uttar gujarat vij company limited

Annual Performance Review for FY 2009-10

UTTAR GUJARAT VIJ COMPANY LIMITED 31

Table 26 : Treatment of Return on Equity

Rs in Lakhs

Sr. No. ParticularsFY 2009-10

(Approved)

FY 2009-10

(Apr-Sep)

FY 2009-10

(RE)

Gain/(Loss)

due to

Controllable

Factor

Gain/(Loss) due

to Uncontrollable

Factor

1 Return on Equity 9,043 4,159 8,538 505 -

3.17. Taxes

3.17.1. The tax implication for UGVCL in FY 2009-10 based on the revised estimate of

ROE has been calculated. The revised estimated for MAT at rate of 15.45% is

worked out to be Rs. 1,320 Lakhs as against the approved amount of Rs. 118

Lakhs approved by the Hon’ble Commission as shown below:

Table 27 : Provision for Taxes

Rs in Lakhs


(Approved)

FY 2009-10

(Apr-Sep)

FY 2009-10

(RE)

Gain/(Loss)

due to

Controllable

Factor

Gain/(Loss) due

to Uncontrollable

Factor

1 Provision for Tax / Tax Paid 118 10 1,320 - (1,202)

3.17.2. The Hon’ble Commission has not approved any Income Tax in the MYT order

citing that UGVCL has not asked for it. It is submitted that UGVCL, in para 5.10

in its MYT Petition has mentioned the applicability of Taxes as under:

“It has been assumed that Fringe Benefit Tax (FBT) shall be paid at 0.5% of the

total employee cost. Further, wherever the Discom is in surplus (including the

RoE component), income tax at the MAT rate of 11.33% has been assumed to

be payable by the company.”

3.17.3. It is submitted that Income Tax is a statutory expense, which should be allowed

without any deduction. Therefore, UGVCL request the Hon’ble Commission to

allow the same as uncontrollable loss without any deduction.

3.17.4. The revised estimate of taxes for FY 2009-10 against amount approved by the

Hon’ble Commission results into a net uncontrollable loss of Rs. 1,202 Lakhs as

indicated in the table above.

3.18. Non-Tariff Income for FY 2009-10

3.18.1. The revised estimate of Non-Tariff Income of UGVCL is Rs. 10,827 Lakhs as

against Rs. 4,288 Lakhs approved by the Hon’ble Commission resulting in a net

controllable gain of Rs. 6,539 Lakhs.



Table 28 : Non-Tariff Income for FY 2009-10

Rs in Lakhs


(Approved)

FY 2009-10

(Apr-Sep)

FY 2009-10

(RE)

Gain/(Loss)

due to

Controllable

Factor

Gain/(Loss) due

to Uncontrollable

Factor

1 Non-Tariff Income 4,288 1,495 10,827 6,539

3.19. Aggregate Revenue Requirement for FY 2009-10

3.19.1. Based on above expenses, table below summarises Aggregate Revenue

Requirement for FY 2009-10 for UGVCL in comparison with values approved by

the Hon’ble Commission.

Table 29 : Aggregate Revenue Requirement for FY 2009-10


(Approved)

FY 2009-10

(Apr-Sep)

FY 2009-10

(RE)Deviation

1 Cost of Power Purchase 331,784 186,423 434,109 (102,325)

2 Operation & Maintenance Expenses 32,197 19,139 39,796 (7,599)

2.1 Employee Cost 23,508 15,224 30,188 (6,680)

2.2 Repair & Maintenance 5,397 1,923 3,846 1,551

2.3 Administration & General Charges 3,292 1,992 5,762 (2,470)

3 Depreciation 9,356 6,084 12,710 (3,354)

4 Interest & Finance Charges 11,134 3,295 6,822 4,312

5 Interest on Working Capital 3,777 2,166 4,846 (1,069)

6 Other Debits 348 1,107 1,582 (1,234)

7 Extraordinary Items 33 46 92 (59)

8 Provision for Bad Debts 326 183 386 (60)

9 Net Prior Period Expenses / (Income) - 151 302 (302)

10 Other Expenses Capitalised (5,707) (1,694) (3,388) (2,319)

11 Sub-Total [1+2 +(3 to 10)] 383,248 216,901 497,257 (114,009)

12 Return on Equity 9,043 4,159 8,538 505

13 Provision for Tax / Tax Paid 118 10 1,320 (1,202)

14 Total Expenditure (11 to 13) 392,409 221,070 507,115 (114,706)

15 Less: Non-Tariff Income 4,288 1,495 10,827 (6,539)

16 Aggregate Revenue Requirement (14 - 15) 388,121 219,575 496,288 (108,167)

Rs in Lakhs

3.20. Sharing of Gains & Losses

3.20.1. MYT Regulations specifies the Mechanism for treatment of Gains and Losses

on account of Uncontrollable and Controllable expenses. The methodology

approved by the Hon’ble Commission for sharing of such gains/ losses is as

follows.

“Mechanism for pass through of gains or losses on account of uncontrollable

factors

• The approved aggregate gain or loss to the Generating Company or Licensee

on account of uncontrollable factors shall be passed through as an adjustment

in the tariff of the Generating Company or Licensee over such period as may be

specified in the Order of the Commission passed under Regulation 9.7 (a).



• Nothing contained in this Regulation 10 shall apply in respect of any gain or

loss arising out of variations in the price of fuel and power purchase which shall

be dealt with as specified by the Commission from time to time.

Mechanism for sharing of gains or losses on account of controllable factors

• The approved aggregate gain to the Generating Company or Licensee on

account of controllable factors shall be dealt with in the following manner:

(a) One-third of the amount of such gain shall be passed on as a rebate in

tariffs over such period as may be specified in the Order of the Commission

under Regulation 9.7;

(b) One-third of the amount of such gain shall be retained in a special reserve

by the Generating Company or Licensee for the purpose of absorbing the

impact of any future losses on account of controllable factors under clause (b)

of Regulation 11.2; and

(c) The balance amount of gain may be utilized at the discretion of the

Generating Company or Licensee.

• The approved aggregate loss to the Generating Company or Licensee on

account of controllable factors shall be dealt with in the following manner:

(a) One-third of the amount of such loss may be passed on as an additional

charge in tariffs over such period as may be specified in the Order of the

Commission under Regulation 9.7; and

• (b) The balance amount of loss shall be absorbed by the Generating Company

or Licensee.

3.20.2. As indicated above, UGVCL has identified all the expenditure heads under

controllable and uncontrollable categories. The gain/ losses arise as a result of

Annual Performance Review for FY 2009-10 for UGVCL shall be suitably passed

through the tariff as per mechanism specified by the Hon’ble Commission.

3.21. Sharing of Gains/ Losses for FY 2009-10

3.21.1. Based on the methodology prescribed in the Regulation, UGVCL has classified

various heads of expenses under Controllable & Uncontrollable factors. The

head wise losses have been dealt in above sections. During FY 2009-10, UGVCL

had incurred a net loss of Rs. 5535 Lakhs on account of controllable factors

while net losses attributed to uncontrollable factors for FY 2009-10 are Rs.

102632 Lakhs.



3.21.2. The following Table summarises net gain/ losses to the UGVCL during FY 2009-

10 on account of controllable & uncontrollable factors.

Table 30 : Net Gain/ Losses for FY 2009-10

Rs in Lakhs


(Approved)

FY 2009-10

(Apr-Sep)

FY 2009-10

(RE)

Gain/(Loss)

due to

Controllable

Factors

Gain/(Loss) due

to

Uncontrollable

Factors1 Cost of Power Purchase# 331,784 186,423 434,109 (15,162.7) (87,163)

2 Operation & Maintenance Expenses 32,197 19,139 39,796 (918) (6,680)

2.1 Employee Cost 23,508 15,224 30,188 - (6,680)

2.2 Repair & Maintenance 5,397 1,923 3,846 1,551 -

2.3 Administration & General Charges 3,292 1,992 5,762 (2,470) -

3 Depreciation 9,356 6,084 12,710 - (3,354)

4 Interest & Finance Charges 11,134 3,295 6,822 3,563 750

5 Interest on Working Capital 3,777 2,166 4,846 - (1,069)

6 Other Debits 348 1,107 1,582 - (1,234)

7 Extraordinary Items 33 46 92 - (59)

8 Provision for Bad Debts 326 183 386 (60) -

9 Net Prior Period Expenses / (Income) - 151 302 - (302)

10 Return on Equity 9,043 4,159 8,538 505 -

11 Provision for Tax / Tax Paid 118 10 1,320 - (1,202)

12 Less: Other Expenses Capitalised 5,707 1,694 3,388 - 2,319

13 ARR (1+2+(3 to 11)-12) 392,409 221,070 507,115 (12,073) (102,632)

14 Non - Tariff Income 4,288 1,495 10,827 (6,539) -

15 Total ARR (13-14) 388,121 219,575 496,288 (5,535) (102,632)

# Gain (Loss) on account of controllable Factors in case of Cost of power purchase has been worked out separately as

shown under paragraphs 3.6.9 and is over the gain / (Loss) on account of uncontrollable factors computed above.

3.22. Revenue for FY 2009-10

3.22.1. During the FY 2009-10, UGVCL has revised its estimate of revenue to Rs.

451,773 Lakhs as against Rs. 347,576 Lakhs as approved by the Hon’ble

Commission. For H1 of FY 2009-10, UGVCL has recovered revenue of Rs.

215,092 Lakhs. Based on the same, revenue is projected for H2 of FY 2009-10

considering same per unit realisation excluding FPPPA charges. PPPA charges

have been computed considering rate off Rs. 0.77 per kWh. In addition to the

same, the revised estimate of revenue has been considered for the purpose of

finding out the revenue gap for FY 2009-10 to be passed on to the consumers.

Table 31 : Revenue for FY 2009-10 Rs. in Lakhs


(Approved)

FY 2009-10

(Apr-Sep)

FY 2009-10

(RE)1 Revenue with Existing Tariff 285,837 182,986 386,277 2 Other Income (Consumer related) 8,362 3,286 8,271

3Total Revenue excluding subsidy

(1 + 2)294,199 186,272 394,548

4 Agriculture Subsidy 50,293 28,820 57,225 5 Other Subsidies 3,084 - -

6Total Revenue including subsidy

(3 + 4 + 5)347,576 215,092 451,773



3.23. Revenue Gap / Surplus for FY 2009-10

3.23.1. The Hon’ble Commission in its MYT Order has approved a total Aggregate

Revenue Requirement of Rs. 388,121 Lakhs for FY 2009-10.

3.23.2. As per mechanism specified in the MYT Regulation 2007, UGVCL proposes to

pass on 1/3rd of total gains/losses on account of controllable factors i.e. Rs.

1,845 Lakhs and total losses on account of uncontrollable factor i.e. Rs.

102,632 Lakhs to the Consumers. Adjusting these to the net Aggregate

Revenue Requirement, UGVCL has arrived at the Revised Aggregate Revenue

Requirement for FY 2009-10 of Rs. 492,598 Lakhs.

3.23.3. This revised Aggregate Revenue Requirement is compared against the revised

estimate of Income under various heads including Revenue with Existing Tariff

of Rs. 386,277 Lakhs, Other Consumer related Income of Rs. 8,271 Lakhs,

Agriculture Subsidies of Rs. 57,225 Lakhs, summing up to a Total Revenue of

Rs. 451,773 Lakhs. Accordingly, total Revenue Gap of UGVCL for FY 2009-10

after treatment of gains / losses due to controllable / uncontrollable factors is

computed at Rs. 40,825 Lakhs, which is being carried forward to the ARR of FY

2010-11 as depicted in the Table below:

Table 32 : Revenue Gap for FY 2009-10

Rs in Lakhs

Sr. No. Particulars FY 2009-10

1Aggregate Revenue Requirement originally

approved for FY 2008-09388,121

2Gain / (Loss) on account of Uncontrollable

factor to be passed on to Consumer (102,632)

3Gain / (Loss) on account of Controllable

factor to be passed on to Consumer (1/3rd of

Total Gain / Loss)

(1,845)

4Revised ARR for FY 2008-09

(1 - 2 - 3)492,598

5 Revenue with Existing Tariff 386,277

6 Other Income (Consumer related) 8,271

7Total Revenue excluding subsidy

(5+6)394,548

8 Agriculture Subsidy 57,225

9 Other Subsidies -

10Total Revenue including subsidy

(7 + 8 + 9)451,773

11Revised Gap after treating

gains/(losses) due to Controllable /

Uncontrollable factors (4 - 10)

40,825



3.23.4. The Hon’ble Commission is requested to approve above Annual Revenue

Requirement and allow UGVCL to pass and recover the Revised Revenue Gap

computed above in the Annual Revenue Requirement for FY 2010-11.



4. Aggregate Revenue Requirement for FY 2010-11

4.1. Preamble

4.1.1. This section outlines the Annual Revenue Requirement of the UGVCL for FY

2010-11, which takes into consideration:

• ARR filed by UGVCL for FY 2010-11 under the MYT petition;

• MYT Tariff Order for FY 2010-11 issued by the Hon’ble Commission dated

17th

January 2009 for UGVCL;

• Actual Performance in FY 2008-09;

• Performance FY 2009-10 (Projected);

• Provisions of GERC terms & conditions of Tariff Regulation, 2005;

4.2. Projection of Energy Requirement for FY 2010-11

4.2.1. Approach for Sales Projection

It has been observed from past experience that the historical trend method

has proved to be a reasonably accurate and well accepted method for

estimating the load, number of consumers and energy consumption. In light of

the above, UGVCL has estimated the above for various customer categories

primarily based on the CAGR trends during past years. Wherever the trend has

seemed unreasonable or unsustainable, the growth factors have been

corrected by the company, to arrive at more realistic projections.

4.2.2. Summary of Growth & Projections

The growth rates observed in the energy sold to each consumer category has

been analyzed for the purpose of sales projections for the FY 2010-11. The

analysis of the growth rate lends insight into the behavior of each category and

hence forms the basis of forecasting the sales for each category.

4.2.3. Category-wise Units Sold

The Break-up of the past sales and the CAGR growth rates for different periods

(5 years, 3 years and year on year) thereof are as follows. It may be noted that

the 5 year CAGR growth rate is for the period between 2005 & 2009 while the

3 year CAGR growth rate is for the period between 2007 & 2009. The year on

year (YoY) growth rate is for the period between 2008 & 2009. Further, the

growth witnessed between 2009 & 2010 based on FY 2009-10 projected

numbers has also been indicated.



Table 33 : Historical Trend in Category-wise Units sold

MUs

Sales FY04-05 FY05-06 FY06-07 FY07-08 FY08-09FY09-10

(Projeciton)

Low Tension Consumers

Residential 662 744 828 936 1,026 1,156

Commercial 194 225 247 296 350 403

Industrial LT 521 556 588 620 615 653

Public Water Works 308 343 365 376 404 425

Agriculture 5,017 5,444 5,707 5,837 6,085 6,547

Street Light 28 31 32 34 37 39

Temporary Supply at LT - - - - - -

LT Total 6,730 7,343 7,769 8,099 8,517 9,223

High Tension Consumers

Industrial HT 1,617 1,498 1,810 2,130 2,381 2,652

Railway Traction 12 11 11 11 12 12

HT Total 1,629 1,509 1,821 2,141 2,393 2,664

TOTAL 8,359 8,852 9,590 10,240 10,910 11,887

Table 34 : Category-wise Growth rates of Units Sold

Sales

CAGR

(5 year)

FY 09 over 05

CAGR

(3 year)

FY 09 over 07

FY 08 over

FY 07

FY 09 over

FY 08

FY 10 over

FY 09


Residential 11.58% 11.32% 13.0% 9.62% 12.67%

Commercial 15.90% 19.04% 19.8% 18.24% 15.14%

Industrial LT 4.23% 2.23% 5.4% -0.81% 6.18%

Public Water Works 7.02% 5.14% 2.9% 7.45% 5.20%

Agriculture 4.94% 3.25% 2.3% 4.25% 7.59%

Street Light 7.22% 6.72% 4.6% 8.82% 5.41%

Temporary Supply at LT 0.00% 0.00% 0.0% 0.00% 0.00%

LT Total 6.06% 4.70% 4.2% 5.16% 8.29%


Industrial HT 10.16% 14.69% 17.7% 11.78% 11.38%

Railway Traction 0.00% 4.45% 0.0% 9.09% 0.00%

HT Total 10.09% 14.63% 17.6% 11.77% 11.32%

TOTAL 6.89% 6.66% 6.8% 6.54% 8.96%

4.2.4. Consumer Profile

The Break-up of the category-wise number of consumers and the CAGR growth

rates for different periods (5 years, 3 years and year on year) are as follows:

Table 35 : Category-wise No. of Consumers

No. of Consumers FY04-05 FY05-06 FY06-07 FY07-08 FY08-09 FY09-10 (Projeciton)


Residential 1,445,926 1,504,935 1,569,817 1,723,720 1,859,775 1,990,331

Commercial 180,698 189,352 199,433 211,078 222,666 235,091

Industrial LT 25,047 26,396 27,836 29,279 30,849 32,490

Public Water Works 9,432 9,901 10,419 11,020 11,633 12,273

Agriculture 201,752 205,289 207,577 213,559 217,221 218,901

Street Light 5,825 6,059 6,509 6,967 7,506 8,049


LT Total 1,868,680 1,941,932 2,021,591 2,195,623 2,349,650 2,497,135


Industrial HT 1,211 1,296 1,440 1,622 1,750 1,955


HT Total 1,212 1,297 1,441 1,623 1,751 1,956

TOTAL 1,869,892 1,943,229 2,023,032 2,197,246 2,351,401 2,499,091



Table 36 : Growth rate of no. of Consumers

No. of Consumers

CAGR

(5 year)

FY 09 over 05

CAGR

(3 year)

FY 09 over 07

FY 08 over

FY 07

FY 09 over

FY 08

FY 10 over

FY 09


Residential 6.49% 8.84% 9.80% 7.89% 7.02%

Commercial 5.36% 5.66% 5.84% 5.49% 5.58%

Industrial LT 5.35% 5.27% 5.18% 5.36% 5.32%


Agriculture 1.86% 2.30% 2.88% 1.71% 0.77%

Street Light 6.54% 7.39% 7.04% 7.74% 7.23%


LT Total 5.89% 7.81% 8.61% 7.02% 6.28%


Industrial HT 9.64% 10.24% 12.64% 7.89% 11.71%


HT Total 9.63% 10.23% 12.63% 7.89% 11.71%

TOTAL 5.90% 7.81% 8.61% 7.02% 6.28%

4.2.5. Connected Load Profile

The Break-up of the connected load profile and the CAGR growth rates for

different periods (3 years and year on year) thereof are as follows.

