Madhya Pradesh Poorv Kshetra Vidyut Vitaran Company ... - Infraline

Madhya Pradesh Poorv Kshetra Vidyut 

Vitaran Company Limited 

Block No. 7, Shakti Bhawan, Vidyut Nagar, Jabalpur 

AGGREGATE REVENUE REQUIREMENT 

& 

TARIFF PROPOSAL PETITION 

(REVISED) 

FOR FY 2011-12

ARR & TARIFF FILING FY-12 

BEFORE THE MADHYA PRADESH 

ELECTRICITY REGULATORY COMMISSION, BHOPAL 

Petition No. 93 of 2010 

Madhya Pradesh Poorv Kshetra 

Vidyut Vitaran Company Limited, (MPPKVVCL) 

Block No. 7, Shakti Bhawan, 

Vidyut Nagar, Jabalpur (MP) 

--------- Petitioner 

Vs 

(1) MP Power Trading Co. Limited 

Shakti Bhawan, Vidyut Nagar, Jabalpur (MP) --------- Respondent No. 1 

(2) MP Transmission Co. Limited 

Shakti Bhawan, Vidyut Nagar, Jabalpur (MP) --------- Respondent No. 2 

IN THE MATTER OF: 

Filing of the ARR application for the distribution and retail supply business for 

the year 2011-12 under tariff principles laid down in "The Madhya Pradesh 

Electricity Regulatory Commission (Terms and Conditions for Determination 

of Tariff for supply and wheeling of Electricity and Methods and Principles of 

Fixation of Charges) Regulations, 2009 (G-35 of 2009)" by the Madhya 

Pradesh Poorv Kshetra Vidyut Vitaran Company Ltd., Jabalpur as the 

Distribution Licensee. 

The Petitioner above named, M.P. Poorv Kshetra Vidyut Vitaran Company Ltd., 

Jabalpur, respectfully submits as under:- 

1. Madhya Pradesh Poorv Kshetra Vidyut Vitaran Company Ltd. (MPPKVVCL), 

(hereinafter referred to as the 'Petitioner', MPPKVVCL, 'the Company' or 'the 

Licensee'), is a Company incorporated under the Companies Act, 1956 and 

Madhya Pradesh Poorv Kshetra Vidyut Vitaran Co. Ltd, Jabalpur P a g e | 2


having its registered office at Block No.7, Shakti Bhawan, Vidyut Nagar, 

Jabalpur. The Petitioner is a deemed licensee under the Fifth Proviso to 

Section 14 of the Electricity Act, 2003. The area of supply of the Petitioner is 

Jabalpur, Rewa, Sagar and Shahdol Commissionary within the State of Madhya 

Pradesh ('MP'). 

2. The Government of Madhya Pradesh ('GoMP' or 'State Government'), vide an 

Order No. 3679-FRS-18-13-2002 dated 31st May, 2005, published in the gazette 

of Madhya Pradesh dated 31st May 2005, have restructured the functions and 

undertakings of Generation, Transmission, Distribution and Retail Supply of 

electricity earlier carried out by the Madhya Pradesh State Electricity Board 

('MPSEB' or the 'Board') and transferred the same to five Companies to function 

independently. The five Companies are as under: - 

1) M.P. Power Generating Company Ltd., Jabalpur (MPPGCL) 

2) M.P. Power Transmission Company Ltd., Jabalpur (MPPTCL) 

3) M.P. Poorv Kshetra Vidyut Vitaran Company Ltd., Jabalpur (MPPKVVCL) 

4) M.P.Madhya Kshetra Vidyut Vitaran Company Ltd. Bhopal (MPMKVVCL) 

5) M.P. Paschim Kshetra Vidyut Vitaran Company Ltd., Indore (MPPKVVCL) 

3. With effect from 1 st June‟2005, the Operation and Management Agreement 

that existed between Madhya Pradesh State Electricity Board and the Five 

Companies came to end with the issue of the said Order dated 31-05-2005. 

The three Vidyut Vitaran Companies viz. MPPKVVCL, Jabalpur, 

MPMKVVCL, Bhopal and MPPKVVCL, Indore started functioning 

independently as Distribution Licensees in their respective area of license and 

from the said date, they are no longer operating as an agent of or on behalf of 

the Board, subject to Cash Flow Mechanism (CFM) provided in the said Order. 

4. On June 3, 2006 GoMP, in exercise of its powers under Section 23 (Sub-section 

(1), (2) and (3)) and Section 56 (Sub-section (2)) of Madhya Pradesh Vidyut 

Sudhar Adhiniyam, 2000 read with Section 131 (Sub-sections (1), (2), (5), (6) 

and (7) of Electricity Act, 2003, effected the transfer of and vesting of the 

functions, properties, interests rights and obligations of MPSEB relating to 

the Bulk Purchase and Bulk Supply of Electricity in the State Government and 



simultaneously re-transferred and re-vested the same to MP Power Trading 

Company Ltd. ('Tradeco' or 'MP Tradeco'). Since then MP Tradeco is 

discharging the responsibilities of procurement of power in bulk and supplying 

to the three Electricity Distribution Companies (DISCOMs), including the 

Petitioner herein. The transfer was affected through "M.P. Electricity 

Reforms Transfer Scheme Rules 2006” (Transfer Scheme Rules) vide 

Notification No.3474 /FRS/17/XIII/2002 dtd 3 rd June 2006 (Transfer Scheme 

Rules). 

5. In the backdrop of the above facts and circumstances, the present application is 

being made by the Petitioner (MPPKVVCL) under Section 61 and Section 62 

(1) (d) of the Electricity Act 2003 for determination of the tariff for the 

distribution and Retail Supply Business for the period FY-2011-12 

following the regulations laid down by the Hon‟ble Commission. 

6. While filing the present ARR under the prevailing Regulation, 

MPPKVVCL has endeavoured to comply with the various legal and 

regulatory directions and stipulations applicable including the directions given 

by the Hon'ble Commission in the Business Rules of the Commission, the 

Guidelines, previous ARR and Tariff Orders and the Madhya Pradesh Electricity 

Regulatory Commission (Terms & Conditions for determination of Tariff) 

Regulation 2009 (hereinafter referred to as the “Regulation). 

7. The existing regulation was notified on 22-01-2010. After the notification of 

the regulation, a major change in the base line data of the company has taken 

place whereby the electricity distribution business of the four RE Co-operative 

societies viz. Amarpatan, Sidhi, Nowgaon and Laundi has been taken over by 

MPPKVVCL w.e.f. 15 th Aug‟2010 and thereafter the consumers of the then 

co-operative societies have become the LT consumers of the licensee. 

Consequent upon taking over of business of RECS, petitioner is required to 

incur additional cost, over and above the cost which is going to be determined 

under the provisions of the regulation in order to supply and maintain the 

electricity in the area of the then RECS. Since, the existing norms provided in 

the regulation do not cover the additional expenses required to be incurred on 



account of taken over of the electricity business in society area, therefore such 

additional cost may kindly be allowed in the interest of the consumers, 

particularly consumers of society area, while deciding the petition. 

8. MPPKVVCL Jabalpur had filed the ARR Petition on 21-12-2010. The motion 

hearing of the petition was held on 25-01-2011and petitioner has submitted its 

response on the queries raised by Hon‟ble Commission. During the course of 

motion hearing on 25-01-11, it was directed by the Commission that petition is 

required to be filed strictly as per the provision of regulation and additional 

submission may be made. As directed by Hon‟ble Commission during motion 

hearing petitioner has revised the petition and impact of uncontrollable cost 

not provided in the regulation has also been covered in additional submission. 

It is however submitted that the prayer made in the petition is based on the 

actual data. 

9. Based on the information available, the Petitioner has made sincere efforts to 

comply with the Regulations of the Hon'ble Commission and discharge its 

obligations to the best of its abilities and resources at its command. However, 

should any further material information become available during the process of 

determination, the petitioner be permitted to reserve the right to file such 

additional information and consequently amend/ revise the application. 

10. The salient features of the ARR with additional submission are as under:- 

i) The normative loss of the licensee as per the existing regulation is 27%. 

However after the notification of regulation, a major change of material 

importance had occurred whereby the Electricity distribution business of the 

four Rural Electricity Co-operative Societies (hereinafter “RECS”) has been 

taken over by the licensee company and the consumers of those societies are 

now the consumers of the company. Since the areas of these societies were 

the high loss segments, the distribution loss of the company has increased 

significantly by 2.35%. Therefore the licensee prays that the normative loss 

level for FY-12 may please be revised and considered as 29.35% in place of 

27%. 

ii) Aggregate revenue requirement for the year 2011-12 is ` 5,374.39 Cr. 



iii) For the purpose of computation of energy requirement the restricted demand 

and supply hours to be maintained in the licensee area, have been considered 

for FY 2011-12. 

iv) Energy sale for FY 2011-12 is projected as 8,385.49 MU for which energy 

requirement will be 12713.86 MU at Ex-Bus and 12375.15 MU at M.P. 

periphery. 

v) Revenue at existing tariff will be ` 3,494.43 Cr., other non-tariff income 

will be ` 32.01 Cr. and therefore the revenue gap will be ` 1,847.95 Cr. 

vi) For recovery of the aforesaid gap, revision in existing tariff is also 

proposed, so that additional amount of ` 1,093.62 Cr. could be recovered. 

vii) The un-recovered amount of ` 754.33 Cr is proposed to be treated as 

“Regulatory Asset” and proposed to be amortized over a period of 3-years 

starting from FY-13. The Licensee has not sought funding cost for the unrecovered 

gap which it proposes to do at the time of truing up. 

viii) The formula for Fuel Surcharge Adjustment and expensive power charges 

for recovery of variation in Power Purchase cost has also been proposed. 

11. The Tariff Proposal for FY-12 for the treatment of the above indicated revenue 

Gap is also prepared and submitted in the relevant section of this petition. 

12. Shri P.K. Singh, Chief Engineer (Commercial) of MPPKVVCL has been 

authorised to execute and file all the documents on behalf of MPPKVVCL in 

this regard. Accordingly, the current filing signed and verified by, and backed by 

the affidavit of Shri P.K.Singh, Chief Engineer (Commercial). 



PRAYER 

In view of the aforesaid facts and circumstances, the Applicant requests that the 

Hon'ble Commission may be pleased to: 

(a) Take the accompanying ARR/Tariff petition of MPPKVVCL on record and treat 

it as complete; 

(b) Consider and approve the normative loss level of MPPKVVCL as 29.35% due to the 

takeover of high loss segment area of RE co-operative societies by MPPKVVCL. 

(c) Consider and approve MPPKVVCL's ARR amounting to ` 5,374.39 Cr. for 

the year 2011-12 including all requested regulatory treatments in the filing. 

(d) Consider and approve MPPKVVCL's Tariff proposal for FY-12. 

(e) The un-recovered amount of ` 754.33 Cr may please be treated as “Regulatory 

Asset” and be amortized over a period of 3-years starting from FY-13. The 

Licensee will not sought funding cost for the un-recovered gap at the time of 

truing up. 

(f) Condone any inadvertent omissions/ errors/ shortcomings and permit the 

petitioner to add/ change/ modify/ alter portion(s) of this filing and make further 

submissions as may be required at a later stage; and 

(g) Pass such order as the Hon'ble Commission may deem fit and proper in the 

facts and circumstances of the case. 

Date:- 31 /01/2011 

Chief Engineer (Commercial) 

MP Poorv Kshetra Vidyut Vitaran Co.Ltd., 

Jabalpur. 



Table of Contents 

A1: ESTIMATION OF SALES ............................................................................... 10 

1.1 Provision of Regulation: ............................................................................................................... 10 

1.2 Method adopted for Estimation of Sales: ................................................................................... 10 

1.3 Category-wise sales projection ................................................................................................... 13 

1.3.1 LV -1: Domestic ....................................................................................................................... 13 

1.3.2 LV -2: Non- Domestic .............................................................................................................. 16 

1.3.3 LV -3.1: Public Water Works .................................................................................................. 18 

1.3.4 LV -3.2: Street Light ................................................................................................................ 22 

1.3.5 LV -4.1: Non Seasonal Industrial ........................................................................................... 24 

1.3.6 LV -4.2: Seasonal Industrial ................................................................................................... 28 

1.3.7 LV -5.1: Agricultural ................................................................................................................ 30 

1.3.8 LV 5.2: Other than Agricultural use ...................................................................................... 36 

1.3.9 HV 1: Railway Traction ........................................................................................................... 39 

1.3.10 HV -2: Coal Mines .................................................................................................................... 40 

1.3.11 HV-3: Industrial and Non-Industrial....................................................................................... 41 

1.3.12 HV -4: Seasonal ....................................................................................................................... 43 

1.3.13 HV -5 Water Works, Lift Irrigation & Other than Agricultural ............................................. 44 

1.3.14 HV -6: Bulk Residential users ................................................................................................ 46 

1.3.15 HV -7: Bulk Supply to Exemptees ......................................................................................... 47 

A2: DEMAND PROJECTION AND ENERGY REQUIREMENT .................... 50 

A3: ASSESSMENT OF AVAILABILITY.............................................................. 56 

3.1 Central Sector Stations Allocated to MP .................................................................................... 56 

3.2 Projection of Availability for future years .................................................................................. 57 

3.3 Projections for Sipat-II and Kahalgaon-II ................................................................................... 57 

3.4 Bilateral and Joint Venture Stations ........................................................................................... 57 

3.5 Review of past Ex-bus availability .............................................................................................. 58 

3.6 Projection of availability for future years ................................................................................... 58 

3.7 MP GENCO stations ...................................................................................................................... 59 

3.8 Capacity addition plan .................................................................................................................. 59 

3.9 Assumption for projecting availability from the future capacities .......................................... 60 

3.10 Overall availability ......................................................................................................................... 61 

3.11 PGCIL Losses ................................................................................................................................ 63 

3.12 Availability at state boundary ...................................................................................................... 63 

A4: ESTIMATION OF COSTS ............................................................................... 65 

4.2 For existing stations ..................................................................................................................... 66 

4.3 For Future capacities .................................................................................................................... 68 

4.4 Details of costs for Existing power plants ................................................................................. 68 

4.5 Details of Costs for future capacities ......................................................................................... 70 

4.6 Inter-state and Intra-state transmission charges ...................................................................... 71 

A5: POWER PURCHASE COST ........................................................................... 74 

A6: O&M EXPENSES .............................................................................................. 78 

6.2 Administrative and General Expenses ....................................................................................... 91 

6.3 Repair and Maintenance Cost: .................................................................................................... 92 

A7: INVESTMENTS ................................................................................................ 95 

A8: FINANCING ...................................................................................................... 96 

8.1 Capitalization ................................................................................................................................. 96 

A9: DEPRECIATION .............................................................................................. 97 



A10: INTEREST AND FINANCE CHARGES ................................................. 100 

10.1 Interest on Project Loans ........................................................................................................... 100 

10.2 Interest on Working Capital ....................................................................................................... 104 

10.3 Interest on consumer Security Deposit .................................................................................... 107 

A11: OTHER COSTS .......................................................................................... 108 

11.1 Other Income ............................................................................................................................... 108 

11.2 Return on Equity ......................................................................................................................... 110 

11.3 Bad and Doubtful Debts ............................................................................................................. 112 

11.4 Other Expenses ........................................................................................................................... 113 

A12: TRUE-UP COST OF PREVIOUS YEAR ................................................. 114 

12.1 TRUE-UP for FY06: ...................................................................................................................... 114 

12.2 TRUE-UP for FY07: ...................................................................................................................... 115 

12.3 TRUE-UP for FY08: ...................................................................................................................... 116 

12.4 TRUE-UP for FY09: ...................................................................................................................... 116 

12.5 TRUE-UP for FY10: ...................................................................................................................... 116 

A13: AGGREGATE REVENUE REQUIREMENT ........................................ 117 

A14: OTHER ITEMS ........................................................................................... 120 

14.1 Energy requirement .................................................................................................................... 120 

14.2 Fuel Surcharge Adjustment ....................................................................................................... 121 

14.3 Expensive Power Charges ......................................................................................................... 124 

A15: TARIFF PROPOSAL FOR FY-12 ............................................................ 126 

A16: COMPLIANCE ON TARIFF ORDER FY 2010-11 ................................ 144 



A1: ESTIMATION OF SALES 

1.1 Provision of Regulation: 

1.1.1 Regulation 22 provides for the method of estimation of sales for each year 

of tariff period. The relevant provision is reproduced as below:- 

22.1 The estimation of the sale for each year of the Tariff period shall be 

based on the category wise and slab wise actual / audited data of the 

sale of electricity, number of consumers, connected / contracted load, 

etc. of the preceding four years. The year wise projections of the 

aforementioned parameters for the tariff period shall also be provided 

along with the tariff petition. 

22.2 The reasonableness of growth in number of consumers, consumption, 

demand of electricity and trend of reduction of losses in previous 

years and anticipated growth in the next years and any other factor, 

which the Commission may consider relevant, may be examined and 

subsequently approved for deciding the quantum of electricity to be 

purchased by the Licensees with such modifications as deemed fit. 

1.2 Method adopted for Estimation of Sales: 

1.2.1 For the purpose of projection of sales for FY12, the distribution licensee 

has considered category wise and slab wise actual data of the sale of 

electricity, number of consumers, connected / contracted load, etc. of the 

preceding four years i.e. FY07, FY08, FY09, FY10 and available data of 

the FY11 i.e. up to the month of Aug‟10. 

1.2.2 The licensee in its first filing for MYT period FY11 to FY13 had projected 

the Sales based on the actual data of FY09. Since the actual data of FY10 is 

now available and it has been observed that the actual sales during FY10 

have significantly deviated from the sales forecast projections made by the 

Licensee and allowed by the Hon‟ble Commission during the previous 

filings and therefore, licensee feels that it will be appropriate to revise its 

sales forecast for FY-12. 



1.2.3 As mentioned in the preceding Para, the licensee has proposed to update its 

Sales Projection on the basis of actual sales and the actual supply hours for 

the period FY10. Further, it is submitted that the Electricity Distribution 

business of the four Rural Electricity co-operative societies viz. Amarpatan, 

Sidhi, Nowgaon and Loundi has been taken over by MPPKVVCL, Jabalpur 

w.e.f 15 th Aug‟10 and therefore consumers of these societies are now the 

consumers of MPPKVVCL. Due to this merger of societies, the sales that 

were approved for HV-7 category in the tariff order FY-11will have a 

shortfall and the LT sales will increase due to retail sales in the societies. 

On account of these changes and since Actual Sales now being available, 

the licensee feels that it is more appropriate to revise the estimated sales as 

approved in the tariff order FY11. The revised estimate of energy sales is 

indicated in table below:- 

Table-1: Comparisons of Revised Estimate of Sale wrt Allowed in Tariff Order For FY11 

TC Category 1 Tariff Order RE Difference % Change 

LV 1 Domestic 1803.22 1934.47 131.25 7.28% 

LV 2 Non-Domestic 349.24 379.21 29.98 8.58% 

LV 3.1 WW & Street Light 198.07 212.07 14.01 7.07% 

LV 4 LT Industrial 216.36 222.54 6.17 2.85% 

LV 5.1 Agriculture Irrigation Pumps 1647.83 1678.52 30.69 1.86% 

LV 5.2 Agriculture related Use 1.34 2.15 0.81 60.04% 

Total (LT) 4216.07 4428.96 212.90 5.05% 

HV 1 Railway Traction 457.55 496.18 38.63 8.44% 

HV 2 Coal Mines 522.63 498.59 -24.04 -4.60% 

HV 3.1 Industrial 1016.72 1063.64 46.92 4.61% 

HV 3.2 Non-Industrial 143.55 161.69 18.14 12.63% 

HV 4 Seasonal 3.21 4.65 1.43 44.65% 

HV 5.1 Public Water Works 48.51 53.13 4.62 9.53% 

HV 5.1 Irrigation 5.79 3.90 -1.89 -32.62% 

HV 5.2 Other Agricultural 8.80 9.77 0.96 10.96% 

HV 6 Bulk Residential Users 317.42 336.85 19.43 6.12% 

HV 7 Bulk Supply to Exemptees 491.79 120.75 -371.04 -75.45% 

Total (HT) 3015.97 2749.15 -266.82 -8.85% 

TOTAL LT+HT 7232.04 7178.11 -53.92 -0.75% 

1.2.4 The sales for FY-12 & FY-13 have been projected on the basis of the actual 

data of Number of Consumers, Connected Load and Consumption during 

the last 4 years and on the basis of revised estimate for FY11. 

1.2.5 The approach being followed is to analyze the Cumulative Annual Growth 

Rates (CAGRs) of each category and its sub-categories in respect of urban 

& rural consumers separately. In order to achieve better precision in 

forecasting, the base data as compared to previous years has been analyzed 



in more details. After analysis of the data, appropriate / reasonable growth 

rates have been taken for future consumer forecasts from the past CAGRs 

of the Category/Sub-category. The past CAGR on sales per consumer/sales 

per kW and connected load has been applied while forecasting the 

connected load and sales in each category/sub-category. The use of specific 

consumption i.e. consumption per consumer and / or consumption per unit 

load is the basic forecasting variables and it follows from the well known 

Partial end use method which is widely used in load and energy sales 

forecasting. The basic intent in using this model is that, the specific 

consumption per consumer and / or consumption per unit load captures 

more faithfully and realistically, the trends and variations in the usage of 

electricity over a growth cycle- e.g. accelerated growth followed by 

moderate growth followed by saturation, and so on. This method has also 

been recommended by the C.E.A. 

1.2.6 The forecast also considers the impact of schemes / plans of licensee such 

as the RGGVY (Rajiv Gandhi Grameen Vidyutikiran Yojana), future 

meterization plan of urban domestic consumers and separation of feeders of 

Agricultural and other categories of consumers and also the increase in 

supply hours. The projection of each tariff category and the relevant 

assumptions has been discussed in the following Paras. 

1.2.7 The overall sales forecast of the MPPKVVCL, Jabalpur (in MUs) is as 

follows: 



Table-2: Revised Estimate of Sale for FY11 and Sales Projection for FY12 & FY13 (in MU) 

TC Category 1 FY11 (RE) FY12 FY13 

LV 1 Domestic 1934.47 2822.66 3716.57 

LV 2 Non-Domestic 379.21 407.52 438.06 

LV 3.1 WW & Street Light 212.07 243.74 281.66 

LV 4 LT Industrial 222.54 238.94 256.81 

LV 5.1 Agriculture Irrigation Pumps 1678.52 1898.81 2053.65 

LV 5.2 Agriculture related Use 2.15 2.22 2.30 

Total (LT) 4428.96 5613.89 6749.03 

HV 1 Railway Traction 496.18 529.25 564.52 

HV 2 Coal Mines 498.59 514.15 530.36 

HV 3.1 Industrial 1063.64 1107.84 1154.52 

HV 3.2 Non-Industrial 161.69 173.55 186.56 

HV 4 Seasonal 4.65 4.65 4.65 

HV 5.1 Public Water Works 53.13 57.09 61.51 

HV 5.1 Irrigation 3.90 4.05 4.20 

HV 5.2 Other Agricultural 9.77 10.49 11.27 

HV 6 Bulk Residential Users 336.85 370.53 407.58 

HV 7 Bulk Supply to Exemptees 120.75 0.00 0.00 

Total (HT) 2749.15 2771.59 2925.17 

TOTAL LT+HT 7178.11 8385.49 9674.20 

1.3 Category-wise sales projection 

1.3.1 LV -1: Domestic 

1.3.1.1 The historical data in this category is as below: 

Table-3: LV-1 Domestic Consumer Historical Data 

Area Sub CONSUMERS (No.) 

3 Year 2 Year 1 Year 

Category FY06-07 FY07-08 FY08-09 FY09-10 CAGR CAGR Growth 

Urban Metered 736818 739130 761271 809456 3.18% 4.65% 6.33% 

Urban Unmetered 24645 11736 7037 9036 -28.43% -12.25% 28.41% 

Urban Temporary 2467 4867 4782 5885 33.62% 9.96% 23.07% 

Urban Total 763930 755733 773090 824377 2.57% 4.44% 6.63% 

Rural Metered 674230 690117 677290 651818 -1.12% -2.81% -3.76% 

Rural Un-metered 356498 663767 730135 766213 29.05% 7.44% 4.94% 

Rural Temporary 558 1048 1206 861 15.56% -9.36% -28.61% 

Rural Total 1031286 1354932 1408631 1418892 11.22% 2.33% 0.73% 

Total Metered 1411048 1429247 1438561 1461274 1.17% 1.11% 1.58% 

Total Un-metered 381143 675503 737172 775249 26.70% 7.13% 5.17% 

Total Temporary 3025 5915 5988 6746 30.65% 6.79% 12.66% 

Total Total 1795216 2110665 2181721 2243269 7.71% 3.09% 2.82% 

Table-4: LV-1 Domestic Load Historical Data 

Area Sub LOAD (kW) 



Urban Metered 458890 477838 501580 536515 5.35% 5.96% 6.96% 

Urban Unmetered 2616 1410 1101 2020 -8.26% 19.69% 83.47% 

Urban Temporary 5470 4729 8924 4848 -3.94% 1.25% -45.67% 

Urban Total 466976 483977 511605 543383 5.18% 5.96% 6.21% 

Rural Metered 175354 181793 178486 169738 -1.08% -3.37% -4.90% 

Rural Un-metered 15638 44141 52151 55424 52.47% 12.05% 6.28% 

Rural Temporary 419 1340 3106 748 21.31% -25.29% -75.92% 

Rural Total 191411 227274 233743 225910 5.68% -0.30% -3.35% 

Total Metered 634244 659631 680066 706253 3.65% 3.47% 3.85% 

Total Un-metered 18254 45551 53252 57444 46.54% 12.30% 7.87% 

Total Temporary 5889 6069 12030 5596 -1.69% -3.98% -53.48% 

Total Total 658387 711251 745348 769293 5.33% 4.00% 3.21% 



Table-5: LV-1 Domestic Unit Historical Data 

Area Sub Unit (MU) 



Urban Metered 712.50 753.69 768.10 850.74 6.09% 6.24% 10.76% 

Urban Unmetered 114.78 15.17 8.82 8.42 -58.14% -25.50% -4.56% 

Urban Temporary 3.67 4.67 5.02 6.38 20.23% 16.86% 26.94% 

Urban Total 830.95 773.53 781.94 865.54 1.37% 5.78% 10.69% 

Rural Metered 302.27 313.74 311.32 312.78 1.15% -0.15% 0.47% 

Rural Un-metered 218.61 307.42 269.40 279.04 8.48% -4.73% 3.58% 

Rural Temporary 0.71 1.03 1.00 1.01 12.56% -0.99% 1.10% 

Rural Total 521.59 622.18 581.71 592.83 4.36% -2.39% 1.91% 

Total Metered 1014.77 1067.43 1079.41 1163.52 4.67% 4.40% 7.79% 

Total Un-metered 333.39 322.59 278.22 287.46 -4.82% -5.60% 3.32% 

Total Temporary 4.38 5.70 6.02 7.39 19.06% 13.85% 22.67% 

Total Total 1352.54 1395.71 1363.66 1458.37 2.54% 2.22% 6.95% 

1.3.1.2 The growth rates used for future projections are as given below: 

Table:-6 LV-1 Growth Considered For Projection 

Area Category 

Urban 

Rural 

Metered Consumer 6.63% DLF 3 year CAGR used 11.22% DLF 3 year CAGR used 

Metered 

Average 

Load/Consumer 

Same as for 2009-10 

Same as for 2009-10, but 

for RGGY 300 W load per 

consumer is used. 

Metered 

Average 

Unit/Consumer 

12.93% 

Assumed that due to 

increase in supply hours in 

urban area the average 

unit per consumer will go 

up by 12.93% 

20.00% 

Assumed that due to 

increase in supply hours 

the average unit per 

consumer will go up by 

20% 

Un-metered Consumer 0.00% 

Un-metered 

Un-metered 

Average 

Load/Consumer 

Average 

Unit/Consumer 

Temporary Consumer 9.96% 

Temporary 

Temporary 

Average 

Load/Consumer 

Average 

Unit/Consumer 

All unmetered Connection 

will be metered by end of 

current year 

3.46% 

Under Regularization of 

connection, it is expected 

that the consumers will 

increase. 

same as for 2009-10 same as for 2009-10 

77 units per consumer for 

FY 10-11 and thereafter 

nil. 

Temporary 2 year CAGR 

used 

30 units for FY 10-11 but 

thereafter at par with 

0.00% 

metered rural consumer is 

used. 

Temporary Current year 

14.66% 

growth is used. 



1.3.1.3 The projections of consumption of rural un-metered domestic connections 

have been considered as 58 units/ consumer/ month which are based on the 

average consumption per consumer per month for metered connections in 

rural area. In addition to the rate of growth assumed as indicated above, the 



impact of implementation of the RGGVY has been taken into account for 

future Consumer / Load / Consumption projections. The implementation 

roadmap of the RGGVY which has been considered for future projections 

by the company is: 

Table:-7 LV-1 Domestic RGGY Assumption 

Year 2010-11 2011-12 2012-13 

Target 213850 300000 242802 

1.3.1.4 The connected load per consumer for consumers added under the RGGVY 

has been taken as 300 watt per consumer. The consumption of the 

consumers is assumed at par with the metered consumption per consumer 

per month for rural consumers. 

1.3.1.5 The sales forecast also considers the meterization of all urban unmetered 

consumers in the general category over the next year. After incorporating 

the growth due to the RGGVY and merger of RE Co-operative Societies, 

the following projections for LV-1 have been arrived at: 

Table:-8 LV-1 Domestic Consumer Projection 

Area Sub 

CONSUMERS (No.) 

Category FY10-11 FY11-12 FY12-13 

Urban Metered 893368 962421 1026269 

Urban Un-metered 9787 0 0 

Urban Temporary 6572 7227 7947 

Urban Total 909728 969649 1034216 

Rural Metered 983114 1369439 1732252 

Rural Un-metered 807265 835186 864072 

Rural Temporary 1063 1219 1397 

Rural Total 1791442 2205844 2597721 

Total Metered 1876482 2331861 2758521 

Total Un-metered 817052 835186 864072 

Total Temporary 7635 8446 9345 

Total Total 2701169 3175492 3631937 

Table:-9 LV-1 Domestic Load Projection 

Area Sub 

LOAD (kW) 


Urban Metered 592133 637902 680221 

Urban Un-metered 2188 0 0 


Urban Total 599735 643856 686767 

Rural Metered 264477 368489 460704 

Rural Un-metered 58394 60413 62503 


Rural Total 323794 429961 524420 

Total Metered 856609 1006391 1140924 

Total Un-metered 60581 60413 62503 


Total Total 923529 1073817 1211188 



Table:-10 LV-1 Domestic Unit Projection 

Area Sub 

Unit (MU) 


Urban Metered 1060.33 1289.99 1553.43 

Urban Un-metered 9.04 0.00 0.00 

Urban Temporary 7.12 7.83 8.61 

Urban Total 1076.50 1297.82 1562.04 

Rural Metered 566.11 946.29 1436.39 

Rural Un-metered 290.62 577.12 716.49 

Rural Temporary 1.24 1.43 1.64 

Rural Total 857.97 1524.83 2154.52 

Total Metered 1626.45 2236.28 2989.82 

Total Un-metered 299.66 577.12 716.49 

Total Temporary 8.37 9.26 10.25 

Total Total 1934.47 2822.66 3716.57 

1.3.2 LV -2: Non- Domestic 

1.3.2.1 The historical data of the category is as below: 

Table:-11 LV-2 Non-Domestic Consumer Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 

CAGR CAGR Growth 

Urban Metered 157179 154012 157089 163410 1.30% 3.01% 4.02% 


Urban Total 157660 154961 158462 165294 1.59% 3.28% 4.31% 

Rural Metered 35556 41335 42038 42404 6.05% 1.28% 0.87% 

Rural Temporary 233 732 1055 1212 73.27% 28.68% 14.88% 

Rural Total 35789 42067 43093 43616 6.81% 1.82% 1.21% 

Total Metered 192735 195347 199127 205814 2.21% 2.64% 3.36% 


Total Total 193449 197028 201555 208910 2.60% 2.97% 3.65% 

Table:-12 LV-2 Non-Domestic Load Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Metered 187690 194209 206655 229238 6.89% 8.64% 10.93% 


Urban Total 189386 196893 213060 237991 7.91% 9.94% 11.70% 

Rural Metered 28842 35990 42598 52791 22.32% 21.11% 23.93% 

Rural Temporary 919 2895 4667 4897 74.66% 30.06% 4.93% 

Rural Total 29761 38885 47265 57688 24.68% 21.80% 22.05% 

Total Metered 216532 230199 249253 282029 9.21% 10.69% 13.15% 


Total Total 219147 235778 260325 295679 10.50% 11.98% 13.58% 



Table:-13 LV-2 Non-Domestic Unit Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Metered 206.69 229.59 242.02 274.32 9.90% 9.31% 13.34% 

Urban Temporary 2.73 5.22 6.77 11.87 63.30% 50.83% 75.22% 

Urban Total 209.42 234.81 248.80 286.19 10.97% 10.40% 15.03% 

Rural Metered 29.54 34.83 39.43 50.17 19.30% 20.02% 27.24% 

Rural Temporary 0.70 2.00 3.89 5.19 95.06% 61.22% 33.38% 

Rural Total 30.24 36.83 43.32 55.36 22.32% 22.60% 27.79% 

Total Metered 236.23 264.42 281.45 324.49 11.16% 10.78% 15.29% 


Total Total 239.66 271.63 292.12 341.55 12.53% 12.13% 16.92% 

1.3.2.2 The growth rates used for future projections are as given below: 

Table:-14 LV-2 Growth Considered For Projection 

Area Category 

Urban 

Metered Consumer 

Metered 3 Year CAGR 

1.30% 

used 

0.87% 

Rural 

Metered 1 year Growth 

used 

Metered 

Average 

Load/Consumer 

5.52% 

3 year CAGR of average 

load per consumer for 

metered is used. 

