aggregate revenue requirement and tariff petition for fy 2016-17

Transcription

AGGREGATE REVENUE REQUIREMENT
AND
TARIFF PETITION
FOR FY 2016-17
*********
Submitted by: -
Madhya Pradesh Power Management Company
Limited, Shakti Bhawan, Vidyut Nagar,
JABALPUR
Madhya Pradesh Poorva Kshetra Vidyut Vitran
Company Limited,
Block No. 7, Shakti Bhawan, Vidyut Nagar,
JABALPUR
Madhya Pradesh Paschim Kshetra Vidyut Vitran
Company Limited,
GPH Compound, Polo Ground,
INDORE
Madhya Pradesh Madhya Kshetra Vidyut Vitran
Company Limited,
Bijlee Nagar Colony, Nishtha Parisar, Govindpura
BHOPAL
BEFORE THE HON’BLE MADHYA PRADESH
ELECTRICITY REGULATORY COMMISSION, BHOPAL
Petition No. ________of 2015
(1)
Madhya Pradesh Power Management Company Limited (MPPMCL)
Shakti Bhawan, Vidyut Nagar, Jabalpur (MP)
(2)
Madhya Pradesh Poorv Kshetra Vidyut Vitaran Company Limited (MPPoKVVCL)
Shakti Bhawan, Vidyut Nagar, Jabalpur (MP)
(3)
--------- Petitioner
Madhya Pradesh Paschim Kshetra Vidyut Vitaran Company Limited (MPPaKVVCL)
GPH, Polo Ground, Indore (MP)
(4)
Madhya Pradesh Madhya Kshetra Vidyut Vitaran Company Limited (MPMKVVCL)
Nishtha Parisar, Bijlee Nagar, Govindpura, Bhopal (MP)
IN THE MATTER OF:
Filing of ARR application for the distribution and retail supply business for the MYT period
FY 2016-17 to FY 2018-19 and tariff proposal petition for FY 2016-17 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, 2015 (RG -35 (II) of 2015)" No. 2256MPERC,2015 Dated 17-12-2015 communicated to MPPMCL vide Commission’s letter no.
2265 dated Dec. 18, 2015 by MPPMCL and MPPoKVVCL, MPPaKVVCL & MPMKVVCL
as the Distribution Licensees.
The Petitioners above respectfully submit as under:1. Madhya Pradesh Power Management Company Ltd., (hereinafter referred to as the 'Petitioner',
MPPMCL, 'the Company' or 'the Licensee'), is a Company incorporated under the Companies Act,
1956 (now Companies Act 2013) and having its registered office at Block No.11, Shakti Bhawan,
Vidyut Nagar, Jabalpur.
2. Madhya Pradesh Poorv Kshetra Vidyut Vitaran Company Ltd., (hereinafter referred to as the
'Petitioner', MPPKVVCL, 'the Company' or 'the Licensee' or ‘East Discom’), is a Company
incorporated under the Companies Act, 1956 (now Companies Act 2013) and 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
ARR for MYT FY 2016-17 to FY 2018-19 and Tariff Petition for FY 2016-17
supply of the Petitioner comprises Jabalpur, Rewa, Sagar and Shahdol Commissionary within the
State of Madhya Pradesh ('MP').
3. Madhya Pradesh Paschim Kshetra Vidyut Vitaran Company Ltd., (hereinafter referred to as the
'Petitioner', MPPaKVVCL, 'the Company' or 'the Licensee' or ‘West Discom’), is a Company
incorporated under the Companies Act, 1956 (now Companies Act 2013) and having its
registered office at GPH, Polo Ground, Indore. 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
comprises Indore and Ujjain Commissionary within the State of Madhya Pradesh ('MP').
4. Madhya Pradesh Madhya Kshetra Vidyut Vitaran Company Ltd. (MPMKVVCL), (hereinafter
referred to as the 'Petitioner', MPMKVVCL, 'the Company' or 'the Licensee' or ‘Central
Discom’), is a Company incorporated under the Companies Act, 1956 (now Companies Act
2013) and having its registered office at Nishtha Parisar, Bijlee Nagar Colony, Govindpura,
Bhopal. 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 comprises Bhopal, Gwalior,
Hoshangabad and Chambal Commissionary within the State of Madhya Pradesh ('MP').