Table 37 : Category-wise Connected Load

MW

Connected Load FY04-05 FY05-06 FY06-07 FY07-08 FY08-09FY09-10

(Projeciton)


Residential 763 821 925 1,044 1,127 1,271

Commercial 186 197 260 277 292 315

Industrial LT 523 531 544 579 613 640

Public Water Works 159 151 152 177 181 196

Agriculture 2,884 2,895 2,878 2,962 3,104 3,350

Street Light 15 16 17 19 20 22


LT Total 4,529 4,611 4,776 5,057 5,337 5,794


Industrial HT 582 567 643 709 814 877


HT Total 587 572 648 713 819 881

TOTAL 5,116 5,183 5,424 5,770 6,156 6,675

Table 38 : Growth Rate for Connected Load

Sales

CAGR

(5 year)

FY 09 over 05

CAGR

(3 year)

FY 09 over 07

FY 08 over

FY 07

FY 09 over

FY 08

FY 10 over

FY 09


Residential 11.58% 11.32% 13.0% 9.62% 12.67%

Commercial 15.90% 19.04% 19.8% 18.24% 15.14%

Industrial LT 4.23% 2.23% 5.4% -0.81% 6.18%


Agriculture 4.94% 3.25% 2.3% 4.25% 7.59%

Street Light 7.22% 6.72% 4.6% 8.82% 5.41%


LT Total 6.06% 4.70% 4.2% 5.16% 8.29%


Industrial HT 10.16% 14.69% 17.7% 11.78% 11.38%


HT Total 10.09% 14.63% 17.6% 11.77% 11.32%

TOTAL 6.89% 6.66% 6.8% 6.54% 8.96%



4.2.6. Growth Projections for FY 2010-11

This section discusses in detail the basis for taking the growth projections for

various categories of consumers as enumerated above. For projecting the

sales, no. of consumers and connected load for FY 2010-11, the base number

of FY 2009-10 is considered. Growth rates for individual categories have been

assumed and same has been applied to values of the FY 2009-10 to arrive at

the projection for FY 2010-11.

Residential

The company has witnessed a near double digit growth in the units sold in the

last few years to this category. The three year CAGR rate between FY 2007-08

and FY 2009-10 was 11.32% . The company expects this midterm trend to

continue for the FY 2010-11.

The number of consumers added in the category has witnessed a three year

CAGR of 8.84% between FY 2007-08 and FY 2009-10. The company expects this

trend to continue.

The connected load has been growing at a three year CAGR of 10.36% between

FY 2007-08 and FY 2009-10. The company expects this trend to continue for FY

2010-11.

The number of connections, unit sales and the load as estimated above have

been added to the projections based on the growth rates discussed above to

arrive at an estimate of the sales projections from this category.

Commercial

The three year CAGR growth rate recorded between FY 2006-07 and FY 2008-

09 for units sold to this category were 19.04% . The same has been assumed as

the growth rate for the FY 2010-11.

The three year CAGR growth rate recorded for the growth in consumers

between FY 2007-08 and FY 2009-10 was 5.66% . The same has been assumed

as the growth rate for the FY 2010-11.




10 for in the connected load was 5.97% which was on lower side for projection

of future years and because of that 8.00% growth rate for the FY 2010-11.

Industrial LT


10 for units sold to this category was 2.23% . The same has been assumed as






10 for growth in the connected load was 6.19% . The company expects the

same rate to continue for the FY 2010-11.

Public Lighting








10 for growth in the connected load was 9.79% . The same has been assumed


Agriculture

UGVCL, based on internal targets is planning to release around 1750 new

connections under this category. Accordingly, the additional connected load

expected in this category is around 22 MW based on norm of 17 HP per

connection. For calculation of sales, average consumption of unmetered and

metered consumers is considered. In Gujarat, the average consumption of

metered consumer is around 700 kWH/HP/Annum and consumption of



unmetered consumer is 1700 kWH/HP/Annum so for projection of sales for

additional connection, 1200 kWH/HP/Annum is taken. This would translate into

an additional consumption of around 36 MU (1200 kWH/HP/Annum).

Table 39 : New Connections to Agriculture Consumers

Release of Pending Agriculture Connections Unit FY 2010-11

Number of New Agriculture Connections Nos. 1750

Total Additional Units Supplied MU 36

Additional Load Added HP 29750

Additional Load Added MW 22

The number of connections, unit sales and the load as estimated above have

been added to the FY 2009-10 details to arrive at an estimate of the sales

projections from this category for FY 2010-11.

Public Water Works




The three year CAGR of growth in consumers has been 5.67% . The same has

been assumed as the growth rate for the FY 2010-11.


10 for growth in the connected load was 9.10% . The same has been assumed


Industrial HT


10 for units sold to this category was 14.69% while the long term 5 year CAGR

was 10.16% and the year on year growth stood at 11.38% . However, given the

past trends, a median value of 11.28% has been assumed as the growth rate

for the FY 2010-11.







10 for growth in the connected load was 12.54% while the long term 5 year

CAGR was 8.76% . The same rate of 8.76% has been considered for the FY 2010

-11.

Railway Traction

The company has witnessed a demand growth in the last three year of 0.00%

growth rate. The same growth has been assumed for the FY 2010-11.

The number of connections to the railways has remained at 1 for the past few

years and the same is not expected to change during the FY 2010-11.


10 for growth in the connected load was negative. So 0.00% growth has been

assumed in the FY 2010-11.

Thus the following table summarizes the growth rate assumptions and the

resultant projected numbers of the sales, number of consumers and connected

load within various tariff categories for FY 2010-11.

Table 40 : Projection of Sales, No. of Consumers and Connected Load

Sales (MU's)No. of

ConsumersLoad Sales (MU's)

No. of

ConsumersLoad


Residential 11.32% 8.84% 10.36% 1,286.82 2,166,362 1,403

Commercial 19.04% 5.66% 8.00% 479.72 248,407 340

Industrial LT 2.23% 5.27% 6.19% 667.55 34,203 680

Public Water Works 5.14% 5.67% 6.19% 446.83 12,968 208

Agriculture - Metered 3.77% 2.79% 2.81% 982.70 64,535 812

Agriculture - Un-Metered 0.00% 0.00% 0.00% 5,600.00 156,116 2,560

Street Light 6.72% 7.39% 9.79% 41.62 8,643 24

Temporary Supply at LT 0.00% 0.00% 0.00% - - -

LT Total 3.06% 7.77% 4.02% 9,505 2,691,235 6,027


Industrial HT 11.28% 10.24% 8.76% 2,951 2,155 954

Railway Traction 0.00% 0.00% 0.00% 12 1 4

HT Total 11.23% 10.23% 8.72% 2,963 2,156 958

TOTAL 4.89% 7.77% 4.64% 12,468 2,693,391 6,985

Consumer Category

Growth Rate FY 2010-11 Projections FY 2010-11

4.3. Estimation of Annual Revenue Requirement for the FY 2010-11

The components for the calculation of total expenses for FY 2010-11 are as

follow:



• Power Purchase Cost

• Operation & Maintenance Cost

• Interest on Loan and Financial Charges

• Interest on Working Capital

• Other Debits

• Extraordinary Items

• Provision for Bad Debts

• Other Expenses Capitalised

• Return on Equity

• Provision for Tax

4.4. Power Purchase Cost for the FY 2010-11

4.4.1. Approach for Calculation of Power Purchase Cost

To arrive at the energy requirement, the total demand in MUs as projected

above has been considered. This has been grossed up by factoring in

transmission and distribution losses to arrive at the gross demand for the

company. It may be noted that transmission losses are assumed as per the

revised estimates forming part of the APR for FY 2009-10 and Annual Revenue

Requirement Application being submitted by GETCO for the FY 2010-11. Once

the gross requirement is known, the purchase of units from each plant has

been arrived at by preparing a Merit Order for each year. Fixed cost for GSECL

has been taken as approved by the Hon’ble Commission for FY 2010-11 during

MYT order dated 17th

January, 2009 and variable cost is taken as per actual of

first six months (April to September) of FY 2009-10. For IPP and Central sector,

fixed cost and variable cost is taken as per actual of first six months (April to

September) of FY 2009-10.

4.4.2. Distribution Losses

The company has achieved a significant reduction in distribution losses, during

recent years. These efforts shall continue and will be enhanced. However, loss

reduction is a slow process and becomes increasingly difficult as the loss levels

come down. In view of this, it is assumed that the distribution loss in FY 2010-

11 would be maintained at the level of 15.00% against 14.00% approved by the

Hon’ble Commission. Approved and projected distribution loss for FY 2010-11

is as shown below:



Table 41 : Distribution Loss for the FY 2010-11

ParticularsFY 2010-11

(Approved)

FY 2010-11

(Projected)Distribution Loss 14.00% 15.00%

4.4.3. Energy Balance

The energy requirement for Company will be met by supply from GUVNL.

Based on the information provided above, Energy Balance of the Company for

the FY 2010-11 is as shown below:

Table 42 : Energy Balance for the FY 2010-11

S.No. Particulars UnitFY 2010-11

(Approved)

FY 2010-11

(Projected)1 Energy Sales MUs 11,958 12468

MUs 1947 2200

% 14.00% 15.00%3 Energy Requirement MUs 13905 14668

MUs 578 788% 3.99% 5.10%

5Total Energy to be input to

Transmission SystemMUs 14483 15456

6 Pooled Losses in PGCIL System MUs 183 151 7 Total Energy Requirement MUs 14666 15608

2 Distribution Losses

4 Transmission Losses

4.4.4. PPA (Capacity) Allocation Details

The company has been currently allocated following PPAs as per the allocation

scheme proposed by GUVNL. Out of the allocated capacities, some of the

stations listed below are not currently commissioned but are expected to come

online during the FY 2010-11.



Table 43 : PPA Allocation for FY 2010-11

Generating Stations Allocated Capacity

Ukai TPS 298

Ukai Hydro 76

Gandhinagar I to IV -

Gandhinagar V 63

Wanakbori I to VI 315

Wanakbori VII 157

Sikka TPS -

Kutch Lignite I to III 129

Kutch Lignite IV 8

Dhuvaran oil -

Kadana Hydro 24

Utran Gas Based -

Dhuvaran Gas Based - Stage-I 21

Dhuvaran Gas Based - Stage-II -

Utran Extension -

Sikka Extension -

ESSAR -

GPEC 77

GIPCL II (160) 48

GIPCL-SLPP 125

GSEG 36

GIPCL - I (145) -

GMDC - Akrimota 125

GSEG Expansion 105

GIPCL, Expansion 63

GSPC-Pipavav 175

NPC - Tarapur- 1&2 32

NPC - Kakrapar 52

NPC - Tarapur- 3&4 -

NTPC - KORBA 77

NTPC - VINDHYACHAL - I 62

NTPC - VINDHYACHAL - II 63

NTPC - VINDHYACHAL - III 70

NTPC - KAWAS -

NTPC - JHANOR -

NTPC - Kahalgoan -

NTPC - Sipat Stage - II -

SSNNL - Hydro 58

NTPC Kahalgaon (New) 12

NTPC North Karanpura -

Sipat Stage-I 108

Wind Farms (Old Policy) 7

Wind Farms (New Policy) 264

Tarini Infrastructure Limited 1

APPL 300

Aryan 20

Total 2,972

4.4.5. Merit Order Dispatch

In order to minimize the power purchase cost, company has worked out a

comprehensive Merit Order Dispatch (MOD) following the same principles as

per the previous Tariff Order from the dispatch available from its PPA allocated



generating stations. The NPC power plants and hydro power plants viz. SSNNL

Hydro, NPC Tarapur and Ukai Hydro have been considered as must-run power

plants and so they have been excluded from merit order calculations. The

dispatch from individual generating stations is worked out based on the merit

order of the variable cost of each generating unit.

4.4.6. Power Purchase cost for FY 2010-11

Based on the allocated capacities and the merit order stacking as described

above, the station wise power purchase quantum and costs are depicted below

for the FY 2010-11.



Table 44 : Power Purchase Cost for the FY 2010-11

UGVCL: Power Purchase for FY

2010-11 (Projected)

Capacity

Allocated to

Discom (MW)

Units

Available

(MU)

Units

Dispatched

(MU)

Fixed Cost

(Rs. Lacs)

Variable

Cost (Rs.

/Unit)

Variable Cost

(Rs. Lacs)

Incentive

(Rs. Lacs)

Total Cost

(Rs. Lacs)

Per Unit

Cost

(Rs./Unit)

Ukai TPS 298 1,755 1,755 10,646 1.70 29,845 - 40,491 2.31

Ukai Hydro 76 159 159 630 0.00 0 - 630 0.40

Gandhinagar I to IV - - - - - - - - -

Gandhinagar V 63 462 462 2,771 2.00 9,253 151 12,175 2.63

Wanakbori I to VI 315 2,134 2,082 10,945 2.16 44,930 314 56,189 2.70

Wanakbori VII 157 1,151 1,151 6,765 1.90 21,842 375 28,983 2.52

Sikka TPS - - - - - - - - -

Kutch Lignite I to III 129 714 714 9,895 1.01 7,242 - 17,137 2.40

Kutch Lignite IV 8 46 46 677 1.01 468 - 1,145 2.48

Dhuvaran oil - - - - - - - - -

Kadana Hydro 24 19 19 682 0.00 0 - 682 3.62

Utran Gas Based - - - - - - - - -

Dhuvaran Gas Based - Stage-I 21 163 49 989 2.54 1,244 45 2,278 4.66

Dhuvaran Gas Based - Stage-II - - - - - - - - -

Utran Extension - - - - - - - - -

Sikka Extension - - - - - - - - -

ESSAR - - - - - - - - -

GPEC 77 459 138 4,471 2.38 3,280 - 7,751 5.62

GIPCL II (160) 48 327 327 1,612 2.06 6,729 - 8,340 2.55

GIPCL-SLPP 125 739 739 7,773 1.12 8,278 - 16,051 2.17

GSEG 36 244 244 2,317 1.79 4,373 - 6,690 2.74

GIPCL - I (145) - - - - - - - - -

GMDC - Akrimota 125 739 739 11,471 0.95 7,022 - 18,492 2.50

GSEG Expansion 105 490 490 287 1.79 8,775 - 9,063 1.85

GIPCL, Expansion 63 380 380 4,380 1.75 6,647 - 11,027 2.90

GSPC-Pipavav 175 292 292 123 1.79 5,224 - 5,347 1.83

NPC - Tarapur- 1&2 32 202 202 - 0.96 1,934 - 1,934 0.96

NPC - Kakrapar 52 321 321 - 2.15 6,915 - 6,915 2.15

NPC - Tarapur- 3&4 - - - - - - - - -

NTPC - KORBA 77 497 497 2,512 0.76 3,779 - 6,291 1.27

NTPC - VINDHYACHAL - I 62 395 395 898 1.25 4,943 - 5,841 1.48

NTPC - VINDHYACHAL - II 63 411 411 3,107 1.23 5,054 - 8,160 1.99

NTPC - VINDHYACHAL - III 70 455 455 5,045 1.19 5,432 - 10,477 2.30

NTPC - KAWAS - - - - - - - - -

NTPC - JHANOR - - - - - - - - -

NTPC - Kahalgoan - - - - - - - - -

NTPC - Sipat Stage - II - - - - - - - - -

SSNNL - Hydro 58 72 72 - 2.05 1,471 - 1,471 2.05

NTPC Kahalgaon (New) 12 76 76 446 1.83 1,392 - 1,837 2.41

NTPC North Karanpura - - - - - - - - -

Sipat Stage-I 108 700 700 2,519 0.87 6,101 - 8,620 1.23

Captive Power Plant 10 10 10 - 2.76 289 - 289 2.76

Wind Farms (Old Policy) 7 14 14 - 1.75 249 - 249 1.75

Wind Farms (New Policy) 264 533 533 - 3.37 17,956 - 17,956 3.37

Tarini Infrastructure Limited 1 9 9 - 3.00 275 - 275 3.00

APPL 300 2,102 2,102 27,985 1.48 31,092 - 59,077 2.81

Aryan 20 23 23 353 0.21 47 - 401 1.77

Total 2,983 16,096 15,608 119,297 1.62 252,082 885 372,264 2.39



4.4.7. Transmission Charges

The transmission charges due to GETCO and PGCIL are given below. The

transmission charges to GETCO are calculated as per the proposed charges

from GETCO in the FY 2010-11.

Table 45 : Transmission Charges for the FY 2010-11

Rs in Lakhs

UGVCL2010-11

(Projected)

GETCO Charges 37,498

PGCIL Charges 6,192

Total Transmission Charges 43,689

4.4.8. GUVNL Cost

GUVNL is entrusted with the operation of supplying power to bulk licensees

and the overall coordination between its subsidiary companies. It also

undertakes the function of raising and managing the overall loan portfolio of

GUNVL and its subsidiaries. The revenue gap, if any, of GUVNL is also to be

recovered through the four Discoms.

For the purpose of projecting GUNVL’s revenue for the FY 2010-11, the existing

GERC approved tariff for the license, namely- Kandla Port Trust has been

considered. The employee expenses and A&G expenses of GUVNL have been

escalated by 8% year on year.