5.52% 


load per consumer for 


Metered Average Unit/kW 0.61% 


consumption per kW for 


2.67% 

Metered 1 year Growth 

is used 

Temporary Consumer 0.00% same as for 2009-10 0.00% same as for 2009-10 

Temporary 

Average 

Load/Consumer 

0.00% same as for 2009-10 0% same as for 2009-10 

Temporary Average Unit/kW 0.00% same as for 2009-10 0% same as for 2009-10 

1.3.2.3 Based on the above growth rates and including the consumers of the RECS, 

the projections for LV-2 the category till FY13 are: 

Table:-15 LV-2 Non-Domestic Consumer Projection 

Area Sub 



Urban Metered 170666 172892 175148 


Urban Total 172577 174803 177059 

Rural Metered 45052 45444 45840 


Rural Total 46284 46676 47072 

Total Metered 215718 218337 220987 


Total Total 218861 221480 224130 



Table:-16 LV-2 Non-Domestic Load Projection 

Area Sub 

LOAD (kW) 


Urban Metered 252625 270038 288651 


Urban Total 261504 278916 297530 

Rural Metered 59182 62990 67043 


Rural Total 64159 67968 72021 

Total Metered 311807 333028 355695 


Total Total 325663 346884 369551 

Table:-17 LV-2 Non-Domestic Unit Projection 

Area Sub 

Unit (MU) 


Urban Metered 304.16 327.11 351.79 


Urban Total 316.20 339.15 363.83 

Rural Metered 57.74 63.10 68.95 


Rural Total 63.02 68.37 74.22 

Total Metered 361.90 390.20 420.74 


Total Total 379.21 407.52 438.06 

1.3.3 LV -3.1: Public Water Works 

1.3.3.1 The historical data for the category is as below: 

Table:-18 LV-3.1 Public Water Works Consumer Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Municipal Corp. 1649 1448 1499 1456 -4.06% 0.28% -2.87% 

Urban Nagar Panchayat 527 752 821 988 23.31% 14.62% 20.34% 

Urban Gram Panchayat 372 236 251 388 1.41% 28.22% 54.58% 

Urban Temporary 66 64 107 101 15.24% 25.62% -5.61% 

Urban Total 2614 2500 2678 2933 3.91% 8.31% 9.52% 

Rural Municipal Corp. 578 385 318 191 -30.86% -29.57% -39.94% 

Rural Nagar Panchayat 45 104 122 93 27.38% -5.44% -23.77% 

Rural Gram Panchayat 1997 2498 2688 2894 13.16% 7.63% 7.66% 

Rural Temporary 58 91 115 114 25.26% 11.93% -0.87% 

Rural Total 2678 3078 3243 3292 7.12% 3.42% 1.51% 

Total Municipal Corp. 2227 1833 1817 1647 -9.57% -5.21% -9.36% 

Total Nagar Panchayat 572 856 943 1081 23.64% 12.38% 14.63% 

Total Gram Panchayat 2369 2734 2939 3282 11.48% 9.56% 11.67% 

Total Temporary 124 155 222 215 20.14% 17.78% -3.15% 

Total Total 5292 5578 5921 6225 5.56% 5.64% 5.13% 



Table:-19 LV-3.1 Public Water Works Load Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Municipal Corp. 10116 8461 8834 8534 -5.51% 0.43% -3.40% 


Urban Gram Panchayat 1873 1216 1343 2076 3.49% 30.66% 54.58% 

Urban Temporary 329 330 536 421 8.57% 12.95% -21.46% 

Urban Total 17025 16225 17304 18994 3.72% 8.20% 9.77% 


Rural Nagar Panchayat 725 1129 1311 1098 14.84% -1.38% -16.25% 

Rural Gram Panchayat 9671 11952 12833 13795 12.57% 7.43% 7.50% 

Rural Temporary 238 344 433 365 15.32% 3.01% -15.70% 

Rural Total 13889 15606 16212 16103 5.05% 1.58% -0.67% 

Total Municipal Corp. 13371 10642 10469 9379 -11.15% -6.12% -10.41% 


Total Gram Panchayat 11544 13168 14176 15871 11.19% 9.78% 11.96% 

Total Temporary 567 674 969 786 11.50% 7.99% -18.89% 

Total Total 30914 31831 33516 35097 4.32% 5.00% 4.72% 

Table:-20 LV-3.1 Public Water Works Unit Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Municipal Corp. 33.11 33.64 41.36 47.18 12.53% 18.42% 14.06% 

Urban Nagar Panchayat 8.08 19.38 22.69 24.47 44.67% 12.37% 7.85% 

Urban Gram Panchayat 1.77 3.59 2.79 3.63 26.95% 0.51% 29.85% 

Urban Temporary 0.92 1.47 1.12 1.31 12.70% -5.58% 17.26% 

Urban Total 43.88 58.08 67.97 76.59 20.40% 14.83% 12.69% 

Rural Municipal Corp. 11.14 3.49 2.12 1.96 -43.99% -25.12% -7.55% 

Rural Nagar Panchayat 1.45 3.21 3.46 3.67 36.23% 6.97% 6.12% 

Rural Gram Panchayat 7.80 16.66 18.65 17.87 31.82% 3.55% -4.20% 

Rural Temporary 0.48 0.58 0.66 0.79 17.88% 16.97% 19.45% 

Rural Total 20.87 23.94 24.89 24.28 5.18% 0.72% -2.42% 

Total Municipal Corp. 44.24 37.13 43.48 49.13 3.56% 15.04% 13.01% 

Total Nagar Panchayat 9.53 22.59 26.15 28.14 43.45% 11.62% 7.62% 

Total Gram Panchayat 9.57 20.26 21.44 21.50 30.94% 3.02% 0.24% 


Total Total 64.75 82.02 92.85 100.87 15.92% 10.90% 8.64% 



1.3.3.2 The following growth rates have been used for future projections: 

Table:-21 LV-3.1 Growth Considered For Projection 

Area Category 

Urban 

Rural 

Municipal Consumer 0.28% 2 Year CAGR used 0.00% same as for 2009-10 

Corporation Current year growth in 

Average 

1.11% average load per 

Load/Consumer 


0.00% same as for 2009-10 

Average Unit/kW 

Current year growth in 

11.70% average consumption 0.00% same as for 2009-10 

per kW is used. 

Nagar Consumer 14.62% 3 Year CAGR used 0.00% same as for 2009-10 

Panchayat 

Gram 

Panchayat 

Average 

Load/Consumer 

4.41% 

Average Unit/kW 9.12% 


load per consumer is 

used. 

Current year growth in 

average consumption 

per kW is used. 

Consumer 0.00% same as for 2009-10 12.91% 

Average 

Load/Consumer 

0.00% same as for 2009-10 5.45% 

0.00% same as for 2009-10 

0.00% same as for 2009-10 

Current year growth 

used. 

2 year CAGR of overall 

rural average load per 


Current year growth 

Average Unit/kW 0.00% same as for 2009-10 3.47% 

used. 


Average 

Load/Consumer 

0.00% same as for 2009-10 0.00% same as for 2009-10 

Average Unit/kW 0.00% same as for 2009-10 0.00% same as for 2009-10 

1.3.3.3 The future projections are based on the above growth rates and includes the 

consumers of the then RECS as given below: 

Table:-22 LV-3.1 PWW Consumer Projection 

Area Sub 



Urban Municipal Corp. 1511 1515 1520 

Urban Nagar Panchayat 1190 1364 1563 

Urban Gram Panchayat 410 410 410 


Urban Total 3213 3391 3595 

Rural Municipal Corp. 192 192 192 

Rural Nagar Panchayat 95 95 95 

Rural Gram Panchayat 3446 3891 4393 


Rural Total 3847 4292 4794 

Total Municipal Corp. 1703 1707 1712 

Total Nagar Panchayat 1285 1459 1658 

Total Gram Panchayat 3856 4301 4803 


Total Total 7060 7683 8389 



Table:-23 LV-3.1 PWW Load Projection 

Area Sub 

LOAD (kW) 






Urban Total 21587 23681 26165 





Rural Total 19658 22960 26892 





Total Total 41245 46642 53057 

Table:-24 LV-3.1 PWW Unit Projection 

Area Sub 

Unit (MU) 


Urban Municipal Corp. 55.30 62.63 70.92 

Urban Nagar Panchayat 33.58 43.85 57.27 

Urban Gram Panchayat 3.83 3.83 3.83 


Urban Total 93.28 110.90 132.64 

Rural Municipal Corp. 1.97 1.97 1.97 

Rural Nagar Panchayat 3.75 3.75 3.75 

Rural Gram Panchayat 23.21 28.60 35.23 


Rural Total 29.72 35.10 41.73 

Total Municipal Corp. 57.27 64.59 72.89 

Total Nagar Panchayat 37.33 47.60 61.02 

Total Gram Panchayat 27.05 32.43 39.06 


Total Total 123.00 146.00 174.37 



1.3.4 LV -3.2: Street Light 

1.3.4.1 The historical data for the category is as below: 

Table:-25 LV-3.2 Street Light Consumer Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Municipal Corp. 507 547 582 625 7.22% 6.89% 7.39% 


Urban Gram Panchayat 400 165 162 243 -15.31% 21.36% 50.00% 

Urban Total 1678 1537 1566 1746 1.33% 6.58% 11.49% 


Rural Nagar Panchayat 73 73 70 37 -20.27% -28.81% -47.14% 

Rural Gram Panchayat 3029 3131 2975 2828 -2.26% -4.96% -4.94% 

Rural Total 3124 3223 3063 2873 -2.75% -5.59% -6.20% 

Total Municipal Corp. 529 566 600 633 6.17% 5.75% 5.50% 


Total Gram Panchayat 3429 3296 3137 3071 -3.61% -3.47% -2.10% 

Total Total 4802 4760 4629 4619 -1.29% -1.49% -0.22% 

Table:-26 LV-3.2 Street Light Load Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Municipal Corp. 6431 7396 7991 8720 10.68% 8.58% 9.12% 


Urban Gram Panchayat 1116 431 362 439 -26.73% 0.92% 21.27% 

Urban Total 14601 15502 16177 17663 6.55% 6.74% 9.19% 


Rural Nagar Panchayat 230 297 273 138 -15.66% -31.84% -49.45% 

Rural Gram Panchayat 3456 3787 3552 3379 -0.75% -5.54% -4.87% 

Rural Total 3747 4118 3853 3533 -1.94% -7.37% -8.31% 

Total Municipal Corp. 6492 7430 8019 8736 10.40% 8.43% 8.94% 


Total Gram Panchayat 4572 4218 3914 3818 -5.83% -4.86% -2.45% 

Total Total 18348 19620 20030 21196 4.93% 3.94% 5.82% 

Table:-27 LV-3.2 Street Light Unit Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Municipal Corp. 26.64 29.12 38.27 42.99 17.30% 21.50% 12.33% 

Urban Nagar Panchayat 13.92 25.62 27.74 30.00 29.16% 8.22% 8.13% 

Urban Gram Panchayat 3.60 1.00 1.09 0.83 -38.61% -8.58% -23.52% 

Urban Total 44.16 55.74 67.10 73.82 18.68% 15.09% 10.01% 

Rural Municipal Corp. 1.29 0.14 0.19 0.10 -57.25% -15.50% -46.66% 

Rural Nagar Panchayat 0.26 0.75 0.89 0.82 46.35% 4.58% -7.94% 

Rural Gram Panchayat 2.25 3.63 4.24 3.73 18.40% 1.50% -11.82% 

Rural Total 3.80 4.52 5.31 4.66 6.98% 1.53% -12.41% 

Total Municipal Corp. 27.93 29.27 38.46 43.09 15.56% 21.34% 12.04% 

Total Nagar Panchayat 14.18 26.36 28.63 30.82 29.52% 8.12% 7.63% 

Total Gram Panchayat 5.85 4.62 5.33 4.57 -7.93% -0.59% -14.21% 

Total Total 47.97 60.25 72.42 78.48 17.83% 14.13% 8.37% 





Area Category 

Urban 

Rural 

Municipal Consumer 7.39% 1 Year growth used 0.00% same as for 2009-10 

Corporation 

Average 

1 year growth in average 

0.51% load per consumer is 

Load/Consumer 

used. 

0.00% same as for 2009-10 


Average Unit/kW 2.99% consumption per kW is 0.00% same as for 2009-10 

used. 

Nagar Consumer 6.81% 1 Year growth used 0.00% same as for 2009-10 

Panchayat 

Average 

Load/Consumer 

0.53% 

Average Unit/kW 0.57% 

Current year growth of 

average load per 



consumption per kW is 

used. 

0.00% same as for 2009-10 

0.00% same as for 2009-10 

Gram Consumer 0.00% same as for 2009-10 0.00% same as for 2009-10 

Current year growth of 

Average 

Panchayat 

0.00% same as for 2009-10 1.53% average load per 

Load/Consumer 


Current year overall 

Average Unit/kW 0.00% same as for 2009-10 9.50% 

growth used. 

1.3.4.3 The future projections based on the above growth rates including consumers 

of the then RECS are as below: 

Table:-29 LV-3.2 Street Light Consumer Projection 

Area Sub 






Urban Total 1914 2032 2158 




Rural Total 2959 2959 2959 




Total Total 4873 4991 5117 



Table:-30 LV-3.2 Street Light Load Projection 

Area Sub 

LOAD (kW) 





Urban Total 19669 21140 22723 




Rural Total 3696 3750 3805 




Total Total 23365 24889 26528 

Table:-31 LV-3.2 Street Light Unit Projection 

Area Sub 

Unit (MU) 


Urban Municipal Corp. 49.09 54.57 60.66 

Urban Nagar Panchayat 33.91 36.61 39.53 

Urban Gram Panchayat 0.84 0.84 0.84 

Urban Total 83.84 92.03 101.04 

Rural Municipal Corp. 0.11 0.11 0.11 

Rural Nagar Panchayat 0.84 0.84 0.84 

Rural Gram Panchayat 4.28 4.76 5.29 

Rural Total 5.24 5.71 6.25 

Total Municipal Corp. 49.20 54.68 60.77 

Total Nagar Panchayat 34.75 37.45 40.38 

Total Gram Panchayat 5.12 5.60 6.13 

Total Total 89.07 97.74 107.28 

1.3.5 LV -4.1: Non Seasonal Industrial 


Table:-32 LV-4.1 Non-Seasonal Industrial Consumer Historical Data 

Area Sub CONSUMERS (No.) 3 Year 2 Year 1 Year 

Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Upto 25HP 9184 9858 9886 10314 3.94% 2.29% 4.33% 

Urban Above 25HP to 100HP 596 859 961 1059 21.12% 11.03% 10.20% 

Urban Above 100HP 32 29 31 29 -3.23% 0.00% -6.45% 

Urban Temporary LT Ind. 58 61 67 99 19.51% 27.40% 47.76% 

Urban Total 9870 10807 10945 11501 5.23% 3.16% 5.08% 

Rural Upto 25HP 4076 15068 16192 16774 60.25% 5.51% 3.59% 

Rural Above 25HP to 100HP 390 327 329 311 -7.27% -2.48% -5.47% 

Rural Above 100HP 6 3 2 1 -44.97% -42.26% -50.00% 

Rural Temporary LT Ind. 51 798 568 330 86.34% -35.69% -41.90% 

Rural Total 4523 16196 17091 17416 56.74% 3.70% 1.90% 

Total Upto 25HP 13260 24926 26078 27088 26.89% 4.25% 3.87% 

Total Above 25HP to 100HP 986 1186 1290 1370 11.59% 7.48% 6.20% 

Total Above 100HP 38 32 33 30 -7.58% -3.18% -9.09% 

Total Temporary LT Ind. 109 859 635 429 57.89% -29.33% -32.44% 

Total Total 14393 27003 28036 28917 26.18% 3.48% 3.14% 



Table:-33 LV-4.1 Non-Seasonal Industrial Load Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Upto 25HP 62650 67792 69012 72334 4.91% 3.30% 4.81% 

Urban Above 25HP to 100HP 25215 37191 41908 46195 22.36% 11.45% 10.23% 

Urban Above 100HP 3973 3087 3272 2941 -9.54% -2.39% -10.12% 

Urban Temporary LT Ind. 213 318 517 710 49.38% 49.42% 37.33% 

Urban Total 92051 108388 114709 122180 9.90% 6.17% 6.51% 

Rural Upto 25HP 21287 76298 80588 81588 56.50% 3.41% 1.24% 

Rural Above 25HP to 100HP 16133 12990 13234 13064 -6.79% 0.28% -1.28% 

Rural Above 100HP 534 272 174 91 -44.56% -42.16% -47.70% 

Rural Temporary LT Ind. 207 2815 2169 1268 82.97% -32.88% -41.54% 

Rural Total 38161 92375 96165 96011 36.01% 1.95% -0.16% 

Total Upto 25HP 83937 144090 149600 153922 22.40% 3.36% 2.89% 

Total Above 25HP to 100HP 41348 50181 55142 59259 12.75% 8.67% 7.47% 

Total Above 100HP 4507 3359 3446 3032 -12.38% -4.99% -12.01% 

Total Temporary LT Ind. 420 3133 2686 1978 67.62% -20.54% -26.36% 

Total Total 130212 200763 210874 218191 18.78% 4.25% 3.47% 

Table:-34 LV-4.1 Non-SEasonal Industrial Unit Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Upto 25HP 50.35 49.99 52.04 55.02 3.00% 4.91% 5.72% 

Urban Above 25HP to 100HP 33.71 35.51 43.00 47.48 12.09% 15.64% 10.44% 

Urban Above 100HP 5.01 4.17 4.47 5.01 0.01% 9.61% 12.06% 

Urban Temporary LT Ind. 0.32 0.40 0.68 0.54 19.61% 16.21% -20.44% 

Urban Total 89.39 90.07 100.19 108.06 6.52% 9.53% 7.85% 

Rural Upto 25HP 23.21 44.81 50.25 53.00 31.69% 8.77% 5.48% 

Rural Above 25HP to 100HP 17.91 12.22 10.09 9.96 -17.76% -9.71% -1.30% 

Rural Above 100HP 1.55 0.95 0.38 0.28 -43.47% -45.90% -26.72% 

Rural Temporary LT Ind. 0.45 2.43 1.43 1.40 45.60% -24.20% -2.51% 

Rural Total 43.11 60.41 62.16 64.64 14.46% 3.44% 3.99% 

Total Upto 25HP 73.56 94.80 102.30 108.02 13.66% 6.75% 5.60% 

Total Above 25HP to 100HP 51.62 47.73 53.09 57.44 3.63% 9.71% 8.21% 

Total Above 100HP 6.56 5.13 4.85 5.29 -6.89% 1.60% 9.01% 

Total Temporary LT Ind. 0.77 2.84 2.12 1.94 36.07% -17.25% -8.29% 

Total Total 132.51 150.48 162.35 172.70 9.23% 7.13% 6.37% 



1.3.5.2 The growth rates used for future projections are as below: 


Area Category 

Urban 

Rural 

Upto 25HP Consumer 

Current year growth is 


3.32% 4.54% 

used. 

used. 

Average 


0.29% 

Load/Consumer 

used. 

0.00% same as for 2009-10 




4.58% 1.75% 

used. 

used. 

Above 25HP Consumer 



9.24% 1.87% 

used. 

used. 

to 100 HP 

Average 



0.71% 3.13% 

Load/Consumer 

used. 

used. 


Above 100HP Consumer 


6.67% 

used. 

0.00% same as for 2009-10 

Average 


0.00% same as for 2009-10 4.60% 

Load/Consumer 

used. 



Average 

Load/Consumer 

0.00% same as for 2009-10 0.00% same as for 2009-10 


1.3.5.3 The future projections based on the above growth rates and considering the 

then RECS consumers are as below: 

Table:-36 LV-4.1 Non-Seasonal Industrial Consumer Projection 

Area Sub 



Urban Upto 25HP 11180 11551 11934 

Urban Above 25HP to 100HP 1181 1290 1409 

Urban Above 100HP 35 38 40 

Urban Temporary LT Ind. 101 101 101 

Urban Total 12497 12979 13484 

Rural Upto 25HP 18681 19529 20416 

Rural Above 25HP to 100HP 334 340 347 

Rural Above 100HP 1 1 1 

Rural Temporary LT Ind. 354 354 354 

Rural Total 19370 20224 21118 

Total Upto 25HP 29860 31080 32350 

Total Above 25HP to 100HP 1515 1630 1756 

Total Above 100HP 36 39 41 

Total Temporary LT Ind. 455 455 455 

Total Total 31867 33204 34602 



Table:-37 LV-4.1 Non-Seasonal Industrial Load Projection 

Area Sub 

LOAD (kW) 


Urban Upto 25HP 78631 81472 84415 


Urban Above 100HP 3570 3808 4062 

Urban Temporary LT Ind. 724 724 724 

Urban Total 134802 143076 151989 

Rural Upto 25HP 90862 94989 99303 



Rural Temporary LT Ind. 1360 1360 1360 

Rural Total 106792 111656 116744 

Total Upto 25HP 169493 176461 183719 


Total Above 100HP 3665 3907 4166 

Total Temporary LT Ind. 2085 2085 2085 

Total Total 241595 254732 268733 

Table:-38 LV-4.1 Non-Seasonal Industrial Unit Projection 

Area Sub 

Unit (MU) 


Urban Upto 25HP 62.55 67.78 73.45 

Urban Above 25HP to 100HP 53.32 58.66 64.54 

Urban Above 100HP 6.08 6.49 6.92 

Urban Temporary LT Ind. 0.55 0.55 0.55 

Urban Total 122.51 133.48 145.46 

Rural Upto 25HP 60.06 63.89 67.96 

Rural Above 25HP to 100HP 11.04 11.59 12.18 

Rural Above 100HP 0.29 0.31 0.32 

Rural Temporary LT Ind. 1.50 1.50 1.50 

Rural Total 72.89 77.29 81.96 

Total Upto 25HP 122.61 131.66 141.40 

Total Above 25HP to 100HP 64.36 70.26 76.72 

Total Above 100HP 6.38 6.79 7.24 

Total Temporary LT Ind. 2.05 2.05 2.05 

Total Total 195.40 210.77 227.41 



1.3.6 LV -4.2: Seasonal Industrial 


Table:-39 LV-4.2 Seasonal Industrial Consumer Historical Data 


Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Upto 25HP 1477 1130 1039 981 -12.75% -6.83% -5.58% 

Urban Above 25HP to 100HP 351 268 253 232 -12.89% -6.96% -8.30% 

Urban Above 100HP 3 2 5 2 -12.64% 0.00% -60.00% 

Urban Total 1831 1400 1297 1215 -12.78% -6.84% -6.32% 

Rural Upto 25HP 341 402 333 302 -3.97% -13.33% -9.31% 


Rural Above 100HP 3 0 0 0 -100.00% 0.00% 0.00% 

Rural Total 414 453 365 324 -7.85% -15.43% -11.23% 

Total Upto 25HP 1818 1532 1372 1283 -10.97% -8.49% -6.49% 

Total Above 25HP to 100HP 421 319 285 254 -15.50% -10.77% -10.88% 

Total Above 100HP 6 2 5 2 -30.66% 0.00% -60.00% 

Total Total 2245 1853 1662 1539 -11.83% -8.87% -7.40% 

Table:-40 LV-4.2 Seasonal Industrial Load Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Upto 25HP 13073 10396 9590 8998 -11.71% -6.97% -6.17% 

Urban Above 25HP to 100HP 15204 11971 11165 9969 -13.12% -8.74% -10.71% 

Urban Above 100HP 417 305 343 224 -18.71% -14.30% -34.69% 

Urban Total 28694 22672 21098 19191 -12.55% -8.00% -9.04% 

Rural Upto 25HP 2667 2866 2441 2294 -4.90% -10.53% -6.02% 


Rural Above 100HP 222 0 0 0 -100.00% 0.00% 0.00% 

Rural Total 5691 4863 3620 3247 -17.06% -18.29% -10.30% 

Total Upto 25HP 15740 13262 12031 11292 -10.48% -7.73% -6.14% 

Total Above 25HP to 100HP 18006 13968 12344 10922 -15.35% -11.57% -11.52% 

Total Above 100HP 639 305 343 224 -29.49% -14.30% -34.69% 

Total Total 34385 27535 24718 22438 -13.26% -9.73% -9.22% 

Table:-41 LV-4.2 Seasonal Industrial Unit Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Upto 25HP 4.51 10.07 7.90 7.86 20.37% -11.63% -0.40% 

Urban Above 25HP to 100HP 10.32 17.26 14.79 13.68 9.86% -10.96% -7.48% 

Urban Above 100HP 0.34 0.44 0.36 0.14 -26.38% -44.13% -62.17% 

Urban Total 15.17 27.76 23.04 21.68 12.65% -11.63% -5.91% 

Rural Upto 25HP 0.88 2.09 1.77 1.77 26.12% -8.10% -0.06% 

Rural Above 25HP to 100HP 1.58 2.07 0.92 0.76 -21.55% -39.38% -16.93% 

Rural Above 100HP 0.14 0.00 0.00 0.00 -100.00% -100.00% -100.00% 

Rural Total 2.60 4.17 2.69 2.53 -0.85% -22.08% -5.83% 

Total Upto 25HP 5.39 12.16 9.66 9.63 21.35% -11.01% -0.34% 

Total Above 25HP to 100HP 11.90 19.33 15.70 14.44 6.68% -13.56% -8.04% 

Total Above 100HP 0.48 0.44 0.36 0.14 -34.17% -44.15% -62.19% 

Total Total 17.76 31.93 25.73 24.21 10.87% -12.92% -5.90% 



1.3.6.2 The growth rates used for future projections are as below: 


Area Category 

Urban 

Rural 

Upto 25HP Consumer 0.00% same as for 2009-10 0.00% same as for 2009-10 

Average 

Current year growth is Current year growth is 

0.12% 1.61% 

Load/Consumer 

used. 

used. 



3.72% 

used. 

8.05% 2 year CAGR is used. 

Above 25HP Consumer 0.00% same as for 2009-10 0.00% same as for 2009-10 

to 100 HP Average 


0.00% same as for 2009-10 22.21% 

Load/Consumer 

used. 

Average Unit/kW 0.00% same as for 2009-10 12.83% 2 year CAGR is used. 

Above 100HP Consumer 0.00% same as for 2009-10 0.00% same as for 2009-10 

Average 


0.00% same as for 2009-10 0.00% 

Load/Consumer 

used. 


1.3.6.3 The future projections based on the above growth rates and considering the 

then RECS consumers are as below: 

Table:-43 LV-4.2 Seasonal Industrial Consumer Projection 

Area Sub 



Urban Upto 25HP 1061 1061 1061 



Urban Total 1302 1302 1302 

Rural Upto 25HP 469 469 469 



Rural Total 491 491 491 

Total Upto 25HP 1530 1530 1530 



Total Total 1793 1793 1793 

Table:-44 LV-4.2 Seasonal Industrial Load Projection 

Area Sub 

LOAD (kW) 


Urban Upto 25HP 9743 9755 9767 



Urban Total 20306 20318 20330 

Rural Upto 25HP 3620 3678 3737 



Rural Total 4785 5101 5477 

Total Upto 25HP 13363 13433 13504 



Total Total 25091 25419 25806 



Table:-45 LV-4.2 Seasonal Industrial Unit Projection 

Area Sub 

Unit (MU) 


Urban Upto 25HP 8.83 9.17 9.52 

Urban Above 25HP to 100HP 14.03 14.03 14.03 

Urban Above 100HP 0.20 0.20 0.20 

Urban Total 23.07 23.41 23.76 

Rural Upto 25HP 3.02 3.31 3.64 

Rural Above 25HP to 100HP 1.05 1.45 2.00 

Rural Above 100HP 0.00 0.00 0.00 

Rural Total 4.07 4.76 5.63 

Total Upto 25HP 11.85 12.48 13.16 

Total Above 25HP to 100HP 15.09 15.48 16.03 

Total Above 100HP 0.20 0.20 0.20 

Total Total 27.14 28.17 29.40 

1.3.7 LV -5.1: Agricultural 

1.3.7.1 The historical data in the category is as below: 

Table:-46 LV-5.1 Agricultural Consumer Historical Data 


Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Metered Permanent 26595 19257 16855 17443 -13.12% -4.83% 3.49% 

Urban Metered Temporary 628 475 528 432 -11.72% -4.63% -18.18% 

Urban Un-Metered Permanent 30610 19503 12142 13198 -24.45% -17.74% 8.70% 

Urban Un-Metered Temporary 2667 3262 5988 5399 26.50% 28.65% -9.84% 

Urban Total 60500 42497 35513 36472 -15.52% -7.36% 2.70% 

Rural Metered Permanent 101812 114927 119302 111277 3.01% -1.60% -6.73% 

Rural Metered Temporary 1464 880 986 408 -34.68% -31.91% -58.62% 

Rural Un-Metered Permanent 105712 104865 104094 113376 2.36% 3.98% 8.92% 

Rural Un-Metered Temporary 45972 80735 162023 153361 49.42% 37.82% -5.35% 

Rural Total 254960 301407 386405 378422 14.07% 12.05% -2.07% 

Total Metered Permanent 128407 134184 136157 128720 0.08% -2.06% -5.46% 

Total Metered Temporary 2092 1355 1514 840 -26.23% -21.26% -44.52% 

Total Un-Metered Permanent 136322 124368 116236 126574 -2.44% 0.88% 8.89% 

Total Un-Metered Temporary 48639 83997 168011 158760 48.34% 37.48% -5.51% 

Total Total 315460 343904 421918 414894 9.56% 9.84% -1.66% 

Table:-47 LV-5.1 Agricultural Load Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Metered Permanent 72930 51939 44229 44501 -15.18% -7.44% 0.61% 

Urban Metered Temporary 1108 1044 1125 805 -10.10% -12.19% -28.44% 

Urban Un-Metered Permanent 75618 46652 27997 31567 -25.26% -17.74% 12.75% 

Urban Un-Metered Temporary 4850 4722 11303 10511 29.41% 49.20% -7.01% 

Urban Total 154506 104357 84654 87384 -17.30% -8.49% 3.22% 

Rural Metered Permanent 273105 306649 314103 283446 1.25% -3.86% -9.76% 

Rural Metered Temporary 2143 2144 1338 1150 -18.74% -26.76% -14.05% 

Rural Un-Metered Permanent 260268 254925 250226 279418 2.39% 4.69% 11.67% 

Rural Un-Metered Temporary 89526 109572 281430 284296 46.99% 61.08% 1.02% 

Rural Total 625042 673290 847097 848310 10.72% 12.25% 0.14% 

Total Metered Permanent 346035 358588 358332 327947 -1.77% -4.37% -8.48% 

Total Metered Temporary 3251 3188 2463 1955 -15.59% -21.69% -20.63% 

Total Un-Metered Permanent 335886 301577 278223 310985 -2.53% 1.55% 11.78% 

Total Un-Metered Temporary 94376 114294 292733 294807 46.18% 60.60% 0.71% 

Total Total 779548 777647 931751 935694 6.27% 9.69% 0.42% 



Table:-48 LV-5.1 Agricultural Unit Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Metered Permanent 54.54 44.24 43.40 47.45 -4.54% 3.56% 9.32% 

Urban Metered Temporary 4.85 1.76 1.43 1.24 -36.57% -16.04% -13.12% 

Urban Un-Metered Permanent 232.25 142.12 76.98 64.95 -34.61% -32.40% -15.63% 

Urban Un-Metered Temporary 9.95 14.15 13.64 18.42 22.79% 14.08% 35.02% 

Urban Total 301.59 202.27 135.45 132.05 -24.06% -19.20% -2.51% 

Rural Metered Permanent 185.16 225.68 273.26 284.84 15.44% 12.35% 4.24% 

Rural Metered Temporary 25.81 3.09 1.60 1.12 -64.91% -39.90% -30.33% 

Rural Un-Metered Permanent 747.05 711.14 520.41 513.84 -11.73% -15.00% -1.26% 

Rural Un-Metered Temporary 176.92 309.51 333.39 434.79 34.95% 18.52% 30.42% 

Rural Total 1134.94 1249.42 1128.66 1234.59 2.85% -0.60% 9.39% 

Total Metered Permanent 239.70 269.92 316.66 332.29 11.50% 10.95% 4.94% 

Total Metered Temporary 30.66 4.84 3.03 2.35 -57.50% -30.30% -22.23% 

Total Un-Metered Permanent 979.29 853.26 597.40 578.79 -16.08% -17.64% -3.12% 

Total Un-Metered Temporary 186.87 323.66 347.03 453.21 34.36% 18.33% 30.60% 

Total Total 1436.52 1451.69 1264.11 1366.64 -1.65% -2.97% 8.11% 

1.3.7.2 The growth used for future projections is as given below: 

The Hon‟ble Commission vide its tariff order for FY 10-11 has provided the 

assessed consumption of un-metered agricultural permanent 3-phase pump 

connections for the purpose of billing as follows: 

Period Rural Area Urban Area 

October to March @ 150 units/HP/month @ 170 units/HP/month 

April & May @ 40 units/HP/month @ 70 units/HP/month 

June to September @ 55 units/HP/month @ 100 units/HP/month 

The licensee in this context submits that the previous load trends and the 

data of monthly input to rural area indicates that there is a remarkable 

change in the irrigation pattern and the agricultural season is continuing up 

to April and even up to May sometimes. The month-wise energy input to 

the rural area during past few years is shown in the table below: 


Apr-08 

Apr-09 

May-08 

May-09 

Jun-08 

Jun-09 

Jul-08 

Jul-09 

Aug-08 

Aug-09 

Sep-08 

Sep-09 

Oct-08 

Oct-09 

Nov-08 

Nov-09 

Dec-08 

Dec-09 

Jan-09 

Jan-10 

Feb-09 

Feb-10 

Mar-09 

Mar-10 


Actual Energy Input in Rural area 

Month 

Input (MU's) 

2008-09 2009-10 2010-11 

April 394.97 429.82 454.45 

May 374.76 375.52 399.98 

June 275.19 311.86 305.52 

July 295.79 292.71 266.00 

August 338.64 353.98 320.20 

September 380.29 353.97 397.74 

October 493.51 416.89 441.45 

November 641.13 397.82 

December 605.27 506.97 

January 496.70 561.39 

February 477.52 467.08 

March 464.91 500.54 

Annual 5238.68 4968.56 2585.34 

(The methodology for deriving the energy input to rural area is annexed as 

Annexure-“A”) 

The following graph shows the month-wise energy input curve for rural 

area. 

