 0.40 0.32 0.31 0.28 0.26 0.45 4.22 Eastman International 0.10 0.10 0.09 0.07 0.08 0.08 0.09 0.07 0.07 0.06 0.06 0.10 0.98 Purshotam Isoat-11 @7.88 0.14 0.14 0.13 0.10 0.08 0.00 0.13 0.11 0.11 0.09 0.09 0.15 1.17 R.C. Enerrn, 0.12 0.13 0.13 0.08 0.10 0.11 0.11 0.10 0.10 0.08 0.08 0.12 1.26 Advika Ener 0.14 0.17 0.16 0.11 0.12 0.13 0.12 0.10 0.10 0.09 0.09 0.14 1.46 A.R. Solar Power-I @5.670 0.14 0.16 0.16 0.10 0.10 0.11 0.14 0.10 0.10 0.07 0.09 0.14 1.42 A.R. Solar Power-II @5.690 0.15 0.17 0.17 0.12 0.12 0.13 0.13 0.09 0.10 0.09 0.10 0.14 1.53 Devishi Renewal ener 2.12 2.26 2.14 1.65 1.66 1. 75 1.93 1.50 1.46 1.48 1.29 2.28 21.53 Devishi Solar nower 2.04 2.24 2.15 1.68 1.68 1.78 1.99 1.53 1.47 1.51 1.31 2.32 21.71 Eminet Solar oower 2.04 1.82 2.10 1.67 1.84 1. 76 2.00 1.60 1.47 1.42 1.30 2.18 21. 70 Sunworld Enernv nvt 2.02 1.78 1.99 1.60 1.74 1.67 1.85 1.49 1.39 1.34 1.25 2.12 20.24 Ema ml Power Ltd. 2.96 3.01 3.01 2.34 2.45 2.27 2.97 2.32 2.10 2.06 2.05 2.98 30.53 Hvdro Power EnQineers 0.16 0.17 0.17 0.12 0.12 0.13 0.14 0.11 0.09 0.09 0.09 0.15 1.53 lmnex India 0.38 0.40 0.39 0.29 0.30 0.30 0.36 0.27 0.25 0.25 0.24 0.35 3.77 Techniaue Solaire Invest 0.80 0.84 0.80 0.60 0.62 0.63 0.73 0.56 0.56 0.49 a.so a.so 7.93 Makin Develoners Pvt. Ltd 0.16 0.18 0.17 0.12 0.13 0.13 0.15 0.11 0.11 0.10 0.11 0.16 1.63 Balluour solar oower ovt.Ltd 1.55 1.52 1.56 1.17 1.11 1.23 1.44 1.13 1.11 1.09 1.01 1.62 15,53 Chudiala Solar nower nroiect nv 1.58 1.57 1.64 1.27 1.26 1.30 1.48 1.15 1.13 1.09 1.02 1.64 16.13 Shakumbhari solar oower oro1e 1.57 1.56 1.64 1.24 1.18 1.27 1.47 1.15 1.12 1.08 1.01 1.64 15.94

. Bindookharak solar nower nroie 0.82 0.85 0.82 0.63 0.64 0.64 0.77 0.63 0.57 0.57 0.50 0.86 8.29 Bhaowanour solar nro;ects oriv:: 0.83 0.84 0.83 0.64 0.63 0.63 0.80 0.62 0.57 0.57 0.51 0.85 8.32 PL sunravs oower limited 1.63 1.69 1.60 1.29 1.41 1.39 1.50 1.28 1.25 1.18 1.03 1.75 17.02 Pl surva vidvut !td 1.64 1.71 1.54 1.19 1.34 1.29 1.44 1.30 1.26 1.23 1.02 1.72 16.68 Pl solar Renewable ltd 1.62 1.11 1.63 1.30 1.41 1.39 1.37 1.15 1.23 1.11 0.99 1.72 16.01 Haridwar solar ciroiects ovt ltd 1 1.63 1.63 1.61 1.21 1.15 1.22 1.57 1.21 1.11 1.12 1.01 1.66 16.13 Haridwar solar nroiects pvt ltd 1.65 1.66 1.63 1.27 1.28 1.30 1.55 1.25 1.13 1.12 1.03 1.71 16.57 Sunheti solar oower nroi t ltd 0.77 0.78 0.76 0.56 0.61 0.65 0.73 0.58 0.55 0.51 0 .46 0.82 7.79 AB Renewable Enerm, nvt ltd 0.86 0.84 0.77 0.40 0.40 0.47 0.75 0.61 0.55 0.55 0.54 0.87 7 .61 Canal Bank Solar ov olant Dhak 1.04 1.07 1.00 0.75 0.81 0.84 0.89 0.72 0.71 0.67 0.59 1.02 10.06 Canal Bank Solar nv nlant Dha!i 1.15 1.21 1.11 0.81 0.89 0.87 1.10 0.83 0.80 0.67 0.70 1.06 11.22 Canal Too Solar ov olant Dhalio( 0.13 0.16 0.14 0.10 0.11 0.11 0.00 0.01 0.05 0.06 0.06 0.10 1.03 Daknatthar canal Bank /4,5 MW 0.60 0.71 0.68 0.31 0.54 0.58 0.71 0.57 0.57 0.47 0.45 o. 71 6.89 Sub-Total 36.88 36.93 36.89 27.83 29.26 29,19 34.52 27.47 26.29 25.04 23.23 38.25 371.77

Solar Rooftop EDC DEHRADUN o.oo 0.00 0.00 0.00 0.00 o.oo 0.13 0.06 0.15 0.15 -0.03 0.05 0.50 EDC SRINAGAR 0.00 0.00 0.00 0.00 0.00 0.00 0.07 0.06 0.06 0.01 0.03 0.10 0.34 EDC TEHRI o.oo 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 o.oo o.oo 0.00 UDC DEHRADUN 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 o.oo 0.00 0.07 EDC HARIDWAR 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.09 0.08 0.07 0.16 0.13 0.63 EDC ROORKEE 0.00 0.00 0.00 0.00 0.00 o.oo 0.44 0.33 0.32 0.28 0.30 2.46 4.14 EDC HALDWANI o.oo 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.01 0.00 0.00 0.00 0.04 EDC KASHIPUR 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Page 224

Details of the stations An, Mav Jun Jul Aun Sen Oct Nov Dec Jan Feb Ma, Total

EDC RANIKHET 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

EDC RUDRAPUR 0.00 0.00 0.00 0.00 0.00 0.00 0.29 0.25 0.23 0.22 0.19 0.64 1.83

EDC PITHORAGARH 0.00 0.00 0.00 o.oo 0.00 o.oo 0.00 0.00 o.oo 0.00 0.00 0.00 0.00

Sub-Total 0.00 0.00 0.00 0.00 0.00 0.00 1.04 a.so 0.86 0.75 0.66 3.37 7.48

Other Laroe Private Meia Thermal I 0.27 5.07 7.82 3.52 8.71 4.17 0.00 0.00 0.00 0.00 0.00 0.00 29.57

Sasan 60.21 64.22 56.52 52.16 53.26 0.00 58.30 64.60 63.79 65.99 59.51 64.34 662.91

Sub-Total 60.48 69.29 64.34 55.68 61.96 4.17 58.30 64.60 63.79 65.99 59.51 64.34 692.47

Total !PP 363.38 363.17 331.98 348.10 381.43 241.00 347.26 164.17 216.20 268.36 219.63 283.43 3528.13

State Rovaltv Power I Dhauliaanoa 11.75 16.23 22.43 24.22 24.37 22.53 10.11 5.58 4.16 3.32 2.92 3.77 151.40

Tanaknur 4.58 5.24 6.63 6.87 7 .14 7.06 5.68 3.24 1.82 1.12 1.13 0.90 51.42

Tehri 28.18 28.27 24.04 21.94 38.29 46.67 25.45 24.35 29.16 32.80 26.01 27.57 352.73

Koteshwar 12.48 14.16 13.01 10.66 13.70 15.20 8.33 8.23 10.08 11.88 10.09 11.66 139.48

Vishnu Prava,, 11.28 16.48 35.44 36.65 34.49 35.41 21.87 10.39 7.74 6.17 5.00 5.59 226.50

GVK Srinanar 10.28 12.25 19.37 26.44 24.93 26.41 14.03 6.90 5.03 4.03 3.47 4.14 157 .28

Raiwakti Him LJria SHP 0.24 0.21 0.25 0.25 0.25 0.27 0.19 0.17 0.12 0.09 0.08 0.09 , I .22

Sub-Total 78.79 92.84 121.17 127.04 143.17 153.55 85.66 58.87 58.10 59.41 48,71 53.72 1081.04

Total Power Purchase from F 1139.56 1276.04 1386.60 1400.42 1428.40 1250.82 1141.05 801.06 854.30 918.85 797.01 938.93 13333.04

Qoen Market Purchases & UI Bankino Received 32.40 5.57 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 37.97

UI Net drawal -5.12 -6.90 6.83 -1.30 0.45 -0.13 0.00 0.00 0.00 0.00 0.00 0.00 -6.18

Tender Purchases 168.39 217.72 215.53 20.15 19.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 640.78

IEX /Net Purchases\ -179.57 0.48 -12.79 -7.76 34.44 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -165.19

Reactive Pavables 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Ooen Market Purchase (Extra\ 233.04 300.63 298.28 27.89 26.98 0.00 886.82

Sub-Total 16.10 216.37 209.57 11.09 54.39 -0.13 233.04 300.63 298.28 27.89 26.98 o.oo 1394.20

Total Purchases 1155.66 1492.41 1596.16 1411.51 1482.79 1250.68 1374.09 1101.69 1152.58 946.74 823.99 938.93 14727.24

Less: Bankino Pavable 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Ui Underdrawal 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Reactive Units Receivables 0.00 0.00 0.00 o.oo o.oo 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00

Sub-Total 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00

State consumation 1155.66 1492.41 1596.16 1411.51 1482.79 1250.68 1374.09 1101.69 1152.58 946.74 823.99 938.93 14727.24

Page 225

Name of Distribution Licensee Licensed Area of Supply

Form: F-2.6

Uttarakhand Power Corporation Limited Uttarakhand

Availability of Power (Power Purchased at Ex Bus) FY2020-21

Details of the stations Ao, Mav Jun Jul NHPC Sala! 3.37 4.78 5.55 5.79 Tanakour 0.02 0.33 0.66 1.19 Chamera I 7.30 9.04 10.79 12.99 Chamera II 2.62 4.32 4.74 3.03 Chamera III 4.53 8.17 9.17 8.68 Uri 11.28 12.28 11.37 11.50 Ohaulitianna 2.64 5.11 8.20 9.16 Dulhasti 11.40 17.05 15.62 13.41 Sewa II 3.68 2.83 2.19 3.17 Uri 11 9.11 10.41 10.40 8.95 Parbati !11 1.86 3.78 5.07 7.85 Kishanoanoa 2.57 2.21 2.54 2.84 Sub-Total 60.37 79.SO 86.31 88.57

SJVNL Nathna Jhakri 5.15 11.09 13.79 12.37 Ramour Eauitv Power 12.60 25.91 34.75 34.18 Ramour Free Power 0.00 o.oo o.oo o.oo Sub-Total 17.75 37.00 48.54 46.55

THDC Tehri HEP I 5.66 5.46 6.59 12.35 Koteshwar 4.76 4.85 6.19 9.54 Sub-Total 10.42 10.31 12.77 21.89

NTPC Sinorauli 48.61 59.24 57.24 61.10 F G Unchahar~I 19.99 18.75 16.18 22.81 F G Unchahar-2 8.57 8.99 7.53 11.01 F G unchahar-3 6.47 6.78 6.40 9.18 F G Unchahar-4 6.59 13.23 11.08 13.40 NC T Dadri:2 5.31 4.81 7.24 2.34 Riha nd-1 STPS 23.41 27 .11 23.86 30.63 Rihand-2 STPS 21.27 19.44 20.85 27 .39 Rihand-3 STPS 28.44 30.08 26.52 26.66 Kahaloaon-Il 18.63 16.59 14.74 14.64 Jhaiiar Aravali 8.30 8.72 9.54 3.21 Sinarauli SHEP 0,00 0.00 0.00 0.00 Koldam /Hvdrol 9.45 20.56 31.61 39.52 Barh STP I 0.00 o.oo 0.00 0.00 Barh STP 11 0.00 o.oo 0.00 0.00 North Karannura 0.00 0.00 0.00 0.00 Slnorauli STPS III 0.00 0.00 0.00 0.00 Anta Gas 0.46 1.27 1.43 0.15 Auraiva Gas 2.43 2.04 0.63 1.26 Dadri Gas 8.09 9.01 5.52 5.20

Auo Seo

5.76 4.50 1.41 1.76

13.43 7 .80 2.80 1.95 8.44 5.56

10.26 6.38 8.95 7.22

13.97 14.18 3.32 1.68 8.30 5.75 8.21 4.34 1.68 2.21

86.54 63.33

10.88 8.84 30.71 26.92

0.00 0.00 41.59 35.76

19.03 10.65 13.15 7.12 32.18 17.77

57.56 60.96 14.78 14.35 8.14 9.08 6.08 6.57

14.09 10.22 0.99 1.14

24.70 27.11 22.74 22.53 26.18 26.10 14.44 12.88

2.40 2.36 0.00 0.00

39.73 22.59 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.06 2.50 1.91 0.61 3.67 4.08

(Fi<: ures in MU) Oct Nov Dec Jan Feb Ma, Total

2.20 1.20 0.95 1.02 1.49 1.88 38.50 1.37 0.63 0.39 0.38 0.27 0.22 8.63 4.30 2.45 1.89 2.02 3.76 4.66 80.43 1.34 1.18 0.86 0.78 1.06 1.38 26.06 3.27 1.93 1.28 1.11 1.04 1.51 54.68 3.13 3.21 2.72 3.24 6.56 9.77 91.71 4.20 2.42 1.74 1.43 1.38 1.76 54.23'

12.25 7.43 5.69 4.49 4.56 5.52 125.57 0.86 0.83 0.67 1.14 3.41 3.92 27.69 2.73 2.60 2.02 2.50 4.36 6.52 73.65 1.98 1.25 0.77 0.45 0.40 0.49 35.95 0.43 0.41 0.63 0.52 a.so 0.90 17.43

38.05 25.54 19.63 19.08 28.80 38.52 634.53

4.85 2.98 2.41 2.14 2.12 2.46 79.09 14.44 9.26 7.36 6.37 5.55 6.52 214.57

0.00 o.oo 0.00 o.oo o.oo o.oo 0.00 19.29 12.24 9.77 8.50 7.68 8.99 293.66

6.96 7./4 8.74 10.42 8.52 9.11 110.74 4.40 4.50 5.55 6.66 5.74 6.63 79.09

11.36 11.73 14.29 17.09 14.26 15.74 189.83

62.92 64.18 64.17 66.95 60.71 62.82 /16.45 12.25 14.72 18.29 20.83 20.12 21.80 214.89

6.63 7.60 7 .35 9.55 7.92 8.22 100.60 5.99 6.90 6.81 7 .61 6.70 6.63 87.12 8.89 10.68 13.27 15.11 14.60 15.82 146.99 0.58 0.75 1.38 0.99 0.62 0.93 22.09

27.64 27.05 24.62 27.32 71.24 24.64 309.33 24.15 23.10 24.46 23.26 22.33 22.44 273.96 18.75 27.36 26.56 28.66 25.98 27.20 318.48 15.55 17.50 17.81 14.59 14.35 14.82 186.54

1.70 3.95 3.61 2.50 4.51 6.73 57 .04 0.00 0.00 0.00 0.00 0.00 0.00 0.00

10.89 7.00 5.68 5.25 5.12 5.86 203.25 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.09 0.79 0.00 1.83 0.96 1. 73 15.26 0.97 0.32 0.02 0.76 0.52 0.74 12.20 4.42 5.26 6.22 2.94 5.01 5.05 64.47

i\

,_\I,, \ / Page 226

Details of the stations An, Mav Jun Jul Aun Sen Oct I Nov Dec Jan Feb Ma, Total

Sub-Total 216.01 246.65 235.37 268.50 239.48 223.07 203.41 217.17 220.24 228.16 210.69 224.93 2733.68

NPCIL Narora APP 12.69 12.54 12.49 13.24 12.76 9 .46 12.62 15.69 16.32 13.83 12.98 16.14 160.74

Raiasthan APP 15.45 16.84 18.64 15.25 15.18 11.10 9.75 13.25 13.91 14.54 11.91 10.63 166.45

Sub-Total 28.14 29.38 31.13 28.48 27.94 20.55 22.37 28.95 30.22 28.37 24.89 26.77 327.19

Total CSGS 332.69 403.13 414.11 454.00 427.74 360.50 294.48 295.63 294.15 301.21 286.32 314.95 4178.90

UJVNL Larne Hvdro Dhakrani 2.72 5.74 8.18 11.78 14.12 14.14 10.20 5.17 3.54 2.64 3.77 '1.58 86.59

Dha[inur 4.88 13.85 13.60 18.48 22.60 22.47 16.63 9.59 7.07 6.03 6.94 7.33 149-.46

Chi bro 32.32 41.54 53.35 81.87 98.03 83.62 54.41 30.67 23.54 20.95 24.39 29.30 574.00

Khodri 15.01 19.11 61.33 36.10 41.43 36,91 25.21 14.29 10.51 9.16 11.03 13.59 293.67

Kulhal 3.50 5.42 9.26 11.61 13.64 14.80 11.59 7 .11 5.74 5.53 5.54 5.49 99.74

Ramaanqa 14.10 22.50 2.58 -0.18 -0.19 -0.17 1.55 1.19 37.14 67.97 30.18 26.88 203.5<1

Tiloth 28.86 45.37 49.29 21.30 10.67 49.22 58.38 36.67 26.45 17.02 18.24 21.43 382.}_Q

Chilla 51.96 61.24 80.67 69.89 68.14 66.69 67.79 56.17 54.29 51.66 39.20 53.29 721.00

Kha ti ma 13,03 16.91 19.76 19.40 24.03 26.52 20.53 9.33 13.35 13.13 11.54 17.83 200.45

UJVNL Receivable 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sub-Total 166.38 231.67 298.04 270.25 292.48 314.20 266.29 170.20 181.62 194.19 150.82 174.72 2710.85

Maneri Bhali II 69.74 138.58 198.45 173.70 185.23 178.23 105.19 55.35 42.50 35.93 34.63 47.69 1265.23

Small H"dro Mohd. Pur 4.51 5.01 4.93 4.43 4.59 4.47 1.33 3.36 5.25 5.29 4.50 5.23 52.90

Pathri 10.44 12.40 12,81 10.40 11.00 10.12 3.30 8.34 11.10 10.78 9.30 11.00 r·o.99

Kanchauti 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00

Chhirkila 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Kulaoarh o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Relaoad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Ounao SHP 1.5 MW 0.79 0.01 0.00 0.02 0.16 0.21 0.21 0.25 0.21 0.20 0.18 0.16 2.39

Surinnarh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Santeshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00

Gauri 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Pandukeshwar 0.00 0.00 o.oo o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Taleshwar 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 o.oo o.oo 0.00 0.00 0.00

Chharandev 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00

Kotaba(Jh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Harsil 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.01

Pilanoad 0.14 0.12 0.20 0.02 0.00 -0.01 0.02 0.15 0.23 0.33 0.37 0.21 1. 78

Tharali 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Umam 0.30 0.33 0.23 0.03 0.00 0.00 0.15 0.31 0.11 0.16 0.35 0.47 2.43

Sonenravan 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0,00

Badrinath 0.00 0.03 0.03 0.01 0.02 0.03 0.01 o.oo 0.00 0.00 0.00 0.00 0.13

Tilwara 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Tanovan o.oo 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00

Jumma 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Galoni 0.43 0.39 0.24 0.38 0.461 0.63 0.83 0.71 0.64 0.65 0.56 0.54 6.45

Kalioanoa 0.00 0.00 o.oo o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sub-Total 16.60 18.28 18.43 15.29 16.23 15.45 5.84 13.12 17.54 17.41 15.25 17.62 187.07

Total UJVNL 252.72 388.53 514.92 459.25 493.93 507.89 377.32 238.67 241.65 247.54 200.70 240.03 4163.15

UREDA SHPs UREDA: Bhikuriva Gardh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Ramoarh 0.00 -0.01 -0.01 0.00 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.0 l

~ \_j

::-;;" Page 227

Details of the stations Ao, Mav Jun Jul Aua Seo Oct Nov Dec Jan Feb Mac Totai Barar + Garaun 0.00 0.00 0.00 0.00 0.02 0.02 0.03 0.01 0.00 0.00 0.01 0.00 0.08 Surinnarh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Santeshwar 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Gauri o.oo 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Taleshwar 0.08 0.08 0.10 0.19 0.21 0.22 0.30 0.19 0.20 0.09 0.03 0.02 1.69 Chharandev 0.02 0.00 0.03 0.06 0.10 0.11 0.08 0.07 0.05 0.05 0.10 0.01 0.69 Kotabaoh 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Harsil 0.03 0.02 0.03 0.03 0.02 0.02 0.02 0.01 0.01 0.01 0.01 0.01 0.21 Tharali 0.02 0.02 0.03 0.00 0.00 0.01 0.04 0.04 0.03 0.01 0.04 0.06 0.29 Badrinath 0.00 0.11 0.11 0.06 0.04 0.05 0.03 0.00 0.00 0.00 0.00 0.00 OAO UREDA: Kanoload SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UREDA: Lathi SHP 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UREDA: Barso! SHP 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 UREDA: Milkhet SHP 0.00 0.00 o.oo o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 Sub Total 0.15 0.23 0.28 0.36 0.40 0.43 a.so 0.32 0.28 0.16 0.18 0.09 3.38 UREDA Solar Solar Plant Dehra Dun 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 Sub Total o.oo 0.00 0.00 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 o.oo o.oo 0.00 UREDA Biomass Avnl Bio Enerav 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00

IPP Hvdro Raiwakti Him Uria SHP 1.21 1.34 1.93 1.54 1.81 2.06 2.88 2.48 1.74 1.38 1.20 1.35 10.92 Hanuman Ganaa SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Greenko Budhil Hvdro Power Pv 13.74 31.72 40.17 45.43 46.65 32.79 16.71 8.03 5.47 4.51 3.17 5.43 253.82 Debal chamoli hvdro 0.71 0.71 1.54 2.07 7.17 2.97 2.74 1.63 1.10 0.78 0.58 0.81 17 .81 LoharKhet r narvativa newer) 0.78 0.84 1.69 2.29 2.66 2.68 2.77 1.77 1.25 0.97 0.86 1.15 19.69 Gunsola H11dro Aounda Thati 0.67 0.85 1.21 1.76 1.72 1.76 1.68 1.01 0.70 0.52 0.54 0.73 13. 17 Bhilanoana r Swasti l 4.73 7.20 11.35 14.15 15.24 15.14 8.81 4.68 3.11 1.93 0.99 3.13 90.47 Van ala 2.23 2.78 4.42 5.25 5.12 5.20 5.21 3.12 2.09 2.32 1.96 2.23 41.93 Motiahat 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Rishloanna 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 Birahi Ganaa 0.64 0.99 1.84 4.22 4.69 4.51 2.77 1.53 0.97 0.74 0.68 0.82 24.41 Tanaa (HHPL'\ 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 HHL: Jalandharioad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 o.oo 0.00 HHL: Sivanoad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 HHL: Kakoranad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sariu II 0.46 0.55 1.88 3.05 3.05 2.98 3.36 2.41 1.42 1.00 0.94 1.24 22.33 Uttar Bharat Sariu III 0.47 0.47 1.31 3.13 2.99 3.22 2.85 1. 70 1.07 0.73 0.67 0.82 19.42 Ganoani 3.35 3.73 4.P 3.80 4.16 5.28 4.70 3.03 2.23 1.75 1.67 2.26 40.09 Badivar 1.14 1.05 1.35 1.39 1.24 1.80 1.84 1.50 1.07 0.81 0.84 1.11 15.13 Sub-Total 30.13 52.23 72.82 88.09 91.50 80.39 56.30 32.88 22.23 17.46 14.10 21.08 579.20

Co-Generation RBNS Suoar Mill 4.62 0.00 0.00 0.00 0.00 0.00 0.00 2.89 8.90 8.36 8.09 8.92 41.77 Uttam Sunar Mills 3.67 0.00 0.00 0.00 0.00 0.00 0.00 2.85 5.09 6.27 5.83 6.19 29.90 Lakshmi Suoar Mills 9.18 2.24 0.00 0.00 0.00 0.00 0.22 4.51 8.75 9.98 9.30 9.89 54.08 Sub-Total 17.47 2.24 o.oo o.oo 0.00 0.00 0.22 10.24 22.74 24.62 23.22 25.00 125.75

Gas Gama 65.50 66.56 59.87 66.36 64.59 46.61 63.36 0.00 25.97 38.54 23.90 54.53 575.77 Beta 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Shravanti 62.42 75.94 72.77 59.59 45.03 61.64 102.22 80.64 85.91 60.75 65.90 61.41 834.22 Sub-Total 127.92 142.50 132.64 125.95 109.62 108.25 165.58 80.64 111.87 99.29 89.79 115.94 1409.98