Further, as per the current projections of demand and supply, the four Discoms

shall have some surplus of energy during FY 2010-11, although this surplus is

likely to appear only in energy terms and not in MW terms i.e., the surplus is

likely to be during off peak hours only. However, it has been assumed that 10%

of the surplus being projected for a particular year shall be traded at marginal

cost plus a Rs. 0.04 per kWh trading margin. This has been included in the

projections of GUVNL’s expenses and revenues. Thus, the Discoms would be

able to recover some of the fixed cost they pay for their allocated capacity

from the revenues from trading.



Table 46 : GUVNL Cost for the FY 2010-11

Rs in Lakhs

GUVNL Cost Allocation2010-11

(Approved)

2010-11

(Projected)

Revenue

Revenue from sale of power to AECo +SECo - -

Revenue from sale of power to KPT 569 911

Revenue from sale of power to Others 146,646 1,170

Revenue from trade of Discom's Surplus 25,116 69,690

Other Income 14,603 16,174

Total Revenue from Sale of Power (A) 186,933 87,945

Expenditure

SLDC Fees & Charges 0 1

Power purchase cost as per PPA allocation 150,922 1,700

Average variable cost of Discom's surplus traded

power17,558 37,229

Employee Cost 1,846 2,440

Admin and General Expenses 1,141 851

Depreciation 862 128

Interest and Financial Charges 13,123 20,322

Share of E-Urja utilization charge 97 97

Total Expenses (B) 185,549 62,767

Amount of Cost Allocation (C=B-A) (1,384) (25,179)

GUVNL Cost Allocation

Based on the above, the actual revenue of GUVNL is sufficient to take care of

the expenses and accordingly, no cost is recoverable from the Discoms.

Accordingly, the allocation of GUVNL expenses for the FY 2010-11 is nil. Similar

treatment was offered by the Hon’ble Commission for the FY 2010-11 wherein

the estimated revenue was higher than the cost projected by the GUVNL.

Table 47 : GUVNL Cost allocation to Discoms for the FY 2010-11

GUVNL Cost Allocation

PGVCL UGVCL MGVCL DGVCL

Power Purchased (MUs) 20,979 15,608 8,077 11,846

% of Allocation 37.13% 27.62% 14.29% 20.96%

GUVNL Cost Allocated to Discoms (Rs. in Lakhs) - - - -

FY 2010-11

Further, GUVNL has taken the assets created for the end to end ERP solution,

EUrja, being implemented across all companies of GUVNL, on its books. The

recurring costs such as depreciation, interest payment on the loans for the

project and the Annual Maintenance Charges shall be allocated to the seven

companies (including GUVNL) in the percentage of the number of licenses

provided to each company for usage of the ERP package. The estimated annual

recurring cost and the company’s share are given below.



Table 48 : Annual Recurring Cost of E-Urja the FY 2010-11

Rs in Lakhs

Annual Recurring Charges2010-11

(Approved)

2010-11

(Projected)

Depreciation 2,826 2,826

Interest Cost 2,136 2,136

AMC 960 960

Total Annual Expenditure 5,923 5,922

Percentage of total licenses with the Company 17.66% 17.66%

Allocation to the Company 1,046 1,046

UGVCL

4.4.9. SLDC Fees & Charges

GERC has directed GETCO to file separate ARR for SLDC. As per GERC

Regulation No.5 of 2005 for “Levy and collection of fees and charges by SLDC

effective from date of Notification”, SLDC has proposed SLDC charges of 534.21

Rs./MW/Month and SLDC fees of 329.74 Rs./MW/Half Year. Based on net

capacity of 2,796 MW allocated to UGVCL, SLDC fees & Charges worked out

to be Rs. 198 Lakhs.

4.4.10. Total Power Purchase Cost

The total power purchase cost for the company for the FY 2010-11 comes to

the power purchase cost through merit order and Discom’s share of GUVNL

revenue gap, as shown below:

Table 49 : Total Cost of Power Purchase for the FY 2010-11

Rs in Lakhs


(Approved)

FY 2010-11

(Projected)Power Purchase Cost through Merit Order 327,488 372,264 Transmission Costs to PGCIL & GETCO 31,364 43,689

GUVNL + E-Urja Cost 1,046 1,046 SLDC Fees & Charges 0 198

Total Power Purchase Cost 359898 417197

4.5. Capital Expenditure

4.5.1. For FY 2010-11, UGVCL has projected to incur a Capital Expenditure of Rs.

29259 Lakhs against an approved amount of Rs. 34713 Lakhs by the Hon’ble

Commission. The scheme-wise projected capital expenditure vis-à-vis approved

by the Hon’ble Commission is as shown below:



Table 50 : Capital Expenditure Plan

Rs in Lakhs

Sr. No. SchemesFY 2010-11

(Approved)

FY 2010-11

(Projected)

A RE-PLAN

1 TASP [WELL] & PETA PARA 1795 1795

2 SCP [HB] 215 215

3 REC WELLS (SPA / OA / DARK ZONE ADIVASI

AREA SCHEME etc.)245 245

A - TOTAL 2255 2255

B RE-NON PLAN

1 TATKAL 0

2 BADP 45 45

3 RGGVY 4064 4064

4 ZOOPAD PATTI 590 590

5 APDRP 0

6 Urbun Development Scheme 1000 0

7 Energy Conservation 500 500

8 Independent Certification Agency 15 15

9 VDS / HVDS 1400 1400

10 Adivasi Area Scheme 0

B TOTAL 7614 6614

C DIST. SCHEME

1 KUTIR JYOTI 225 225

2 SI SCHEME 4400 4400

3 SI Scheme (Meter) 2200 2200

4 Load Sheding Transformer 500 500

5 ND SCHEME 6600 6600

6 JYOTIGRAM 325 325

7 Automatic P.F. Control Panel 1000 1000

8 ADB 0

9 Nirmal Gujarat 100 100

10 REPLACEMENT OF ASSETS 0

11 GE 14.91 TO 14.96 0

12 VIVEKADHIN 0

13 OTHERS 500 500

14 Hand Held Instruments 100 100

C TOTAL 15950 15950

D Other new Schemes

1 Arial Bunch Conductor/U.G. Cable 1620 1620

2 Automatic Meter Reading 40 40

3 GIS 660 660

4 Automation & Computerisation 320 320

5 Other Renovation work 1500 1500

6 Pending AG Connections (Golden Goal) 4454 0

7 Misc Civil Work 300 300

D TOTAL 8894 4440

GRAND TOTAL A+B+C+D 34713 29259

4.5.2. The details of various schemes under above Capital Expenditures proposed by

UGVCL during FY 2010-11 have been provided in Annexure – 1.



4.6. Funding of CAPEX

4.6.1. The funding of above mentioned Capital Expenditure is envisaged through

various sources categorised under four headings namely: Consumer

Contribution, Grants, Equity and Debt. The grants have been considered based

on the present budgeted figure available with the companies. The remaining

expenditure projected for FY 2010-11 are proposed to be funded through debt

and equity in the ratio of 70:30. The detailed breakup of funding of capital

expenditure during FY 2010-11 is mentioned below.

Table 51 : Funding Plan of Capital Expenditure

Rs in Lakhs


(Approved)

FY 2010-11

(Projected)

1 Capital Expenditure 34,713 29,259 2 Less : Consumer Contribution 5,841 5,852

3 Grants 7,943 7,035

4 Balance CAPEX 20,929 16,372

5 Debt @ 70% 10,692 11,461

6 Equity @ 30% 10,237 4,912

4.6.2. The details of the Interest and finance charges based on the above funding

plan have been discussed in details under paragraph 4.10 of the petition.

4.7. Operation & Maintenance Expenses

4.7.1. The O&M expenses for FY 2010-11 has been computed on basis of revised

estimates of FY 2009-10 and is consisting of Employee cost, Administration &

General Expenses and Repair and Maintenance expenses. The O&M expenses

for FY 2010-11 computed on the basis of revised estimates of FY 2009-10 are

as below along with the value approved by the Hon’ble Commission vide Multi

Year Tariff Order.

Table 52 : Proposed O&M Expenses for FY 2010-11

Rs in Lakhs


(Approved)

FY 2009-10

(RE)

FY 2010-11

(Approved)

FY 2010-11

(Projected)

1 Employee Cost 23,508 30,188 22,270 26,408

2 Repair & Maintenance 5,397 3,846 5,720 4,230

3 Administration & General Charges 3,292 5,762 3,490 6,223

4 Operation & Maintenance Expenses 32,197 39,796 31,480 36,860

4.7.2. The methodology deployed by the company for projection of Employee cost,

Administration & General Expenses and Repair and Maintenance expenses

have been dealt one by one in the subsequent paragraphs.



Employee Cost

Employee expenses include salaries, bonus, other benefits like medical

expense reimbursement, LTA, etc. and terminal benefits in the form of

pension, gratuity, leave encashment, staff welfare etc.

The Petitioner submits that the employee cost has been estimated considering

trend of past year’s employee cost, increase in dearness allowance, its merger

and its impact on other allowances such as HRA, field allowances, PF, CPF etc.

Additionally, increase in salary due to regular increments as well as promotion

has also been considered.

Considering the above, the percentage increase in employee cost has been

considered @ 8% on FY 2009-10 after excluding gratuity fund provision of Rs.

3238 Lakhs for calculation of employee cost of FY 2010-11.

The Petitioner humbly requests the Hon’ble Commission to approve the

proposed expenses of Rs. 26,408 Lakhs under Employee cost for the FY 2010-

11 without any disallowance.

Repair & Maintenance Expenses

Repairs & maintenance expenses are directly related to age of the assets, its

wear and tear during the period. Considering past trends, it is estimated that

the expenditure for the year 2010-11 will increase with the increasing vintage

of the assets which require periodical and higher repairs. Further, there is

sometimes need to undertake emergency repairs which have not been

provided for in the projections. Thus, these expenses are uncontrollable in

nature. The repairs and maintenance expenses have been escalated @ 10% on

the projected R&M expenses of FY 2009-10. The amount of R&M expenses for

FY 2010-11 is computed at Rs. 4,230 Lakhs, which lower than Rs. 5,720 Lakhs

actually approved by the Hon’ble Commission. UGVCL requests the Hon’ble

Commission to approve the proposed expenses of Rs. 4,230 Lakhs under

Repair and Maintenance for the FY 2010-11 without any disallowance.

Administration & General Expenses

Administration expenses mainly comprises of rents, telephone and other

communication expenses, professional charges, conveyance and travelling

expenses etc. It has been estimated that A&G expenses will increase @ 8% for

FY 2010-11. The estimated A&G expenses for FY 2010-11 computed at Rs.



6,223 Lakhs are higher than Rs. 3,490 Lakhs actually approved by the Hon’ble

Commission. UGVCL requests the Hon’ble Commission to approve the

proposed expenses of Rs. 6,223 Lakhs under A&G expenses for the FY 2010-11

without any disallowance.

4.8. Provision for bad and Doubtful Debts

4.8.1. Provision for bad & doubtful debts is considered at 0.10% of the revenue from

sale of power. It is a very legitimate expenditure which is associated with the

business risk and is a consumer related expense as the UGVCL is in a

distribution business. UGVCL accordingly, has computed Provision for Bad &

Doubtful Debts at Rs. 364 Lakhs.

Table 53 : Bad and Doubtful Debts for the FY 2010-11

Rs in Lakhs


(Approved)

FY 2009-10

(RE)

FY 2010-11

(Approved)

FY 2010-11

(Projected)

1 Provision for Bad Debts 326 386 357 364

4.9. Depreciation

4.9.1. The Gross Fixed Assets & Depreciation for FY 2010-11 has been computed on

basis of revised estimates of FY 2009-10. UGVCL has considered the Closing

Gross Block of Fixed Assets as in the Balance Sheet of FY 2008-09. The

provisional assets addition in FY 2009-10 has been considered to arrive at the

estimated Gross Block in the beginning of the FY 2010-11. The addition during

the FY 2010-11 has been projected considering projected capital expenditure

plan for FY 2010-11. Depreciation has been calculated taking into consideration

the opening balance of assets in the beginning of the year and the provisional

capitalisation. The GERC regulations specify that the CERC rates have to be

used for computation of the depreciation to be charged during the year. Earlier

the weighted average rate of depreciation by applying rates specified by CERC

was 3.63%. However, with the CERC notifying new rates for FY 2010-11

onwards, the same have been used for computation of the depreciation

charged during the year and the weighted average rate of depreciation works

out to 5.31%.The projected and approved depreciation for FY 2010-11 is as

shown below:



Table 54 : Depreciation for the FY 2010-11

Rs in Lakhs


(Approved)

FY 2009-10

(RE)

FY 2010-11

(Approved)

FY 2010-11

(Projected)

1 Gross Block in Beginning of the year 241,022 226,736 275,141 253,749

2 Additions during the Year (Net) 34,119 27,013 34,713 29,259

3 Depreciation for the Year 9,356 12,710 10,604 14,251

4 Average Rate of Depreciation 3.62% 5.28% 3.63% 5.31%

4.10. Interest on Loan

4.10.1. The interest expenditure on account of long-term loans depends on the

outstanding loan, repayments, and prevailing interest rates on the outstanding

loans. Further, the projected capital expenditure and the funding of the same

also have a major bearing on the long-term interest expenditure.

4.10.2. The Opening balance of Loan for FY 2010-11 amounts to Rs. 96,258 Lakhs as

against Rs. 88,702 Lakhs approved by the Hon’ble Commission. The normative

loan addition in FY 2010-11 is computed at Rs. 11,461 Lakhs as per the Capex

funding plan discussed in Section 4.6 above.

4.10.3. The repayment of loan has been computed assuming that 1/10th

portion would

be repaid in every Financial Year. The total repayment of existing and new loan

during the year is computed at Rs. 9,626 Lakhs.

4.10.4. The interest on the opening loans has been computed considering the

weighted average rate of interest for the last year @ 8.91%and @ 10.50% on

the new loans drawn during the year. The same works out to Rs. 8,746 Lakhs.

4.10.5. The figures of Interest on Security Deposit and Guarantee have been taken at

the same level as the projected figures of FY 2009-10. UGVCL submits that it

has been allocated some Govt. of Gujarat Guarantees, where it is required to

pay the guarantee charges. These are the legacy loans which have come from

the erstwhile GEB. These charges are, thus, beyond control of UGVCL and

hence require to be considered in the total financial cost.

4.10.6. The Interest and Finance Charges for FY 2010-11 computed on basis of revised

estimates of FY 2009-10 has been tabulated below.



Table 55 : Interest & Financial Charges for the FY 2010-11

Rs in Lakhs


(Approved)

FY 2009-10

(RE)

FY 2010-11

(Approved)

FY 2010-11

(Projected)

1 Opening Loans 88,353 92,869 88,702 96,258

2 Loan Additions during the Year 9,184 34,197 9,270 11,461

3 Repayment during the Year 8,835 30,808 8,870 9,626

4 Closing Loans 88,702 96,258 89,102 98,093 5 Average Loans 88,528 94,563 88,902 97,175

6 Interest on Loan 8,853 8,422 8,890 8,746

7 Interest in Security Deposit 1,985 2,446 2,109 2,446

7 Guarantee Charges 296 232 296 232

8 Total Interest & Financial Charges 11,134 11,100 11,295 11,424

4.10.7. It is submitted that the Interest and Finance Charges outlined in the above

table also has an element of Interest on Working Capital. In addition, in line

with the provisions of the Tariff Regulations, the licensee is also computing

interest on working capital on normative terms as prescribed under the

regulations. This leads to an issue of double accounting and additional burden

on the consumers. In order to take care of this anomaly, the company is

deducting the component relating to interest on working capital from the total

interest and finance charges given above. Considering interest on working

capital component same as of last year Rs. 4278 Lakhs, the interest and finance

charges being claimed by UGVCL for FY 2010-11 would be revised to Rs. 7,146

Lakhs.

4.11. Interest on Working Capital

4.11.1. The interest on working capital has been calculated based on the normative

working formula by the Hon’ble Commission in its Terms and Conditions of

Tariff Regulations. However, instead of considering Revenues for two months,

revenues of the company for only one month has been considered for

projecting the total working capital during the FY 2010-11.

4.11.2. According to Regulation 20 (v) (b), the Hon’ble Commission, in its Multi Year

Tariff Order on 17th

January, 2009 has taken the rate of interest on working

capital equal to the short-term prime lending rate of SBI as on 01/04/2004,

which was 10.25%. UGVCL has used the same rate of interest for computing

the interest on working capital for FY 2010-11 as shown below:



Table 56 : Interest on Working Capital for the FY 2010-11

Rs in Lakhs


(Approved)

FY 2009-10

(RE)

FY 2010-11

(Approved)

FY 2010-11

(Projected)

1 O & M expenses 2,683 3,316 2,623 3,072

2 Maintenance Spares 1,824 2,607 1,934 3,056

3 Receivables 323,343 41,357 34,790 39,832

4 Total Working Capital 327,850 47,280 39,347 45,959

5 Rate of Interest on Working Capital 10.25% 10.25% 10.25% 10.25%

6 Interest on Working Capital 33,605 4,846 4,033 4,711

4.12. Other Expense Items

4.12.1. There are two other minor items of costs, Other Debits and Extraordinary

Items which have been taken at Rs. 1,582 Lakhs and Rs. 92 Lakhs respectively,

which is at same level as the projected figures of FY 2009-10.

4.13. Other Expenses Capitalised

4.13.1. Under other expenses capitalised, capitalisation of O&M expenses is included.

UGVCL has projected Other Expenses Capitalised at Rs. 3,388 Lakhs which is at

the same level as the projected figures of FY 2009-10.

4.14. Return on Equity

4.14.1. As per the Tariff regulations issued by the Hon’ble Commission, a return @

14% on the equity base is considered as reasonable and hence allowed by

Hon’ble Commission. Accordingly, UGVCL has computed the Return on Equity

considering a rate of return at 14%.