700.00 

650.00 

600.00 

550.00 

500.00 

450.00 

400.00 

350.00 

300.00 

250.00 

200.00 

150.00 

100.00 

50.00 

0.00 

Energy I/P to Rural 

area (MU) 

600.00 

550.00 

500.00 

450.00 

400.00 

350.00 

300.00 

250.00 

200.00 

150.00 

100.00 

50.00 

0.00 

During FY 09-10 


Area (MU) 


Apr-10 

May-10 

Jun-10 

Jul-10 

Aug-10 

Sep-10 

Oct-10 

Nov-10 

Dec-10 

Jan-11 

Feb-11 

Mar-11 


500.00 

450.00 

400.00 

350.00 

300.00 

250.00 

200.00 

150.00 

100.00 

50.00 

0.00 


area (MU) 

Similarly, the month wise un-restricted demand for 33kV rural feeder 

(group no. 1 to 4) is tabulated as below: 

Un-restricted Demand in MW 

Month 2009-10 2010-11 

April 243.5 219.3 

May 210.5 208.8 

June 143.5 153.8 

July 108.5 106.3 

Aug. 124.5 97.8 

Sept. 127.5 112.3 

Oct. 162.0 209.0 

Nov. 326.8 

Dec. 457.8 

Jan. 274.3 

Feb 297.3 

Mar 255.0 

(Source: Power system office of M.P. Transco) 

The load curve for 33kV rural feeders (group 1 to 4) is shown as below: 



It may be seen from the above tables & curves that the energy input 

/ demand of rural area / feeders during the month of April & May is more or 

less at the same level as the seasonal input / demand of the rural area is. 

Therefore, it may be concluded that the agricultural season in the licensee‟s 

area is extending up to the month of May. It is therefore requested that April 

may please be treated as irrigation season at least. It is also submitted that 

the level of assessment of consumption of un-metered agricultural pump 

connections in Maharashtra is 1804 units / HP / Yr., in Haryana it is 1680 

units / HP / Yr. and in Chattisgarh it is 1650 units / HP / Yr. In view of the 

above facts and also considering the increased supply hours on agricultural 

feeders it is prayed that the Hon‟ble Commission may kindly consider and 

approve the criteria for assessing the consumption for the purpose of billing 

for FY-12 as follows: 

Period Rural Area Urban Area Remarks 

During season for 

October to April @ 150 units/HP/month @ 170 units/HP/month 

seven month 

During off season 

May to September @ 55 units/HP/month @ 100 units/HP/month 

for five months 

1.3.7.3 In view of the above, the assumptions for assessment of consumption for 

un-metered agricultural pump connections has been taken as below: 



Table:-49 LV-5.1 Agricultural Assessement of units Assumption (Units/HP) 

Urban Urban Urban Rural Rural Rural 

2010-11 2011-12 2012-13 2010-11 2011-12 2012-13 

April 70 170 170 40 150 150 

May 70 100 100 40 55 55 

June 100 100 100 55 55 55 

July 100 100 100 55 55 55 

Aug 100 100 100 55 55 55 

Sept 100 100 100 55 55 55 

Oct 170 170 170 150 150 150 

Nov 170 170 170 150 150 150 

Dec 170 170 170 150 150 150 

Jan 170 170 170 150 150 150 

Feb 170 170 170 150 150 150 

March 170 170 170 150 150 150 

Total 1560 1690 1690 1200 1325 1325 

Temporary 175 175 175 155 155 155 

1.3.7.4 On the basis of the above, the projections for LV 5.1 which includes the 

consumers of the then RECS are as below: 

Table:-50 LV-5.1 Agricultural Consumer Projection 

Area Sub 



Urban Metered General 18213 18933 19681 

Urban Metered Temporary 0 0 0 

Urban Unmetered General 16427 19107 22225 

Urban Unmetered Temporary 6177 6486 6810 

Urban Total 40818 44526 48716 

Rural Metered General 111721 111721 111721 

Rural Metered Temporary 0 0 0 

Rural Unmetered General 156664 192195 235784 

Rural Unmetered Temporary 163761 171949 180547 

Rural Total 432146 475865 528051 

Total Metered General 129934 130654 131402 

Total Metered Temporary 0 0 0 

Total Unmetered General 173091 211302 258008 

Total Unmetered Temporary 169938 178435 187357 

Total Total 472964 520391 576767 

Table:-51 LV-5.1 Agricultural Load Projection 

Area Sub 

LOAD (kW) 


Urban Metered General 48328 50237 52222 

Urban Metered Temporary 0 0 0 

Urban Unmetered General 39156 45545 52975 

Urban Unmetered Temporary 11104 11660 12243 

Urban Total 98588 107442 117441 

Rural Metered General 294142 294142 294142 

Rural Metered Temporary 0 0 0 

Rural Unmetered General 381383 467879 573992 

Rural Unmetered Temporary 281226 295287 310052 

Rural Total 956751 1057308 1178185 

Total Metered General 342470 344379 346364 

Total Metered Temporary 0 0 0 

Total Unmetered General 420539 513424 626967 

Total Unmetered Temporary 292330 306947 322294 

Total Total 1055340 1164750 1295626 



Table:-52 LV-5.1 Agricultural Unit Projection 

Area Sub 

Unit (MU) 


Urban Metered General 88.37 113.96 118.48 

Urban Metered Temporary 0.00 0.00 0.00 

Urban Unmetered General 73.89 85.94 93.68 

Urban Unmetered Temporary 20.55 20.89 21.93 

Urban Total 182.81 220.79 234.09 

Rural Metered General 455.66 537.02 540.14 

Rural Metered Temporary 0.00 0.00 0.00 

Rural Unmetered General 579.15 688.88 804.68 

Rural Unmetered Temporary 460.90 452.13 474.74 

Rural Total 1495.71 1678.03 1819.55 

Total Metered General 544.03 650.98 658.62 

Total Metered Temporary 0.00 0.00 0.00 

Total Unmetered General 653.04 774.81 898.36 

Total Unmetered Temporary 481.45 473.02 496.67 

Total Total 1678.52 1898.81 2053.65 

1.3.8 LV 5.2: Other than Agricultural use 

1.3.8.1 The historical data for the category is as follows: 

Table:-53 LV-5.2 Other Than Agricultural Use Consumer Historical Data 


Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Upto 3HP 459 0 15 38 -56.42% 0.00% 153.33% 

Urban >3HP to 5HP 285 0 2 12 -65.21% 0.00% 500.00% 

Urban >5HP to 10HP 715 0 1 16 -71.82% 0.00% 1500.00% 

Urban >10HP to 20HP 146 0 1 7 -63.67% 0.00% 600.00% 

Urban >20HP 8 0 0 3 -27.89% 0.00% 0.00% 

Urban Temporary 14 0 0 5 -29.05% 0.00% 0.00% 

Urban Total 1627 0 19 81 -63.21% 0.00% 326.32% 

Rural Upto 3HP 2274 3 97 56 -70.91% 332.05% -42.27% 

Rural >3HP to 5HP 1916 0 15 70 -66.82% 0.00% 366.67% 

Rural >5HP to 10HP 4135 0 9 14 -84.98% 0.00% 55.56% 

Rural >10HP to 20HP 371 0 6 8 -72.17% 0.00% 33.33% 

Rural >20HP 46 2 1 0 -100.00% -100.00% -100.00% 

Rural Temporary 1444 1237 2 221 -46.51% -57.73% 10950.00% 

Rural Total 10186 1242 130 369 -66.91% -45.49% 183.85% 

Total Upto 3HP 2733 3 112 94 -67.48% 459.76% -16.07% 

Total >3HP to 5HP 2201 0 17 82 -66.60% 0.00% 382.35% 

Total >5HP to 10HP 4850 0 10 30 -81.64% 0.00% 200.00% 

Total >10HP to 20HP 517 0 7 15 -69.27% 0.00% 114.29% 

Total >20HP 54 2 1 3 -61.84% 22.47% 200.00% 

Total Temporary 1458 1237 2 226 -46.28% -57.26% 11200.00% 

Total Total 11813 1242 149 450 -66.35% -39.81% 202.01% 



Table:-54 LV-5.2 Other Than Agricultural Use Load Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Upto 3HP 818 0 18 60 -58.14% 0.00% 233.33% 

Urban >3HP to 5HP 1037 0 7 44 -65.12% 0.00% 528.57% 

Urban >5HP to 10HP 5072 0 5 100 -72.98% 0.00% 1900.00% 

Urban >10HP to 20HP 1415 0 8 78 -61.94% 0.00% 875.00% 

Urban >20HP 242 0 0 128 -19.13% 0.00% 0.00% 

Urban Temporary 65 0 0 13 -41.52% 0.00% 0.00% 

Urban Total 8649 0 38 423 -63.43% 0.00% 1013.16% 

Rural Upto 3HP 4000 13 49 75 -73.43% 140.19% 53.06% 

Rural >3HP to 5HP 7093 0 52 342 -63.60% 0.00% 557.69% 

Rural >5HP to 10HP 28809 0 57 91 -85.33% 0.00% 59.65% 

Rural >10HP to 20HP 3754 0 61 88 -71.38% 0.00% 44.26% 

Rural >20HP 1120 104 86 0 -100.00% -100.00% -100.00% 

Rural Temporary 5663 1630 2 764 -48.71% -31.54% 38100.00% 

Rural Total 50439 1747 307 1360 -70.01% -11.77% 343.00% 

Total Upto 3HP 4818 13 67 135 -69.63% 222.25% 101.49% 

Total >3HP to 5HP 8130 0 59 386 -63.79% 0.00% 554.24% 

Total >5HP to 10HP 33881 0 62 191 -82.20% 0.00% 208.06% 

Total >10HP to 20HP 5169 0 69 166 -68.21% 0.00% 140.58% 

Total >20HP 1362 104 86 128 -54.53% 10.94% 48.84% 

Total Temporary 5728 1630 2 777 -48.62% -30.96% 38750.00% 

Total Total 59088 1747 345 1783 -68.87% 1.03% 416.81% 

Table:-55 LV-5.2 Other Than Agricultural Use Unit Historical Data 



Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Urban Upto 3HP 0.45 0.02 0.02 0.06 -48.92% 92.57% 256.73% 

Urban >3HP to 5HP 0.44 0.02 0.02 0.03 -59.65% 9.59% 15.85% 

Urban >5HP to 10HP 1.93 0.07 0.01 0.08 -65.00% 7.31% 1060.73% 

Urban >10HP to 20HP 0.54 0.02 0.01 0.04 -59.81% 38.57% 260.65% 

Urban >20HP 0.20 0.01 0.00 0.08 -25.57% 239.80% 0.00% 

Urban Temporary 0.24 0.04 0.03 0.01 -69.98% -57.89% -74.65% 

Urban Total 3.79 0.17 0.08 0.29 -57.36% 30.22% 250.86% 

Rural Upto 3HP 1.98 0.24 0.03 0.08 -65.60% -41.70% 177.14% 

Rural >3HP to 5HP 3.34 0.24 0.13 0.15 -64.77% -22.08% 13.35% 

Rural >5HP to 10HP 12.04 0.20 0.06 0.08 -81.49% -38.51% 31.78% 

Rural >10HP to 20HP 1.88 0.05 0.02 0.08 -64.83% 22.52% 319.37% 

Rural >20HP 0.68 0.01 0.00 0.00 -100.00% -100.00% 0.00% 

Rural Temporary 4.98 1.64 0.90 0.27 -62.34% -59.68% -70.44% 

Rural Total 24.90 2.38 1.13 0.65 -70.32% -47.73% -42.65% 

Total Upto 3HP 2.43 0.25 0.05 0.14 -61.32% -25.48% 206.33% 

Total >3HP to 5HP 3.78 0.26 0.15 0.17 -64.10% -18.72% 13.76% 

Total >5HP to 10HP 13.96 0.27 0.07 0.16 -77.51% -23.79% 144.28% 

Total >10HP to 20HP 2.43 0.07 0.03 0.12 -63.58% 26.77% 299.75% 

Total >20HP 0.88 0.02 0.00 0.08 -54.88% 103.52% 0.00% 

Total Temporary 5.22 1.67 0.92 0.27 -62.63% -59.64% -70.55% 

Total Total 28.69 2.55 1.22 0.94 -67.95% -39.20% -22.49% 




Nominal growth of 10% has been used for the consumer‟s projection. The 

average load per consumer has been projected on the same basis as in the 

year 2009-10. The average consumption per kW has been projected on the 

basis of current year pattern. 

1.3.8.3 The future projections based on the above growth rates are as follows: 

Table:-56 LV-5.2 Other than Agricultural Use Consumer Projection 

Area Sub 



Urban Upto 3HP 42 46 51 

Urban >3HP to 5HP 13 15 16 

Urban >5HP to 10HP 18 19 21 


Urban >20HP 3 4 4 


Urban Total 89 97 106 

Rural Upto 3HP 62 68 75 

Rural >3HP to 5HP 77 85 93 

Rural >5HP to 10HP 15 17 19 

Rural >10HP to 20HP 9 10 11 

Rural >20HP 0 0 0 


Rural Total 384 400 418 

Total Upto 3HP 103 114 125 

Total >3HP to 5HP 90 99 109 

Total >5HP to 10HP 33 36 40 

Total >10HP to 20HP 17 18 20 

Total >20HP 3 4 4 


Total Total 472 497 524 

Table:-57 LV-5.2 Other than Agricultural Use Load Projection 

Area Sub 

LOAD (kW) 


Urban Upto 3HP 66 73 80 


Urban >5HP to 10HP 110 121 133 


Urban >20HP 0 0 0 


Urban Total 237 260 285 

Rural Upto 3HP 83 91 100 

Rural >3HP to 5HP 376 414 455 

Rural >5HP to 10HP 100 110 121 

Rural >10HP to 20HP 97 106 117 

Rural >20HP 0 0 0 


Rural Total 1420 1485 1557 

Total Upto 3HP 149 163 180 

Total >3HP to 5HP 425 467 514 

Total >5HP to 10HP 210 231 254 

Total >10HP to 20HP 97 106 117 

Total >20HP 0 0 0 


Total Total 1657 1745 1842 



Table:-58 LV-5.2 Other than Agricultural Use Unit Projection 

Area Sub 

Unit (MU) 


Urban Upto 3HP 0.07 0.08 0.09 

Urban >3HP to 5HP 0.12 0.13 0.14 

Urban >5HP to 10HP 0.11 0.12 0.13 

Urban >10HP to 20HP 0.00 0.00 0.00 

Urban >20HP 0.00 0.00 0.00 


Urban Total 0.30 0.33 0.36 

Rural Upto 3HP 0.10 0.11 0.12 

Rural >3HP to 5HP 0.18 0.20 0.22 

Rural >5HP to 10HP 0.05 0.05 0.06 

Rural >10HP to 20HP 0.08 0.09 0.10 

Rural >20HP 0.00 0.00 0.00 


Rural Total 1.85 1.89 1.94 

Total Upto 3HP 0.17 0.19 0.21 

Total >3HP to 5HP 0.30 0.33 0.36 

Total >5HP to 10HP 0.16 0.17 0.19 

Total >10HP to 20HP 0.08 0.09 0.10 

Total >20HP 0.00 0.00 0.00 


Total Total 2.15 2.22 2.30 

1.3.9 HV 1: Railway Traction 

1.3.9.1 The historical data for the category is as follows: 

Table:-59 HV-1 Railway Traction Historical Data 

Area Sub Year 


FY FY FY FY CAGR CAGR Growth 

Category 06-07 07-08 08-09 09-10 

Total Consumer 7 7 7 7 0.00% 0.00% 0.00% 

Total Load(kW) 111000 150000 162000 165600 14.26% 5.07% 2.22% 

Total Unit (MU) 383.32 381.65 422.81 465.18 6.66% 10.40% 10.02% 


Table:-60 HV-1 Growth Considered For Projection 

Area Category 

Urban 

Rural 

220 kV Consumer 0.00% same as for 2009-10 0.00% same as for 2009-10 

Load (kW) 0.00% same as for 2009-10 0.00% same as for 2009-10 

Units (MU) 

3 year overall CAGR is 

6.66% 

used. 

0.00% same as for 2009-10 



Units (MU) 

3 year overall CAGR is 

6.66% 

used. 

0.00% same as for 2009-10 




Table:-61 HV-1 Railway Traction Projection 

Area Sub 

Year 


Total Consumer 7 7 7 

Total Load(kW) 168300 168300 168300 

Total Unit (MU) 496.18 529.25 564.52 

1.3.10 HV -2: Coal Mines 

1.3.10.1 The historical data in the category is as follows : 

Table:-62 HV-2 Coal Mines Historical Data 

Area Sub Year 


Category 

FY FY FY FY 

06-07 07-08 08-09 09-10 


Consumer 132 kV 1 1 1 1 0.00% 0.00% 0.00% 

33 kV 38 37 37 35 -2.70% -2.74% -5.41% 

11 kV 4 4 3 3 -9.14% -13.40% 0.00% 

Total 43 42 41 39 -3.20% -3.64% -4.88% 

Load(kW) 132 kV 50000 50000 36000 36000 -10.37% -15.15% 0.00% 

33 kV 79869 76419 65186 63895 -7.17% -8.56% -1.98% 

11 kV 3800 3800 1350 1350 -29.18% -40.40% 0.00% 

Total 133669 130219 102536 101245 -8.84% -11.82% -1.26% 

Unit (MU) 132 kV 144.35 206.54 221.85 211.80 13.63% 1.27% -4.53% 

33 kV 360.14 285.15 277.36 265.49 -9.66% -3.51% -4.28% 

11 kV 9.88 15.32 13.12 6.36 -13.63% -35.56% -51.51% 

Total 514.36 507.01 512.33 483.66 -2.03% -2.33% -5.60% 



Area Category 

Urban 

Rural 



Units (MU) 2.42% 2 year overall CAGR is used. 0.00% same as for 2009-10 



Units (MU) 2.42% 2 year overall CAGR is used. 7.95% Current year growth is used 



Units (MU) 2.42% 2 year overall CAGR is used. 0.00% same as for 2009-10 




Table:-64 HV-2 Coal Mines Projection 

Area Sub 

Year 


Consumer 132 kV 1 1 1 

33 kV 35 35 35 

11 kV 3 3 3 

Total 39 39 39 

Load(kW) 132 kV 36000 36000 36000 

33 kV 63895 63895 63895 

11 kV 1350 1350 1350 

Total 101245 101245 101245 

Unit (MU) 132 kV 216.92 222.17 227.54 

33 kV 275.15 285.31 295.98 

11 kV 6.52 6.67 6.84 

Total 498.59 514.15 530.36 

1.3.11 HV-3: Industrial and Non-Industrial 

1.3.11.1 The historical data in the industrial category is as follows: 

Table:-65 HV-3.1 Industrial Historical Data 

Area Sub Year 



Consumer 132 kV 9 9 10 10 3.57% 5.41% 0.00% 

33 kV 173 196 207 215 7.51% 4.73% 3.86% 

11 kV 56 80 94 119 28.56% 21.96% 26.60% 

Total 238 285 311 344 13.06% 9.86% 10.61% 

Load(kW) 132 kV 149500 139000 132300 130500 -4.43% -3.11% -1.36% 

33 kV 128942 138519 135627 142059 3.28% 1.27% 4.74% 

11 kV 30527 33306 27478 29122 -1.56% -6.49% 5.98% 

Total 308969 310825 295405 301681 -0.79% -1.48% 2.12% 

Unit (MU) 132 kV 313.76 517.58 508.75 554.95 20.94% 3.55% 9.08% 

33 kV 486.50 379.29 375.45 416.35 -5.06% 4.77% 10.89% 

11 kV 32.75 61.42 55.82 50.47 15.50% -9.35% -9.58% 

Total 833.01 958.28 940.02 1021.78 7.05% 3.26% 8.70% 


Table:-66 HV-3.1 Growth Considered For Projection 

Area Category 

Urban 

Rural 



Units (MU) 1.28% 2 year CAGR is used. 5.19% 2 year CAGR is used. 

33 kV Consumer 5.61% 2 year CAGR is used. 0.00% same as for 2009-10 

Load (kW) 3.19% 3 year CAGR is used. 0.37% 1 year growth is used. 

Units (MU) 7.80% 2 year CAGR is used. 1.90% 2 year CAGR is used. 

11 kV Consumer 12.66% 2 year overall CAGR is used. 7.32% 1 year growth is used. 

Load (kW) 5.34% 1 year growth is used. 0.57% 2 year CAGR is used. 

Units (MU) 2.76% 2 year overall CAGR is used. 3.70% 1 year overall growth is used. 




Table:-67 HV-3.1 Industrial Projection 

Area Sub 

Year 



33 kV 222 228 236 

11 kV 132 146 162 

Total 363 384 407 

Load(kW) 132 kV 130500 130500 130500 

33 kV 144800 147622 150528 

11 kV 30393 31731 33139 

Total 305694 309854 314167 

Unit (MU) 132 kV 574.94 595.86 617.74 

33 kV 436.74 458.50 481.71 

11 kV 51.95 53.49 55.06 

Total 1063.64 1107.84 1154.52 

1.3.11.4 The historical data in the non-industrial category is as follows: 

Table:-68 HV-3.2 Non Industrial Historical Data 

Area Sub Year 



Consumer 132 kV 0 0 0 1 0.00% 0.00% 0.00% 

33 kV 42 47 64 77 22.39% 28.00% 20.31% 

11 kV 114 132 153 171 14.47% 13.82% 11.76% 

Total 156 179 217 249 16.87% 17.94% 14.75% 

Load(kW) 132 kV 0 0 0 18000 0.00% 0.00% 0.00% 

33 kV 22709 22027 26892 33873 14.26% 24.01% 25.96% 

11 kV 20512 21635 21839 24048 5.44% 5.43% 10.11% 

Total 43221 43662 48731 75921 20.66% 31.86% 55.80% 

Unit (MU) 132 kV 0.00 0.00 0.00 13.51 0.00% 0.00% 0.00% 

33 kV 160.36 54.42 69.12 76.46 -21.88% 18.53% 10.62% 

11 kV 32.19 54.08 50.00 60.89 23.68% 6.11% 21.78% 

Total 192.55 108.51 119.12 150.86 -7.81% 17.91% 26.65% 


Table:-69 HV-3.1 Growth Considered for Projection 

Area Category 

Urban 

Rural 



Units (MU) 0.00% same as for 2009-10 0.00% same as for 2009-10 

33 kV Consumer 14.06% 1 year overall growth is used. 16.67% 1 year growth is used. 

Load (kW) 16.34% 3 year CAGR is used. 6.25% 2 year CAGR is used. 

Units (MU) 10.57% 1 year growth is used. 4.64% 3 year CAGR is used. 

11 kV Consumer 10.71% 1 year growth is used. 6.67% Current year growth is used. 

Load (kW) 3.22% 3 year CAGR is used. 18.32% Current year growth is used. 

Units (MU) 4.58% 2 year CAGR is used. 18.32% Current year growth is used. 




1.3.12 HV -4: Seasonal 

Table:-70 HV-3.2 Non-Industrial Projection 

Area Sub 

Year 



33 kV 88 101 116 

11 kV 189 208 230 

Total 278 310 346 

Load(kW) 132 kV 18000 18000 18000 

33 kV 38859 44625 51297 

11 kV 25244 26555 28000 

Total 82103 89180 97297 

Unit (MU) 132 kV 13.51 13.51 13.51 

33 kV 83.78 91.83 100.70 

11 kV 64.40 68.21 72.35 

Total 161.69 173.55 186.56 

1.3.12.1 The historical data in the category is as follows : 

Table:-71 HV-4 Seasonal Historical Data 

Area Sub Year 



Consumer 33 kV 11 10 14 12 2.94% 9.54% -14.29% 

11 kV 1 1 2 2 25.99% 41.42% 0.00% 

Total 12 11 16 14 5.27% 12.82% -12.50% 

Load(kW) 33 kV 3563 5053 3339 2956 -6.04% -23.51% -11.47% 

11 kV 80 80 126 126 16.35% 25.50% 0.00% 

Total 3643 5133 3465 3082 -5.42% -22.51% -11.05% 

Unit (MU) 33 kV 3.18 4.00 2.76 4.53 12.52% 6.47% 64.07% 

11 kV 0.02 0.05 0.15 0.11 84.84% 48.71% -25.49% 

Total 3.20 4.05 2.91 4.65 13.23% 7.09% 59.47% 

1.3.12.2 Since there is no growth in the number of consumers, the load and the 

consumption, no future projections have been made for this category. The 

data has been considered same, as that of FY-11: 

Table:-72 HV-4 Seasonal Projection 

Area Sub 

Year 



11 kV 2 2 2 

Total 14 14 14 

Load(kW) 33 kV 2956 2956 2956 

11 kV 126 126 126 

Total 3082 3082 3082 

Unit (MU) 33 kV 4.53 4.53 4.53 

11 kV 0.11 0.11 0.11 

Total 4.65 4.65 4.65 



1.3.13 HV -5 Water Works, Lift Irrigation & Other than Agricultural 

1.3.13.1 The historical data in the HT Waterworks sub-category is as follows: 

Table:-73 HV-5.1 Water Works Historical Data 

Area Sub Year 



Consumer 33 kV 16 13 14 14 -4.35% 3.77% 0.00% 

11 kV 14 9 10 13 -2.44% 20.19% 30.00% 

Total 30 22 24 27 -3.45% 10.78% 12.50% 

Load(kW) 33 kV 9735 8960 7562 7562 -8.08% -8.13% 0.00% 

11 kV 2488 1718 1583 2026 -6.62% 8.59% 27.98% 

Total 12223 10678 9145 9588 -7.77% -5.24% 4.84% 

Unit (MU) 33 kV 45.21 41.55 39.32 41.86 -2.53% 0.37% 6.45% 

11 kV 5.74 7.70 7.30 7.72 10.41% 0.18% 5.75% 

Total 50.95 49.25 46.63 49.58 -0.90% 0.34% 6.34% 



Area Category 

Urban 

Rural 



Units (MU) 11.38% 1 year growth is used. 0.00% same as for 2009-10 



Units (MU) 4.28% 1 year growth is used. 27.50% 2 year CAGR is used. 


Table:-75 HV-5.1 Water Works Projection 

Area Sub 

Year 



11 kV 13 13 13 

Total 27 27 27 

Load(kW) 33 kV 7562 7562 7562 

11 kV 2026 2026 2026 

Total 9588 9588 9588 

Unit (MU) 33 kV 44.94 48.38 52.20 

11 kV 8.19 8.72 9.31 

Total 53.13 57.09 61.51 



1.3.13.4 The historical data in the HT Lift Irrigation sub-category is as follows: 

Table:-76 HV-5.1 Irrigation Historical Data 

Area Sub Year 



Consumer 33 kV 16 18 18 19 5.90% 2.74% 5.56% 

11 kV 10 11 11 11 3.23% 0.00% 0.00% 

Total 26 29 29 30 4.89% 1.71% 3.45% 

Load(kW) 33 kV 6479 7229 6404 7243 3.79% 0.10% 13.10% 

11 kV 1738 1836 1790 1790 0.99% -1.26% 0.00% 

Total 8217 9065 8194 9033 3.21% -0.18% 10.24% 

Unit (MU) 33 kV 2.21 3.23 4.25 3.49 16.35% 3.84% -17.87% 

11 kV 0.48 0.54 0.50 0.27 -17.71% -29.30% -46.54% 

Total 2.70 3.77 4.75 3.76 11.68% -0.21% -20.91% 



Area Category 

Urban 

Rural 



Units (MU) 0.00% same as for 2009-10 4.09% 2 year CAGR is used 



Units (MU) 0.00% same as for 2009-10 0.00% same as for 2009-10 


Table:-78 HV-5.1 Irrigation Projection 

Area Sub 

Category 

Year 

FY10-11 FY11-12 FY12-13 


11 kV 11 11 11 

Total 30 30 30 

Load(kW) 33 kV 7243 7243 7243 

11 kV 1790 1790 1790 

Total 9033 9033 9033 

Unit (MU) 33 kV 3.63 3.78 3.93 

11 kV 0.27 0.27 0.27 

Total 3.90 4.05 4.20 

1.3.13.7 The historical data of the “HT other than agricultural use” sub-category is 

as follows: 

Table:-79 HV-5.2 Other than Agricultural Historical Data 

Area Sub Year 



Consumer 33 kV 8 9 9 9 4.00% 0.00% 0.00% 

11 kV 0 0 1 2 0.00% 0.00% 100.00% 

Total 8 9 10 11 11.20% 10.55% 10.00% 

Load(kW) 33 kV 2900 3200 2694 2723 -2.08% -7.75% 1.08% 

11 kV 0 0 90 203 0.00% 0.00% 125.56% 

Total 2900 3200 2784 2926 0.30% -4.38% 5.10% 

Unit (MU) 33 kV 4.24 7.58 7.76 8.83 27.72% 7.94% 13.83% 

11 kV 0.00 0.00 0.23 0.27 0.00% 1509.27% 19.68% 

Total 4.24 7.58 7.98 9.10 29.02% 9.58% 14.00% 





Area Category Urban Rural 



Units (MU) 6.15% 1 year growth is used 11.78% 2 year CAGR is used 



Units (MU) 4.66% 1 year growth is used 0.00% same as for 2009-10 


Table:-81 HV-5.2 Other than Agricultural Projection 

Area Sub 

Category 

Year 

FY10-11 FY11-12 FY12-13 


11 kV 2 2 2 

Total 11 11 11 

Load(kW) 33 kV 2723 2723 2723 

11 kV 203 203 203 

Total 2926 2926 2926 

Unit (MU) 33 kV 9.48 10.19 10.96 

11 kV 0.28 0.29 0.31 

Total 9.77 10.49 11.27 

1.3.14 HV -6: Bulk Residential users 

1.3.14.1 The historical data in this category is as follows: 

Table:-82 HV-6 Bulk Residential User Historical Data 

Area Sub Year 



Consumer 33 kV 38 42 35 34 -3.64% -10.03% -2.86% 

11 kV 16 20 22 23 12.86% 7.24% 4.55% 

Total 54 62 57 57 1.82% -4.12% 0.00% 

Load(kW) 33 kV 42457 47498 51329 49829 5.48% 2.42% -2.92% 

11 kV 5116 6690 6414 6315 7.27% -2.84% -1.54% 

Total 47573 54188 57743 56144 5.68% 1.79% -2.77% 

Unit (MU) 33 kV 154.41 253.38 265.17 279.00 21.80% 4.93% 5.21% 

11 kV 9.20 24.05 24.99 27.23 43.56% 6.40% 8.94% 

Total 163.61 277.43 290.17 306.22 23.24% 5.06% 5.53% 



Area Category 

Urban 

Rural 



Units (MU) 10.00% Nominal growth is used 10.00% Nominal growth is used 



Units (MU) 10.00% Nominal growth is used 10.00% Nominal growth is used 




Table:-84 HV-6 Bulk Residential user Projection 

Area Sub 

Year 



11 kV 23 23 23 

Total 57 57 57 

Load(kW) 33 kV 49829 49829 49829 

11 kV 6315 6315 6315 

Total 56144 56144 56144 

Unit (MU) 33 kV 306.90 337.59 371.35 

11 kV 29.95 32.94 36.24 

Total 336.85 370.53 407.58 

1.3.15 HV -7: Bulk Supply to Exemptees 

1.3.15.1 The historical data in this category is as follows: 

Table:-85 HV-7 Bulk Supply to Exemptee Historical Data 

Area Sub Year 



Consumer 33 kV 4 10 52 56 141.01% 136.64% 7.69% 

11 kV 0 27 0 0 0.00% -100.00% 0.00% 

Total 4 37 52 56 141.01% 23.02% 7.69% 

Load(kW) 33 kV 22627 53463 135564 132801 80.38% 57.61% -2.04% 

11 kV 0 74807 0 0 0.00% -100.00% 0.00% 

Total 22627 128270 135564 132801 80.38% 1.75% -2.04% 

Unit (MU) 33 kV 299.04 266.27 233.33 371.15 7.47% 18.06% 59.07% 

11 kV 49.69 103.82 173.56 0.00 -100.00% -100.00% -100.00% 

Total 348.73 370.09 406.88 371.15 2.10% 0.14% -8.78% 

1.3.15.2 With the takeover of business of the Rural Co-operative Societies by 

MPPKVVCL w.e.f 15th Aug‟10, the consumers of these societies are now 

the consumers of the licensee and therefore the future projections for this 

category has been considered as “nil”. 