5. The Government of Madhya Pradesh ('GoMP' or 'State Government'), vide an Order No. 3679FRS-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: a)
b)
c)
d)
e)
M.P. Power Generating Company Ltd., Jabalpur (MPPGCL)
M.P. Power Transmission Company Ltd., Jabalpur (MPPTCL)
M.P. Poorv Kshetra Vidyut Vitaran Company Ltd., Jabalpur (MPPoKVVCL)
M.P. Paschim Kshetra Vidyut Vitaran Company Ltd., Indore (MPPaKVVCL)
M.P. Madhya Kshetra Vidyut Vitaran Company Ltd. Bhopal (MPMKVVCL)
6. With effect from 1st 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 Discoms viz. MPPoKVVCL, Jabalpur, MPPaKVVCL,
Indore and MPMKVVCL, Bhopal 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.
7. 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 and simultaneously re-transferred and revested the same to MP Power Trading Company Ltd. ('Tradeco' or 'MP Tradeco'). Since then, MP
Tradeco discharged the responsibilities of procurement of power in bulk and supplying to the three
Electricity Distribution Companies (DISCOMs), including the Petitioner herein. The transfer was
3
affected through "M.P. Electricity Reforms Transfer Scheme Rules 2006” (Transfer Scheme
Rules) vide Notification No.3474 /FRS/17/XIII/2002 dtd 3rd June 2006 (Transfer Scheme Rules).
8. In accordance with GoMP decision, the name of MP Power Trading Company Ltd has been
changed to MP Power Management Company Ltd. MPPMCL is the holding Company of the three
electricity distribution companies (Discoms) of MP State, viz., M. P. Poorv Kshetra Vidyut Vitaran
Company Ltd., M. P. Paschim Kshetra Vidyut Vitaran Company Ltd. and M. P. Madhya Kshetra
Vidyut Vitaran Company Ltd. The Petitioner (MPPMCL) has been vested with several of functions
and powers that were earlier vested with the erstwhile Madhya Pradesh State Electricity Board. The
Registrar of Companies MP has issued the Certificate of Incorporation Consequent upon Change of
Name on 10.04.2012.
9. GoMP has entrusted the MPPMCL with the responsibility inter alia of representing the Discoms
before the Commission with regard to filing the tariff petition and facilitating all proceedings
thereon. The Management and Corporate functions agreement signed by the MPPMCL with the
three Discoms of MP also provide for the same.
10. MPPMCL has signed “Management and Corporate Functions Agreement” on 5th June 2012, with
the three Discoms of the State, wherein it has been agreed that the Petitioner shall perform inter alia
the following functions of common nature for the Discoms:

In consultation with Discoms, undertake long-term/ medium-term/short-term planning
and assessment of the power purchase requirements for the three Discoms and explore
opportunities for power procurement as per the regulations of MPERC;

Allocation of power among the Discoms from the forthcoming projects as per retail tariff
order and as per the GoMP notification and further instructions in this regard;

Economic, reliable and cost effective power procurement of Short-term, Medium-term
and Long-term and sale of surplus power, if any, for the purpose of Banking /
maximization of revenue;

Exploring opportunities for procurement of power on long-term and medium-term basis,
procure power and finalizing Power Purchase Agreements (PPAs);

The expenses of MPPMCL have been considered to be included as part of power
purchase cost of the Discoms.
11. In the backdrop of the above facts and circumstances, the present application is being made by the
MPPMCL along with the three Distribution Companies of MP State under Section 61 and Section
62 (1) (d) of the Electricity Act 2003 for determination of the tariff for distribution and Retail
Supply Business for the period FY 2016-17 following the regulations laid down by the Hon’ble
Commission.
12. While filing the present ARR under the prevailing Regulation, MPPMCL along with the Discoms
has endeavored to comply with the various legal and regulatory directions and stipulations
4
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 2015
(hereinafter referred to as the “Regulations”).
13. It is submitted that as soon as the retail tariff order becomes applicable, the voltage level and
consumer category wise cross subsidy surcharge, additional surcharge, wheeling charges and
transmission charges in respect of open access customers should also be notified and made
effective from the tariff application date. It is therefore, prayed to kindly issue the approach paper
for determination of the voltage level and consumer category wise cross subsidy surcharge,
additional surcharge, wheeling charges and transmission charges also along with the retail tariff
order for open access customers.