Page 223

Details of the stations Ao, Mav Jun Jul Aue Seo Oct Nov Dec Jan Feb Ma, Total

Solar RV Akash Ganaa solar r:iower ltd 0.27 0.26 0.27 0.21 0.22 0.21 0.23 0.17 0.16 0.15 0.15 0.26 7.57 Metro Frozen 0.13 0.13 0.13 0.09 0.10 0.11 0.11 0.08 0.08 0.07 0.07 0.12 1.21 Jav Ace Technoloaies 0.21 0.23 0.21 0.16 0.15 0.00 0.19 0.13 0.14 0.13 0.12 0.20 1.36 UJVNL (1.466) Dhakrani 0.23 0.25 0.23 0.17 0.19 0.18 0.24 0.19 0.19 0.16 0 .16 0.23 2.c,2 UJVNL I 4.398)khodari 0.67 0.72 0.67 0.49 0.54 o.ss 0.71 0.58 0.57 0.48 0.45 0.69 7.11 Redwoods o.oo 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 o.oo Madhav Infra 2.01 2.02 1.94 1.35 1.46 1.62 1.85 1.43 1.34 1.26 1.21 2.00 19.50 Purshotam Industries Ltd.-I @7. 0.11 0.11 0.10 0.08 0.12 0.00 0.11 0.09 0.08 0.08 0.07 0.12 1.07 Purshotam Industries Ltd.-II @ 0.14 0.15 0.12 0.09 0.11 0.00 0.13 0.10 0.10 0.09 0.08 0.14 1.24 Purshotam Isoat-I @7 .96 0.13 0.13 0.13 0.11 0.12 0.00 0.14 0.12 0.11 0.10 0.09 0.16 1.34 Vivaan Solar Pvt. Ltd. 0.42 0.43 0.38 0.30 0.34 0.34 0.40 0.32 0.31 0.28 0.26 0.45 4.22 Eastman International 0.10 0.10 0.09 0.07 0.08 0.08 0.09 0.07 0.07 0.06 0.06 0.10 0.98 Purshotam Isoat-II @7.88 0.14 0.14 0.13 0.10 0.08 0.00 0.13 0.11 0.11 0.09 0.09 0.15 .l.27 R.C. Enerm, 0.12 0.13 0.13 0.08 0.10 0.11 0.11 0.10 0.10 0.08 0.08 0.12 1.26 Advika Enerov 0.14 0.17 0.16 0.11 0.12 0.13 0.12 0.10 0.10 0.09 0.09 0.14 1.46 A.R. Solar Power-I @5.670 0.14 0.16 0.16 0.10 0.10 0.11 0.14 0.10 0.10 0.07 0.09 0.14 1.42 A.R. Sotar Power-II @5.690 0.15 0.17 0.17 0.12 0.12 0.13 0.13 0.09 0.10 0.09 0.10 0.14 1.53 Devishi Renewal ener 2.12 2.26 2.14 1.65 1.56 1.75 1.93 1.50 1.46 1.48 1.29 2.28 21.53 Devishi Solar oower 2.04 2.24 2.15 1.68 1.68 1.78 1. 99 1.53 1.47 1.51 1.31 2.32 21.71 Eminet Solar oower 2.04 1.82 2.10 1.67 1.84 1.76 7 .00 1.60 1.47 1.42 1.30 2.18 21.20 Sun world Enern,, ovt 2.02 1.78 1.99 1.60 1.74 1.67 1.85 1.49 1.39 1.34 1.25 2.12 20.24 Emami Power Ltd. 2.96 3.01 3.01 2.34 2.45 2.27 2.97 2.32 2.10 2.06 2.05 2.98 30.53 Hvdro Power Enl"'ineers 0.16 0.17 0.17 0.12 0.12 0.13 0.14 0.11 0.09 0.09 0.09 0.15 1. 53 Imoex India 0.38 0.40 0.39 0.29 0.30 0.30 0.36 0.27 0.25 0.25 0.24 0.35 3.77 Technioue Solaire Invest 0.80 0.84 0.80 0.60 0.62 0.63 0.73 0.56 0.56 0.49 a.so 0.80 7.93 Makin Develooers Pvt. Ltd 0.16 0.18 0.17 0.12 0.13 0.13 0.15 0.11 0.11 0.10 0.11 0.16 l.63 Ballunur solar ower nvt.Ltd 1.55 1.52 1.56 1.17 1.11 1.23 1.44 1.13 1.11 1.09 1.01 1.62 15.53 Chudiala Solar oower oroiect ov 1.58 1.57 1.64 1.27 1.26 1.30 1.48 1.15 1.13 1.09 1.02 1.64 16.13 Shakumbhari solar nower nroier 1.57 1.56 1.64 1. 24 1.18 1.27 1.47 1.15 1.12 1.08 1.01 1.64 15.94 Bindookharak solar oower oroie 0.82 0.85 0.82 0.63 0.64 0.64 0.77 0.63 0.57 0.57 0.50 0.86 8.29 Bhaowanour solar oroiects oriva 0.83 0.84 0.83 0.64 0.63 0.63 0.80 0.62 0.57 0.57 0.51 0.85 8.32 Pl sunravs nower limited 1.63 1.69 1.60 1.29 1.41 1.39 1.50 1.28 1.25 1.18 1.03 1.75 17.02 PL surva vidvut ltd 1.64 1.71 1.54 1.19 1.34 1.29 1.44 1.30 1.26 1.23 1.02 1.72 16.68 PL solar Renewable !td 1.62 1.11 1.63 1.30 1.41 1.39 1.37 1.15 1. 73 1.11 0.99 1.72 16.01 Haridwar solar oroiects ovt ltd 1 1.63 1.63 1.61 1.21 1.15 1.22 1.57 1.21 1.11 1.12 1.01 1.66 16.13 Haridwar solar nroiects nvt ltd 1.65 1.66 1.63 1.27 1. 28 1.30 1.55 1.25 1.13 1.12 1.03 1.71 16.57 Sunheti solar Power nroi ovt ltd 0.77 0.78 0.76 0.56 0.61 0.65 0.73 0.58 0.55 0.51 0.46 0.82 7.79 AB Renewable Ener ovt ltd 0.86 0.84 0.77 0.40 0.40 0.47 0.75 0.61 0.55 0.55 0.54 0.87 7.61 Canal Bank Solar nv nlant Dha k 1.04 1.07 1.00 0.75 0.81 0.84 0.89 0.72 0.71 0.62 0.59 1.02 10.06 Canal Bank Solar pv olant Dhali 1.15 1.21 1.11 0.81 0.89 0.87 1.10 0.83 0.80 0.67 0.70 1.06 11.22' Canal Ton Solar nv nlant Dhalini 0.13 0.16 0.14 0.10 0.11 0.11 0.00 0.01 0.05 0.06 0.06 0.10 1.03 Dakoatthar canal Bank t4.5 MW 0.60 0.71 0.68 0.31 0.54 0.58 0.71 0.57 0.57 0.47 0.45 0.71 6.89 Sub-Total 36.88 36.93 36.89 27.83 29.26 29.19 34.52 27.47 26.29 25.04 23.23 38.25 371.77

Solar Rooftoo EDC DEHRADUN 0.00 0.00 0.00 0.00 0.00 0.00 0.13 0.06 0.15 0.15 -0.03 0.05 0.50 EDC SRINAGAR 0.00 0.00 0.00 0.00 0.00 0.00 0.07 0.06 0.06 0.01 0.03 0.10 0.34 EDC TEHRI 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo UOC DEHRADUN 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 u.02 EDC HARIDWAR 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.09 0.08 0.07 0.16 0.13 0.63 EDC ROORKEE 0.00 0.00 0.00 0.00 0.00 0.00 0.44 0.33 0.32 0.28 0.30 2.46 4.14 EDC HALDWANI 0.00 o.oo 0.00 0.00 0.00 0.00 0.01 0.01 0.01 0.00 0.00 0.00 0.04 EDC KASHIPUR 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Page 229

Details of the stations ADC Mav Jun Jul Auo Sea Oct Nov Dec Jan Feb Mac Total EDC RANIKHET 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EDC RUDRAPUR o.oo 0.00 0.00 0.00 0.00 0.00 0.29 Q.75 0.23 0.22 0.19 0.64 1.83 EDC PlTHORAGARH o.oo 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 Sub-Total o.oo o.oo o.oo 0.00 0.00 0.00 1.04 0.80 0.86 0.75 0.66 3.37 7.48

Other Larae Private Meia Thermal I o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 Sasan 64.63 58.98 57.61 52.51 47.79 50.24 58.30 64.60 63.79 65.99 59.51 64.34 708.30 Sub-Total 64.63 58.98 57.61 52.51 47.79 50.74 58.30 64.60 63.79 65.99 59.51 64.34 708.30 Total IPP 277.17 293.11 300.24 294.73 278.56 268.51 316.46 216.96 248.06 233.30 210.70 268.08 3205.87 Uocomina Stations

15.86 14.47 14.14 12.89 11.73 12.33 14.31 15.85 15.65 16.19 14.60 15.79 173.80 15.90 14.51 14.18 12.92 11.76 12.36 14.35 15.90 15.70 16.24 14.64 15.83 174.29

.· 0.00 o.oo 0.00 0.00 0.00 o.oo 0.00 0.00 o.oo 0.00 0.00 o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

28.04 25.68 32.98 34.10 30.29 44.11 44.99 36.63 26.23 19.95 20.47 27.27 370.74 6.86 6.28 8.07 8.34 7.41 10.79 11.00 8.96 6-41 4.88 5.01 6.67 90.68

... · 0.00 0.00 o.oo o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

.S;';;C"t :.;o;::,r 14.65 17.34 16.44 7.43 13.09 13.98 17.26 13.87 13.95 11.41 10.82 17.25 167.49 seer 1 ,,,:,-::_~ :;[();· 9.15 10.84 10.28 4.64 8.18 8.74 10.79 8.67 8.72 7 .13 6.77 10.78 104.68 UF<i::D.C, :::o:?.r 25.04 29.64 28.11 12.70 22.38 23.90 29.52 23.72 23.84 19.51 18.51 29.49 286.35 Sub-Total 115.50 118.76 124.19 93.02 104.83 126.21 142.22 123.61 110.so 95.30 90.82 123.09 1368.03

State Rovaltv Power Dhaulioanoa 6.44 11.54 17.40 21.64 21.65 18.05 10.11 5.58 4.16 3.32 2.92 3.77 126.59 Tanaknur 1.13 2.43 3.92 5.31 5.92 6.84 5.68 3.24 1.82 1.12 1.13 0.90 39.44 Tehri 17.52 16.84 20.48 42.37 70.21 41.84 25.45 24.35 29.16 32.80 26.01 27.57 374.59 Koteshwar 8.72 8.71 10.98 17.87 25.23 14.03 8.33 8.23 10.08 11.88 10.09 11.66 145.81 Vishnu Pravao 9.73 25.46 34.90 32.82 34.18 33.72 21.87 10.39 7.74 6.17 5.00 5.59 227.57 GVK Srinanar 5.35 9.33 16.64 26.16 27.15 24.89 14.03 6.90 5.03 4.03 3.47 4.14 147.12 Raiwakti Him Uria SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total 48.89 74.30 104.31 146.17 184.34 139.37 85.47 58.70 57.99 59.32 48.62 53.63 1061.11 Total Power Purchase from F 1026.97 1277.83 1457.78 1447.16 1489.40 1402.47 1215.95 933.57 952.35 936.65 837.16 999.77 13977.06 Ooen Market Purchases & UI Bankino Received o.oo 0.00 o.oo 0.00 o.oo 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 UI Net drawal 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tender Purchases 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 IEX (Net Purchases) 137.97 -50.30 -86.93 -93.03 -165.46 -119.23 15.32 298.68 309-47 337 .59 373.05 184.74 1141.87 Reactive Pavables o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 Qnen Market Purchase (Extra 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total 137 .97 -50.30 -86.93 -93.03 -165.46 -119.23 15.32 298.68 309.47 33 7 .59 373.05 184.74 1141.87 Total Purchases 1164.94 1227 .54 1370.84 1354.12 1323.93 1283.24 1231.27 1232.25 1261.82 1274.25 1210.21 11S4.51 15118.93 Less: Bankino Pavable UI Underdrawal Reactive Units Receivables Sub-Total o.oo o.oo 0.00 0.00 o.oo 0.00 o.oo o.oo 0.00 o.oo o.oo o.oo 0.00

State Consumntion 1164.94 1227.54 1370.84 1354,12 1323.93 1283.24 1231.27 1232.25 1261.82 1274.25 1210.21 1184.51 15118.93

Page 230

Name of Distribution Uttarakhand Power Corporation Limited

Licensed Area of Sui Uttarakhand

Detail of UI Charge and Additional UI Charge Payable/ Receivable for Overdrawal / Underdrawal from Central Generating Stations

FY 2018-19

Overdrawals during Underdrawa!s

Below 49.20 Below 49.50 and upto

Below 49.90 49.50-50.20 Month 49.20

UI Au<J1t1 U! Additional Additional UI UI Additional UI Charge 1 u, 1...narge

MU Charge

onal MU Charge UI Charge

MU Ul Charge Charge

MU Charge Ul Charge

MU Receivable

Payable{P ... .,.,' Anril 0 0 0 0 0 0 3.56 16682703 3422524 26.46 7.1E+07 11373549 29.92 62234296 4270308 Mav 0 0 0 0 0 0 14.51 73809846 15299656 50.43 1.7E+08 35980675 29.15 34923937 1610470 June 0 0 0 0 0 0 7.21 36384223 9126882 42.40 1.2E+08 21763927 22.29 29954748 42865? Julv 0 0 0 0 0 0 5.82 28346616 8727240 44.64 1.1E+08 28819707 19.37 32997921 153210 Au oust 0 0 0 0 0 0 1.88 8999371 691961 12.79 3.4E+07 2385528 37.42 62834359 241140 Sentember 0 0 0 0 0 0 2.55 12367230 1406849 16.73 4.5E+07 5186427 36.02 64364156 0 October 0 0 0 0 0 0 2.15 10411709 1815879 16.49 4.1E+07 5595280 35.48 54996457 258811 November 0 0 0 0 0 0 2.18 10015400 779102 24.64 6.2E+07 3768381 23.68 46076597 119418 December 0 0 0 0 0 0 3.51 17162371 1350131 26.61 7 .1E+07 5145348 23.82 51611059 3981546 TOTAL TILL 0 0 0 0 0 0 43.37 214179469 42620224 261.19 7 .2E+08 L2E+08 257.15 4.4E+0S 11063555

FY 2019~20

Overdrawals durino Underdrawa!s

Below 49.85 49.85 - 50.05 Above 50.05 Month

UI Additional Additional UI UI Additional I vi 1...11arge

MU MU UI Charge MU MU UI C~arge Pa able(P Charge UI Charge Charge Charge Ul Charge Receivable Y

" Januarv 0.9 7E+06 7029000 23.85 92129628 3913243 0.91 0 0 23.76 648303131 9687916 Februarv 0.3 2E+06 2318352 12.71 44001245 1610565 0.34 0 0 31.97 86414031110099618 March 0.3 2E+06 2261024 13.37 44757811 2428406 0.89 0 0 29.34 75140295 11227727 Anril 0.3 3E+06 2738360 15.64 54442426 4180886 0.84 0 0 21.94 43037240 12151358 Mae 0.6 5E+06 4641824 19.92 75350527 4379298 0.82 0 0 28.23 54802507 14927941 June 1.1 9E+06 8599432 24.53 91234892 6364695 1.73 0 0 20.52 39370502 3082109 Julv 0.5 4E+06 3590560 18.5 66704073 5102533 1.94 0 0 22.19 43494324 1530915 Au oust 0.6 5E+06 5021344 20.85 73503721 8007673 1.04 0 0 20.91 46439424 1242909 Sentember 0.2 2E+06 1864848 18.22 52477196 5764276 0.62 0 0 20.161 33831029 1350004 Total for the year 4.8 4E+07 38064744 167.59 594601519 41751575 9.13 0 0 219.02 4.87E+OS 65300497

Total Ul Total

Sign Net Total Additional

Receivable charges

UI charges Deviation Receivable/Pa

Payable Payable

Charge yable

(Rs.) (Rs.) (Rs.) (Rs.) (Rs.)

57963988 70879339 11373549 24288900 33313467 169442649 35980675' 172109857 29526096 115906736 21763927 108144567 32844711 112732939 28819707 108707935 62593219 33752374 2385528 26455367 64364156 44795060 5186427 14382669 54737646 40594606 5595280 -8547760 45957179 61840428 3768381 19651630 47629513 71420087 5145348 28935922

428929975 721364168 1.2E+08 412453015

Total UI , o,a1

Sign Net Total

charges Additional

Deviation Receivable/Pa Receivable UI charges

Payable Pava"IR

Charge yable

(Rs. Cr.) (Rs. Cr.) (Rs. Cr.) (Rs.) (Rs. Cr.)

55142397 99158628 10942243 89532401 144490375 76314413 46319597 3928917 70153995 44088096 63912568 47018835 4689430 55989564 43785261 30885882 57180786 6919246 44994550 78208700 39874566 79992351 9021122 63370976 112509883 36288393 99834324 14964127 3250654 81760712 41963409 70294633 8693093 183018 37207335 45196515 78525065 13029017 367900 46725467 32481025 54342044 7629124 124965 29615108

422059168 632666263 79816319 3.28E+08 618391437

Page231

Name of Distribution Licensee licensed Area of Supply

Form: F-2.8

Energy Balance

FY 2019-20

Month* Particulars

Energy Sales Distribution Losses Energy Requirement at Discom Periohery PTCUL Losses Energy Requirement at State Periphery Total Energy Availability at State Periphery Energy Deficit/ (Surplus)*

FY 2020-21 Month*

Particulars

Enerov Sales Distribution Losses Enern, Reouirement at Discom Periohen, PTCU L Losses Energy Requirement at State Periphery Tota! Energy Availability at State Periphery Energy Deficit/ (Surplus)*

Uttarakhand Power Corporation Limited Uttarakhand

Apr May June July Aug

938 993 1,112 1 094 1 071 156 165 185 182 178

1 094 1,158 1 296 1 275 1,249 16 16 18 18 18

1 109 1 175 1 315 1 293 1 267

1306.53 ##### 1562.37 1384.54 1451.52

/197 (285\ (248' (91 (185'

Apr May June July Aug

967 1 024 1,145 1 127 1 104 157 167 186 183 180

1124 1.190 L332 1 310 L283 16 17 19 19 18

1,140 1 207 1 351 1 329 1,301

1 008 1,255 1434 1 418 1 460

132 (48 (831 (89 (159

Sep

1 040 173

1 213 17

1 230 1228.98

1

Sep

1 072 174

1,246 18

1,264 1,378 (114

Oct Nov Dec Jan

997 988 1,012 1,021 166 164 168 170

1 163 1 153 1,180 1 191 17 16 17 17

1 179 1 169 1197 1 207 1123.21 783.20 836.16 899.96

56 386 361 307

Oct Nov Dec Jan

1 027 1 018 1,043 1 052 167 166 170 171

1 195 1,184 1 213 1 223 17 17 17 17

1 211 1 201 1 230 1 241 1 197 915 934 917

15 286 296 323

Feb

968 161

1 129 16

1,145 779.09

366

Feb

997 16?

1 160 16

1176 819 357

Mac

952 158

1110 16

1 126 919.56

206

Ma,

981 160

1140 16

1,157 980 177

/'. ( ' ;::t

Total

12,185 2 025

14,210 202

14 412 1144.56

678 .. Petitioner

Total

12 557 2 044

14 601 207

14 sos

1 094

Page 232

Name of Distribution Licensee Ucensed Area of Supply

Form: F-2.9

Power Purchase Expenses

2019-20

Source of Power (Station wise)

NHPC Sala] Tanakour Chamera I Chamera II Chamera III Uri Dhauliqanoa Oulhasti Sewa II Uri II Parbati l1I KishannanrJa Sub-Total

SJVNL Nathpa Jhakri Rampur Eouitv Power

Ramr:iur Free Power Sub-Total

THDC Tehri HEP I Koteshwar Sub-Total

NTPC Sincrauli F G Unchahar-1 F G Unchahar-2 F G Unchahar-3 F G Unchahar-4 N CT Dadri:2 Rihand-1 STPS Rihand-2 STPS Rihand-3 STPS Kahaloaon-lI Jhaiiar Aravali Sinarauli SHEP

Fixed Cost Variable Other Cost payable by

Cost (P/U) (P/U) the UPCL (Rs. Cr.)

61.60 0.07 3.76 164.80 0.33 3.95 114.10 -0.27 7.26 100.50 0.09 3.29 212.30 0.08 16.22

82.20 0.08 9.66 121.50 0.24 11.24 274.90 59.79 28.25 216.90 0.09 8.93 237.30 0.07 24.52 153.90 0.26 18.78 168.80 0.00 3.61

98.43 0.07 11.31

192.58 0.09 140.74 0.00 0.00 0.00

212.70 0.21 21.09 231.38 0.20 23.48

139.62 0.29 44.31 334.54 15.98 26.80 337.81 7.46 10.52 334.71 17 .69 12.11 315.90 27.28 33.20 378.32 1.74 0.42 133.40 0.44 23.38 112.43 0.39 13.12 131.87 0.99 40.61 212.34 0.66 21.57 368.19 119.39 19.10 504.00 0.60 0.00

Variable Total Cost Total Cost to be Total

Cost payable (Fixed+ Any Other Cost paid by UPCL (Rs.

by UPCL (Rs. Variable) (Rs. Cr.) Cost per

Cr.} (Rs. Cr.) Cr.) unit

2.65 6.41 0.00 6.42 1.55 2.34 6.29 0.00 6.30 4.62

10.26 17.52 -0.02 17.50 2.03 3.08 6.37 0.00 6.38 2.17

13.45 29.67 0.00 29.68 4.89 7.49 17.14 0.01 17.15 1.97 8.99 20.24 0.02 20.26 2.86

33.11 61.35 6.90 68.25 5.92 7.50 16.43 0.00 16.43 4.96

19.30 43.82 0.01 43.83 5.63 6.35 25.13 0.01 25.14 6.36 2.94 6.55 0.00 6.55 3.92

263.88 3.93

9.87 21.18 0.01 21.19 ? .21

45.90 186.64 0.02 186.66 8.18 0.00 0.00 0.00 0.00 0.00

207.85 6.41

24.56 45.66 0.02 45.68 4.13 18.52 42.00 0.02 42.01 5.48

87.70 4.68

99.54 143.85 0.20 144.05 2.11 71.59 98.38 3.27 101.66 4.96 33.02 43.54 0.70 44.23 4.72 27.01 39.12 1.37 40.49 5.24 46.43 79.63 3.84 83.47 5.93

6.35 6.76 0.03 6.79 4.23 40.33 63.71 0.13 63.83 2.20 29.97 43.09 0.10 43.19 1.69 41.35 81.95 0.30 82.25 ?.74 39.61 61.18 0.12 61.30 3.43 24.65 43.76 7.66 51.41 8.02

0.00 0.00 0.00 0.00 0.00

Page 233

/

Fixed Cost Variable Other Cost payable by

Source of Power (Station wise) Cost (P/U) (P/U) the UPCL (Rs.

Cr.)

Koldam fHvdro) 253.05 1.42 64.39 Barh STP 1 0.00 0.00 0.00 Barh STP II 0.00 0.00 0.00 North Karanoura 0.00 0.00 0.00 Sinnrauli STPS 11I 0.00 0.00 0.00 Anta Gas 342.92 ?30.44 12.95 Auraiva Gas 459.11 61.83 18.57 Dadri Gas 433.79 126.89 19.85 Sub-Total

NPCIL Narora APP 248.53 3.51 0.00 Raiasthan APP 328.11 6.41 0.00 Sub-Total Total CSGS UJVNL Larae Hvdro Dhakrani 101.40 40.00 10.75 Dhaliour 82.00 40.00 11.55 Chlbro 53.00 40.00 33.54 Khodri 65.00 40.00 18.54 Kulhal 83.25 40.00 8.59 Ramaanaa 139.00 40.00 11.08 Tiloth 63.00 40.00 17.21 Chilla 51.00 40.00 30.91 Khatima 114.70 40.00 27.53 UJVNL Receivable 0.00 0.00 0.00 Sub-Total

Maneri Bhali II 100.73 40.00 117.72

Small Hvdro Mohd. Pur 204.00 0.00 o.oo Pathri 153. 00 40.00 0.00 Kanchauti 0.00 0.00 0.00 Chhirkila 0.00 0.00 o.oo Kulaoarh 0.00 0.00 0.00 Relaoad 0.00 0.00 0.00 Dunao SHP 1.5 MW 469.00 0.00 o.oo Surinaarh 0.00 0.00 o.oo Santeshwar 0.00 0.00 o.oo Gauri 0.00 0.00 0.00 Pandukeshwar 0.00 0.00 0.00 Taleshwar 0.00 0.00 o.oo Chharandev 0.00 0.00 0.00 Kotabanh 0.00 0.00 0.00 Harsil 0.00 0.00 0.00 Pllannad 285.00 0.00 0.00 Tharali 0.00 0.00 0.00

variable Total Cost Cost payable {Fixed + Any Other Cost by UPCL {Rs. Variable) (Rs. Cr.)

Cr.) (Rs. Cr.)

58.04 122.43 0.31 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 3.87 16.82 2.49 5.62 24.19 0.72

24.96 44.81 6.99

45.84 45.84 0.62 63.36 63.36 1.19

10.69 21.44 4.?2 12.48 24.03 6.09 35.91 69.45 27.10 19.17 37 .71 11.79

9.05 17.64 4.35 31.55 42.63 9.08 74.37 41.58 15.47 36.85 67.76 28.90 24.66 52.19 8.60

0.00 0.00 0.00

132.31 250.03 52.54

10.92 10.92 o.oo 18.54 18.54 4.35 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.98 0.98 0.00 0.00 0.00 0.00 o.oo 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.70 0.70 0.00 o.oo 0.00 0.00

Total Cost to be paid by UPCL (Rs.

Cr.)

1 ?2.74 0.00 0.00 0.00 o.oo

19.31 24.91 51.81

941.44

46.46 64.55

111.01 1611.88

25.65 30.12 96.55 49.50 71.99 51.71 57.05 96.67 60.79

0.00 490.02

302.57

10.92 23.39

0.00 0.00 0.00 0.00 0.98 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 0.70 o.oo

Total Cost per

unit

5.59 0.00 0.00 0.00 0.00

17.87 21.25

9.40 3.62

2.63 3.49 3,07 3.89

2.43 1.98 1.43 1.68 7 .02 2.28 1.48 1.34 2.83 0.00 1.70

2.30

2.04 1.93 0.00 0.00 0.00 0.00 4.69 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 7 .85 0.00

,t \)

t--/ Page 234

Fixed Cost Variable Total Cost Variable Other Cost payable by Cost payable (Fixed+ Any Other Cost

Total Cost to be Total Source of Power (Station wise)

Cost (P/U) (P/U) the UPCL (Rs. by UPCL (Rs. Variable) (Rs. Cr.) paid by UPCL (Rs. Cost per

Cr.} Cr.) (Rs. Cr.) Cr.) unit

Uraam 195.00 40.00 0.00 1.01 1.01 0.21 1.22 2.35 Sonenravaq 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Badrinath 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tilwara 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tanovan 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Jumma 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Galori 125.00 40.00 0.00 0.92 0.92 0.29 1.21 1.65 Kaliaanoa 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00 Sub-Total 38.42 2.00

Total UJVNL 831.01 1.89 UREDA Sub Total UREDA Solar Solar Plant Dehra Dun 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub Total UREDA Biomass Avni Bio Enerqv 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total

IPP Hvdro Raiwakti Him Uria SHP 350.00 0.00 0.00 8.23 8.23 0.00 8.23 3.50 Hanuman Ganaa SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Greenko Budhil Hvdro Power Pvt Ltd 182.20 57.89 38.91 38.27 77.18 11.65 88.82 4.41

Debal chamoli hvdro 380.00 5.00 0.00 7.21 7.21 0.09 7.30 3.85 LoharKhet { parvativa nowerl 380.00 5.00 0.00 8.80 8.80 0.12 8.92 3.85 Gunsola Hvdro Aaunda Thati 440.00 5.00 0.00 6.53 6.53 0.07 6.61 4.45 Bh ilanqanarswasti l 380.00 5.00 0.00 38.22 38.22 0.50 38.72 3.85

Vanala 499.00 0.00 0.00 24.97 24.97 0.00 24.97 4.99

Motinhat 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Rishiaanqa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Birahi Ganna 410.00 5.00 0.00 10.71 10.71 0.13 10.84 4.15 Tanqa !HHPLl 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 HHL: Jalandhariaad 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 0.00

HHL: Sivancad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

HHL: Kakoraaad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sariu II 587.00 0.00 0.00 15.91 15.91 0.00 15.91 5.87

Uttar Bharat Sariu III 577.00 0.00 0.00 11.78 11.78 0.00 11.78 5.77

Ganaani 450.21 0.00 0.00 20.65 20.65 0.00 20.65 4.50

.Badivar 504.00 0.00 0.00 8.92 8.92 0.00 8.92 5.04

Sub-Total 251.67 4.42

' Co-Generation RBNS Suqar Mill 230.41 0.00 5.27 10.41 15.69 0.00 15.69 3.47

Uttam Sucar Mills 289.00 0.00 1.89 8.63 10.52 0.00 10.52 3.52

Lakshmi Sunar Mills 328.00 0.00 1.20 14.72 15.91 0.00 15.91 3.55

Sub-Total 42.12 3.51

Gas Gama 562.79 0.00 99.05 324.04 423.09 0.00 423.09 7.35

Page 235

Fixed Cost Variable Total Cost Total Cost to be Total Variable Other Cost payable by Cost payable (Fixed+ Any Other Cost Source of Power (Station wise)

Cost (P/U) (P/U) the UPCL (Rs. by UPCL (Rs. Variable) (Rs. Cr.) paid by UPCL (Rs. Cost per

Cr.) Cr.) (Rs. Cr.) Cr.) unit

Beta 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Shravanti 563.37 0.00 268.56 665.25 933.81 0.00 933.81 7.91 Sub-Total 1356.90 7.72

Solar RV Akash Ganqa solar oower ltd 482.17 10.21 0.00 1.24 1.24 0.03 1. ?6 4.92 Metro Frozen 476.30 10.09 0.00 0.57 0.57 0.01 0.59 4.86 Jav Ace Technoloaies 566.34 0.00 0.00 1.06 1.06 0.00 1.06 5.66 UJVNL (1.466) Dhakrani 662.05 0.00 0.00 1.60 1.60 0.00 1.60 6.62 UJVNL r 4. 398 lkhodari 662.86 o.oo o.oo 4.71 4.71 0.00 4.71 6.63 Redwoods 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Madhav Infra 774.00 12.00 0.00 15.09 15.09 0.23 15.33 7 .86 Purshotam Industries Ltd.-I @7 .71 773.00 2.00 o.oo 0.83 0.83 0.00 0.83 7.75 Purshotam Industries Ltd.-11 (a:)7.73 771.00 2.00 0.00 0.96 0.96 0.00 0.96 7.73 Purshotam Isoat-I @7.96 788.00 2.00 0.00 1.05 1.05 0.00 1.06 7.90 Vivaan Solar Pvt. Ltd. 67? .08 1.70 o.oo 2.84 2.84 0.01 2.85 6.74 Eastman International 676.08 1.69 0.00 0.66 0.66 0.00 0.66 6.78 Purshotam Isoat-II @7.88 796.00 2.00 0.00 1.01 1.01 0.00 1.02 7.98 R.C. Enernv 671.54 0.00 0.00 0.85 0.85 0.00 0.85 6.72 Adv[ka Ener 641.17 0.00 0.00 0.94 0.94 0.00 0.94 6.41 A.R. Solar Power-I @S.670 483.66 2.05 o.oo 0.69 0.69 0.00 0.69 4.86 A.R. Solar Power-II @5.690 482.08 2.03 o.oo 0.74 0.74 0.00 0.74 4.84 Devishi Renewal enerm, 473.73 5.09 o.oo 10.20 10.20 0.11 10.31 4.79 Devishi Solar oower 476.37 5.08 0.00 10.34 10.34 0.11 10.45 4.81 Eminet Solar oower 487.55 5.06 0.00 10.33 10.33 0.11 10.44 4.93 Sunworld Enernv pvt 488.38 5.07 o.oo 9.89 9.89 0.10 9.99 4.93 Emami Power Ltd. 492.66 10.30 o.oo 15.04 15.04 0.31 15.36 5.03 Hvdro Power Ennineers 479.96 2.03 o.oo 0.73 0.73 0,00 0.74 4.82 Imoex India 478.51 2.40 0.00 1.81 1.81 0.01 1.82 4.31 Techninue Solaire Invest 491.10 12.00 0.00 3.90 3.90 0.10 3.99 5.03 Makin Develooers Pvt. Ltd 507.37 2.04 o.oo 0.83 0.83 0.00 0.83 5.09 Balluour solar power ovt. Ltd 493.85 1.45 0.00 7.67 7.67 0.02 7.69 4.95 Chudiala Solar oower nroiect nvt. 501.63 1.45 0.00 8.09 8.09 0.02 8.11 5.03 Shakumbhari solar oower oroiect ovt Ltd 505.51 1.46 0.00 8.06 8.06 0.02 8.08 5.07