Table:-86 HV-7 Bulk Supply to Exemptee Projection 

Area Sub 

Year 



11 kV 0 0 0 

Total 56 0 0 

Load(kW) 33 kV 132801 0 0 

11 kV 0 0 0 

Total 132801 0 0 

Unit (MU) 33 kV 120.75 0.00 0.00 

11 kV 0.00 0.00 0.00 

Total 120.75 0.00 0.00 



1.3.16 Summary 

1.3.16.1 The summary of forecasted consumer, load and sales for each category is 

given below:- 

Table-87: Summary of Consumer 

Consumer (No.) 2006-07 2007-08 2008-09 2009-10 2010-11 2011-12 2012-13 

Actual Actual Actual Actual RE Projection Projection 

LV 1 Domestic 1795216 2110665 2181721 2243269 2701169 3175492 3631937 

LV 2 Non-Domestic 193449 197028 201555 208910 218861 221480 224130 

LV3.1 Water Works 5292 5578 5921 6225 7060 7683 8389 

LV3.2 Street Light 4802 4760 4629 4619 4873 4991 5117 

LV4.1 Non Seasonal 14393 27003 28036 28917 31867 33204 34602 

LV4.2 Seasonal 2245 1853 1662 1539 1793 1793 1793 

LV5.1 Agricultural 315460 343904 421918 414894 472964 520391 576767 

LV5.2 Other Agri 11813 1242 149 450 472 497 524 

LT Total 2342670 2692033 2845591 2908823 3439059 3965530 4483259 

HV1 Railway 7 7 7 7 7 7 7 

HV2 Coal Mines 43 42 41 39 39 39 39 

HV3.1 Industrial 238 285 311 344 363 384 407 

HV3.2 Non-Industrial 156 179 217 249 278 310 346 

HV4 Seasonal 12 11 16 14 14 14 14 

HV5.1 HV Irrigation 26 29 29 30 30 30 30 

HV5.2 HV Other Agr 8 9 10 11 11 11 11 

HV5.3 HV Water Works 30 22 24 27 27 27 27 

HV-6 Bulk Residential 54 62 57 57 57 57 57 

HV-7 RECS 4 37 52 56 56 0 0 

HT Total 578 683 764 834 882 879 939 

TOTAL LT+HT 2343248 2692716 2846355 2909657 3439941 3966410 4484198 

Table-88: Summary of Connected Load 

Load (kW) 2006-07 2007-08 2008-09 2009-10 2010-11 2011-12 2012-13 


LV 1 Domestic 658387 711251 745348 769293 923529 1073817 1211188 

LV 2 Non-Domestic 219147 235778 260325 295679 325663 346884 369551 

LV3.1 Water Works 30914 31831 33516 35097 41245 46642 53057 

LV3.2 Street Light 18348 19620 20030 21196 23365 24889 26528 

LV4.1 Non Seasonal 130212 200763 210874 218191 241595 254732 268733 

LV4.2 Seasonal 34385 27535 24718 22438 25091 25419 25806 

LV5.1 Agricultural 779548 777647 931751 935694 1055340 1164750 1295626 

LV5.2 Other Agri 59088 1747 345 1783 1657 1745 1842 

LT Total 1930029 2006172 2226907 2299371 2637483 2938879 3252331 

HV1 Railway 111000 150000 162000 165600 168300 168300 168300 

HV2 Coal Mines 133669 130219 102536 101245 101245 101245 101245 

HV3.1 Industrial 308969 310825 295405 301681 305694 309854 314167 

HV3.2 Non-Industrial 43221 43662 48731 75921 82103 89180 97297 

HV4 Seasonal 3643 5133 3465 3082 3082 3082 3082 

HV5.1 HV Irrigation 8217 9065 8194 9033 9033 9033 9033 

HV5.2 HV Other Agr 2900 3200 2784 2926 2926 2926 2926 

HV5.3 HV Water Works 12223 10678 9145 9588 9588 9588 9588 

HV-6 Bulk Residential 47573 54188 57743 56144 56144 56144 56144 

HV-7 RECS 22627 128270 135564 132801 132801 0 0 

HT Total 694042 845240 825567 858021 870915 749352 761781 

TOTAL LT+HT 2624071 2851412 3052474 3157392 3508398 3688230 4014112 



Table-89: Summary of Units (MUs) 

Unit (MU) 2006-07 2007-08 2008-09 2009-10 2010-11 2011-12 2012-13 


LV 1 Domestic 1352.54 1395.71 1363.66 1458.37 1934.47 2822.66 3716.57 

LV 2 Non-Domestic 239.66 271.63 292.12 341.55 379.21 407.52 438.06 

LV3.1 Water Works 64.75 82.02 92.85 100.87 123.00 146.00 174.37 

LV3.2 Street Light 47.97 60.25 72.42 78.48 89.07 97.74 107.28 

LV4.1 Non Seasonal 132.51 150.48 162.35 172.70 195.40 210.77 227.41 

LV4.2 Seasonal 17.76 31.93 25.73 24.21 27.14 28.17 29.40 

LV5.1 Agricultural 1436.52 1451.69 1264.11 1366.64 1678.52 1898.81 2053.65 

LV5.2 Other Agri 28.69 2.55 1.22 0.94 2.15 2.22 2.30 

LT Total 3320.40 3446.28 3274.46 3543.76 4428.96 5613.89 6749.03 

HV1 Railway 383.32 381.65 422.81 465.18 496.18 529.25 564.52 

HV2 Coal Mines 514.36 507.01 512.33 483.66 498.59 514.15 530.36 

HV3.1 Industrial 833.01 958.28 940.02 1021.78 1063.64 1107.84 1154.52 

HV3.2 Non-Industrial 192.55 108.51 119.12 150.86 161.69 173.55 186.56 

HV4 Seasonal 3.20 4.05 2.91 4.65 4.65 4.65 4.65 

HV5.1 HV Irrigation 2.70 3.80 4.78 3.76 3.90 4.05 4.20 

HV5.2 HV Other Agr 4.24 7.58 7.98 9.10 9.77 10.49 11.27 

HV5.3 HV Water Works 50.95 49.25 46.63 49.58 53.13 57.09 61.51 

HV-6 Bulk Residential 163.61 277.43 290.17 306.22 336.85 370.53 407.58 

HV-7 RECS 348.73 370.09 406.88 371.15 120.75 0.00 0.00 

HT Total 2496.66 2667.63 2753.63 2865.93 2749.15 2771.59 2925.17 

TOTAL LT+HT 5817.07 6113.91 6028.08 6409.69 7178.11 8385.49 9674.20 



A2: DEMAND PROJECTION AND ENERGY REQUIREMENT 

2.1 Provision of Regulation:- 

2.1.1 Regulation 24 provides the methods of estimation of power purchase 

requirement and availability. The relevant provision is reproduced as 

below:- 

24.1 Each year‟s estimated sale as per clause 22 will be grossed up by the 

percentage losses as indicated in the clause 23.1 to arrive at the figure 

of power purchase requirement of the Licensee for such year. 

Transmission losses both for inter-State and intra-State transmission 

systems will be allowed in addition to prescribed distribution losses 

for that year. 

24.2 The Discom wise availability of the power shall be as per the 

allocation notified by the GoMP from time to time. The availability 

from CPPs and any other source shall also be considered while 

determining the total availability. 

24.3 In addition, as per the requirement under Section 86 (1) (e) of the 

Act, the Commission has indicated the quantum of power to be 

purchased by Distribution Licensees from non-conventional / 

renewable energy sources. Availability of power from such sources 

shall also be included in the total availability of power. 

Submission of MPPKVVCL, Jabalpur as per the Regulation:- 

2.1.2 In the regulation 23.1, the Distribution losses for the MYT period FY 2011 

to 2013 have been indicated as 30% (FY-11), 27% (FY-12) and 24% (FY- 

13). The following power purchase quantum has been arrived in accordance 

with method indicated in the regulation. 

2.1.3 The Inter-State transmission losses have not been provided in the regulation 

therefore they have been computed separately for Eastern Region and 

Western Region stations. Similarly, Hon‟ble Commission has not specified 

the loss level trajectory for Intra-state transmission system; however the 



intra-State transmission loss of 4.09% has been considered for determining 

the energy requirement at State periphery. It is prayed that the Hon‟ble 

commission may please allow actual transmission losses. The energy 

balance for MPPKVVCL for FY 2011-12 & FY 2012-13 is presented in the 

following table: 

Table-90: Energy Balance :- Distribution loss target as per the Regulation 

Particulars TO RE Proj. Proj. 

FY10-11 FY10-11 FY11-12 FY12-13 

Total Unit Sold to LT Consumer 4216.07 4428.96 5613.89 6749.03 

Total Unit Sold to HT Consumer 3015.97 2749.15 2771.59 2925.17 

Total Unit Sold 7232.04 7178.11 8385.49 9674.20 

Normative Distribution Loss 30% 30% 27% 24% 

Energy Requirement at Discom Periphery 10331.48 10254.45 11486.97 12729.21 

Transmission Loss 4.09% 4.09% 4.09% 4.09% 

Energy Requirement at State Periphery 10772.06 10691.74 11976.82 13272.04 

External Loss 2.13% 2.99% 2.75% 2.62% 

Ex-Bus Energy Requirement 11006.00 11021.49 12315.93 13629.05 

2.2 Additional Submission of MPPKVVCL, Jabalpur:- 

2.2.1 The licensee has to meet the power demand of the consumers, as per the 

relevant provisions of the Electricity Act, 2003 under the obligation to 

supply electricity. Therefore, quantum of power purchase may not be 

restricted on the basis of normative loss levels. Under any given operating 

conditions of the power system, the quantum of energy and power demand 

is more or less uncontrollable variables and the loss level is an 

indeterminate quantity. In fact, normative loss level and hence the 

normative quantum of power purchase are quantities based on a 

hypothetical system model with “frozen” conditions of these variables – 

e.g. input, output, loss. The power and energy demand vary from instant to 

instant and it is not possible to predict the loss level for any particular 

instant. For meeting the peak system demand and associated losses to the 

extent possible, scheduling of additional generation is required. Monthly 

load duration curve may be referred while implementing merit order 

dispatch. The principle of deciding a “normative” quantum of power based 

on a normative loss level is neither logical nor reasonable for the licensee 



and also to the consumers. The principle of “normative” power requirement 

is not feasible in practice, and it results in indiscriminate load 

shedding/curtailment of power to the consumers. 

2.2.2 The MPPKVVCL, Jabalpur has projected average un-restricted / restricted 

Demand, average supply hours and corresponding Energy Requirement for 

the year 2011-12 as shown in Table below: 

Table:- 91 Projected Demand & Energy requirement During 2011-12 

Particular Apr-11 May-11 Jun-11 Jul-11 Aug-11 Sep-11 Oct-11 Nov-11 Dec-11 Jan-12 Feb-12 Mar-12 2011-12 

Projected Average Un-restricted Demand (MW) at MP Periphery 

00 - 06 Hrs 1800 1730 1600 1550 1630 1600 1600 1860 1980 1760 1950 1780 1737 

06 - 12 Hrs 1500 1380 1420 1340 1430 1420 1460 1810 2080 2060 2050 1720 1639 

12 - 18 Hrs 1460 1330 1440 1250 1320 1350 1290 1780 2040 1930 1860 1570 1552 

18 - 24 Hrs 2090 1840 1710 1600 1800 1940 2100 2280 2420 2360 2400 2290 2069 

Projected Supply Hrs. 

CHQ 22:00 22:00 22:00 22:00 22:00 22:00 22:00 22:00 22:00 22:00 22:00 22:00 22:00 

DHQ 20:00 20:00 20:00 20:00 20:00 20:00 20:00 20:00 20:00 20:00 20:00 20:00 20:00 

THQ 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 

Rural 

(Where Agri. 

Feeders has 

been 

segregated) 

Rural 

(Where Agri. 

Feeders has 

not been 

segregated) 

16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 16:00 

12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 12:00 

Agri. feeder 08:00 08:00 08:00 08:00 08:00 08:00 08:00 08:00 08:00 08:00 08:00 08:00 08:00 

Projected Average Restricted Demand (MW) at MP Periphery 

00 - 06 Hrs 1490 1440 1325 1235 1225 1335 1415 1555 1555 1445 1545 1480 1420 

06 - 12 Hrs 1175 1065 1115 960 960 1115 1115 1400 1420 1465 1400 1340 1211 

12 - 18 Hrs 1210 1110 1190 1020 1010 1115 1060 1455 1610 1515 1495 1280 1256 

18 - 24 Hrs 1750 1655 1425 1320 1490 1600 1820 2020 2050 1940 2045 1910 1752 

No. of Days 30 31 30 31 31 30 31 30 31 31 29 31 366 

Energy Requirement (MU) at MP Periphery 

00 - 06 Hrs 268 268 239 230 228 240 263 280 289 269 269 275 3118 

06 - 12 Hrs 212 198 201 179 179 201 207 252 264 272 244 249 2657 

12 - 18 Hrs 218 206 214 190 188 201 197 262 299 282 260 238 2755 

18 - 24 Hrs 315 308 257 246 277 288 339 364 381 361 356 355 3845 

Total 1013 980 910 844 871 930 1006 1157 1234 1184 1128 1118 12375 

2.2.3 It could be seen from the above table that MPPKVVCL, Jabalpur requires 

12375 MU of energy at state periphery to maintain the average supply 

hours. 



2.3 Distribution loss and Energy Balance 

2.3.1 In the regulation 23.1, the Distribution losses for the MYT period FY-11 to 

13 have been indicated as 30% (FY-11), 27% (FY-12) and 24% (FY-13). 

Looking to previous year‟s reduction in losses, MPPKVVCL had submitted 

its comments on draft regulation and proposed the loss level as 36.5% for 

2010-11 and 1% reduction in subsequent years. GoMP had also proposed 

the loss level of MPPKVVCL as 32.50% (FY-11), 28.50% (FY-12) and 

24.00% (FY-13). 

2.3.2 The regulation was notified on 22 nd Jan‟2010. After the notification of the 

regulation, a major change in the base line data of the company had 

occurred. The electricity distribution business of the four RE Co-operative 

societies viz. Amarpatan, Sidhi, Nowgaon and Laundi has been taken over 

by MPPKVVCL w.e.f. 15th Aug‟2010 as per the directives of the 

Commission; and the consumers of the then co-operative societies are now 

the LT consumers of the licensee. Since the areas pertaining to these 

societies were the areas with high distribution losses hence it has an adverse 

impact on the losses of the company. In fact, distribution losses of the 

company have increased by about 2.35% on this account. Taking over the 

business of REC societies has nullified the actual reduction in the 

distribution losses achieved by the company in the FY 10-11 and this will 

impact likewise in FY 11-12 also. 

2.3.3 The Company had filed a petition no. 38 of 2010 before the Hon‟ble 

Commission seeking an increase in the loss level trajectory by 2.35% for 

MYT period. The calculation in support of increase in the loss level has 

also been provided by the company. The petition no. 38/10 has been closed 

by the Hon‟ble Commission but this issue has not been resolved and is yet 

to be decided. It is therefore prayed that the Commission may kindly 

consider these additional losses of 2.35% for the purpose of tariff 

determination over and above the loss trajectory stipulated in the MYT 

regulation. 



2.3.4 Regulation 46 provides that the Commission may, at any time add, vary, 

alter, modify or amend any provisions of the regulation. There is a major 

change in the base data and the losses of the company have been increased 

due to takeover of RECS, but its impact has not been accounted by revising 

the loss trajectory. It is therefore prayed that Hon‟ble Commission may 

kindly modify the regulation and allow the distribution loss level trajectory 

for FY12 as 29.35% for MPPKVVCL Jabalpur. 

2.3.5 After considering the distribution loss trajectory as 29.35% and Inter-State / 

Intra state transmission loss as explained before, the energy balance for 

MPPKVVCL for FY 2011-12 & FY 2012-13 is presented in the following 

table: 

Table-92: Energy Balance After Merger of the RECS where the Distribution losses 

will increase by 2.35% 

Particulars TO RE Proj. Proj. 

FY10-11 FY10-11 FY11-12 FY12-13 

Total Unit Sold to LT Consumer 4216.07 4428.96 5613.89 6749.03 

Total Unit Sold to HT Consumer 3015.97 2749.15 2771.59 2925.17 

Total Unit Sold 7232.04 7178.11 8385.49 9674.20 

Distribution Loss 30.00% 32.82% 29.35% 25.90% 

Energy Requirement at Discom Periphery 10331.48 10684.71 11869.01 13055.91 

Transmission Loss 4.09% 4.09% 4.09% 4.09% 

Energy Requirement at State Periphery 10772.06 11140.35 12375.15 13612.67 

External Loss 2.13% 2.87% 2.66% 2.55% 

Ex-Bus Energy Requirement 11006.00 11469.69 12713.86 13969.57 

2.3.6 It could be seen from the above submission that MPPKVVCL, Jabalpur 

requires 12375MU quantum of energy at M.P. periphery in 2011-12 to 

maintain the supply hours as proposed in previous table 91. As per method 

provided in regulation and considering the additional loss of 2.35%, the 

quantum of power purchased at M.P. periphery works out to 12375.15 MU 

which is at par with the energy required to maintain the proposed supply 

hours. It is therefore prayed that the Hon‟ble Commission may please allow 

12375.15 MU of power purchase which has been determined on the basis of 

restricted demand with the following average supply hours plan. 

Commissionary Headquarter 

- 22 Hours 

District Headquarter 

- 20 Hours 

Tehsil Headquarter 

- 16 Hours 



Rural (where Agricultural Feeders have been segregated) - 16 Hours 

Rural (Where Agricultural feeders have not been segregated) - 12 Hours 

Agricultural feeder - 8 Hours 

2.3.7 The Comparison of energy balance as per the provision of regulation and 

after incorporating the additional submission is given in table below:- 

Table-93: Comparision of Energy Balance for FY12 

Particulars 

As per 

Regulation 

As per 

additional 

Deviation 

Submission 

Total Unit Sold to LT Consumer 5613.89 5613.89 0.00 

Total Unit Sold to HT Consumer 2771.59 2771.59 0.00 

Total Unit Sold 8385.49 8385.49 0.00 

Normative Distribution Loss 27.00% 29.35% 2.35% 

Energy Requirement at Discom Periphery 11486.97 11869.01 382.04 

Transmission Loss 4.09% 4.09% 0.00% 

Energy Requirement at State Periphery 11976.82 12375.15 398.33 

External Loss 2.75% 2.66% -0.09% 

Ex-Bus Energy Requirement 12315.93 12713.86 397.93 

2.3.8 It is prayed that the Hon‟ble Commission may kindly consider an additional 

loss of 2.35% on account of change in base data of the company due to 

takeover of societies and allow the quantum of energy purchase at state 

boundary as 12375.15 MU for FY12. 



A3: ASSESSMENT OF AVAILABILITY 

3.1 Central Sector Stations Allocated to MP 

3.1.1 The Western Region central sector stations which are allocated to M.P are 

listed in the table below with details of the capacity allocation to the state. 

Table-94: Allocated capacity to MP in Western Region generating stations[1] 

S.No. Plant Region Total Firm Infirm 

Capacity Allocation Allocation 

(MW) (MW) (MW) 

Special 

allocation 

(MW)[2] 

Total 

Allocation 

(MW) 

1 NTPC-Korba WR NTPC 2100 400 37.76 52.63 490.39 

2 NTPC-Vindyachal I WR NTPC 1260 385 28.27 32.26 445.53 

3 NTPC-Vindyachal II WR NTPC 1000 273 22.82 25.47 321.29 

4 NTPC-Vindyachal III WR NTPC 500 200 24.33 25.47 249.8 

5 NTPC-Kawas WR NTPC 656.2 140 0 140 

6 NTPC-Gandhar WR NTPC 657.39 117 0 117 

7 KAPP WR NPC 440 93 7.19 11.21 111.4 

8 TAPS WR NPC 1080 180 26.28 27.5 233.78 

9 NTPC -Sipat – II WR NTPC 1000 143 24.33 25.47 192.8 

Total 8693.59 1931 170.98 200.01 2301.99 

[1] The infirm allocation is as per the WRPC letter dated 8th Oct 2010, applicable from 16 th Oct 2010. 

[2] Special allocation for Bundelkhand region in MPPKVVCL, Jabalpur 

3.1.2 The Eastern Region central sectors which are allocated to M.P. are listed in 

the table below with details of the capacity allocation to the state. 

Table-95: Allocated capacity to MP in Eastern Region generating stations[3] 

S.No. Plant Region Total 

Capacity 

(MW) 

Firm 

Allocation 

(MW) 

Infirm 

Allocation 

(MW) 

Total 

Allocation 

to M.P. 

(MW) 

1 NTPC - Farakka ER NTPC 1600 0 0 0 

2 NTPC - Talcher ER NTPC 1000 0 0 0 

3 NTPC - Kahalgaon ER NTPC 840 0 0 0 

4 NTPC - Kahalgaon-II ER NTPC 1500 74 0 74 

Total 4940 74 0 74 

[3] Allocation is as per the ERPC website 

3.1.3 It is submitted that the infirm allocation may change as per WRPC/ERPC 

directives from time to time, therefore for forecasting the availability from 

these stations, the latest allocation has been assumed to be constant over the 

years. 



3.2 Projection of Availability for future years 

3.2.1 The projection of availability for the future years has been done based on 

energy projections given by WRLDC. The table below provides details of 

the projection for future years. 

Table 96: Projected ex-bus availability for FY11-FY13 [4] in MUs 

S.No. Stations Region FY 11 FY 12 FY 13 

1 NTPC-Korba WR 3672 3572 3572 

2 NTPC-Vindyachal I WR 3217 3037 3037 

3 NTPC-Vindyachal II WR 2415 2259 2259 

4 NTPC-Vindyachal III WR 1923 1729 1729 

5 NTPC-Kawas WR 744 940 940 

6 NTPC-Gandhar WR 667 778 778 

7 KAPP WR 170 477 477 

8 TAPS WR 1029 1058 1058 

9 NTPC - Farakka ER - - - 

10 NTPC - Talcher ER - - - 

11 NTPC - Kahalgaon ER - - - 

Total 13837 13851 13851 

[4] FY 10 Projections based on actual data till 31 st October 2010 

3.3 Projections for Sipat-II and Kahalgaon-II 

3.3.1 The new plants Sipat-II and Kahalgaon-II were commissioned during 

FY09. First unit of Sipat-II was commissioned in June 08 while the second 

unit was commissioned in January‟09. Similarly Kahalgaon-II was 

commissioned in January 09. Future projections for these two plants have 

been done on the basis of past six months actual data. 

Table 97: Projected ex-bus availability for FY10-FY13 [5] in MUs 


1 NTPC-Sipat - II WR 1473 1469 1469 

2 NTPC-Kahalgaon - II ER 336 586 586 

Total 1809 2055 2055 

[5] FY 10 Projections based on actual data till 31 st October 2010 

3.4 Bilateral and Joint Venture Stations 

3.4.1 The Bilateral and Joint-Venture stations in which Madhya Pradesh is having 

its allocation are listed in the table below: 



Table-98: Bilateral and Joint Venture Stations 

S.No. Region Total 

Capacity 

(MW) 

Firm 

Allocation 

(MW) 

Infirm 

Allocation 

(MW) 

Total 

Allocation 

to M.P. 

(MW) 

1 Sardar Sarovar WR JV 1450 827 0 827 

2 Omkareshwar HPS State JV 540 540 0 540 

3 DVC (MTPS) ER DVC 500 200 0 200 

4 Indirasagar State JV 1000 1000 0 1000 

Total 3490 2567 0 2567 

3.5 Review of past Ex-bus availability 

3.5.1 The table provides details of the station-wise ex-bus energy sent out [6] 

during last three years i.e. FY 08, FY 09, and FY 10. 

Table-99: Past ex-bus availability for the joint venture projects 


1 Sardar Sarovar WR 2484 1293 1395 

2 Omkareshwar HPS State 687 781 938 

3 DVC (MTPS) ER 0 513 399 

4 Indirasagar State 2715 1563 2112 

Total 5886 4150 4845 

6 

As per the monthly reports of WRPC and ERPC 

3.6 Projection of availability for future years 

3.6.1 Considering the availability from these stations on a month wise basis for 

past years, future projections are based on the average of past three years. 

The table below provides details of the availability considered for FY11- 

FY13. 

Table-100: Projected ex-bus availability for FY11-FY13 in MUs 


1 Sardar Sarovar WR 1842 1518 1518 

2 Omkareshwar HPS State 1025 1018 1018 

3 DVC (MTPS) ER 627 475 475 

4 Indirasagar State 2266 2302 2302 

Total 5761 5313 5313 



3.7 MP GENCO stations 

3.7.1 The availability of MP Genco stations have been taken as per current 

availability for FY 11 (till August) and future plan as per the scheduled 

maintenance. Projections for future years i.e. for FY13 have been 

considered as per the capacity addition plan of MP Genco and considering 

the operational trend. Furthermore, the total despatch has been considered 

at 90% of the availability based on projections of MP Genco for FY12. The 

table below provides projection of the availability for MP Genco stations 

for future years. 

Table-101: Projected ex-bus availability for FY10-FY13 in MUs 


1 ATPS - Chachai-PH 1&2 State 323 1034 1034 

2 STPS - Sarani-PH 1, 2 & 3 State 4318 5557 5557 

3 SGTPS - Bir'pur - PH 1 & 2 State 2537 4307 4307 

4 SGTPS – Extn State 3131 3052 3052 

5 ATPS – Extn State 1009 1279 1279 

6 CHPS-Gandhi Sagar State 20 171 171 

7 CHPS-RP Sagar & Jawahar Sagar 41 160 160 

8 Pench THPS State 211 240 240 

9 Banasgar Tons HPS-Tons State 904 1017 1017 

10 Banasgar Tons HPS-Silpara State 0 100 100 

11 Banasgar Tons HPS-Devloned State 0 82 82 

12 Banasgar Tons HPS-Bansagar IV State 14 63 63 

13 Birsingpur HPS State 70 45 45 

14 Bargi HPS State 400 533 533 

15 Rajghat HPS State 1 48 48 

16 Marhi Khera HPS State 9 75 75 

Total 12987 17762 17762 

3.8 Capacity addition plan 

3.8.1 The capacity addition plan for the state which includes MP Genco capacity 

addition, ISGS stations and other JV and case-1 addition capacity is 

presented in the table below with details of the capacity allocated to M.P. 

and their unit wise tentative commissioning schedule. 



Table-102: Capacity addition plan till FY 13 

Sr. No. Station 

1 

NTPC Sipat - Stage 

I 

Region / 

State 

WR 

Fuel 

CGS / 

P - Coal 

FY 12 FY 13 

(MW) 

Unit 1 660 94.33 12 12 

Unit 2 660 94.33 6 12 

Unit 3 660 94.33 12 

Sub Total 1980 283 

2 

DVC (Chandrapur 

CGS / Unit 7 250 100 12 12 

ER 

TPS Extn.) 

P - Coal Unit 8 250 100 6 12 


3 

Case - I (Essar 

CGS / Unit 1 75 75 3 12 

WR 

power) 

P - Coal Unit 2 75 75 


4 

PTC - Torrent Surat 

(Gas) 

IPP Gas Unit 1 1100 100 12 12 


Unit 1 & 2 80 87.21 12 12 

Unit 3 & 4 80 87.21 9 12 

5 Maheswar Hydel IPP Hydel Unit 5 & 6 80 87.21 6 12 

Unit 7 & 8 80 87.21 3 12 

Unit 9 & 10 80 87.21 12 12 


6 Korba Stage-III WR 

CGS / 

P - Coal 

Unit 1 500 60 12 12 


GRAND TOTAL 

4,630 1,229 

Unit 

Total 

Capacity 

(MW) 

Allocated 

Capacity 

to MP 

State 

Months of 

Operation 

3.9 Assumption for projecting availability from the future capacities 

3.9.1 The assumptions used for forecasting the availability from the future 

capacities are as below: 

(a) PLF considered for Coal based stations is 85%; 

(b) PLF considered for Gas based stations is 68% (as current gas 

availability is very poor); 

(c) Auxiliary consumption considered for Coal based stations is 6%; 

(d) Auxiliary consumption considered for Gas based stations is 3%; 

(e) The availability has been forecasted based on the month of operation 

in a particular year and the past trend of energy availability from the 

plants; 

(f) 15% slippage has been considered for new capacity addition; 

(g) For Hydel stations design energy has been considered; 

3.9.2 Based on the above assumptions, the forecast has been done for the future 

years till FY13 for the additional capacities. 



3.10 Overall availability 

3.10.1 The overall availability at state boundary based on the discussions above is 

presented below: 

Table-103: Overall MUs forecast till FY 13 

Station FY 11 FY 12 FY 13 

NTPC-Korba 3473 3379 3379 

NTPC-Vindyachal I 3043 2873 2873 

NTPC-Vindyachal II 2284 2137 2137 

NTPC-Vindyachal III 1819 1635 1635 

NTPC-Kawas 703 889 889 

NTPC-Gandhar 631 736 736 

KAPP 161 451 451 

TAPS 973 1001 1001 

NTPC – Farakka 0 0 0 

NTPC – Talcher 0 0 0 

NTPC – Kahalgaon 0 0 0 

NHDC - Indira Sagar 2266 2302 2302 

Sardar Sarovar 1742 1436 1436 

Omkareshwar HPS 1025 1018 1018 

Lanco Amarkantak 0 0 0 

ATPS - Chachai-PH 1&2 323 1034 1034 

STPS - Sarani-PH 1, 2 & 3 4318 5557 5557 

SGTPS - Bir'pur - PH 1 & 2 2537 4307 4307 

CHPS-Gandhi Sagar 20 171 171 

CHPS-RP Sagar & Jawahar Sagar 41 160 160 

Pench THPS 211 240 240 

Banasgar Tons HPS-Tons 904 1017 1017 

Banasgar Tons HPS-Silpara 0 100 100 

Banasgar Tons HPS-Devloned 0 82 82 

Banasgar Tons HPS-Bansagar IV 14 63 63 

Birsingpur HPS 70 45 45 

Bargi HPS 400 533 533 

Rajghat HPS 1 48 48 

Marhi Khera HPS 9 75 75 

RSEB (Chambal,Satpura) 483 0 0 

UPPCL (Rihand,Matatila,Rajghat) 46 60 60 

MSEB(Pench) 0 0 0 

GridCo (Hirakud) 0 0 0 

Others 1 (Wind & CPP) 121 121 121 

NTPC - Sipat Stage II 1393 1389 1389 

NTPC - Kahalgaon 2 310 541 541 

DVC (MTPS) 579 438 438 

SGTPS - Bir'pur - Extn 3131 3052 3052 

ATPS - Chachai-Extn 1009 1279 1279 

NTPC Sipat - Stage I 0 798 1824 

NTPC Mauda - Nagpur 0 0 159 

DVC (Chandrapur TPS Extn.) 0 826 1257 

DVC (Durgapur Steel) 0 0 471 

Case-I (Essar Power) 0 274 483 

PTC - Torrent Surat (Gas) 0 548 547 

Bina Power 0 0 1072 

Maheswar Hydel 0 396 1090 

Total 34,039 41,009 45,070 



3.10.2 The Discom wise projection of availability has been considered as per the 

information provided by MP Tradeco and also considers the special 

allocation for MPPKVVCL, Jabalpur. This has also been updated with the 

latest allocation as per WRPC dated 8 th Oct‟ 2010. 

Table-104: Capacity allocation to Discoms as per GoMP notification 

Discom wise Allocation 

Generating Stations 

Percentage (%) 

Central West East Total 

1 NTPC-Korba 30.00% 22.00% 48.00% 100.00% 

2 NTPC-Vindyachal I 45.45% 16.70% 37.85% 100.00% 

3 NTPC-Vindyachal II 27.62% 36.83% 35.55% 100.00% 

4 NTPC-Vindyachal III 35.92% 35.92% 28.16% 100.00% 

5 NTPC-Kawas 30.00% 40.00% 30.00% 100.00% 

6 NTPC-Gandhar 30.00% 40.00% 30.00% 100.00% 

7 KAPP 30.00% 40.00% 30.00% 100.00% 

8 TAPS 30.00% 40.00% 30.00% 100.00% 

9 NTPC – Farakka 30.00% 40.00% 30.00% 100.00% 

10 NTPC – Talcher 30.00% 40.00% 30.00% 100.00% 

11 NTPC – Kahalgaon 30.00% 40.00% 30.00% 100.00% 

12 NHDC - Indira Sagar 30.00% 40.00% 30.00% 100.00% 

13 Sardar Sarovar 30.00% 40.00% 30.00% 100.00% 

14 Omkareshwar HPS 30.00% 40.00% 30.00% 100.00% 

15 Lanco Amarkantak 40.00% 30.00% 10.00% 100.00% 

16 ATPS - Chachai-PH 1&2 30.00% 40.00% 30.00% 100.00% 

17 STPS - Sarani-PH 1, 2 & 3 30.00% 40.00% 30.00% 100.00% 

18 SGTPS - Bir'pur - PH 1 & 2 30.00% 40.00% 30.00% 100.00% 

19 CHPS-Gandhi Sagar 30.00% 40.00% 30.00% 100.00% 

20 CHPS-RP Sagar & Jawahar Sagar 30.00% 40.00% 30.00% 100.00% 

21 Pench THPS 30.00% 40.00% 30.00% 100.00% 

22 Banasgar Tons HPS-Tons 30.00% 40.00% 30.00% 100.00% 

23 Banasgar Tons HPS-Silpara 30.00% 40.00% 30.00% 100.00% 

24 Banasgar Tons HPS-Devloned 30.00% 40.00% 30.00% 100.00% 

25 Banasgar Tons HPS-Bansagar IV 30.00% 40.00% 30.00% 100.00% 

26 Birsingpur HPS 30.00% 40.00% 30.00% 100.00% 

27 Bargi HPS 30.00% 40.00% 30.00% 100.00% 

28 Rajghat HPS 30.00% 40.00% 30.00% 100.00% 

29 Marhi Khera HPS 30.00% 40.00% 30.00% 100.00% 

30 Mini-Micro HPS 31.08% 37.04% 31.88% 100.00% 

31 RSEB (Chambal,Satpura) 31.08% 37.04% 31.88% 100.00% 

32 UPPCL (Rihand,Matatila,Rajghat) 31.08% 37.04% 31.88% 100.00% 

33 MSEB(Pench) 31.08% 37.04% 31.88% 100.00% 

34 GridCo (Hirakud) 31.08% 37.04% 31.88% 100.00% 

35 Others 1 (Wind & CPP) 31.08% 37.04% 31.88% 100.00% 

36 NTPC - Sipat Stage II 39.05% 17.36% 43.59% 100.00% 

37 NTPC - Kahalgaon 2 10.00% 40.00% 30.00% 100.00% 

38 DVC (MTPS) 30.00% 40.00% 30.00% 100.00% 

39 SGTPS - Bir'pur - Extn 30.00% 40.00% 30.00% 100.00% 

40 ATPS - Chachai-Extn 30.00% 40.00% 30.00% 100.00% 

Gross Weighted Average 31.08% 37.04% 31.88% 100.00% 



3.10.3 Any future capacity which is proposed to come has been allocated to 

Tradeco and the Discom wise availability has been calculated for the 

current existing capacities. 

3.11 PGCIL Losses 

3.11.1 The Inter-State transmission losses have been computed separately for 

Eastern Region and Western Region stations by taking the past 52 weeks 

data available on the website of PGCIL. For Western Region an average 

loss level of 5.42% and for Eastern region an average loss level of 2.44% 

has been considered. 

3.12 Availability at state boundary 

3.12.1 The availability at state boundary has been calculated after considering the 

ER and WR PGCIL losses and is presented in table below. 



Table-105: Availability for MPPKVVCL, Jabalpur at State Boundary (MUs) 

Station FY 11 FY 12 FY 13 

NTPC-Korba 1892 1622 1622 

NTPC-Vindyachal I 1152 1087 1087 

NTPC-Vindyachal II 812 760 760 

NTPC-Vindyachal III 512 460 460 

NTPC-Kawas 211 267 267 

NTPC-Gandhar 189 221 221 

KAPP 32 135 135 

TAPS 195 300 300 

NTPC - Farakka 0 0 0 

NTPC - Talcher 0 0 0 

NTPC - Kahalgaon 0 0 0 

NHDC - Indira Sagar 453 691 691 

Sardar Sarovar 697 431 431 

Omkareshwar HPS 205 305 305 

Lanco Amarkantak 0 0 0 

ATPS - Chachai-PH 1&2 97 310 310 

STPS - Sarani-PH 1, 2 & 3 1727 1667 1667 

SGTPS - Bir'pur - PH 1 & 2 761 1292 1292 

CHPS-Gandhi Sagar 4 51 51 

CHPS-RP Sagar & Jawahar Sagar 8 48 48 

Pench THPS 42 72 72 

Banasgar Tons HPS-Tons 181 305 305 

Banasgar Tons HPS-Silpara 0 30 30 

Banasgar Tons HPS-Devloned 0 25 25 

Banasgar Tons HPS-Bansagar IV 3 19 19 

Birsingpur HPS 38 14 14 

Bargi HPS 91 160 160 

Rajghat HPS 0 14 14 

Marhi Khera HPS 4 23 23 

Mini-Micro HPS 0 0 0 

RSEB (Chambal,Satpura) 147 0 0 

UPPCL (Rihand,Matatila,Rajghat) 14 19 19 

MSEB(Pench) 0 0 0 

GridCo (Hirakud) 0 0 0 

Others 1 (Wind & CPP) 37 38 38 

NTPC - Sipat Stage II 607 605 605 

NTPC - Kahalgaon 2 167 162 162 

DVC (MTPS) 203 131 131 

SGTPS - Bir'pur - Extn 939 916 916 

ATPS - Chachai-Extn 303 384 384 

Total 11,723 12,564 12,564 

3.12.2 The availability from the stations which have been kept with MP Tradeco 

are allocated to the MPPKVVCL, Jabalpur based on the weighted average 

capacity allocation and these stations will be considered to be despatched as 

per the merit order principle. 



