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Power Department Government of NCT of Delhi

DERC (BUSINESS PLAN) REGULATIONS, 2023

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Post independence, the Delhi State Electricity Board (DSEB) came into existence and it had the responsibility of generation and distribution. Further, DSEB was transformed into various forms such as Delhi Electric Supply Undertaking (DESU) and Delhi Vidyut Board (DVB).

In May 1999, the Delhi Electricity Board Regulatory Commission (DERC) was constituted to look after regulatory matters such as tariff order creation, etc. as part of reforms; DVB was unbundled into six companies in July 2002. These are

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Delhi Electricity Regulatory Commission Business Plan...

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Delhi Electricity Regulatory Commission

Business Plan Regulations, 2017

DELHI ELECTRICITY REGULATORY COMMISSION

Delhi Electricity Regulatory Commission Business Plan Regulations, 2017

Friday, 01 September 2017 Page 2 of 29

New Delhi, 31 August, 2017

F.3(512)/Tariff/DERC/2016-17/5750: In exercise of powers conferred under Section 181 read

with Section 61 and Section 86(1)(b) of the Electricity Act, 2003 (Act 36 of 2003) and all other

powers enabling it in this behalf, the Delhi Electricity Regulatory Commission hereby notifies

the following Regulations namely:

PART 1 PRELIMINARY

1. SHORT TITLE, COMMENCEMENT AND EXTENT

(1) These Regulations shall be called the Delhi Electricity Regulatory Commission (Business

Plan) Regulations, 2017.

(2) These Regulations shall remain in force for a period of 3 (three) years i.e., for FY 2017-18,

FY 2018-19 and FY 2019-20, unless reviewed earlier.

(3) The period of validity of these Regulations may be extended by the Commission, as

deemed fit and the operational norms may also be extended as per the principles laid

down in these Regulations:

Provided that the target for reduction in Distribution Loss for extended period shall be

determined by the Commission based on the approved values by the Commission in the

past, latest audited accounts, estimate of the actual for the relevant year, prudence check

and other factors considered appropriate by the Commission.

(4) These Regulations shall extend to the whole of National Capital Territory of Delhi.

2. DEFINITIONS AND INTERPRETATION

In these Regulations, unless the context otherwise requires, words and expressions used in

these Regulations shall have the same meaning as defined in Delhi Electricity Regulatory

Commission (Terms and Conditions for Determination of Tariff) Regulations, 2017;

Words and expressions used but not defined in these Regulations shall have the same

meaning as assigned to it in the Electricity Act 2003 or any other law framed under the Act. by

the Commission.

Friday, 01 September 2017 Page 3 of 29

BUSINESS PLAN FOR GENERATING ENTITY

3. RATE OF RETURN ON EQUITY

Return on Equity in terms of Regulation 4(1) of the DERC (Terms and Conditions for

Determination of Tariff) Regulations, 2017 for Generating Entity shall be computed at the

Base Rate of 14.00% on post tax basis:

Provided that the Equity for the purpose of Return on Equity shall be lower of the

Normative Equity determined as per Regulation 63 of the Delhi Electricity Regulatory

Commission (Terms And Conditions For Determination of Tariff) Regulations, 2017 or

Equity available as per Audited Financial Statement of the relevant year.

4. TAX ON RETURN ON EQUITY

The base rate of Return on Equity as allowed by the Commission under Regulation 3, shall

be grossed up with the Minimum Alternate Tax or Effective Tax Rate of the respective

financial year in terms of Regulation 72 and 73 of the DERC (Terms and Conditions for

Determination of Tariff) Regulations, 2017, as per the following formula:

Rate of Return on Equity= 14/[(100-Tax Rate)/100]

where, Tax Rate is Minimum Alternate Tax (MAT) or Effective Tax Rate, as the case may be.

Illustration-

(i) In case of the Generating Entity paying Minimum Alternate Tax (MAT), say @

20.96% including surcharge and cess, then,

Rate of Return on Equity shall be = 14/[(100-20.96)/100] = 17.71%

(ii) In case of Generating Entity paying normal Corporate Tax including surcharge and

(a) Estimated Gross Income from generation for FY 2017-18 is, say Rs. 1000 Cr. and

(b) If estimated Advance Tax for the year on above is Rs. 240 Cr., then,

Effective Tax Rate for the year 2017-18 = 240/1000 = 0.24 or 24%, and

Rate of Return on Equity shall be = 14/[(100-24)/100] = 18.42%

5. MARGIN FOR RATE OF INTEREST ON LOAN

Margin for rate of interest for the Control Period in terms of Regulation 4(2) of the

DERC (Terms and Conditions for Determination of Tariff) Regulations, 2017 for the

Generating Entity shall be allowed as the difference in weighted average rate of

interest on actual loan as on 1st April 2017 and 1 (one) year Marginal Cost of Fund

based Lending Rate (MCLR) of SBI as on 1st April 2017:

Provided that the rate of interest on loan (MCLR plus Margin) shall not exceed

Friday, 01 September 2017 Page 4 of 29

approved base rate of return on equity i.e., 14.00%.

6. OPERATION AND MAINTENANCE EXPENSES

(1) Normative Operation and Maintenance expenses in terms of Regulation 4(3) and

Regulation 92 of the DERC (Terms and Conditions for Determination of Tariff) Regulations,

2017 for the Generating Entity shall be as follows :

(a) Normative Operation and Maintenance expenses for existing generating stations

shall be as follows :

Table 1: O&M Expenses (Rs. Lakh/ MW)

Station 2017-18 2018-19 2019-20

GTPS 29.66 31.32 33.08

PPS I 17.69 18.68 19.73

(b) Additional R&M Expenses for generating stations shall be as follows :

Table 2: Additional R&M Expenses (in Rs. Cr.)

GTPS 0.00 0.00 0.00

PPS I 16.12 16.12 0.00

(2) Impact of any statutory Pay revision on employee’s cost as may be applicable on case to

case basis shall be considered separately, based on actual payment made by the

Generation Entity and shall be allowed by the Commission after prudence check at the

time of true up of ARR for the relevant financial year.

7. CAPITAL INVESTMENT PLAN

(1) The tentative Capital Investment plan for Gas Turbine Power Station for FY 2017-18 to

FY 2019-20 is as follows:

Table 3:Capital Investment plan (in Rs. Cr.)