Bindookharak solar oower oroiect ovt ltd 506.29 1.46 0.00 4.20 4.20 0.01 4.?1 5.08 Bhaowanour solar oroiects orivate ltd 511.66 1.47 0.00 4.26 4.26 0.01 4.27 5.13 PL sunravs oower limited 506.54 10.15 o.oo 8.62 8.62 0.17 8.79 5.17 PL surva vidvut ltd 480.57 10.22 0.00 8.02 8.02 0.17 8.19 4.91 PL solar Renewable ltd 487 .94 10.03 0.00 7.81 7.81 0.16 7.97 4.98 Haridwar solar nroiects nvt ltd 1 476.32 1.47 0.00 7.68 7.68 0.02 7.71 4.78 Haridwar solar oroiects ovt ltd 2 475.38 1.46 0.00 7.88 7.88 0.02 7.90 4.77 Sunheti solar oower oroi r.vt ltd 504.56 10.11 0.00 3.93 3.93 0.08 4.01 5.15 AB Renewable Ener ovt ltd 506.99 o.oo 0.00 3.86 3.86 0.00 3.86 5.07 Canal Bank Solar ov o!ant Dhakrani 583.50 o.oo o.oo 5.87 5.87 0.00 5.87 5.83 Canal Bank Solar nv olant Dhaliour 588.63 0.00 0.00 6.60 6.60 0.00 6.60 5.89 Canal Ton Solar ov olant Dhaliour 610.41 0.00 0.00 0.63 0.63 0.00 0.63 6.10 Dakoatthar canal Bank r4.5 MW\ 597 .78 0.00 0.00 4.12 4.12 0.00 4.12 5.98 Sub-Total 197.08 5.30

Page 236

Fixed Cost Variable Total Cost Total Cost to be

Variable Other Cost payable by Cost payable (Fixed+ Any Other Cost Total Source of Power (Station wise)

Cost (P/U) (P/U) the UPCL (Rs. by UPCL (Rs. Variable) (Rs. Cr.} paid by UPCL (Rs. Cost per

Cr.) Cr.) (Rs. Cr.) Cr.) unit

Other Laroe Private Meia ThermaJ I 327 .34 0.17 14.67 9.68 24.35 0.00 24.36 8.60 Sasan 138.45 25.29 11.13 91.78 102.91 16.06 118.98 1.87 Sub-Total 143.33 2.16 Total !PP 1991.10 5.70

State Rovaltv Power Dhauliqanqa 266.25 0.00 0.00 40.31 40.31 0.00 40.31 2.78 Tanakour 266.25 0.00 o.oo 13.69 13.69 0.00 13.69 2.78 Tehri 266.25 0.00 0.00 93.91 93.91 0.00 93.91 2.78 Koteshwar 266.25 0.00 0.00 37.14 37.14 0.00 37.14 2.78 Vishnu Pravaa 266.25 0.00 0.00 60.30 60.30 0.00 60.30 2.78 GVK Srinaaar 266.25 0.00 0.00 41.88 41.88 0.00 41.88 2.78 Raiwakti Him Uria SHP 266.25 0.00 0.00 0.59 0.59 0.00 0.59 ).66 Sub-Total 0.00 0.00 0.00 0.00 0.00 0.00 287.82 2.78 Total Power Purchase from Firm Sources Onen Market Purchases & UI Onen Market Purchase r Extra l 400.00 0.00 0.00 0.00 0.00 0.00 557.68 0.00 Sub-Total 557.68 4.18 Total Purchases 5279.49 3.67

State Consumotion 5279.49 3.67

Transmission Charoes PGCIL Sub-Total 475.95

PTCUL Sub-Total 266.36 Total Transmission charoes 742.31 Gross Consumotion 4.10 Total Power Purchase Cost (inc trans. Charoes) 6021.30 4.10

Page 237

Name of Distribution Licensee Licensed Area of Supply

Form: f-2,9

Power Purchase Expenses

2020-21

Source of Power (Station wise)

NHPC Sa!al Tanakour Chamera I Chamera II Chamera III Uri Dhaulioanoa Dulhasti Sewa II Uri II Parbatl III Kishanqanqa Sub-Total

SJVNL Nathoa Jhakri Rampur Equitv Power

Ramour Free Power Sub-Total

THDC Tehri HEP I Koteshwar Sub-Total

NTPC Sinqrauli F G Unchahar-I F G Unchahar-2 F G Unchahar-3 F G Unchahar-4 NC T Dadri:2 Rihand-1 STPS

Fixed Cost Variable Other Cost payable by

Cost (P/U) (P/U) the UPCL (Rs. Cr.)

64.06 0.07 3.91 171.39 0.33 4.11 118.66 0.00 7.55 104.52 0.09 3.43 220. 79 0.08 16.87

85.49 0.08 10.04 126.36 0.24 11.69 285.90 59.79 29.38 225.58 0.09 11.10 246.79 0.07 25.51 160.06 0.26 19.53 175.55 0.00 3.75

102.37 0.07 12.78

200.28 0.09 54.94 0.00 0.00 0.00

221.21 0.21 21.94 240.64 0.20 24.38

145.20 0.29 44.90 347.92 15.98 26.95 351.33 7.46 12.99 348.10 17.69 11.94 328.54 0.00 32.46 393.46 1.74 1.29 138.74 0.44 22.35

Variable Total Cost Total Cost to be Total

Cost payable (Fixed + Any Other Cost by UPCL (Rs. Variable) (Rs. c,.)

paid by UPCL (Rs. Cost per

Cr.) (Rs. Cr.) Cr.) unit

2.47 6.38 0.00 6.38 1. 73 1.48 5.59 0.00 5.59 6.76 9.54 17.09 0.00 17.09 2.22 2.72 6.15 0.00 6.15 2.46

12.07 28.95 0.00 28.95 5.53 7.84 17.88 0.01 17.89 2.04 6.85 18.55 0.01 18.56 3.57

35.90 65.28 7.19 72.47 6.02 6.25 17.35 0.00 17.35 6.54

18.18 43.68 0.01 43.69 6.19 5. 75 25.29 0.01 25.29 7.34 3.06 6.81 0.00 6.81 4.08

266.23 4.38

8.10 20.87 0.01 20.88 2.76

42.97 97.91 0.02 97.93 4.76 0.00 0.00 0.00 0.00 0.00

118.81 4.22

24.50 46.44 0.02 46.46 4.38 19.03 43.41 0.02 43.43 5.73

89.89 4.94

105.48 150.38 0.20 150.58 2.16 74.77 101.72 3.29 105.01 5.10 35.34 48.34 0.72 49.06 5.09 28.59 40.52 1.39 41.91 5.33 48.29 80.75 0.00 80.75 5.73

8.69 9.98 0.04 10.02 4.73 42.92 65.26 0.13 65.39 2.21

f; '{, •'-.3 -·

( .,.;-- Page 238

Fixed Cost Variable Total Cost Total Cost to be Total

Source of Power (Station wise) Variable Other Cost payable by Cost payable (Fixed + Any Other Cost

paid by UPCL (Rs. Cost (P/U) (P/U) the UPCL (Rs. by UPCL (Rs. Variable) (Rs. Cr.)

Cost per

Cr.) Cr.) (Rs. Cr.) Cr.) unit

Rlhand-2 STPS 116.92 0.39 14.16 32.03 46.20 0,10 46.30 1.76 Rihand-3 STPS 137.14 0.99 39.05 43.68 82.72 0.30 83.03 2.72 Kaha!oaon-II 220.84 0.66 21.59 41.20 62.78 0.12 62.90 3.52 Jhaiiar Aravali 382.92 119.39 15.15 21.84 36.99 6.52 43.52 7.96 Sinqraull SHEP 524.16 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Koldam (Hvdro I 263.18 1.42 64.39 53.49 117.88 0.28 118.16 6.07 Barh STP I 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Barh STP II 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 North Karanoura 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Slnaraull STPS III 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00,

Anta Gas 356.63 230.44 12.12 5.44 17.56 3.37 20.93 14.31 Auraiva Gas 477.47 61.83 18.20 5.83 24.03 0.72 24.75 21.17 Dadri Gas 451.14 126.89 18.04 29.09 47.12 7.84 54.96 8.90 Sub-Total 957.27 3.66

NPCIL Narora APP 258.47 3.51 0.00 41.55 41.55 0.54 42.09 2.73 Raiasthan APP 341.23 6.41 0.00 56.80 56.80 1.02 57.82 3:~ Sub-Total 99.91 3.19 Total CSGS 1532.10 3.83 UJVNL Larae Hvdro Dhakrani 105.46 40.00 10.75 9.13 19.88 3.46 23.34 2.70 Dhaliour 85.28 40.00 11.55 12.75 24.30 5.98 30.28 2.03

Chibro 55.12 40.00 33.54 31.64 65.18 22.96 88.14 1.54

Khodri 67.60 40.00 18.54 19.85 38.39 11. 75 50.14 1.71

Kulhal 86.58 40.00 8.59 8.59 17.18 3.97 21.15 2.13

Ramaanaa 144.56 40.00 11.08 )9.42 40.51 8.14 48.65 2.39

Tiloth 65.52 40.00 17. ?1 25.09 42.30 15.32 57.61 1.50

Chilla 53.04 40.00 30.91 38.24 69.15 28.84 97.99 1.36

Khatima 119.29 0.00 27.53 23.91 51.44 0.00 51.44 2.57

UJVNL Receivable 0.00 0.00 -0.10 0,00 -0.10 0.00 -0.10 0.00

Sub-Total 468.64 1.73

Maneri Bhali II 83.00 122.35 117.72 105.01 222.73 154.80 377.53 2.98

Small Hvdro Mohd. Pur 212.16 0.00 0.00 11.22 11.22 0.00 11.22 2.12

Pathri 159.12 40.00 0.00 19.25 19.25 4.84 ?4.09 1.99

Kanchauti 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Chhirkila 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Kulaaarh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oc Relaaad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Ounao SHP 1.5 MW 487.76 0.00 0.00 1.16 1.16 0.00 1.16 4.88

/~ Page239 _./

Fixed Cost Variable Total Cost Total Cost to be

Variable Other Cost payable by Cost payable (Fixed+ Any Other Cost Total

Source of Power (Station wise) Cost (P/U) (P/U) the UPCL (Rs. by UPCL (Rs. Variable) (Rs. Cr.)

paid by UPCL (Rs. Cost per

Cr.) Cr.) (Rs. Cr.) Cr.) unit

Surinaarh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Saoteshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Gauri 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Pandukeshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Taleshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Chharandev 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Kotabaah 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Harsil 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Pilannad 296.40 0.00 0.00 0.53 0.53 0.00 0.53 2.96 Tharali 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Uraam 202.80 0.00 0.00 0.49 0.49 0.00 0.49 2.03 Sonenravaa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Badrinath 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tilwara 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 Taoovan 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Jumma 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Galoai 130.00 40.00 0.00 0.84 0.84 0.26 1.10 1.70 Kalioanaa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total 38.60 2.06 Total UJVNL 884.77 2.13 UREDA SHPs U REDA: Bhiku riv a Gardh 0.00 0.00 o.oo 0.00 0.00 o.oo 0.00 0.00 Ramaarh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Barar + Garaun 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Surinr1arh 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Saoteshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Gauri 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Taleshwar 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Chharandev 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Kotabaah 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Harsil 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Thara!i 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Badrinath 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 0.00 UREDA: Kanoload SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UREOA: Lathi SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UREDA: Barsol SHP 0.00 0.00 0.00 0.00 0.00 o.oo o.oo 0.00 UREDA: Milkhet SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Sub Total UREDA Solar Solar Plant Dehra Dun 0.00 0.00 0.00 0.00 0.00 0.00 0.00 o.oo Sub Total UREDA Biomass Avni Bio Enernv 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00

Page 240

Fixed Cost Variable Total Cost Variable Other Cost payable by Cost payable (Fixed+ Any Other Cost

Total Cost to be Total Source of Power (Station wise) Cost (P /U) (P/U) the UPCL (Rs. by UPCL (Rs. Variable) (Rs. Cr.)

paid by UPCL (Rs. Cost per

Cr.) Cr.) (Rs. Cr.) Cr.) unit

Sub-Total

IPP Hvdro Raiwakti Him Uria SHP 364.00 0.00 0.00 7.07 7.07 0.00 7.07 3.64

Hanuman Ganoa SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Greenko Budhil Hvdro Power Pvt Ltd 189.49 57.89 36.92 48.10 85.02 14.08 99.09 4.08

Deba! chamoll hvdro 395.20 5.00 0.00 7.04 7.04 0.09 7.13 4.00

LoharKhet { oarvativa nowe(l 395.20 5.00 0.00 7.78 7.78 0.10 7.88 4.00

Gunso!a Hvdro Aounda Thati 457.60 5.00 0.00 6.02 6.02 0.07 6.09 4.63

Bhllanoanarswastil 395.20 5.00 0.00 35.75 35.75 0.45 36.21 4.00

Vana!a 518.96 0.00 0.00 21.76 21.75 0.00 21.76 5.19

Motiahat 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Rishiaanaa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Birahi Ganna 426.40 5.00 0.00 10.41 10.41 0.12 10.53 4.31

Tanna (HHPL) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

HHL: Jalandharinad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

HHL: Sivanoad 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00

HHL: Kakoraqad 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sariu II 610.48 0.00 0.00 13.63 13.63 0.00 13.63 6.10

Uttar Bharat Sariu III 600.08 0.00 0.00 11.65 11.65 0.00 11.65 6.00

Gannani 468.22 0.00 0.00 18.77 18.77 0.00 18.77 4.68

Badivar 524.16 0.00 0.00 7.93 7.93 0.00 7.93 5.24

Sub-Total 247.75 4.37

Co-Generation RBNS Suaar Mill 239.63 0.00 5.27 10.01 15.28 0.00 15.28 3.66

Uttam Suoar Mills 300.56 0.00 1.89 8.99 10.88 0.00 10.88 3.64

Lakshmi Suaar Mills 341.12 0.00 1.20 18.45 19.64 0.00 19.64 3.63

Sub-Total 45.80 3.64

Gas Gama 585.30 0.00 99.05 337.00 436.05 0.00 436.05 7.57

Beta 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Shravanti 585.90 0.00 268.63 488.77 757.40 0.00 757.40 9.08

Sub-Total 1193.45 8.46

Solar RV Akash Ganaa solar oower ltd 501.45 0.00 0.00 1.29 1.29 0.00 1.29 5.01

Metro Frozen 495.35 0.00 0.00 0.60 0.60 0.00 0.60 4.95

Jav Ace Techno!ooies 588.99 0.00 0.00 1.10 1.10 0.00 1.10 5.89

UJVNL (1.4661 Dhakrani 688.53 0.00 0.00 1.67 1.67 0.00 1.67 6.89

UJVNL (4.398'\khodari 689.38 0.00 0.00 4.90 4.90 0.00 4.90 6.89

Redwoods 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Madllav Infra 804.96 0.00 0.00 15.70 15.70 0.00 15.70 8.05

Ii ~ Page 241

/Ur' ,

Fixed Cost Variable Total Cost Total Cost to be Variable Other Cost payable by Cost payable (Fixed+ Any Other Cost Total

Source of Power (Station wise) Cost (P /U) (P/U) the UPCL (Rs. by UPCL (Rs. Variable) (Rs. Cr.)

paid by UPCL (Rs. Cost per

Cr.) Cr,) (Rs. Cr.) Cr.) unit

Purshotam Industries Ltd.-I @7.71 803.92 0.00 0.00 0.86 0.86 0.00 0.86 8.04 Purshotam Industries Ltd.-II @7.73 801.84 0.00 0.00 1.00 1.00 0.00 1.00 8.02 Purshotam Isoat-I @7,96 819.52 0.00 0.00 1.10 1.10 0.00 1.10 8.20 Vivaan Solar Pvt. Ltd. 698.96 0.00 0.00 2.95 2.95 0.00 2.95 6.99 Eastman Internatlonal 703.12 0.00 0.00 0.69 0.69 0.00 0.69 7.03 Purshotam Isoat-II @7.88 827.84 0.00 0.00 1.05 1.05 0.00 1.05 8.28 R.C. Enermr 698.41 0.00 0.00 0.88 0.88 0.00 0.88 6.98 Advika Enerm, 666.82 0.00 0.00 0.98 0.98 o.oo 0.98 6.67 A.R. Solar Power-I @5.670 503.01 0.00 0.00 0.72 0.72 0.00 0.72 5.o3 A.R. Solar Power-II @5.690 501.36 0.00 0.00 0.77 0.77 0.00 0.77 5.01 Devishi Renewal enerov 492.68 o.oo 0.00 10.61 10.61 0.00 10,61 4.93 Devishi Solar oower 495.43 0.00 0.00 10.76 10.76 o.oo 10.76 4.95 Eminet Solar oawer 507.05 0.00 0.00 10.75 10.75 0.00 10.75 5.07 Sunwor\d Enern" nvt . 507.91 0.00 0.00 10.28 10.28 0.00 10.28 5.08 Emami Power Ltd. 512.37 0.00 0.00 15.64 15.64 0.00 15.64 5.12 Hvdro Power Enoineers 499.15 0.00 0.00 0.76 0.76 0.00 0.76 4.99 Imoex India 497.65 0.00 0.00 1.88 1.88 o.oo 1.88 4.98 Techniaue Solaire Invest 510.74 0.00 0.00 4.05 4.05 0.00 4.05 5.11 Makin Deve\ooers Pvt. Ltd 527.67 0.00 0.00 0.86 0.86 0.00 0.86 5.28 Ballunur solar nower ovt.Ltd 513.60 0.00 0.00 7.98 7.98 0.00 7.98 5.14 Chudiala Solar power nroject nvt. 521.69 0.00 0.00 8.41 8.41 o.oo 8.41 5.22

Shakumbhari solar oower oroiect ovt Ltd 525.73 0.00 0.00 8.38 8.38 0.00 8.38 5.26

Bindookharak solar oower oroiect ovt ltd 526.54 0.00 o.oo 4.36 4.36 o.oo 4.36 5.27

Bhanwannur solar nroiects orivate ltd 532.12 0.00 0.00 4.43 4.43 0.00 4.43 5.32 PL sunravs power limited 526.80 0.00 0.00 8.97 8.97 0.00 8.97 5.27 PL surva vidvut ltd 499.79 0.00 0.00 8.34 8.34 0.00 8.34 5.00 PL solar Renewable ltd 507.46 0.00 0.00 8.12 8.12 0.00 8.12 5.07 Haridwar solar oroiects ovt ltd 1 495.38 0.00 0.00 7.99 7.99 0.00 7.99 4.95 Haridwar solar oroiects ovt \td 2 494.39 0.00 0.00 8.19 8.19 0.00 8.19 4.94 Sunheti solar power nroi nvt ltd 524. 74 0.00 0.00 4.09 4.09 0.00 4.09 5.25 AB Renewable Enernv nvt ltd 527.27 0.00 0.00 4.01 4.01 0.00 4.01 5.27 Canal Bank Solar ov olant Dhakrani 606.83 0.00 0.00 6.11 6.11 0.00 6.11 6.07 Canal Bank Solar ov o!ant Dhaliour 612.18 0.00 0.00 6.87 6.87 o.oo 6.87 6.12 Canal Too Solar ov olant Dhaliour 634.82 0.00 0.00 0.66 0.66 0.00 0.66 6.35 Dakoatthar canal Bank (4.5 MW'l 621.69 0.00 0.00 4.28 4.28 0.00 4.28 6.22 Sub-Total 203.01 5.46

Solar Rooftoo EDC DEHRADUN 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EDC SRINAGAR 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EDC TEHRI 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Page 242

Fixed Cost Variable Total Cost Variable Other Cost payable by Cost payable (Fixed+ Any Other Cost Total Cost to be Total

Source of Power (Station wise) Cost (P /U) (P/U) the UPCL (Rs. by UPCL (Rs. Variable) (Rs. Cr.)

paid by UPCL (Rs. Cost per

Cr.) Cr.) (Rs. Cr.) Cr.) unit

UOC DEHRADUN 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EDC HARIDWAR 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EDC ROORKEE 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EDC HALDWANI 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EDC KASHIPUR 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EDC RANIKHET 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EDC RUDRAPUR 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EOC PITHORAGARH 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total 4.01 5.36

Other Laroe Private Meia Thermal I 340.44 0.17 14.67 0.00 14.67 0.00 14.67 0.00 Sasan 143.99 25.29 11.12 101.99 113.11 17.16 130.27 1.92 Sub-Total 144.94 2.14 Total !PP 1838.96 5.81 Uocomina Stations Meia Thermal II 400.00 0.00 0.00 69.52 69.52 0.00 69.52 4.18 Tanda II 400.00 0.00 0.00 69.72 69.72 0.00 69.72 4.18 Bhvunder Ganqa 400.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Khairo Ganqa 400.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00, Vvasi 400.00 0.00 0.00 148.30 143.30 0.00 148.30 4.00 Taoovan Vishnuaad 400.00 0.00 0.00 36.27 36.27 0.00 36.27 4.18 Tehri Pumo Storaae 400.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vishnuaad 400.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Melkhet 400.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 SECI Solar 400.00 0.00 0.00 67.00 67.00 0.00 67.00 4.18 SECI Non-Solar 400.00 0.00 0.00 41.87 41.87 0.00 41.87 4.18 UREDA Solar 400.00 0.00 0.00 114.54 114.54 0.00 114.54 4.00 Sub-Total 547.21 4.09

State Rovaltv Power Dhauliaanaa 277.12 0.00 0.00 35.08 35.08 0.00 35.08 2.89 Tanaknur 277.12 0.00 0.00 10.93 10.93 0.00 10.93 2.89 Tehri 277.12 0.00 0.00 103.81 103.81 0.00 103.81 2.89 Koteshwar 277.12 0.00 0.00 40.41 40.41 0.00 40.41 2.89 Vishnu Pravaa 277.12 0.00 0.00 63.06 63.06 0.00 63.06 2.89 GVK Srinaoar 277.12 0.00 0.00 40.77 40.77 0.00 40.77 2.89 Raiwakti Him Uria SHP 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total 294.06 2.89 Total Power Purchase from Firm Sources 5097.10 3.72 Ooen Market Purchases & UI Bankinq Received 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UI Net draw al 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

,'>- Page 243

Fixed Cost Variable Total Cost Total Cost to be

Variable Other Cost payable by Cost payable (Fixed + Any Other Cost Total

Source of Power (Station wise) paid by UPCL (Rs. Cost per Cost (P /U) (P/U) the UPCL (Rs. by UPCL (Rs. Variable) (Rs. Cr.)

Cr.) unit Cr.) Cr.) (Rs. Cr.)

Tender Purchases 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IEX (Net Purchases) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Reactive Pavables 400.00 0.00 0.00 456.75 456.75 0.00 456.75 4.18 Ooen Market Purchase (Extra) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sub-Total 456. 75 0.00 Total Purchases 5553.85 0.00 Less: Bankino Pavable 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 UI Underdrawal 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Reactive Units Receivables 0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 Sub-Total 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

State Consumption 0.00 0.00 0.00 3885.03 5227.59 0.00 5553.85 0.00

Transmission Charaes PGCIL POC Charnes Transmission POSOCO NRLDC vpen Access ....... arges + L,1~"-""',

CHARGES FOR RETURN OF BANKED POWER Sub-Total 373.37

PTCUL PTCUL Bhilanaana-3 ULDC Sub-Total 415.45 Total Transmission charoes 788.82 Gross Consumption 6342.67 4.29 Water Tax Cost of REC 36.85 Total Power Purchase Cost (inc trans. Chara es) 6379.52 4.32

Page 244

Name of Uttarakhand Power Corporation Limited

Licensed Uttarakhand

Form: F-3

Details of Transmission and Load Dispatch Charges

FY 2018-19

S.No. Item Actuals

PGCIL Transmission 1 Charnes 437.10

PTCUL and SLDC 2 Transmission Char•es 311.88

Net charged to Revenue 748.97

(Figures in Rs Crore)

FY 2019-20 FY 2020-21

Estimated Projected

475.85 373.37

266.36 415.45

742.21 788.82

Page 245

Name Uttarakhand Power Corporation Limited Ucens, Uttarakhand

Form: F-4

Operations and Maintenance Expenses

Referen S.No. Item ce

1 Emolovee Exoenses F -4.1 2 Adminstrative & General Costs F -4.2

3 Re"air & Maintenance Exoenses F -4.3 Sub-total (1 to 31

FY 2012-13

(Actuals/ A udited)

224.04 76.60 16.59

317.23

FY 2013- FY 2014- FY 2015-

14 15 16

(Actuals/ A (Actuals/ A (Actuals/ A udited) udited) udited)

258.71 263. 70 246.94 77.18 86.99 115.51 18.01 20.99 17.51

353.89 371.69 379.95

Figures in Crores

FY 2016- FY 2017- FY 2018- FY 2019-FY 2020-21

17 18 19 20

(Actuals/ A (Actuals/ A (Actuals/ A Total

udited) udited) udited) (Estimated Projected

)

305.64 294.04 341.58 345.67 467.76 113.70 129.60 137.66 71.81 72.58

25.91 42.71 47.48 173.92 203.26 445.25 466.36 526.71 591.39 743.61

Page 246

Name of Di Uttarakhand Power Corporation Limited Licensed At Uttarakhand

Form: F- 4.1 Employee Expenses

S.No Particulars

FY 2012-13

(Actuals/ Audited)

A EmCJlovee's Cost (Other Than Covered In 'C'&'D' 1 Salaries 99.97

2 Additional Pay/ Dearness Allowance

67.16 ](DA) 3 other Allowances & Relief 12.45 4 Interim Relief/ Wane Revision 0.00 5 Honorarium/Overtime 0.00 6 Statutorv bonus! EX-<" ratia 0.49

Sub Total 180.07 B Other Costs

1 Medical Exoenses Reimbursement 3.87

2 Travelling Allowance(Conveyance

0.00 Allowance)

3 Leave Travel Assistance 0.00 4 Earned Leave Encashment 20.07

5 Payment Under Workman's

0.14 Comnensation And Gratuitv

6 Subsidised Electricitv To Emnio"ees 0.00 7 Anv Other Item 26.19 8 Staff Welfare Exnenses 0.18

Sub Total 50.45

C Apprentice And Other Training

0.54 Exnenses

D Contribution To Terminal Benefits 0.00 1 Provident Fund Contribution 0.82 2 Provision for PF Fund 0.00 3 Anv Other Items 26.10

Total D 26.92 Imnact of 7th Pav commission

E Grand Total 257.98 F Emn[ovee expenses canitalised 33.94 G Net Emolovee exoenses r E1-1 F) 224.04

Imnact of 7th Pav commission Total

FY 2013- FY 2014- FY 2015-14 15 16

(Actuals/ (Actuals/ (Actuals/ Audited) Audited) Audited}

97.78 92.82 88.54

79.35 91.93 97.28

15.13 16.60 15.92 0.00 0.09 0.00 0.00 0.00 0.00 1.02 1.18 1. 09

193.27 202.62 202.84

3.74 5.98 6.73

0.00 0.00 0.00

0.00 0.00 0.00 20.30 20.47 18.21

0.24 0.17 0.37

0.00 0.00 0.00 29.98 36.54 40.33 0.22 0.21 0.13

54.49 63.37 65.77

0.75 0.47 0.74

0.00 0.00 0.92 1.69 2.18 0.00 0.00 0.00

47.75 45.90 37.83 48.67 47.59 40.02

297.18 314.04 309.36 38.47 50.34 62.42

258.71 263.70 246.94

(Figures in Rs Crore) FY 2016- FY 2017- FY 2018- FY 2019- FY 2020-

17 18 19 20 21

(Actuals/ (Actuals/A (Actuals/ Audited) udited) Audited)

Projected Projected

126.20 101.77 li?.08 111.75 154.86

100.05 96.29 106.04 105.73 146.52

15.78 14.75 16.24 16. 'JO 22.44 0.00 o.oo 0.00 0.00 0.00

0.00 0.00 0.00 2.04 2.03 2.24 2,23 3.09

244.06 214.84 236.60 235.91 326.92

6.81 7.77 8.56 8.54 11.83

0.00 0.00 0.00

0.00 o.oo 0.00 0.00 0.00 20.19 20.50 22.58 22.51 31.20

0.18 0.39 0.43 0.43 0.60

0.00 0.12 0.14 0.14 0.19 49.32 58.13 64.01 63.83 88.45 0.77 0.28 0.31 0.31 0.42

76.75 87.20 96.03 95.75 132.69

0.74 0.68 0.75 0.74 1.03

2.29 2.33 2.56 ?.55 3.54 0.00 0.00 0.00

38.42 43.08 47.44 47 .30 65.55 40.72 45.41 50.00 49.86 69.09

29.19 -362.27 348.13 412.57 382.26 529.73 56.62 54.09 70.99 65.78 86.34

305.64 294.04 341.58 316.48 438.57 29.19 29.19

341.58 345.67 467.76

Page 247

Form: F- 4.1 Employee Expenses

8. Details of number of employees

s. No.