4.14.2. The return on equity has been computed @ 14% on average equity based upon

the opening balance of equity and normative additions during the year, which

has been arrived at by considering 30% of the capital expenditure net of

consumer contribution and grants as funded from equity as already explained

in paragraph 4.6 above. Accordingly, the normative return on equity for FY

2010-11 is computed at Rs. 9,216 Lakhs as shown below:

Table 57 : Return on Equity for the FY 2010-11

Rs in Lakhs


(Approved)

FY 2009-10

(RE)

FY 2010-11

(Approved)

FY 2010-11

(Projected)

1 Opening Equity Capital 61,576 58,596 67,608 63,374

2 Equity Additions during the Year 6,032 4,778 6,279 4,912

3 Closing Equity 67,608 63,374 73,887 68,286

4 Average Equity 64,592 60,985 70,748 65,830

5 Rate of Return on the Equity 14% 14% 14% 14%

6 Return on Equity 9,043 8,538 9,905 9,216



4.15. Taxes

4.15.1. UGVCL has projected Income Tax on the MAT rate (i.e. 15.45 %) on the

normative Return on Equity (ROE) as computed above. Accordingly, Provision

for tax for FY 2010-11 is estimated at Rs. 1,424 Lakhs compared to an approved

amount of Rs. 111 Lakhs approved by the Hon’ble Commission. UGVCL

requests the Hon’ble Commission to approve the total amount of tax which

include Income Tax computed using MAT rate. It is also requested to the

Hon’ble Commission to pass on the impact of revised tax rates as per approved

budget by the Central Government.

4.16. Revenue Projections for Non-Tariff Income

4.16.1. The income in this category comprises of interest on loans & advances to

employees / contractors, income from investments with Banks, Delayed

Payment Surcharges from the Consumers etc. In the absence of any basis of

projection, UGVCL has escalated the Non-Tariff Income for FY 2010-11 by 6%

over the projected figures of FY 2009-10.

Table 58 : Non-Tariff Income for the FY 2010-11

Rs in Lakhs


(Approved)

FY 2009-10

(RE)

FY 2010-11

(Approved)

FY 2010-11

(Projected)

1 Total Non-Tariff Income 4,288 10,827 4,545 11,476

4.17. Aggregate Revenue Requirement for FY 2010-11

4.17.1. Based on above discussed expenses, the Aggregate Revenue Requirement for

FY 2010-11 has been determined as Rs. 477,979 Lakhs. As discussed in Section

3.23, UGVCL has determined a Revenue Gap of Rs. 40,825 Lakhs after treating

the losses incurred by it in FY 2009-10 on account of controllable and

uncontrollable factors. Thus, taking into account the above mentioned gap,

UGVCL proposes net Aggregate Revenue Requirement for FY 2010-11 as Rs.

518,805 Lakhs.

4.17.2. The Table below shows comparison of Aggregate Revenue Requirement

approved by the Hon’ble Commission in MYT order and the projection made by

UGVCL for FY 2010-11 on basis of revised estimates of FY 2009-10.



Table 59 : Proposed Aggregate Revenue Requirement for FY 2010-11


(Approved)

FY 2009-10

(RE)

FY 2010-11

(Approved)

FY 2010-11

(Projected)

1 Cost of Power Purchase 331,784 434,109 359,898 417,197

2 Operation & Maintenance Expenses 32,197 39,796 31,480 36,860

2.1 Employee Cost 23,508 30,188 22,270 26,408

2.2 Repair & Maintenance 5,397 3,846 5,720 4,230

2.3 Administration & General Charges 3,292 5,762 3,490 6,223

3 Depreciation 9,356 12,710 10,604 14,251

4 Interest & Finance Charges 11,134 6,822 11,295 7,146

5 Interest on Working Capital 3,777 4,846 4,033 4,711

6 Other Debits 348 1,582 366 1,582

7 Extraordinary Items 33 92 33 92

8 Provision for Bad Debts 326 386 357 364

9 Net Prior Period Expenses / (Income) - 302 - -

10 Other Expenses Capitalised (5,707) (3,388) (6,049) (3,388)

11 Sub-Total [1+2 +(3 to 10)] 383,248 497,257 412,017 478,815

12 Return on Equity 9,043 8,538 9,905 9,216

13 Provision for Tax / Tax Paid 118 1,320 111 1,424

14 Total Expenditure (11 to 13) 392,409 507,115 422,033 489,456

15 Less: Non-Tariff Income 4,288 10,827 4,545 11,476

16 Aggregate Revenue Requirement (14 - 15) 388,121 496,288 417,488 477,979

17

Revenue Gap in FY 2009-10 after treating gains

/(losses) due to Controllable/ Uncontrollable

Factor

40,825

18Revised Aggregate Revenue Requirement (16 +

17) 417,488 518,805

19 Revenue with Existing Tariff 307,407 364,397

20 Other Income (Consumer related) 9,056 8,914

21 Total Revenue excluding subsidy (19 + 20) 316,463 373,310

22 Agriculture Subsidy 47,594 55,651

23 Other Subsidies 3,359 -

24 Total Revenue including subsidy (21 to 23) 367,416 428,961

25 Gap / (Surplus) (18 - 24) 50,072 89,843

Rs in Lakhs

4.17.3. UGVCL request the Hon’ble Commission to approve the revised Aggregate

Revenue Requirement for FY 2010-11 without any disallowances.

4.18. Estimated Revenue Gap for FY 2010-11 based on existing Tariff

4.18.1. The estimated category wise revenue based on the existing tariff works out to

Rs. 364,397 Lakhs in FY 2010-11 is as shown in the table below.



Table 60 : Estimated Revenue at for FY 2010-11 at existing tariff

Rs. Lakhs

Approved Projected


Residential 38,659 41,339

Commercial 19,562 26,702

Industrial LT 32,752 36,573

Public Water Works 12,493 15,484

Agriculture 63,063 78,572

Street Light 1,436 1,694

LT Total 167,965 200,363


Industrial HT 138,838 163,318

Railway Traction 604 715

HT Total 139,442 164,033

TOTAL 307,407 364,397

Consumer CategoryRevenue FY 2010-11

4.18.2. The revenue from existing tariff as outlined in the above table is including the

PPPA Charges of Rs 0.77/kWh.

4.19. Revenue Projections for Other Consumer Related Income

4.19.1. The revenue from Other Consumer Related Income comprises of revenue on

account of charge imposed other than the basic charges applicable to the

Consumers. These include income on account of meter rent, wheeling charges,

Inspection charges and miscellaneous charges. In line with the methodology

adopted by the Hon’ble Commission in its MYT Order, UGVCL has projected its

Other Consumer related Income for FY 2010-11 by escalating the projected

figures of FY 2009-10 by the average increase in number of consumers during

FY 2010-11. The same is outlined in the table below:

Table 61 : Other Consumer related Income for the FY 2010-11 Rs in Lakhs


(Approved)

FY 2009-10

(RE)

FY 2010-11

(Approved)

FY 2010-11

(Projected)

1 Other Consumer related Income 8,362 8,271 9,056 8,914

4.20. Subsidy

4.20.1. As regards subsidy, it is assumed that the agricultural subsidy that was

received by the erstwhile GEB from the State Government will continue to be

received by the four Discoms i.e, UGVCL, PGVCL, DGVCL and MGVCL in

proportion to their respective percentage share in agricultural consumption.

The quantum of agricultural subsidy, however, has been considered at the

same level as past year i.e., Rs. 1100 Crores for the FY 2010-11. Accordingly,

the share of subsidy for the Discom is worked out as shown in the table below.



Table 62 : Subsidy for the FY 2010-11

Rs in Lakhs


(Approved)

FY 2010-11

(Projected)% Share in Unmetered Agriculture Sales 43.27% 50.59%

Share of Agriculture Subsidy 47594 55,651

Other Subsidies (Write back of C.C. / Grants) 3359 0

4.21. Total Revenue for the FY 2010-11

4.21.1. Based on the above, the total expected revenue of the company for the FY

2010-11 comprises of revenue from sale of power at existing tariff, other

consumer related income, Agriculture Subsidy and other subsidies. Total

revenue for the FY 2010-11 is as shown below:

Table 63 : Total Revenue for the FY 2010-11 Rs in Lakhs


(Approved)

FY 2010-11

(Projected)

1 Revenue with Existing Tariff 307,407 364,397 2 Other Income (Consumer related) 9,056 8,914

3 Agriculture Subsidy 47,594 55,651 4 Other Subsidies 3,359 -

5 Total Revenue including subsidy (1 to 4) 367,416 428,961

4.22. Estimated Revenue Gap for FY 2010-11

4.22.1. Based on the above, the estimated revenue gap for FY 2010-11 at existing tariff

is as outlined in the table below:

Table 64 : Estimated Revenue Gap for FY 2010-11 at existing tariff Rs in Lakhs


(Approved)

FY 2010-11

(Projected)

1 Revised Aggregate Revenue Requirement 417,488 518,805

2 Revenue with Existing Tariff 307,407 364,397

3 Other Income (Consumer related) 9,056 8,914

4 Total Revenue excluding subsidy (2 + 3) 316,463 373,310

5 Agriculture Subsidy 47,594 55,651

6 Other Subsidies 3,359 - 7 Total Revenue including subsidy (4 to 6) 367,416 428,961 8 Gap / (Surplus) (1 - 7) 50,072 89,843

4.22.2. As can be seen from the above, the estimated revenue gap for FY 2010-11 at

existing tariff is to the tune of Rs. 89,843 Lakhs. UGVCL request the Hon’ble

Commission to treat this revenue gap as a “Regulatory Asset” and permit its

recovery over a period no longer than three years.



5. Fuel and Power Purchase Cost Adjustment

5.1. Fuel and Power Purchase Cost Adjustment

5.1.1. The Hon’ble Commission has allowed Discoms / GUVNL to claim the increase in

the fuel price and power purchase cost according to the formula (approved in

June 2004) for increase in Fuel Price and Power Purchase cost (FPPPA) from its

customers. The formula approved by the Hon’ble Commission for the

calculation of FPPPA charges is reproduced below.

FPPPA = [FOG + PPP1 + PPP2] / [S.E.]

Where,

FOG Adjustment on account of variations in delivered cost of Fuel at

GEB’s (now GSECL) Thermal Power Stations Rs. Millions

PPP1 Adjustment on account of variable cost of power purchased in

Rs. Millions

PPP2 Adjustment on account of fixed cost of power purchased in Rs.

Millions

SE Saleable Energy in Million Units

5.1.2. Pursuant to reorganization and unbundling of erstwhile GEB into different

functional entities that is one generating company (GSECL), one transmission

company (GETCO) ad four Distribution Companies (DGVCL, MGVCL, PGVCL and

UGVCL). The power is purchased from different sources like GSECL, IPPs,

Central Sector Stations, through competitive bidding, CPPs and other

renewable sources. The entire power procurement by Discoms through GUVNL

is purchase of power from external sources as the generating stations of

erstwhile GEB is now owned and operated by the separate generating

company i.e. GSECL, for which Hon’ble Commission is determining tariff

through a separate tariff order. Hence, Discoms are required to make payment

to GSECL for purchase of power as per the Hon’ble Commission’s Order for

GSECL. Therefore, power purchase by GUVNL / Discoms from GSECL power

stations is also purchase of power like purchase of power from other sources.

Hence, it would not be appropriate to have separate fuel component for

increase in fuel cost of GSECL owned stations in FPPPA formula. It is therefore

requested to Hon’ble Commission to have only one component in the formula

for variation in power purchase price including power purchase from GSECL

owned stations.



5.1.3. It is to submit that all the generating stations from which GUVNL is purchasing

power, the cost for the same is determined / approved by the appropriate

Commissions like cost of power purchase from GSECL stations is determined by

the Hon’ble GERC, IPPs are governed by the provisions of PPAs, for central

generating stations the tariff is either determined by the Central Electricity

Regulatory Commission or Department of Atomic Energy in case of Nuclear

Power Plant and in case of Competitive Bidding, the tariff is adopted by the

GERC. The tariff for renewable sources is also determined by the Hon’ble

GERC. Therefore, the tariff for entire power purchased by GUVNL/Discoms is

determined/approved by the appropriate Commission and hence the entire

power procurement by GUVNL/Discoms is purchase of power only.

5.1.4. The incremental cost paid by the GUVNL/Discoms compare to base year for

purchase of power from various sources is to be recovered by Discoms as

Power Purchase Price Adjustment mechanism. The proposed formula for

calculation of per unit power purchase price adjustment charges is as follows:

PPPA = [(PPCA – PPCB)] / [1-LA]

Where,

PPCA Is the average power purchase cost per unit of delivered

energy, computed based on the operational parameters

approved by the Commission or principles laid down in

the power purchase agreements in Rs. / KWh for all the

generating stations who have supplied power in the

given quarter, calculated as total power purchase cost

billed in Rs. Million divided by the total quantum of

power purchase in million units made during the quarter.

PPCB Is the approved average base power purchase cost per

unit of delivered energy for all the generating stations

considered by the Hon’ble Commission for supplying

power to the company in Rs. / KWh, calculated as the

total power purchase cost approved by the Hon’ble

Commission in Rs. Million divided by the total quantum

of power purchase in million units considered by the

Commission;

LA Is the weighted average of the approved level of



Transmission and Distribution losses for the four Discoms

applicable for a particular quarter.

5.1.5. In the last MYT order of the Hon’ble Commission dated 17th

January, 2009, it

was mentioned that specific generating stations have been allocated to each of

Discoms. The fuel cost adjustment shall be specific to the stations allocated.

The cost increase in all generating stations of GSECL can not be pooled to claim

the fuel adjustment for the specific stations allocated. In this regard, it is to

humbly submit that the formula proposed above is more rational in current

scenario. In case, the Hon’ble Commission decide to calculate PPPA

Discomwise, then also the proposed formula is more appropriate and

rationale. However, to ensure uniform tariff across the State, it is requested to

approve the recovery of PPPA charges from the consumers across the State

considering all the Discoms together as proposed above.

5.1.6. For calculation of PPPA for FY 2010-11, the base rates approved by the Hon’ble

Commission vide multi year tariff order dated 17th

January, 2009 will be

considered. Same has been indicated below:

Table 65 : Base Power Purchase Prices for Calculation of PPPA for FY 2010-11

Sr.

No. Power Stations

Capacity

Fixed

Cost

Energy

Purchase

Variable

Cost

(MW)

(Rs.

Lakhs) (MU) (Rs/Kwh)

GSECL

1 Ukai TPS 850 24,478 4,879 1.5

2 Ukai Hydro 305 2,461 637 -

3 Gandhinagar I to IV 660 25,280 3,340 1.75

4 Gandhinagar V 210 9,087 1,540 1.47

5 Wanakbori I to VI 1,260 36,996 8,538 1.73

6 Wanakbori VII 210 9,018 1,540 1.64

7 Sikka TPS 240 10,396 1,408 1.99

8 Kutch Lignite I to III 215 16,115 1,190 1.07

9 Kutch Lignite IV 75 8,224 461 0.98

10 Dhuvaran oil 220 7,501 1,313 3.76

11 Kadana Hydro 242 6,816 190 -

12 Utran Gas Based 135 5,206 1,044 2.16

13 Dhuvaran Gas Based -

Stage-I 107 5,187 815 2.21

14 Dhuvaran Gas Based -

Stage-II 112 7,124 860 2.21

15 Utran Extension 375 17771 0 1.86

16 Sikka Extension - - -

Total of GSECL Plants 5216 191,660



Sr.

No. Power Stations Capacity

Fixed

Cost

Energy

Purchase

Variable

Cost

IPPs

17 ESSAR 300 11106 1224 2.01

18 GPEC 655 45919 2556 2.47

19 GIPCL II (160) 160 5136 953 1.72

20 GIPCL-SLPP 250 18071 1577 0.95

21 GSEG 156.1 11522 722 1.48

22 GIPCL - I (145) 41.6 922 0 2.17

23 GMDC - Akrimota 250 23841 1388 0.61

24 GSEG Expansion 350 958 18 2.12

25 GIPCL, Expansion 250 17520 1377 1.75

26 GSPC-Pipavav 360 986 23 2.12

Total of IPPs 2772.7 135981

Share from Central Sector

27 NPC - Tarapur- 1&2 160 0 1010 0.94

28 NPC – Kakrapar 125 0 803 2.03

29 NPC - Tarapur- 3&4 274 0 1822 2.73

30 NTPC – KORBA 360 9014 2474 0.57

31 NTPC - VINDHYACHAL - I 230 7464 1575 1.03

32 NTPC - VINDHYACHAL - II 239 10733 1636 0.98

33 NTPC - VINDHYACHAL - III 266 11982 1908 0.94

34 NTPC – KAWAS 187 10417 350 3.09

35 NTPC – JHANOR 237 11965 1544 1.73

36 NTPC - Kahalgoan 166 10005 1076 1.21

37 NTPC - Sipat Stage - II 273 0 1769 0.54

38 SSNNL – Hydro 231 0 288 2.05

39 NTPC Kahalgaon (New) 260 18221 1264 1.7

40 NTPC North Karanpura 77 5396 375 1.7

41 Sipat Stage-I 540 37843 3500 1.7

Total from central Sector 3625 133040

Captive Power Plant

41 CPP 329.38 2.14

Wind Farm

42 Wind Farm 724.5 24 1275 3.31

Bagasse Plants

43 Bagasse 15.9 15.9 98 3

Competitive Bidding

44 APPL 1000 91209 6482 1.479

45 Aryan 200 21866 519 0.2084

5.1.7. The PPPA, as calculated above in Rs. /KWh, will be recovered in the form of

power purchase price adjustment (PPPA) charge for every unit of the energy

consumption and will be forming a part of the energy bill to be served on

monthly/bimonthly or any other periodical basis. The implementation and



application of the formula and all other terms may continue to be as per the

Hon’ble Commission’s earlier order (approved in June 2004).