Description 2017-18 2018-19 2019-20 Efficiency

Improvement

1 Procurement and commissioning of exhaust plenum for GT # 1

1.45 0 0 Reduction in Gross Station Heat Rate

2 Replacement of Steam Ejector with Vacuum Pump Mod-1,2,3

0.35 0.35 0.35 Increase in

output power

3 Installation of VFD in Condensate Extraction Pump (CEP) Mod-I,2,3

0.08 0.08 0 Reduction in

Auxiliary Consumption

4 Procurement of steam turbine rotor/GBC/ Inner casing/Steam glands, for steam turbine (34MW)-Mod-2

0 17 0 Increase in

5 Total 1.88 17.43 0.35

Friday, 01 September 2017 Page 5 of 29

(2) The Capital investment plan and the respective scheduled date of commissioning,

submitted by the Generating Entity in the Annual Tariff Petition, shall form the basis for

computation of Annual Fixed Cost in terms of Regulation 99 of the DERC (Terms and

Conditions for Determination of Tariff) Regulations, 2017.

Provided that, any improvement in operational parameters resulting from commissioning

of the scheme due to any Additional Capital Investment in existing generating stations

shall form the basis for computing the Energy Charge Rate, from the scheduled date of

commissioning of the respective schemes, in terms of Regulation 103 of the DERC (Terms

and Conditions for Determination of Tariff) Regulations, 2017.

(3) Capital cost shall be trued up annually and financial impact on account of variation in

projected capital cost in the tariff order vis-a-vis actual capital cost and scheduled date of

commissioning vis-a-vis actual date of commissioning shall be dealt as per the provisions

of Regulations 61, 62 and 150 of the DERC (Terms and Conditions for Determination of

Tariff) Regulations, 2017.

8. NORMS OF OPERATION FOR GENERATING STATIONS:

(1) Normative Annual Plant Availability Factor and Normative Annual Plant Load Factor for

existing generating stations of Delhi shall be as follows :

I. Normative Annual Plant Availability Factor (NAPAF) : 85%

II. Normative Annual Plant Load Factor (NAPLF) : 85%

(2) GROSS STATION HEAT RATE (GHR)

Gross Station Heat Rate for existing generating stations of Delhi shall be as follows:

Table 4:Gross Station Heat Rate (GHR)

(3) AUXILIARY ENERGY CONSUMPTION

Auxiliary Energy Consumption shall be computed in two parts:

a) Fixed: 0.5% of the generation at normative PLF of the plant capacity which shall form

part of other expenses under Fixed Cost, at energy charge rate approved by the

Commission in respective Tariff Order.

b) Variable: 2.0% in Combined Cycle mode and 0.5% in Open Cycle mode of the actual

generation which shall form part of computation of energy charge rate of the

respective month.

Generating Station Combined Cycle Open Cycle

(kCal/ kWh)

1 Gas Turbine Power Station (GTPS) 2450 3125

2 Pragati Power Station I (PPS I) 2000 2900

Friday, 01 September 2017 Page 6 of 29

9. INCENTIVE

Incentive to a Generating Entity or unit thereof shall be payable at a flat rate of

25 Paisa/kWh for ex-bus scheduled energy corresponding to scheduled generation in

excess of ex-bus energy corresponding to Normative Annual Plant Load Factor

(NAPLF) as specified in Regulation 8(1) of these Regulations.

10. INCENTIVE SHARING MECHANISM FOR RE-FINANCING OF LOAN

(1) The incentive due to lower rate of interest on account of re-financing of loan in terms of

Regulation 71 of the DERC (Terms and Conditions for Determination of Tariff) Regulations,

2017 from FY 2017-18 to FY 2019-20 of the Generation Entity shall be computed as the

product of total quantum of loan availed and difference of weighted average rate of

interest on actual loans versus margin of 2.00%plus (+) SBI MCLR.

(2) The incentive on account of re-financing of loan computed as per sub clause (1) above

shall be shared equally between the Consumers and the Generation Entity.

11. Operational Norms for Rithala Combined Cycle Power Plant shall be the norms specified

in Regulation 7.3 of the Delhi Electricity Regulatory Commission (Terms and Conditions

for Determination of Generation Tariff) Regulations, 2007 for E/EA/EC/E2 Class Machine.

Friday, 01 September 2017 Page 7 of 29

BUSINESS PLAN FOR TRANSMISSION LICENSEE

12. RATE OF RETURN ON EQUITY

Determination of Tariff) Regulations, 2017 for Transmission Licensee shall be computed at

the Base Rate of 14.00% on post tax basis:

13. TAX ON RETURN ON EQUITY

The base rate of Return on Equity as allowed by the Commission under Regulation 10 of

these Regulations shall be grossed up with the Minimum Alternate Tax or Effective Tax

Rate of the respective financial year in terms of Regulation 72 and 73 of the DERC (Terms

and Conditions for Determination of Tariff) Regulations, 2017, as per the following

(i) In case of the Transmission Licensee paying Minimum Alternate Tax (MAT), say @

(ii) In case of Transmission Licensee paying normal Corporate Tax including surcharge

(a) Estimated Gross Income from Transmission Business for FY 2017-18 is, say Rs.

1000 Cr. and,

Effective Tax Rate for the year 2017-18 = 240/1000 = 0.24 or 24% and

14. MARGIN FOR RATE OF INTEREST ON LOAN :

Transmission Licensee shall be allowed as the difference in weighted average rate of

Friday, 01 September 2017 Page 8 of 29

15. OPERATION AND MAINTENANCE EXPENSES

(1) The Normative, Bay wise and Circuit kilometres wise, Operation and Maintenance

Expenses of a Transmission Licensee, including own consumption of energy for

Transmission Licensee’s installations and offices, shall be as follows:

Table 5: Bay wise Norms for HVAC (Rs. Lakh/bay)

Voltage Levels 2017-18 2018-19 2019-20

400kV 45.23 47.76 50.44

220kV & below 15.30 16.16 17.06

Table 6: Circuit km wise Norms for HVAC lines (Rs. Lakh/ckm.)