14. It is also submitted that the Petitioners have not separated the consumers, connected load, energy
units sold and projected revenue in the Franchisee areas of Sagar, and Ujjain from their sales and
revenue model as the consumers in the franchisee area remain to be the consumers of the
Distribution Licensee and not the Franchisee. The franchisee is only a collection agent working on
behalf of the Distribution Licensee and recovers charges from consumers at the tariff determined by
the Hon’ble MPERC. The revenue realized by the Distribution Licensee is completely in
accordance with the tariff determined by the Hon’ble MPERC. The projections of these parameters
have been done on the basis of most feasible growth rate out of Compounded Annual Growth Rate
(CAGR) for the last 3 and 2 years, YoY growth and corresponding period growth up to September
2015.
15. This petition is filed on the basis of normative parameters as provided by Hon’ble MPERC in
Regulation no: 2256-MPERC.2015 dated 17/12/2015 regarding MPERC (Terms and Conditions
for Determination of Tariff for Supply and Wheeling of Electricity and Methods and Principles for
Fixation of Charges) Regulations 2015. The Regulation does not provide segregation of normative
losses for the Distribution Licensees into voltage wise normative losses in respect of technical and
commercial losses. Therefore, the Petitioners face difficulty in segregation of normative losses in
voltage level wise technical and commercial losses.
The Hon’ble MPERC in the previous year’s order has referred to an Appellate Tribunal for
Electricity (APTEL) judgment to determine the voltage level wise Cost of Supply in the state of
MP. However, this judgment is to determine the voltage level wise cross subsidy surcharge and not
consumer tariff. In the present petition, the Petitioners have proposed consumer category wise tariff
on the basis of Average Cost of Supply, which is in line with the National Tariff Policy 2006. The
Hon’ble Commission is requested to determine the voltage level and consumer category wise cross
subsidy surcharge on the basis of the available data with the Distribution Licensees in accordance
with the methodology suggested by the APTEL and also approved by Hon’ble Commission in its
Retail Supply Tariff Order for FY 2016-17.
16. Based on the information available, the Petitioners have made sincere efforts to comply with the
Regulations of the Hon'ble Commission and discharge its obligations to the best of its ability and
resources at its command. However, should any further information of material significance
5
becomes available during the process of determination, the petitioners may be permitted to reserve
the right to file such additional information and consequently amend/ revise the petition.
17. In consequences of the APTEL’s judgement, the Hon’ble Commission has approved the balance
amount of true- up costs for all the three Discoms for FY 2005-06. The approved true up amount
has also been considered while filing the total ARR for FY 2016-17. Further it is submitted that the
balance amount of true-up cost for FY 2006-07, 2007-08, 2008-09, 2009-10, 2010-11 and 2011-12
has not been included as the Hon’ble Commission has still not issued any order for balance true-up
cost consequent to the judgement of Supreme Court/APTEL regarding true-up for aforementioned
years. Further, the true-up cost for the year FY 2012-13 is still under consideration with the
Hon’ble Commission. Therefore, this cost also has not been included in this petition. It is prayed
that after issuing the relevant orders, the Hon’ble Commission may include these costs before
issuing the final tariff order.
18. The salient features of the ARR for FY 2016-17 are as under:S.No.
ARR Items
East
Central
West
TotalState
1
Total ARR (excluding True Up)
Rs Crs
9,551
9,656
10,537
29,744
2
Revenue at current tariffs
Rs Crs
8,071
8,121
9,114
25,306
3
Gap (excluding true-up)
Rs Crs
1,480
1,534
1,423
4,438
4
Average Cost of Supply (excluding true-up)
Rs/kWh
6.07
6.42
5.92
6.13
Impact of True-Up Amounts of Past Years
A
Impact of True Up for Discoms for FY 2005-06
Rs Crs
104
125
138
366
B
Impact of True Up for MPGenco for FY 2012-13
Rs Crs
-34
-32
-38
-104
C
Impact of True-Up for MPTransco for FY 2013-14
Rs Crs
91
87
103
281
5
Total ARR (Including True Up)
Rs Crs
9,713
9,835
10,740
30,288
6
Total Revenue Gap (including True-up)
Rs Crs
1,642
1,714
1,626
4,982
7
Average Cost of Supply (including true-up)
Rs/kWh
6.17
6.54
6.04
6.24
19. However, despite the various measures taken to improve commercial and technical efficiencies,
Discoms are unable to recover the costs incurred, which are compelling the Discoms to propose for
an increase in the existing tariff.