6. Prayer

UGVCL respectfully prays to the Hon'ble Commission;

1. The Hon’ble Commission is requested to condone delay in filing of this petition.

2. To admit this petition seeking Annual Performance Review for FY 2009-10 and to

Continue Existing Tariff for FY 2010-11.

3. To approve the Annual Performance Review for FY 2009-10 and allow sharing of

gains / losses with the Consumers as per sharing mechanism prescribed in the

MYT Regulations.

4. To approve Annual Revenue Requirement of FY 2010-11 based on results of

Annual Performance Review as requested in this petition and to allow its

recovery.

5. To approve methodology for recovery of Revenue Gap for FY 2010-11 as given in

the petition.

6. To recognize the revenue gap between the revised aggregate revenue

requirement for FY 2010-11 and the total revenues from the proposed tariff as

“Regulatory Asset” to be recovered through tariffs in future.

7. To approve the actual capital expenditure for the FY 2008-09 and revised capital

expenditure plan for FY 2009-10 & FY 2010-11.

8. To approve the formula proposed for calculation of PPPA charges.

9. The Hon’ble Commission is requested to consider approved parameters/ARR of

GSECL, GETCO and SLDC while finalizing tariff of UGVCL.

10. To grant any other relief as the Hon'ble Commission may consider appropriate.

The petitioner craves leave of the Hon'ble Commission to allow further

submissions, addition and alteration to this Petition as may be necessary from

time to time.

11. Pass any other order as the Hon’ble Commission may deem fit and appropriate

under the circumstances of the case and in the interest of justice.

Declaration that the subject matter of the petition has not been raised by the

petitioner before any other competent forum, and that no other competent forum

is currently seized of the matter or has passed any orders in relation thereto.



Annexure 1: Capital Expenditure Schemes for FY 2010-11

A brief description of the funding of the above mentioned schemes is given below:

Rural Electrification Scheme

TASP Wells and petapara: (Government Grant)

The company undertakes the work of rural electrification in Tribal areas under Tribal

Area sub plan financed by the state Govt. for electrification of virgin areas and also

extensive electrification in the areas already electrified earlier for providing such

electrification facilities in tribal areas. The State Government is providing the financial

assistance under TASP scheme. The scheme evolves of electrification of wells and

petaparas for different circles under UGVCL. It has been estimated to electrify 760+2379

= 3139 nos. of wells during the year 2009-10, with enhanced target. The proposed

expenditure for this works out to be Rs 911+ 2853 = 3764 lacs

Schedule Caste Sub Plan: (SCSP) (Govt. Grant)

It has been emphasized that whenever any village is electrified for all purpose, schedule

cast localities and other backward areas of main village and surroundings are also

covered. For such electrification of schedule cast localities, State Government is

allocating grant every year for implementing the programme under SCSP scheme.

It has been estimated that approximate 10100 schedule cast localities of UGVCL shall be

covered under this scheme involving for tentative expenditure of Rs 395 lakhs for the

year 2009-10

Kutir Jyoti Scheme: (Govt. grant)

This is also a similar scheme for benefiting the Tribal area. This is the grant scheme to be

given by Govt. of Gujarat. It is estimated that 23000 single phase connections in Tribal

area under Himatnagar and Palanpur circles will be covered under this scheme costing

for capital expenditure of Rs. 633Lakhs for the year 2009-10



Electrification of Hutments (Gen & SCSP): (Govt. grant)

This scheme is meant for electrification of hutments in certain slum areas situated in

and around Urban and Rural areas with a view to support and help socially,

economically and educationally weaker section of society, who are living in the

hutments. The scheme involves energisation of single point power supply to the

identified beneficiaries in consultation with local body. It has been proposed that during

the year 2009-10 to cover about 32000 nos. of Hutments situated in Sabarmati,

Mehsana, Himatnagar and Palanpur circles. Expenditure of about 1222 Lakhs for the

above scheme for the year 2009-10 is proposed. This expenditure will be granted by

Govt.

Normal Wells: (own fund)

As indicated earlier, over and above electrification of wells and petaparas in tribal

areas, normal RE works are also carried out for electrification of wells.. It has been

estimated that during 2009-10 there will be Rs. 1288+1016= 2304 lakhs expenditure for

electrification of 920 + 726 = 1646 wells, with enhanced target.

Centrally Sponsored Scheme

Rajiv Gandhi Gramin Vidyutikaran Yojna (RGGVY): (90% GOI Subsidy)

Govt. of India has launched the scheme RGGVY for rural electricity infrastructure and

house hold electrification for providing access to electricity to all households in five

years. The scheme envisages the provision of 66/11kv sub. station in rural areas,

electrification of rural households, intensive electrification of electrified villages and

habitations, additional distribution transformer centers etc.

Of the total capital outlay subsidy component is provided at 90%. However for the

project to be eligible for capital subsidy under the scheme, prior commitment of the

states shall be required for deployment of franchisees for the management of rural

distribution under the project. Under such arrangement non Governmental organization

(NGO’s), user’s Associations, cooperative association or individual Entrepreneurs, the

Panchayat Institutions would be associated as rural distribution franchisees. The

Franchisees arrangement could be for system beyond and including feeders from

substation or from including distribution transformers. The underlying basic purpose

would be to prevent the pilferage of power.

Considering the scope of work as envisaged in four circles a provisional out lay of Rs.

5635 lakhs has only been estimated for the year 2009-10 for about 1 lac nos of

connections.



Distribution Schemes

Normal Development Scheme (Non-Plan):

The company has to lay distribution lines up to installation of HT/LT consumers which

calls for considerable investment for laying HT/LT lines, service connection lines and

meters etc. For expansion of distribution system and considering the present year trend

of capital expenditure under this head of work it is proposed to make provision of 7080

lakhs for the year 2009-10.

Breakup of Capex under Normal Development Scheme:

S.N NORMAL DEVELOPMENT

SCHEME

2009-10 2010-11

Phy. Rs. Phy. Rs.

1. Lighting & Domestic 75000 2250 80000 2400

2. LT industrial connections 2500 1000 2500 1000

3. HT industrial connections 165 198 170 204 4. Agriculture shifting 510 332 500 325 5. Agriculture PDC to 600 420 600 420 6. Agriculture Extension of load 22000 2200 25000 2500

7. Water works 550 330 500 300

8. Turnkey maintenance KM 5000 150 5000 150 9. Other works 200 251 10. Total 106325 7080 114270 7550

System Improvement Scheme (Non- Plan, Non- Grant):

Every year new consumers are added to the distribution system and also existing

consumers are demanding for additional load in their demand. Hence the system

expansion is based on the consumer’s requirement rather than technical requirement.

This leads to increase the loading of existing system networks and requires to be

improved by providing bifurcating existing feeders, renovation of lines and up gradation

of system etc. during the year 2009-10 UGVCL has planned to expenditure of Rs. 45

crore.

Other New Schemes (Internal resources + grant)

Energy Conservation:

The Energy Conservation measures in the following areas are proposed for

implementation.

Replacement of existing Ag. Pump sets by Energy efficient pump sets:

A pilot project is implemented for replacement of existing poorly efficient pump sets of

farmers by EEPS to reduce the power demand in Ag.sector by the GOG. This project is

successfully implemented in Nine Talukas of North Gujrat under jurisdiction of UGVCL



during year 2008-09 and continued during 2009-10. The motto of the scheme is to

achieve 10% to15% energy saving.The scheme is implemented on tri party basis and the

project cost to be shared equally by the State Govt., UGVCL and Ag. Consumer, who is

willing to take the benefit of the scheme.

Total of Rs.24.54 Crores has been allocated to UGVCL for the FY 2009-10. The physical

target is 16200 nos. As per the latest reports of Nov-09, total 4987 EEPS has been

replaced during FY 2009-10.In the entire scheme 5394 EEPS has been replaced since

2008-09 and 2009-10.Total 51406 HP saved by installation of EEPS. Yearly energy saving

will be 87.39 MUs .Hence as per Ag tariff considering Rs.1700 / HP /Year energy saving

for 51406 HP would arrive at Rs.26.22 Crores. The payback period of the entire scheme

is 2.0 years.

Installation of APFC panels/HVDS (KHUSHY):

A project of installation of automatic power factor control panels in each distribution

transformer of Ag. Predominant rural feeders having high losses are proposed for

UGVCL. For improvement of P.F. OF 11 KV feeders, planning & actions are being taken

during the Year- 2009-10 for providing line Capacitors initially on 50 feeders having low

PF. This will compensate reactive energy & thereby augment the capacity & save

energy.

KHUSHY ( Kisan Hit Urja Shakti Yojna) is High voltage Distribution system by installing

smaller size of distribution transformers and thereby reduction of L.T lines up to

negligence level by converting it into HV line . To improve voltage profile in rural area

the small capacity of distribution transformers are to be installed by extending 11 KV

line as possible as nearer to the load and distribution transformer of the capacity of

10,16 KVA are erected and supply is released to consumer through a short length of LT

lines. The new Agriculture connections are released by adopting HVDS.

The proposed amount for either or combined both of the projects under the state Govt.

grant is Rs. 400 lacs.

Information, education and Communication (IEC)

For this programme the proposed amount under the state Govt. grant for various

measures on Energy conservation is Rs. 05 Lacs. The amount will be spent to educate all

categories of electricity consumers. This will help to build up the concept of Energy

saving among the general public. Under the project the various mass awareness

programmes such as seminars, exhibitions, workshops etc. to bring awareness in all

categories of consumers will be arranged at different locations throughout the state

from time to time. The stalls for Energy Conservation tips, Safety measure & micro drip



irrigation campaign were provided at Satlasana, Danta & Khedbrahma during Ambaji

Bhadarvi mela & also Unjha Mahotsav of Umiya Mataji, stall was provided at Unjha for

above said purpose during the period of 28th Nove-2009 to 2nd Dec-2009. Under the

publicity campaign printing of pamphlets, posters, banners, telecasting of short films on

TV, cable net work & on Radio, advertisement in print media, depicting hoardings

containing Energy saving messages/ slogans etc. will be carried out during the

celebration of “Energy Conservation Week.”



Annexure 2: Performance of UGVCL in FY 2008-09

Preamble

This section deals with the comparison of performance of UGVCL during FY 2008-09

with parameters approved by the Hon’ble Commission. As per MYT Regulations,

UGVCL needs to submit the comparison of the performance for FY 2008-09 with the

forecast approved by the Hon’ble Commission. The summary of the performance is

given in the subsequent paragraphs.

Category wise Sales and Revenue

The comparison of the actual category-wise energy sales and revenue with the sales

and revenue as approved by the Hon’ble Commission is given in the table below:

Table 66 : Category-wise Sales and Revenue

FY 2008-09

(Approved)

FY 2008-09

(Actual)

FY 2008-09

(Approved)

FY 2008-09

(Actual)

A LT Consumers

1 Residential 1,049 1,026 30,211 37,276 2 Commercial 326 350 15,876 19,758 3 Industrial LT 656 615 29,389 34,086 4 Public Water Works 398 404 11,025 14,278 5 Agriculture 5,835 6,085 62,435 113,179

6 Public Lighting 37 37 1,265 1,548 LT Total (A) 8,301 8,517 150,201 220,125

B HT Consumers7 Industrial HT 2,442 2,381 115,262 130,304

8 Railway Traction 11 12 604 727 HT Total (B) 2,453 2,393 115,866 131,030 Grand Total (A + B) 10,754 10,910 266,067 351,155

Particulars

Sales (MUs) Revenue (Rs. Lacs)

S.No.

Distribution Losses

In FY 2008-09, UGVCL has performed well in bringing down the distribution loss

levels. The UGVCL has achieved a distribution loss of 14.71% which is among the

lowest in comparison with such large size distribution utilities in other States of

India. The table below highlights the comparison of actual distribution losses

achieved by the UGVCL against that approved by the Hon’ble Commission vide its

Tariff Order.

Table 67 : Distribution Losses


(Approved)

FY 2008-09

(Actual)Distribution Loss 16.00% 14.71%



Energy Requirement and Energy Balance

Based on the above details relating to the sales and the distribution losses, the

summary of actual Energy Requirement and Energy Balance of UGVCL compared to

the approved numbers by the Hon’ble Commission has been depicted below:

Table 68 : Energy Requirement and Energy Balance

S.No. Particulars UnitFY 2008-09

(Approved)

FY 2008-09

(Actual)

1 Energy Sales MUs 10754 10910MUs 2048 1881% 16.00% 14.71%

3 Energy Requirement MUs 12802 12791

MUs 546 575% 4.09% 4.30%

5Total Energy to be input to

Transmission SystemMUs 13348 13366

6 Pooled Losses in PGCIL System MUs 196 1597 Total Energy Requirement MUs 13544 13525

2 Distribution Losses

4 Transmission Losses

Power Purchase Cost

The power purchase for meeting the demand of the consumers is done through

GUVNL which performs the function of a Bulk purchaser and supplier of power. The

Power purchase is carried out adopting the Merit Order Despatch Principles to

ensure economic purchase of power. The power purchase cost comprises of the

basic power purchase cost, allocation of the GUVNL cost and transmission charges

payable to GETCO and PGCIL. The details of the same are provided below.

Table 69 : Details of Power purchase cost

Rs in Lakhs


(Approved)

FY 2008-09

(Actual)Total Power Purchase Cost 298,069 372,033

Capital Expenditure for 2008-09

UGVCL had incurred total capital expenditure of Rs. 22,467 Lakhs during FY 2008-09.

Part of the funding of this Capital Expenditure was done through Consumer

Contribution and Grants. The remaining expenditure incurred during FY 2008-09 has

been funded through debt and equity. The detailed breakup of funding of capital

expenditure during FY 2008-09 is mentioned below.



Table 70 : Funding of Capital Expenditure for FY 2008-09


(Approved)

FY 2008-09

(Actuals)Deviation

1 Total Capital Expenditure for the Year 33,889 22,467 11,422 2 Consumer Contribution 5,391 5,717 (326) 3 Grants 9,175 5,402 3,773

4 Balance CAPEX for the Year 19,323 11,348 7,975 5 Debt 9,938 7,944 1,994 6 Equity 9,385 3,404 5,981

Rs in Lakhs

Aggregate Annual Revenue Requirement

Based on Annual Accounts for FY 2008-09, the performance of UGVCL has been

highlighted below as against Cost elements approved by the Hon’ble Commission.

Table 71 : Net Aggregate Revenue requirement for FY 2008-09


(Approved)

FY 2008-09

(Actuals)Deviation

1 Cost of Power Purchase 298,069 372,033 (73,964) 2 Operation & Maintenance Expenses 31,766 34,638 (2,872)

2.1 Employee Cost 23,569 25,807 (2,238) 2.2 Repair & Maintenance 5,091 3,496 1,595 2.3 Administration & General Charges 3,106 5,335 (2,229) 3 Depreciation 8,123 7,781 342 4 Interest & Finance Charges 10,987 7,581 3,406 5 Interest on Working Capital 3,435 4,114 (679)

6 Other Debits 332 1,582 (1,250) 7 Extraordinary Items 33 33 0 8 Provision for Bad Debts 293 - 293 9 Net Prior Period Expenses (386) 386

10 Other Expenses Capitalised (5,384) (4,723) (661)

11 Sub-Total [1+2 +(3 to 10)] 347,654 422,652 (74,998)

12 Return on Equity 8,215 7,965 250 13 Provision for Tax / Tax Paid 118 154 (36)

14 Total Expenditure (11 to 13) 355,987 430,771 (74,784) 15 Less: Non-Tariff Income 4,045 10,214 (6,169)

16 Aggregate Revenue Requirement (14 - 15) 351,942 420,557 (68,615) 17 Revenue with Existing Tariff 266,067 351,155 (85,088) 18 Other Income (Consumer related) 7,700 7,782 (82) 19 Total Revenue excluding subsidy (17 + 18) 273,767 358,937 (85,170) 20 Agriculture Subsidy 53,464 57,129 (3,665) 21 Other Subsidies 2,802 420 2,382 22 Total Revenue including subsidy (19 to 21) 330,033 416,486 (86,453) 23 Gap / (Surplus) (16 - 22) 21,909 4,071 17,838

Rs in Lakhs

Revenue Gap/Surplus for FY 2008-09

Based on the actual expenditure incurred during the year and the revenue accrued,

the revenue gap in FY 2008-09 is Rs. 4,071 Lakhs as against the approved gap of Rs.

21,909 Lakhs. The actual Revenue Gap for FY 2008-09 has been depicted below:



Table 72 : Revenue Gap/Surplus


(Approved)

FY 2008-09

(Actuals)Deviation

1 Aggregate Revenue Requirement 351,942 420,557 (68,615) 2 Revenue with Existing Tariff 266,067 351,155 (85,088) 3 Other Income (Consumer related) 7,700 7,782 (82) 4 Total Revenue excluding subsidy (2 + 3) 273,767 358,937 (85,170) 5 Agriculture Subsidy 53,464 57,129 (3,665) 6 Other Subsidies 2,802 420 2,382 7 Total Revenue including subsidy (4 to 6) 330,033 416,486 (86,453) 8 Gap / (Surplus) (7 - 1) 21,909 4,071 17,838

Rs in Lakhs



Annexure 3: Tariff Schedule for FY 2010-11

TARIFF SCHEDULE

TARIFF FOR SUPPLY OF ELECTRICITY AT LOW TENSION, HIGH TENSION, AND EXTRA

HIGH TENSION

GENERAL

1. The tariff figures indicated in this tariff schedule are the tariff rates payable by the

consumers of unbundled Distribution Licensees of the erstwhile GEB.

2. These tariffs are exclusive of Electricity Duty, tax on sale of electricity, taxes and

other charges levied by the Government or other competent authorities from time

to time which are payable by the consumers, in addition to the charges levied as per

the tariff.

3. All these tariffs for power supply are applicable to only one point of supply.

4. The charges specified are on monthly basis. Distribution Licensee may decide the

period of billing and adjust the tariff rate accordingly.