400kV 8.13 8.59 9.07

220kV 2.03 2.15 2.27

Transmission Licensees and shall be allowed by the Commission after prudence check at

the time of true up of ARR for the relevant financial year.

16. CAPITAL INVESTMENT PLAN

(1) The tentative Capital Investment Plan for the Transmission Licensee for FY 2017-18 to

Table 7:Capital Investment plan (in Rs. Cr.)

Details of scheme 2017-18 2018-19 2019-20

1 New Works

a Substations - - -

b Lines - - -

c Substations 132 267 618

d Lines 8 238 435

e=a+b+c+d Sub Total 140 505 1053

2 Automation Works

a 400 kV - - 20

b 220 kV - - 106

c=a+b Sub Total - - 126

Friday, 01 September 2017 Page 9 of 29

3 Augmentation Works

a 400 kV - 7 25

b 220 kV 37 298 71

c 66kV and below - 69 38

d=a+b+c Sub Total 37 374 134

4 Land Cost including Civil 27 27 27

5=1+2+3+4 Grand Total 204 906 1340

(2) The Capital investment and the respective scheduled date of commissioning, submitted

by the Transmission Licensee in the Annual Tariff Petition, shall form the basis for

computation of Annual Fixed Cost in terms of Regulation 111 of the DERC (Terms and

17. NORMS OF OPERATION FOR TRANSMISSION BUSINESS

(1) Normative Annual Transmission System Availability Factor (NATAF) for recovery of Annual

Fixed Charges for AC System shall be considered at 98%.

(2) Transmission System Availability shall be computed as per the formulae and methodology

specified in Appendices-I, II and III of these Regulations.

18. TRANSMISSION CHARGES FOR TRANSMISSION LICENSEEE

The Transmission Charges (inclusive of incentive) for AC system to be billed, in terms of

Regulation 112 to 115 of the DERC (Terms and Conditions for Determination of Tariff)

Regulations, 2017, for a calendar month for transmission system or part thereof shall be

computed as follows:

a) For TAFM ≤ 98%, AFC x (NDM/NDY) x (TAFM/98%)

b) For TAFM: 98% < TAFM < 99%,

AFC x (NDM/NDY) x (1)

c) For TAFM: 99% < TAFM ≤ 99.75%,

AFC x (NDM/NDY) x (TAFM/99%)

d) For TAFM ≥ 99.75%,

AFC x (NDM/NDY) x (99.75%/99%)

Friday, 01 September 2017 Page 10 of 29

AFC =Annual Fixed Cost specified for the year in Rupees

NATAF =Normative Annual Transmission availability factor, in per cent

NDM =Number of days in the month

NDY =Number of days in the year

TAFM =Transmission System availability factor for the month.

19. INCENTIVE SHARING MECHANISM FOR RE-FINANCING OF LOAN

2017 from FY 2017-18 to FY 2019-20 of the Transmission Licensee shall be computed as

the product of total quantum of loan availed and difference of weighted average rate of

interest on actual loans versus margin of 2.00%plus (+) SBI MCLR..

shall be shared equally between the Consumers and the Transmission Licensee.

Friday, 01 September 2017 Page 11 of 29

BUSINESS PLAN FOR DISTRIBUTION LICENSEE

20. RATE OF RETURN ON EQUITY

(1) Wheeling Business: Return on Equity in terms of Regulation 4(1) of the DERC

(Terms and Conditions for Determination of Tariff) Regulations, 2017 shall be

computed at the Base Rate of 14.00% on post tax basis.

(2) Retail Business: Return on Equity in terms of Regulation 4(1) of the DERC (Terms

and Conditions for Determination of Tariff) Regulations, 2017 shall be computed at

the Base Rate of 2.00% on post tax basis.

(3) Carrying Cost: Return on Equity in terms of Regulation 2(16) of the DERC (Terms

and Conditions for Determination of Tariff) Regulations, 2017 for computation of

weighted average rate of interest for funding of Regulatory Asset/accumulated

Revenue Gap through debt and equity shall be considered at 14.00% on pre-tax

(4) The Equity for the purpose of Return on Equity for Wheeling and Retail Business

shall be lower of the Normative Equity determined as per Regulation 63 of the

Delhi Electricity Regulatory Commission (Terms And Conditions For Determination

of Tariff) Regulations, 2017 or Equity available as per Audited Financial Statement

of the relevant year:

Provided that balance Equity left over after funding requirement of capitalisation as

per Audited Financial Statement shall be utilised towards funding of accumulated

Revenue Gap, if any.

21. TAX ON RETURN ON EQUITY

The base rate of return on equity as allowed by the Commission under Regulation

17(1) and Regulation 17(2) of these Regulations shall be grossed up with the

Minimum Alternate Tax or Effective Tax Rate of the respective financial year in

terms of Regulation 72 and 73 of the DERC (Terms and Conditions for Determination

of Tariff) Regulations, 2017, as per the following formula:

Rate of Return on Equity= 16/[(100-Tax Rate)/100]

Friday, 01 September 2017 Page 12 of 29

(i) In case of the Distribution Licensee paying Minimum Alternate Tax (MAT) say @

Rate of Return on Equity shall be = 16/[(100-20.96)/100] = 20.24%

(ii) In case of Distribution Licensee paying normal Corporate Tax including surcharge

(a) Estimated Gross Income from Distribution business for FY 2017-18, say is

Rs. 1000 Cr. and

Rate of Return on Equity shall be = 16/[(100-24)/100] = 21.05%.

22. MARGIN FOR RATE OF INTEREST ON LOAN

(1) Margin for rate of interest for the Control Period in terms of Regulation 4(2) of the

Distribution Licensee shall be allowed as the difference in weighted average rate of

approved base rate of return on equity for wheeling business i.e., 14.00%.

(2) The Distribution Licensees shall follow transparent mechanism to avail Loans and,

to the extent possible, shall endeavour to invite open tender for availing Loans.