20. The petitioners would like to reiterate their proposal to alter the mechanism for deriving Fuel Cost
Adjustment (FCA) for recovery/adjustment of uncontrollable costs due to increase or decrease in
the cost of fuel in case of coal, oil and gas based generating stations. The petitioners would like to
resubmit that the existing mechanism to calculate FCA does not have any provision to recover the
incremental power purchase. The petitioners also urge that the average power purchase cost should
6
be considered in the formula instead of only variable costs, thus passing on the complete fixed costs
on to the consumers as a legitimate cost.
21. Shri F.K. Meshram, Chief General Manager (Revenue Management) of MPPMCL; Shri P.K.
Singh, Executive Director (Commercial) of MPPoKVVCL; Shri Pavan Kumar Jain, ASE
(Commercial) of MPPaKVVCL and Shri A.R. Verma, General Manager & Superintending
Engineer (Commercial) of MPMKVVCL have been authorized to execute and file all the
documents on behalf of the respective petitioners in this regard. Accordingly, the current filing is
signed and verified by, and backed by the affidavit of respective authorized signatories.
7
PRAYER
In view of the aforesaid facts and circumstances, the Applicants request that the Hon'ble Commission
may be pleased to:
(a)
Take the accompanying ARR/Tariff petition of the above petitioners on record and treat it as
complete;
(b)
Consider and approve petitioners’ ARR (including true-up amounts of all companies
previous years) amounting to Rs. 9,713 Cr for East Discom, Rs. 9,835 Cr for Central
Discom and Rs. 10,740 Cr for West Discom for the year FY 2016-17;
(c)
Considering the aforesaid facts and circumstances the Hon’ble Commission may be pleased to allow
expenses of MPPMCL as stated to be allowed and include them as a part of power purchase cost of
three Discoms, to meet the ends of justice;
(d)
Consider and approve Petitioners’ tariff proposal for FY 2016-17 to recover the costs for the
ensuing year;
(e)
Consider and determine the wheeling charges, voltage level and consumer category wise
cross subsidy surcharge, additional surcharge and transmission charges for open access
customers on the basis of ARR petition for FY 2016-17 and make applicable w.e.f the
application date of the revised tariff;
(f)
Condone any inadvertent omissions/ errors/ shortcomings and permit the petitioners 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 an order as the Hon'ble Commission deems fit and proper as per the facts and
circumstances of the case.
Date: - 21st December 2015
Shri F.K. Meshram, Chief General Manager
(Revenue Management)
MPPMCL, Jabalpur
Shri P.K. Singh, Executive Director
(Commercial)
MP Poorv Kshetra Vidyut Vitaran Co.
Ltd., Jabalpur
Shri Pavan Kumar Jain, ASE
(Commercial)
MP Paschim Kshetra Vidyut Vitaran Co.
Ltd., Indore.
Shri A.R. Verma, GM & SE
(Commercial)
MP Madhya Kshetra Vidyut Vitaran Co.
Ltd., Bhopal.
8
9
Table of Contents
PRAYER
1.
8
Estimation of sales
16
1.1
Method adopted for Estimation of Sales
16
1.2
Category-wise sales projection
18
1.2.1.
LV -1: Domestic
18
1.2.2.
LV -2: Non-Domestic
22
1.2.3.
LV -3.1: Public Water Works
24
1.2.4.
LV -3.2: Street Light
27
1.2.5.
LV -4.1: Non- Seasonal Industrial
30
1.2.6.
LV -4.2: Seasonal Industrial
33
1.2.7.
LV -5.1: Agricultural
35
1.2.8.
LV -5.2: Other allied agricultural Use
38
1.2.9.
HV -1: Railway Traction
42
1.2.10.
HV -2: Coal Mines
44
1.2.11.
HV-3: Industrial and Non-Industrial
45
1.2.12.