Item

1 TOP Met 1.1 MD AND Dir. 2 OFFICERS

2.1 Technical Cadre 2.1.1 Class A 2.1.2 Class B 2.2 Accounts Cadre

2.2.1 Class A 2.2.2 Class B 2.3 HRI Adm. Cadre

2.3.1 Class A 2.3.2 Class B

3 STAFF 3.1 Technical Cadre

3.1.1 Class C 3.2 Accounts Cadre

3.2.1 Class C 3.3 HRIAdmin Cadre

3.3.1 Class C 3.4 Oneratino Cadre

3.4.1 Class C 4 Others I Class D + Dvinn Cadre) 5 Total Emolovees

FY2012-13

(Actuals/ Audited)

4

102 233

11 22

3 8

382

130

1208 1751 3854

FY 2013- FY 2014- FY 2015-14 15 16

(Actuals/ (Actuals/ (Actuals/ Audited) Audited) Audited)

4 3 5

100 129 127 221 196 195

11 11 8 21 22 20

7 7 8 5 7 5

347 323 329

121 116 153

1213 1122 1189 1633 1561 1534 3683 3497 3573

FY 2016- FY 2017- FY 2018-FY 2019-20

17 18 19

(Actuals/ (Actuals/ A (Actuals/ As on As on 30-09- 31-03-

Audited) udited} Audited) 201'"' 2020

4 4 3 5 5 I

126 126 129 132 130 217 214 204 203 203

8 8 10 10 9 28 28 26 32 31

9 7 7 7 7 3 3 7 7 2

287 280 275 277 277

136 130 126 I 162 161

571 533 538 530 524

1163 1040 I 967 911 872 649 550 I 492 479 459

3201 2923 I 2779 2750 26SO

.-~ ;~

Page 248

Name of Distribution Licensee Licensed Area of Supply

Form: F-4.2 Reoair & Maintenance Exoenditure

S. No Particulars

1 Plant and Machinery

2 Building

3 Civil Works

4 Hydraulic Works

5 Lines, Cables Net Works etc.

6 Furniture and Fixtures

7 Office Equipments

Total (1 to 7)

Uttarakhand Power Corporation Limited Uttarakhand

FY 2012- FY 2013- FY 2014-13 14 15

(Actuals/ (Actuals/ (Actuals/ Audited) Audited) Audited)

24.37 15.59 19.81

3.78 2.14 2.28

0.12 0.40 0.74

0.00 0.00 0.00

48.11 58.65 63.69

0.02 0.04 0.04

0.21 0.36 0.42

76.60 77.18 86.99

FY 2015-16

(Actuals/ Audited)

25.35

6.72

0.52

0.00

81.78

0.00

1.13

115.51

(Fiqures FY 2016- FY 2017-

FY 2018-19 FY 2019-20 FY 2020-21 17 18

(Actuals/ (Actuals/ A (Actuals/ Audited FY 2019-20 FY 2020-21

Audited) udited) )

26.55 28.35 31.03 39.20 45.82

3.05 5.02 3.70 4.68 5.47

0.18 0.14 1.41 1.78 2.08

0.00 0.00 0.00 0.00 0.00

82.02 95.41 100.77 127.31 148.79

0.02 0.05 0.18 0.23 0.27

1.87 0.64 0.56 0.71 0.83

113.70 129.60 137.66 173.92 203.26

r,

JL i .---,

Page 249

Name of Distribution Licensee Licensed Area of Supply

Uttarakhand Power Corporation Limited Uttarakhand

form: F-4.3 Administration & General Expenses

S.No FY 2012-13 FY 2013-14

Particulars (Actuals/ (Actuals/ Audited) Audited)

A Administrative Exoenses 1 Rent rates and taxes

Lease / Rent 0.36 0.38 Rates & Taxes 0.05 0.04

2 Insurance 0.09 0.11

3 Comnensation for death and damaqes - 0.36

4 Revenue Stamn Exnenses Account 0.17 0.19

5 Telenhone Postaqe Teleqram & Telex Charqes 2.26 1.59

6 Incentive & Award To Emolovees/Outsiders - -7 Consultanrv Charoes 1.47 1.98

8 Technical Fees - -8 Other Professional Charqes 0.58 1.42

9 Conve;;ance And Travellinq 1.76 1. 75

10 License And Registration Plant & Machinery - -Fee Of Vehicles 0.06 0.20

Vehlcle Expenses (Other Vehicles Running

11 Than Trucks And Delivery Expenses Petrol 2.20 2.19 Anrl nj

Vans) Hirina Of Vehicles ro.21 0.06

12 Securit" / Service Charoes Paid To Outside - -13 Traininn

Sub-Total 'A' (1 To 13) 8.80 10.26

B Other Charnes 1 Fee And Subscrintions Books And Periodicals 0.08 0.14

2 Printinn And Stationerv 1.59 1.34

3 Advertisement Exoenses ( Other Than Purchase 2.20 2.32

FY 2014-15

(Actuals/ Audited}

0.36 0.06 0.09 0.44 0.17 1.86

-1.53

-1.47 1.73

-0.01

2.76

0.13 -

10.61

0.20 1.21 3.02

(Figures in R'--FY 2015- FY 2016- I FY 2017-

FY 2018-19 FY 2019- FY 2020-

16 17 18 20 21

(Actuals/ (Actuals/ (Actuals/ (Actuals/ Projected

Audited) Audited) Audited) Audited) Pro'1ected

I 0.35 0.57 0.48 0.51 0.24 0.75

0.10 0.07 0.03 0.04 0.02 0.02 0.10 0.11 0.12 0.13 0.06 0.06 0.67 0.98 1.04 0.50 0.51 0.17 - - - -3.26 2.73 2.13 7.27 1.08 1.11

- - - - -1.28 5.11 5.46 5.83 2.77 2.84

- - - - -1. 75 1.10 0.93 LOO 0.47 0.49 1.65 1.45 1.36 1.45 0.69 0. 71

- - - - -

0.01 0.01 0.06 0.07 0.03 0.03 ',j

3.27 3.41 4.26 4.54 2.16 2.21

0.07 0.20 - - -- 0.37 0.39 0.19 0.19

0.35 0.38 0.18 0.18 12.65 14.28 16.53 17.65 8.39 8.59

1. 7 5 0.12 0.18 0.19 0.09 0.09 1.62 1.53 1.43 1.52 0.72 0.74 3.90 3.89 4.11 4.39 2.09 2.14

Page 250

Form: F-4.3 Administration & General Expenses (Figures in R~ -S.No FY 2012-13 FY 2013-14

FY 2014- FY 2015- FY 2016- FY 2017-FY 2018-19

FY 2019- FY 2020-15 1s 17 18 20 21

Particulars (Actuals/ (Actuals/ (Actuals/ (Actuals/ (Actuals/ (Actuals/ (Actuals/

Projected Audited) Audited) Audited) Audited) Audited) Audited) Audited) Proiected 4 Contributions/Donations To Outside Institutes/ 0.10 - - - - - - - -5 Electricitv Charnes To Offices 3.20 3.79 6.77 4.65 5.23 9.63 10.28 4.89 5.00 6 Water Charqes 0.23 0.47 0.44 0.43 0.53 0.48 0.51 0.24 0.25 7 Entertainment Charqes 0.02 0.01 0.00 0.02 0.00 0.00 0.00 0.00 0.00 8 Exo. on CSR activities 1.46 - - - - -9 Miscellaneous Exnenses 4.93 5.92 5.54 6.30 7.04 5.72 6.10 2.90 2.97

10 Bandwidth Software licence Renewal Charqes 8.36 8.93 4.24 4.34 11 Penalty to UERC 6.29 6.71 3.19 3.27 12 U.E.R.C. Fees 2.52 ?.68 1.28 1.31

Sub-Total 'B' (1 To 8} 12.36 13.98 17.17 19.63 18.34 38.70 41.32 19.65 20.11 C Leaal Charaes 0.66 0.65 1.08 1.03 1.91 0.78 0.83 0.39 0.40 D Auditor's Fee 0.08 a.as 0.11 0.13 0.98 0.18 0.19 0.09 0.09 E Material Related Exoenses - -1 AMC of Harware - - - - 2.42 2.58 1.23 1. ?6 2 Purchase Related Advertisement Exoenses - - - 0.23 0.18 - - - -3 Vehicle runninq and hirinq exnenses (Truck/ - - 0.16 - 0.16 -4 other Freiaht - - - - - - - I 5 Transit Insurance - - - - - - -6 Octroi - - - - - - -7 Incidental Stores Bmenses - - - - - - -8 Fabrication Charoes - - - - - - - -

Sub Total 'E' <1 To 8) - - 0.16 0.23 0.33 2.42 2.58 1.23 1.26 Honararium 0.04 0.10 0.11 a.as a.as Grand Total c A To E) 21.89 24.97 29.13 33.67 37.61 58.72 62.68 29.81 30.50 A&G extlenses capitalised 5.30 6.96 8.14 16.16 11. 70 16.00 15.21 7.23 7.40 Net A&G Exoenses ! F - GI 16.59 18.01 20.99 17.51 25.91 42.71 47.48 22.58 23.10 Provision: Data Center Cost & License fees - 49.23 49.48 A&G exoenses includina Provision f H+Il 16.59 18.01 20,99 17.51 25.91 42.71 47.48 71.81 72.58

Name of Distribution Licen: Licensed Area of Supply

Form: F- 5,1

Uttarakhand Power Corporation Limited Uttarakhand

Statement of Grnss Fixed Asset Base & Financing Plan

FY 2018-19

Particulars of Assets Opening balance Additions during the year*

Land and Rlahts 18.41 0.17

Land held under lease 12.30 1.13 Buildinas 127.52 17.73

Plant & Machinarv 810.83 325.42 Lines&Cable Network 3604. 79 545.55 Furniture and Fixtures 11.61 0.34

Vehicles 2.88 0.02 Office Eauinment 25.39 41.49 OTHERS-: 0.00 0.11

-1.H\ldraulic Works 0.75 0.00

-2.0ther Civil Works 1.94 0.11 Intannible Fixed Assets 77.93

Total 4616.42 1009.90

FY 2019-20

Particulars of Assets Opening Balance Additions of assets during

the year*

Land and Rights 18.59

Land held under lease 13.43

Buildings 145.25

Plant & Machi nary 1072. 75

Lines&Cable Network 4141. 72

Furniture and Fixtures 11.91 Vehicles 2.90 Office E,.,uinment 66.88 OTHERS-: 0.11 -1.Hvdraullc Works 0.75 ~2.0ther Civll Works 2.05

Total 5554.15 937.06

fFiaures in Rs Crore

Retirement of assets Closing balance

during the year*

0.00 18.59 0.00 13.43 0.00 145.25

63.50 1072. 75 8.62 4141. 72 0.04 11.91 0.00 2.90 0.00 66.88 0.00 0.11 0.00 0.75 0.00 2.05 0.00 77.93

72.17 5554.15 ..

Petitioner

(Fiaures in Rs Crore'J

Retirement of assets Closing balance

during the year*

6491.21 - . Petitioner

Page 252

Name of Distribution Ucen: Licensed Area of Supply

Form: F- 5.1

Uttarakhand Power Corporation limited Uttarakhand

Statement of Gross Fixed Asset Base & Financing Plan

FY 2020-21

Particulars of Assets Opening balance Additions during the year*

Land and Rlohts Land held under lease Buildinns Plant & Machinarv Unes&Cable Network Furniture and Fixtures

Vehicles Office Eouinment OTHERS-: -1.Hvdraulic Works -2.0ther Civil Works

Total 6491.21 977.22

Fi(lures in Rs Crorel

Retirement of assets Closing balance during the year*

7468.43 ..

Page 253

Name of Distribution Licensee Licensed Area of Supply

Form: F- 5.2

Statement of Asset wise Depreciation

2018-19

Rate of Particulars of Assets Depreciation in

%

Land and Riahts Land held under lease 3.34% Buildinas 3.34% Plant & Machinerv 5.28% Lines&Cable Network 5.28% Furniture and Fixtures 6.33% Vehicles 5.28% Office Eauioment 6.33% OTHERS-: -1.Hvdraulic Works 3.34% -2.0ther Civil Works 5.28%

Intanoible Assets Total 5.21%

2019-20

Rate of Particulars of Assets Depreciation in

%

Land and Riahts Land held under lease 3.34% Buildinas 3.34% Plant & Machinerv 5.28% Unes&Cable Network 5.28% Furniture and Fixtures 6 33% Vehicles 5.28% Office Eauioment 6.33% OTHERS·: -1.Hvdraulic Works 3.34% -2.0ther Civil Works 5.28%

Total 5.21%

Uttarakhand Power Corporation Limited Uttarakhand

Opening GFA less Net Asset addition during Consumer the year less consumer

Contribution/ Grant contribution/ grant

2.169.41 367.66

Opening GFA less Net Asset addition during Consumer the year less consumer

Contribution/ Grant contribution/ grant

2,537.07 431.60

Fiqures in Rs Crore)

Closing GFA less consumer Average GFA

Depreciation for

contribution/ grant the Year

2.537.07 2.353.24 122.60

Closing GFA less Depreciation for

consumer Average GFA the Year

contribution/grant

2,968.67 2,752.87 173.12

Page 254

Form: F- 5.2

Statement of Asset wise Depreciation

2020-21

Rate of Opening GFA less Net Asset addition during Closing GFA less Depreciation for Particulars of Assets Depreciation in Consumer the year less consumer consumer Average GFA

% Contribution/ Grant contribution/ grant contribution/ grant the Year

Land and Riahts Land held under lease 3.34% Buildinas 3.34% Plant & Machinerv 5.28% Lines&Cable Network 5.28% Furniture and Fixtures 6 33% Vehicles 5.28% Office Enuinment 6.33% OTHERS-: -1.Hvdraulic Works 3.34% -2.0ther Civil Works 5.28%

Total 5.21% 2 968.67 650.00 3 618.67 3 293.67 201.30

Page 255

Name of Distribution Licensee Licensed Area of Supply

Form: F- 5.3

Statement of Depreciation

Financial Year FYOZ

Depreciation on Capital Cost

ueprec1at1on on Additional Capitalisation Amount or Additional Caoitalisation

Denrec:iation Amount

Detail of FERV MmounL 01 .... ". on which Depreciation is charoed

Deoreclation Amount

Depreciation recovered durlnq the vear 15.7

Advance against Depreciation recovered durlno the vear

Depreciation and Advance against Depreciation recovered durinq the vear

Depreciation and Advance against Depreciation recovered upto the vear 15.7

FY03 FY04

15.7 57.79

42.1 48.34

57.8 106.1

Uttarakhand Power Corporation Limited Uttarakhand

FYOS FY06 FY07 FY08 FY09 FYlO

106.1 155.1 174.2 190.3 209.2 228.1

.

48.97 19.06 16.13 18.89 18.87 24.33

155.1 174.2 190.3 209.2 228.1 252.4

fFioures in Rs Crore

FYll FY12 FY13 FY14 FY15 FY16 FY17 FY18 FY19 FYZO FYZl

257 285.6 321.8 360.5 436.17 542.03 656.15 774.89 902.30 1024.90 1198.03

33.2 36.2 38.77 75.63 105.86 114.12 118.74 127.40 122.60 173.12 201.30

286 321.S 360.5 436.2 542.03 656.15 774.89 902.30 1024.90 1198.03 1399.33

Page 256

Name of Distribution Licensee Licensed Area of Supply

Form: F-5.4

Uttarakhand Power Corporation Limited Uttarakhand

Contributions, Grants and subsidies towards Cost of Capital Assets

FY 2018-19 FY 2019-20 FY 2020-21

S. No. Source (Actuals/ Total Audited) (Estimated)

Projected

Consumer Contribution/Grant Towards Cost Of Capital

1 Assets

Sub-Total

Subsidies Towards Cost Of 1 Capital Assets

Grant Towards Cost Of 2 Capital Assets

Sub-Total

Total 570.07 505.46 327.21 ..

Pet1t1oner

Page 257

Name of Distribution Licensee Licensed Area of Supply

Form: F- 6.1

St t a ement o f C . IE ao1ta d"t xoen I ure

Particulars

A) Expenditure Details

al Land bl Buildina c) Maier Civil Works dl Plant & Machinerv el Vehicles f) Furniture and Fixtures ,., 1 Office Enuinment & Others Total fAl

B) Break up of sources of financing

Loan (in Rs. Cr.)

Eauitv (in Rs. Cr.)

Grant/Consumer Contribution (Rs. Cr.)

Total (Bl

Uttarakhand Power Corporation Limited Utta ra khan d

FY 2018-19 FY 2019-20 FY of COD

Actual / Audited Projected

795.04 1158.79

201.02 421.48

110.69 178.36

483.32 558.95

795.03 1158.79

FY 2020-21

Projected

745.36

437.11

188.34

119.91

745.36

Page 258

Name of Distribution Licensee Licensed Area of Supply

Form: F- 6.2

Statement of Capital Works-in-Progress

S. No. Particulars

1 Ooeninq balance of CWIP

2 Add: New Investment

Caoital Exoenditure

Exoenses Caoitalised

Interest Durinq Construction

3 Less: Investment Caoitafised

4 Closing balance of CWIP

Uttarakhand Power Corporation Limited Uttarakhand

FY 2018-19 FY 2019-20

Actual / Audited Total

(Estimated)

877.95 663.75

795.04 1 158.79

1009.24 937.06

663.75 885.48

FY 2020-21

Projected

885.48 745.36

977.22 653.62

Page 259

Name of Distribution Licensee Licensed Area of Supply

Form: F- 6,3

Details of Capital Cost and Financing Structure

Year ending March

Basic Proiect Financial Parameters Canital Cost*

Addition durino the vear Deletion durina the vear

Gross Canital Cost r A~ Eriuitv anainst Orininal Proiect Cost

Addition durino the vear Eauitv Sub-Total rs

Debt outstandino aoainst the oririinal Caoita! cost New Loans added durina the vear

Debt Sub-Total IC Grants anainst ori< in al nroiect cost

Addition durina the vear Grants Sub-Total (D

Total Financino fB+C+D~

Uttarakhand Power Corporation Limited Uttarakhand

FY 2017-18 FY 2018-19 FY of COD Actual/ Actual/

Audited Audited

397.55 937.73

13.46 130.56

256.06 237.10

128.03 570.07

397.55 937.73

FY 2019-20 FY 2020-21

Total (Estimated•

Projected

937.06 977.22

129.48 195.00

302.12 455.00

505.46 327 .21

937.06 977.22

Page 260

Name of Distribution Licensee Licensed Area of Supply

Form: F-6.4

Statement of Capital Works-in-Progress

Particulars

(A} Opening balance of CWIP

(a) Opening balance of CWIP as per books

(b) Amount of capital liabilities in (a) above

( c) Amount of (i) !DC (ii) FC (iii) FERV & (iv) Hedging cost included in (a) above

(B) Add: Addition/ Adjustment

(a) Add: Addition/Adjustment in CWIP Amount during the period

(b) Amount of capital liabilities in (a) above

( c) Amount of (i) !DC (ii) FC (iii) FERV & (iv) Hedglng cost included in (a) above l'-J Expenses cap1ta11sea

(a) Capitalization/Transfer to Fixed asset of CWIP Amount during the period

(b) Amount of capital liabilities in (a) above

(c) Amount of (i) !DC (ii) FC (iii) FERV & (iv) Hedging cost included in (a) above (D} Closing balance of CWIP

(a) Closing CWIP Amount as per books

(b) Amount of capital liabilities in (a) above (c) Amount of (i) !DC (ii) FC (iii) FERV & (iv) Hedging cost in (a) above

Uttarakhand Power Corporation Limited Uttarakhand

(Figures in Rs Crore)

FY 2018-19 FY 2019-20 FY 2020-21

Actual / Audited Total

Projected (Estimated}

877.95 663.75 885.48

795.04 1158.79 745.36

1009.24 937.06 977.22

663.75 885.48 653.62

Page 261

Name of Distribution Licensee Licensed Area of Supply

Form: F-6,5

Uttarakhand Power Corporation Limited Uttarakhand

Break-up of Construction/Supply /Service Packages

Scope of Whether

worksl (in awarded

No. of Name/No. of through Date of

line with head bids Date of Construction/ supply

of cost break-!CB/DCB/

receiv Award Start of

/ service package Departmental work ups as ed

applicable) ly/ Deposit Work, etc.

NA

Date of Completi

on of Work

IFioures in Rs Crorel

Actual Taxes &

Value of Firm or expenditure till

Duties !DC, FC,

With the completion FERV Award2 in and Sub-Total

(Rs. Escalati or up to COD

IEDC &Hedging

(Rs. Lakh) on in whichever is cost (Rs.

Lakh). (Rs. prices earlier (Rs.

Lakh) Lakh)

Lakh)

Pet1t1oner

Page 262

Name of Distribution Licensee Licensed Area of Supply

Form: F-6.6

Uttarakhand Power Corporation Limited Uttarakhand

Element wise Break-up of Project/Asset/Element Cost for Distribution System

Cost in Rs. Lakh

As per Original Estimates (3) Actual Capital Expenditure

S. No. as on COD (4)

Quantity Rate Estimated

Quantity Estimated

Amount Rate

Amount A TRANSMISSION LINE

1.0 Preliminarv works 1.1 Desinn & Enaineerinn

Preliminary Investigation, Right of way, 1.2 forest clearance, PTCC, general civil works

Liabilities/ Variation (6=3 Provisions (5) 4-5)

1.3 ,Total Preliminarv works Information is not available. The Petitioner requests waiver for the same

2.0 Transmission Lines material 2.1 Steel 2.2 Conductor 2.3 Earth Wlre 2.4 Insulators 2.5 Hardware Flttinns 2.6 Conductor & Earth wire accessories 2.7 Snares

2.8 Erection, Stringing & Civil works including "-·· --

Total Transmission Lines material

Fiqures in Rs Crore)

Reasons for Admitted Cost Variation (7) (8)

Page 263

Cost in Rs. Lakh

As per Original Estimates (3) Actual Capital Expenditure

S, No. as on COD (4) Liabilities/ Variation (6=3 Reasons for Admitted cost

Quantity Rate Estimated

Quantity Rate Estimated Provisions (5) 4-5) Variation (7) (8)

Amount Amount

3.0 Taxes and Duties 3.1 Custom Dutv 3.2 Other T::.x<>s & Duties

Total Taxes & Duties

Total -Transmission lines

B. SUBSTATIONS 4.0 Pre\iminar\1 works & land 4.1 Desian & Enoineerino 4.2 Land 4.3 Site ore,.,aration

Total Prelimin:;arv wnrks & J::.nd

5.0 Civil Works

5.1 Control Room & Office Buildfng rncluding " ..•

5.2 Townshin & Colonv 5.3 Roads and Drainaae 5.4 Foundation for structures 5.5 Misc. civil works

Total Civil Works

6.0 Substation Eouioments

6.1 Switchgear (CT,PT, Circuit Breaker, Isolator , ... , 6.2 Transformers

6.3 Compensating Equipment( Reactor, SVCs .. , 6.4 Control Rela" "' Prot<>ction Panel 6.5 Bus Bars/ conductorsllnsulators 6.6 Outdoor liahtinn 6.7 Emeroencv D.G. Set 6.8 Groundino Svstem Information is not available. The Petitioner requests waiver for the same 6.9 Structure for switchvard 6.10 6.11

Total Substation Eauioments 7.00 Snares

8.00 Taxes and Duties 8.1 Custom Dutv 8.2 Other Taxes & Duties 8.3 Total Taxes & Duties

Total rsub~stationl

C Communication S tem 9.1 Prellminarv Works

Page 264

Cost in Rs. Lakh

As per Original Estimates (3) Actual Capital Expenditure

S. No. as on COD (4) Liabilities/ Variation (6=3 Reasons for Admitted Cost

Quantity Rate Estimated

Quantity Estimated Provisions (5) 4-5) Variation (7) (8)

Amount Rate

Amount 9.2 Communication System equipment's

9.3 Taxes and Duties Total I Communication Svstem\

10.0 Construction and pre-commissioning

10.1 Site supervision & site administration etc.

10.2 Tools and Plants 10.3 construction Insurance

Total Construction and pre

--

11.0 Overheads 11.1 Establishment 11.2 Audit & Accounts 11.3 Contin,.,enc" Information is not available. The Petitioner requests waiver for the same

Total Overheads

12.0 Cost of Plant & Machinerv

13.0 Capital Cost including Plant & Machinery

13.1 Interest Durina Construction flDCl 13.2 Financinr Charnes (fC'

13.3 Foreign Exchange Rate Variation (FERV)

13.4 Hedninn Cost Total of !DC, FC, FERV & Hedging Cost

Capital cost including !DC, FC, FERV & ,_..,_, __ ,.. __ ,. I

Note. 1. In case of cost variation, a detailed note giving reasons of such variation should be submitted clearly indicating whether such cost over- run was beyond the control of the transmission licensee. 2. Separate details of free hold/lease hold land should be submitted.

/ f '

!~ Petitioner

Page 255

Name of Distribution Licensee Licensed Area of Supply

Form: F-6.7

Statement of Additional Capitalisation after COD

Work/Equipment

S.No. Year proposed to be added after

COD upto Cut off Date/beyond Cut- off Date

1

3 4 5

I

Uttarakhand Power Corporation Limited Uttarakhand

Amount capitalized /Proposed tobe Justification.

capitalized

·NA

(Figures In Rs Crore)

Regulations under which

Admitted

covered Costl

Petitioner

Page 266

Name of Distribution Licensee Licensed Area of Supply

Form: F-6.8

Uttarakhand Power Corporation Limited Uttarakhand

Financing of Additional Capitalisation

(Figures in Rs Crore' Financial Year (Starting from Actual Actual Projected Projected

COD\ FY 2017-18 FY 2018-19 FY 2019-20 FY 2020-21

1 2 3

Amount capitalised in Work/Enuinment

Financina Details

Total Loan 256.06 237 .10 302.12 455.00

Grants/Consumer Contribution 128.03 570.07 505.46 327.21 Eouitv 13.46 130.56 129.48 195.00

Total 397.55 937.73 937.06 97 ,.22

Page 267

Name of Distribution Licensee Licensed Area of Supply

Form: F-6.9

Incidental Expenditure during Construction

S.No. Parameters A Exoenses: 1 Emolovees' Remuneration & Benefits 2 Finance Costs 3 Water Charqes 4 Communication Exoenses 5 Power Charaes 6 Other Office and Administrative Exoenses 7 Others (Please Soecitv Details) 8 Other ore-Ooeratinq Exoenses

B Total Exnenses Less: Income from sale of tenders Less: Income from auest house Less: Income recovered from Contractors Less: Interest on Deoosits ....

Uttarakhand Power Corporation Limited Uttarakhand

(Fiaures in Rs Crore) Year-1 Year-2 Year 3 Year-4 Year-5

NA

Note:IEDC should be duly reconciled with the corresponding figures of Auditor's Certificate.