23. OPERATION AND MAINTENANCE EXPENSES

Regulation 92 of the DERC (Terms and Conditions for Determination of Tariff)

Regulations, 2017 for the Distribution Licensees shall be as follows:

Table 8: O&M Expenses for BRPL for the Control Period Particulars Unit 2017-18 2018-19 2019-20

66 kV Line Rs. Lakh/ckt. km 3.454 3.648 3.853

33 kV Line Rs. Lakh/ckt. km 3.454 3.648 3.853

11kV Line Rs. Lakh/ckt. km 1.001 1.058 1.117

LT Line system Rs. Lakh/ckt. km 5.170 5.460 5.766

66/11 kV Grid S/s Rs. Lakh/MVA 0.933 0.986 1.041

33/11 kV Grid S/s Rs. Lakh/MVA 0.933 0.986 1.041

11/0.415 kV DT Rs. Lakh/MVA 2.209 2.333 2.464

Friday, 01 September 2017 Page 13 of 29

Table 9: O&M Expenses for BYPL for the Control Period Particulars Unit 2017-18 2018-19 2019-20

66 kV Line Rs. Lakh/ckt. km 4.421 4.669 4.931

33 kV Line Rs. Lakh/ckt. km 4.421 4.669 4.931

11kV Line Rs. Lakh/ckt. km 1.857 1.961 2.071

LT Line system Rs. Lakh/Ckt. km 8.290 8.756 9.247

66/11 kV Grid S/s Rs. Lakh/MVA 1.045 1.104 1.166

33/11 kV Grid S/s Rs. Lakh/MVA 1.045 1.104 1.166

11/0.415 kV DT Rs. Lakh/MVA 2.296 2.425 2.561

Table 10: O&M Expenses for TPDDL for the Control Period Particulars Unit 2017-18 2018-19 2019-20

66 kV Line Rs. Lakh/ckt. km 3.297 3.482 3.678

33 kV Line Rs. Lakh/ckt. km 3.297 3.482 3.678

11kV Line Rs. Lakh/ckt. km 0.862 0.910 0.961

LT Line system Rs. Lakh/ckt. km 6.372 6.730 7.107

66/11 kV Grid S/s Rs. Lakh/MVA 0.927 0.979 1.034

33/11 kV Grid S/s Rs. Lakh/MVA 0.927 0.979 1.034

11/0.415 kV DT Rs. Lakh/MVA 1.326 1.400 1.479

Table 11: O&M Expenses for NDMC for the Control Period Particulars Unit 2017-18 2018-19 2019-20

(2) The Distribution Licensees shall be allowed own (Auxiliary) consumption, at Zero

Tariff for actual recorded consumption subject to a maximum of 0.25% of total

sales to its retail consumers for the relevant financial year as part of O&M expenses

for the relevant year:

(3) Actual recorded own (Auxiliary) consumption in excess of 0.25% of total sales to its

retail consumers for the relevant financial year, shall be billed at Non Domestic

Tariff of respective year’s Tariff Schedule and shall form part of revenue billed and

collected for the same year.

(4) Impact of any statutory Pay revision on employee’s cost as may be applicable on

case to case basis shall be considered separately, based on actual payment made

by the Distribution Licensees and shall be allowed by the Commission after

prudence check at the time of true up of ARR for the relevant financial year.

Friday, 01 September 2017 Page 14 of 29

24. CAPITAL INVESTMENT PLAN

(1) The tentative Capital Investment Plan in terms of Regulation 4(4) of the DERC

(Terms and Conditions for Determination of Tariff) Regulations, 2017 for the

Distribution licensee shall be as follows:

Table 12: Capitalisation for BRPL for the Control Period (in Rs. Cr.)

Particulars 2017-18 2018-19 2019-20 Total

Capitalization 425 439 449 1313

Smart Meter 87 87 87 262

Less: Deposit Work 40 41 42 123

Total 472 485 494 1452

Table 13: Capitalisation for BYPL for the Control Period (in Rs. Cr.)

Capitalization 331 345 349 1025

Smart Meter 64 64 64 191

Less: Deposit Work 11 11 12 34

Total 384 398 401 1182

Table 14: Capitalisation for TPDDL for the Control Period (in Rs. Cr.)

Capitalization 423 414 414 1251

Smart Meter 66 66 66 198

Less: Deposit Work 50 50 50 150

Total 439 430 430 1299

(2) The Licensee shall submit the quarterly Capital investment plan along with

scheduled date of Commissioning in the Annual Tariff Petition for the relevant year,

which shall form the basis for computing the Fixed Cost in terms of Regulation 130

(c) of the DERC (Terms and Conditions for Determination of Tariff) Regulations,

(3) The Distribution Licensee shall submit an application including details of actual

Capitalisation on quarterly basis for physical verification and true up of capital cost

within 1 (one) month of the completion of the relevant quarter.

(4) The quarterly Capital Cost submitted by the Distribution Licensee as per aforesaid

sub-Regulation (3) shall be trued up by the Commission and financial impact on

account of variation in projected capital cost in the tariff order vis-a-vis actual

capital cost & scheduled date of commissioning vis-a-vis actual date of

commissioning shall be dealt under the Annual true up of relevant financial year as

Friday, 01 September 2017 Page 15 of 29

(a) Any excess tariff recovered on account of variation in projected

capitalization in the tariff order vis-a-vis trued up capitalization by more than

10% during the year, shall be adjusted in the Revenue Gap/Surplus of the

relevant year along with interest rate at 1.20 times of the bank rate

prevalent on 1st April of respective year:

Provided that any excess tariff recovered on account of variation in

projected capitalization in the tariff order vis-a-vis trued up capitalization

due to reasons beyond the control of the Distribution Licensee i.e., delay in

‘In-principle’ approval of the schemes, road cutting permission from the

concerned agencies etc., shall be adjusted in the Revenue Gap/Surplus of

the relevant year along with interest rate equal to bank rate prevalent on 1st

April of respective year.

(b) Any shortfall in tariff recovered on account of variation in projected

relevant year along with interest rate at 0.80 times of the bank rate

prevalent on 1st April of respective year.