A4: ESTIMATION OF COSTS 


4.1.1 Regulation 25 provides the methods of estimation of power purchase cost. 

The relevant provision is reproduced as below:- 

25.1. The cost of power purchase from State Generating Stations shall be as 

per the tariff determined / approved by the Commission from time to time. 

The cost of purchase from the Central Sector Stations shall be based on the 

tariff as per CERC‟s orders as may be applicable from time to time. 

25.2. In respect of projects executed by the State of Madhya Pradesh along 

with any other State(s), the Commission shall determine the tariff in 

consultation with the other concerned Regulatory Commissions where the 

responsibility is not assigned to CERCz. 

25.3. The cost of power purchased from other Generating Companies, 

Traders and other Distribution Licensees shall be as per the PPAs and 

trading arrangements approved by the Commission, subject to the condition 

that the Distribution Licensees gets prior approvals of such arrangements 

from the Commission in accordance with the appropriate regulations. 

25.4. The Cost of power generated by the generating plant of the 

Distribution Licensee and sold by it to its consumers shall be based on tariff 

determined by the Commission. 

25.5. The cost of power to be procured from the Captive Power Plants shall 

be as decided by the Commission from time to time. 

25.6. The cost of power to be purchased by Distribution Licensees from 

non-conventional / renewable sources of energy shall be as determined by 

the Commission from time to time. This cost shall be included in the ARR 

while estimating the cost for procurement of power by the licensee. 



4.2 For existing stations 

4.2.1 The Fixed Costs of MP Genco‟s stations for FY 2010-11 to FY 2012-13 

have been kept in accordance with the tariff order issued by the MPERC 

from time-to-time. The following table provides a summary of order 

numbers through which tariff were issued by the MPERC. 

Table-106: MPERC order for applicable tariff for MPPGCL plants under MYT Principles 

Station Petition/ Order number Date/ Year 

NHDC - Indira Sagar CERC 33/2009 20 th October 2009 

Sardar Sarovar MPERC 03 of 2007 18 th January 2008 

Omkareshwar HPS CERC 56/2007 30 th October 2007 

ATPS - Chachai-PH 1&2 MPERC MYT 54/2009 3 rd March 2010 

STPS - Sarani-PH 1, 2 & 3 MPERC MYT 54/2009 3 rd March 2010 

SGTPS - Bir'pur - PH 1 & 2 MPERC MYT 54/2009 3 rd March 2010 

CHPS-Gandhi Sagar MPERC MYT 54/2009 3 rd March 2010 

CHPS-RP Sagar & Jawahar Sagar MPERC MYT 54/2009 3 rd March 2010 

Pench THPS MPERC MYT 54/2009 3 rd March 2010 

Banasgar Tons HPS-Tons MPERC MYT 54/2009 3 rd March 2010 

Banasgar Tons HPS-Silpara MPERC MYT 54/2009 3 rd March 2010 

Banasgar Tons HPS-Devloned MPERC MYT 54/2009 3 rd March 2010 

Banasgar Tons HPS-Bansagar IV MPERC MYT 54/2009 3 rd March 2010 

Birsingpur HPS MPERC MYT 54/2009 3 rd March 2010 

Bargi HPS MPERC MYT 54/2009 3 rd March 2010 

Rajghat HPS MPERC MYT 54/2009 3 rd March 2010 

Marhi Khera HPS MPERC MYT 54/2009 3 rd March 2010 

Others 1 (Wind & CPP) - - 

SGTPS - Bir'pur - Extn MPERC MYT 54/2009 3 rd March 2010 

ATPS - Chachai-Extn MPERC 25/2010 Jul-10 

4.2.2 Fixed and variable costs of each of the stations that have been considered 

for determining the power purchase cost with the following assumptions: 

Central Sector Stations for which capacity allocation percentage to each 

Discom has been defined by GoMP, Fixed Costs as approved by Central 

Electricity Regulatory Commission Orders for each individual station for 

FY 09 have been adopted for FY 10 to FY 13 also. 



4.2.3 Variable costs (including FPA) for MP Genco & Central Generating 

Stations have been adopted as per the October 2010 bills and have been 

annually escalated at the rate specified by the CERC in its notification 

dated 27th March 2009. 

4.2.4 For the new stations which have become available to state during the 

current year which are of the Central & State Sector Stations, the following 

methodology has been adopted: 

(a) For Sipat-I, Fixed and Variable Cost as indicated in the Retail Supply 

Tariff Order dated 29th July 2009 has been adopted. Also, the variable 

cost has been escalated at the rate of 6.35% as per the MPERC tariff 

order for FY11. 

(b) For DVC Chandrapur, single part tariff of DVC Mejia has been 

adopted since there were no means to assume this cost for the 

particular station. 

(c) For Essar Power, single part tariff @ Rs. 2.45 has been adopted as per 

the PPA signed by MP Power trading company Ltd. 

(d) For MP Genco rate for Birisinghpur Extension and Amarkantak Phase 

III, fixed and variable cost is taken as indicated in the Retail Supply 

Tariff Order dated 29th July 2009. Also, the variable cost has been 

escalated at the rate of 6.35% as per MPERC tariff order for FY11. 

(e) For Torrent (Gas), fixed tariff @ Rs. 1.08 and variable charge @ Rs. 

2.23 as per CERC order dated 11.01.2010 has been considered. 

4.2.5 The following table provides a summary of fixed and variable costs of each 

of the stations that have been considered for determining the power 

purchase cost with the following assumptions: 

(a) East, West and Central Discoms‟ share of fixed cost has been 

considered for its ARR purpose. 



(b) Fuel Price Adjustment (FPA) has been projected in the same manner as 

that of variable cost per unit and is included in the variable component 

of the generation cost. 

(c) The fixed and the variable costs of the new stations have been pooled 

together to get an average bulk supply rate [7] at which MP Tradeco 

will supply power to each individual Discom. 

7 Bulk Supply Rate includes fixed & variable Generation Cost and also cost of the associated 

Transmission Capacities of both PGCIL & MP Transco. 

4.3 For Future capacities 

4.3.1 For all the future capacities which are proposed to be commissioned in 

future the rates as per the PPAs have been considered. This has been 

explained in the note in subsequent sections. 

4.4 Details of costs for Existing power plants 

4.4.1 The table below provides the details of the costs viz. fixed costs and 

variable costs for all the existing plants 



Table-107: Cost details of existing stations 

Station 

Fixed charges 

in ` Cr. for the state 

Variable charges 

(including FPA, 

incentives,other costs) in 

`/kWh 

NTPC-Korba 97 0.92 

NTPC-Vindyachal I 108 1.80 

NTPC-Vindyachal II 129 1.76 

NTPC-Vindyachal III 152 1.76 

NTPC-Kawas 54 5.28 

NTPC-Gandhar 65 2.93 

KAPP 2.17 

TAPS 3.22 

NHDC - Indira Sagar 495 0.04 

Sardar Sarovar 194 0.07 

Omkareshwar HPS 263 0.50 

ATPS - Chachai-PH 1&2 61 1.18 

STPS - Sarani-PH 1, 2 & 3 322 1.36 

SGTPS - Bir'pur - PH 1 & 2 379 1.14 

CHPS-Gandhi Sagar 4 3.83 

CHPS-RP Sagar & Jawahar Sagar 0 1.51 

Pench THPS 11 0.28 

Banasgar Tons HPS-Tons 142 1.01 

Banasgar Tons HPS-Silpara - - 

Banasgar Tons HPS-Devloned - - 

Banasgar Tons HPS-Bansagar IV 14 0.89 

Birsingpur HPS 6 0.59 

Bargi HPS 10 0.35 

Rajghat HPS 5 1.39 

Marhi Khera HPS 27 3.75 

RSEB (Chambal,Satpura) 0 4.24 

UPPCL (Rihand,Matatila,Rajghat) 0 - 

Others 1 (Wind & CPP) 0 3.55 

NTPC - Sipat Stage II 119 1.15 

NTPC - Kahalgaon 2 53 2.11 

DVC (MTPS) - 2.90 

SGTPS - Bir'pur - Extn 369 1.01 

ATPS - Chachai-Extn 167 0.92 



4.5 Details of Costs for future capacities 

4.5.1 The table below provides details of the costs considered for future 

capacities which are based on the existing PPAs signed with them. 

Table-108: Cost details of future stations and basis 

Station 

Fixed Costs 

(` Cr.) 

Energy Charges 

`/kWh escalated 

for future years 

Basis 

NTPC Sipat - Stage I 107 0.63 As per MPERC tariff Order 

DVC (Chandrapur TPS Extn.) 296 2.36 Considered same as Mejia 

Case-I (Essar Power) - 2.45 As per PPA 

PTC - Torrent Surat (Gas) - 3.31 CERC order Jan‟10 

Maheswar Hydel 239 As per Guidelines 

4.5.2 On the basis of above details the Discom wise power purchase cost has 

been worked out as per the requirement and energy balance. In the 

Regulation no provision has been made for the principle of merit order 

dispatch while determining the power purchase cost. Looking to the 

decision of the Hon‟ble Commission in its previous tariff order, petitioner 

has adopted the principle of merit order dispatch for the purpose of deriving 

the power purchase cost. The power purchase cost has been calculated on 

the quantum of power so arrived by grossing up sales with the normative 

distribution loss of 27% as indicated in the regulation and also determined 

the quantum of power after considering the additional distribution loss of 

2.35% i.e. overall distribution loss of 29.35%. The power purchase cost so 

determined is elaborated in the subsequent table. 

4.5.3 The Hon‟ble Commission in its regulation 25.3 provides that the cost of 

power purchased from other Generating Companies, Traders and other 

Distribution Licensees shall be as per the PPAs and trading arrangements 

approved by the Commission, subject to the condition that the Distribution 

Licensees gets prior approvals of such arrangements from the Commission 

in accordance with the appropriate regulations. 



4.5.4 In the petition filed earlier on 21-12-10, the trading margin @ 3 paisa per 

unit as provided by MP Tradeco has been considered for procurement of 

energy through MP Tradeco. This cost has been projected in anticipation of 

the approval of the Commission and on the assumption that the Hon‟ble 

Commission will approve the same in the petition likely to be filed by MP 

Tradeco in due course. Further it is gathered that MP Tradeco has filed the 

petition for fixing the trading margin @ 4 paisa per unit, therefore it is 

prayed that the Hon‟ble Commission may please consider the trading 

margin as approved. Therefore, petitioner is hereby claiming the trading 

margin @ 4 paise per unit in this revised petition. 

4.6 Inter-state and Intra-state transmission charges 

4.6.1 Regulation 26 provides the charges payable to transmission licenses. The 

relevant provision is reproduced as below:- 

26.1. The transmission charges for the use of transmission system of Central 

Transmission Licensees for the power purchased from outside the State 

shall be considered as per the orders issued by the CERC from time to time. 

26.2. The transmission charges for the use of State Transmission System of 

the State Transmission Licensee shall be as per the orders of the 

Commission as issued from time to time. 

Submission of MPPKVVCL, Jabalpur as per the Regulation:- 

4.6.2 The inter-state transmission charges (PGCIL cost) have been projected as 

per the actual bills of FY 2011. For calculating the cost for FY 2012 and FY 

2013 the cost of additional inter-state transmission cost on account of new 

capacities coming up during the year has also been considered. 



4.6.3 The intra-state transmission cost i.e. MP Transco cost has been taken as per 

the tariff order of MP Transco. According to Table-53 of MP Transco tariff 

order dated 14/10/2010 the Transmission charges for long term beneficiary 

is determined as Rs. 2525 per MW per day. Further, as per the said MP 

Transco tariff order a transmission capacity of 2867 MW has been allocated 

to MPPKVVCL, Jabalpur for FY12. Therefore as per MP Transco tariff 

order MPPKVVCL, Jabalpur is required to pay Rs. 264.23 Cr in the year 

2011-12. 

Additional submission of MPPKVVCL, Jabalpur:- 

4.6.4 The Hon‟ble Commission in its tariff order dated 14/10/10 for MP Transco 

has allowed the terminal benefits of employees pertaining to MP Transco 

only. In the regulation RG-28(I) clause 27.6 provides that the existing 

arrangement of allowing funds for terminal benefits shall continue on actual 

payment basis, for one more year only i.e. for FY 2009-10 to the 

Transmission Licensee. In the eventuality either of the actions, as in (a) and 

(b) of mentioned regulation, are not completed within the time frame 

mentioned above, the Commission shall assess current pension contribution 

of existing employees for FY 2010-11 and onwards and shall allow such 

expenses only in the employee cost of Transmission Licensee pertaining to 

employees on the roles of Transmission Licensee from FY2010-11 

onwards. Subsequently Hon‟ble Commission has amended the regulation 

vide regulation no. ARG-28(I)(i) of 2010 in which it provides that the 

existing arrangement of allowing expenses for terminal benefits in ARR of 

MP Power Transmission Company Ltd. shall continue on actual payment 

basis up to FY 2010-11 to the Transmission Licensee. However, the 

Hon‟ble Commission has still not revised the ARR of MP Transco 

consequent of these changes in regulation. However, M.P. Transco has 

intimated that after including the terminal benefits for FY11 on actual 

payment basis, the following transmission charges may be claimed by the 

distribution companies in its ARR for FY12. 



Annual Transmission charges 2011-12 

Terminal Benefits 2010-11 (Projection) 

Less Provisioning 2010-11 

Total 

EZ Capacity 2867 MW Transmission Cost 

CZ Capacity 3125 MW Transmission Cost 

WZ Capacity 3237 MW Transmission Cost 

SEZ Capacity 12 MW Transmission Cost 

851.63 Cr. 

379.25 Cr. 

-37.51 Cr. 

1193.37 Cr. 

370.24 Cr. 

403.56 Cr. 

418.02 Cr. 

1.55 Cr. 

4.6.5 The FY 13 cost for MP Transco has been taken same as FY 12 in absence of 

any tariff order. 



A5: POWER PURCHASE COST 

5.1 The table below provide details of the energy balance and power purchase 

cost considering merit order dispatch for MPPKVVCL, Jabalpur based on 

the regulation only. 

Table-109: MPPKVVCL, Jabalpur 

( ` in Cr.) 

Details of PP Cost-As per provision of Regulation FY 11 FY 12 FY 13 

A Ex-bus Units Purchased 11,008 12,301 13,625 

B Fixed Cost (` Crs.) 1,001 1,020 1,020 

C Variable Cost (` Crs.) 1,390 1,543 1,980 

D 

MP Tradeco Trading Margin 

(@ 4 p/unit) 

E = B+C+D 

Total Power Purchase Cost 

- Ex Bus 

(` Crs.) 2,391 2,564 3,000 

E/A Rate of Power Purchase (`/kWh) 2.17 2.08 2.20 

H External Losses MU 316 325 353 

I 

Inter State Transmission 

Cost 

(` Crs.) 103 130 164 

J = (A - H) 

Units Purchased at State 

Periphery 

MU 10,692 11,977 13,272 

K = (I - E) 


at State Boundary 

(` Crs.) 2,494 2,694 3,165 

J/K 

Rate of Power Purchase at 

State Boundary 

(`/kWh) 2.33 2.25 2.38 

L 

Intra State Transmission 

Cost - MPTransco.) 

(` Crs.) 250 264 264 

M = (K+L) 


at Discom Interface 

(` Crs.) 2,745 2,958 3,429 

N Transmission Loss MU 437 490 543 

O = (K - N) 

Units Purchased at Discom 

Boundary 

MU 10,254 11,487 12,729 

O/M 


Discom Boundary 

(`/kWh) 2.68 2.58 2.69 

5.2 The details of Energy balance and power purchase cost considering the 

merit order dispatch for MPPKVVCL, Jabalpur after incorporating the 

additional submission as elaborated in the preceding Para is tabulated 

below: 



Table-110: MPPKVVCL, Jabalpur 

( ` in Cr.) 

Details of PP Cost-After additional Submission FY 11 FY 12 FY 13 

A Ex-bus Units Purchased 11,470 12,714 13,970 

B Fixed Cost (` Crs.) 1,001 1,020 1,020 

C Variable Cost (` Crs.) 1,519 1,687 2,095 

D 


(@ 4 p/unit) 

46 51 56 

E = B+C+D 


- Ex Bus 

(` Crs.) 2,566 2,758 3,171 



I 


Cost 

(` Crs.) 106 134 165 

J = (A - H) 


Periphery 

MU 11,140 12,375 13,613 

K = (I - E) 



(` Crs.) 2,672 2,891 3,336 

J/K 



(`/kWh) 2.40 2.34 2.45 

L 



(` Crs.) 250 370 370 

M = (K+L) 



(` Crs.) 2,922 3,261 3,707 


O = (K - N) 


Boundary 

MU 10,685 11,869 13,056 

O/M 



(`/kWh) 2.73 2.75 2.84 

5.3 It could be seen from above tables that MPPKVVCL, Jabalpur will require 

additional 413 MUs of energy at Ex-bus on account of increase in losses of 

2.35% due to take over of the distribution business of RECS. Additional 

amount of Rs. 197 cr. which includes 143 Cr towards variable charge of 

power purchase cost, Rs 3 Cr towards Inter-state transmission charges and 

Rs. 51 Cr towards trading margin to MP Tradeco @ 4 paise per unit, will be 

required in FY12. Similarly on account of amendment in regulation of MP 

Transco Rs. 106 Cr towards transmission charges of 2010-11 will also be 

required in FY12 for paying to MP Transco. Therefore additional amount of 

Rs. 303 Cr over and above Rs. 2958 Cr which has been calculated as per 

the provisions of the regulation will be required in FY12 towards power 



purchase cost. It is therefore prayed that Hon‟ble Commission may kindly 

consider and allow Rs. 3261 Cr towards Power Purchase Cost as a prudent 

cost which includes Inter and Intra state transmission charges. 

5.4 The Comparison of Power Purchase Cost which includes the Inter-state and 

Intra-Discom transmission cost as per the provision of regulation and after 

incorporating the additional submission is given in table below:- 

Table-111: Comparision of Power Purchased Cost for FY12 

As per 

Regulation 

As per 

Additional 

Submission 

( ` in Cr.) 

Deviation 

A Ex-bus Units Purchased 12,301 12,714 413 

B Fixed Cost (` Crs.) 1,020 1,020 0 

C Variable Cost (` Crs.) 1,543 1,687 143 

D 


(@ 4 p/unit) 

0 51 51 

E = B+C+D 


- Ex Bus 

(` Crs.) 2,564 2,758 194 



I 


Cost 

(` Crs.) 130 134 3 

J = (A - H) 


Periphery 

MU 11,977 12,375 398 

K = (I - E) 



(` Crs.) 2,694 2,891 197 

J/K 



(`/kWh) 2.25 2.34 0.09 

L 



(` Crs.) 264 370 106 

M = (K+L) 



(` Crs.) 2,958 3,261 303 


O = (K - N) 


Boundary 

MU 11,487 11,869 382 

O/M 



(`/kWh) 2.58 2.75 0.17 

5.5 It is prayed that Hon‟ble Commission may kindly consider additional cost 

of Rs. 303 Cr and may kindly allow Rs. 3261 towards power purchase cost 

for FY12. 



5.6 SLDC Charges 

Hon‟ble Commission in its Regulation has not provided the cost to be incurred 

towards SLDC charges. As per SLDC tariff order for FY11, the SLDC charges 

of Rs. 2.24 Cr for FY12 has been projected which has been estimated as 10% 

higher than the SLDC charges for FY11. 

5.7 MP Genco True cost 2007-08 

The Hon‟ble Commission has issued the MP Generation true order for 

2007-08 on 24 th Jan‟2011. The Commission has allowed Rs. 214.88 Cr. to 

MP Genco to recover the amount during FY-12. At Para 8 of the said order 

it is indicated that amount emerging from true-up shall be recoverable from 

the three distribution companies of the state in the ratio of energy supplied 

to them in FY 07-08 in equal monthly instalments during FY 2011-12. This 

order has been received by the petitioner on 28 th Jan‟2011, therefore the 

impact of MP Genco true-up amount has not been incorporated in the ARR. 

It is prayed to the Hon‟ble Commission that the true-up amount of MP 

Genco for 2007-08 may kindly be allowed additionally over and above the 

ARR for FY-12 prayed in this petition. 



A6: O&M EXPENSES 


6.1.1 Regulation 32 provides the method of estimation of O&M expenses. The 

relevant provision is reproduced as below:- 

32.1 Operation and Maintenance expenses shall be determined for the 

Tariff Period based on normative O&M expenses specified by the 

Commission in these Regulations. The O&M expenses comprise of 

employee cost, repairs & maintenance (R&M) cost and 

administrative & general (A&G) cost. The norms for O&M 

expenses have been fixed on the basis of metered sale and Gross 

Fixed Assets (GFA) of the Distribution Licensees. These norms 

exclude pension, terminal benefits and incentive to be paid to 

employees, taxes payable to the Government, MPSEB expenses and 

fee payable MPERC. The Distribution Licensee shall claim the 

taxes payable to the Government and fees to be paid to MPERC 

separately as actual. The claim of expenses towards pension and 

terminal benefits shall be dealt as indicated in these regulations at 

clause 32.6 and 32.6. 

32.2 Normative O&M expenses other than expenses on payment of 

arrears to employees up to 31.08.08 on account of revision of pay 

scales of the employees based on the Sixth Pay Commission 

recommendations, as implemented by the Distribution Licensees at 

the commencement of the Tariff Period have been escalated at the 

rate of 6.14% considering a weighted average of Wholesale Price 

Index and Consumer Price Index in the ratio of 60: 40. 



32.3 For first Financial Year of the control period, the impact of 

implementation of 6th Pay Commission recommendations has been 

considered in employees cost, which has been escalated @ 6.14% in 

subsequent Years. The Commission has also considered expected 

expenditure of Rs. 33.37 Crore for East Discom, Rs.31.31 Crore for 

West Discom and Rs. 29.52 Crore for Central Discom in each 

financial year towards payment of arrears up to 31.8.2008 for the 

period from 2010-11 to 2012-13 as one third each year for the 

Distribution Licensees. 

32.4 In the case of repair & maintenance for determining expenses to be 

allowed for the control period, trend of repair & maintenance on 

percentage of opening GFA as per audited figures of 2006-07, 2007- 

08 & 2008-09 have been taken. For administration & general 

expenses, audited figures for the year 2008-09 have been taken as 

base and escalated Year-wise at inflation rate of 6.14% to arrive at 

the amounts allowed for the control period. 

32.5 The amount of arrears on account of 6th Pay Commission for the 

period up to 31.08.08 actually paid by the Distribution Licensees 

shall be compared with amount towards this included in O&M 

charges at the time of true-up and variation, if any, shall be trued up. 

32.6 Employees transfer to Companies from MPSEB is yet to take place. 

Actuarial analysis for assessment of present level of unfunded 

terminal liabilities and segregation of this liability for pensioners, 

past service rendered by employees on rolls and current provision 

for serving employees is yet to be completed. The scheme for 

funding this un-funded liability and operational since Terminal 

Benefit Trust Fund has been pronounced by the State Government. 



32.7 As per the Commission‟s view, the funds needed for pension 

contribution of existing employees i.e. current liability for each Year 

alone should be allowed in the employee cost of the M.P. 

Transmission Company Ltd., M.P. Generating Company Ltd., and 

three Distribution Companies. The Commission, in the intervening 

period, has been allowing funds needed for actual pension payment 

and other terminal benefits like gratuity. With the rapid increase in 

pension bills, its impact on tariff is progressively going up. This 

arrangement of allowing actual pension payment has become 

unsustainable and will have to be discontinued in near future. In 

view of the above, the Commission in the MYT regulations for 

Transco had directed that an actuarial analysis for determining 

pension liability of pensioners as also for service already rendered 

by existing employees on one hand and current provision needed for 

each fiscal year commencing from FY 2010-11 for serving 

employees on other hand, be got conducted for each Year and 

findings be reported to the Commission. The M.P. Transmission 

Company Limited had been charged with carrying out this activity 

by Sept, 2009. It has now been informed that this activity is likely to 

be completed by February, 2010. The Commission, based on 

outcome of actuarial analysis, will take a comprehensive view and 

will firm up a strategy to meet this unfunded liability. The 

Commission, while finalising the above, shall also take into 

consideration the various arrangements made in other States for 

meeting this liability as also the views of all stakeholders. 

32.8 Increase in O&M charges on account of war, insurgency or changes 

in laws, or like eventualities where the Commission is of the 

opinion that an increase in O&M charges is justified, may be 

considered by the Commission for a specified period. 



32.9 Any saving achieved by a Licensee in O&M expenses in any Year 

shall be allowed to be retained by it. The Licensee shall bear the 

loss if it exceeds the targeted O&M expenses for that Year. 

32.10 The norms for O&M expenses shall be as under: 

a. R&M Expenses shall be allowed on the opening GFA of the 

financial year @ 2% for East Discom, @ 2% for West Discom 

and @ 2.3% for Central Discom. 

b. Employee expenses and A&G expenses have been worked out for 

the financial year 2010-11 after taking in to account the past 

actual expenses as per audited balance sheets, expenses on 

account of revision of pay and arrears as per 6th pay Commission 

etc. 

Expenses allowed (Rs. in Crore) for 

2010-11 

DISCOMS East West Central 

Employee expenses excluding arrears 415.06 389.37 367.15 

Arrears 33.37 31.31 29.52 

A&G expenses 73.37 64.39 69.57 

For subsequent financial years of the control period employee 

expenses (excluding arrears) and A&G expenses will be escalated 

@ 6.14% every year for taking care of normal inflation. Expenses 

against payment of arrears for subsequent financial years of the 

control period shall be allowed on the same level as allowed for 

2010-11 indicated in the above table. 

32.11 Incentive/ disincentive for increase/ reduction in metered sale shall 

be provided. Discom wise incentives/ disincentives based on the 

present level of metered sale shall be as follows: 



1. In case of MP Poorv Kshetra Vidyut Vitaran Co. Ltd., for every 

1% increase in metered sales, expressed as percentage of total 

sale, from 80 % (present level of metered sale), an incentive of 

Rs.3.27 Crore shall be provided. Similarly a disincentive for 

every 1% increase in un-metered sale from 20% shall also be 

applicable at the rate of Rs.3.27 Crore. 

2. In case of MP Madhya Kshetra Vidyut Vitaran Co. Ltd., for every 


sale, from 81% (present level of metered sale), an incentive of 




3. In case of MP Paschim Kshetra Vidyut Vitaran Co. Ltd., for every 


sale, from 70% (present level of metered sale), an incentive of 




32.12 The amount of incentive so earned by the distribution licensee shall 

be utilized for implementation of meterisation schemes which may 

include expenses on account of procurement & installation of 

meters on unmetered connections and other related activities. The 

Licensee shall keep a separate account of the incentive earned and 

its actual utilisation and shall submit the details to the Commission 

along with subsequent ARR/ true up petition. 

32.13 For computing metered sale for the purpose of incentive/ 

disincentive, actual sale done through DTR meters to unmetered 

agricultural connections shall be considered as metered sale 

provided that this substantiated by the licensee. 



32.14 For the purpose of arriving at metered sale percentage, fraction 

more than 0.5 shall be rounded off to next higher integer. Similarly, 

fraction less than or equal to 0.5 shall be rounded off to next lower 

integer. 

Submission of MPPKVVCL, Jabalpur as per the regulation:- 

6.1.2 The O&M expenses based on the provision of regulation is as below:- 

Employee Cost 

As per the provision of regulation employee cost has been calculated as 

below:- 

Table-112: Employee Cost -As per provision of Regulation 

( ` in Cr.) 

Particular FY11 FY12 FY13 

Employees Expenses excluding arrears 415.06 440.54 467.59 

Arrears 33.37 33.37 33.37 

Total 448.43 473.91 500.96 

A&G Expenses 

6.1.3 As per the provision of regulation A&G expenses cost has been calculated 

as below:- 

Table-113: Administrative & General Expenses-As per ( Regulation ` in Cr.) 

Particulars FY11 FY12 FY13 

A&G Expenses 73.37 77.87 82.66 

Repair and maintenance Expenses 

6.1.4 As per the provision of regulation R&M expenses has been calculated as 

below:- 

Table-114: Repair and Maintenance Expenses-As per Regulation 

( ` in Cr.) 

Sr. No. Particulars FY 10-11 FY 11- 12 FY 12- 13 

1 Opening GFA of FY year 2196.64 2798.85 4263.85 

2 2% of GFA 43.93 55.98 85.28 



Other Item of O&M Expenses 

Terminal Benefit (Pension, Gratuity and Leave Encashment) 

6.1.5 As per the regulation 32.6 and 32.7 the method of calculation of Terminal 

Benefit has been provided 

6.1.6 The Government of Madhya Pradesh („GoMP or „State Government‟), vide 

an Order No. 6259-FRS-17-13- 2002 dated 30th September, 2003, in 

exercise of powers conferred by subsections (1), (2), (5), (6) and (7) of 

section 131 and section 133 of the electricity Act 2003 read with sub 

section (1), (2) and (3) of Section 23, 24 and Sub section (2) of section 56 

of the Madhya Pradesh Vidyut Sudhar Adhiniyam, 2000, makes the rule 

(herein after referred as Madhya Pradesh Electricity Reform First Transfer 

Scheme Rules, 2003) for regulating the transfer and vesting of functions, 

properties and interests rights and liabilities of the Madhya Pradesh State 

Electricity Board in the State Government and re transfer and revesting 

thereof by the State Government in any other company or body corporate or 

authority and also for the transfer of Personnel of the Madhya Pradesh State 

Electricity Board to any other company or body corporate or authority and 

for determining the terms and condition on which such transfer and vesting 

shall be made. According to rule 10 and 11 of these rule stated as follows: 

“10. The State Government shall notify appropriate arrangement in regard 

to the funding of the pension funds and other personnel related funds 

by the transferees to the extent they are not funded on the date of the 

transfer of the personnel from the Board including for the date of the 

transfer, by the respective transferees to which these personnel are 

transferred and till such time such payments shall be duly made by the 

Board”. 

“11.The State Government shall notify appropriate arrangements in regard 

to the funding and due payment of the terminal benefits to the existing 



pensioners of the Board as on the date of the Transfer and till such 

time such payments shall be duly made by the Board.” 

6.1.7 GoMP vide order No. 4003-FRS-17-13-2002 dated 13th June 2005 makes 

amendments in the Madhya Pradesh Electricity Reform First Transfer 

Scheme Rules, 2003 the amended rule 10 and 11 read as follows: 

“10. In regard to the funding of the pension funds and other personnel 

related funds by the transferees to the extent they are not funded on 

the date of the transfer of the personnel from the Board including the 

due payment of the amounts to personnel who retire after the date of 

the transfer, by the respective transferees to which these personnel are 

transferred following arrangements, but not limited to them, shall be 

made till such time such payments shall be duly made by the Board”: 

a) All the personnel of the Board who retire after the date of the transfer 

shall be the pensioners of the respective transferees to which these 

personnel are transferred and they shall be paid pension and other 

terminal benefit regularly by the respective transferees. The priority of 

payment of the terminal benefits to such pensioners shall be at par 

with the payment of salary and wages to the personnel of the 

respective transferees. However the contribution towards the pension 

and other terminal benefits for the past service rendered by the 

personnel up to the date of transfer in MPSEB/MPEB, shall be made 

by Transco and contributions for the part of service rendered under 

the transferee shall be provided by the respective transferee. 

b) A separate fund shall be created by the transferees for payment of 

pension and other terminal benefits of the personnel who retire after 

the date of the transfer through regular subscription of appropriate 

amount into a terminal Benefits Trust being created by the State 

Government. 

“11. In regard to the funding and due payment of the terminal benefits to 

the existing pensioners of the Board as on the date of the transfer 



following arrangements but not limited to them shall be made and till 

such time such payment shall be duly made by the Board: 

c) All the existing pensioners of the Board, as on the date of transfer of 

the personnel shall be treated as deemed transferred to the Transco 

and they shall be paid terminal benefits regularly by the Transco. The 

priority of payment of the pension and other terminal benefits to the 

existing pensioners shall be at par with the payment of salary and 

wages to the personnel of the Transco. 

d) A separate fund shall be created by the Transco for payment of 

pension and other terminal benefits of the personnel who retire after 

the date of the transfer through regular subscription of appropriate 

amount into a terminal Benefits Trust being created by the State 

Government. 

6.1.8 The Government of Madhya Pradesh („GoMP or „State Government‟), vide 

an Order No. 3679-FRS-18-13- 2002 dated 31st May, 2005 (i.e date of 

transfer) , published in the gazette of Madhya Pradesh dated 31 st May‟ 

2005, have restructured the functions and undertakings of Generation, 

Transmission, Distribution and Retail Supply of electricity earlier carried 

out by the Madhya Pradesh State Electricity Board („MPSEB‟ or the 

„Board‟) and transferred the same to five Companies to function 

independently. The five Companies are as under: - 

1) M.P. Power Generating Company Ltd., Jabalpur ; 

2) M.P. Power Transmission Company Ltd., Jabalpur ; 

3) M.P. Poorv Kshetra Vidyut Vitaran Company Ltd., Jabalpur ; 

4) M.P. Madhya Kshetra Vidyut Vitaran Company Ltd. Bhopal ; 

5) M.P. Paschim Kshetra Vidyut Vitaran Company Ltd., Indore ; 

6.1.9 Subsequently the Government of Madhya Pradesh („GoMP or „State 

Government‟), vide an Order No. 4068-FRS-18-2002-XIII dated 12 th 

June‟2008, published in the gazette of Madhya Pradesh he final opening 

balance sheets of the companies. Para “K” of the said order stipulated as 

follows: 



“K.” The past unfunded liabilities of the pensioners and employees of the 

MPSEB existing as on 31st May 2005 are to be assessed by Actuarial 

valuation and is therefore retained with residual MPSEB for the time 

being. The actual pension/Gratuity payments shall be claimed by MP 

Power Transmission Co. Ltd in its ARR till requisite fund equivalent to 

the past unfunded liabilities is built up in the manner provided in Rule 

10 and 11 notified earlier vide No. 4003-FRS-17-13-2002 dated 13th 

June 2005. 