5. The energy supplied under these tariffs can be utilised only within the compact area

of the premises not intervened by any area/road belonging to any person or

authority other than the consumer.

6. Except in cases where the supply is used for the purpose for which the Distribution

Licensee has permitted lower tariff, the power supplied to any consumer shall be

utilised only for the purpose for which supply is taken and as provided for in the

tariff.

7. The above is without prejudice to the rights of the GERC to determine different

tariffs for such consumers as it may consider it expedient under the provisions of

Section 61 and Section 62 of the Electricity Act, 2003.

8. The meter charges shall be applicable as prescribed under ‘GERC (Licensee’s Power

to Recover Expenditure incurred in providing supply and other Miscellaneous

Charges) Regulations, 2005 as in force from time to time.

9. The Fuel Cost and Power Purchase Adjustment Charges shall be applicable in

accordance with the Formula approved by the Gujarat Electricity Regulatory

Commission from time to time.



10. Payment of penal charges for usage in excess of contract demand / load for any

billing period does not entitle the consumer to draw in excess of contract demand /

load as a matter of right.



PART - I

SCHEDULE OF TARIFF FOR SUPPLY OF ELECTRICITY

AT LOW AND MEDIUM VOLTAGE

1.0 RATE LFD-I (FOR RESIDENTIAL PREMISES):

This tariff will apply to services for lights, fans and small electrical appliances such as

refrigerators, cookers, heaters and small motors having individual capacity not

exceeding two BHP attached to domestic appliances in the residential premises.

Single-phase supply (aggregate load upto 6 kW)

Three-phase supply (aggregate load above 6 kW including small motive power load up

to 10 kW).

1.1 Fixed Charges/Month:

Range of Connected Load: (Other than BPL Consumers)

(a) Upto and including 2 kW Rs.5/- per month

(b) Above 2 to 4 kW Rs. 15/- per month

(c) Above 4 to 6 kW Rs.30/- per month

(d) Above 6 kW Rs.45/- per month

For BPL Household Consumers:

Fixed charges Rs.5/- per month

PLUS

1.2 Energy Charges: For the total monthly consumption: (Other than BPL

consumers)

(a) First 50 units 270 Paise per Unit

(b) Next 50 units 300 Paise per Unit

(c) Next 100 units 360 Paise per Unit

(d) Next 100 units 420 Paise per Unit

(e) Above 300 units 470 Paise per Unit



1.3 Energy charges: For the total monthly consumption – For the consumer below

poverty line (BPL)**


(b) For remaining units Rate as per LFD-I

**The consumer who wants to avail the benefit of the above tariff has to produce a

copy of the Card issued by the authority concerned at the sub-division office of the

Distribution Licensee. The concessional tariff is only for 30 units per month.

1.4 Minimum bill (excluding meter charges)

Payment of fixed charges as specified in 1.1 above.

2.0 RATE LFD-I (Rural):

This tariff will apply to services for residential premises located in areas within gram

panchayat as defined in the Gujarat Panchayats Act.

However, this will not apply to villages which are located within the geographical

jurisdiction of Urban Development Authority.

Single-phase supply (aggregate load upto 6 kW)

Three-phase supply (aggregate load above 6 kW including small motive power load up

to 10 kW)

2.1 Fixed Charges/Month:

Range of Connected Load: (Other than BPL Consumers)


(b) Above 2 to 4 kW Rs. 15/- per month

(c) Above 4 to 6 kW Rs.30/- per month


For BPL Household Consumers:

Fixed charges Rs.5/- per month



PLUS

2.2 Energy Charges: For the total monthly consumption: (Other than BPL

consumers)


(b) Next 50 units 250 Paise per Unit

(c) Next 100 units 310 Paise per Unit

(d) Next 100 units 370 Paise per Unit

(e) Above 300 units 430 Paise per Unit

2.2 Energy charges: For the total monthly consumption – For the consumer below

poverty line (BPL)**


(b) For remaining units Rate as per LFD-I (Rural)

**The consumer who wants to avail the benefit of the above tariff has to produce a

copy of the Card issued by the authority concerned at the sub-division office of the

Distribution Licensee. The concessional tariff is only for 30 units per month.

2.4 Minimum bill (excluding meter charges):


Note: If the part of the residential premises is used for non-residential (commercial)

purposes by the consumers located in rural area with population upto 10,000 as per

Census- 2001, entire consumption will be charged under this tariff.

3.0 RATE LFD-II (FOR COMMERCIAL PREMISES)

This tariff will apply to the services for the purposes specified in the rate LFD-I in respect

of commercial premises, such as shops, offices, banks, studio, storage, distribution

pumping stations, refilling of gas, oil and other material, Railway Stations, hostels,

laboratories, hospitals, telephone exchanges, infocom, broadcasting and telecasting

stations, training centres, public gardens, cinema theatres, drama theatres, video

parlours, public meeting house, recreation places, multiplexes, malls, workshop, hotels,

restaurants, showrooms, education institutes other than specified under LFD – III etc.



3.1 Fixed Charges:

Range of Connected Load:


(b) Above 2 to 4 kW Rs.100/- per month

(c) Above 4 kW to 6 kW Rs.150/- per month


PLUS

3.2 Energy charges:

(a) For the first 50 units per month 360 Paise per unit

(b) For the next 100 units per month 420 Paise per unit

(c) For the next 150 units per month 480 Paise per unit

(d) For the remaining units per month 490 Paise per unit

3.3 Minimum Bill (excluding meter charges):


4.0 RATE LFD-III

This tariff is applicable to the educational and other institutions registered with the

Charity Commissioner.

(a) Fixed charges Rs.45/- per month

(b) Energy charges 310 Paise per Unit

5.0 RATE-LTP

This tariff shall be applicable for motive power services

5.1 RATE LTP-I

This tariff is applicable for aggregate motive power load not exceeding 125 BHP.

5.1.1. Fixed charges per month:



For an installation having the contracted load upto 10 BHP Rs.22/- per BHP

For installation having contracted load exceeding 10 BHP:

(i) For first 10 BHP of contracted load Rs.22/- per BHP

(ii) For next 40 BHP of contracted load Rs.40/- per BHP

(iii) For next 25 BHP of contracted load Rs.65/- per BHP

(iv) For next 25 BHP of contracted load Rs.100/- per BHP

(v) Balance BHP of contracted load Rs.155/- per BHP

PLUS

5.1.2 Energy charges:

(a)

For installation having contracted load upto and including

10 BHP:

For entire consumption during the month

360 Paise per Unit

(b)

For installation having contracted load exceeding 10 BHP:

For entire consumption during the month 385 Paise per Unit

PLUS

5.1.3 Reactive Energy Charges:

For installation having contracted load of 50 BHP and above

for all reactive units (KVRAH) drawn during the month 10 Paise per KVARH

5.1.4 Minimum bill per installation per month for consumers other than Seasonal

Consumers:

(a) When contracted load is upto 75 BHP Rs.105 per BHP

(b) When contracted load exceeds 75 BHP Rs.180 per BHP

5.1.5 Minimum Bill Per Installation for Seasonal Consumers

(a) “Seasonal Consumer”, shall mean a consumer who takes and uses power supply

for ice factory, ice candy machines, ginning and pressing factory, oil mill, rice mill, huller,

salt industry, sugar factory, khandsari, cold storage plants (including such plants in

fisheries industry), tapioca industries manufacturing starch, etc.

(b) Any consumer, who desires to be billed for the minimum charges on annual basis

shall intimate to that effect in writing in advance about the off-season period during

which energy consumption, if any, shall be mainly for overhauling of the plant and



machinery. The total period of the off-season so declared and observed shall be not less

than three calendar months in a calendar year.

(c) The total minimum amount under the head “Fixed and Energy Charges” payable

by the seasonal consumer satisfying the eligibility criteria under sub-clause (a) above

and complying with the provision stipulated under sub-clause (b) above shall be

Rs.1200/- per annum per BHP of the contracted load for the installation having the

contracted load upto 75 BHP, and Rs.2000/- per annum per BHP when contracted load is

exceeding 75 BHP.

(d) The units consumed during the off-season period shall be charged for at a flat

rate of 400 Paise per unit.

(e) The electricity bills related to the off-season period shall not be taken into

account towards the amount payable against the annual minimum bill. The amount paid

by the consumer towards the electricity bills related to the seasonal period only under

the heads “Fixed Charges” and “Energy Charges”, shall be taken into account while

determining the amount of short-fall payable towards the annual minimum bill as

specified under sub-clause (c) above.

5.2 RATE LTP-II

This tariff shall be applicable to educational institutions and research and development

laboratories for motive power services where machines and appliances are primarily

used for demonstration/research purposes only.

5.2.1 Energy Charges

For all units consumed during the month 400 Paise per Unit

NOTE:

The educational institutions and research laboratories will have an option to either

select of the rate LTP-I with minimum charges or rate LTP-II without minimum charges.

The option can be exercised to switch over from LTP-I tariff to LTP-II and vice versa twice

in a calendar year by giving not less than one month’s notice in writing.



5.3 RATE LTP-III

This tariff shall be applicable to consumers using electricity for motive power services

for minimum contract demand of 20 kW and up to 100 kW at low voltage.

5.3.1 Fixed charges:

(a) For billing demand upto the contract demand

(i) For first 20 to 40 kW of billing demand Rs.65/- per kW per month

(ii) Next 20 kW of billing demand Rs.100/- per kW per month

(iii) Above 60 kW of billing demand Rs.165/- per kW per month

(b) For billing demand in excess of the contract

demand Rs.210/- per kW

PLUS


For the entire consumption during the month 405 Paise per Unit

PLUS


For all the reactive units (KVARH) drawn during the month 10 Paise per KVARH

5.3.4 Billing Demand

The billing demand shall be highest of the following, rounded to the next full kW:

(a) Eighty-five percent of the contract demand

(b) Actual maximum demand registered during the month

(c) 20 kW

5.3.5 Minimum Bill

Payment of demand charges every month based on the billing demand.



NOTE:

1. This tariff shall be applicable if the consumer so opts to be charged in place of LTP-I

Tariff.

2. The option can be exercised to switch over from LTP-I tariff to LTP-III tariff and vice

versa twice in a calendar year by giving not less than one month’s notice in writing.

3. Consumer has to provide metering system in the event when proper metering

system is not provided by Distribution Licensee.

4. In the event of actual maximum demand exceeds 100 kW more than three occasions

during the period of six months, the consumer has to provide his distribution

transformer at his cost and maintain at his cost.

5.4 RATE LTP-IV

This tariff is applicable for aggregate motive power load not exceeding 125 BHP and

using electricity exclusively during night hours from 10.00 PM to 06.00 AM next day.

(The supply hours shall be regulated through time switch to be provided by the

consumer at his cost.)

5.4.1 Fixed Charges per month:

Fixed charges specified in RATE LTP-I above.

PLUS

5.4.2 Energy Charges:



For contract load of 50 BHP and above: For all

reactive units (KVARH) drawn during the month 10 Paise per KVARH

NOTE:

1. 10% of total units consumed and 15% of the contract load can be availed beyond the

prescribed hours for the purpose of maintenance.

2. For the purpose of office lighting, fans etc. the consumer may apply for a separate

connection.



3. This tariff shall be applicable if the consumer so opts to be charged in place of LTP-I

tariff by using electricity exclusively during night hours as above.

4. The option can be exercised to switch over from LTP-I tariff to LTP-IV tariff and vice


5. In case the consumer is not fulfilling the conditions of this tariff category, then such

consumer for the relevant billing period will be billed under tariff category LTP-I.

5.5 RATE LTP-IV (A)

This tariff is applicable to consumers using electricity for motive power services for

minimum contract demand of 20 kW and upto 100 kW at low voltage and using

electricity exclusively during night hours from 10.00 PM to 06.00 AM next day. The

supply hours shall be regulated through time switch to be provided by the consumer at

his cost.

5.5.1 Fixed Charges per month:

Fixed charges specified in RATE LTP-III above.

PLUS




For all reactive units (KVARH) drawn during the

month 10 Paise per KVARH

NOTE:

1. 10% of total units consumed and 15% of the contract demand can be availed beyond

the prescribed hours for the purpose of maintenance.


connection.

3. This tariff shall be applicable if the consumer so opts to be charged in place of LTP-III




4. The option can be exercised to switch over from LTP-III tariff to LTP-IV(A) tariff and

vice versa twice in a calendar year by giving not less than one month’s notice in

writing.


consumer for the relevant billing period will be billed under tariff category LT-III.

5.6 RATE LTP-V

Applicable for supply of electricity to Low Tension Agricultural consumers contracting

load up to 125 BHP requiring power supply for lifting water from surface water sources

such as cannel, river, & dam and supplying water directly to the fields of farmers for

agricultural irrigation only.

(a) Fixed charges per month Rs. 25/- per BHP

PLUS

(b) Energy charges


6.0 RATE WW (Water Works)

This tariff shall be applicable to motive power services used for water works and

sewerage pumping purposes.

6.1 Type I – Water works and sewerage pumps operated by other than local

authority:

(a) Fixed charges per month Rs.15/- per BHP

PLUS

(b) Energy charges per month:


6.2 Type II – Water works and sewerage pumps operated by local authority such as

Municipal Corporation. Gujarat Water Supply & Sewerage Board located outside Gram

Panchayat Area will also attract this tariff:

(a) Fixed charges per month Rs.9 per BHP



PLUS

(b) Energy charges per month:


6.3 Type III – Water works and sewerage pumps operated by Gram Panchayat or

Gujarat Water Supply & Sewerage Board for its installations located in Gram

Panchayats:

Energy charges per month:

For entire consumption during the month 240 Paise/Unit

6.4 Type IV - Water works and sewerage pumps operated by Municipalties /

Nagarpalikas:

Energy charges per month:

For entire consumption during the month 270 Paise/Unit

6.5 Time of Use Discount:

Applicable to all the water works consumers having connected load of 50 HP and above

for the Energy consumption during the Off-Peak Load Hours of the Day.

For energy consumption during the off-peak period, viz.,

1100 Hrs to 1800 Hrs. 30 Paise per Unit

For energy consumption during night hours, viz., 2200

Hrs to 0600 Hrs. next day 75 Paise per Unit

7.0 RATE-AG (AGRICULTURAL)

This tariff is applicable to motive power services used for irrigation purposes only

excluding installations covered under LTP-V category.

7.1 The rates for following group are as under:

7.1.1 HP Based Tariff:

For entire contracted load Rs.140/BHP/month



ALTERNATIVELY

7.1.2 Metered Tariff:

Fixed Charges Rs.10 per BHP per month

Energy Charges:

For entire consumption 50 Paise per Unit per month

7.1.3 Tatkal Scheme:

Fixed Charges Rs.10 per BHP per month

Energy Charges:

For entire consumption 70 Paise per Unit per month

NOTE: The consumers under Tatkal Scheme shall be eligible for normal metered tariff as

above, on completion of five years period from the date of commencement of supply.

7.2 No machinery other than pump water for irrigation will be permitted under this

tariff. Any other machinery connected in the installation governed under this tariff shall

be charged separately at appropriate tariff for which consumers shall have to take

separate connection.

7.3 Agricultural consumers who desire to supply water to brick manufacturing units

shall have to pay Rs. 100/HP per annum subject to minimum of Rs. 2000/- per year for

each brick Mfg. Unit to which water is supplied in addition to existing rate of HP based /

metered agricultural tariff.

Such Agricultural consumers shall have to pay the above charges for a full financial year

irrespective of whether they supply water to the brick manufacturing unit for full or part

of the Financial Year.

Agricultural consumers shall have to declare their intension for supply of the water to

such brick manufacturing units in advance and pay charges accordingly before

commencement of the financial year (i.e. in March every year).

8.0 RATE SL (STREET LIGHTS)

8.1 Tariff for Street Light for Local Authorities and Industrial Estates:



This tariff includes the provision of maintenance, operation and control of the street

lighting system.


For all the units consumed during the month: For streetlights

operated by industrial estates and local authority 330 Paise per Unit

8.1.2 Minimum Charges:

The minimum energy consumption is prescribed for consumer with more than 50 street

lights within a village or an industrial estate, as the case may be, as equivalent to 2200

units per annum per kilo watt of connected load during the year.

8.1.3 Renewal and Replacements of Lamps:

The consumer shall arrange for renewal and replacement of lamp at his cost by person

authorised by him in this behalf under Rule-3 of the Indian Electricity Rules, 1956 / Rules

issued by CEA under the Electricity Act, 2003.

8.2 Tariff for power supply for street lighting purposes to consumers other than

the local authorities and industrial estates:


For all units consumed during the month 330 Paise per kWh

8.2.2 Minimum Charges:

Rs.3 per month per fixture

8.2.3 Renewal and Replacement of Lamps:

The consumer shall arrange for renewal and replacement of lamp at his cost by person

authorised by him in this behalf under Rule-3 of the Indian Electricity Rules, 1956 / Rules

issued by CEA under the Electricity Act, 2003.

8.2.4 Maintenance other than Replacement of Lamps:

Maintenance of the street lighting system shall be carried out by Distribution Licensee.



9.0 RATE TMP (TEMPORARY):

This tariff is applicable to services for temporary supply at the low voltage.

9.1 Energy Charges:

For the supply used for the purposes stipulated in respective tariff for permanent

supply:

(a) Rate LFD-I (for residential premises) & LFD-I

(Rural) 435 Paise/Unit

(b) Rate LFD-II (for non-residential premises) 480 Paise/Unit

(c) Rate LFD-III (for educational and other

institutions) 480 Paise/Unit

(d) Rate LTP-I, LTP-II and LTP-III 640 Paise/Unit

9.1.2 Minimum charges:

(a) For the purpose stipulated in LFD: Rs.20/- per day

(b) For the purpose stipulated in Rate LTP-I Rs.200/- per BHP per month

(c) For the purpose stipulated in Rate LTP-III Rs.225/- per kW per month

NOTE: Payment of bill is to be made within seven days from the date of issue of the bill.