25. TARGET FOR DISTRIBUTION LOSS

(1) The Distribution Loss target in terms of Regulation 4(9)(a) of the DERC (Terms and

Conditions for Determination of Tariff) Regulations, 2017 for the Distribution

licensees shall be as follows:

Table 15: Target for Distribution Loss for the Control Period

Sr. No. Distribution Licensee 2017-18 2018-19 2019-20

1 BSES Rajdhani Power Limited 10.93% 10.19% 9.50%

2 BSES Yamuna Power Limited 13.00% 11.69% 10.50%

3 Tata Power Delhi Distribution Limited 8.38% 8.19% 8.00%

4 New Delhi Municipal Council 10.30% 9.63% 9.00%

(2) The amount for Overachievement/Underachievement on account of Distribution

Loss target shall be computed as per the formula specified in the Regulation 159 of

the DERC (Terms and Conditions for Determination of Tariff) Regulations, 2017 for

the Distribution Licensee.

(3) Any financial impact due to Underachievement on account of Distribution Loss

target by the distribution licensee for the relevant year shall be to the account of

Friday, 01 September 2017 Page 16 of 29

distribution licensee as specified in Regulation 161 of the DERC (Terms and

(4) Any financial impact due to Overachievement on account of Distribution Loss target

by the distribution licensee for the relevant year shall be shared between the

Distribution Licensee and Consumers as follows:

i. in case actual Distribution Loss is between the loss target and loss target

minus [50%*(Previous Year Target-Current Year Target)] for the relevant year

shall be shared in the ratio of 2/3rd to Consumers and 1/3rd to the Distribution

ii. in case actual Distribution Loss is less than loss target minus [50%*(Previous

Year Target-Current Year Target)] for the relevant year shall be shared in the

ratio of 1/3rd to Consumers and 2/3rd to the Distribution Licensee.

Illustration.-

a) Sales (A) = 1000 MU

b) Previous Year Distribution Loss Target (B) = 12%

c) Current Year Distribution Loss Target (C) = 10%

d) Power Purchase allowed by the Commission in Tariff Order [D=A/(1-C)] = 1111 MU

e) Trued up Power Purchase Rate (E)= Rs. 5.00/kWh

CASE 1 [Actual Loss> Loss Target]

a) Actual Distribution Loss (F) = 12%

b) Actual Power Purchase done by the Distribution Licensee [G=A/(1-F)] = 1136 MU

c) The Distribution Licensee has under-achieved the Distribution Loss target from

10% to 12% resulting into procurement of additional 25 MU (G-D).

d) 100% Loss to Distribution Licensee = (25*5)/10 = Rs. 12.50 Cr.

CASE 2 [Loss Target>Actual>[Loss Target -50%*(Previous Year Target-Current Year Target)]

a) Actual Distribution Loss (F) = 9%

b) Actual Power Purchase done by the Distribution Licensee [G=A/(1-F)] = 1099 MU

c) The Distribution Licensee has Over-achieved the Distribution Loss target from

10% to 9% resulting into lesser procurement of additional 12 MU (G-D).

d) 1/3rd of Incentive to Distribution Licensee = (12*5)/10*(1/3) = Rs. 2 Cr.

Friday, 01 September 2017 Page 17 of 29

e) 2/3rd of Incentive to Consumers = (12*5)/10*(2/3) = Rs. 4 Cr.

CASE 3 [Actual<[Loss Target -50%*(Previous Year Target-Current Year Target)]

f) Actual Distribution Loss (F) = 8%

g) Actual Power Purchase done by the Distribution Licensee [G=A/(1-F)] = 1087 MU

Incentive up to overachievement of loss target minus [50%*(Previous Year Target-

Current Year Target)]

2/3rd of Incentive to Consumers = [(1111-1099)*5)/10]*2/3 = Rs. 4 Cr. ------- (i)

Balance 1/3rd to Distribution Licensee = [(1111-1099)*5)/10]*1/3 = Rs. 2 Cr.—(ii)

Incentive for overachievement less than loss target minus [50%*(Previous Year Target-

1/3rd of Incentive to Consumers = [(1099-1087)*5)/10]*1/3 = Rs. 2 Cr. ---------- (iii)

Balance 2/3rd to Distribution Licensee = [(1099-1087)*5)/10]*2/3 = Rs. 4 Cr. ---(iv)

Total incentive to Consumers (i) + (iii) = Rs. 6 Cr.

Total incentive to Distribution Licensee (ii) + (iv) = Rs. 6 Cr.

26. TARGET FOR COLLECTION EFFICIENCY

(1) The targets for Collection Efficiency for FY2017-18 to FY2019-20 of the Distribution

Licensees shall be 99.50%.

(2) The financial impact on account of Collection Efficiency target shall be computed as

per the formula specified in Regulation 163 of the DERC (Terms and Conditions for

Determination of Tariff) Regulations, 2017 for the Distribution Licensee.

(3) The financial impact on account of over-achievement in terms of Regulation 164 of

the Distribution Licensee, from 99.50% to 100% shall be shared equally between

Consumers and the Distribution Licensees.

27. TARGET FOR RENEWABLE PURCHASE OBLIGATION

(1) The targets for Renewable Purchase Obligation (RPO) in terms of Regulation 124 of

the DERC (Terms and Conditions for Determination of Tariff) Regulations, 2017 of a

Distribution Licensee from FY 2017-18 to FY 2019-20 shall be computed as a

percentage of total sale of power to its retail consumers in its area of supply

excluding procurement of hydro power. The target for Renewable Purchase

Obligation shall be as follows:

Friday, 01 September 2017 Page 18 of 29

Table 16: Targets for Renewable Purchase Obligation

1 Solar Target (Minimum) 2.75% 4.75% 6.75%

2 Total 11.50% 14.25% 17.00%

(2) The Distribution Licensee shall comply with its RPO through procurement of either

Solar energy or combination of Solar energy and Non-Solar energy with minimum

purchase of Solar energy as specified in the table above:

Provided that the Distribution Licensee may purchase solar energy in excess of the

minimum solar Target as specified in aforesaid sub-Regulation (1),

Provided further that the Distribution Licensee may purchase Renewable Energy

Certificate (‘REC’) for any shortfall in meeting their total RPO targets for any

financial year within three months from the date of completion of the relevant

financial year.

(3) Renewable Energy generation recorded through Renewable Energy meters

installed in the premises of net metering Consumers shall be deemed to be part of

RPO of the Distribution Licensee as specified in Delhi Electricity Regulatory

Commission (Net Metering for Renewable Energy) Regulations, 2014, for the

relevant year:

Provided that in case the annual generation from solar generation system

recorded through Renewable Energy meters exceeds the Capacity Utilisation

Factor (CUF) of 19%, the Distribution Licensee shall get the Renewable Energy

meters tested by Independent third party, National Accreditation Board for

Testing and Calibration Laboratories (NABL) accredited meter testing lab.