Petitioner

(} LI .~

·/

Page 268

Name of Distribution Licensee Licensed Area of Supply

Form: F-6.10

Statement of De-capitalisation

Year of Work/Equipme S.No De- nt

capitalisa proposed to be tion De-capitalised

(1) (2) (3)

1

2

Uttarakhand Power Corporation Limited Uttarakhand

Original Year of Book Debt Equity

capitalisation of Value of ratio at the asset/ equipment the asset time of

being being capitalisati decapitalised decapitalis on

ed

(4) (5) (6)

Cumulative Cumulative Depreciatio Repayment of

n Loan correspondi correspond in

ng to g to decapitalisa decapitalisati

tion on

(7) (8)

3 Information is not available. The Petitioner requests waiver for the same 4 5

I I

'Fioures in Rs Crore)

Justification

(9)

/', \_

f'J-:/ Petitiorier

Page 269

Name of Distribution Licen: Uttarakhand Power Corporation Limited Licensed Area of Supply Uttarakhand

Form: F- 7 .1

Details of Financial Packages (Fiqures in Rs Crore)

Amount in Interest Rate Upfront

0/o of 010 of Exchange Terms of Grace Guarantee Fees/ 0/o of

Amount in FC Rate

Indian Repayment Period

/ Return on Commission Exposure

Total Total Total PC

Source of Funds Currency Equity Premium

Debt Equity

(Name of Currency) (Rs./FC) (Rs. in Crore) (Years) (Years) (%) (Rs. in Crore) (Rs. in Crore) (%) (%) (%)

(A) Debt

Foreian:

Loan I

Loan II

Loan III Loan IV etc

Indian:

Loan I

Loan II etc. NA

Total Loan (Al

rs·) Eauitv

Foreion:

Indian:

Total Eouitvi'B1

C) Grants

Foreion:

Indian:

Total Grant (C")

Total Financino (A+B+C)

Total Pro1ect Cost

Petitioner

~

Ii ;:::J. ./

Page 270

Name of Distribution Licensee licensed Area of Supply

Form: F- 7.2

Uttarakhand Power Corporation limited Uttarakhand

Draw Down Schedule for Calculation of IDC & Financing Charges

SI. No. Draw Down Quarter 1

Quantum Exchange Rate Amount in

Particulars in Foreign on Draw Down Indian Currency Date Rupee

1 Loans 1.1 Foreinn Loans

1.1.1 Foreinn Loan 1 Draw Down Amount !DC Financina Charaes FERV Hedninn Cost

1.1.2 Foreinn Loan 1 Draw Down Amount !DC Financinq Charnes FERV Hedqinn Cost

1.1.n Foreinn Loan n Draw Down Amount !DC Financina Charaes FERV Hedninn Cost

1.1 Total Foreian Loans Draw Down Amount !DC Financinn Charnes FERV Hedoinn Cost

1.2 Indian Loans

1.2.1 Indian Loan 1

fFioures in Rs Crore)

Quarter 2 Quarter n (COD)

Quantum in Exchange Rate Amount in Quantum in Exchange Rate

Foreign on Draw Down Indian Foreign on Draw Down

Currency Date Rupee Currency Date

NA

Page 271

SI. No. Draw Down Quarter 1 Quarter 2 Quarter n (COD)

Quantum Exchange Rate Amount in Quantum in Exchange Rate Amount in Quantum in Exchange Rate Particulars in Foreign on Draw Down Indian Foreign on Draw Down Indian Foreign on Draw Down

Currency Date Rupee Currency Date Rupee Currency Date

Draw Down Amount !DC Financina Charaes

1.2.2 Indian Loan 2 Draw Down Amount !DC Financinq Charaes

1.2.n Indian Loan n Draw Down Amount !DC Financino Charoes

1.2 Total Indian Loans NA Draw Down Amount IDC Financinn Charoes

1 Total of Loans Drawn !DC Financino Charoes FERV Hedqinq Cost

2 Enuitv

2.1 Foreion Eauitv Drawn

2.2 Indian Eauitv Drawn

2 Total Eauitv Deoloved

Note: 1. Drawl of Debt and Equity shall be on pari passu basis quarter wise to meet the Commissioning schedule. Drawl of higher Equity in beginning is 2. Applicable Interest Rates including reset dates used for computation may be furnished separately. 3. In case of Multi Unit Project, details of Capitalisation ratio used to be furnished

Petitioner

Page 272

Name of Distribution Licensee Form: F- 7.3 Statement of Outstanding Loans

FY 2018-19

Loan Agency (Source of loan)

(1) State Govn. Loans

GPF Loan

District Plan

APDRP

MNP

PMGY Sub-Total (A)

Other than State Govn. Loans

R-APDRP PART- A ( PFC)

R-APDRP (SCADAJ (PFC)

R-APDRP- PART- B (PFCl Grant R-APDRP- PART-8 (PFC] Loan

AERP ( REC)

RGGVY ( REC I

OLD REC LOAN ( REC )

NEW REC LOANS ( REC I !DPS Loans

DDUGVY (Loan)

Sub- Total (Bl

Normative Loans

TOTAL (A+B+C)

Uttarakhand Power Corporation Umited

Rate of Balance at the interest

Repayment beginning of

(O/o) period (Years) the year

Actual/ Actual/ Auditted Actual/ Auditted

Auditted

(2) (3) (4)

127.10

10.00 Uoto 2023-24 0.81

10.00 Uoto 2023-24 10.23

10.00 Unto 2023-24 21.14

10.00 Uoto 2023-24 1.09 160.37

0.00

93.85

8.25

273.15 11.25 32.18

3.00 Uoto 2017-18 0.00

11.00 Uoto 2021-22 29.13

9.75 Unto Dec 2022 129.01 10 equal Install. After three year

10.25 from the receipt

709.48 - C

7.50 Uoto 2019-20 0.00 10 equal Install. After three year from the receipt

10.25 of Fund

0.00

1275.04

0.00

0.00

0.00

1435.42

(Figures in Rs Crores)

Amount Principal

Principal Principal received

due during redeemed Overdue Principal Due at

during the the year

during the at the year the year end year year end

Actual/ Auditted Actual/ Actual/ Actual/

Actual/ Auditted Auditted Auditted Auditted

(5) (6) (7) (8)=(6)-(7) (9) = ( 4 )+(5)-(6)

0.00 0.00 0.00 0.00 127.10 0.00 0.00 0.00 0.00 0.81

0.00 1.74 1.74 0.00 8.49 0.00 4.23 4.23 0.00 16.92

0.00 0.27 0.?7 0.00 0.82 o.oo 6.24 6.24 0.00 154.14

0.00 0.00 0.00 0.00 0.00 10.73 0.00 0.00 0.00 104.58

6.03 0.00 0.00 0.00 14.28 59.45 0.00 0.00 0.00 332.60

1.72 2.70 2.70 0.00 31.20

0.00 0.00 0.00 0.00 0.00 0.00 7.96 7.96 0.00 ? 1.17

0.00 22.48 22.48 0.00 106.53

64.10 52.64 5L64 0.00 720.93 19.07 6.07 6.07 0.00 13.00

29.04 0.00 0.00 0.00 29.04

190.14 91.85 91.85 0.00 1373.32

0.00 0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00

190.14 98.09 98.09 0.00 1527.46

n (V""' / ~age 273

Name of Distribution Licensee Form: F- 7.3 Statement of Outstanding Loans

FY 2019-20

Loan Agency (Source of loan)

(1)

State Govn. Loans

GPF Loan

District Plan

APDRP

MNP

PMGY

Sub-Total r A)

Other than State Govn. Loans

R-APDRP PART- A ( PFC) R-APDRP (SCADA) (PFC)

R-APDRP- PART- B (PFC) Grant

R-APDRP- PART-B (PFC\ Loan

AERP ( REC l

RGGVY ( REC l

OLD REC LOAN r REC l

NEW REC LOANS ( REC) IPDS (Loan)

DDUGVY (Loan) Sub- Total (6)

Normative Loans

TOTAL f A+B+C)

Uttarakhand Power Corporation Limited

Rate of Balance at the interest

Repayment beginning of

(D/o) period (Years)

the year

Estimated Estimated Estimated (2) (3) (4)

127 .10

10.00 Unto 2023-24 0.81

10.00 Uoto 2023-24 8.49

10.00 Upto 2023-24 16.92

10.00 Unto 2023-24 0.82

154.14

0.00

0.00

104.58

14.28

332.60

11.25 31.20

3.00 Uoto 2017-18 0.00

11.00 Upto 2021-22 21.17

9.75 Uoto Dec 2022 106.53 1 w equai instar1. After three year from the receipt

10.25 of fund 720.93 7.50 Unto 2019-20 13.00

' il'~c<.lll.

After three year from the receipt

10.25 of Fund 29.04 1373.32

0.00 o.oo 0.00

1527.46

Amount Principal

Principal Principal received

due during redeemed Overdue Principal Due at

during the the year

during the at the year the year end year year end

Estimated Estimated Estimated Estimated Estimated (SI (6) rn /8)=(6H7l (9)=(41+15H61

0.00 0.00 0.00 0.00 127.10 0.00 0.00 0.00 0.00 0.81

0.00 1. 74 1.74 0.00 6.75 0.00 4.23 4.23 0.00 12.69 0.00 0.27 0.27 0.00 0.55 0.00 6.24 6.24 o.oo 147.90

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00 104.58

0.00 0.00 0.00 0.00 14.28

o.oo 0.00 0.00 0.00 332.60

0.00 2.77 2.77 0.00 28.43

0.00 0.00 0.00 0.00 0.00

0.00 7.96 7.96 0.00 13.20

0.00 24.66 24.66 0.00 81.87

63.06 43.92 43.92 0.00 740.07 0.00 13.00 13.00 0.00 0.00

30.38 0.00 0.00 0.00 59.42 93.44 92.31 92.31 o.oo 1374.45

0.00 0.00 0.00 0.00 0.00 0.00 o.oo 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00

93.44 98.55 98.55 o.oo 1522.35

Page 274

Name of Distribution Licensee Form: F- 7.3 Statement of Outstanding Loans

FY 2020-21

Loan Agency (Source of loan)

(1 \ State Govn. Loans

GPF Loan

District Plan

APDRP

MNP

PMGY Sub-Total /Al

Other than State Govn. Loans

R·APDRP PART- Ai PFC)

R-APDRP ISCADA \ IPFC\

R-APDRP· PART· B (PFC) Grant

R-APDRP- PART-B IPFC\ Loan

AERP I REC l

RGGVY ( REC l

OLD REC LOAN I REC \

NEW REC LOANS r REC \ IPDS (Loan1

DDUGVY (Loan) Sub- Total ( B)

Normative Loans

TOTAL (A+B+C)

Uttarakhand Power Corporation Limited

Rate of Balance at the interest

Repayment beginning of

(%) period (Years)

the year

Estimated Estimated Estimated (2\ (3 \ (4\

127.10

10.00 Unto 2023-24 0.81

10.00 Unto 2023-24 6.75

10.00 Unto 2023-24 12.69

10.00 Unto 2023-24 0.55

0.00 147.90

0.00 0.00

0.00 0.00

0.00 104.58

0.00 14.28

0.00 332.60

11.25 28.43

3.00 Unto 2017-18 0.00

11.00 Unto 2021-22 13.20

9.75 Unto Dec 2022 81.87 J.u equal install. After three year from the receipt

10.25 of Fund 740.07 7.50 Unto 2019-20 0.00

1 w equal 1nsta11. After three year from the receipt

10.25 of Fund 59.42 0.00 1374.45

0.00 0.00 0.00

00/o 0.00 1522,35

Amount to be Principal

Principal to received

due during be redeemed

during the the year

during the year year

Estimated Estimated Estimated I 51 (6\ (]\

0.00 0.00 0.00

0.00 0.00 0.00

0.00 1.74 1.74

0.00 4.23 4.23

0.00 0.?7 0.27 0.00 6.24 6.24

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 0.00 0.00

0.00 0.00 0.00

0.00 2.70 2.70

0.00 0.00 0.00

0.00 7.96 7.96

0.00 27.26 27.26

0.00 57.62 57.62 0.00 0.00 0.00

23.58 0.00 0.00 23.58 95.55 95.55

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

23.58 101.78 101.78

Principal Overdue

at the year end

Estimated 8l-:J6l-f7\

0.00 0.00 0.00

0.00 0.00 0.00

0.00 0.00 0.00 0.00 0.00 0.00

0.00

0.00 0.00

0.00 0.00

0.00 0.00 0.00 0.00 0.00 0.00

Principal Due at the year end

Estimated rgb(4\+151 .. r5\

127.10 0.81

5.01 8.46 0.28

141.66

0.00 0.00

104.58

14.28

332.60

25.73 0.00

5.24 54.61

682.45 0.00

83.00 1302.49

0.00 0.00 0.00

1444.14

r-'\(._

"LP';_.,, Page 275

Name of Distribution Licensee Licensed Area of Supply

Form: F- 7.4

Uttarakhand Power Corporation Limited Uttarakhand

Calculation of Weighted Average Interest Rate of Interest on Actual Loans *

S.No. Particulars 2018-19

(1) (2) (3)

Total Loan 1 Gross Loan - Ooenino 1307.51

Cummu!ative payments of Loan upto Previous 2 Year 3 Net Loan - Ooenina 4 Add: Drawl(sl durina the vear -

5 Less: Repayment(s) of Loan during the year

6 Net Loan - Closina 1 399.55 7 Averaae Net Loan 1353.53 8 Rate of Interest on Loan on Annual Basis 9 Interest on Loan 144.02

Weighted Average Rate or Interest on 10 Loans 11%

Page 276

Name of Distribution Licensee Licensed Area of Supply Form: F- 7.5

Uttarakhand Power Corporation Limited Uttarakhand

Calculation of Interest on Normative Loan

(Fiaures in Rs Crore) Particulars FY 2019-20 FY 2020-21

Onenino Loan 868.17 997.16

Addition 302.12 455.00

Reoavment 173.12 201.30

Closino 997.16 1 250.86

Weiahted averaae rate of interest 11.00% 11.00%

Interest on Canital Loans 102.59 123.64

Page 277

Name of Distribution Licensee Licensed Area of Supply

Uttarakhand Power Corporation Limited Uttarakhand

Form: F-8

Details of Interest on Working Capital

FY 2018-19

S. No. Item Actual/ Audited

1 O&M exoenses renuivalent to 1 monthl 43.17

2 Maintenance Spare (15% of operation and

77.70 maintenance exoenses\

3 Receivables (Two months of cosumers bills) 1,056.22

4 Capita! required to finance shorfall in collection of

63.37 current dues

Less:

5 Adjustments held as security deposit 801.25

6 One month equivalent of cost of power purchased 500.93

7 Working Capital Requirement (61.71)

8 Interest Rate ( State Bank Advance Rate /SBAR)) 13.70%

9 Interest on Workina Caoital -

( Fiaures in Crores

FY 2019-20 FY 2020-21

Total Projected

(Estimated)

49.28 52.98

88.71 111.54

1,088.96 1,337.96

62.07 72.25

871. 54 934.33

501.81 531.63

(84.32) 117.76

13.70% 13.70%

- 16.13

Page 278

Name of Distribution Licensee Licensed Area of Supply

Form: F-9

Provision for Bad Debts

S.No.

Uttarakhand Power Corporation Limited Uttarakhand

Item

FY 2017-18

(Actuals/ Audited)

1 Opening Balance of Receivables

2 Total Provision Available at the beginning of the year

3 Total% of Provisioning Available (2 /1 x 100)

4 Revenue Billed

5 Provision for Bad Debts (1% of 4) -

(Fiou1·es in Rs Crnrel

FY 2017-18 FY 2019-20 FY 2020-

FY 2021-22 21

(Actuals/ Au Projected Projected Projected dited)

r

0 0 0 I i i I 0 ~

Petitioner

Page 279

Name of Distribution Licensee licensed Area of Supply Form 9.A

Uttarakhand Power Corporation limited Uttarakhand

Scheme wise detail of capital expenditure

'. < . Start Date . ·•

5r:·-Project-Details Scheme lnvestm~

0rii.p..pl)r0Val Date SChedu!e Actual

No I

·' Date Date

• . . . . R-APDRP Caoitalization

l 1 Mussoorie 2 2 Baznur 3 3 Landhora 4 4 Mano!ore 5 5 Kiccha 6 6 Sitraoan1

7 Tl Pithoraoarh 8 8) Pauri Garhwal

9 9) Srinaaar Garhwal 10 10 Ranikhet 11 11 Kotdwar 12 12 Tehri Garhwal 13 13 Gooeshwar

14 Joshimath " 14 "' ~

t: 0 15 15) Almora

N • "' 0. ~

16 a: 16 Tanakour "' " ~

17 17 Khatima 0 18 18 Ramnaoar 0.

" 19 19 Vikasnanar " 20 20 Uttarkashi 21 21 Gadarpur 22 22 Ha!dwani

23 23 Rishfkesh 24 24 Laksar 25 25 Kashiour 26 26 Jasour 27 27 Roorkee 28 28 Rudraour 29 21 Haridwar 30 30 Nainital

31 Dehradun Part-'B' of 02.02.2015 R-APORP

{Figures in Rs Crore)

Com_p\etion _Date· PV paid. Upto da_te of Apprcived Cost u"pto .C8pifa!ization

Date of Schedule.'

as per . previous 1

• Claimed for . Capitalizati

1• Actual Date Investment Year{n-1)(as the current • Date

Approval [er Audited on

. year ' - - - .

- 17.57 18.10.2017 7.67

11.08.2014 27.12.2017 4.3 26.12.2017 14.03 22.09.2017 4.88 28.07.2017 4.24

03.10.2014 10.12.2015 8.73 01.06.2015 3.78

04.10.2014 21.09.2015 7.75 25.10.2015 3.59

30.09.2014 11.10.2017 7.47 4.86

18.10.2014 24.09.2017 2.22 07.02.2016 2.78 "' ~

0 17.10.2014 13.04.2016 N

9.73 "' u °' 29.04.2015 05.03.2016 ~

2.42 ~ ~

~ z 0 "' 11.08.2014 08.17.2017 10 "' 31.12.2016 11.65

30.09.2014 - 3.93

07.12.2017 6.46

11.08.2014 30.12.2017 3.83 30.09.2017 26.31

22.09.2014 24.03.2018 14.35

31.12.2017 6.09 28.12.2017 49.37 04.08.2017 11.24

11.08.2014 31.12.2017 33.2 28.11.2017 21.58 31.12.2017 86.72 30.12.2017 6.88

Ext. upto 31.03.2018 -

191.46 0

Page 280

Name of Distribution Licensee Uttarakhand Power Corporation Limited Licensed Area of Supply Uttarakhand Form 9.A Scheme wise detail of capital expenditure

s. Works/Projects

Date of Date of completion as Estimated

N. Investm oer Investment Cost Works covered under Part-'B' of R-APDRP:-1' Mussoorie 17.57 2) Baznur 7.67 3' Landhora 4.30 4\ Mannlore 14.03 5' Kiccha 4.88 6) Sitranani 4.24 Tl Pithora,.,arh 8.73 81 Pauri Garhwal 3.78

9) Srinagar Garhwal 2.75

1m Ranikhet 3.59 111 Kotdwar 7.47 12 Tehri Garhwal 4.86 13 Goneshwar 2.22 14 Joshimath 19.12.20 2.78 15 Almora 14

9.73 16 Tanakour 2.42 17 Khatfma 10.00

1 18 Ramnaaar 31.12.2017 11.65

19 Vikasnanar 3.93 20 Uttarkashi 6.46 21 Gadar"ur 3.83

22 Haldwani 26.31

23 Rlshikesh 14.35 24 Laksar 6.09 25 Kashi"ur 49.37

26 Jasnur 11.24

27 Roorkee 33.20

28 Rudranur 21.58 21 Ha rid war 86.72 30 Nainital 6.88

Dehradun Profect covering the works covered 02.02.20 191.46 under 15 Part-'B' of R-APDRP

Date of Completion Expected Physical as ... er a"'reement date of Pronress

100% 18.10.2017 100%

11.08.2014 27.12.2017 100% 26.12.2017 100% 22.09.2017 100% 28.07.2017 100%

03.10.2014 10.12.2015 100% 01.06.2015 100%

04.10.2014 21.09.2015 100%

25.10.2015 100% 30.09.2014 11.10.2017 100%

100%

18.10.2014 24.09.2017 100% 07.02.2016 100%

17.10.2014 13.04.2016 100% 29.04.2015 05.03.2016 100%

11.08.2014 08.12.2017 100% 31.12.2016 100%

100% 30.09.2014 07.12.2017 100%

11.08.2014 30.12.2017 100% 30.09.2017 100%

22.09.2014 24.03.2018 100% 31.12.2017 100% 28.12.2017 100% 04.08.2017 100%

11.08.2014 31.12.2017 100% 28.11.2017 100% 31.12.2017 100% 30.12.2017 100%

11.08.2015 100%

(figures in Rs Crore)

Financial Pronress

9.84 2.84 2.46 3.16 ?.67 3.52 5.60 4.56

2.33

3.98 6.37 4.44 2.84 2.79 10.40 2.36 5.71 7.37 3.83 5.87 2.81 17.48 9.93 2.85

14.55 7.80 9.26

13.27 29.59 6.89

134.48

Remarks

Completed

/1 ( /

1\J' . / /

Page 281

Name of Distribution Licensee Licensed Area of Supply Form 9.A

Uttarakhand Power Corporation Limited Uttarakl1and

Scheme wise detail of capital expenditure

Pronress Renart of Inv0 stment A roval Accorded to UPCL rp .. onress for the F.Y 2018- 2019\ s.

Works/Projects Date at Date pt,completion-as Estimated Date of'Completion Expected

N-.- Investm - oer Investment Cost as aer aoreement date of For Intreaated Pnwer Deve/onment Svstem Proiect MoP GoI :-

1) Mahua Kheraganj 9.30 05.01.2019

2 l Sultanour Patti 3.51 05.01.2019 31 Kela Khera 4.39 05.01.2019 4) Mahua Oabra

3.93 05.01.2019 Harfnur 5 Dwarahat 4.09 14.01. ?019 6 Jhabrera 7.17 17.11.2018 7 Lansdowne 3.18 19.12.2018 8 Doaadda 1.73 19.12.?018 9 Doiwala 4.74 28.02.2019 10 Rudraoravaa 7.64 ?6.03.2019 11 Nandnravan 2.09 28.10.2018 25.02.2018 12 Gau char 4.50 31.03.2019 13 Muni Ki Reti 10.88 26.03.2019

14) Narendranagar 5.14 12.11.2018

15) Veerbhadra 9.88 26.03.2019

IDPL

1 16 Badrinath,.,uri 05.10.20 5.00 31.03.2019 17 Karnnravaa 16

30.09.2019 4.27 28.02. ?019 18 Devanravari 6.45 01.03.2019 19 Chamba 5.56 26.03.2019 20 Kaladhunoi 4.55 31.01.2019 21 Lalkuwan 3.21 21.12.2018 22 Bhimtal 8.35 18.03.2019 23 Dineshour 8.05 19.01.2019 24) Herbertnur 5.37 31.03.2019 25 Kirtinaoar 3.17 26.03.2019 26 Gannotri 1.80 01.01.2019 27 Bhawati 7.24 28.10.2018 18.03.2019 28 Shakti,.,arh 3.55 18.12.2018 29 Chamoawat 5.53 14.01.2019 30) Lohanhat 3.46 31.01.2019 31 l Baaeshwar 6.36 25.02.2019 32 Dldihat 2.64 05.01.2019 33 Dharchula 2.53 31.01.2019 34 Chakrata 9.57 15.12.2018 28.03.2019 35 Barkot 6.37 2.1.11.2018 27.12.2018 36 Kedarnath 4.46 31.03.2019 37) Dehradun 1.04 27.01.2018 03.01.2019

(Figures in Rs Crore)

Physical Financial PrbnresS Pronress

Remarks

2.74

1.19 2.68

2.45

3.05 1.75 2.14 1.65 4.73 3.3

1.39 2.76 5.28

5.49

3.81

2.25 100% ?.87 Completed

3.61 3.57 2.02 2.23 4.85 3.77 3.24 1.35 1.08 4.32 2.84 4.70 2.75 3.11 2.33 1.51 3.65 5.25 1.15 0.62

Page 282

Name of Distribution Licensee Licensed Area of Supply

Uttarakhand Power Corporation Limited Uttarakhand

Form 9.A Scheme wise detail of capital expenditure

Works covered under Part-'B' of R-APDRP :-1' ·Mussoorie 2) Bazour 3 Landhora 4 Manolore 5 Klecha 6 Sitraoani 7 Pithoranarh 8 Pauri Garhwal

9) Srinagar Garhwal

10 Ranikhet 11 Kotdwar 12 Tehri Garhwal 13 Gooeshwar

,1~4=J~o~s~h~im~a~t~h~--" 19 _ 12_20 15 Almora 16 Tanaknur 17 Khatlma 18 Ramnaoar 19 Vikasnanar 20 Uttarkashi 21 Gadarnur 221 Haldwani 231 Rishikesh 241 Laksar 25' Kashiour 261 Jas"ur 271 Roorkee 28) Rudra"ur 211 Haridwar 30) Ni:linital

Dehradun Project

14

covering the works 02.02.20 covered under 15 Part-'B' of R-APDRP

31.12.2017

Estimated D.ate·ot.,Co,~ru-·w~·Fioa:i.1 · .Expe~ed c0St: as·ner l:ln'r'El?hi"e'rlt · 1 date of ·

17.57 7,67 4.30 14.03 4.88 4.24 8.73 3.78

2.75

3.59 7.47 4.86 2.22 2.78 9.73 2.42

10.00 11.65 3.93 6.46 3.83 26.31 14.35 6.09

49.37 11.24 33.20 21.58 86.72 6.88

191.46

11.08.2014

03.10.2014

04.10.2014

30.09.2014

18.10.2014

17.10.2014 29.04.2015

11.08.2014

30.09.2014

11.08.2014

22.09.2014

11.08.2014

11.08.2015

18.10.2017 27.12.2017 26.12.2017 22.09.2017 28.07.2017 10.12.2015 01.06.2015

21.09.2015

25.10.2015 11.10.2017

24.09.2017 07.02.2016 13.04.2016 05.03.2016 08.12.2017 31.12.2016

07.12.2017 30.12.2017 30.09.2017 24.03.2018 31.12.2017 ?8.12.2017 04.08.2017 31.12.2017 28.11.2017 31.12.2017 30.12.2017

Physi?.¥1,1 Prci"nreSs ·.

100% 100% 100% 100% 100% 100% 100% 100%

100%

100% 100% 100% 100% 100% 1'00% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100%

100%

(Figures in Rs Crore)

·Financial Pronress

9.84 2.88 2.96 3.69 2.67 3.52 5.60 4.56

2.33

3.98 6.37 4.84 2.84 3.06 10.40 2.36 5.71 7 .37 3.83 6.38 2.81 17.48 9.93 3.18

14.55 7.80

10.77 13.27 30,31 6.89

138.38

Remarks

Completed

Page 283

Name of Distribution Licensee Licensed Area of Supply Form 9.A

Uttarakhand Power Corporation Limited Uttarakhand

Scheme wise detail of capital expenditure

Pror ress Renart of Investment A--roval Accorded to UPCL fPronress for the F.Y 2019- 2020\ s . . ··, .· -.-... . ,·-:-·.Ftate:-of Date·of,cOmpl_eti_o_n_cas ·t:Esti_mat_ed · Date ofl. ·I. ··Expected N. Works/ProJects· 'i t . : oer. Investment.. Cost, Comole. date of , . ._.. nvesm.