HV -4: Seasonal
49
1.2.13.
HV -5 Water Works, Lift Irrigation & Other allied Agricultural use
51
1.2.14.
HV -6: Bulk Residential users
55
2.
Energy Requirement at Discom Boundary and Ex-Bus Energy Requirement 57
2.1.
Conversion of annual sales to monthly sales
57
2.2.
MPPTCL Losses
57
2.3.
Distribution Losses
58
2.3.1.
3.
3.1.
3.2.1
3.2.
3.2.1.
Conversion of annual Distribution loss levels to monthly losses
Assessment of Availability
58
65
Details of Generation Capacities allocated to Discoms
65
Availability from MP Discoms’ allocated stations
68
Details of Generation Capacities allocated to MPPMCL – Existing and Capacity
Addition for the MYT period FY 17-FY 19
Availability from MPPMCL allocated stations
70
72
3.3.
Overall availability
73
3.4.
Backdown of Power
73
3.5.
Inter-State Transmission Losses
74
3.6.
Management of Surplus Energy
75
10
3.7.
3.7.1.
4.
Energy Balance
Energy Requirement vis-à-vis Availability and Management of Shortfall
Power Purchase Cost
76
76
77
4.1.
Details of Costs for Stations allocated to MP Discoms
77
4.2.
Merit Order Dispatch (MoD)
80
4.3.
RPO Cost
87
4.4.
Estimation of Other Power Purchase Costs
88
4.4.1.
Inter-State Transmission Charges
88
4.4.2.
Intra-State Transmission Charges – MPPTCL fixed costs excluding Terminal
Benefits (Cash Outflow)
88
Intra-State Transmission Charges – Terminal Benefits (Cash Outflow) to be
included in MPPTCL costs
89
4.4.4.
MPPMCL Costs
90
4.4.5.
Total Power Purchase Costs
91
4.4.3.
5.
O&M Expenses - Discoms
93
5.1.
Employee Costs
93
5.2.
Administrative & General Expenses
94
5.3.
Repair and Maintenance Expenses
94
5.4.
Gist of O&M Expenses
94
6.
Investment Plan – Discoms
95
6.1.1.
Capital Investment Plan
95
6.1.2.
Scheme Wise Capitalization
96
6.1.3.
CWIP
97
6.1.4.
Fixed Assets Addition
98
7.
Other Costs/ Income – Discoms
99
7.1.
Depreciation
99
7.2.
Interest and Finance Charges
99
7.2.1.
Interest on Project Loans
99
7.2.2.
Interest on Working Capital
101
7.2.3.
Interest on Consumer Security Deposit
103
7.3.
Other Income
104
7.4.
Return on Equity
105
7.5.
Bad and Doubtful Debts
106
8.
Income/Expenses of MPPMCL
107
11
8.1
Income
107
8.2
Expenses
108
9.
Annual Revenue Requirement
113
9.1.
Annual Revenue Requirement of MPPMCL
113
9.2.
Annual Revenue Requirement of Discoms
113
10.
Terminal Benefits (Pension, Gratuity and Leave Encashment) Provision
116
11.
Power Purchase Cost Adjustment (PPCA)
119
12.
Tariff Proposal for FY 2016-17
123
12.1. Salient Features of the Tariff Proposal
125
12.1.1.
Merging of tariff slabs of 0 to 50 units and 51 to 100 units as 0 to 100 units in LV
1.2 Domestic Category
125
12.1.2.
Removal of optional demand based tariff (only for contract demand above 10 kW
and upto 20 kW) in LV 2.1 and LV 2.2 Non Domestic category
125
12.1.3.
Merging of LV 3.1 Public Water Works and LV 3.2 Street Light categories
125
12.1.4.
Rebate to all LT consumers for online payment of bills
125
12.1.5.
Permission to use 10% of connected load/ contracted demand for temporary usage
by LT consumers
126
12.1.6.
Limiting the sanctioned load/ connected load under LT connection to 75 kW/ 100
HP
126
12.1.7.
Merging of HV 3.2 Non Industrial use and HV 3.3 Shopping Mall
12.1.8.
Merging of HV 5.1 Public Water Works and HV 5.2 Other Allied Agricultural use126
12.1.9.
Addition of apartments/ colonies/ townships in HV 6.2 Bulk Residential Use
127
12.1.10.