6.1.10 As per the directives an actuary valuation was out carried in the year 2009- 

10 which assessed the Terminal benefit liability of MPPKVVCL as on 31 st 

March‟2009. 

6.1.11 GoMP in its official gazette no. 615 dated 30/11/2010 passed an order to 

transfer personnel of Madhya Pradesh Electricity Board to the successor 

entities. 

6.1.12 In the light of above legal provision related to terminal benefits it can be 

said: 

a. that the liability to pay terminal benefits to the personnel who retired 

from the service of the MPEB / MPSEB on or before 31 st May 2005 is 

vested with MP Transco. 

b. that the liability to pay terminal benefit to the personnel who retired 

after 31 st May 2005 is vested with respective transferee company. 

However the contribution towards the pension and other terminal 

benefits for the past service rendered by the personnel up to 31 st May 

2005 in MPSEB / MPEB, shall be made by Transco and contributions 

for the part of service rendered under the transferee shall be provided 

by the respective transferee. 

6.1.13 As stated above the actuarial valuation carried out and liability as on 31 st 

March‟2009 for MPPKVVCL determined as follows: 



Table-115: Actuarial valuation & Liability as on 31 st March'2009 

Particulars 

Gratuity 

Leave 

Encashment 

Pension 

Pensioners 

Employees / Family 

pensioners 

2377.07 

( ` in Cr.) 

Total 

Liability 

Total Past Service Liability 377.22 133.61 2887.90 

Liability Pertaining to MPSEB 

(up to 01/06/2005) 

319.65 112.22 1396.26 618.56 2446.69 

Liability Pertaining to MPPKVVCL 

(from 01/06/2005 to 31 st March 2009 

57.57 21.39 362.25 

441.21 

6.1.14 In addition to this liability, Actuary prescribed the following percentage of 

the Future contribution rate (as a % of Basic Pay + Grade pay + DA) 

required to be made by MPPKVVCL towards meeting the liabilities arising 

due to future Service: 

Table-116: Future Contribution rate of liability on account of Actuary 

Leave 

Assumption Gratuity Pension 

Encashment 

( ` in Cr.) 

Total 

Contribution rate 4.95% 21.73% 0.77% 27.45% 

Interest rate 7% 7% 7% 

6.1.15 According to above prescribed data liability for the 2009-10, 2010-11 and 

2011-12 has been worked out and this liability is pertaining to eligible 

employees of such benefit: 

Table-117: Amount of Future Contribution liability 

( ` in Cr.) 

Year Gratuity Pension 

Leave 

Encashment 

Total 

2009-10 15.36 67.44 2.38 85.18 

2010-11 22.03 104.34 4.29 130.66 

2011-12 23.77 112.53 4.62 140.92 

Total 61.16 284.31 11.29 356.76 

6.1.16 In the light of above, it is prayed that, Hon‟ble Commission kindly allow 

the cost of Rs.797.97 Cr. in the ARR of 2011-12, for meeting the past 

service liability in respect of MPPKVVCL as per the actuarial valuation 

report: 



Table-118: Terminal Benefit Liability 

( ` in Cr.) 

Particular Gratuity Pension 

Leave Total 

Encashment Liability 

Past Service Liability Pertaining to 

MPPKVVCL as determined by actuary 

57.57 362.25 21.39 441.21 

(From 01.06.2005 to 31 st March'2009) 

2009-10 15.36 67.44 2.38 85.18 

2010-11 22.03 104.34 4.29 130.66 

2011-12 23.77 112.53 4.62 140.92 

Total up 2011-12 118.73 646.56 32.68 797.97 

FY 20012-13 25.42 120.36 4.95 150.73 

MPERC Fees 

6.1.17 MPERC Fees has been projected to Rs. 0.50 Crore based on past trend 

Incentive/Disincentive to metered sale 

6.1.18 As per the provision of regulation Incentive and disincentive of metered 

sale is estimated as below:- 

Table-120: Metered Sale incentive/disincentive-As per Regulation 

( ` in Cr.) 


1 Total Sale (MU) 7178.11 8385.49 9674.20 

2 Metered sale (MU) 5743.97 6560.54 7562.68 

3 % of metered sale wrt Total 80% 78% 78% 

4 Variation wrt 80% 0% -2% -2% 

5 Rate of Incentive (In Cr) 3.27 3.27 3.27 

6 Total Incentive 0.00 -6.54 -6.54 

6.1.19 Gist of O&M expenses as per the provision of regulation is summarised as 

below:- 

Table-121: Gist of O&M expenses-As per Regulation 

( ` in Cr.) 


1 Employee Cost(including arrears) 448.43 473.91 500.96 

2 A&G Expenses 73.37 77.87 82.66 

3 R&M expenses 43.93 55.98 85.28 

4 Other Item of O&M expenses 0.50 141.42 151.23 

5 metered sale incentive 0.00 -6.54 -6.54 

Total O&M expenses 566.23 742.65 813.59 




Employee Cost 

6.1.20 Employee expenses mainly comprise of salaries, dearness allowance, 

bonus/Ex gratia/and other allowance, wage revision arrears and Terminal 

Benefits in the form of pension & gratuity, leave encashment and staff 

welfare expenses. 

6.1.21 During the year 2010-11 pursuant to different orders of Hon‟ble 

Commission and Hon‟ble High Court of Madhya Pradesh, the electricity 

distribution business of the four Rural Electricity Co-operative Societies 

viz. Nowgaon, Sidhi, Laundi and Amarpatan has been taken over by 

MPPKVVCL wef 15 th Aug‟2010. Therefore MPPKVVCL is required to 

incur additional operating expenses such as salary of employees, 

administrative expenses and Repair and Maintenance of plant and 

machinery, lines and cables etc. Previously these expenses were incurred by 

the respective societies. 

6.1.22 GoMP has increased DA of employees/Pensioners in the year 2010 by 13% 

in addition to normal yearly increment. MP Poorv Kshetra Vidyut Vitran 

Co. Ltd has started paying DA at increased rate. 

6.1.23 The Regulation of the Hon‟ble commission came into force in the year 

2009 however impact of 6 th pay commission and increase in D.A. 

afterwards may not be full incorporated therefore it is prayed that Hon‟ble 

commission kindly give due regards before allowing the employee cost for 

FY 11-12. 

6.1.24 Employees cost has been projected on the basis of actual available data up 

to Sep‟2010 and projected for next 6 months. The Employees cost has been 

inflated by 10% for FY 11-12 and FY 12-13 so as to accommodate the 

increase in salary cost due to increase in DA and effect of coalescence of 

consumers of RECS with LT consumers of the company. 



Table-122: Employee Cost as per additional submission 

( ` in Cr.) 

Particular FY11 FY12 FY13 

Employee Strength 

Working Strength At The Beginning Of The Year 13,282.00 12,682.00 11,954.00 

Salaries 306.09 336.70 370.37 

D.A. 81.07 89.71 98.09 

Other Allowances & Relief 14.52 15.98 17.57 

Medical Expenses Reimbursement 0.84 0.92 1.01 

Leave Travel Assistance (0.00) (0.00) (0.00) 

Earned Leave Encashment 9.65 10.61 11.68 

Subsidised Electricity To Employees 2.04 1.71 2.47 

Interim Relief / Wage Revision 60.00 66.00 72.60 

Staff Welfare Expenses 0.03 0.04 0.04 

Apprentice And Other Training Expenses 0.37 0.41 0.45 

a) Provident Fund Contribution 0.57 0.63 0.69 

b) Pension Payments 91.24 100.36 110.40 

c) Gratuity Payment 42.71 46.98 51.68 

Any Other Items 1.21 1.33 1.46 

Bonus/Exgratia To Employees 0.07 0.08 0.09 

Total 610.41 671.46 738.60 

Employee expenses capitalised 12.59 13.36 14.18 

Net Employee expenses (F)-(G) 597.82 658.10 724.42 

6.2 Administrative and General Expenses 

6.2.1 Administration expenses mainly comprise of rent, Insurance, Conveyance 

and travelling, telephone and other miscellaneous expenses like 

communication expenses, professional charges, conveyance and travelling, 

other debits, MPERC Fees, Common Allocation expenses of MPSEB. On 

account of taken over the distribution business of 4 RECS, petitioner is 

required to incur additional cost under A&G expenses for proper services to 

the consumers of society area. Expenses on A&G of society‟s area have 

been projected on the basis of actual figures of FY 2009-10 and 

subsequently inflated by 6.14%. The additional cost for society area is Rs. 

2.97 Cr. (FY 2010-11) Rs. 3.15 Cr. (FY 2011-12) and Rs. 3.34 Cr. (FY 

2012-13). The head wise overall A&G expenses has been projected and 

provided in the following table:- 



Table-123: Administrative & General Expenses 

( ` in Cr.) 


Rent 0.54 0.57 0.61 

Rates & Taxes 2.49 2.64 2.81 

Insurance 9.27 9.84 10.45 

Revenue Stamp Expenses Account 0.03 0.03 0.03 

Telephone,Postage,Telegram & Telex Charges 2.01 2.14 2.27 

Incentive & Award To Employees/Outsiders 0.42 0.44 0.47 

Consultancy Charges 0.02 0.03 0.03 

Technical Fees 1.14 1.21 1.28 

Other Professional Charges 0.14 0.15 0.16 

Conveyance And Travel 13.18 13.99 14.85 

Others 0.79 0.84 0.89 

MPERC Fees 0.5 0.50 0.5 

Fee And Subscriptions Books And Periodicals 0.03 0.03 0.03 

Printing And Stationery 3.16 3.35 3.56 

Advertisement Expenses 0.9 0.95 1.01 

Electricity Charges To Offices 3.47 3.68 3.91 

Water Charges 0.15 0.16 0.17 

Entertainment Charges 0.05 0.05 0.19 

Miscellaneous Expenses 37.23 39.52 41.81 

Allocation of Common Expenditure of MPSEB 16.69 17.72 18.81 

Legal Charges 1.85 1.97 2.09 

Auditor's Fee 0.21 0.21 0.24 

Total Charges 94.26 100.01 106.14 

A&G expenses capitalized 0.73 0.78 0.83 

Net A&G expenses 93.53 99.23 105.31 

6.3 Repair and Maintenance Cost: 

6.3.1 Repairs and Maintenance Expenses go towards the day to day upkeep of the 

distribution network of the company and form an integral part of the 

company‟s efforts towards reliable and quality power supply that results in 

the reduction of losses in the system. With ageing, the quantum of such 

expenses is bound to increase in future. Such expenditure is further 

influenced by a number of other factors namely: 

Overloading of equipments leading to equipment failures 

Availability of time for system shut down for maintenance of 

equipments. 

Length of network and Voltage level. 

Escalation in cost of raw materials. 

Timely Availability of raw materials. 



6.3.2 R&M has been projected based on the norms of the commission. However, 

On account of taken over the distribution business of 4 RECS, petitioner is 

required to incur additional cost under R&M expenses to maintain the 

distribution network of society area. Expenses on R&M of societies area 

have been projected on the basis of actual figures of FY 2009-10 and 

subsequently inflated by 6.14% as Audit of Annual Accounts of some of the 

Societies is pending and proper capital work plan in the area of REC 

societies is to be prepared and approved by Hon‟ble commission hence 

projection of Fixed assets cannot be made. The additional expenses have 

been projected as Rs. 1.09 Cr. (FY 2010-11) Rs. 1.16 Cr. (FY 2011-12) and 

Rs. 1.23 Cr. (FY 2012-13). The overall R&M expenses has been projected 

and provided in the following table : 

Table-124: Repair and Maintenance Expenses 

( ` in Cr.) 


1 Plant and Machinery 28.03 34.87 53.87 

2 Building 7.99 9.93 15.34 

3 Civil Works 1.93 2.4 3.71 

5 Lines, Cables Net Works etc. 9.34 11.62 17.95 

6 Vehicles 1.89 2.35 3.62 

7 Furniture and Fixtures 0.06 0.08 0.12 

8 Office Equipments 1 1.25 1.93 

9 Station Supplies 0.02 0.02 0.03 

10 Any other items -4.32 -5.37 -8.29 

A Gross R&M expenses 45.94 58.31 88.28 

B Less: R&M expenses capitalised 0.92 1.17 1.77 

A-B Net R&M expenses 45.02 57.14 86.51 

Other Items of O&M 

Terminal Benefit and MPERC Fees 

6.3.3 Terminal Benefit has been incorporated under employee cost therefore not 

included in other items of O&M. Expenses, similarly MPERC fees has been 

incorporated under Administrative and General Expenses. 



Metered Sales Incentive 

6.3.4 The Petitioner has submitted that the benchmark for billing to unmetered 

agricultural consumers may be as per the seasonal and non seasonal 

periods. It is proposed that agricultural season may be considered as 

October to April and non agricultural season may be considered as May to 

September. Therefore the consumption of unmetered connection may effect 

and will increase. Further unmetered sales are unforeseeable obvious reason 

of variation in agricultural consumption specially for the temporary 

agricultural consumer, due to climatic factor etc..Hence the proportion of 

metered connection cannot be controlled strictly the disincentive on account 

of increase in unmetered consumption would mean penalty for obligation to 

supply to the consumer. Therefore in the interest of the consumer the 

disincentive for unmetered consumption above 20% has not considered. 

6.3.5 The Comparison of O&M as per the provision of regulation and after 

incorporating the additional submission is given in table below: 

Table-125 Comparision of O&M expenses for FY 12 

( ` in Cr.) 

Particulars 

As per norms 

As per 

additional 

Submission Variation 

Employee Cost 473.91 658.10 184.19 

A&G Expenses 77.87 99.23 21.35 

R&M expenses 55.98 57.14 1.16 

Other Item of O&M expenses 141.42 - -141.42 

Metered sale incentive -6.54 - 6.54 

Total 742.65 814.47 71.82 

6.3.6 It is prayed that Hon‟ble Commission may kindly considered additional 

cost of Rs. 71.82 Cr and may kindly allow Rs. 814.47 O&M for FY12. 



A7: INVESTMENTS 

7.1 The capital investments are planned extensively by MPPKVVCL under 

various schemes like Feeder Segregation, ADB, RAPDRP, STN and TSP. 

The capital investment plan is prepared to achieve following major 

objectives: 

a. Loss reduction. 

b. System strengthening. 

c. Regular supply to rural households through Feeder Segregation. 

d. Reliability of services. 

e. Rural Electrification. 

Table-126: Capital expenditure Plan 

( ` in Cr.) 

Name of Scheme FY 2010-11 FY 2011-12 FY 2012-13 

ST(N) 30 35 40 

TSP 21 30 35 

SCSP 33.75 40 45 

Feeder Separation(capital) 20.92 100.56 80.98 

Feeder Separation Ph-1 (IDC) 3.27 61.39 16.37 

Feeder Separation Ph-2 (IDC) - 41 45.55 

ADB incl ERP 100 248 156 

RGGVY(Loan) 10 37.91 33.27 

KMP-New Ag pump conn 5 5 5 

Feeder Separation-Loan(REC) Ph-1 83.6 585.2 167.2 

Feeder Separation-Loan(ADB) Ph-2 - 485.91 323.94 

R-APDRP 181.72 414 190 

RGGVY(Grant) 90 341.17 299.45 

JBIC 30.82 - - 

SBI counter fund(ADB) 20 93.08 37.92 

Consumer Deposits 43 45 47 

Total 673.08 2,563.22 1,522.69 



A8: FINANCING 

8.1 Capitalization 

8.1.1 The MPPKVVCL has Rs.640.76 Cr. CWIP as on 31st March 2010 as per 

the Audited Accounts for FY 2009-10. For the projection period, the 

capitalization has been assumed as follows: 

8.1.2 It is assumed that achievement of the total investment plan on a yearly basis 

would be 65% for (FY 2010-11), 75% for (FY 2011-12) and 70% (FY 

2012-13). The entire investments achieved for a particular year are added to 

the opening CWIP to obtain the CWIP for the year. 

8.1.3 The capitalization rate is considered as uniform for entire control period as 

50% of the investment achieved. 

Following table shows the year wise bifurcation of CWIP: 

Table-127: CWIP 

( ` in Cr.) 

Particulars FY 09-10 FY 10- 11 FY 11-12 FY 12-13 

Opening Balance of CWIP 640.76 766.91 830.89 1743.77 

Fresh Investment during the year 378.53 666.19 2377.88 1997.4 

Investment capitalised -252.38 -602.21 -1465 -1649.72 

Closing Balance of CWIP 766.91 830.89 1,743.77 2091.45 

8.1.4 Proportion of assets to be added in FY 2010-11 to FY 2012-13 is considered 

at the average of last 3 years total assets addition. Following is the assets 

wise details of GFA addition : 

Table-128: Fixed assets addition 

( ` in Cr.) 

Particular FY 10-11 FY 11-12 FY 12-13 

Land & land rights 0.1 0.23 0.25 

Buildings 7.42 18.04 20.31 

Hydraulic works 0 0 0.01 

Other civil works 0.03 0.1 0.08 

Plant & machinery 197.26 426.68 540.38 

Lines, cables, networks 395.03 1014.16 1083.57 

Vehicles 0.07 0.17 0.22 

Furniture & fixtures 0.01 0.03 0.02 

Office equipments 2.3 5.59 4.87 

Total 602.21 1,465.00 1,649.72 



A9: DEPRECIATION 

Provision of Regulation 

9.1 Para 30 of regulation provides the method of calculation of depreciation. 

The relevant provision is reproduced as below:- 

30.1 For the purpose of Tariff, depreciation shall be computed in the 

following manner: 

a. The value base for the purpose of depreciation shall be the capital 

cost of the assets as admitted by the Commission 

b. The approved/accepted cost shall include foreign currency funding 

converted to equivalent rupee at the exchange rate prevalent on the 

date of foreign currency actually availed. 

c. The salvage value of the asset shall be considered as 10% and 

depreciation shall be allowed up to maximum of 90% of the 

capital cost of the asset. 

d. Land other than land held under lease shall not be a depreciable 

asset and its cost shall be excluded from the capital cost while 

computing depreciable value of the asset. 

e. Depreciation shall be calculated annually based on „straight line 

method‟ and at rates specified in Annexure III to these Regulations 

for the assets of the Distribution System declared in commercial 

operation after 31/03/2010. 

Provided that, the remaining depreciable value as on 

31st March of the Year closing after a period of 12 Years from 

Date of Commercial Operation shall be spread over the balance 

useful life of the assets. 



Provided further that the Consumer contribution or capital 

subsidy/ grant etc. for asset creation shall be treated as may be 

notified by the Commission from time to time. 

f. In case of the existing Projects, the balance depreciable value as 

on 1.4.2010 shall be worked out by deducting the cumulative 

depreciation including Advance against Depreciation as admitted 

by the Commission up to 31.3.2010 from the gross depreciable 

value of the assets. The rate of Depreciation shall be continued to 

be charged at the rate specified in Appendix-II till cumulative 

depreciation reaches 70 %. Thereafter, the remaining depreciable 

value shall be spread over the remaining life of the asset such that 

the maximum depreciation does not exceed 90 %. 

g. Depreciation shall be chargeable from the first Year of commercial 

operation. In case of commercial operation of the asset for part of 

the Year, depreciation shall be charged on pro rata basis. 

Submission of MPPKVVCL, Jabalpur as per regulation:- 

9.2 According to the norms MPPKVVCL, Jabalpur has developed a detailed 

depreciation model based on rates specified by the Hon‟ble commission in 

annexure-III of said regulation. However depreciation on assets prior to 

01.04.2010 is calculated based on the rates specified in “Terms and 

Conditions for determination of Tariff for Distribution and Retail Supply of 

Electricity Regulations, 2005.” Depreciation on fixed assets of society 

have not been taken as Audit of Annual Accounts of some of the Societies 

is pending and proper capital work plan in the area of REC societies is to be 

prepared and approved by Hon‟ble commission hence projection of Fixed 

assets cannot be made. The depreciation during the year so worked out for 

FY 10-11 to FY 12-13 is shown below: 



Table-129: Depreciation as per regulation 

( ` in Cr.) 

Particulars FY10-11 FY11-12 FY12-13 

Building 0.9 1.64 2.48 

Hydraulic Works 0.09 0.09 0.09 

Other Civil Works 0.05 0.05 0.05 

Plant & Machinery 25.37 46.49 75.01 

Line Cable Networks etc. 74 114.73 156.71 

Vehicles 0.03 0.04 0.05 

Furniture & fixtures 0 0 0 

Office Equipments 0.66 0.94 1.26 

Total 101.09 164.00 235.66 


9.3 Depreciation on Fixed assets has been worked as per the provision of the 

regulation and provided in the table below: 

Table-130: Depreciation as per additional submission 

( ` in Cr.) 

Particulars FY10-11 FY11-12 FY12-13 

Building 0.9 1.64 2.48 

Hydraulic Works 0.09 0.09 0.09 

Other Civil Works 0.05 0.05 0.05 

Plant & Machinery 25.37 46.49 75.01 

Line Cable Networks etc. 74 114.73 156.71 

Vehicles 0.03 0.04 0.05 

Furniture & fixtures 0 0 0 

Office Equipments 0.66 0.94 1.26 

Total 101.09 164.00 235.66 

9.4 The Comparison of depreciation as per the provision of regulation and after 

incorporating the additional submission is given in table below 

Table-131 Comparision of Depreciation for FY 12 

( ` in Cr.) 

Particulars 

As per norms 

As per 

additional 


Depreciation 164.00 164.00 - 

Total 164.00 164.00 - 



A10: INTEREST AND FINANCE CHARGES 

10.1 Interest on Project Loans 

Regulation 29 provides the method of calculation of interest and finance 

charges on loan capital. The relevant provision is reproduced as below:- 

29.1. The loans arrived at in the manner indicated in Regulation 19 shall be 

considered as gross normative loan for calculation of interest on loan. 

29.2. The normative loan outstanding as on 1.4.2010 shall be worked out by 

deducting the cumulative repayment as admitted by the Commission 

up to 31.3.2010 from the gross normative loan. 

29.3. The repayment for each Year of the Tariff period 2010-11 to 2012-13 

shall be deemed to be equal to the depreciation allowed for that Year. 

29.4. Notwithstanding any moratorium period availed by the Distribution 

Licensee, the repayment of loan shall be considered from the first 

Year of commercial operation of the Project and shall be equal to the 

annual depreciation allowed. 

29.5. The rate of interest shall be the weighted average rate of interest 

calculated on the basis of the actual loan portfolio at the beginning of 

each Year applicable to the Project: 

Provided that if there is no actual loan for a particular Year 

but normative loan is still outstanding, the last available weighted 

average rate of interest shall be considered. 

Provided further that if the Distribution System does not 

have actual loan, then the weighted average rate of interest of the 

Distribution Licensee as a whole shall be considered. 

29.6. The interest on loan shall be calculated on the normative average loan 

of the Year by applying the weighted average rate of interest. 



29.7. The Distribution Licensee shall make every effort to re-finance the 

loan as long as it results in net savings on interest and in that event 

the costs associated with such refinancing shall be borne by the 

consumers and the net savings shall be shared between consumers 

and Distribution Licensee in ratio 1:1. 

29.8. The changes to the terms and conditions of the loans shall be reflected 

from the date of such re-financing. 

29.9. Interest charges on security deposits with the licensee shall be 

considered at the rate specified by the Commission from time to time. 


10.1.1 The existing regulation was also applicable for previous year i.e. FY 10-11 

in which the Hon‟ble commission has issued the tariff order for FY 2011. 

The methodology adopted for calculating Interest and Finance charges on 

project loan in tariff order ,same methodology has been adopted for 

projecting the interest and finance charges on project loan as per regulation 

for FY 12 also.The details is elaborated in following table: 

Table-132: Interest and Finance Charges on project Loan as per Regulation 

( ` in Cr.) 


1. Addition to GFA during the year 602.21 1,465.00 1,649.72 

2. Consumer constribution during the year 8.60 9.00 9.40 

3. Net addition to GFA during the year (1-2) 593.61 1,456.00 1,640.32 

4. 30% of addition to net GFA considered as funded through equity(4=3*30%) 178.08 436.80 492.09 

5. Balance addition to net GFA during the year funded through debt(5=3-4) 415.52 1,019.20 1,148.22 

6. Debt Repayment due during the year (equal to the depreciation claim) 101.09 164.00 235.66 

7. Debt associated with GFA as per tariff order FY 10-11 (Rs. 398.76 crore as on 

31st March 2010 as per Tariff order FY 11 +addition in GFA funded through loan 

- debt repayment )and for subsiquent years projected as per method adopted in 

tariff order of FY 10-11 712.43 1,567.63 2,480.19 

8. Weighted average rate of interest % on all loans 0.09 0.10 0.07 

9.Total Interest on project loans(9=7*8) 67.56 162.51 179.59 

10. Finance Charges 2.00 2.50 3.00 

11. Total Interest on project loan and Finance charges 69.56 165.01 182.59 




10.1.2 MPPKVVCL submits that it has a wide portfolio of loans in order to meet 

its investment requirements in the areas of capacity augmentation of 

distribution networks, besides other investments for system improvements. 

10.1.3 Interest and Finance charges of REC societies have not been taken as the 

Audit of some of the society is pending therefore loan liability for future 

year cannot be ascertain with the available information. 

10.1.4 The details of calculations for interest and finance charges are explained 

below. The scheme wise details have been presented in the tariff formats as 

annexure. 

(a) The interest and repayment of the loans is based on the respective 

repayment schedule of the loans and the interest. 

(b) The additions of the new loans are considered in tandem with the 

investment plan to reflect the actual cash inflows for the projects. 

10.1.5 Based on the above assumptions interest and finance charges on project 

loan is as detailed below: 



Table-133: Interest and Finance Charges on project Loan as per additional submission 

( ` in Cr.) 

Particulars FY 10-11 FY 11-12 FY 12-13 

I. Interest charges on State Govt. Loans, Bonds And Advances 

Interest charges on loans from the State Government 97.22 88.57 79.91 

Interest charges on Bonds 0.69 0.02 - 

Interest charges on debentures 0.1 - - 

Total of I 98.01 88.59 79.91 

II. Interest on Long Term Loans / Credits from the 

APDRP 4.97 4.98 4.97 

PM Gramodaya Yojna 

2.26 2.26 2.26 

MNP 1.16 1.16 1.16 

NABARD 1.47 1.47 1.47 

ADB 2.67 2.67 2.67 

Market Loan 8.66 8.67 8.66 

PFC 2.2 1.76 1.33 

REC (MPSEB) 9.96 9.18 8.33 

HUDCO 14.66 13.42 12.19 

SBI Counter Guarantee Loan 2.3 8.33 15.45 

REC-JBIC 7.68 11.6 11.17 

PFC- RAPDRP 11.92 44.7 55.63 

ADB (2324) 1.91 5.96 5.03 

ADB (2347 ) 0.43 2.25 2.43 

ADB (2520) 0.71 2.27 5.65 

REC- FEEDER SEPARATION 3.27 61.39 16.37 

ADB -FEEDER SEPARATION 0 16.2 40.49 

STN 1.47 4.66 8.33 

TSP 1.03 3.53 6.71 

SCSP 1.65 5.27 9.43 

Total of II 80.38 211.73 219.73 

Total of : I + II 178.39 300.32 299.64 

Cost of raising finance and bank charges 2.00 2.50 3.00 

Less: capitalized 60.18 67.68 79.76 

Total 120.21 235.14 222.88 

10.1.6 The Comparison of Interest on project loan and Finance charges as per the 

provision of regulation and after incorporating the additional submission is 

given in table below 

Table-134 Comparision of Interest and Finance charges for FY12 

( ` in Cr.) 

Particulars 

As per norms 

As per 

additional 


Interest Charges and Finance Charges 165.01 235.13 70.12 

Total 165.01 235.13 70.12 




cost of Rs. 70.12 Cr and may kindly allow Rs. 235.13 interest on project 

loan for FY 12. 

10.2 Interest on Working Capital 


10.2.1 The interest on working capital has been calculated on the basis of 

provision of Regulations. However, consumer security deposit received 

during the period is considered instead of closing balance, for projecting the 

total working capital during the control period. The Interest on working 

capital so calculated has been shown in the table given below. The interest 

rate has been considered at 11.75% p.a. which is the PLR of SBI as on 

1.4.2010. 



Table-135: Interest on working capital-as per regulation 

( ` in Cr.) 

Sl. No. Particulars FY11 FY12 FY13 

A) 

1/6th of annual requirement of inventory for 

previous year 

17.95 19.39 21.03 

B) O&M expenses - - - 

R&M expenses 43.93 55.98 85.28 

A&G expense 73.87 71.83 76.62 

Employee expenses 448.43 614.83 651.69 

B) i) Total of O&M expenses 566.23 742.65 813.59 

B) ii) 1/12th of total 47.19 61.89 67.80 

C) Receivables - - - 

C) i) Annual Revenue from wheeling charges** - - - 

C) ii) 

Receivables equivalent to 2 months average billing 

of wheeling charges 

- - - 

D) Total Working capital 65.13 81.27 88.83 

(A), B) ii), C) ii)) - - - 

E) Rate of Interest * 0.12 0.12 0.12 

F) Interest on Working capital 7.65 9.55 10.44 

Actual expenditure as per Audited Accounts NA - - 

For Retail Sale activity 


A) 


previous year 

- - - 

B) Receivables - - - 

B) i) Annual Revenue from Tariff and charges** 3,036.99 3,494.43 3,964.34 

B) ii) Receivables equivalent to 2 months average billing 506.16 582.41 660.72 

C) Power Purchase expenses 2,745.96 2,960.60 3,431.43 

C) i) 1/12th of power purchase expenses 228.83 246.72 285.95 

D Consumer Security Deposit 57.07 63.92 71.59 

E) Total Working capital (A+B ii) - C i) - D) 220.26 271.77 303.18 

F) Rate of Interest * 11.75% 11.75% 11.75% 

G) Interest on Working capital 25.88 31.93 35.62 

Total Interest on working capital from wheeling 

activities 

7.65 9.55 10.44 

Total Interest on working capital from retail 

activities 

25.88 31.93 35.62 

Net Interest from working capital 33.53 41.48 46.06 

Additional Submission of MPPKVVCL, Jabalpur:- 

10.2.2 The interest on working capital has been calculated on the basis of 

provision of Regulations. However, consumer security deposit received 

during the period is considered instead of closing balance, for projecting the 

total working capital during the control period. The Interest on working 

capital so calculated has been shown in the table given below. The interest 

rate has been considered at 11.75% p.a. which is the PLR of SBI as on 

1.4.2010. Working capital requirement of society area has not been 



considered due to annual audit of some of the society is pending hence 

interest on working capital also not considered in following calculation. 

Due to additional submission of power purchase cost, requirement of 

working capital has changed and interest on working capital has also got 

changed, calculation on interest on working capital is enumerated below: 

Table-136: Interest on working capital-as per additional submission 

( ` in Cr.) 


A) 


previous year 

17.95 19.39 21.03 

B) O&M expenses - - - 

R&M expenses 45.02 57.14 86.51 

A&G expense 93.53 99.24 105.31 

Employee expenses 597.82 658.10 724.42 

B) i) Total of O&M expenses 736.38 814.48 916.24 

B) ii) 1/12th of total 61.36 67.87 76.35 

C) Receivables - - - 

C) i) Annual Revenue from wheeling charges** - - - 

C) ii) 

Receivables equivalent to 2 months average 

billing of wheeling charges 

- - - 

D) Total Working capital 79.31 87.26 97.38 

(A), B) ii), C) ii)) - - - 

E) Rate of Interest * 11.75% 11.75% 11.75% 

F) Interest on Working capital 9.32 10.25 11.44 

Actual expenditure as per Audited Accounts NA - - 

For Retail Sale activity 


A) 


previous year 

- - - 

B) Receivables - - - 

B) i) Annual Revenue from Tariff and charges** 3,036.99 3,494.43 3,964.34 

B) ii) 

Receivables equivalent to 2 months average 

billing 

506.16 582.41 660.72 

C) Power Purchase expenses 2,923.34 3,263.67 3,709.18 

C) i) 1/12th of power purchase expenses 243.61 271.97 309.10 

D Consumer Security Deposit 57.07 63.92 71.59 

E) Total Working capital (A+B ii) - C i) - D) 205.48 246.51 280.03 

F) Rate of Interest * 11.75% 11.75% 11.75% 

G) Interest on Working capital 24.14 28.96 32.90 

Total Interest on working capital from wheeling 

activities 

9.32 10.25 11.44 

Total Interest on working capital from retail 

activities 

24.14 28.96 32.90 

Net Interest from working capital 33.46 39.22 44.35 



10.2.3 The Comparison of Interest working capital loan as per the provision of 

regulation and after incorporating the additional submission is given in 

table below: 

Table-137 Comparision of Interest on wokring capital for FY12 ( ` in Cr.) 

Particulars 

As per norms 

As per 

additional 


Interest on wokring capital 41.48 39.22 (2.26) 

Total 41.48 39.22 (2.26) 


cost of Rs.2.26 Cr and may kindly allow Rs. 39.22 Cr. interest on working 

capital for FY12. 

10.3 Interest on consumer Security Deposit 


10.3.1 Interest on consumer security deposit has been paid according to the 

Hon‟ble commission‟s regulation for security deposit. Interest on consumer 

security deposit of society area has not been considered due to annual audit 

of some of the society is pending. Below mentioned table shows the 

projection of interest on consumer security deposit: 

Table-138: Interest on consumer security deposit as per regulation ( ` in Cr.) 


Interest on Consumer Security Deposit 31.96 35.80 40.09 


10.3.2 Security deposit has been paid as per provision of regulation only therefore 

MPPKVVCL claim as per regulation only. 

10.3.2 The Comparison of Interest on CSD as per the provision of regulation and 

after incorporating the additional submission is given in table below: 

Table-139 Comparision of Interest on CSD for FY12 

( ` in Cr.) 

Particulars 

As per norms 

As per 

additional 


Interest on consumer security deposit 35.80 35.80 - 

Total 35.80 35.80 - 



A11: OTHER COSTS 

11.1 Other Income 

11.1.1 Provision of Regulation 

As per regulation 38 provision of other income are: 

38.1 A schedule for other income as provided in the schedule of 

Miscellaneous Charges and General Charges under MPERC (Details 

to be furnished by licensees for determination of Tariff and manner of 

making an application) Regulation 2004 as amended from time to 

time shall be classified under „Other Income‟. 