(4) The cost of Renewable Energy of purchased by the Distribution Licensee through

Power Purchase Agreement approved by the Commission and the total power

injected into the grid through net metering arrangement, in excess of RPO target

shall be part of power purchase cost of the Distribution Licensee for the relevant

(5) Non-compliance of the RPO targets by the Distribution Licensee shall attract

penalty at the rate of 10% of the weighted average Floor Price of Solar and Non-

Solar Renewable Energy Certificate, as specified by Central Electricity Regulatory

Commission for the relevant year, for quantum of shortfall in RPO.

(6) The amount of penalty imposed on the Distribution Licensee due to non-

Friday, 01 September 2017 Page 19 of 29

compliance of the RPO targets shall be reduced from the ARR during True up of the

relevant Financial Year in terms of the Regulation 124 of the DERC (Terms and

28. CONTINGENCY LIMIT FOR SALE OF POWER THROUGH DEVIATION SETTLEMENT

MECHANISM (UNSCHEDULED INTERCHANGE CHARGES)

(1) The Contingency Limit for disposing off of Power through Deviation Settlement

Mechanism in terms of the Regulation 152 (c) of the DERC (Terms and Conditions

for Determination of Tariff) Regulations, 2017 from FY 2017-18 to FY 2019-20 of the

Distribution Licensees shall be 5% of Net Power Procured by the Distribution

Licensee for the relevant month.

(2) In case the Distribution Licensee disposes off more than 5% of the net Power

procured by the Licensee for the relevant month through Deviation Settlement

Mechanism (Unscheduled Interchange Charges) than the rate of realisation

through UI shall be considered at the average rate of power purchase/sale through

exchange during same month for Delhi region.

29. INCENTIVE SHARING MECHANISM FOR SALE RATE OF SURPLUS POWER

(1) The computation of incentive for Sale Rate of Surplus Power in terms of the

Regulation 165 of the DERC (Terms and Conditions for Determination of Tariff)

Regulations, 2017 from FY 2017-18 to FY 2019-20 of the Distribution Licensees shall

be as follows:

i. The variable cost of the generating station for which power is surplus and

required to be sold through Power Exchanges shall be considered as the

previous month’s billed variable cost of such generating station.

ii. The variable cost of the generating station for which power is surplus and

required to be sold through Banking and Bilateral arrangements shall be

considered as the previous month’s billed variable cost of such generating

station prevalent at the date of entering into such contracts.

iii. The incentive shall be the product of Rate difference (Actual Sale Rate-

Variable Cost) and Quantum of Power actually sold.

(2) The incentive computed under sub-clause (1) above shall be shared between the

Consumers and the Distribution Licensees in the following prescribed manner: -

i. The incentive realisation upto 100% recovery of Average Fixed Cost per unit

Friday, 01 September 2017 Page 20 of 29

of all Generating sources of relevant year, projected by the Commission in

the relevant Tariff Order, prorated to actual sale of Surplus Power shall be

shared in the ratio of 2/3rd to the Consumers and 1/3rd to the Distribution

ii. The incentive realisation above 100% recovery of Average Fixed Cost per unit

shared in the ratio of 1/3rd to the Consumers and 2/3rd to the Distribution

Illustration:-

a) Quantum of Sale of Surplus Power (A) = 1000 MU

b) Applicable Variable Cost per Unit (B) = Rs. 2.00/kWh

c) Actual Sale rate of Surplus Power (C) = Rs. 3.50/kWh

d) Incentive [D=A*(C-B)] = Rs. 150 Cr.

e) Approved Average Fixed Cost per unit in the Tariff Order (E)= Rs. 1.00/kWh

Incentive realisation upto 100% recovery of Average Fixed Cost per unit = (E*A) =

Rs. 100 Cr. shall be shared in the ratio of 2/3rd (Rs. 67 Cr. ) to the Consumers and 1/3rd

(Rs. 33 Cr. ) to the Distribution Licensees.

Incentive realisation above 100% recovery of Average Fixed Cost per unit = [D-(E*A)] =

Rs. 50 Cr. shall be shared in the ratio of 1/3rd (Rs. 16.67 Cr. ) to the Consumers and 2/3rd

(Rs. 33.33 Cr. ) to the Distribution Licensees.

i. Total incentive to the Distribution Licensees = Rs. 66.33 Cr. (33+33.33)

ii. Total incentive to the Consumers = Rs. 83.67 Cr. (67+16.67)

30. MECHANISM FOR RECOVERY OF POWER PURCHASE COST ADJUSTMENT CHARGES

The mechanism for recovery of Power Purchase Cost Adjustment Charges (PPAC) in

terms of the Regulation 134 of the DERC (Terms and Conditions for Determination of

Tariff) Regulations, 2017 from FY 2017-18 to FY 2019-20 of the Distribution Licensees

shall be as follows:

(1) The Commission shall specify the detailed formula for computation of PPAC in the

Tariff Order for the relevant year.

(2) The Distribution Licensee shall compute the PPAC for any quarter as per the

Friday, 01 September 2017 Page 21 of 29

specified formula for that relevant year:

Provided that a quarter refers to one-fourth of a year i.e., January, February

and March (Q1); April, May and June (Q2); July, August and September (Q3);

and October, November and December (Q4).

(3) The PPAC computation of any quarter shall be equally spread and adjusted over

subsequent quarter only:

Provided that the Commission may allow to carry forward PPAC to more than

one quarter in order to avoid any tariff shock to consumers in terms of

Regulation 136 of the DERC (Terms and Conditions for Determination of

(4) The treatment of PPAC computation as per the specified formula shall be as

(a) in case PPAC does not exceed 5% for any quarter, the Distribution Licensee

may levy PPAC at 90% of computed PPAC with prior intimation to the

Commission without going through the regulatory proceedings.

(b) in case PPAC exceeds 5% for any quarter, the Distribution Licensee may levy

PPAC of 4.50% without going through the regulatory proceedings and shall

file an application for prior approval of the Commission for the differential

PPAC claim (Actual PPAC % – 4.50%).