For Intre~ted Power Develonment Svstem Pro•ect MoP GoI :-

1) Mahua Kheraganj 9.30 05.01.2019

2' Sultan"ur Patti 3.51 05.01.2019

31 Kela Khera 4.39 05.01.2019 4) Mahua Oabra 3.93 05.01.2019 Hari"ur s Dwarahat 4.09 14.01.2019

6 Jhabrera 7 .17 17.11.2018

7 Lansdowne 3.18 19.12.2018

8 Do'"'adda 1.73 19.12.2018

9) Doiwala 4.74 28.02. 7019

10' Rudranra"ao 7.64 26.03.2019 10 Nand;.::rcl"ao 2.09 28.10.2018 25.02.2018 12\ Gauchar 4.50 31.03.7019

13) Muni Ki Reti 10.88 26.03.2019

14) Narendranagar 5.14 12.11.2018

15) Veerbhadra 9.88 26.03.2019 IOPL

1 16 Badrinathnuri 05.10.20 5.00 31.03.2019

17 Karn"ra"a 16 30.09.2019 4.27 28.02.2019

18 Devanravao 6.45 01.03.2019

19 Chamba 5.56 26.03.2019

20 Kaladhunni 4.55 31.01.2019

21 Lalkuwan 3.21 21.12.2018

22) Bhimtal 8.35 18.03.2019

23 Dinesh"'ur 8.05 19.01.2019

24 Herbertnur 5.37 31.03.2019

25 Kirtina'"'ar 3.17 26.03.2019

26 Gannotri 1.80 01.01.2019

27 Bhawali 7.24 28.10.2018 18.03.?019

28 Shaktinarh 3.55 18.12.2018

29 Cham-,:;awat 5.53 14.01.2019

30 Lohanhat 3.46 31.01.2019

31 Ba,:;eshwar 6.36 25.02.2019

32 Didihat 2.64 05.01.2019

33 Dharchula 2.53 31.01.2019

34 Chakrata 9.57 15.12.2018 28.03.2019

35 Barkot 6.37 21.11.2018 27.12.2018

36 Kedarnath 4.46 31.03.2019

37~- Dehradun 1.04 77.01.2018 03.01.2019

(Figures in Rs Crore)

Physical Financial \:· Remarks

Pr(r't"ess Pronf'eSS

2.74

1.97 3.59

2.55

3.92 3.43 3.38 1.65 4.73 6.15 1.79 3.87 6.58

5.53

4.30

2.44 100% 3.64 Completed

6.30 3.57 3.23 2.46 5.77 6.22 4.39 1.99 1.61 6.32 2.95 4.70 2.75 3.11 2.56 2.39 3.81 6.32 1.15 0.62

Page 284

I

Name of Distribution Licensee Licensed Area of Supply Form 9.A

Uttarakhand Power Corporation Limited Uttarakhand

Scheme wise detail of capital expenditure

RAPORP Part B -· ..

.; .~ .,,.,· - . (;lectrical

S.No • ca:p;_tal expendituce Inspector.ii

.. ··,.cc•,, / te .· . . · ... ,

c~rtificate· 1 Haridwar ? Laksar 3 Roorkee 4 Mannlore 5 Landhora 6 Rudranur 7 Gadarour 8 Kiccha 9 Khatima

10 Sitarnani 11 Kashiour 12 Jasnur 13 Bazour 14 Haldwani 15 Ramnanar 16 Na in ital 17 Pauri 18 Ranikhet 19 Rlshikesh 20 Kotdwar 21 Vikasnanar 22 Joshimath 23 Tanaknur 24 Almora 25 Uttarkashi 26 Srinanar 27 Pithoraoarh 28 Gooeshwar 29 Tehri 30 Mussoorie 31 Dehradun

(Figures in Rs Crore)

details 1 ·

of Pi'ice Fina'nciill Vl::lriatio .. \Pr.'o'gre.ss

n ...

4449862 30.31 406897 3.19 1694582 10.77 233620 3.68 476325 2.96 2732826 13.01 455908 2.76 409630 2.64 970922 5.63 526812 3.47

2622284 14.29 1144247 7.68 444468 2.86 2940874 17.08 1597655 7.21 736774 6.63 97773 4.57

211666 3.98 0 9.93 0 5.84 0 4.26

800940 3.06 467424 2.34 2813577 10.40 1032752 6.38 411832 2.43 240188 5.59 869012 2.93 614953 4.74

0 0

Page 285

(Figures in Rs Crore)

Name of Distribution Licens( Uttarakhand Power Corporation Ltd. Licensed Area of Supply Uttarakhand Form-9.A Scheme wise detail of Caoital Expenditure

,:,sr. .

,- Inv_eSt:in~iit: A,ippr'_Oval .. Start Date ··.· _Com"letion Date Approved .Cost Capital"lzati. Cap1talizatio Date of p.v_..naid uoto date

:-. Pl'.o_]ect.oeta·/(s :sCh'eme S;Chf?:dUle ··ACtual Schedule . on upto ry_ d_aimed . _cap_itali:Za

',NO ·- _Date. - :Acfoal Date as per - Supply . Date · o·ate - · oa1e Investment nrevioUs for the tion

Erection

1 1) Mahua Kheraganj 05.01.2019 9.3

2 ii"" Sultanour Patti 05.01.2019 3.51

3 3\ Kela Khera 05.01.2019 4.39

4) Mahua Dabra 4 Harinur 05.01.2019 3.93

5 5 Dwarahat 14.01.2019 4.09

6 6 Jhabrera 17.11.2018 7.17

7 7 Lansdowne 19.12.2018 3.18

8 8 Dooadda 19.12.2018 1.73

9 9 Doiwala 28.02.2019 4.74

10 10 Rudranravaq 26.03.2019 7.64

11 11 Nandnravan 25.02.2018 2.09

12 12 Gauchar 31.03.2019 4.5

13 13 Muni Ki Reti 26.03.2019 10.88

14 14) Narendranagar 12.11.2018 5.14

15) Veerbhadra "' 15 IDPL "' 26.03.2019 9.88 ~ ~

16 16\ Badrinathnuri Ol 0 0 31.03.2019 5 N N ~ ~ ~

17 17) Karnoravao 0 0 0 28.02.2019 4.27 H z z "

2 18 18 Devanravan H ~ ~ 01.03.7019 6.45

19 19 Chamba '" 00 26.03.2019 5.56 0 N

20 20 KaladhunC1i 31.01.2019 4.55

21 21 Lalkuwan 21.12.2018 3.21

22 22 Bhirntal 18.03.2019 8.35

23 23 Dineshour 19.01.2019 8.05

24 24 Herbertnur 31.03.2019 5.37

25 25 Kirtinaoar 26.03.2019 3.17

26 26 Gannotri 01.01.2019 1.8

27 27 Bhawali 18.03.2019 7.24

28 28 Shaktioarh 18.12.2018 3.55

29 29 Charnoawat 14.01.2019 5.53

30 30 Lol1anhat 31.01.2019 3.46

31 31 Baoeshwar 25.02.2019 6.36

32 32 Didihat 05.01.2019 2.64

33 33 Dharchula 31.01.2019 2.53

34 34 Chakrata 28.03.2019 9.57

35 35 Barkot 27.12.7018 6.37

36 36 Kedarnath 31.03.2019 4.46

37 37 Dehradun 03.01.2019 1.04

Page 286

(Figures in Rs Crore)

Name of Distribution License Uttarakhand Power Corporation Ltd. Licensed Area of Supply Uttarakhand Form-9.A Scheme wise detail of Capital E xoenditure

~r. . ...... ····. ·'·,, -~ {~it~~~ ·/"·.,:ic.·/;·\ ,.:', ·:_,._,,-,, ·"·.,::I•.,' ':.'Star.f;_Date...- : : Comnletion·.,oate Approve_d,C_ost Cap,_~i:ll_1~at1 Ci3p.italizat10 Date of PV: ;:;.aid u.:..-to date >;Inve.~~!'.f?!Jlt_,!\P.Pr'Oval ··\SChE!dUte >- ·. Act.lJ.81_:: •>SChE!:dUJe· ;, as:pe.r oniuPtO n·,clairried Capitaliza

:~o ·:-.: . .',</-:•+: .\, °;' '.,- ' , ' [)ate , .' ,;-_-', b'8fe',;' ::I . ·Oat~:.'·' f'tf8tia (4.c.tUaJ oate InVE.'stm'erit ,,:rev'iOus, tor'the tion Supply Erection

1 1) Mahua Kheraganj 05.01.2019 9.3

2 2\ Sultan"ur Patti 05.01.2019 3.51 3 31 Kela Khera 05.01.2019 4.39

4) Mahua Dabra 4 Harinur 05.01.2019 3.93 5 5 Dwarahat 14.01.2019 4.09 6 6 Jhabrera 17.11.?018 7.17 7 7 Lansdowne 19.12.2018 3.18 8 8 Do,.,adda 19.12.2018 1. 73 9 9) Doiwala 28.02.2019 4.74

10 101 Rudraoravan 26.03.2019 7.64 11 11) Nandoravaa 25.02.2018 2.09 12 12\ Gauchar 31.03.2019 4.5 13 131 Muni Ki Reti 26.03.2019 10.88

14 14) Narendranagar 12.11.2018 5.14 15) Veerbhadra

"' "' 15 IDPL :16.03.2019 9.88 6 0

~ ~ N

16 16 Badrinathouri "' 0 0 31.03.2019 5 0 N N ~ "' N

17 17 Karnnravan C, 0 0 28.02.2019 4.27 H " a. z "' 18 18 Devaoravao H ~ ~ 01.03.2019 6.45 ,i ': 19 19 Chamba '° 00 26.03.2019 5.56 "' ~

0 N ~

"' 20 20 Kaladhun"i 31.01.2019 4.55

21 21 Lalkuwan 21.12.2018 3.21 22 22 Bhimtal 18.03.2019 8.35 23 23 Dineshnur 19.01.2019 8.05 24 24 Herbert,.,ur 31.03.2019 5.37 25 25 Kirtinaoar 26.03.2019 3.17 26 26 Gannotri__ 01.01.2019 1.8 27 27 Bhawali 18.03.2019 7.24 28 28 Shaktinarh 18.12.2018 3.55 29 29 Chamnawat 14.01.2019 5.53 30 30 Lohan hat 31.01.2019 3.46 31 31 Baoeshwar 25.02.2019 6.36 32 32 Didihat 05.01.?019 2.64

33 33 Dharchula 31.01.?019 2.53

34 34 Chakrata 28.03.2019 9.57

35 35 Barkot 27.12.?018 6.37 36 36 Kedarnath 31.03.2019 4.46 37 3Tl Dehradun 03.01.2019 1.04

Page 287

(Figures in Rs Crore)

Name oF Distribution License Uttarakhand Power Corporation Ltd. Licensed Area of Supply Uttarakhand Form-9.A Scheme wise detail of Capital Expenditure

·sr. ,, · .. ' ,, ·_· . . Start Date Comnletion Date Approveu Cost Cap1ta11zat1 Cap1ta11zat10 Date or . PV.caid ucto date ·< Proje~ Details Scheme

I.nves~ment ApproVal Schedule Actual Schedule as per on uptb n. claimed Capitaliza Nd . Date Actual Date Supply Erection

•' .·. .. Date Date Date Investment arevious for the tion

1 1) Mahua Kheraganj 05.01.2019 9.3

2 2 \ Sultannur Patti 05.01.2019 3.51 3 3 l Kela Khera 05.01.2019 4.39

4) Mahua Dabra 4 Harinur 05.01.2019 3.93 5 5 Dwarahat 14.01.2019 4.09 6 6 Jhabrera 17.11.2018 7.17 7 7 Lansdowne 19.12.2018 3.18 88 Dooadda 19.12.2018 1. 73 9 9 Doiwala 28.02.2019 4.74

10 10 Rudranravaa 26.03.2019 7.64 11 11 Nandnravaa 25.02.2018 2.09 12 12 Gauchar 31.03.2019 4.5 13 13 Muni Ki Retr 26.03.2019 10.88

14 14) Narendranagar

12.11.2018 5.14 15) Veerbhadra

"' "' 15 IDPL M M 26.03.2019 9.88 u 16 16 Badrinathnuri "' 0 0 31.03.2019 5

" N N ~

"' 17 17 Karnora11aq 0 0 28.02.2019 4.27 ~

0. z ~

18 18 Devanravaa ~ M M 01.03.2019 6.45 ~ 19 19 Chamba ~ "' 26.03.2019 5.56 ~

0 N 20 20 Kaladhunai 31.01.2019 4.55 21 21 Lalkuwan 21.12.2018 3.21 22 22 Bhimtal 18.03.2019 8.35 23 23 Dineshnur 19.01.2019 8.05 24 24 Herbertour 31.03.2019 5.37 25 25 Kirtinaaar 26.03.2019 3.17 26 26 Ganaotri 01.01.2019 1.8 27 27 Shawali 18.03.2019 7.24 28 28 Shaktioarh 18.12.2018 3.55 29 29 Chamoawat 14.01.2019 5.53 30 30 Lohanhat 31.01.2019 3.46 31 311 Baaeshwar 25.02.2019 6.36 32 32\ Didihat 05.01.?019 2.64 33 33 Dharchula 31.01.2019 2.53 34 34 Chakrata 28.03.2019 9.57 35 35 Barkot 27.12.2018 6.37 36 36 Kedarnath 31.03.2019 4.46 37 371 Dehradun 03.01.2019 1.04

Page 288

Name of Distribution Licensee Licensed Area of Supply

Uttarakhand Power Corporation Limited Uttarakhand

Form: F-10

Return on Equity

FY 2018-19

S.No. Item Actual/ Audited

1 Equity at the beginning of the year 591.51 2 Ca pita I Expenditure( capitalization) 110.30 3 Equity portion of capita! expenditure -4 Equity at the end of the year 701.81

Return Computation

5 Return on Equity on Opening Balance of Equity 106.70

FY 2019-20 FY 2020-21

Total (Estimated) Projected

701.81 831.29

129.48 195.00

831.29 1 026.29

766.55 928.79

126.48 153.25

Page 289

Name of Distribution Licensee Licensed Area of Supply

Form: F-10.1

Details of Additional RoE

Uttarakhand Uttarakhand Power Corporation Limited Uttarakhand Uttarakhand

Completion Time as per Investment approval Actual Completion time

S.No. Actual COD Start Date

Scheduled COD Months Start Date Months (Date) (Date)

1

2

3

4 NA

....

....

(Finures in Rs Crorel

Qualifying time schedule(as per

regulation) (in months)

. . Pet1t1oner

Page 290

Name of Distribution Licensee Licensed Area of Supply

Uttarakhand Power Corporation Limited Uttara kha nd

Form: F-11

Details of Non-Tariff Income

FY 2018-19

S.No. Item

Actual / Audited

A) Miscellaneous income from consumers

1 Interest on deoosits 57.41

2 Income from staff welfare activities 0.17

3 Rebate/Incentive 6.00

4 Misc receipts 7.37

5 Material Cost Variance 8.46

6 Transitorv Reserve Written Back

Interest on Institutional/Liabilities for 7 previous vears written back

8 Delaved oavment surcharae 165.00

9 Revenue from sale of surolus nower outside State

10 Wheelinq charqes recovery (L&H Power above 100 HPl

11 CSS (L&H Power above 100 HP) (includinq additional surcharqe

12 Prior Period Income

Total 244.41

(Figures ln Rs Crore

FY 2019-20 FY 2020-21

Total Projected

(Estimated)

244.41 244.41

Page 291

Name of Distribution Licensee Licensed Area of Supply

Uttarakhand Power Corporation Limited Uttarakhand

Form: F-12

Income from Wheeling Charges

FY 2018-19

Open Contracted Fixed Energy

S.No Access Capacity Charge Energy

Charge

Consumer (kW) (Rs/kW/m Wheeled

(Rs/kWh) onth)

1 2 3 4 5

1 80 490580

Total

FY 2019-20

Open Contracted Fixed Energy

Charge Energy S.No Access Capacity

(Rs/kW/m Wheeled Charge

Consumer (kW) ,..,n+h' (Rs/kWh)

1 2 3 4 5

1 2 3 4 5

Total .

FY 2020-21

(Fiqures in Rs Crore)

Any Other Charge Revenue

as approved by from Fixed

Revenue from Revenue from Total

Commission Charge

Energy Charge Other Charge Revenue

(Please specify)

6 7 8 9 10-7+8+9 9.65

9.65

Petitioner

Any Other Charge Revenue

as approved by Revenue from Revenue from Total

Commission from Fixed

Energy Charge Other Charge Revenue rp1---- s---if··'-

Charge

6 7 8 9 10-7+8+9

Page 292

Open Contracted Fixed Energy

Any Other Charge Revenue

Charge Energy as approved by Revenue from Revenue from Total S.No Access Capacity

(Rs/kW/m Wheeled Charge

Commission from Fixed

Energy Charge Other Charge Revenue Consumer (kW) nnth)

(Rs/kWh) ,...,, ____ ----jf··' Charge

1 2 3 4 5 6 7 8 9 10~7+8+9 1 2 3 4 5

Total

Page 293

Name of Distribution Licensee

Licensed Area of Supply

Form: F-13

Uttarakhand Power Corporation Limited

Uttarakhand

Revenue from Sale of Power at Existing Tariffs

1.2 Other Domestic Consumers i u to 100 Units month 1252 ii 101-200 Units month 607 iii 201-400 Units month 431 iv Above 400 Units month 394

(v 401-500 Units month vi Above 500 Units month

2. Sin le Point Bulk Su I 120 31173 46.98 RTS-1A: Snowbound 1. Domestic 2. Non-Domestic u to 1 kW 3. Non-Domestic above 1 kW & upto 4kW

4. Non-Domestic above 4 kW

RTS-2: Non-Domestic 266325 1100976 1366.63 Government, Educational Institutions and Hos itals etc. 1.1 U to 25 kW 9328 27345 22.57 1.2 Above 25 kW 1115 58470 125.84 2. Other nan-Domestic Users

2.1 Upta 4 kW and consumption 70879 96654 17.37

upto 50 units per month

2.2 Others upto 25 kW not covered 181881 628899 726.94

in 2.1 above 2.3 Above 25 kW 3084 263996 443.78 3. Single Paint Bulk Supply above

15 14603 29.85 75 kW 4. Independent Advertisement

23 220 0.27 Hoardin s 5. Revenue from MCG

18 Rs Con Month 0.00 Rs Con Month 1 179.93

2.75 Rs kWh 55 Rs Con Month 413.02 3.55 Rs kWh 85 Rs Con Month 43.23 258.78 4.90 Rs kWh 145 Rs Con Month 46.90 257.86 5.65 Rs kWh 230 Rs Con Month 27.70 222.58 250.27 0,00 Rs kWh 0 Rs Con Month 0,00 Rs kWh o Rs Con Month 4.40 Rs kWh 75 Rs Kw/Month 2.81 20.67 23.48

1.61 Rs kWh 18 Rs Con Month 1.61 Rs kWh 18 Rs Con Month

2.36 Rs/kWh 18 Rs/Con/Month

3.51 Rs/kWh 30 Rs/Con/Month

101.35 741.01 842.36

4.50 Rs kWh 65 Rs kW Month 2.13 10.16 12.29 4.25 Rs kvah 75 Rs kVA Month 5.98 56.30 62.28

0 Rs kW Month

4.70 Rs/kWh 70 Rs/kW/Month 8.12 8.16 16.28

5.60 Rs/kWh 75 Rs/kW/Month 56.60 407.09 463.69

5.45 Rs kvah 75 Rs KVA Month 27.00 241.86 268.86

5.50 Rs/kvah 75 Rs/KVA/Month 1.49 17.28 18.78

6.10 Rs/kWh 90 Rs/kW /Month 0.02 0.17 0.19

o Rs kW Month

('\

['--~

Page 294

Revenue from Sale of Power at Existing Tariffs

RTS-3: Public Lam s 0 Rs/kW/Month 1.41 27.51 28.92

1. Urban 1516 13192 38.51 5.20 Rs kvah 60 Rs KVA Month 1.08 21.08 22.16 2. Rural 435 4884 11.74 5.20 Rs kvah 50 Rs KVA Month 0.33 6.43 6.76 RTS-4: Private Tube-wells/

36477 193792 183.38 35.75 35.75 Pum in sets 1. Metered 183.32 1.95 Rs/kWh 35.75

RTS- 4A: Agriculture Allied Services 107 4356 11 2.06 2.06

1. Metered 10.55 1.95 Rs kWh 0.00 Rs BHP Month 2.06 RTS -3: Govt. Public Utilities (RTS-5: Government Irrigation 1930 69218 159.17 5.47 87.12 92.59

S stem 1.1 U to 75 kW 1867 54723 150.15 5.20 Rs kvah 60 Rs KVA Month 4.48 82.19 86.66 2.2 Above 75 kW 63 14494 9.02 5.20 Rs kval1 50 Rs KVA Month 0.99 4.94 5.92 RTS -3: Govt. Public Utilities

1946 103014 434.94 0 Rs/KVA/Month 7.78 238.07 245.85 RTS-6: Public Water Works

1. Urban 967 55340 229.46 5.20 Rs kWh 60 Rs kW Month 4.53 125.60 130.13

2. Rural 980 47674 205.48 5.20 Rs kWh 50 Rs kW Month 3.25 112.47 115. 72 RTS-5: LT & HT Industr 0 Rs KVA Month Total LT 11081 231372 316.62 0 Rs KVA Month 44.31 135.31 179.63

1. LT Industries uto25kW 8270 0 0.00 0 Rs KVA Month

Atta Chakkis 2540 21153 60.11 4.35 Rs kWh 145 Rs kW Month 3.68 26.15 29.83

Other than atta Chakkis 5729 39418 83.23 4.35 Rs kWh 145 Rs kW/Month 6.86 36.21 43.07 2. LT Industries (above 25kW &

2811 170802 173.28 4.00 Rs/kvah 145 Rs/KVA/Month 33.77 72.96 106.73 u to 75 kW -Normal Hours 3. Peak Hour Char es 6.00 Rs kvah 4. Off Peak Hour Char es 3.40 Rs kvah 5. Revenue from MCG Total HT 2173 1746526 6493.03 575.80 3 179.90 3 755.71 1. HT Industries (contracted load u to 1000 KVA

682480 1760.05

1.1 Load factor upto 40% -Normal Hours

131.71 3.95 Rs/kvah 300 Rs./KVA of BD 200.57 53.09 253.65

1.2 Load factor above 40%- 612.02 4.35 Rs/kval1 Normal Hours

300 Rs./l(VA of BO 271.66 271.66

2. HT Industries (above 1000 1064046 4732.98 0 Rs./KVA of SD KVA 2.1 Load factor upto 40% -Normal Hours

354.18 3.95 Rs/kvah 360 Rs./KVA of SD 375.24 142. 76 518.00

2.2 Load factor above 40%-Normal Hours

1580.86 4.35 Rs/kvah 360 Rs,/KVA of BO 701. 71 701. 71

f\ "s..L

I~ Page 295

Revenue from Sale of Power at Existing Tariffs

3,1 Pea Hour Charges(Load Factor u to 40% 3.2 Peak Hour Charges(Load Factor

1704.68 6.53 Rs/kvah above 40% 1,135.87 1,135.87

3.3 Off Peak Charges- Load Factor 282.66 3.36 Rs/kvah

u to 40% 96.91 96.91

3.4 Off Peak Charges- Load Factor 1583.09 3.70 Rs/kvah 597. 70 597. 70 above 40%

3.5 Continuous Supply Surcharge 2018.74 0.49 Rs/kvah 100.32

3.6 Revenue from MCG Voltage Rebate {Surcharge) 1.84% 0.00% 82.58

76 55704 181.30 5.35 91.56 96.91 upp y

55704 181.30 5.05 Rs/kWh 80.00 Rs/Kw/Month 5.35 91.56

2 15300 28.47 3.87 12.78 16.65 15300 28.47 4.40 Rs kvah 250 Rs KVA Month 3,87 12.78

2581381 6796436 12185 943.87 5 600.17 6 546.10

Page 296

Name of Distribution Licensee

Licensed Area of Supply

Form: F-13

Uttarakhand Power Corporation Limited

Uttarakhand

Revenue from Sale of Power at Existing Tariffs

1.2 Other Domestic Consumers i u to 100 Units/month ii 101-200 ·units/month iii 201-400 Units/month 447 iv Above 400 Units/month 106728 409 v 401-500 Units/ month 0 vi) Above 500 Units/month 0

2. Single Point Bulk Su PIY 128 32420 48.82 RTS-lA: Snowbound 1. Domesb·c 2. Non-Domestic upto 1 kW 3. Non-Domestic above 1 kW & upto 4 kW 4. Non-Domestic above 4 kW RTS-2: Non-Domestic 283869 1145015 1435.19 Government, Educational Institutions and Hosoita set . 1.1 U to 25 kW 9943 28439 23.70 1.2 Above 25 kW 1188 60809 132.16 2. Other non-Domestic Users 2.1 Upto 4 kW and consumption upto 75548 100520 18.24 50 unit er month 2.2 others upto 25 kW not covered in

193862 654055 763.41 2.1 above 2.3 Above 25 kW 3287 274556 466.04 3. Single Point Bulk Supply above 75 16 15187 31.35 kW 4. Independent Advertisement 24 229 0.29 Hoardlnos 5. Revenue from MCG RTS -3: Govt. Public Utilities (RTS-

2029 18798 51.37 3: Public Lam s 1. Urban 1576 13719 39.36 2. Rural 453 5079 12.00

18 Rs Con/Month 0.00 Rs Con Month

2.75 Rs kWl1 55 Rs Con Month 3.55 Rs kWh 85 Rs Con Month 4.90 Rs kWh 145 Rs Con Month 5.65 Rs kWh 230 Rs Con Month 231.32 0.00 Rs kWh 0 Rs Con Month 0.00 Rs kWh O Rs/Con Month 4.40 Rs kWh 75 Rs Kw Month 2.92 21.48 24.40

1.61 Rs kWh 18 Rs Con Month 1.61 Rs kWh 18 Rs Con Month

2.36 Rs/kWh 18 Rs/Con/Month

3.51 Rs kWh 30 Rs Con Month 105.40 778.19 883.59

4.50 Rs kWh 65 Rs kW Month 2.22 10.67 12.88 4.25 Rs kvah 75 Rs kVA Month 6.22 59.12 65.34

0 Rs kW Montl1

4. 70 Rs/kWh 70 Rs/kW/Month 8.44 8.57 17.02

5.60 Rs/kWh 75 Rs/kW/Month 58.86 427.51 486.37

5.45 Rs kvah 75 Rs KVA Month 28.08 253.99 282.07

5.50 Rs/kvah 75 Rs/KVA/Month 1.55 18.15 19.70

6.10 Rs/kWh 90 Rs/kW /Month 0.02 0.18 0.20

o Rs kW /Month

O Rs/kW /Month 1.47 28.11 29.58

5.20 Rs kvah 60 Rs KVA Month 1.12 21.55 22.67 5.20 Rs kvah 50 Rs KVA Month 0.35 6.57 6.91

.r·~:

~ Page 297

Revenue from Sale of Power at Existing Tariffs

Pum in sets 38422 204173 187.05 36.46 36.46

1. Metered 186.99 1.95 Rs kWh 36.46

RTS- 4A: Agriculture Allied Services 111 4530 11 2.10 2.10

1. Metered 10.76 1.95 Rs kWh 0.00 Rs BHP Month 2.10

RTS -3: Govt. Public Utilities (RTS-2024 72739 164.05 5.74 89.80 95.54

5: Government Irrigation System)

1.1 Upto 75 kW 1958 57507 154. 76 5.20 Rs kvah 60 Rs KVA/Month 4.71 84.71 89.41 2.2 Above 75 kW 66 15232 9.29 5.20 Rs/kvah SO Rs KVA Month 1.04 5.09 6.13 RTS -3: Govt. Public Utilities (RTS- 2126 6: Public Water Works

105074 460.20 0 Rs/KVA/Month 7.93 251.90 259.83

1. Urban 1056 56447 242.79 5.20 Rs kWh 60 Rs kW Month 4.62 132.89 137.51 2. Rural 1070 48627 217.41 5.20 Rs kWh 50 Rs kW Month 3.32 119.00 122.32 RTS-5: LT & HT Industr 0 Rs KVA Month Total LT 11415 241995 323.46 0 Rs KVA Month 46.35 138.24 184.58 1. LT Industries (upto 25 kW) 8519 0 0.00 0 Rs KVA Month 74.72 Atta Cha kkis 2617 22124 61.41 4.35 Rs kWh 145 Rs kW Month 3.85 26.71 30.56 other than atta Chakkis 5902 41228 85.03 4.35 Rs kWh 145 Rs kW Month 7.17 36.99 44.16 2. LT Industries (above 25kW & upto 75 2896 kW -Normal Hours

178643 177.03 4.00 Rs/kvah 145 Rs/KVA/Month 35.32 74.54 109.86

3. Peak Hour Char es 6.00 Rs kvah 4. Off Peak Hour Charqes 3.40 Rs kvah 5. Revenue from MCG Total HT 2248 1817444 6633.26 599.19 3 248.67 3 847.85 1. HT Industries ( contracted load u to 1000 KVA

710192 1798.06 540,47

1.1 Load factor upto 40% -Normal 134.56 3.95 Rs/kvah 300 Rs./KVA of BD 208. 71 54.23 262.94 Hours 1.2 Load factor above 40%- Normal Hours