38.2 Revenue from other business shall be treated as income to the extent 

authorized by the Commission under Section 41 of the Act. 

39.1 Surcharge as may be prescribed will be payable if the bills are not 

paid up to due date. The part of a month will be reckoned as full 

month for the purpose of calculation of delayed payment surcharge. 

The delayed payment surcharge will not be levied for the period after 

supply to the consumer is permanently disconnected. 

39.2 The delayed payment surcharge shall not be considered as income for 

purpose of determination of gap between annual revenue requirement 

and tariff & other income. 


11.1.2 The main components of Non-Tariff Income are sale of surplus contracted 

power, meter rent and miscellaneous charges from consumers. Meter rent 

and miscellaneous charges have been projected as percentage of tariff 

income. Other income of society area has not been considered due to annual 

audit of some of the society is pending. 



Table-140: Other income 

( ` in Cr.) 


Income from Investment, Fixed & Call Deposits 

Interest Income from Investments 5.81 8.15 11.27 

Interest from Banks other than Fixed Deposits 1.31 1.31 1.31 

Interest on (any other items) 

Sub-Total 7.12 9.46 12.58 

Interest on loans and Advances to staff 1.51 2.54 3.58 

Interest on Advances to Suppliers / Contractors - - - 

Income/Fee/Collection against staff welfare activities 

0.02 0.02 0.02 

Miscellaneous receipts 17.45 19.98 22.86 

Meter Rent - - - 

Recovery from theft of energy - - - 

Surcharge and Additional Surcharge - - - 

Incentive due to Securitisation of CPSU Dues - - - 

Misc. charges from consumers 

Delayed payment surcharge from Retail Sale 

consumers 

Any other subsidies / grants other than those u/s 65 

- - - 

Deferred Income (Consumer Contribution) - - - 

Sub-Total 18.99 22.55 26.46 

Total (A+B) 26.11 32.01 39.04 


11.1.3 MPPKVVCL claim other income as per provision of regulation only 

therefore there is no additional submission. 

11.1.4 The Comparison of other income as per the provision of regulation and 


Table-141 Comparision of Other income for FY 12 

( ` in Cr.) 

Particulars 

As per norms 

As per 

additional 


Other income 32.01 32.01 - 

Total 32.01 32.01 - 



11.2 Return on Equity 


28.1. Return on equity shall be computed in rupee terms, on the paid up 

equity capital Determined in accordance with Regulation 19. 

28.2. Return on equity shall be computed on pre-tax basis at the rate of 

16%.Any expenses on payment of Income Tax shall be allowed extra 

on actual basis on the licensed business of Distribution licensee. 

28.3. The premium raised by the licensee while issuing share capital and 

investment of internal resources created out of free reserve, if any, 

shall also be reckoned as paid up capital for the purpose of 

computing return on equity, provided such premium amount and 

internal resources are actually utilised for meeting capital expenditure 

and forms part of the approved financial package. For the purposes of 

calculation of computation of return, the portion of free reserves 

utilized for meeting the capital expenditure shall be considered from 

the date the asset created is productively deployed in the distribution 

business. 


11.2.2 According to the Para 28 of regulation, MPPKVVCL is entitled to Return 

on Equity @ 16% p.a .Return on equity of society area has not been 

considered due to annual audit of some of the society is pending and proper 

capital plan in society area is to be prepared by the company and approved 

by the Hon‟ble commission hence projection of Fixed assets can not be 

made. Based on the provision of regulation the calculation of return on 

equity is as follows: 



Table-142: Return on equity 

( ` in Cr.) 

Sl.No. Particulars FY 10-11 FY 11-12 FY 12-13 

A 

Gross Fixed Assets at the beginning of year 

(net of consumer contributions) 

1,585.04 2,083.64 3,193.48 

A1 

Opening balance of GFA identified as funded 

through equity 

475.51 625.09 958.04 

A2 

Opening balance of GFA identified as funded 

through debt 

1,109.53 1,458.55 2,235.43 

B 

Proposed capitalisation of assets as per the 

investment plan (net of consumer 

593.61 1,456.00 1,640.32 

contribution) 

B1 

Proportion of caplitalised assets funded out of 

equity, internal reserves 

24.81 117.23 89.45 

B2 

Balance Proportion of capitalised assets funded 

out of project loans (B - B1) 

568.80 1,317.56 1,299.02 

C1 Normative additional equity (30% of B) 178.08 436.80 492.09 

C2 Normative additional debt (70% of B) 415.52 1,019.20 1,148.22 

D1 

Excess / shortfall of additional equity over 

normative (B1-C1) 

(153.27) (319.57) (402.64) 

D2 

Excess / shortfall of additional debt over 

normative (B2-C2) 

153.27 298.36 150.79 

E 

Equity eligible for Return (A1+(C1/2)) OR 

(A1+(B1/2)), whichever is lower 

487.92 683.71 1,002.77 

Return on Equity (16% on E) 78.07 109.39 160.44 


11.2.3 Return on equity has been calculated based on provision of regulation therefore 

there is no additional submission on return on equity. 

11.2.4 The Comparison of Return on Equity as per the provision of regulation and 


Table-143: Comparision of Return on Equity for FY 12 

( ` in Cr.) 

Particulars 

As per norms 

As per 

additional 


Return on equity 109.39 109.39 - 

Total 109.39 109.39 - 



11.3 Bad and Doubtful Debts 


33.1.Bad and Doubtful Debts shall be allowed to the extent of the 

Distribution Licensee has actually written off bad debts subject to a 

maximum limit of 1% of the yearly revenue. 


11.3.2 Bad and doubtful debts have been projected on the basis of 1% of the 

revenue of the control period; following table shows the basis of year wise 

amount: 

Table-144: Bad Debts 

( ` in Cr.) 


Bad and Doubtful Debts 30.37 34.94 39.64 

Additional submission of MPPKVVCL, Jabalpur 

11.3.3 Bad and doubtful debts has been claimed as per regulation only therefore, 

no additional submission under bad and doubtful debts. 

11.3.4 The Comparison of Return on Equity as per the provision of regulation and 


Table-145 Comparision of Bad and doutful debts for FY 12 ( ` in Cr.) 

Particulars 

As per norms 

As per 

additional 


Bad and doutful debts 34.94 34.94 - 

Total 34.94 34.94 - 



11.4 Other Expenses 


11.4.1 Other expenses include sundry expenses and extraordinary items. These 

expenses are necessarily incurred by MPPKVVCL. Other expenses of 

society area have not been considered as the annual account of some of the 

society is pending. Therefore projection of other expense cannot be made. 

Projection of other expenses is based on the past trend, however regulation 

is not provided and rule for the other expenses .Following is the detail of 

other expenses: 

Table-146: Other expenses 

( ` in Cr.) 


Other Debits, Write-offs and extraordinary items(net) 17.73 20.72 24.1 

11.4.2 The Comparison of other expenses as per the provision of regulation and 


Table-147 Comparision of Other expenses for FY 12 

( ` in Cr.) 

Particulars 

As per norms 

As per 

additional Variation 

Submission 

Other expenses 0 20.71 (20.71) 

Total - 20.71 (20.71) 


cost of Rs. 20.71 Cr and may kindly allow Rs 20.71 other expenses for 

FY12. 



A12: TRUE-UP COST OF PREVIOUS YEAR 

The Company has started functioning independently w.e.f. 1 st June‟2005. 

Although the Tariff petition for the year 2005-06 was filed by MPSEB and 

the tariff was issued by the Commission on 29 th June-2005, but the said 

tariff order was made applicable to the all the distribution licensees and 

accordingly the True-up petition for the distribution licensees was finalized 

for FY-06. This was the first true-up exercise of the MPERC for the 

Distribution licensees of the state. Thereafter, MPERC has regularly 

determined the true-ups for respective year. The year wise true-up cost and 

its Gap is summarised as below:- 

12.1 TRUE-UP for FY06: 

As discussed earlier, on the directives of Hon‟ble Commission 

MPPKVVCL had submitted the petition no. 58/07 before the Commission 

for True-up of financial profit or loss for the period June‟05 to March‟06. 

Any truing up exercise is directly related with the estimation provided in 

the tariff order. Company wise estimation had not been provided in the 

tariff order for FY06, but while deciding the true-up order dated 16-1-08, 

MPERC has shown a profit of Rs. 85 Cr to MPPKVVCL, Jabalpur against 

the loss of 403.23 Cr. This profit had been passed on to the consumers 

during the determination of Tariff for FY09 and thus has reduced the ARR 

for FY09. 

Apart from other expenses, the Hon‟ble Commission had 

disallowed the power purchase cost to the tune of Rs. 124.41 Cr. The 

Company filed a petition no. 29/08 for review of MPERC order dated 16-1- 

2008. In the mean time MPERC had registered a Suo-moto petition no. 

28/08 regarding procurement of short term power during the year 2005-06, 

2006-07 and 2007-08. Hon‟ble Commission had decided the review 

petitions no. 29/08 vide its order dated 31-1-2009 and had allowed only Rs 

6.39 Cr. from balance cost of Rs 124.41 Cr. for the year 05-06 and 

remaining cost of Rs. 118.02 Cr. was not considered. The allowed Cost of 



Rs. 6.39 Cr was passed on to the consumers during the determination of 

Tariff for FY 2009-10. 

Aggrieved by the Hon‟ble Commission order, the three distribution 

licensees of the state along with MP Tradeco had filed an appeal no. 

36/2010 before the Hon‟ble Appellate Tribunal for Electricity, New Delhi 

(hereinafter Hon‟ble Tribunal). The Hon‟ble Tribunal had decided the 

appeal in the favour of Distribution licensees vide its order dated 2-8-10. 

The Hon‟ble commission has registered a suo-moto petition no. 66 of 2010 

for deciding the power purchase cost for the year 2005-06 in compliance to 

the Hon‟ble Tribunal‟s Judgement. The matter is still under consideration to 

MPERC. 

In this context it is submitted that the expenses allowed by the 

Hon‟ble Tribunal shall be claimed only after the decision of the suo-moto 

petition no. 66 of 2010 of the Commission. 


On the directives of Hon‟ble Commission, MPPKVVCL had 

submitted the petition no. 22/08 before the Commission for True-up of 

ARR for the period 1 st April‟07to 31 st March‟07. The Hon‟ble Commission 

while deciding the true-up order dated 16-6-09 had shown a profit of Rs. 

128.86 Cr. to MPPKVVCL against the loss of Rs 440.90 Cr. This profit had 

been passed on to the consumers during the determination of Tariff for 

FY2009-10 and has reduced the ARR for FY 10. 

Apart from other expenses, the Hon‟ble Commission had 

disallowed the power purchase cost to the tune of Rs. 332.72 Cr. Aggrieved 

by the Hon‟ble Commission‟s order; all the three distribution companies of 

the state had filed appeal no. 145/2009 before the Hon‟ble Appellate 

Tribunal for electricity, New Delhi. The Hon‟ble Tribunal has decided the 

appeal in favour of the Distribution licensees vide its order dated 19-5-10, 

and has allowed the power purchase cost only. The Hon‟ble Commission 

had filed an appeal for review of Tribunal‟s order dtd. 19/05/2010 before 

the Hon‟ble Appellate Tribunal, New Delhi. 



In this context it is submitted that the expenses allowed by the 

Hon‟ble Tribunal shall be claimed only after the decision of the review 

appeal of the Commission. 


On the directives of Hon‟ble Commission, MPPKVVCL, Jabalpur 

had submitted the petition no. 59/09 before the Commission for True-up of 

ARR for the period 1 st April‟07 to 31 st March‟08. The Hon‟ble Commission 

while deciding the true-up petition and passed the order dated 13/04/10 had 

shown loss of only Rs. 171.79 Cr to MPPKVVCL, Jabalpur against the loss 

of Rs 921.51 Cr. This loss had been passed on to the consumers during the 

determination of Tariff for FY-11. 

Aggrieved by the Hon‟ble Commission‟s order, the three 

distribution companies of the state had filed appeal no. 150/2010 before the 

Hon‟ble Appellate Tribunal for electricity New Delhi and this appeal is yet 

to be decided. In this context it is submitted that the expenses allowed, if 

any by the Hon‟ble Tribunal shall be claimed only after the decision of the 

appeal. 


On the directives of Hon‟ble Commission, MPPKVVCL, Jabalpur 

had submitted the petition before the Commission for True-up of ARR for 

the period April‟08 to March‟09. This petition is yet to be decided by 

MPERC. In this context it is submitted that the expenses allowed, if any by 

the Commission shall be claimed only after the decision of the true –up 

petition. 


MPPKVVCL will submit the petition for True-up of ARR for the 

period 1 st April‟09 to 31 st March‟10 by end of this month. Therefore, 

company has not claimed any true-up cost for the financial year 2009-10 in 

this petition. 



A13: AGGREGATE REVENUE REQUIREMENT 

13.1 Summary of Aggregate revenue requirement calculated on the basis of 

provision of regulation for MPPKVVCL is tabulated below: 

Table-145: Summary of ARR as per the Regulation 

( ` in Cr.) 


Revenue 

Revenue from sale of power (Inclusive of tariff subsidy) 3,036.99 3494.43 3,964.34 

Other income (excluding DPS) 26.11 32.01 39.04 

Total Revenue or Income 3,063.10 3526.44 4,003.39 

Expenditure 

Purchase of Power 2,493.68 2694.12 3,164.73 

Inter-State Transmission charges 250.24 264.23 264.23 

SLDC Charges 2.04 2.24 2.47 

Repairs and Maintenance 43.93 55.98 85.28 

Employee costs 448.43 614.83 651.69 

Administration and General expenses 73.87 71.83 76.62 

other expenses - 0.00 - 

Bad and Doubtfuls Debts 30.37 34.94 39.64 

Less :Expenses Capitalised - 0.00 - 

Total 3,342.56 3738.19 4,284.66 

PBDIT -279.47 -211.75 -281.27 

Depreciation and Related debits 101.09 164.00 235.66 

PBIT -380.56 -375.75 -516.93 

Interest & Finance Charges 135.06 242.29 268.74 

Profit/Loss before Tax and ROE -515.62 -618.04 -785.67 

Tax - 0.00 - 

Profit/Loss after Tax (Before RoE) -515.62 -618.04 -785.67 

RoE 78.07 109.39 160.44 

Profit/Loss after Tax (After RoE) -593.68 -727.43 -946.12 

Terminal Benfit Cost from FY 2005-06 to FY 2010-11 - 657.05 - 

Profit/Loss after Tax after ROE and after Terminal 

Benefit of previous years 

-593.68 -1,384.48 -946.12 

ARR (Income from Sale of power+Gap) 3,656.78 4,910.92 4,949.50 



13.2 Summary of Aggregate revenue requirement calculated after incorporating 

the additional submission for MPPKVVCL is tabulated below: 

Table-146: Summary of ARR as per additional submission 

( ` in Cr.) 


Revenue 

Revenue from sale of power (Inclusive of tariff subsidy) 3,036.99 3494.43 3,964.34 

Other income (excluding DPS) 26.11 32.01 39.04 

Total Revenue or Income 3,063.10 3526.44 4,003.39 

Expenditure 

Purchase of Power 2,671.06 2891.19 3,336.47 

Inter-State Transmission charges 250.24 370.24 370.24 

SLDC Charges 2.04 2.24 2.47 




other expenses 17.73 20.71 24.10 

Bad and Doubtfuls Debts 30.37 34.94 39.64 

Less :Expenses Capitalised 14.24 15.30 16.77 

Total 3,707.81 4133.81 4,689.17 

PBDIT -644.71 -607.37 -685.78 

Depreciation and Related debits 101.09 164.00 235.66 

PBIT -745.81 -771.37 -921.44 


Profit/Loss before Tax and ROE -931.45 -1081.51 -1,228.75 

Tax - 0.00 - 

Profit/Loss after Tax (Before RoE) -931.45 -1081.51 -1,228.75 

RoE 78.07 109.39 160.44 

Profit/Loss after Tax (After RoE) -1,009.51 -1,190.90 -1,389.19 

Terminal Benfit Cost from FY 2005-06 to FY 2010-11 - 657.05 - 



-1,009.51 -1,847.95 -1,389.19 

ARR (Income from Sale of power+Gap) 4,072.61 5,374.39 5,392.58 



13.3 The Comparison of ARR for FY12 calculated on the basis of provision of 

regulation and calculated after incorporating the additional submission is 

tabulated as below:- 

Table-147: Comparision of ARR - Summary for FY12 

Particulars 

As per 

Regulation 

As per 

Additional 

Submission 

( ` in Cr.) 

Deviation 

Revenue 

Revenue from sale of power (Inclusive of tariff subsidy) 3,494.43 3494.43 - 

Other income (excluding DPS) 32.01 32.01 - 

Total Revenue or Income 3,526.44 3526.44 - 

Expenditure 

Purchase of Power 2,694.12 2891.19 197.06 

Intra-State Transmission charges 264.23 370.24 106.01 

SLDC Charges 2.24 2.24 - 




Other expenses - 20.71 20.71 

Bad and Doubtfuls Debts 34.94 34.94 - 

Less: Expenses Capitalised - 15.30 15.30 

Total 3,738.19 4133.81 395.62 

PBDIT -211.75 -607.37 -395.62 

Depreciation and Related debits 164.00 164.00 - 

PBIT -375.75 -771.37 -395.62 


Profit/Loss before Tax and RoE -618.04 -1081.51 -463.47 

Tax - 0.00 - 

Profit/Loss after Tax (Before RoE) -618.04 -1081.51 -463.47 

RoE 109.39 109.39 - 

Profit/Loss after Tax (After RoE) -727.43 -1,190.90 -463.47 

Terminal Benfit Cost from FY 2005-06 to FY 2010-11 657.05 657.05 - 



-1,384.48 -1,847.95 -463.47 

0 0 0 

ARR (Income from Sale of power+Gap) 4,910.92 5,374.39 463.47 



A14: OTHER ITEMS 

14.1 Energy requirement 

The licensee has to meet the power demand of the consumers, as per 

the relevant provisions of the Electricity Act, 2003 under the obligation to 

supply. Therefore, quantum of power purchase may not be restricted on the 

basis of normative loss levels. Under any given operating conditions of the 

power system, the quantum of energy and the power demand are more or 

less uncontrollable variables and the loss level is an indeterminate quantity. 

In fact, normative loss level and hence the normative quantum of power 

purchase are quantities which are based on a hypothetical system model 

with “frozen” conditions of these variables – e.g. input, output, loss. The 

power and energy demand vary from instant to instant and it is not possible 

to predict the loss level for any particular instant. For meeting the peak 

system demand and estimated losses to the extent possible, scheduling of 

additional generation is required. Monthly load duration curve may be 

referred while implementing merit order dispatch. The principle of deciding 

a “normative” quantum of power based on a normative loss level is neither 

logical nor reasonable for the licensee and for the consumers. The principle 

of “normative” power requirement is not feasible to be followed in practice 

and it would results in indiscriminate load shedding/curtailment of power to 

the consumers. 

It is therefore prayed that the quantum of power purchase may 

please be considered for meeting demand to the extent possible on the basis 

supply hours plan as mentioned in the previous paras. 



14.2 Fuel Surcharge Adjustment 

14.2.1 At present there is no mechanism for automatic pass-through of the 

enhanced costs to the licensee due to unforeseen circumstances beyond the 

control of the licensee. Thus even though generating and transmission 

utilities pass their uncontrollable costs, the licensee is not able to pass on 

the same to its consumers. This is basically the power purchase cost which 

represents the most substantial part of Distribution Licensee's revenue 

requirement. Any material change in hydro-thermal mix, generation source 

mix, fuel cost etc have a significant impact on the power purchase cost for 

the Distribution Licensee. Given the extent of the costs involved, it is 

crucial that a mechanism should be formulated whereby the distribution 

Licensee is able to regularly recover allowable changes in the power 

purchase cost, on account of variation in fuel costs, from consumers. Such a 

mechanism would enable the Distribution Licensee to manage its functions 

in a more effective manner. This is also in line with the provisions of 

Clause 5.3 (h) (4) of the National Tariff Policy which reads that 

"Uncontrollable costs should be recovered speedily to ensure that future 

consumers are not burdened with past costs. Uncontrollable costs would 

include (but not limited to) fuel costs, costs on account of inflation, taxes 

and cess, variations in power purchase unit costs including on account of 

hydro-thermal mix in case of adverse natural events ". 

14.2.2 In line with the above provision, the Distribution Licensee submits the 

following formula for computation of Fuel Surcharge Adjustment: 

(a) FSA (Rs Cr.) = P + I + A, where FSA = Fuel Surcharge Adjustment 

(b) P = Change in cost of generation and power purchase due to variation 

in the landed fuel cost and due to approved short term power purchase. 

(c) I = Interest on working capital on account of change in fuel cost on 

account of factor 'P' above 

(d) A = Adjustment factor for over-recovery / under-recovery which shall 

be computed in accordance with the formula given below: 



(e) AJ-2 (Rs. Cr.) = XJ-4 + YJ-2 

where: 

(i) XJ-4 : Incremental cost in month "J-4" 

(ii) YJ-2 : Incremental cost in month "J-4" actually recovered in 

month "J-2" 

(f) 

The calculation for FSA to be charged for the month "J" shall be as 

follows: 

FSAJ (Rs Cr.) = PJ-2 + I J-2 + AJ-2 

14.2.3 The FSA would be applicable from the month following the month in 

which the additional costs are calculated. (This means that the FSA for 

month of June would be recovered in August.) 

14.2.4 The Licensee proposes that the FSA shall be recoverable from both metered 

as well as unmetered consumer categories as indicated in the formula 

below: 

FSA Rs./kWh = 

(FSA / (Metered sales + un-metered consumption estimates)) * 10 

14.2.5 The consumption for unmetered category consumers would be estimated 

based on methodology and norms adopted for the same for developing sales 

forecast for such categories. 

14.2.6 The need for adjustment factor 'A' as mentioned in the above formula 

would be clear with help of an example: 

14.2.7 Consider that a Distribution Licensee has incurred a higher power purchase 

cost, of say Rs 10 Cr. for month of April on account of higher fuel prices. 

The licensee would have been served with corresponding power purchase 

bill by supplier/generator in month of May and it is assumed that the entire 

cost is allowed by the Commission to be recovered through FSA. If the 

anticipated sale during the month of June is 500MU, then the FSA per unit 



to be recovered would be 20 paise/kWh. Now if the actual sale for June is 

450 MU, then there would be an under-recovery to the extent of Rs 1 Cr.. 

Conversely, if the actual sale for June is 550MU, then there would be an 

over-recovery of Rs 1 Cr. Therefore, there is a need for the FSA formula to 

provide for regular adjustments on account of such over recovery/under 

recovery. 



14.3 Expensive Power Charges 

14.3.1 All Power purchases are undertaken by the licensee through the MP 

Tradeco. The MP Tradeco arranges the power for three Distribution 

licensees of the state viz. Poorv Kshetra, Paschim Kshetra & Madhya 

Kshetra Vidyut Vitaran companies. Also, apart from entering into contract 

for purchase of power from various sources, MP Tradeco has also entered 

into arrangement of banking of power under which the power is sold in 

kind and is returned in kind at a later date or vice-versa. The licensee 

generally avoids the load shedding of HT consumers and LT consumers of 

Commissionary and Distt. HQ. Therefore, in case of unforeseen shortage of 

power, the licensee is compelled to manage the power supply to these 

categories of consumers by arranging expensive power. Moreover, vide 

Para 40.1(j) of the instant MYT regulation, the Hon‟ble Commission has 

provided that it may consider to prescribe additional charges on account of 

procurement of costly power. In effect, through this regulation, the Hon‟ble 

Commission has contemplated a distinction between the cost of long-term 

power and short-term power (i.e. expensive power) from the point of view 

of tariff determination. Therefore, licensee proposes that the additional cost 

of expensive power is allowed to be recovered from HT consumer and LT 

consumer of Commissionary/Distt. HQ. Since the LT loss level of different 

area is different, therefore it will be appropriate to recover the cost of 

expensive power from LT consumers of Distt. H.Q. in proportion to their 

requirement in the following manner. 

Formula 

Net energy requirement 

R1 MU with cost C1 

Availability from identified sources 

R2 MU with cost C2 

Difference 

(R2-R1) MU 

Partially/fully power arranged from short term R3 MU with cost C3 i.e. (R3/(H1+L1) percentage of 

sources (For supplying power to HT consumer and total requirement) 

LT consumer of CHQ and DHQ) 

Power requirement to HT Consumer H1 (Incorporating 1.5% distribution loss, 4.9% 

Transmission losses, and 2% external losses) 

Power requirement to LT Consumer of CHQ/DHQ L1 (Incorporating actual distribution loss of the area, 

4.9% Transmission losses, and 2% external losses) 

Expensive power arranged to HT consumer H1 x (R3 / (H1+L1) %) 



Expensive power arranged to LT consumer of H1 x (R3 / (H1+L1) %) 

CHQ/DHQ 

Difference of Expensive Power Cost per unit (D1) = (C3/R3) – (C1/R1) 

Qty in MU Total Cost Expensive power charges 

HT Consumer H1x(R3/(H1+L1)%) H1x(R3/(H1+L1)%)xD1 {H1x(R3/(H1+L1)%)xD1}/HT Sale 

LT Consumer L1x(R3/(H1+L1)%) L1x(R3/(H1+L1)%)xD1 {L1x(R3/(H1+L1)%)xD1}/LT Sale 

Example 

Consider that the commission has allowed the requirement of 275 MU with an 

average power purchase cost @ 2.00 Rs. Per unit for the month of April. In case of 

shortage in availability, Distribution Licensee has arranged expensive power purchase 

of 20 MU from short term sources at average rate Rs. 6.24 per unit to meet out the 

requirement of HT consumer and LT consumer of CHQ and DHQ. The licensee 

would have been served with corresponding power purchase bill by 

supplier/generator in month of May and it is assumed that the entire cost is allowed 

by the Commission to be recovered through EPC. If the sale during the month of 

April for HT consumer was 100 MU and LT consumer of CHQ and DHQ was 45 

MU, then the EPC per unit to be recovered would be calculated as under:- 

Power requirement for HT Consumer [{100/(1-1.5%)}/(1-4.9%)]/(1-2%) 

= 108.55 MU 

Power requirement for LT Consumer of CHQ/DHQ say 35.5% [{45/(1-35.5%)}/(1-4.9%)]/(1-2%) 

Distribution loss 

= 75 MU 

Total power requirement for HT and LT consumers of = 108.55+75 = 183.55 MU 

DHQ/CHQ 

Percentage of Expensive power purchase in the month (20/183.55) % = 11% 

Expensive power arrange to HT consumer 

Expensive power arrange to LT consumer of DHQ/CHQ 

Additional cost towards expensive power to HT consumers 

Per unit Expensive charges to be recovered from HT 

consumer in the monthly bill of June 

Additional cost towards expensive power to LT consumers 

of CHQ/DHQ 

Per unit Expensive charges to be recovered from LT 

consumer of CHQ/DHQ in the monthly bill of June 

= 108.55X11% = 11.94 MU 

= 75X11% = 8.06 MU 

= 11.94X (6.24-2.00) = 5.06 Cr. 

= 5.06/100 = Rs. 0.51 per unit 

= 8.06X(6.24-2.00) = 3.42 Cr. 

= 3.42/45 = Rs. 0.76 per unit 



A15:TARIFF PROPOSAL FOR FY-12 

15.1 The Hon‟ble Commission has issued the tariff order for FY 2006-07 on 31 st 

March‟2006, tariff order for FY 2007-08 on 30 th March‟07, tariff order for 

FY 2008-09 on 29 th March‟2008, tariff order for FY 2009-10 on 29 th July‟ 

2009 and tariff order for FY 2010-11 on 18 th May‟2010. The Gist of the 

Tariff Hike for MPPKVVCL is as under:- 

SN Particular 2006-07 2007-08 2008-09 2009-10 2010-11 

1 Approved Sales (MU) 6017 6598 7370 6915 7232 

2 

Revenue at Existing Tariff (Rs. In 

Crores) 

2107.82 2413.38 2706.1 2568.37 2798.30 

3 Revenue at Revised Tariff (Rs. In Crores) 2179.87 2419.35 2779.53 2649.21 3100.00 

4 

Additional Revenue on account of 

revision of Tariff (Rs. In Crores) 

72.05 5.97 73.43 80.84 301.70 

5 % Tariff Hike (overall basis) 3.42% 0.25% 2.71% 3.16% 10.78% 

6 

Average Revised per unit Tariff (Rs.) 

(Revenue at revised tariff / Approved 

Sale) 

3.62 3.67 3.77 3.83 4.29 

15.2 The annualized variation (Base year 2004-05) in the wholesale price index 

of India for FY 2005-06 was 4.38%, for FY 2006-07 was 6.51%, for FY 

2007-08 was 4.81% , for FY 2008-09 was 8.03%, for FY 2009-10 it was 

3.57% and for the year 2010-11 till October it is 8.61%. It is quite apparent 

from the figures indicated that, the Tariff hikes during these years except 

previous financial year i.e. FY 2010-11 were not at all commensurate with 

the rise in wholesale price index, which has severely affected the financial 

health of the licensee. The Distribution licensees are unable to sustain the 

multiple onslaughts of intrinsic rise in expenditure due to inflationary 

pressures, relentless and consistent rise in power and energy demands, 

rather unrealistic normative constraints imposed by MPERC, rapidly falling 

credit rating in the market, obligations to be met under the policy objectives 

of the State and Central governments. Therefore, it has now become 

expedient for the licensee to seek an appropriate hike in the tariff - i.e., to 

the level as proposed and detailed in the instant petition. It would not be 

possible for the licensee either to maintain its operational viability or, to 

operate efficiently, at the least, without the enhancement in the retail tariff 



sought through this petition. 

15.3 In view of the facts outlined, the MPPKVVCL has proposed a tariff hike 

which translates in monetary terms to Rs. 1,093.62 Cr. The ARR for the 

financial year 2011-12 is Rs. 5,374.39 Cr. and revenue at existing Tariff 

(Tariff income) works out to Rs. 3,494.43 Cr. and Non-tariff Income 

works out to Rs. 32.01 Cr. resulting into the Gap of Rs. 1,847.95 Cr. It is 

to mention here that this Gap does not include the True-up Costs for the 

previous years. The average Cost of Supply for FY12 will be Rs. 6.41 per 

unit. Considering the Non-tariff Income the average tariff of Rs. 6.37 per 

unit is required to meet out the gap. However, MPPKVVCL has proposed 

the average tariff of Rs. 5.47 per unit to fulfill the partial gap. On account 

of the proposed tariff, the additional revenue of Rs. 1,093.62 Cr. would be 

generated and fulfill the partial gap. The un-recovered amount of Rs. 

754.33 Cr. is proposed to be treated as “Regulatory Asset” and proposed to 

be amortized over a period of 3-years starting from FY-13. The Licensee 

has not sought funding cost for the un-recovered gap which it proposes to 

do at the time of truing up. 

15.4 The schedule of the proposed Retail Tariff for FY 2011-12 is enclosed with 

this petition. The National tariff Policy requires that by the end of FY 

2010-11, the tariff for all consumers should be within +/- 20% of the 

average cost of supply. The average Cost of supply for the financial year 

2011-12 for MPPKVVCL will be Rs. 6.41 per unit. The MPPKVVCL, 

Jabalpur in this petition, proposes the average tariff of Rs. 5.47 Per unit to 

fulfill the deficit. While designing the tariff, the licensee has made efforts 

to maintain the Cross subsidy within limits and reduces the same as 

compared to the previous year. 

15.5 The tariff proposals for FY12 are annexed. The impact on revenue due to 

proposed tariff is given in the table below: 



Tariff Category 

Sale 

Revenue at 

Existing 

Tariff 

Revenue 

at 

Proposed 

Tariff 

Additional 

Revenue at 

proposed 

tariff 

MU Rs Cr Rs Cr Rs Cr 

LV 1 Domestic 2822.66 1061.39 1427.99 366.59 

LV 2 Non-Domestic 407.52 236.59 276.36 39.77 

LV 3.1 WW & Street Light 243.74 94.03 141.12 47.09 

LV 4 LT Industrial 238.94 115.04 143.33 28.30 

LV 5.1 Agriculture Irrigation Pumps 1898.81 598.52 883.34 284.82 

LV 5.2 Agriculture related Use 2.22 0.92 1.33 0.41 

Total (LT) 5613.89 2106.50 2873.48 766.98 

HV 1 Railway Traction 529.25 278.55 347.57 69.01 

HV 2 Coal Mines 514.15 276.01 326.89 50.88 

HV 3.1 Industrial 1107.84 548.55 682.82 134.27 

HV 3.2 Non-Industrial 173.55 101.83 122.31 20.48 

HV 4 Seasonal 4.65 2.48 2.95 0.47 

HV 5.1 Public Water Works 61.14 25.78 31.48 5.70 

HV 5.2 Other Agricultural 10.49 4.48 5.46 0.98 

HV 6 Bulk Residential Users 370.53 150.25 195.09 44.85 

HV 7 Bulk Supply to Exemptees 

Total (HT) 2771.59 1387.93 1714.58 326.65 

TOTAL LT+HT 8385.49 3494.43 4588.05 1093.62 

15.6 The comparison of average rate per unit for different categories of 

consumer with percentage from overall average tariff for the financial year 

2010-11 as per tariff order and for the year financial 2011-12 as per 

proposed tariff is as under: 


ARPU at 

Exiting 

Tariff 

ARPU at 

Proposed 

Tariff 

% Hike in 

ARPU 

Proposed 

ARPU as a 

% of Acos 

Proposed 

ARPU as 

a % of 

Average 

Tariff 

Rs/ Unit Rs/ Unit (%) (%) (%) 

LV 1 Domestic 3.76 5.06 34.54% 79% 92% 

LV 2 Non-Domestic 5.81 6.78 16.81% 106% 124% 

LV 3.1 WW & Street Light 3.86 5.79 50.07% 91% 106% 

LV 4 LT Industrial 4.81 6.00 24.60% 94% 110% 

LV 5.1 Agriculture Irrigation Pumps 3.15 4.65 47.59% 73% 85% 

LV 5.2 Agriculture related Use 4.15 6.01 44.70% 94% 110% 

Total (LT) 3.75 5.12 36.41% 80% 94% 

HV 1 Railway Traction 5.26 6.57 24.78% 103% 120% 

HV 2 Coal Mines 5.37 6.36 18.43% 100% 116% 

HV 3.1 Industrial 4.95 6.16 24.48% 97% 113% 

HV 3.2 Non-Industrial 5.87 7.05 20.12% 111% 129% 

HV 4 Seasonal 5.33 6.34 18.85% 100% 116% 

HV 5.1 Public Water Works 4.22 5.15 22.11% 81% 94% 

HV 5.2 Other Agricultural 4.27 5.21 21.90% 82% 95% 

HV 6 Bulk Residential Users 4.05 5.27 29.85% 83% 96% 

HV 7 

Bulk Supply to Exemptees 

Total (HT) 5.01 6.19 23.53% 97% 113% 

TOTAL LT+HT 4.17 5.47 31.30% 86% 100% 



15.7 It could be seen from the above table that the licensee has tried to reduce 

the cross subsidy for the cross subsidizing categories of the consumers as 

compared to previous year. 