(5) The Distribution Licensee shall upload the computation of PPAC on its website

before the same is levied in the consumers’ electricity bills.

(6) Revenue billed on account of PPAC by the Distribution Licensee, without going

through the regulatory proceedings, shall be trued up along-with the Power

Purchase Cost of the relevant year and no Carrying Cost shall be allowed due to

under-recovery of revenue for the same year.

(7) Revenue billed on account of PPAC by the Distribution Licensee, without going

Purchase Cost of the relevant year and Carrying Cost shall be at 1.20 times of

interest rate on the excess revenue recovered for the same year.

31. INCENTIVE SHARING MECHANISM FOR RE-FINANCING OF LOAN

(1) The incentive due to lower rate of interest on account of re-financing of loan in

terms of Regulation 71 of the DERC (Terms and Conditions for Determination of

Friday, 01 September 2017 Page 22 of 29

Tariff) Regulations, 2017 from FY 2017-18 to FY 2019-20 of the Distribution

Licensee shall be computed as the product of total quantum of loan availed and

difference of weighted average rate of interest on actual loans versus margin of

2.00% plus (+) SBI MCLR.

(2) The incentive on account of re-financing of loan computed as per sub clause (1)

above shall be shared equally between the Consumers and the Distribution

32. RATIO OF ALLOCATION OF ARR INTO WHEELING & RETAIL SUPPLY

The ratio of allocation of ARR into Wheeling & Retail Supply Business in terms of

the Regulation 4(9)(e) of the DERC (Terms and Conditions for Determination of

Tariff) Regulations, 2017 shall be as follows:

Table 17: Retail Business

Particulars BRPL TPDDL BYPL

Cost of Power Purchase 100% 100% 100%

Inter-State Transmission charges 100% 100% 100%

Intra-state Transmission charges 100% 100% 100%

SLDC fees and charges 100% 100% 100%

Operation & Maintenance Costs 40% 38% 38%

Depreciation (including AAD) 21% 23% 19%

Return on Capital Employed 26% 28% 28%

Income Tax 26% 28% 28%

Non Tariff Income 85% 60% 85%

Table 18: Wheeling Business

Operation & Maintenance Costs 60% 62% 62%

Depreciation (including AAD) 79% 77% 81%

Return on Capital Employed 74% 72% 72%

Income Tax 74% 72% 72%

Non Tariff Income 15% 40% 15%

33. TREATMENT OF REVENUE GAP/SURPLUS

(1) Various components of ARR of the Distribution Licensees shall be trued up in terms

of the Regulation 152 of the DERC (Terms and Conditions for Determination of

(2) Variation on account of projections of various components of ARR in annual tariff

order vis-a-vis trued up expenses for computation of Revenue Gap/Surplus shall be

as follows:

i. Power Purchase Cost: The variation in Power Purchase Cost shall be adjusted in

Friday, 01 September 2017 Page 23 of 29

the Revenue Gap/Surplus along-with Interest for half year as per Regulation 21

and Regulation 29 of these Regulations.

ii. Capital Cost: The variation in RoCE, Depreciation and Income Tax on account of

variation in Capital Cost related expenses shall be dealt as per Regulation 23 of

these Regulations.

(3) The Revenue Gap/Surplus computed as per aforesaid sub-Regulation (2) for the

trued up year shall be adjusted against the closing balance of accumulated Revenue

Gap for the relevant year:

Provided that if there is no accumulated Revenue Gap or any Surplus left after

adjusting against closing balance of accumulated Revenue Gap for the relevant

year, same shall be adjusted in the ARR.

34. Time Slots for Time of Day (ToD) Tariff

The Commission may, in terms of the Regulation 133 & 153 of the DERC (Terms and

Conditions for Determination of Tariff) Regulations, 2017 specify Time Slots for Time of

Day (ToD) Tariff through separate Order.

Friday, 01 September 2017 Page 24 of 29

MISCELLANEOUS

35. Issue of Regulations, Orders and Practice Directions: Subject to the provision of the Act

and these Regulations, the Commission may, from time to time, issue Orders and Practice

directions with regard to the implementation of these Regulations and procedure to be

followed on various matters, which the Commission has been empowered by these

Regulations to direct in matters incidental or ancillary thereto.

36. Powers to remove difficulties: If any difficulty arises in giving effect to any of the

provisions of these Regulations, the Commission may, by a general or special order, not

being inconsistent with the provisions of these Regulations or the Act, do or undertake to

do things or direct the Licensee to do or undertake such things which appear to be

necessary or expedient for the purpose of removing the difficulties.

37. Power of Relaxation: The Commission may in public interest and for reasons to be

recorded in writing, relax any of the provision of these Regulations.

38. Interpretation: If a question arises relating to the interpretation of any provision of these

Regulations, the decision of the Commission shall be final.

39. Saving of Inherent Powers of the Commission: Nothing contained in these Regulations

shall limit or otherwise affect the inherent powers of the Commission from adopting a

procedure, which is at variance with any of the provisions of these Regulations, if the

Commission, in view of the special circumstances of the matter or class of matters and for

reasons to be recorded in writing, deems it necessary or expedient to depart from the

procedure specified in these Regulations.

40. Enquiry and Investigation: All enquiries, investigations and adjudications under these

Regulations shall be done by the Commission through the proceedings in accordance with

the provisions of the Delhi Electricity Regulatory Commission Comprehensive (Conduct of

Business) Regulations, 2001 as amended from time to time.

41. Power to Amend: The Commission, for reasons to be recorded in writing, may at any time

vary, alter or modify any of the provision/(s) of these Regulations by amendment.