Supply would be disconnected for non-payment of dues on 24 hours notice.

10.0 DELAYED PAYMENT CHARGES FOR LT CONSUMERS:

10.1 No delayed payment charges shall be levied if the bill is paid within ten days

from the date of billing (excluding the date of billing).

Delayed payment charges will be levied at the rate of 1.5% per month or part thereof

(upto the time of ultimate disconnection of supply) in case of all LT consumers except

Agricultural category and for the period from the date of permanent disconnection, the

delayed payment charges will be levied at the rate of 1.25%. Delayed payment charges

will be levied at the rate of 1% per month or part thereof for the consumer governed

under Rate AG from the date of billing till the date of payment if the bill is paid after ten

days from the date of billing.

For Government dues, the delayed payment charges will be levied at the rate provided

under the relevant the Electricity Duty Act.



PART-II

TARIFFS FOR SUPPLY OF ELECTRICITY AT HIGH TENSION

(3.3 KV AND ABOVE, 3-PHASE 50 C/S), AND EXTRA HIGH TENSION

The following tariffs are available for supply at high tension for large power services for

contract demand not less than 100 kVA

11. RATE HTP-I

For regular power supply for larger power service purposes not specified in rate HTP-II

(A) and II (B)

12. RATE HTP-II (A)

For the purpose specified therein.

13. RATE HTP-II (B)

For the purposes specified therein.

14. RATE HTP-III

For supplying at high tension for temporary purposes and for contract load of not less

than 100 kVA.

15. RATE HTP-IV

For using electricity exclusively during night hours.

16. RATE HTP-V

17. RATE RAILWAY TRACTION

11.0 RATE HTP-I:

This tariff will be applicable for supply of electricity to HT consumers contracted for 100

kVA and above for regular power supply and requiring the power supply for the

purposes not specified in Rate HTP-II(A) and HTP-II(B). Research & Development Units

recognised by the Ministry of Science and Technology, Department of Scientific and

Industrial Research and Government, shall pay at HTP-I rates. Water Works and

Sewerage pumping stations run by Local Authorities and GW & SB, GIDC Water Works,



Jetty which is an integrated part of main plant of industries, water works connection

which is an integrated part of main plant of industries and agriculture consumers other

than those covered under HTP – V rates having the Contracted Demand 100 kVA and

above shall pay at HTP-I rates.

11.1 Demand Charges ; (other than Public Water Works)

11.1.1 For billing demand upto contract demand.

(a) For first 500 kVA of billing demand Rs.98/- per kVA per month

(b) For next 500 kVA of billing demand Rs.139/- per kVA per month

(c) For next 1500 kVA of billing demand Rs.208/- per kVA per month

(d) For billing demand in excess of 2500 kVA Rs.237/- per kVA per month

11.1.1a For billing demand upto contract demand for Public Water Works of Gujarat

Water and Sewage Board, Municipal Coporations, Municipalities and other local

authorities.

(a) For first 500 kVA of billing demand Rs.89.25/- per kVA per month

(b) For next 500 kVA of billing demand Rs.126/- per kVA per month

(c) For next 1500 kVA of billing demand Rs.189/- per kVA per month

(d) For billing demand in excess of 2500 kVA Rs.215.25/- per kVA per month

11.1.2 For Billing Demand in Excess of Contract Demand (other than Public Water

Works)

For billing demand in excess over the

contract demand Rs.369 per kVA per month

11.1.2a For billing demand in excess of contract demand for Public Water Works of

Gujarat Water and Sewage Board, Municipal Coporations, Municipalities and other local

authorities.

For billing demand in excess over the

contract demand Rs.335 per kVA per month

PLUS



11.2 Energy Charges for all HTP-I consumers including Public Water Works.

For entire consumption during the month

(a) Upto 1000 kVA contract demand 385 Paise per Unit

(b) For 1001 kVA to 2500 kVA contract demand 405 paise per Unit

(c) Above 2500 kVA contract demand 415 Paise per Unit

PLUS

11.3 Time of Use Charges:

(These charges shall be levied from a consumer having contract demand or actual

demand of 500 kVA and above):

For energy consumption during the two peak periods, viz.,

0700 Hrs to 1100 Hrs and 1800 Hrs to 2200 Hrs 75 Paise per Unit

11.4 Billing Demand:

The billing demand shall be the highest of the following:

(a) Actual maximum demand established during the month

(b) Eighty-five percent of the contract demand

(c) One hundred kVA

11.5 Minimum Bills:

Payment of “demand charges” based on kVA of billing demand.

11.6 Lighting and Non-Industrial Loads:

The consumption of lights and fans and other non-industrial loads of the factory building

as also the consumption of creche, laboratory, stores, time keeper’s office, yards, watch

and ward, first aid centres, and dispensaries during a month registered at the main

meter on HT side shall be charged at the energy charges specified above.

11.7 Power Factor:

11.7.1 Power Factor Adjustment Charges:



(a) The power factor adjustment charges shall be levied at the rate of 1% on the

total amount of electricity bills for the month under the head “Demand Charges” and

“Energy Charges” for every 1% drop or part thereof in the average power factor during

the month below 90% upto 85%.

(b) In addition to the above clause, for every 1% drop or part thereof in average

power factor during the month below 85% at the rate of 2% on the total amount of

electricity bill for that month under the head “Demand Charges” and “Energy Charges”,

will be charged.

11.7.2 Power Factor Rebate:

If the power factor of the consumer’s installation in any month is above 95%, the

consumer will be entitled to a rebate at the rate of 0.5% (half percent) in excess of 95%

power factor on the total amount of electricity bill for that month under the head

“Demand Charges” and “Energy Charges” for every 1% rise or part thereof in the

average power factor during the month above 95%.

11.8 Meter Charges:

The meter charges per month are chargeable as prescribed under ‘GERC (Licensee’s

Power to Recover Expenditure incurred in providing supply and other Miscellaneous

Charges) Regulations, 2005 as in force from time to time.

11.9 Electricity Duty and Tax on Sale of Electricity:

Electricity Duty and tax on sales of electricity will be collected in accordance with the

rates prescribed by the Government from time to time. The consumer shall make

separate metering arrangement for segregation of energy consumption wherever

necessary for the purpose of levying electricity duty at different rate.

11.10 Maximum Demand and its Measurement:

The maximum demand in kW or kVA, as the case may be, shall mean an average

KW/KVA supplied during consecutive 30/15 minutes period of maximum use where such

meter reading directly the maximum demand in KW/KVA have been provided.

11.11 Contract Demand:



The contract demand shall mean the maximum KW/KVA for the supply, of which the

supplier undertakes to provide facilities from time to time.

11.12 Rebate for Supply at EHV:

On Energy charges: Rebate @

(a) If supply is availed at 33/66 kV 0.5%

(b) If supply is availed at 132 kV and above 1.0%

11.13 Concession for Use of Electricity during Night Hours:

For the consumer eligible for using supply at any time during 24 hours, entire

consumption shall be billed at the energy charges specified above. However, the energy

consumed during night hours of 10.00 PM to 06.00 AM next morning (recorded by a

polyphase meter operated through time-switch) as is in excess of one third of the total

energy consumed during the month, shall be eligible for concession at the rate of 75

Paise per unit. The polyphase meter and time switch shall be procured and installed by

the consumer at his cost and sealed by the Distribution Licensee.

11.14 Seasonal Consumers taking HT Supply:

11.14.1 The expression, “Seasonal Consumer”, shall mean a consumer who takes

and uses power supply for ice factory, ice-candy machines, ginning and pressing factory,

oil mill, rice mill, salt industry, sugar factory, khandsari, cold storage plants (including

such plants in fishery industry), tapioca industries manufacturing starch, pumping load

or irrigation, white coal manufacturers etc.

11.14.2 A consumer, who desires to be billed for minimum charges on annual

basis, shall intimate in writing in advance about the off-season during which energy

consumption, if any, shall be mainly for overhauling of the plant and machinery. The

off-season period at any time shall be a full calendar month/months. The total period of

off-season so declared and observed shall be not less than three calendar months in a

calendar year.

11.14.3 The total minimum amount under the head “Demand and Energy

Charges” payable by a seasonal consumer satisfying the eligibility criteria under sub



clause 10.14.1 above and complying with provisions stipulated under sub clauses

10.14.2 above shall be Rs.4000/- per annum per kVA of the billing demand.

11.14.4 The billing demand shall be the highest of the following:

(i) The highest of the actual maximum demand registered during

the calendar year.

(ii) Eighty-five percent of the arithmetic average of contract

demand during the year.

(iii) One hundred kVA.

11.14.5 Units consumed during the off-season period shall be charged for at the

flat rate of 415 Paise per unit.

11.14.6 Electricity bills paid during off-season period shall not be taken into

account towards the amount payable against the annual minimum bill. The amount

paid by the consumer towards the electricity bills for seasonal period only under the

heads “Demand Charges” and “Energy Charges” shall be taken into account while

determining the amount payable towards the annual minimum bill.

11.15 Delayed Payment Charges:

No delayed payment charges if the bill is paid within ten days from the date of billing

(excluding the date of billing).

Delayed payment charges will be levied at the rate of 1.5% per month (upto the time of

permanent disconnection of supply) in case of all HT consumers except Agricultural

category and for the period from the date of permanent disconnection, the delayed

payment charges will be levied at the rate of 1.25%. Delayed payment charges will be

levied at the rate of 1% per month or part thereof for the Agriculture consumers from

the date of billing till the date of payment if the bill is paid after ten days from the date

of billing.

For Government dues, the delayed payment charges will be levied at the rate provided

under the relevant Electricity Duty Act.



12.0 RATE HTP-II (A)

Applicability: This tariff shall be applicable for supply of energy to HT consumers

contracting for 100 KVA and above, requiring power supply for Railways (other than

Railway Workshops chargeable under Rate HTP-I and Railway Traction), shops, hotels,

restaurants, showrooms, hostels, amusement parks, resorts, water parks, aerodromes,

auditoriums, banks, studios, offices, film production, workshops, storage, chilling

centers, distribution pumping stations, refilling of gas, oil and other materials, cinema

theatres, drama theatres, video parlours, public meeting halls, recreation places,

multiplexes, malls, commercial complexes, laboratories, hospitals, medical college,

telephone exchange, infocom, broadcasting and telecasting stations, industrial training

centres, ports, jetty (independent, not integrated part to main industries), public

garden, educational institutions other than specified under HTP – II (B), research and

development units situated in industries other than specified under HTP-I, construction

of premises/project etc., requiring and given separate point of supply and such other

establishments as may be approved from time to time.

12.1 Demand Charges:

(a) For billing demand upto contract demand:

(i) For first 1000 kVA of billing demand Rs.173/- per kVA per month

(ii) For billing demand in excess of 1000 kVA Rs.260/- per kVA per month

(b) For billing demand in excess of contract

demand

Rs.396 per kVA per month for

billing demand in excess over

the contract demand

PLUS

12.2 Energy Charges:


PLUS


(These charges shall be levied from a consumer having contract demand or actual

demand of 500 kVA and above):

For energy consumption during the two peak periods,

viz., 0700 Hrs to 1100 Hrs and 1800 Hrs to 2200 Hrs 75 Paise per Unit



12.4 Billing demand

12.5 Minimum bill

12.6 Power factor Same

12.7 Meter charges as per

12.8 Electricity Duty and tax on sale of electricity HTP-I

12.9 Maximum demand and its measurement Tariff

12.10 Contract demand

12.11 Rebate for supply at EHV

12.12 Delayed payment charges

13.0 RATE HTP-II(B):

Applicability: This tariff shall be applicable for supply of energy to HT consumers

contracting for 100 kVA and above, requiring power supply for residential colonies,

townships, educational institutions governed by the government, and Defence

Establishments (Establishments under the Armed Forces and the Ministry of Defence,

other than the units of public sector undertakings under the Ministry of Defence),

requiring and given separate point of supply.


(a) For entire billing demand Rs.127/- per kVA per month

(b) For billing demand in excess of contract demand Rs.385 per kVA per month

PLUS


For all units consumed during the month 370 Paise/Unit

PLUS


These charges shall be levied on a consumer having contract demand or actual demand

of 500 kVA and above:

For energy consumption during the two peak periods,

viz., 0700 Hrs to 1100 Hrs and 1800 Hrs to 2200 Hrs 75 Paise per Unit



13.4 Billing Demand

13.5 Minimum Bill

13.6 Power Factor Same as

13.7 Meter Charges per HTP-I

13.8 Electricity Duty and Tax on Sale of Electricity Tariff

13.9 Maximum Demand and its Measurement

13.10 Contract Demand


13.12 Delayed Payment Charges

14.0 RATE HTP-III:

This tariff shall be applicable to a consumer taking supply of electricity at high voltage,

contracting for not less than 100 kVA for temporary period. A consumer not taking

supply on regular basis under a proper agreement shall be deemed to be taking supply

for temporary period.


For billing demand upto contract demand Rs.462/- per kVA per month

For billing demand in excess of contract demand Rs.550/- per kVA per month

PLUS



PLUS

14.3 Time of use charges:

(These charges be levied from the consumer who is having contracted demand or actual

demand of 500 kVA and above).

Additional charge for the energy consumption during two peak

periods, i.e., 07.00 Hrs to 11.00 Hrs and 18.00 Hrs to 22.00 Hrs. 75 Paise per Unit



14.4 Billing Demand:

14.5 Minimum Bill:

14.6 Maximum demand and its measurement. Same as per

14.7 Meter Charges: HTP-I

14.8 Electricity duty and tax on sale of electricity Tariff



15.0 RATE HTP-IV

This tariff shall be applicable for supply of electricity to HT consumers contracted for

100 kVA and above for regular power supply and requiring the power supply for the

purposes not specified in Rate HTP-II(A) and HTP-II(B); and consumer opting to use

electricity exclusively during night hours from 10.00 PM to 06.00 AM next day.


Same rates as specified in Rate HTP-I

PLUS



15.3 Billing demand

15.4 Minimum bill

15.5 Power factor

15.6 Meter charges As per

15.7 Electricity duty and tax on sale of Electricity Rate

15.8 Maximum demand and its measurement HTP-I






NOTE:

1. 10% of total units consumed and 15% of the contract demand can be availed beyond

the prescribed hours for the purpose of maintenance.


connection.

3. This tariff shall be applicable if the consumer so opts to be charged in place of HTP-I


4. The option can be exercised to switch over from HTP-I tariff to HTP-IV tariff and vice



consumer for the relevant billing period will be billed under tariff category HTP-I.

16.0 RATE HTP- V

HT - Agricultural (for HT Lift Irrigation scheme only)

This tariff shall be applicable for supply of electricity to High Tension Agricultural

consumers contracting for 100 kVA and above, requiring power supply for lifting water

from surface water sources such as canal, river and dam, and supplying water directly

to the fields of farmers for agricultural irrigation only.


Demand Charges Rs. 25 per kVA per Month

PLUS



16.3 Power Factor

16.4 Meter charge

16.5 Billing Demand


16.7 Minimum bill As per HTP-I Tariff

16.8 Maximum demand





17.0 RATE – RAILWAY TRACTION:

This tariff is applicable for power supply to Railway Traction at 132 kV/66 kV.


(a) For billing demand upto the contract demand Rs.160 per kVA per month

(b) For billing demand in excess of contract demand Rs.400 per kVA per month

NOTE: In case of the load transfer for traction supply due to non-availability of power

supply at preceding or succeeding point of supply or maintenance at Discom’s level,

excess demand over the contract demand shall be charged at normal rate at

appropriate point of supply.

Normal Demand Charges will also apply in case of bunching of trains. However, Discoms

shall charge excess demand charges while raising the bills and Railways have to give

convincing details and documentary proof of bunching of trains if they want to be

charged at the normal demand charges. If satisfactory proof of bunching of trains is

provided, Discom shall consider that occasion for normal demand charges, otherwise

excess demand charges will be applicable specified as above at 17.1(b).

PLUS



17.3 Power Factor

17.4 Meter charge

17.5 Billing Demand


17.7 Minimum bill As per HTP-I Tariff

17.8 Maximum demand





Annexure 4: Tariff Filling Formats

Appendix-3

TARIFF FILING FORMSUttar Gujarat Vij Company Limited

110

Checklist of Forms and other information/

documents for tariff filing for Distribution

Company

Uttar Gujarat Vij Company Limited

Year


Form No. Title of Tariff Filing Forms (Distribution) Tick

Form D - 1 Cost of Purchase of Power Y

Form D - 2 Fixed Assets and Depreciation Y

Form D - 3 Detailed Calculation of item wise Interest Y

Form D - 4 Sale of Electrical Energy Y

Form D - 5 Summary of categorywise tariff increase YOther Information/ Documents

Sl. No. Information/Document Tick

1 Corporate audited Balance Sheet and Profit & Loss

Accounts with all the Schedules & annexures for the

relevant years.

Y

2 Copies of relevant loan Agreements

3 Copies of the approval of Competent Authority for the

Capital Cost and Financial package.4 Utilities carrying out generation and transmission in

addition to distribution shall also submit all relevant

forms given in Appendix - A, Appendix - B and

Appendix - C

5 Any other relevant information, (Please specify)

Y

Note: Electronic copy in the form of CD/Floppy disc shall

also be furnished.