625.24 4.35 Rs/kvah 300 Rs./KVA of BD 277.53 277.53

2. HT Industries (above 1000 KVA) 1107252 4835.19 0 Rs./KVA of BO

2.1 Load factor upto 40% -Normal Hours

361.83 3.95 Rs/kvah 360 Rs./KVA of BO 390.48 145.84 536.32

2.2 Load factor above 40%- Normal 1615.00 4.35 Rs/kvah Hours

360 Rs./KVA of BD 716.86 716.86

3.1 Peak Hour Charges(Load Factor 249.08 6.53 Rs/kvah 165.97 165.97 u to 40% 3.2 Peak Hour Charges(Load Factor 1741.49 above 40%

6.53 Rs/kvah 1,160.40 1,160.40

3.3 Off Peak Charges- Load Factor upto 288. 77 3.36 Rs/kvah 99.01 99.01 40%

r, .~ t~ Page 298

Revenue from Sale of Power at Existing Tariffs

3.4 Off Peak Charges- Loa Factor above 40% 3.5 Continuous Su I Surcharoe 2062.34 0.49 Rs kvah 102.49

3.6 Revenue from MCG Vo!taoe Rebate Surcharoe 1.84% 0.00% 84.28

RTS-6: Mixed Load 77 56818 184.93 5.45 93.39 98.84

Mixed Load Single Point Bulk Supply above 75 kW including MES as deemed 56818 184.93 5.05 Rs/kWh 80.00 Rs/Kw/Month 5.45 93,39

licensee RTS-7: Railway Traction 2 15606 29.04 3.94 13.04 16.98

1. Railway Traction 15606 29.04 4.40 Rs kvah 250 Rs KVA Month 3.94 13.04

Revenue oc accpunt of additional energy charge imposed as per order

303.47 303.47

dated 25 October 2019 Total 2745323 7070620 12557 986.58 6 073.70 7 062.37

Page 299

Name of Distribution Licensee

Licensed Area of Supply

Form: F-14

Uttarakhand Power Corporation Limited

Uttarakhand

Revenue from Sale of Power at Proposed Tariffs

1.2 Other Domestic Consumers (i) upto 1 00 Units/month 1301 (ii) 101~200 Units/month 631 (iii) 20"1-400 Units/month 447 (iv} Above 400 Units/month 409 vj 401-500 Units month

rvO Above 500 Uuits month 2. Single Point Bulk Su ]y 32420 48.82 RTS-1A: Snowbound 1. Domestic 2. Non-Domestic u to 1 kW

3. Non-Domestic above 1 kW & upto 4 kW

4. Non-Domestic above 4 kW

RTS-2: Non-Domestic 283869 1145015 1435.19 Government, Educational lnstitutions and Hos itals etc. 1.1 Upto 25 kW 9943 28439 23.70 1.2 Above 25 kW 1188 60809 132.16 2. Other non-Domestic Users 2.1 Upto 4 kW and consumption upto SO units

75548 100520 18.24 er month 2.2 Others upto 25 kW not covered ln 2.1

193862 654055 763.41 above 2.3 Above 25 kW 3287 274556 466.04 3. Single Point Bulk St1pply above 75 kW 16 15187 31.35

4. Independent Advertisement Hoardings 24 229 0.29

5. Revem1e from MCG RTS ·3: Govt Public Utilities (RTS-3:

2029 18798 51.37 PublicLa.m s 1. Urban 1576 13719 39.36 2. Rural 453 5079 12.00

236.47 1.441.09 3.26 Rs kWh 75 Rs Con Month 99.71 523.20 5.25 Rs kWh 135 Rs Con Month 73.03 404.31 5.25 Rs kWh 135 Rs Con Month 46.45 281.35 5.25 Rs kWh 135 Rs Con Month 17.29 232.23 0.00 Rs kWh 0 Rs Con Month 0.00 Rs kWh o Rs Con Month 4.85 Rs kWh 85 Rs Kw Month 3.31 23.68 26.98

1.61 Rs kWh 25 Rs Con Month 1.61 Rs kWh 25 Rs Con Month

2.36 Rs/kWh 25 Rs/Con/Month

3.51 Rs/kWh 40 Rs/Con/Month

127.24 887.13 1 014.37

5.00 Rs kWh 90 Rs kW Month 3.07 11.85 14.92 4.80 Rs kvah 100 Rs kVA Month 8.29 66.77 75.07

o Rs kW Month

4.85 Rs/kWh 80 Rs/kW/Month 9.65 8.85 18.50

6.45 Rs/kWh 90 Rs/kW/Month 70.64 492.40 563.04

6.15 Rs/kvah 90 Rs KVA Month 33.70 286.62 320.31 6.20 Rs kvah 90 Rs/KVA Month 1.86 20.46 22.32 6.45 Rs/kWh 90 Rs/kW/Month 0.02 0.19 0.21

O Rs kW Month

0 Rs/kW/Month 2.49 31.36 33.85

5.80 Rs kvah 100 Rs KVA Month 1.87 24.03 25.90 5.80 Rs kvah 90 Rs KVA Month 0.62 7.33 7.95

/\ \),, ,._,,.

' -- Page 300

Revenue from Sale of Power at Proposed Tariffs

RTS-4: Private Tube-wells/ Pumping sets 38422 204173 187.05 40.20 40.20 1. Metered 186.99 2.15 Rs kWh 40.20 RTS- 4·A: Agriculture Allied Services 111 4530 11 2.31 2.31 1. Metered 10.76 2.15 Rs kWh 0.00 Rs BHP Month 2.31 RTS-3: Govt. Public Utilities (RTS-5:

2024 72739 164.05 9.71 99.29 109.01 Government lrri0 ation System 1.1 Upto 75 kW 1958 57507 154.76 5. 75 Rs kvah 100 Rs KVA Month 7.84 93.67 101.51 2.2 Above 75 kW 66 15232 9.29 5. 75 Rs kvah 90 Rs KVA Month 1.87 5.63 7.49 RTS -3: Govt. Public Utilities (RTS-6: Public

2126 105074 460.20 0 Rs/KVA/Month 13.67 278.54 292.21 Waterworks 1. Urban 1056 56447 242.79 5.75 Rs kWh 100 Rs kW Month 7.70 146.95 154.65 2. Rural 1070 48627 217.41 5.75 Rs kWh 90 Rs kW Month 5.97 131.59 137.56 RTS-5: LT &HT lndusn·y Total LT 11415 241995 323.46 57.53 152.28 209.81 1. LT Industries Lupto 25 kW] 8519 0 0.00 0 Rs KVA Month 83.97 Atta Chakkis 2617 22124 61.41 4.80 Rs kWh 180 Rs kW Month 4.78 29.47 34.25 Other than atta Chakkis 5902 41228 85.03 4.80 Rs kWh 180 Rs kW Month 8.91 40.82 49.72 2. LT lndustries (above 2SkW & upto 75 kW)-

2896 178643 177 .03 4.40 Rs/kvah 180 Rs/KVA/Month 43.85 81.99 125.84 Normal Honrs 3. Peak Hour Char es 6.60 Rs kvah 4. Off Peak !-lour Charges 3.40 Rs kvah 5. Revenue from MCG

Total HT 2248 1817444 6633.26 726.17 3 522.15 4 248.32 1. HT Industries (contracted load upto

710192 1798.06 606.96 1000 KVA 1.1 load factor upto 40%-Normal Hours 134.56 4.40 Rs kvah 350 Rs. KVA of BD 243.49 60.41 303.91

1.2 load factor above40%- Normal Hours 625.24 4. 75 Rs/kvah 350 Rs./KVA of BD 303.05 303.05

2. HT Industries (above 1000 KVA) 1107252 4835.19 0 Rs. KVA of BD 2.1 load factor 11pto 40%-Normal Hours 361.83 4.40 Rs kvah 445 Rs. KVA of BD 482.67 162.46 645.13

2.2 load factor above 40%, Normal Hours 1615.00 4. 75 Rs/kvah 445 Rs.jKVA of BD 782.78 782.78

3.1 Peak Hour Charges(Load Factor upto 249.08 7.13 Rs/kvah 181.09 181.09 40% 3.2 Peak Hour Charges(Load Factor above 1741.49 7.13 Rs/kvah 1,266.14 1,266.14 40%

3.3 Off Peak Charges- Load Factoi· upto '1·0% 288. 77 3.50 Rs/kvah 103.13 103 13

3.'1- Off Peak Charges- Load Factor above 40% 1617.28 3.90 Rs/kvah 643.61 643.61

3.5 Continuous Sup l Surcharge 2062.34 0.53 Rs kvah 111.12 3.6 Revenue from MCG Vo/ta9e Rebate [Surcharge) 1.84% 0.00% 91.64

., !'1

,0), Page 301

Revenue from Sale of Power at Proposed Tariffs

Mixed Load Single Point Bulk Supply above 75 56818 184.93 5. 70 Rs/kWh 110.00 Rs/Kw/Month 105.41

kW i11cludi11u MP.Sas deemed lici?nsee RTS•7: Railwa Traction 2 15606 29.04 5.05 14.82 19.86 1. Railway Traction 15606 29.04 5.00 Rs/kvah 320 Rs KVA Month 5.05 14.82 Total 2745323 7070620 12557 1198.87 6 405.02 7 606.20

Page 302

Name of Distribution Licensee Licensed Area of Supply

Uttarakhand Power Corporation Limited Uttarakhand

Form: F-15

Collection Efficiency

FY2018-19

S. No. Particulars

(Actuals/ Audited)

HT Catena ..... HT lndustrv 100.75% Mixed Load 98.53% Rai!wav traction 98.89%

LT Catenorv Domestic 91.87% Non-Domestic 98.16%

Educational Institutions Etc Others 74.27% Public Lames 49.95% PTW / Anriculture allied services 76.69% Govt. Irrination 46.23% PWW 93.99% LT lndustrv 103.61 %

Total 97.44°/o

(Figures in Rs Crore)

FY2019-20 FY2020-21 FY2021-22

Projected Projected Projected

I

\) "'-'""

Petitioner

Page 303

Name of Distribution Licensee Licensed Area of Supply

Uttarakhand Power Corporation Limited Uttarakhand

Form: F-16

Summary of Truing Up

· FY 2018-19

S. No. Particulars Approved Actual

1 Power Purchase Expenses 4,831.69 5,023.07

1.2 Past UJVNL Arrears 147.09 1.3 PGCIL Charnes 388.08 437.10 1.4 PTCUL Charnes 209.30 311.88

2 Qneration & Maintenance Exnenses 2.1 Emolovee Exoenses 351.80 332.89

2.2 Administration & General Expenses 27.79 47.48

2.3 Renair & Maintenance Exnenses 125.98 137.66

3 Depreciation 142.42 122.60

4 Interest on Long-term Loan Capital inc!udinn consumer securitv denosit

138.47 144.02

5 Interest on Working Capital - -

6 (Surplus)/ Gap of previous years including carrying cost

(93.93) (93.93)

7 UPCL's share in gain on account of Controllable parameters

lZ.28

A Total Expenditure 6074.51 6475.03

B Return on Equity 78.24 106.70

C Revenue 6,152.75 6,581.73 1 Revenue from sale of electricitv 6 013.19 6 211.19 2 Non tariff income 155.26 244.41

D Revenue Gap/(Surplus) - (A+B-C) (15.70) 126.14

Fiaures in Rs Crore)

Deviation Reason for Deviation Controllable Uncontrollable

329.75 As per actuals

As oer actuals 49.02 As ner actuals Uncontrollable

102.58 Uncontrollable - Controllable

/18.91 Nil arowth factor Controllable

19.69 Additional cost towards

Controllable IT expenditure

11.68 As oer actuals Controllable

(19.82) As per actual Uncontrollable canitalization

5.55 As per actual Uncontrollable canitalization

- Recomputed as per Controllable

normative

-

Mechanism provided in petition

28.46 As per actual Uncontrollable caoitalization

Uncontrollable

Petitioner

Page 304

Name of Distribution Licensee Licensed Area of Supply

Form: F-17 .1

Uttarakhand Power Corporation Limited Uttarakhand

System Average Interruption Frequency Index (SAIFI)

FY 2018-19

A; = Total No. of Nt = Total Connected

sustained Ni = Connected Load Load at 11 kV in the

Month Urban/ interruptions (each of ith Feeder affected

Distribution Rural longer than 5 due to each

minutes) on ith interruption Licensee's Supply

Feeder for the month Area

Urban 10446 590013 711811 Apr-18

Rural 31546 1006671 1394489

Urban 12237 584743 699386 May-18

Rural 44392 1074073 1438123

Urban 14121 588628 715530 Jun-18

Rural 40064 1119763 1474884

Urban 14574 626682 747165 Jul-18

Rural 40953 1105583 1432360

Urban 13738 634886 783744 Aug-18

Rural 39191 1122418 1493591

Urban 12350 653342 783427 Sep-18

Rural 37253 1119241 1501538

n = No. of 11 kV SAIFI

Feeders in the n licensed area of

supply (excluding I JJ:';) X Ni} those serving predominantly i=l N,

Agriculture loads)

401 23

805 35

383 29

773 49

386 33

776 47

391 35

779 49

387 31

787 45

392 30

792 43

Page 305

Form: F-17.1 System Average Interruption Frequency Index (SAIFI)

FY 2018 19 -n = No. of 11 kV

SAIFI

Ai = Total No. of Nt = Total Connected

Feeders in the n sustained N1 = Connected Load licensed area of

Urban/ interruptions (each of ith Feeder affected Load at 11 kV in the supply ( excluding I @i X Ni} Month

Rural longer than 5 due to each Distribution those serving

minutes) on ith interruption Licensee's Supply predominantly i=1 N,

Feeder for the month Area Agriculture loads)

Urban 10415 608682 784866 393 23 Oct-18

Rural 30538 1084008 1494182 817 34

Urban 8076 594897 778948 399 16 Nov-18

Rural 26925 1037048 1467391 816 27

Urban 8541 623452 806578 400 19 Dec-18

Rural 26912 1113861 1510181 815 28

Urban 10636 660559 842410 404 24 Jan-19

Rural 31937 1121877 1520625 817 33

Urban 10649 670397 847320 407 ?--" Feb-19

Rural 32170 1105199 1511061 816 32

Urban 9179 658378 837030 409 20 Mar-19

Rural 28564 1073004 1487038 816 28 ..

Petitioner

Page 306

Name of Distribution Licensee Licensed Area of Supply

Form: F-17.2

Uttarakhand Power Corporation Limited Uttarakhand

System Average Interruption Duration Index (SAIDI)

FY 2018-19

si = Total No. of Nt = Total Connected

sustained Ni = Connected Load

Urban/ interruptions ( each of ith Feeder affected Load at 11 kV in the

Month Distribution Rural longer than 5 due to each

Licensee's Supply minutes) on ith interruption

Feeder for the month Area

Urban 284304 590013 711811 Apr-18

Rural 1087165 1006671 1394489

Urban 366116 584743 699386 May-18

Rural 1622739 1074073 1438123

Urban 390322 588628 715530 Jun-18

Rural 1319798 1119763 1474884

Urban 402922 626682 747165 Jul-18

Rural 1274312 1105583 1432360

Urban 391563 634886 783744 Aug-18

Rural 1317237 1122418 1493591

Urban 399647 653342 783427 Sep-18

Rural 1350733 1119241 1501538

Urban 353404 608682 784866 Oct-18

Rural 1111308 1084008 1494182

n = No. of 11 kV Feeders in the

licensed area of supply ( excluding

SAIDI those serving predominantly

Agriculture loads)

401 643 I 805 1120

383 883

773 1631

386 904

776 1326

391 986

779 1350

387 917

787 1303

392 965

792 1704

393 762

817 1182

Page 307

Form: F-17.2 System Average Interruption Duration Index (SAIDI)

FY 2018-19

n = No. of 11 kV Bi = Total No. of

Nt = Total Connected Feeders in the

sustained Ni = Connected Load licensed area of Urban/ interruptions ( each of ith Feeder affected Load at 11 kV in the

supply ( excluding Month Distribution SAIDI Rural longer than 5 due to each Licensee's Supply

those serving minutes) on ith interruption predominantly

Feeder for the month Area Agriculture loads)

Urban 232808 594897 Nov-18

778948 399 462

Rural 803275 1037048 1467391 816 825

Urban 223416 623452 806578 400 486 Dec-18

Rural 763422 1113861 1510181 815 848

Urban 299840 660559 842410 404 654 Jan-19

Rural 1085192 1121877 1520625 817 1098

Urban 306754 670397 847320 407 658 Feb-19

Rural 1196291 1105199 1511061 816 1157

Urban 232954 658378 837030 409 506 Mar-19

Rural 909075 1073004 1487038 816 890 ..

Pet1t1oner

(\

~

Page 308

Name of Distribution Licensee Licensed Area of Supply

Form: F-17.3

Uttarakhand Power Corporation Limited Uttarakhand

Momentary Average Interruption Frequency Index (MAIFI)

FY 2018-19

ci ::::: Total No. of Nt ::::: Total Connected

sustained N 1 ::::: Connected Load Load at 11 kV in the

Month Urban/ interruptions ( each of ith Feeder affected Distribution Rural longer than 5 due to each

Licensee"s Supply minutes) on ith interruption

Feeder for the month Area

Urban 3045 593217 711811 Apr-18

Rural 7488 993219 1394489

Urban 3668 584610 699386 May-18

Rural 9097 1049485 1438123

Urban 4644 584445 715530 Jun-18

Rural 9918 1101337 1474884

Urban 4769 622049 747165 Jul-18

Rural 9954 1090076 1432360

Urban 4455 607861 783744 Aug-18

Rural 9548 1088252 1493591

Urban 3819 633689 783427 Sep-18

Rural 8199 1111489 1501538

n = No. of 11 kV Feeders in the

licensed area of supply ( excluding

MAIFI those serving predominantly

Agriculture loads)

401 7

805 9

383 8

773 10

386 11

776 11

391 11

779 11

387 11

787 11

392 8

792 9

Page 309

Form: F-17.3 Momentary Average Interruption Frequency Index (MAIFI)

FY 2018-19

n = No. of 11 kV c; = Total No. of

Nt = Total Connected Feeders in the sustained Ni = Connected load licensed area of

Urban/ interruptions ( each of ith Feeder affected load at 11 kV in the

supply (excluding Month Distribution MAIFI

Rural longer than 5 due to each Licensee's Supply

those serving minutes) on ith interruption predominantly

Feeder for the month Area

Agriculture loads)

Urban 3102 673066 784866 393 7 Oct-18

Rural 6316 1056639 1494182 817 6

Urban 2403 674801 778948 399 6 Nov-18

Rural 5497 1022511 1467391 816 6

Urban 2699 697231 806578 400 6 Dec-18

Rural 5213 1105820 1510181 815 6

Urban 2815 711145 842410 404 6 Jan-19

Rural 5885 1119626 1520625 817 7

Urban 3155 723682 847320 407 6 Feb-19

Rural 6888 1104556 1511061 816 7

Urban 2651 740446 837030 409 5 Mar-19

Rura! 6634 1077918 1487038 816 7 ..

Pet1t1oner

Page 310

,,----,----·-----.---.--.. -.. ~,~-~ ··------·---- ... •. ~-------

Name of Distribut\on Licensee Licensed Area of Supply

Uttarakhand Power Corporation Limited Uttarakhand

Form: F-18.1

Shunt Capacitor Addition / Repair Program

S.No. Particulars

Canacitor Additions

1 Total Canacitors renuirement at the end of Previous year

2 Acual installed Canacitors at the end of Previous Year

3 Backloo/shortfall at the end of orevious vear (1-21

4 Additional Reouirement for the Current Year

5 Total Caoacitv reauired to be added durlnq the current vear (3+4)

6 Actual installed durina first half of Current vear 7

Taroet for the 2nd half of Current vear

8 Total Caoacitors likelv to be added durlno Current Year (6+7) 9

Total caoacitv likelv to be available bv the end of current vear (2+8)

10 Short fall if anv (5-9)

Ren air of Defective Shunt Canacitors

11 At the end of the end of nrevious vear

12 Net Caoacitv Available bv the end of orevious vear (2-11;

13 Caoacitors damaaed durina 1st half of tl1e current vear

14 Capacitors reoaired durlna 1st ha!f of the current vear

15 Net Canacitv Available bv the end of 1st half of the vear (12-13+14)

16 Tarqet level of damaqed capacitors by the end of current year

17 Net Canacitv Likelv to be Available bv tl1e end of current vear (9-16)

18 Net Shortfall bv the end of the vear (5-17)

Capacity fMVAR'

795

795

---

-

-

-

--

-

795

-

-

795

-

-

-' '' \' ~

Petitioner

Page 311

Name of Distribution Licensee Licensed Area of Supply

Form: F-18.2

Electrical Accidents

Type of Accident

HUMAN

ANIMAL

Total

Uttarakhand Power Corporation Limited Uttarakhand

No. of Accidents

Previous year (2018-19) Current year(2019-20) upto September

FATAL NON FATAL Total FATAL NON FATAL Total

56 44 100 33 43 76

64 7 71 70 l 71

120 51 171 103 44 147

Petitioner

Page 312

Name of Distribution Licensee Licensed Area of Supply

Form: F-18.3

Uttarakhand Power Corporation Limited Uttarakhand

Abstract of Outages due to feeder tripping

- ~-- .. _

SI No Item No. of Total duration of Feeders

No. of Trippings Tripping (Hrs)

1 66 KV 1 85 5

2 33 KV 457 23059 8797

3 11 KV 1547 213179 79009

4 Average duration of interruption

1 :25 per feeder for voltage Level 1

5 Average duration of interruption 0:01 per feeder for voltage Level 2

6 Average duration of interruption 0:00 per feeder for voltage Level 3 -Vo/rage levels for D1stnbut1on Licensee are 66kV, _,3 kV andl 1 kV

Current Year (2019-20)

No. of No. of Total

Feeders Trippings duration of Tri--inn

1 69 9

458 14174 4976

1578 127952 397875

3:09

0:01

0:02

Average interruption per feeder= total duration of interruptions/ (no. of feeders x no. of trippings) The above statement is to be accompanied by a detailed note to outline the reasons thereof and measures taken/planned for improvE

(\ ! i

~

Page 313

Name of Distribution Licensee Licensed Area of Supply

Form: F-18.4

Uttarkhand Power Corporation Uttarakhand

Category wise Load Shedding carried out during the year

S. No. Particulars Furnace/Non - Small

Continuous Town FY 2018-19

1 On SLDC's instructions (to control drawal) 53.53 1.74

2 On SLDC's instructions (to avoid overloading 0.08 0.04 in Transmission Licensee's network'\

3 On SLDC's instructions (Due to Low Voltage 0.00 0.00 in DPCL network\

4 Due to outage in Transmission Licensee's 0.07 0.10

5 Due to outane in own Network 0.00 0.00

6 Due to outage in the network of some other Distribution Licensee

0.00 0.00

Due to Transmission constraints in 0.00 0.00 7 transmission Licensee's Neb.Nork

8 To avoid overloading in own Network 0.00 0.00

9 To avoid overloading in the Network of some other Distribution Licensee

0.00 0.00

10 Any Other Reason 0.00 0.00

Total for FY 2018-19 53.68 1.87 FY 2019-20

1 On SLDC's instructions (to control drawal) 11.97 0.14

2 On SLDC's instructions (to avoid overloading 0.00 0.00 in Transmission Licensee's network)

3 On SLDC's instructions (due to low voltage in DPCL network\

0,00 0.00

4 Due to outage in Transmission licensee's network

0.00 0.00

5 Due to outage in own network 0.00 0.00

6 Due to outage in the network of some other Distribution Licensee

0.00 0.00

7 Due to transmission constraints in 0.00 0.00 Transmission licensee's network

8 To avoid overloadin'" in own network 0.00 0.00

9 To avoid overloading in the network of some other Distribution Licensee

0.00 0.00

10 An11 other reason 0.00 0.00 Total for FY 2019-20 11.97 0.14

(In MU)

Big Town Hills Rural Total

0.13 0.00 16.84 72.24

0.00 0.00 0.14 0.26

0.00 0.00 0.00 0.00

0.00 0.00 0.19 0.36

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.13 0.00 17.18 72.86

0.00 0.00 3.79 15.90

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00 o.oo o.oo 3,79 15.90

Petitioner

Page314

Name of Distribution Licensee Licensed Area of Supply

Form: F-18.5

Overioaded Feeders

S.No Area

1 Dehradun Urban A 66 KV

Dehradun Sub-Total Dehradun (U) 66 KV

B 33 KV Dehradun Sub-Total Dehradun (UI 33 KV

C 11 KV Dehradun Sub-Total Dehradun (Ul 11 KV

2 Dehradun Rural A 66 KV

Dehradun Sub-Total Dehradun (Rl 66 KV

B 33 KV Dehradun Sub-Total Dehradun (R) 33 KV

C 11 KV Dehradun Sub-Total Dehradun (RI 11 KV

3 Srinaoar A 66 KV

Pauri Sub-Total Srinariar 66 KV

B 33 KV Pauri Sub-Total Srinaoar 33 KV

Uttarkhand Power Corporation Uttarakhand

Previous Year 2018-19

No. of Line

Line lengh No. of Feeders Feeder

Length overload

overloade (ckt:Km) d Feeders ed

(ckt:Km)

0 0 0 0 0 0 0 0

14 199.472 0 0 14 199.472 0 0

128 708.9 0 0 128 708.9 0 0

0 0 0 0 0 0 0 0

68 552.674 0 0 68 552.674 0 0

190 3879.911 0 0 190 3879.911 0 0

0 0 0 0 0 0 0 0

48 606.44 0 0 48 606.44 0 0

"lo

Number of

Overload ed

Feeder

'" . 0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

Current Year 2019-20

% Line %

% length of No. of !engh

Number Line of length of

Overload No. of Feeders overload Overload ed Feeder

Length overload ed Overload

(ckt:Km) ed ed

Feeder ed Feeders Feeder

Feeder in Area (ckt:Km}

;,..., A -in Area

0 0 0 0 0 0 0 0 0 0 0 0 0 0

0 14 199.472 0 0 0 0 0 14 199.472 0 0 0 0

0 128 748.88 0 0 0 0 0 128 748.88 0 0 0 0

0 0 0 0 0 0 0 0 0 0 0 0 0 0

0 68 563.7 0 0 0 0 0 68 563.7 0 0 0 0

0 190 3920.94 0 0 0 0 0 190 3920.94 0 0 0 0

0 0 0 0 0 0 0 0 0 0 0 0 0 0

0 48 606.44 0 0 0 0 0 48 606.44 0 0 0 0

Page 315

Previous Year 2018-19 Current Year 2019-20 %

% Line ",O

% Line Number Number No. of length of No. of lengh length of

Line lengh of Line of S.No Area No. of Feeders Overload No. of Feeders overload Overload Length overloade Overload Length Overload Feeder overload ed Feeder overload ed ed

(ckt:Km) ed d Feeders ed Feeder

(ckt:Km) Feeders

ed (ckt:Kni) Feeder

ect Feeder

Feeder

'" ' in Area (ckt:Km)

'" in Area

C 11 KV Pauri 134 5260.55 0 0 0 0 134 5648.111 0 0 0 0 Sub-Total Srinaoar 11 KV 134 5260.55 0 0 0 0 134 5648.111 0 0 0 0

4 Tehri A 66 KV

Tehri 0 0 0 0 0 0 0 0 0 0 0 0 Uttarkashi 0 0 0 0 0 0 0 0 0 0 0 0 Sub-Total Tehri 66 KV 0 0 0 0 0 0 0 0 0 0 0 0

B 33 KV Tehri 33 364 0 0 0 0 33 364.4 0 0 0 0 Uttarkashi 8 285.3 0 0 0 0 8 285.3 0 0 0 0 Sub-Total Tehri 33 KV 41 649.3 0 0 0 0 41 649.3 0 0 0 0

C 11 KV Tehri 77 4141 0 0 0 0 77 4244.75 0 0 0 0 Uttarkashi 33 2053.93 0 0 0 0 37 2075.05 0 0 0 0 Sub-Total Tehri 11 KV 110 6194.93 0 0 0 0 114 6319.8 0 0 0 0

5 Karanoravaa A 66 KV

Chamoli 1 121 0 0 0 0 1 121 0 0 0 0 Rudraoravaa 0 0 0 0 0 0 0 0 0 0 0 0 Sub-Total Karanoravaa 66 KV 1 121 0 0 0 0 1 121 0 0 0 0

B 33 KV Chamoli 14 267.34 0 0 0 0 14 267.339 0 0 0 0 Rudranravaa 2 136.19 0 0 0 0 2 136.19 0 0 0 0 Sub-Total Karanaravao 33 KV 16 403.53 0 0 0 0 16 403.529 0 0 0 0

C 11 KV .