Surendra Edupghanti

(Secretary)

Friday, 01 September 2017 Page 25 of 29

Appendix-I Procedure for Calculation of Transmission System

Availability Factor for a Month

1. Transmission system availability factor for a calendar month (TAFM) shall be calculated by the respective transmission licensee, got verified by the concerned SLDC separately for each AC and HVDC transmission system and grouped according to sharing of transmission charges. Transmission System Availability shall be calculated separately for each Transmission System. For the purpose of calculation of TAFM: a. AC transmission lines: Each circuit of AC transmission line shall be considered as one

b. Inter-Connecting Transformers (ICTs): Each ICT bank (three single phase transformer together) shall form one element.

c. Static VAR Compensator (SVC): SVC along with SVC transformer shall form one element. However, 50% credit to inductive and 50% to capacitive rating shall be given.

d. Bus Reactors/Switchable line reactors: Each Bus Reactors/Switchable line reactors shall be considered as one element.

e. HVDC Bi-pole links: Each pole of HVDC link along with associated equipment at both ends shall be considered as one element.

f. HVDC back-to-back station: Each block of HVDC back-to-back station shall be considered as one element. If associated AC line is not available, the HVDC back-to-back station block shall also be considered as unavailable.

g. In case of outage of a transmission element affecting evacuation of power from a generating station, outage hours shall be multiplied by a factor of 2.

2. The Availability of AC and HVDC portion of Transmission system shall be calculated as under: % TAFM for AC system = n * AVn + p * Avp + q * Avq + r * Avr x 100

n+ p + q + r

Where n = Total number of AC lines. AVn = Availability of n number of AC lines. p = Total number of bus reactors/switchable line reactors AVp = Availability of p number of bus reactors/switchable line reactors q = Total number of ICTs. AVq = Availability of q number of ICTs. r = Total number of SVCs. AVr = Availability of r number of SVCs.

3. The weightage factor for each category of transmission elements shall be as under:

Friday, 01 September 2017 Page 26 of 29

(a) For each circuit of AC line – Surge Impedance Loading for Uncompensated line (SIL) multiplied by ckt-km. SIL rating for various voltage level and conductor configuration is given in Appendix-II. However, for the voltage levels and/or conductor configurations not listed in Annexure-I, appropriate SIL based on technical considerations may be used for availability calculation under intimation to long-term transmission customers/DICs. For compensated AC line, Surge Impedance Loading (SIL) shall be as certified by the SLDC considering the compensation on the line. For shunt compensated line the reduced value of SIL shall be taken in accordance with the location of the reactor. Similarly in case of the lines with series compensation the higher SIL shall be taken as per the percentage of compensation. (b) For each HVDC pole- The rated MW capacity * ckt-km (c) For each ICT bank – The rated MVA capacity (d) For SVC- The rated MVAR capacity (inductive and capacitive) (e) For Bus Reactor/switchable line reactors – The rated MVAR capacity. (f) For HVDC back-to-back station connecting two grids- Rated MW capacity of each block. 4. The availability for each category of transmission elements shall be calculated based on the weightage factor, total hours under consideration and non-available hours for each element of that category. The formulae for calculation of Availability of each category of the transmission elements are as per Appendix-III. 5. The transmission elements under outage due to following reasons shall be deemed to be available: i. Shut down availed for maintenance or construction of elements of another transmission scheme. If the other transmission scheme belongs to the transmission licensee SLDC may restrict the deemed availability period to that considered reasonable by him for the work involved. ii. Switching off of a transmission line to restrict over voltage and manual tripping of switched reactors as per the directions of SLDC. 6. Outage time of transmission elements for the following contingencies shall be excluded from the total time of the element under period of consideration: i. Outage of transmission elements due to force majeure events. The onus of satisfying

the SLDC that outage of transmission element was due to force majeure events shall rest with the Transmission Licensee.

ii. Outage caused by grid incident/disturbance not attributable to the transmission licensee, e.g. faults in substation or bays owned by other agency causing outage of the transmission licensee’s elements, and tripping of lines, ICTs, HVDC, etc. due to grid

Friday, 01 September 2017 Page 27 of 29

disturbance. However, if the element is not restored on receipt of direction from SLDC while normalizing the system following grid incident/disturbance within reasonable time, the element will be considered not available for the period of outage after issuance of SLDC’s direction for restoration.

Friday, 01 September 2017 Page 28 of 29

Appendix-II

SURGE IMPEDANCE LOADING (SIL) OF AC LINES

No. Line Voltage (kV) Conductor Configuration SIL (MW)

1 765 Quad Bersimis 2250

2 400 Quad Bersimis 691

3 400 Twin Moose 515

4 400 Twin AAAC 425

5 400 Quad Zebra 647

6 400 Quad AAAC 646

7 400 Triple Snowbird 605

8 400 ACKC(500/26) 556

9 400 Twin ACAR 557

10 220 Twin Zebra 175

11 220 Single Zebra 132

12 132 Single Panther 50

13 66 Single Dog 10

Friday, 01 September 2017 Page 29 of 29

Appendix-III

FORMULAE FOR CALCULATION OF AVAILABILITY OF EACH CATEGORY OF TRANSMISSION ELEMENTS

Availability of AC Lines (Avn) = i = 1n∑Wi (Ti - TNAi)

Ti i = 1n∑ Wi

Availability of ICT (Avq) = k = 1

q∑Wk (Tk - TNAk) Tk k = 1

Availability of Switched Bus Reactor (Avp) = m = 1

p∑Wm (Tm - TNAm) Tm m= 1

Availability of ICT (Avq) = k=1

q∑ Wk (Tk - TNAk)

Availability of SVC (Avr) = l=1r∑ 0.5 * WIL (TL - TNAL) + l=1

r ∑ 0.5 * WCL (TCL - TNACL) l=1r ∑ 0.5*

WIL + l=1r ∑ 0.5* WCL TIL

Where: Wi = Weightage factor for ith transmission line Wk = Weightage factor for kth ICT WIL & WCL = Weightage factors for inductive & capacitive

operation of lth SVC Wm = Weightage factor for mth bus reactor

Ti, Tm, Tk, TIL, TCL, - The total hours of ith AC line, kth ICT, lth SVC (Inductive Operation), lth SVC (Capacitive Operation), mth Switched Bus Reactor during the period under consideration.(excluding time period for outages not attributable to transmission licensee for reasons given in Para 6 of the procedure) TNAi, TNAk, TNAIL, TNACL, TNAm - The non-availability hours (excluding the time period for outages not attributable to transmission licensee taken as deemed availability as per Para 5 of the procedure) for ith AC line, kth ICT, lth SVC (Inductive Operation), lth SVC (Capacitive Operation),mth Switched Bus Reactor.

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