111

Form D - 1Cost of Purchase of Power

Company


Year


FY 2010-11

A Physical Data

1 Share of utility MW2 Maximum entitled power purchase MKwh3 Actual Purchase of Power by the Utility MKwh 15608

B Cost Data

1 Basic Variable Cost Rs / Kwh

2 Transmission charge Rs / Kwh

3 Other Charges Rs / Kwh

4 Total Variable Charge Rs / Kwh 1.62

5 Basic Variable Cost Rs. In Lakhs

6 Transmission charge Rs. In Lakhs

7 Other Charges Rs. In Lakhs

8 Total Variable Charge Rs. In Lakhs 252082

Fixed Cost

9 Interest on debt Rs. In Lakhs

10 Depreciation Rs. In Lakhs

11 O & M Rs. In Lakhs

12 Insurance Rs. In Lakhs

13 Interest on Working Capital Rs. In Lakhs

14 Return on Equity Rs. In Lakhs

15 Tax Rs. In Lakhs

16 Total Fixed Cost Rs. In Lakhs

17 Total Fixed Cost Rs / Kwh

18 Incentive (Dis) Rs. In Lakhs

19 Total variable and fixed Cost and incentive Rs. In Lakhs 417197

C Other data

1 Cost of Purchase of Power per Unit Paise 267

112

DAKSHIN GUJARAT VIJ COMPANY LIMITED

Form D - 2

Fixed Assets and Depreciation

Year-2008-09 Rs. in lakhs

As at the

beginning

of the

Financial

Year

Additions Deductions

As at the

end of the

Financial

Year

As at the

beginning of

the

Financial

Year

Additions Deductions

As at the

end of the

Financial

Year

As at the

beginning of

the Financial

Year

As at the

end of the

Financial

Year

Land 1005 -957 0 48 0 0 0 1005 48

Buildings 798 319 0 1117 152 38 191 645 926

Hydraulic works 59 1 0 60 11 2 13 48 47

Other Civil Works 119 112 0 231 23 8 31 97 200

Plant & Machinery 54231 7457 0 61687 10361 2117 12479 43869 49209

Lines & Cables 146460 15268 0 161728 27983 5551 33534 118477 128194

Vehicles 257 -7 0 251 49 9 58 208 193

Furniture & Fixtures 179 90 0 269 34 9 43 145 225

Office Equipments 1228 118 0 1345 235 46 281 993 1065

Capital Expenditure on Assets not belonging to utility

0 0 0 0 0 0 0 0 0

Spare Units 0 0 0 0 0 0 0 0 0

Capital Spares 0 0 0 0 0 0 0 0 0

Asset Taken over from licensee0 0 0 0 0 0 0 0 0

TOTAL 204335 22401 0 226736 38849 7781 0 46630 0 165486 180107

Net Block

Net Addition Net Addition

Particulars

Gross Block Depreciation

Applicable

rate of

Depreciation

(%)

113


Form D - 2

Fixed Assets and DepreciationYear-2009-10 Rs. in lakhs

As at the

beginning of

the Financial

Year

AdditionsDeductio

ns

As at the

end of the

Financial

Year

As at the

beginning

of the

Financial

Year

AdditionsDeductio

ns

As at the

end of the

Financial

Year

As at the

beginning of

the Financial

Year

As at the

end of the

Financial

Year

Land 48 -1153 -1105 0 0 0 As per 48 -1105

Buildings 1117 385 1502 191 44 234 CERC norms 926 1268Hydraulic works 60 1 61 13 3 17 47 45Other Civil Works 231 135 366 31 10 41 200 325Plant & Machinery 61687 8992 70679 12479 3494 15973 49209 54706Lines & Cables 161728 18411 180139 33534 9025 42559 128194 137580Vehicles 251 -8 243 58 23 81 193 162Furniture & Fixtures 269 108 377 43 20 64 225 313Office Equipments 1345 142 1488 281 90 370 1065 1117


0 0 0 0 0 0 0 0

Spare Units 0 0 0 0 0 0 0 0Capital Spares 0 0 0 0 0 0 0 0

Asset Taken over from licensee 0 0 0 0 0 0 0 0

TOTAL 226736 27013 253749 46630 12710 59340 180107 194409

Net Block


Particulars


Applicable rate

of Depreciation

(%)

114


Form D - 2

Fixed Assets and DepreciationYear-2010-11 Rs. in lakhs

As at the

beginning of

the Financial

Year

AdditionsDeductio

ns

As at the end

of the

Financial

Year

As at the

beginning of

the Financial

Year

AdditionsDeductio

ns

As at the

end of the

Financial

Year

As at the

beginning of

the Financial

Year

As at the

end of the

Financial

Year

Land -1105 -1249 -2355 0 0 0 As per -1105 -2355Buildings 1502 417 1920 234 57 292 CERC norms 1268 1628Hydraulic works 61 1 62 17 3 20 45 43Other Civil Works 366 146 512 41 15 55 325 457Plant & Machinery 70679 9739 80419 15973 3989 19962 54706 60456Lines & Cables 180139 19942 200081 42559 10038 52597 137580 147484Vehicles 243 -9 234 81 23 104 162 130Furniture & Fixtures 377 117 494 64 28 91 313 402Office Equipments 1488 154 1642 370 99 469 1117 1172


0 0 0 0 0 0 0 0

Spare Units 0 0 0 0 0 0 0 0Capital Spares 0 0 0 0 0 0 0 0

Asset Taken over from licensee 0 0 0 0 0 0 0 0

TOTAL 253749 29259 283008 59340 14251 73591 194409 209417

Note : Net Addition to Gross Block has been estimated & apportioned to different assets considering last years parformance.

Net Block


Particulars


Applicable rate

of Depreciation

(%)

115

Form D - 3Detailed Calculation of item wise Interest

Company


Year


Rs. In Lakhs

Date Amount

A) Loan & Debentures

B) Others

Fixed DepositsSecurity DepositsBank Over draftOthers (to specify)

Type of the borrowing & Name of the Lender

Principal Amount

Opening Balance of outstanding Loans / Debentures

Amount of Interest

Borrowings during the Year Repayment

amount during the year

Closing Balance of Outstanding loan / debentures

Rate of Interest

Others (to specify)

TOTAL

116

Form D - 5Summary of categorywise tariff increase

Company

Uttar Gujarat Vij Company Limited Year


FY 2010-11

Category

Units

Sold

Cost of

supply

Sales

Revenue

at

existing

tariff

Sales

Revenue at

existing

tariff

Sales

Revenue

at

proposed

tariff

Sales

Revenue at

proposed

tariff

Increase

in Sales

Revenue

Increase in

Sales

Revenue

Increase in

Sales

Revenue

Sales

Revenue at

existing

tariff as %

of cost of

supply

Sales

Revenue at

proposed

tariff as %

of cost of

supply

Mus Paise/Unit Rs. Lakhs Paise/Unit Rs. Lakhs Paise/Unit Rs. Lakhs Paise/Unit % % %

1 Domestic 1287 416 41339 321 41339 321 0 0.00 0.0% 77% 77%2 Commercial 480 416 26702 557 26702 557 0 0.00 0.0% 134% 134%3 Industrial LT & MT 668 416 36573 548 36573 548 0 0.00 0.0% 132% 132%4 Public Lighting 42 416 1694 407 1694 407 0 0.00 0.0% 98% 98%5 Agriculture* 6583 416 78572 119 78572 119 0 0.00 0.0% 29% 29%6 Water Works 447 416 15484 347 15484 347 0 0.00 0.0% 83% 83%7 Industrial HT 2951 416 163318 553 163318 553 0 0.00 0.0% 133% 133%8 Railways 12 416 715 596 715 596 0 0.00 0.0% 143% 143%

Total 12468 416 364397 292 364397 292 0 0.00 0.0% 70% 70%

* Agriculture Revenue including tariff compensation

117

Form D - 4Sale of Electrical EnergyFull Year with Propsed TariffsCompany


Year


Consumer Category

Total for all Categories

FY 2010-11

A Physical Data1 Units Sold Mkwh 12468

2 Units Sold during Peak hours (ToU)

3 Connected Load Kw

4 Contract Demand Kw/KVA

5 Actual Recorded Demand Kw/KVA

6 Normal Billed Demand Kw/KVA

7 Excess Billed Demand Kw/KVA

8 Total Billed Demand Kw/KVA

9 Number of Single Phase Consumers

10 Number of Three Phase Consumers

11 Total Number of Consumers 2693391

12 Power Factor %

13 Monthly Consumption per consumer Kwh 386

14 Connected Load per Consumer HP/Kw

15 Normal Billed Demand per Consumer Kw/KVA

16 Excess Billed Demand per Consumer Kw/KVA

17 Total Billed Demand per Consumer Kw/KVA

B Sales Revenue

1 Fixed Charge / Demand Charge Rs. In Lakhs 50524

2 Excess Demand Charge Rs. In Lakhs 872

3 Total Fixed Charge / Demand Charge Rs. In Lakhs 51397

4 Energy Charge Rs. In Lakhs 218730

5 Time of Use Charge Rs. In Lakhs 0

6 Power Factor Adjustment/ Reactive Energy/EHV rebateRs. In Lakhs -1737

7 Energy + ToU + PF Adjustment Charge ( 4+5+6) Rs. In Lakhs 216993

8 Fuel Cost Adjustment Rs. In Lakhs 96007

9 Total Charge Rs. In Lakhs 364397

10 Prompt Payment Discount, if Any. Rs. In Lakhs 0

11 Net Sale of Energy Rs. In Lakhs 364397

C Sales Revenue

1 Fixed Charge / Demand Charge Paise per unit 411 Fixed Charge / Demand Charge Paise per unit 41

2 Excess Demand Charge Paise per unit 1

3 Total Fixed Charge / Demand Charge Paise per unit 41

4 Energy Charge Paise per unit 175

5 Time of Use Charge Paise per unit 0

6 Power Factor Adjustment Paise per unit -1

7 Energy + ToU + PF Adjustment Charge ( 4+5+6) Paise per unit 174

8 Fuel Cost Adjustment Paise per unit 77

9 Total Charge Paise per unit 292

10 Prompt Payment Discount, if Any. Paise per unit 0

11 Net Sale of Energy Paise per unit 292

118



Year


Consumer Category

Residential

FY 2010-11



3 Connected Load Kw









12 Power Factor %






B Sales Revenue


2 Excess Demand Charge Rs. In Lakhs




6 Power Factor Adjustment/ Reactive Energy Rs. In Lakhs 0






C Sales Revenue

1 Fixed Charge / Demand Charge Paise per unit 111 Fixed Charge / Demand Charge Paise per unit 11





6 Power Factor Adjustment Paise per unit 0






119



Year


Consumer Category

Commercial

FY 2010-11



3 Connected Load Kw









12 Power Factor %






B Sales Revenue












C Sales Revenue

1 Fixed Charge / Demand Charge Paise per unit 38











120



Year


Consumer Category

LTP - Industrial

FY 2010-11



3 Connected Load HP 842931









12 Power Factor %


14 Connected Load per Consumer HP/Kw 25




B Sales Revenue












C Sales Revenue












121



Year


Consumer Category

Water Works

FY 2010-11












12 Power Factor %






B Sales Revenue












C Sales Revenue












122



Year


Consumer Category

Agriculture

FY 2010-11












12 Power Factor %






B Sales Revenue












C Sales Revenue












123



Year


Consumer Category

Street Light

FY 2010-11



3 Connected Load Kw









12 Power Factor %


14 Connected Load per Consumer HP/Kw 0.0




B Sales Revenue












C Sales Revenue












124



Year


Consumer Category

HTP

FY 2010-11



3 Connected Load Kw



6 Normal Billed Demand KVA 1050591

7 Excess Billed Demand KVA

8 Total Billed Demand KVA




12 Power Factor %



15 Normal Billed Demand per Consumer Kw/KVA 487



B Sales Revenue





5 Time of Use Charge- Night Use Discount Rs. In Lakhs 0

6 Other Charges Rs. In Lakhs -1727






C Sales Revenue












125



Year


Consumer Category

Railways

FY 2010-11



3 Connected Load Kw



6 Normal Billed Demand KVA 4409

7 Excess Billed Demand KVA

8 Total Billed Demand KVA




12 Power Factor %



15 Normal Billed Demand per Consumer Kw/KVA 4409



B Sales Revenue





5 Time of Use Charge- Night Use Discount Rs. In Lakhs 0

6 Other Charges Rs. In Lakhs -9






C Sales Revenue












126

Form D - 4

Sale of Electrical Energy

Full Year with Proposed Tariffs

Company


Year


Consumer Category

LFD-1 (Urban)

Slab

1-50 kWh

FY 2010-11



3 Connected Load Kw/ HP 12223









12 Power Factor %






B Sales Revenue

1 Fixed Charge / Demand Charge* Rs. In Lakhs 10




6 Other Charges (net of discounts/rebates) Rs. In Lakhs 0





C Sales Revenue












* Fixed Charges adjusted on a prorata basis in energy slabs

127

Form D - 4



Company


Year


Consumer Category

LFD-1 (Urban)

Slab

51-100 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













128

Form D - 4



Company


Year


Consumer Category

LFD-1 (Urban)

Slab

101-200 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













129

Form D - 4



Company


Year


Consumer Category

LFD-1 (Urban)

Slab

201-300 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













130

Form D - 4



Company


Year


Consumer Category

LFD-1 (Urban)

Slab

above 300 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













131

Form D - 4



Company


Year


Consumer Category

BPL Urban

Slab

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













132

Form D - 4



Company


Year


Consumer Category

LFD-1 (Rural)

Slab

1-50 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













133

Form D - 4



Company


Year


Consumer Category

LFD-1 (Rural)

Slab

51-100 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













134

Form D - 4



Company


Year


Consumer Category

LFD-1 (Rural)

Slab

101-200 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













135

Form D - 4



Company


Year


Consumer Category

LFD-1 (Rural)

Slab

201-300 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













136

Form D - 4



Company


Year


Consumer Category

LFD-1 (Rural)

Slab

above 300 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













137

Form D - 4



Company


Year


Consumer Category

BPL Rural

Slab

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













138

Form D - 4



Company


Year


Consumer Category

LFD-II

Slab

1-50 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













139

Form D - 4



Company


Year


Consumer Category

LFD-II

Slab

51-150 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













140

Form D - 4



Company


Year


Consumer Category

LFD-II

Slab

151-300 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













141

Form D - 4



Company


Year


Consumer Category

LFD-II

Slab

Above 300 kWh

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













142

Form D - 4



Company


Year


Consumer Category

LFD-III

Slab

LFD III

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













143

Form D - 4



Company


Year


Consumer Category

A1

Slab

< = 7.5 HP

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












144

Form D - 4



Company


Year


Consumer Category

A1

Slab

> 7.5 HP

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












145

Form D - 4



Company


Year


Consumer Category

A2

Slab

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












146

Form D - 4



Company


Year


Consumer Category

A3

Slab

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












147

Form D - 4



Company


Year


Consumer Category

A5

Slab

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












148

Form D - 4



Company


Year


Consumer Category

LTP-I

Slab

0-10 BHP

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












149

Form D - 4



Company


Year


Consumer Category

LTP-I

Slab

11-50 BHP

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












150

Form D - 4



Company


Year


Consumer Category

LTP-I

Slab

51-75 BHP

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












151

Form D - 4



Company


Year


Consumer Category

LTP-I

Slab

76-100 BHP

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












152

Form D - 4



Company


Year


Consumer Category

LTP-I

Slab

Above 100 BHP

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












153

Form D - 4



Company


Year


Consumer Category

LTP-II

Slab

LTP II

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












154

Form D - 4



Company


Year


Consumer Category

LTP-III

Slab

20-40 KW

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












155

Form D - 4



Company


Year


Consumer Category

LTP-III

Slab

40-60 KW

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












156

Form D - 4



Company


Year


Consumer Category

LTP-III

Slab

>60 KW

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












157

Form D - 4



Company


Year


Consumer Category

LTP-III

Slab

Bill Demand > Contract Demand

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












158

Form D - 4



Company


Year


Consumer Category

WW

Slab

WW

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












159

Form D - 4



Company


Year


Consumer Category

WW1

Slab

WW1

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












160

Form D - 4



Company


Year


Consumer Category

WW3

Slab

WW3

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












161

Form D - 4



Company


Year


Consumer Category

WW4

Slab

WW4

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












162

Form D - 4



Company


Year


Consumer Category

LTPSL-1

Slab

SL1

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












163

Form D - 4



Company


Year


Consumer Category

LTPSL-3

Slab

SL2

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












164

Form D - 4



Company


Year


Consumer Category

HTP-I Others

Slab

<= 500 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue





6 Other Charges (net of discounts/rebates) Rs. In Lakhs -265





C Sales Revenue












165

Form D - 4



Company


Year


Consumer Category

HTP-I Others

Slab

> 500 & <= 1000 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












166

Form D - 4



Company


Year


Consumer Category

HTP-I Others

Slab

> 1000 & <= 2500 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












167

Form D - 4



Company


Year


Consumer Category

HTP-I Others

Slab

> 2500 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












168

Form D - 4



Company


Year


Consumer Category

HTP-I PWW

Slab

<= 500 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













169

Form D - 4



Company


Year


Consumer Category

HTP-I PWW

Slab

> 500 & <= 1000 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













170

Form D - 4



Company


Year


Consumer Category

HTP-I PWW

Slab

> 1000 & <= 2500 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













171

Form D - 4



Company


Year


Consumer Category

HTP-I PWW

Slab

> 2500 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue













172

Form D - 4



Company


Year


Consumer Category

HTP-II A

Slab

First 1000 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












173

Form D - 4



Company


Year


Consumer Category

HTP-II A

Slab

Excess of 1000 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












174

Form D - 4



Company


Year


Consumer Category

HTP-II B

Slab

HTP II B

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












175

Form D - 4



Company


Year


Consumer Category

HTP-III

Slab

HTP III

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












176

Form D - 4



Company


Year


Consumer Category

HTP-IV

Slab

First 500 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












177

Form D - 4



Company


Year


Consumer Category

HTP-IV

Slab

Next 500 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












178

Form D - 4



Company


Year


Consumer Category

HTP-IV

Slab

Next 1500 KVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












179

Form D - 4



Company


Year


Consumer Category

HTP-IV

Slab

Above 2500 kVA

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












180

Form D - 4



Company


Year


Consumer Category

Seasonal

Slab

SEASONAL

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












181

Form D - 4



Company


Year


Consumer Category

Railway

Slab

RAILWAY TRACTION

FY 2010-11












12 Power Factor %






B Sales Revenue










C Sales Revenue












182