Rebate on energy charges for incremental load factor for HT consumers
127
12.1.11.
Rebate for online bill payment by HT consumers
127
12.1.12.
ToD surcharge reduced to 0% for HT consumers
127
12.1.13.
Additional Charges for energy for Excess Demand by HT consumers
127
12.1.14.
Rebate of 5 paise per unit for all domestic and non-domestic consumers having
prepaid meters
128
13.
Voltage-Wise Cost of Supply
126
129
13.1. Commission Directives
129
13.2. Voltage-wise Losses
130
13.2.1. Methodology
130
13.3. Calculation
131
13.4. Determination of Cross-Subsidy Surcharge
134
14.
135
Compliance on Tariff Order FY 2015-16
12
14.1.1.
Distribution losses
135
14.1.2.
Meterization of unmetered connections
139
14.1.3.
Capex plan for reduction in technical losses
141
14.1.4.
Segregation of rural feeders into agricultural and others
143
14.1.5.
Issue of tariff card with first bill based on new tariff
145
14.1.6.
Filing of ARR and tariff proposals in Hindi language
145
14.1.7.
Accounting of rebates/incentives/surcharge
146
14.1.8.
Maintaining uniform accounts
147
14.1.9.
Compliance of Regulations
148
14.1.10.
Mandatory demand based tariff for all Non-domestic LV consumers having load in
excess of 25 HP
148
14.1.11.
Assessment of consumption for billing to consumers
149
14.1.12.
Technical studies of the Distribution network to ascertain voltage-wise cost of
supply
149
15.
TARIFF SCHEDULES
153
Incentive/ Rebate / penalties
192
Other Terms and Conditions for permanent connections:
200
13
List of tables
Table 1: Sales for FY 2015-16 (Revised Estimates) and the MYT Period FY 2017 to FY 2019 ......... 17
Table 2: LV-1 Domestic Unit Projection ............................................................................................... 19
Table 3: LV-2 Non-Domestic Unit Projection....................................................................................... 22
Table 4: LV-3.1 PWW Unit Projection ................................................................................................. 24
Table 5: LV-3.2 Street Light Unit Projection ........................................................................................ 27
Table 6: LV-4.1 Non-Seasonal Industrial Unit Projection .................................................................... 30
Table 7: LV-4.2 Seasonal Industrial Unit Projection............................................................................. 33
Table 8: LV-5.1 Agriculture Unit Projection ......................................................................................... 35
Table 9: LV-5.2 Other allied Agriculture Unit Projection ..................................................................... 38
Table 10: HV-1 Railway Traction Projection ........................................................................................ 42
Table 11: HV-2 Coal Mines Projection ................................................................................................. 44
Table 12: HV-3 Industrial and Non-Industrial Projection ..................................................................... 45
Table 13: HV-4 Seasonal – Projections ................................................................................................. 49
Table 14: HV-5 Water Works, Lift Irrigation & Other allied Agricultural use – Projections ............... 51
Table 15: HV-6 Bulk Residential user – Projections ............................................................................. 55
Table 16: Month-Wise Sales Profiles of Discoms ................................................................................. 57
Table 17: MPPTCL Losses: Past Data from MP-SLDC ....................................................................... 57
Table 18: Loss level targets (%) for Discoms (as per MPERC regulations) ......................................... 58
Table 19: Monthly energy requirement at State Boundary (MU) for FY 17- FY 19 ............................ 59
Table 20: Ex-bus energy purchases to be done during MYT FY 17-19 ................................................ 64
Table 21: Stations with MP Share which are allocated to MP Discoms ............................................... 65
Table 22: Allocation percentage for FY 17 ........................................................................................... 67
Table 25: Past and Projected ex-bus availability of Stations with MP Share which are allocated to MP
Discoms (MU) ....................................................................................................................................... 69
Table 26: Stations allocated to MPPMCL – Existing and Capacity Addition till FY 19 ...................... 70
Table 27: Stations allocated to MPPMCL – Projected-Ex Bus Availability till FY’19 (MU) .............. 72
Table 28: Overall availability till FY’19 (MU) ..................................................................................... 73
Table 29: Management of Surplus Energy with Discoms for the MYT period FY 17-FY 19 .............. 75
Table 30: Ex-Bus Purchases by Discoms from Various Sources .......................................................... 76
Table 31: Fixed and Variable Costs of Discom Allocated Stations for MYT FY 2016-17 to FY 201819............................................................................................................................................................ 77
Table 32: Fixed and Variable Costs of MPPMCL allocated stations .................................................... 78