15.8 Consumer Category wise comparison of the existing and proposed tariff is 

given in the table below: 




LOW TENSION - LV 1: DOMESTIC 

EXISTING TARIFFS 

PROPOSED TARIFF 

FY 11 FY 12 

Energy Minimum Charges per month Fixed Charge per month Energy Minimum Charges per month Fixed Charge per month 

Type of 

Charge 

Charge 

installation 

(Rs/KWh) 

(Rs/KWh) 

Urban Rural Criteria Urban Rural Criteria Urban Rural Criteria Urban Rural Criteria 

Rs. Rs. Rs. Rs. 

Metered 

1.1 Consumption upto 30 unit per month 

Upto 30 units 2.85 35.00 35.00 Rs. Per 0.00 0.00 0.00 4.00 50.00 50.00 Rs. Per 0.00 0.00 

Connection 

Connection 

1.2 Consumption more than 30 unit per month 

(With Telescopic Unit) 

Upto 50 units 3.15 50.00 50.00 Rs. Per 20.00 10.00 Rs. Per Connection 4.50 70.00 50.00 Rs. Per 30.00 21.00 Rs. Per Connection 

Connection 

Connection 

51 to 100 units 3.60 50.00 50.00 Rs. Per 40.00 20.00 Rs. Per Connection 5.00 70.00 50.00 Rs. Per 50.00 35.00 Rs. Per Connection 

Connection 

Connection 

101 to 200 units 4.35 50.00 50.00 Rs. Per 

Connection 

55.00 35.00 Rs. for each 0.5 kW 

of authorised Load 

5.25 70.00 50.00 Rs. Per 

Connection 

75.00 53.00 Rs. for each 0.5 kW 


Above 200 units 4.50 50.00 50.00 Rs. Per 

Connection 

60.00 50.00 Rs. for each 0.5 kW 


5.50 70.00 50.00 Rs. Per 

Connection 

100.00 70.00 Rs. for each 0.5 kW 


Demand Based 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.00 0.00 0.00 0.00 40.00 28.00 0.00 

Temporary (for 

construction of 

own house) 

6.00 500.00 500.00 Rs. Per 

Connection 

100.00 75.00 Rs. for each 0.5 kW 

of highest of 

sanction/connected/re 

corded Load 

8.00 700.00 600.00 Rs. Per 

Connection 

150.00 105.00 Rs. for each 0.5 kW 

of highest of 


corded Load 

Temporary (for 

social/marriage/r 

eligious 

function) 

6.00 500.00 500.00 Rs. Per 

Connection 

100.00 75.00 Rs. for each 0.5 kW 

of highest of 


corded Load per day 

or part thereof 

Madhya Pradesh Poorv Kshetra Vidyut Vitaran Co. Ltd, Jabalpur P a g e | 130 

8.00 700.00 600.00 Rs. Per 

Connection 

150.00 105.00 Rs. for each 0.5 kW 

of highest of 


corded Load per day 

or part thereof 

Through DTR 2.70 0.00 0.00 0.00 0.00 3.00 0.00 0.00 0.00 0.00 

for cluster of 

Juggi/Jhopadi 

Un-Metered 

Urban Areas 3.50 77.00 0.00 Units per 

consumer 

50.00 0.00 Rs. Per Connection 4.50 91.00 0.00 Units per 

consumer 

50.00 0.00 Rs. Per Connection 

Rural Areas 3.00 0.00 30.00 Units per 

consumer 

0.00 20.00 Rs. Per Connection 4.00 0.00 58.00 Units per 

consumer 

0.00 20.00 Rs. Per Connection



LOW TENSION - 

Type of installation 

Energy 

Charge 

(Rs/KWh) 

Rs. 



FY 11 

FY 12 

Energy 

Minimum Charges per 


Fixed Charge per month Charge 

month 

month 

(Rs/KWh) 

Fixed Charge per month 

Urban Rural Urban Rural Urban Rural Urban Rural 

Criteria 

Criteria 

Criteria 

Rs. 

Criteria 

2.1 Connected load base Tariff 4.55 360 240 60.00 40.00 Rs. Per kW 5.80 480 240 80 56 Rs. Per kW 

Demand Base Tariff for 

above 10 kW CD 

(Optional) 

For all units if monthly 

2.2 consumption is upto 50 

units 

For all units if monthly 

consumption exceeds 50 

units 

Demand Base Tariff for 

above 10 kW CD 

(Optional) 

LV 2: NON-DOMESTIC 

4.55 360 240 120.00 72.00 

Rs. Per kVA of 

billing demand 

5.80 480 240 150 105 



5.00 360 240 30.00 15.00 Rs. Per kW 5.90 480 240 50 35 Rs. Per kW 

5.45 360 240 60.00 30.00 Rs. Per kW 6.10 480 240 75 53 Rs. Per kW 

4.55 360 240 132.00 76.00 

Temporary Connection 6.60 360 240 100.00 60.00 



Rs. Per kW or 

part thereof 

5.75 480 240 144 101 

7.00 480 240 200 140 



Rs. Per kW or 

part thereof 

Temporary Connection(for 

marriage purpose at 

marriage gardens or 

marriage halls etc.) 

For X-ray Plants 

Single Phase 

Three Phase 

6.60 500.00 500.00 30.00 15.00 7.00 800 600 30 21 

Additional Fixed Charges (Rs. Per machine per month) 

Additional Fixed Charges (Rs. Per machine per month) 

300.00 

500.00 

500.00 700.00 




LOW TENSION - LV 3: PUBLIC WATER WORKS AND STREET LIGHTS 



Energy 

Charge 

(Rs/KWh) 

Rs. 


FY 11 FY 12 

Energy 



Fixed Charge per month Charge 

Fixed Charge per month 

month 

month 

(Rs/KWh) 


Criteria Criteria Criteria Criteria 

Rs. 

PUBLIC WATER WORKS 

Municipal Corporation/ 

Cantonment Board 

3.40 0.00 0.00 130.00 130.00 Rs. Per kW 5.15 0.00 0.00 150.00 105.00 Rs. Per kW 

Municipality / Nagar 

Panchayat 


Gram Panchayat 3.40 0.00 0.00 45.00 45.00 Rs. Per kW 5.15 0.00 0.00 90.00 63.00 Rs. Per kW 

Temporary 4.42 0.00 0.00 58.50 58.50 Rs. Per kW 6.00 0.00 0.00 200.00 140.00 Rs. Per kW 

STREET LIGHTS (incl. Traffic Signals) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Municipal Corporation/ 

Cantonment Board 


Municipality / Nagar 

Panchayat 


Gram Panchayat 3.50 0.00 0.00 45.00 45.00 Rs. Per kW 5.25 0.00 0.00 200.00 140.00 Rs. Per kW 

Temporary 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 




LV-4: LT INDUSTRY 


A Non Seasonal 

Energy 

Charge 

(Rs/KWh) 

Rs. 



FY 11 

FY 12 

Minimum Charges per month Fixed Charge per month 

Energy 

Charge 

(Rs/KWh) 



Criteria 

Criteria 

Criteria 

Rs. 

Criteria 

Upto 25 HP 3.50 360 240 

Minimum Annual 

units per HP or 

part thereof of 

contract demand. 

55.00 15.00 Rs. Per HP 4.50 480 240 





80.00 56.00 Rs. Per HP 

Demand Based Tariff 

(CD and connected 

load Upto 100 HP) 

4.55 360 240 





144.00 60.00 



5.00 480 240 





144.00 101.00 



Demand Based Tariff 

(CD upto 100 HP and 

connected load >100 

HP but 100 HP but 

less than 150 HP and 

connected load



LV 5.1: IRRIGATION PUMP FOR AGRICULTURE 



FY 11 FY 12 

Energy 

Energy 

Type of 

Charge Minimum Charges per month Fixed Charge per month Charge 

installation 

(Rs/KWh) 

(Rs/KWh) 



Criteria Criteria Criteria 

Rs. 

Rs. 

Criteria 

First 300 units 2.80 75 75 

Units per HP or part 

0.00 0.00 4.30 75 75 Units per HP or 0.00 0.00 

Above 300 

3.30 75 75 thereof of connected 


0.00 0.00 4.80 75 75 0.00 0.00 

units 

load per month for 

connected load per 

Temporary 

3.80 75 75 the months from Oct 0.00 0.00 5.30 75 75 

month for the 

0.00 0.00 

Connections 

to March and 25 

months from Oct 

DTR metered 

units for the month 

to March and 25 

group 

2.50 75 75 0.00 0.00 4.00 75 75 0.00 0.00 

from April to Sept. 

units for the month 

consumers 

from April to Sept. 

Assessment of Permanent Un-meterd consumers 

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

(April to May) 70 50 0.00 0.00 180 160 0.00 0.00 

(June to July) 70 50 0.00 0.00 100 65 0.00 0.00 

Single 

(Aug to Sept) 100 65 0.00 0.00 100 65 0.00 0.00 

Phase 

(Oct to March) As 180 160 0.00 0.00 As 180 160 0.00 0.00 

Units per HP of the 

Units per HP of 

indicated 

indicated 

(April to May) 70 40 sanction load 0.00 0.00 170 150 the sanction load 0.00 0.00 

above 

above 

(June to July) 70 40 0.00 0.00 100 55 0.00 0.00 

Three 

(Aug to Sept) 100 55 0.00 0.00 100 55 0.00 0.00 

Phase 

(Oct to March) 170 150 0.00 0.00 170 150 0.00 0.00 

Assessement of Temporary Unmeterd consumers 

0.00 0.00 0.00 0 0 0.00 0.00 0.00 

Single Phase 

190 170 0.00 0.00 190 170 0.00 0.00 

0.00 0.00 0.00 

0.00 

Three Phase 

175 155 0.00 0.00 175 155 0.00 0.00 





LV 5.2: OTHER THAN AGRICULTURE USE 



FY 11 FY 12 

Energy 

Energy 

Type of 

Charge Minimum Charges per month Fixed Charge per month Charge 

installation 

(Rs/KWh) 

(Rs/KWh) 



Criteria Criteria Criteria 

Rs. 

Rs. 

Criteria 



Connected 

units per HP or part 

Rs. Per 


Rs. Per 

Load Base 

3.30 360 240 

50.00 15.00 4.50 480 240 

80.00 56.00 

thereof of contract 

HP 


HP 

Upto 25 HP 

demand. 


Above 25 HP 

and upto 100 

HP 

4.25 360 240 


units per HP or part 

thereof of contract 

demand. 

128.00 56.00 

Rs. Per 

kVA of 

billing 

demand 

5.00 480 240 





144.00 100.80 

Rs. Per 

kVA of 

billing 

demand 

HIGH TENSION - HV-1: RAILWAY TRACTION 



FY 11 FY 12 

Type of Energy Charge Minimum Annual Fixed Charge Per kVA Energy Charge Minimum Annual Fixed Charge Per kVA 

installation Upto 

50% LF 

Above 

50% LF 

Consumption on 

%LF of CD 

of billing demand per 

month 

Upto 

50% LF 

Above 

50% LF 


%LF of CD 


month 

Rs. Rs. Units Rs. Criteria Rs. Rs. Units Rs. Criteria 

220 kV 4.50 4.50 1500 Per kVA of CD 200.00 4.85 4.85 1500 Per kVA of CD 450.00 






HIGH TENSION - HV 2: COAL MINES 



FY 11 FY 12 



50% LF 

Above 

50% LF 


%LF of CD 


month 

Upto 

50% LF 

Above 

50% LF 


%LF of CD 


month 






HIGH TENSION - HV-3: INDUSTRIAL AND NON-INDUSTRIAL 



FY 11 FY 12 



50% LF 

Above 

50% LF 


%LF of CD 


month 

Upto 

50% LF 

Above 

50% LF 


%LF of CD 


month 


HV 3.1 Industrial Use 

400kV 0.00 0.00 0.00 0.00 4.60 3.91 1800 Per kVA of CD 550.00 





HV 3.2 Non-industrial use 

400 kV 0.00 0.00 0.00 0.00 4.70 4.00 1800 Per kVA of CD 550.00 

220 kV 0.00 0.00 0.00 0.00 4.80 4.08 1800 Per kVA of CD 500.00 




HV 3.3 Shopping Mall 

220 kV 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

132 kV 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 







HIGH TENSION - HV-4: SEASONAL 



FY 11 FY 12 



50% LF 

Above 

50% LF 


%LF of CD 


month 

Upto 

50% LF 

Above 

50% LF 


%LF of CD 


month 


During Season 



During Off Season 

33 kV 5.28 NA 

on 10% of CD 

240.00 or MD which 

ever is higher 

6.00 NA 340.00 

11 kV 5.52 NA 215.00 

on 10% of CD 

or MD which 


6.60 NA 315.00 

on 10% of CD 

or MD which 


on 10% of CD 

or MD which 


HIGH TENSION - HV-5: IRRIGATION, PUBLIC WATER WORKS AND OTHER THAN AGRICULTURAL 



FY 11 FY 12 



50% LF 

Above 

50% LF 


%LF of CD 


month 

Upto 

50% LF 

Above 

50% LF 


%LF of CD 


month 


HV 5.1 Public WW, Group Irrigation and LIS 




HV 5.2 Other than agricultural use 








HIGH TENSION - HV-6: BULK RESIDENTIAL USERS 



FY 11 

FY 12 



50% LF 

Above 

50% LF 


%LF of CD 


month 

Upto 

50% LF 

Above 

50% LF 


%LF of CD 


month 


HV 6.1 Town ship, residential coloney 




HV 6.2 Registered Group Housing Society 




HIGH TENSION - HV-7: BULK SUPPLY TO EXEMPTEES 



FY 11 FY 12 



50% LF 

Above 

50% LF 


%LF of CD 


month 

Upto 

50% LF 

Above 

50% LF 


%LF of CD 


month 


RECs having mixed 3.20 3.20 200.00 0.00 0.00 0.00 

Mixed domestic and 2.60 2.60 100.00 0.00 0.00 0.00 

Mixed domestic and 3.20 3.20 150.00 0.00 0.00 0.00 



15.9 Salient features of Tariff proposal 

a. Demand Based tariff for Domestic consumer and other LT 

consumers having Contract Demand more than 10 kW is proposed to 

be introduced. 

b. The ToD Tariff for all Demand based LT consumers is proposed to 

be introduced. 

Reason for proposal: The Deputy Chairman, Planning Commission of India 

vide its letter dated 10 th Sept’2010 had requested the Govt. of M.P. for 

universal implementation of ToD principles. This will help in effective 

management of peak demand. Therefore the Licensee proposes that the ToD 

tariff may be applicable to all the consumers provided with demand based 

meters having ToD facility. 

c. The Peak period Surcharge is proposed as 20% of Energy charge in 

place of present level of 15% of Energy charge. 

d. The Off-peak period Rebate is proposed to be withdrawn. 

Reason for increase of ToD surcharge and withdrawal of ToD Rebate: The rate of 

additional power purchase during the peak period is generally higher as compared to 

the normal period rate due to increase in system demand. Similarly rate of additional 

power purchase during off peak period is less as compared to normal period due to 

decrease in system demand. The price of short term transaction of electricity through 

traders is down loaded from CERC web-site and given as under:- 

Month 

Price of Power Transacted through Traders 

Weighted average Sale Price (Rs per unit) 

Round the Peak % diff Off Peak 

Clock (RTC) 

w.r.t. RTC 

% diff 

w.r.t RTC 

Jan'09 7.43 8.55 15% 6.78 -9% 

Feb'09 6.89 8.16 18% 6.19 -10% 

March'09 7.35 8.08 10% 7.53 2% 

April'09 6.83 9.05 33% 8.47 24% 

May'09 6.6 8.18 24% 8.03 22% 

June'09 5.04 6.44 28% 5.07 1% 

July'09 4.72 5.92 25% 4.98 6% 

Aug'09 4.46 6.32 42% 5.77 29% 

Sept'09 4.6 6.02 31% 5.48 19% 

Oct'09 4.86 6.48 33% 5.8 19% 

Nov'09 5.05 5.76 14% 5.91 17% 

Dec'09 4.96 5.12 3% 5.06 2% 

Jan'10 5.34 5.01 -6% 5.11 -4% 



Month 

Price of Power Transacted through Traders 

Weighted average Sale Price (Rs per unit) 

Round the Peak % diff Off Peak 

Clock (RTC) 

w.r.t. RTC 

% diff 

w.r.t RTC 

Feb'10 4.95 5.72 16% 5.22 5% 

March'10 4.99 5.4 8% 4.73 -5% 

April'10 5.68 6.62 17% 5.72 1% 

May'10 6.26 6.39 2% 5.88 -6% 

June'10 5.57 5.84 5% 5.67 2% 

July'10 4.97 5.89 19% 5.02 1% 

Source:- CERC web site Market Monitoring 

It could be seen from the above table that price of power during peak period is 

higher than the price of power traded round the clock by generally more than 15%. It 

could also be seen from the above table that price of power during off peak period is also 

generally higher than the price of power traded round the clock. It is therefore 

concluded that rebate offered in previous Tariff order during off peak period is not in 

line with the price of power during off peak period. The surcharge during peak period is 

also lower than the price of power during peak period. In the opinion of MPPKVVCL, 

Jabalpur the range of surcharge during the peak period should be increased by at least 

5% and rebate should be withdrawn during off peak period. It would also be appropriate 

to recover such additional charges to those consumers who have utilized the power 

during peak period. 

e. In HT category the Load Factor calculation formula is proposed in 

the same manner as already approved by the Commission in its 

Tariff Order for FY 2010-11. 

f. The Tariff for Temporary supply is proposed as 1.5 times of the 

normal tariff in place of present level of 1.3 times. 

g. Dharmshalas run by Govt. registered trustees is proposed under LV- 

1 category and those not registered is proposed under LV-2.1 

category. Similarly the Tariff for mobile towers is proposed under 

LV-2.2 category. 

Reasons for proposed changes: - Some instances have been reported by field 

offices that some Dharmshalas are letting accommodation to the persons on 

commercial basis and also availing benefits of concessional tariff applicable for 

DLF categories. In order therefore to prevent misuse of DLF tariff by such 

Dharmshalas for commercial use, it has been proposed to consider only such 

Dharmshalas for the benefit of DLF tariff which are run by registered trustees. 



Similarly, Government of India is issuing licenses to infrastructure companies 

for erection and operation of Telecom Towers for installation of multiple 

transmitters of separate telecom companies in the same tower. Since, the use of 

power supply in such telecom towers with multiple transmitters of separate 

telecom companies is entirely used for non industrial use, it has been proposed 

h. On account of takeover of societies the tariff for HV-7 category has 

not been proposed. 

i. The tariff for 400kV Supply to HV-3 category is proposed to be 

introduced. 

j. The delayed payment surcharge is proposed as 2% in place of present 

level of 1.5%. 

k. The calculation for Billing to HT consumer willing to avail supply 

temporarily through existing meter is proposed to be changed. 

Reasons for proposed changes:-The changes have been proposed to take care of 

various scenarios in which actual MD recorded exceeds the deemed CD (sum of 

CD for permanent supply and Temporary demand), actual MD recorded is below 

the permanent contract demand and actual MD recorded is between the permanent 

CD and deemed CD. 

l. The Additional charge for excess demand to Railway traction is 

proposed at same level as applicable to other HT consumers. 

Reasons for proposed changes:The earlier method of calculation of excess demand 

charges in respect of Railway Traction Supply Points in 2 stages i.e. up to 15% 

over and above CD and above 15% over and above CD on demand charges other 

than the normal demand charges is proposed to be removed and it has now been 

proposed to consider the same method for calculation of excess demand charges 

based on normal demand charges for Railway Traction Supply Points also as 

applicable for other HT consumers to avoid any discrimination among the HT 

consumers as mandated in Electricity Act, 2003. 

m. The provision of terms and conditions of consumers who is not the 

consumer of the licensee and seeks to avail power for 

synchronization with the grid is proposed to be removed. 



Reasons for proposed changes: Since the terms and condition for generators 

connected to the grid but who are not the consumer of the licensee and seeks to 

avail power for synchronisation with the grid or start-up power are the matter 

related with the relevant regulation, such as supply code, regulation of CPP and 

not with the retail supply tariff. Therefore it is proposed to remove this condition 

from the retails supply tariff. 

15.10 Based on the available information, the Petitioner has made sincere efforts 

to comply with the Regulations of the Hon'ble Commission and discharged 

its obligations to the best of its abilities and resources in its command. 

However, should any further material information become available during 

the process of determination, the Applicant be permitted to reserve the right 

to file such additional information and consequently amend/ revise the 

application. 



Annexure- “A” 

Method of Calculation of Input in Rural Area 

1. The energy input (with HT) of all the 15 circles of MPPKVVCL is equal to 

the Energy input (with HT) for MPPKVVCL (Urban & Rural area) say “A” 

2. The total of energy sold to 220 kV/132kV EHV and 33 kV HV consumers 

(within the circle) and 11 kV consumers (within the divisions of the circles) 

altogether say “B” 

3. Considering the transformation losses as 1.5% of energy input (without HT) 

for MPPKVVCL say “C” is computed as per the following formula 

C = A- 1.015*B 

4. The sum of Energy input (w/o HT) to all the District HQ say “D” 

5. Energy input to rural area say “I(r)” is then computed as: 

I(r) = C - D 



A16:COMPLIANCE ON TARIFF ORDER FY 2010-11 

The objective of reforms in the power sector is to provide reliable 

quality supply at an affordable price. Looking to the present state of affairs, 

there is a need to take urgent steps to achieve these objectives. The 

Distribution licensees need to come out of the scenario of high level of 

losses and inefficient services to become commercially viable by quickly 

adopting effective efficient improvement measures in their operations. The 

Commission is concerned over the fact that a lot of time has elapsed since 

the process of reforms began however the desirable levels of operations 

have not been achieved. The Commission in tariff orders issued in the past 

has been consistently advising the Distribution Companies to align with the 

new initiatives envisaged in the Electricity Act, 2003 and consequent 

policies to fulfil the objectives of reforms. 

The distribution licensees have submitted the status of compliance 

against various directives issued in the past. A review of the submissions 

made by the distribution licensees in this regard reveals that the progress 

achieved is not at all satisfactory and Licensees must move ahead quickly 

so as to achieve desirable results. The Commission wishes to focus on those 

issues that acquire high priority for overall improvement in the performance 

of distribution management. The Commission in its Retail Tariff Order for 

FY 2009-10 had issued a number of directives. . The status of compliance 

submitted by the Licensees, observations of the Commission against these 

directives and fresh directives are as given below – 

16.1 Distribution losses: 

16.1.1 Commission‟s Directives: 

The Commission therefore directs that the Licensees should concentrate 

their focus on this very important issue during the ensuing period so as 

not only to reach the level of normative losses but improve further. 



16.1.2 MPPKVVCL Submission 

It is submitted that the loss level of MPPKVVCL which was 37.23% 

for the year 2008-09 has reduced to 33.45% during 2009-10. Therefore 

MPPKVVCL has achieved the reduction of loss level by 3.78%. As per the 

loss trajectory notified by the GoMP the reduction of losses in the year 

2009-10 was 3.00% i.e. the reduction of losses from 29.5% to 26.5%. The 

company has already achieved more than the desired reduction in losses. 

However for achieving the loss level the company has submitted the 5- 

years Capex plan for reduction in technical losses to the Hon’ble 

Commission vide letter no. 7516 dtd. 23-10-2010. It is expected that after 

such investment the company will definitely achieve the desired level in 

losses. 

16.2 Meterization of unmetered connections 


Commission again directs as follows: 

i. All un-metered domestic connections in urban areas should be 

provided with the meters by end of Dec’2010. 

ii. 

All un-metered domestic connections in rural areas be provided 

with meters in a phased manner and meterization be completed by 

March 11. 

iii. Not less than 25% of the distribution transformers having predominantly 

agriculture load spread over the entire area of the 

Company be provided with the meter by end of Dec’10. 

iv. 

Data of all metered DTRs but not less than 10% of the total DTRs 

having pre-dominant agriculture load and capturing diverse 

consumption pattern, should be collected and compiled on a 

regular basis. The consumer indexing and verification of actual 

connected load be also got done and compared with the recorded 

consumption. The Commission directs to submit the above data 

and its analysis on a quarterly basis and also along with the 

petition for ARR and tariff proposals for the next year. 




It is submitted that the company has achieved the target of 100% 

meterization of Domestic categories in urban area. For rural area, due to 

stressed financial condition and limited resources the company is not in a 

position to procure and install the meters on all un-metered domestic 

consumers of rural area. Since the quantum of un-metered DL&F 

consumers in rural area due to regularization of ghost consumers has 

already reached to the tune of 7 lakhs, the company is facing difficulty for 

procuring such a huge quantum of costly meters with stressed financial 

conditions. 

Regarding DTR meterization of agricultural predominant DTRs, the 

company has started implementation of HVDS scheme under ADB funding 

wherein meters for individual agricultural consumers are being installed 

inside the distribution box of DTR. Under ADB scheme it is proposed to 

install 17656 nos. DTR in first phase and 16739 nos. DTRs in second 

phase. On all the 34395 transformers, total 130761 Agricultural consumers 

will be provided with meters. Till 31 st July’2010 total 7950 DTRs have been 

installed with 22597 consumer meters. Under feeder bifurcation scheme the 

agricultural feeders are being separated with provision of feeder meters. 

It is submitted that the company is in progress for collecting the data 

from field for those consumers who have been provided metered 

connections under HVDS scheme and the same will be submitted to 

Hon’ble Commission by the end of Jan’2011. 

16.3 Capex plan for reduction of technical losses: 

16.3.1 Commission„s directives: 

The Licensees are directed to file the progress of Capex during the year 

FY10-11 up to June’10 by end of July’10 and quarterly thereafter. In 

addition the Capex plan for the year FY 11-12 be also filed by July’10. 




It is submitted that the company has already filed the 5-years capex 

plan funded by GoMP to the Hon’ble Commission vide letter no. 7516 dtd. 

23-10-2010.The progress of approved capex plan is also submitted before 

the Commission vide letter no. 7516 dtd. 23-10-2010. 

16.4 Installation of meters having facility to record average monthly 

demand on domestic category of consumers:- 

16.4.1 Commission Directives: 

The Commission directs to provide meters having facility to record 

average monthly demand on all the domestic connections having a 

connected load of 10 KW and above during this year. 


It is submitted that the project of AMR for all such consumers having 

connected load above 10HP is already in progress and 75% consumers 

have already been covered. It is expected that balance 25% consumers will 

be covered by March’2011. However the company proposes the demand 

based tariff for consumer having connected load of 10kW and above. 

16.5 Segregation of rural feeders into agricultural and others: 


The Commission directs that comprehensive details indicating total no. of 

11Kv feeders that require separation, no. of feeders for which the 

schemes have been prepared and no. feeders for which the scheme is 

under preparation be filed. Proposed source for funding and timelines for 

completion indicating as to when all such feeders would be separated be 

informed. The information be filed by end of July’10. 




It is submitted that the company has already filed a petition before the 

Hon’ble Commission for approval of feeder separation scheme. The present 

status of feeder separation under different schemes is given as below. 

Sr. 

no. 

Particulars 

Under feeder 

Seg. Scheme 

Under 

ADB 

scheme 

Under 

RGGVY 

scheme 

Total 

a) Total no. of feeders 

requires separation: 

1645 83 327 2055 

b) No. of feeders for which 

scheme have been 1645 83 327 2055 

prepared: 

c) No. of feeders for which 

scheme is under - - - Nil 

preparation: 

d) Proposed 

funding 

source for 

REC and ADB ADB REC 

e) Timeline for completion: Dec‟2012 Dec‟2012 Dec‟2012 

f) Work completed up to 

FY-11 

Nil 20 21 41 

16.6 Minimum supply hours: 

16.6.1 Commission‟s directives: 

The Commission directs the Licensees to maintain the minimum daily 

supply hours as directed in the tariff order for FY 09-10 during this year. 


It is submitted that the month-wise average supply hours for the 

financial year 2009-10 and 2010-11 up to Sept’10 is given as below: 

SR. 

COMM. DISTT. TEHSIL 

MONTH YEAR 

NO. 

H/Q H/Q H/Q 

Rural 

1 APRIL 2009-2010 23:45:00 22:08:00 16:34:00 14:00:00 

2010-2011 21:16:00 18:36:00 13:07:00 9:44:00 

2 MAY 2009-2010 24:00:00 22:01:00 16:01:00 13:05:00 

2010-2011 21:22:00 19:20:00 13:14:00 9:31:00 

3 JUNE 2009-2010 22:20:00 19:27:00 12:14:00 9:30:00 

2010-2011 21:45:00 19:33:00 13:29:00 9:29:00 

4 JULY 2009-2010 22:24:00 21:29:00 15:17:00 12:40:00 

2010-2011 23:18:00 22:02:00 14:59:00 11:20:00 

5 AUG. 2009-2010 22:29:00 19:26:00 11:40:00 9:10:00 

2010-2011 23:44:00 22:28:00 15:51:00 13:15:00 

6 SEPT. 2009-2010 23:23:00 22:22:00 17:56:00 15:51:00 

2010-2011 23:44:00 23:36:00 20:22:00 19:10:00 

7 OCT. 2009-2010 23:40:00 22:14:00 16:09:00 13:10:00 

2010-2011 



SR. MONTH YEAR COMM. DISTT. TEHSIL Rural 

NO. 8 NOV. 2009-2010 22:30:00 H/Q 21:07:00 H/Q 18:34:00 H/Q 14:41:00 

2010-2011 

9 DEC. 2009-2010 22:40:00 20:11:00 17:04:00 10:34:00 

2010-2011 

10 JAN. 2009-2010 22:22:00 18:55:00 14:45:00 11:55:00 

2010-2011 

11 FEB. 2009-2010 22:02:00 17:57:00 13:22:00 9:29:00 

2010-2011 

12 MARCH 2009-2010 22:02:00 18:03:00 13:41:00 10:14:00 

2010-2011 

AVERAGE 2009-2010 22:48:05 20:26:40 15:16:25 12:01:35 

2010-2011 22:31:30 20:55:50 15:10:20 12:04:50 

16.7 New connections or enhancement of load under tariff category LT 

Industrial 4.1 C 

16.7.1 Commission‟s directives: 

The Commission under this tariff order has made changes to the relevant 

provisions in this regard which may be complied and compliance reported 

in next three months. 


The company has issued the bill to the consumer under this category 

strictly as per the provisions of the tariff order. 

16.8 Appointment of Franchisees: 


The Commission directs the licensee to submit details whenever a 

franchisee is appointed in the area of the licensee. 


The status of the franchisee during the year 2008-09 has already been 

submitted before the commission by the company in the response of queries 



of the commission in True-up petition 2008-09. The status for the year 

2009-10 will be submitted along with the True-up petition for 2009-10. 

16.9 Issue of tariff card with first bill based on new tariff for the year 2009- 

2010: 


The distribution companies are directed to issue a tariff card to all 

consumers containing details of tariff for various categories applicable as 

per the tariff order for the year 2010-11 with the first bill based on this 

tariff order. 


It is submitted that the tariff booklet to all HT consumers has been 

provided by the company. The tariff order is available on the website of the 

commission and vide publicity has already been made for implementation 

of applicable tariff for the year 2010-11. The printing of tariff card is 

costlier affair and therefore it is prayed that the company may please be 

exempted for providing the tariff card to all the LT consumers. 

16.10 Filing of ARR and tariff proposals in Hindi language 


All the distribution companies are directed that ARR and tariff proposals 

and true up petitions in future should be filed both in English and Hindi. 


It is submitted that the filing has been made in English and all the 

sincere efforts will be taken for conversion of this petition into Hindi. 



16.11 Accounting of rebates/incentives/ surcharge: 


The Commission again directs the Licensees to ensure capturing of 

requisite details from the revenue billing of the consumers and submit the 

data failing which the Commission may initiate suitable proceedings 


The month-wise billing details of HT consumer is submitted in the soft 

copy of the petition. It is submitted that the requisite details is available in 

the submitted data. 

16.12 New Directives: 

16.12.1 In addition to the above directives, the Commission issues the following 

new directives in this order 

Maintaining uniform accounts: 

The Commission has observed that the method of capturing the 

accounts in the three Distribution Companies is not uniform. Moreover, the 

method of presentation of expenses and revenues is also different in three 

Companies. The chart of accounts also needs to be developed for uniform 

implementation across the three Distribution Companies. The Commission 

directs that all the three Companies should evolve a common acceptable 

methodology of capturing cost and ensuring that in future accounts, this 

methodology is consistently applied with a common Accounting Policy 

taking into consideration of followings - 

(i) 

Basis of framing account should be same for all the three 

Distribution Companies. 

(ii) All the three Distribution Companies should evolve a common chart 

of accounts. 

(iii) Methodology of presentation of expenditure and revenues in 

Financial Accounts should be common. 



It is suggested that the three Discoms should form a committee of their 

Officers who should come up with suitable recommendations, keeping in 

above view, by August, 2010. 


It is submitted that the three distribution companies are functioning 

independently w.e.f. 1 st June’2005. Since different statutory auditors for the 

three distribution companies are functioning separately therefore the 

company is facing difficulty for compliance of aforesaid directive. 

16.13 Compliance of Regulations: 

The Commission observed that the Licensees have submitted their ARR/ 

Tariff petition for FY 10-11 in variance to with the provisions of the 

Regulations particularly with regard to the distribution losses, O&M , 

depreciation etc. The Commission directs that in future the petition be 

filed strictly in accordance with provisions of the Regulations and if a 

Licensee wishes to draw the attention on some specific issues, it can be 

done through additional submissions in the petition. 


The company is filing this petition in accordance with the provisions 

of the regulations along with additional submission.

Madhya Pradesh Poorv Kshetra Vidyut Vitaran Company ... - Infraline

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