Chamoli 49 2389.11 0 0 0 0 49 2408.ll 0 0 0 0 Rudraoravaa 21 1257.73 0 0 0 0 21 1261.4 0 0 0 0 Sub-Total Karannrayao 11 KV 70 3646.84 0 0 0 0 70 3669.51 0 0 0 0

6 Rudranur A 66 KV

,/--\

;;::j-':;/

Page316

Previous Year 2018-19 Current Year 2019-20 70

% Line "" % Line Number Number Line

No. of lengh of

length of No. of lengh length of S.No Area No. of Feeders Overload No. of

Line Feeders overload

of Overload

Feeder Length

overload overloade Overload

ed Feeder Length

overload Overload (ckt:Km) d Feeders ed (ckt:Km) ed ed

ed Feeder ed ed (ckt:Km) Feeder Feeders Feeder

in Area (ckt:Km) Feeder

;" . ,_ I\-.,.~ in Area U.S.Naqar 0 0 0 0 0 0 0 0 0 0 0 0 Sub-Total Rudraour 66 KV 0 0 0 0 0 0 0 0 0 0 0 0 B 33 KV U.S.Naaar 69 346 0 0 0 0 69 410.3 1 11.34 1.449275 2.763831 Sub-Total Rudraour 33 KV 69 346 0 0 0 0 69 410.3 1 11.34 1.44928 2.76383 C 11 KV U.S.Nanar 185 2427.57 0 0 0 0 187 2589.503 12 105.87 6.417112 4.088429 Sub-Total RudrarJur 11 KV 185 2427.57 0 0 0 0 187 2589.503 12 105.87 6.41711 4.08843

7 Pithoraaarh A 66 KV

Pithorar.arh 0 0 0 0 0 0 0 0 0 0 0 0 Champawat 0 0 0 0 0 0 0 0 0 0 0 0 Sub-Total Pithoraoarh 66 KV 0 0 0 0 0 0 0 0 0 0 0 0

B 33 KV Pithoraaarh 9 281 0 0 0 0 9 306.665 0 0 0 0 Chamnawat 3 165.87 0 0 0 0 3 141 0 0 0 0 Sub-Total Pithoraaarh 33 KV 12 446.87 0 0 0 0 12 447.665 0 0 0 0

C 11 KV Pithoraaarh 76 3106.101 0 0 0 0 76 3133.541 0 0 0 0 Chamnawat 26 1743.9 0 0 0 0 26 1754.52 0 0 0 0 Sub-Total Pithoraoarh 11 KV 102 4850.001 0 0 0 0 102 4888.061 0 0 0 0

8 Rookree A 66 KV

Haridwar 1 12 0 0 0 0 1 12 0 0 0 0 Sub-Total Roorkee 1 0 0 0 0 0 0 12 0 0 0 0

8 33 KV Haridwar 48 318.6 0 0 0 0 48 384.4 2 13 4.166667 3.381894 Sub-Total Roorkee 48 318.6 0 0 0 0 48 384.4 2 13 4.16667 3.38189

C 11 KV Haridwar 128 2240.05 2 10.48325 1.5625 0.467992 131 2476.5'1 17 394.79 12.9771 15.94139 Sub-Total Roorkee 128 2240.05 2 10.4833 1.5625 0.46799 131 2476.51 17 394.79 12.9771 15.9414

9 Haridwar A 66 KV

Haridwar 0 0 0 0 0 0 0 0 0 0 0 0 Sub-Total Haridwar 0 0 0 0 0 0 0 0 0 0 0 0

B 33 KV Haridwar 50 247 0 0 0 0 50 267 .07 0 0 0 0 Sub-Total Haridwar 50 247 0 0 0 0 50 267.07 0 0 0 0

C 11 KV Haridwar 150 1931 0 0 0 0 165 2095.11 25 156.63 15.15152 7.47598

Page 317

Previous Vear 2018-19 Current Year 2019-20 "lo

% Line °lo

% No. of

Line Number length of No. of lengh

Number length of Line lengh of Line of S.No Area No. of

Length Feeders

overloade Overload Overload No. of

Length Feeders overload

Overload Overload

Feeder overload ed Feeder overload ed ed (ckt:Km) ed d Feeders ed Feeder

(ckt:Km) ed Feeders ed

Feeder (ckt:Km) Feeder in Area (clct:Km)

Feeder in Area ;n • - ;" .

Sub-Total Haridwar 150 1931 0 0 0 0 165 2095.11 25 156.63 15.1515 7.47598 10 Haldwani

A 66 KV Nainital 0 0 0 0 0 0 0 0 0 0 0 0 Sub-Total Haldwani 0 0 0 0 0 0 0 0 0 0 0 0

B 33 KV Nainital 31 386.862 0 0 0 0 32 418.462 0 0 0 0 Sub-Total Haldwani 31 386.862 0 0 0 0 32 418.462 0 0 0 0

C 11 KV Nainital 122 2861.803 0 0 0 0 129 2937.987 0 0 0 0 Sub-Total Haldwani 122 2861.803 0 0 0 0 129 2937.987 0 0 0 0

11 Kashinur A 66 KV

U.S.Naoar 0 0 0 0 0 0 0 0 0 0 0 0 Sub-Total Kashiour 0 0 0 0 0 0 0 0 0 0 0 0

B 33 KV U.S.Naqar 27 265.374 0 0 0 0 27 278.974 0 0 0 0 Sub-Total Kashipur 27 265.374 0 0 0 0 27 278.974 0 0 0 0

C 11 KV U.S.Naaar 98 1668.31 0 0 0 0 98 1726.931 0 0 0 0 Sub-Total Kashiour 98 1668.31 0 0 0 0 98 1726.931 0 0 0 0

12 Ranikhet A 66 KV

Almora 0 0 0 0 0 0 0 0 0 0 0 0 Baqeshwar 0 0 0 0 0 0 0 0 0 0 0 0 Sub-Total Kashiour 0 0 0 0 0 0 0 0 0 0 0 0

B 33 KV Almora 25 492.65 0 0 0 0 25 546.65 0 0 0 0 Baneshwar 8 185.78 0 0 0 0 8 185.78 0 0 0 0 Sub-Total Kashinur 33 678.43 0 0 0 0 33 732.43 0 0 0 0

C 11 KV Almora 101 3875.276 0 0 0 0 101 4820.02 0 0 0 0 Baaeshwar 29 1635.14 0 0 0 0 29 1670.1 0 0 0 0 Sub-Total Kashiour 130 5510.416 0 0 0 0 130 6490.12 0 0 0 0

Total for all Circles at 66 KV 2 133 0 0 0 0 2 133 0 0 0 0

Total for all Circles at 33 KV 457 5100.552 0 0 0 0 458 5361.742 3 24.34 0.65502 0.45396

Total for all Circles at 11 KV 1547 41180.28 2 10.4833 0.12928 0.02546 1578 43511.46 54 657.29 3.42205 1.51061

Page318

Name of Distribution Licensee Licensed Area of Supply

Form: F-18.6

Failure of Transformers

SI. No. Item

Transformation ratio

1 66/33 KV

2 33/11 KV

3 11/0.4 KV

Average duration of interruption

Average duration of interruption per 5 transformer for Transformation ratio

66/33 KV

Average duration of interruption per 6 transformer for Transformation

ratio33/11 KV

Average duration of interruption per 7 transformer for Transformation ratio

1110.4 KV

Uttarakhand Power Corporation Limited Uttarakhand

FY 2018-19

No. of No. of Total Duration of Transformers failures failure (Hrs.)

5 0 0

640 589 474

73264 6204 124424

0:00:00

0:01:49

0:00:24

No. of Transformers

5

645

74493

Transformation ratios for Distribution Licensee are 66/33 kV, 33/11 kV AND 11 kV /400 V.

FY 2019-20

No. of failures

Total Duration of failure (Hrs.)

0 0

356 465

2983 60011

0:00:00

0:02:55

0:00:23

The above statement is to be accompanied by a detailed note to outline the reasons thereof and measures taken/planned for i!(1'1?rovement.

:}v,/ Petitior/er

Page319

Name of Distribution Licensee Licensed Area of Supply

Form: 18.7

Uttarakhand Power Corporation Limited Uttarakhand

Overloaded Distribution Transformers (DTRs)

Previous Year (2018-19)

S.No. Area No. of O/o number of No. of DTRs in

overloaded overloaded Area

DTRs in area DTRs

1 EDC Haldwani A 33/llKV i Nainital 50 0 o.oo

Total EDC Haldwani 50 0 o.oo B 11/0.4 KV i Dlstrict Nainital 5880 40 0.01

Total EDC Haldwani 5880 40 0.01 2 EDC Kashinur A 33/llKV i U.S.Naaar 49 5 0.10

Total EDC Kashinur 49 5 0.10 B 1110.4 KV i U.S.Nar,ar 6543 158 0.02

Total EDC Kashinur 6543 158 0.02 3 EDC Ranikhet A 33/llKV i Almora 44 0 0.00 ii Bar,eshwar 13 0 0.00

Total EDC Ranikhet 57 0 0.00 B 11/0.4 KV i Almora 4164 4 0.00

Baneshwar 1734 1 0.00 Total EDC Ranikhet 5898 5 0.00

4 EDC Rudranur A 33/11 KV

U.S.Naoar 67 0 0.00 Total EDC Rudranur 67 0 0.00

B 11/0.4 KV U.S.Naoar 8902 197 0.02 Total EDC Rudranur 8902 197 0.02

5 EDC Pithoraaarh

Current Year (2019-20)(30 Sep. 2019)

No. of No. of

DTRs in overloade O/o number of

Area d DTRs in overloaded DTRs

area

53 0 0.00 53 0 o.oo

5898 24 0.00 5898 24 0.00

48 6 0.13 48 6 0.13

6543 42 0.01 6543 42 0.01

45 0 0.00 13 0 0.00 58 0 0.00

4221 4 0.00 1737 1 0.00 5958 5 0.00

67 0 0.00 67 0 0.00

9075 120 0.01 9075 120 0.01

Page 320

Previous Year {2018-19) Current Year (2019-20)(30 Sep. 2019)

S.No. Area No. of O/o number of No, of No. of

No. of DTRs in overloaded overloaded DTRs in

overloade 0/o number of Area

DTRs in area DTRs Area d DTRs in overloaded DTRs

area

A 33/11 KV i Pithoraoarh 29 0 0.00 29 0 0.00

ii Chamnawat 11 0 0.00 11 0 0.00

Total EDC Pithoranarh 40 0 0.00 40 0 0.00

B 11/0.4 KV i Pithoraoarh 3570 14 0.00 3570 3 0.00

ii Chamoawat 1552 0 0.00 1561 0 0.00 Total EDC Pithoraaarh 5122 14 0.00 5131 3 0.00

6 Roorkee A 33 KV

Haridwar 60 0 0.00 60 2 0.03

Sub Total Circle 33 KV 60 0 0.00 60 2 0.03

B 11 KV Haridwar 10648 125 0.01 11039 86 0.01

Sub Total Circlell KV 10648 125 0.01 11039 86 0.01

7 Haridwar A 33 KV

Haridwar 67 0 0.00 68 2 0.03

Sub Total Circle 33 KV 67 0 0.00 68 2 0.03

B 11 KV Haridwar 7057 40 0.01 7294 94 0.01

Sub Total Circlell KV 7057 40 0.01 7294 94 0.01

8 Dehradun Urban A 33 KV

Derhadun 56 0 o.oo 56 0 0.00

Sub-Total Circle 33 KV 56 0 0.00 56 0 0.00

8 11 KV Dehradun 2745 0 0.00 2767 0 o.oo Sub-Total Circle 11 KV 2745 0 0.00 2767 0 0.00

9 Dehradun Rural A 33 KV

Page 321

Previous Year (2018-19) Current Year (2019-20)(30 Sep. 2019)

S.No. Area No. of O/o number of No. of No. of

No. of DTRs in overloaded overloaded DTRs in

overloade O/o number of Area d DTRs in overloaded DTRs

DTRs in area DTRs Area area

Dehradun 66 0 0.00 67 0 0.00 Sub-Total Circle 33 KV 66 0 0.00 67 0 0.00

B 11 KV Dehradun 5211 12 0.00 5304 12 0.00 Sub-Total Circle 11 KV 5211 12 0.00 5304 12 0.00

10 Srinaaar A 33 KV

Paurl 51 0 0.00 50 0 0.00 Sub-Total Circle 33 KV 51 0 0.00 50 0 0.00

B 11 KV Pauri 5843 0 0.00 5925 0 0.00 Sub-Total Circle 11 KV 5843 0 0.00 5925 0 0.00

11 Tehri A 33 KV

Tehri 27 0 0.00 27 0 0.00 Uttarkashi 20 0 0.00 20 0 0.00 Sub-Total Circle 33 KV 47 0 0.00 47 0 0.00

B 11 KV Tehri 3904 0 0.00 3904 0 0.00 Uttarkashi 1617 0 0.00 1748 0 0.00 Sub-Total Circle 11 KV 5521 0 0.00 5652 0 0.00

12 Karannravan A 33 KV

Chamoli 21 0 0.00 23 0 0.00 Rudraora"ari 9 8 Sub-Total Circle 33 KV 30 0 0.00 31 0 0.00

B 11 KV Chamoli 2111 0 0.00 2111 0 0.00 Rudranravari 1783 0 1796 0 Sub-Total Circle 11 KV 3894 0 0.00 3907 0 0.00 Total 33111 KV 640 5 0.01 645 10 0.02 Total 1110.4 KV 73264 591 0.01 74493 386 0.01

The above statement is to be accompanied by a detailed note to outline the reasons thereof and measures taken/planned for improvement.

Page 322

Name of Distribution Licensee Licensed Area of Supply

Form: F-18.8

Ageing Schedule of Receivables As on 31-03-2018)

Uttarakhand Power Corporation Limited Uttarakhand

Receivables of Licensee with age SI. No. Receivables 6 mths to 3 to 4 4 to 5

< 6 months 11,ear 1 to 2 years 2 to 3 years "ea rs "ears

Electrici'"'1 Distribution Circle I Rural). Dehradun Domestic 3.97 5.96 7.14 0.43 0.01 4.60 Non-Domestic 0.77 1.16 3.72 3.59 0.00 0.00 LT Industrv (0.00\ I0.00\ 0.36 0.00 0.00 0.00 HT Industrv 0.00 0.00 0.00 4.41 0.00 83.29

1 Mixed Load 10.00, (0.00\ 0.05 0.12 0.00 0.00 Private Tube-wells 0.18 0.27 0.20 0.00 0.00 (0.00 Public Lamos 0.22 0.33 0.43 10.00· ro.oo 0.00 Public Water Works 0.05 0.07 2.92 0.00 (0.00 16.00 Govt. Irriaation Svstem 10.00\ I0.00\ 8.29 0.00 4.71 11.71 Railwav Traction - - - - - -Subtotal for the Circle 5.18 7.78 23.12 8.56 4.73 115.60 Electricity Distribution Circle (Urban), Dehradun Domestic 0.00 0.00 0.00 0.24 0.00 5.81 Non-Domestic 0.05 0.07 0.00 1.70 0.00 1.91 LT Industn, 10.00: /0.00i 0.00 0.11 0.00 0.28

2 HT Industrv 0.10 0.15 0.00 ro.oo, 0.00 10.00, Mixed Load 0.14 0.21 0.10 (0.001 0.27 (0.00\ Private Tube-wells 0.00 0.00 0.02 0.00 0.02 0.01 Public La mns (0.00\ (0.00i 0.04 (0.00\ 1.92 0.00 Public Water Works (0.001 ro.oo, 0.00 2.55 I0.00 10.00\ Govt. Irrioation Svstem 0.00 0.00 10.00\ 10.00, 0.00 0.26 Railwav Traction - - - - - -Subtotal for the Circle 0.29 0.44 0.17 4.60 2.20 8.26

(Rs. Crores·

> 5 years Total

26.23 48.33 30.21 39.45 3.30 3.67

187.05 274.76 - 0.18

1.59 2.24 0.21 1.19 5.36 24.39

10.00' 24.72 - -

253.95 418.93

17.02 23.07 3.36 7.08 1.15 1.53

10.00' 0.24 10.00' 0.73 0.10 0.16 0.00 1.96 8.49 11.04

(0.00\ 0.25 - -

30.10 46.06

Page 323

Receivables of Licensee with age

SI. No. Receivables 6 mths to 3 to 4 4 to 5 < 6 months 1 to 2 years 2 to 3 years > 5 years Total

1 "ear "ears vears Electricity Distribution Circle, Srinanar Domestic 2.77 4.16 7.10 3.87 32.14 6.93 23.49 80.46

Non-Domestic 1.45 2.18 0.00 (0.00\ 14.86 7.19 26.7? 52.39

LT Industrv 0.15 0.22 0.10 0.18 0.87 0.27 2.14 3.92

3 HT Industrv 3.18 4.77 8.13 7.75 0.00 0.00 56.26 80.10

Mixed Load 0.04 0.06 i0.00 ro.OO) 0.21 (0.00) 0.00 0.30

Private Tube-wells 0.00 0.01 0.01 0.00 0.01 0.03 0.00 0.06

Public Lamos 0.52 0.78 2.03 0.00 0.00 0.00 0.02 3.35

Public Water Works (0.00\ !0.00\ 14.45 (0.00\ (0.00\ (0.00) 6.37 20.81

Govt. Irriaation Svstem 0.00 0.00 0.00 0.00 I0.00\ 0.00 (2.59\ (2.58\

Railwav Traction - - - - - - - -Subtotal for the Circle 8.12 12.17 31.82 11.80 48.08 14.41 112.40 238.81

Electricity Distribution Circle, Roorkee + Hardwar Domestic 20.22 30.32 48.19 34.63 -io.oo 15.88 200.81 350.04

Non-Domestic 0.00 0.00 (0.00\ 6.61 2.17 9.40 96.46 114.65

LT Industrv 0.00 0.00 0.00 0.92 0.84 (0.00 16.43 18.19

4 HT Industrv ro.oo To.001 0.00 0.00 19.71 0.00 ro.oo 19.72

Mixed Load ro.oo ro.001 0.00 0.52 0.00 0.00 0.04 0.57

Private Tube-wells 0.00 0.00 12.90 7.45 1.68 9.04 24.02 55.09

Public Lamos 1.10 1.65 5.37 ro.oo 0.00 ro.oo 0.00) 8.13

Public Water Works 0.00 0.00 0.00 (0.00 0.00 4.67 0.00\ 4.67

Govt. Irriaation Svstem 0.61 0.92 ro.OO\ ro.oo 10.46 1.72 0.001 13.70

Railwav Traction ro.001 I0.00\ 0.14 ro.oo To.001 0.04 0.00 0.18

Subtotal for the Circle 21.93 32.89 66.46 50.13 34.87 40.72 337.74 584.75

Electricity Distribution Circle, Haldwani Domestic 0.27 0.40 0.00 ro.001 1.32 2.43 14.64 19.06

Non-Domestic (0.00\ (0.00\ 0.25 0.00 ro.oo 0.66 10.03 10.93

LT Industrv ro.oo• ro.OO\ 0.00 (0.00\ ro.oo• 0.18 1.20 1.38

5 HT Industrv 0.93 1.40 (0.00\ (0.00\ 1.54 0.90 18.10 22.87

Mixed Load 0.00 0.00 0.02 0.00 0.21 0.00 (0.00 0.23

Private Tube-wells 0.03 0.04 (0.00\ 0.00 ro.oo (0.00' 0.12 0.18

Public Lamos 0.64 0.96 2.13 0.00 ro.oo 0.00 0.71 4.44

Public Water Works 2.78 4.17 5.39 0.00 0.00 10.00 16.06 28.41

Govt. Irriaation Svstem 4.94 7.41 1.24 0.00 12.60 (0.00 29.47 55.67

Railwav Traction - - - - - - - -

Subtotal for the Circle 9.59 14.38 9.03 0.01 15.67 4.17 90.33 143.18

Page 324

Receivables of Licensee with age SI. No. Receivables 6 mths to 3 to 4 4 to 5

< 6 months 1 vear

1 to 2 years 2 to 3 years vears vears

> 5 years Total

Electricity Distribution Circle, Rudranur + Kashinur Domestic 2.34 3.51 ro.OO' 13.36 0.00 15.11 13.70 48.03 Non-Domestic 0.00 0.00 0.00 !0.00\ (0.00\ 10.81 19.46 30.26 LT Industrv 0.00 0.00 0.00 4.55 0.00 0.00 10.00 4.55

6 HT Industrv 0.00 0.00 0.00 (0.00\ (0.00\ 0.00 (86.12 /86.12 Mixed Load 0.00 0.00 !0.00' (0.00\ 10.00) 0.00 10.83 (0.84 Private Tube-wells 0.58 0.87 7.21 8.31 10.41 14.10 43.36 84.84 Public Lamns 0.00 0.00 23.92 (0.00) 10.00 (0.00) 0.00 23.92 Public Water Works 0.46 0.69 0.00 0.00 0.00 5.79 9.38 16.32 Govt. Irrination Svstem 10.00\ ro.001 11.30 ro.001 5.84 3.68 0.00 20.82 Railwav Traction - - - - - - - -Subtotal for the Circle 3.39 5.08 42.43 26.22 16.24 49.50 (1.06 141.80 Electricity Distribution Circle, Ranikhet+Pithroaarh Domestic 1.47 2.20 2.89 2.39 4.98 2.77 31.79 48.50 Non-Domestic 2.35 3.52 5.83 6.89 5.44 4.47 18.43 46.93 LT Industrv 0.12 0.18 0.09 0.00 0.02 0.19 2.46 3.06

7 HT Industrv 0.02 0.02 10.00) 0.08 0.00 ro.oo 0.16 0.28 Mixed Load 0.12 0.19 0.21 0.01 0.39 0.00 0.24 1.16 Private Tube-we!ls 0.01 0.02 0.05 0.05 0.04 0.02 0.09 0.28 Public Lamos 0.00 0.00 1.82 !0.00\ 0.07 0.00 0.00 1.90

Public Water Works 1.99 2.98 2.52 0.00 0.00 0.00 25.50 33.00 Govt. Irriaation Svstem 1.81 2.72 6.94 (0.001 3.?8 2.03 5.48 2?.26 Railwav Traction - - - - - - - -Subtotal for the Circle 7.89 11.84 20.34 9.41 14.24 9.49 84.16 l!:17.37

Total UPCL Domestic 31.04 46.56 65.32 54.92 38.45 53.52 327 .69 617.51 Non-Domestic 4.61 6.92 9.81 18.79 22.47 34.43 204.66 301.69 LT Industrv 0.27 0.40 0.56 5.76 1.73 0.91 26.67 36.29 HT Industrv 4.23 6.34 8.14 12.25 21.26 84.19 175.44 311.85

8 Mixed Load 0.31 0.46 0.38 0.65 1.08 0.01 (0.56\ 2.33 Private Tube-wells 0.81 1.21 20.38 15.82 12.17 23.21 69.27 142.85 Public Lamos 2.48 3.72 35.74 ro.001 1.99 0.02 0.94 44.88 Public Water Works 5.27 7.91 25.28 2.56 0.00 26.45 71.17 138.64 Govt. Irriaation Svstem 7.37 11.05 27.77 (0.00) 36.90 19.41 32.35 134.85 Railwav Traction 10.00) (0.00\ 0.14 (0.00\ !0.001 0.04 0.00 0.18 Total 56.39 84.58 193.37 110.74 136.04 242.1 907.63 1 730.90 ..

Petitioner

Pag2 325

s. No.

A

1

2

3

4

B

1

2

3

4

Name of Distribution Licensee Licensed Area of Supply

Form: F-18.9

Status of Metering

Item

2018-19

No. of metered consumers at the beginning of the previous year

No. of unmetered consumers at the beginning of the previous year

Total no. of consumers at the beginning of the previous year (1+2)

Unmetered consumers as% of total consumers at the beginning of the previous year (2/3)

2019-20

No. of metered consumers at the beginning of the current year

No. of unmetered consumers at the beginning of the current year

Total no. of consumers at the beginning of the current year (1+2)

Unmetered consumers as % of total consumers at the beginning of the current year (2/3)

Domestic

1,941,096

1,941,096.00

0.00%

2,124,219

0

2,124,219

0.00%

Non- Private Tube-LT Industry

Domestic wells

234,412 32,456 10,229

234,412.00 32,456.00 10,229.00

0.00% 0.00% 0.00%

249940 34733 10756

0 0 0

249,940 34,733 10,756

0.00% 0.00% 0.00%

Public Government Railway HT Public

Water Irrigation Total Industry Lamps Traction

Wortrs C m

2,329 1,470 1,605 1,772 2 222S37l

0

2,329.00 1,470.00 1,605.00 1,772.00 2 2225371

0.00% 0.00% 0.00% 0.00% 0.00% 0.00%

2100 1876 1782 1841 2 2427249

0 0 0 0 0 0

2,100 1,876 1,782 1,841 2 2427249

0.00% 0.00% 0.00% 0.00% 0.00% 0.00%

Page 326

Name of Distribution Licensee Licensed Area of Supply

Form: F-18.10

Release of Customer Bills

S. No. Category

1 Domestic 2 Non-Domestic 3 LT Industrv 4 HT Indust"'' 5 Mixed Load 6 Private Tube-wells 7 Public Lamos 8 Public Water Works 9 Govt. Irriaation Svstem 10 Railwav Traction

Total

Uttarakhand Power Corporation Limited Uttarakhand

Previous year

No. of customer bills No. of customer bills

served within 30 days of served after 30 days of

billing period billing period

12195945 -2905230 -

125910 -26574 -

882 -67189 -20076 -20322 -21678 -

24 -15383830 -

Current year (Actual) ·-

No. of customer bills No. of customer bills served within 30 days of served after 3 0 days of

billing period billing period

6.341 891 -1 510 720 -

64 844 - I

13 686 -450 . -

35 274 -10 440 -10.567 -1L273 -

12 -7999156 -

Petitioner

Page 327

Name of Distribution Licensee Licensed Area of Supply

Form : F-18.11

Uttarakhand Power Corporation Limited Uttarakl1and

Number of Pending Service Connection Application

FY 2018-19

Pending at the No. of

S. No. Category beginning of the Associated Applications

period Load (MW) Received during

period

1 RTS-1( Domestic) 14 378 14.38 227 287 2 RTS-2( Non-Domestic) 1 709 1.71 17 3?3 3 RTS-3al Public Liohtinal 210 0.21 823 4 RTS-3b(Govt. Irrq, l 77 0.08 616 5 RTS-3cf Public Water works' 80 0.08 159 6 RTS-4CPTW\ 641 0.64 2.672 7 RTS-71 Industrial" 180 0.18 890 8 RTS-81 Mix Load) 4 0.00 2

Total 17.279 17.28 249 772.00

FY 2019-20 (Unto Sentember 2019)

Pending at the No. at

S. No. Category beginning of the Associated Applications Load (MW) Received during

period ' . 1 RTS-l(Domesticl 12 992 12.99 52,068 2 RTS-2(Non-Domestic) 2 557 2.56 10-478 3 RTS-3af Public Linhtinq'\ 66 0.07 49 4 RTS-3b1 Govt. Irrn. 'I 88 0.09 29 5 RTS-3crPub!ic Water works'I 61 0.06 152 6 RTS-4(PTW) 1 044 1.04 2 192 7 RTS-7findustriall 243 0.24 498 8 RTS-S(Mix Load'\ 1 0.00 1

Total 17 052 17.05 65.467

No of Connections Pending at Associated

released during Associated Load

the end of the Associated

Load (MW) period

(MW) period

Load (MW)

227.29 211556 211.56 12,992 30.98 17.32 14540 14.54 2 557 20.73 0.82 897 0.90 66 0.35 0.62 516 0.52 88 3.56 0.16 142 0.14 61 3.61 2.67 1991 1.99 1 044 6.33 0.89 681 0.68 243 43.35 0.00 3 0.00 1 0.25

249.77 230 326 230.33 17 052 109,16

No of Connections Pending at Associated

released durlng Associated Load

the end of the Associated

Load (MW) (MW) Load (MW) period period

52.07 47898 47.90 10 083 39.57 10.48 9186 9.19 2 567 32.30 0.05 47 0.05 30 0.32 0.03 18 0.02 83 3.55 ' 0.15 112 0.11 72 7.22 2.19 1933 1.93 999 10.29 0.50 435 0.44 201 64.35 0.00 1 0.00 1 0.06

65.47 59 630 59.63 14 036 157.66

Petitioner

Page 328