Table 33: MoD of station for FY 17 ...................................................................................................... 80
Table 34: Total Fixed Costs and Variable Costs of Discom Allocated Stations ................................... 82
Table 35: Total Fixed and Variable Costs of fixed and variable costs of MPPMCL allocated stations 85
Table 36: RPO Obligation for MYT FY 17-FY 19 ............................................................................... 87
Table 37: Inter-State Transmission Charges .......................................................................................... 88
Table 38: Intra-state Costs – excluding Terminal Benefits ................................................................... 89
Table 39: Total Intra-State Transmission Costs and Allocation to Discoms (Rs Cr) ............................ 90
Table 40: MPPMCL Costs: Details and Discoms Allocation (Rs Cr) ................................................... 90
Table 41: Total Power Purchase Costs - FY'17 to FY'19 ...................................................................... 91
14
Table 42: Employee Cost ....................................................................................................................... 93
Table 43: Administrative and General Expenses-As per Regulation (Rs. Cr.) ..................................... 94
Table 44: Repair and Maintenance Expenses-As per Regulation (Rs. Cr.) ........................................... 94
Table 45: Gist of O&M expenses-As per Regulation (Rs. Crores) ....................................................... 94
Table 46: Capital expenditure Plan (Rs. Crores) ................................................................................... 95
Table 47: Scheme Wise Capitalization (Rs. Crores) ............................................................................. 96
Table 48: CWIP (Rs. Cr.) ...................................................................................................................... 97
Table 49: Fixed Assets Addition (Rs. Cr.)............................................................................................. 98
Table 50: Depreciation – as per regulation (Rs. Cr.) ............................................................................. 99
Table 51: Interest on Project Loans (Rs. Cr.) ........................................................................................ 99
Table 52: Interest on Working Capital (Rs. Cr.) .................................................................................. 101
Table 53: Interest on consumer security deposit as per regulation (Rs. Crores) ................................. 103
Table 54: Other Income (Rs. Cr.) ........................................................................................................ 104
Table 55: Return on equity as per regulation (Rs. Crores) .................................................................. 105
Table 56: Bad and Doubtful Debts – As per regulation (Rs. Crores) .................................................. 106
Table 60: Employee particulars ........................................................................................................... 111
Table 61: Employee expenses (Rs. Cr.) ............................................................................................... 111
Table 62: Summary of ARR for MPPMCL (Rs. Cr.) .......................................................................... 113
Table 63: Summary of ARR of Discoms as per the Regulation (Rs. Crores) ..................................... 114
Table 64: Future Contribution rate of liability on account of Actuary ................................................ 116
Table 65: Calculation of Terminal Benefits Provisions (Rs. Crores) .................................................. 116
Table 66: Terminal Benefits Provisions Liability for Discoms (Rs. Cr.) ............................................ 118
Table 67: Summary of proposed tariff for FY 2016-17 ....................................................................... 123
Table 68: Category-wise proposed revenue for FY 2016-17............................................................... 124
Table 69: Cost of Supply Calculation for East Discom for FY17 ....................................................... 131
Table 70: Cost of Supply Calculation for Central Discom for FY17 .................................................. 132
Table 71: Cost of Supply Calculation for West Discom for FY17 ...................................................... 132
Table 72: Cost of Supply Calculation for MP State for FY17 ............................................................. 133
15
1. Estimation of sales
1.1 Method adopted for Estimation of Sales
For the purpose of projection of sales, the distribution licensees have 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. FY 2011-12, FY 2012-13, FY 2013-14 and FY 2014-15 and available
data of the FY 2015-16 i.e. up to the month of September 2015.
The licensees, in the previous year’s filing for FY 2015-16, had projected the Sales based on the
actual data of FY 2013-14. Since the actual data of FY 2014-15 is now available and it has been
observed that the actual sales during FY 2014-15 have deviated significantly from the sales forecasted
by the Licensee and those allowed by the Hon’ble Commission during the previous filings, the
licensees feel that it will be appropriate to revise the sales forecast for FY 2015-16 and thereafter
project the sales for FY 2016-17.
The sales for FY 2016-17 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 FY 2015-16.
The approach being followed is to analyze 3 year and 2 year Compound Annual Growth Rates
(CAGRs) and year on year growth rate of each category and its sub-categories in respect of urban &
rural consumers separately. After analysis of the data, appropriate / reasonable growth rates have been
assumed for future consumer forecasts from the past CAGRs of the Category/Sub-category by the
three Discoms.
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 variable and 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
the trends and variations in the usage of electricity over a growth cycle more precisely. This method
has been recommended by the C.E.A. also.
The forecast also considers the impact of schemes / plans of licensee such as the RGGVY (Rajiv
Gandhi Grameen Vidyutikaran Yojana and separation of feeders of Agricultural and other categories
of consumers and increase in supply hours in rural areas. The projections for each tariff category and
the relevant assumptions of the three Discoms have been discussed in the following sections. The
overall sales forecast is as follows:
16
Table 1: Sales for FY 2015-16 (Revised Estimates) and the MYT Period FY 2017 to FY 2019
TC
LV 1
LV 2
LV 3.1
LV 4
LV 5.1
LV 5.3
Category
FY 16
3,695
756
530
327
4,665
12
9,985
614
485
2,529
225
7
67
10
84
Domestic
Non-Domestic
WW & Street Light
LT Industrial
Agriculture Irrigation Pumps
Agriculture related Use
Total (LT)
HV 1
Railway Traction
HV 2
Coal Mines
HV 3.1
Industrial
HV 3.2
Non-Industrial
HV 3.3
Shopping Mall
HV 3.4
Power Intensive industries
HV 4
Seasonal
HV 5.1
Public Water Works and
Irrigation
HV 5.2
Other Agricultural
14
HV 6
Bulk Residential Users
291
HV 7
RECS/Start-up Power
0
Total (HT)
4,326
TOTAL LT+HT
14,311
* Digits rounded off to the nearest integer
East Discom
FY 17 FY 18
4,294
5,106
848
952
596
672
363
406
4,877
5,106
15
19
10,993 12,262
672
736
504
525
2,826
3,163
242
260
7
8
74
81
11
12
92
100
FY 19
6,157
1,070
759
459
5,347
24
13,816
807
547
3,543
279
9
90
13
109
FY 16
3,512
784
343
271
4,377
29
9,317
1,039
35
2,140
405
0
0
2
155
Central Discom
FY 17 FY 18
4,039
4,557
901
1,040
407
490
301
334
4,940
5,632
35
42
10,623 12,096
1,195
1,375
35
35
2,387
2,675
439
476
0
0
0
0
2
2
163
171
FY 19
5,275
1,202
601
372
6,499
51
13,999
1,581
35
3,010
517
0
0
3
180
FY 16
3,559
845
364
550
7,119
2
12,439
434
0
2,474
375
42
204
5
387
West Discom
FY 17 FY 18
3,858
4,241
911
983
401
442
584
620
8,079
8,858
2
2
13,835 15,146
434
434
0
0
2,474
2,474
375
375
42
42
204
204
5
6
387
387
FY 19
4,634
1,060
487
659
9,727
2
16,570
434
0
2,474
375
42
204
6
387
FY 16
10,767
2,386
1,238
1,147
16,161
43
31,741
2,087
520
6,961
986
67
454
17
626
MP State
FY 17 FY 18
12,192 13,904
2,660
2,975
1,404
1,604
1,247
1,360
17,896 19,597
52
63
35,451 39,503
2,301
2,545
539
560
7,494
8,107
1,036
1,089
69
71
471
490
18
20
642
659
FY 19
16,067
3,332
1,847
1,490
21,572
77
44,385
2,821
582
8,810
1,147
74
512
21
677
16
292
0
4,736
15,730
21
295
0
5,713
19,529
7
163
0
3,947
13,264
7
177
0
4,406
15,029
9
209
0
5,543
19,542
6
31
1
3,959
16,397
6
31
1
3,959
17,793
6
31
1
3,959
20,529
27
485
1
12,231
43,972
30
500
1
13,101
48,552
36
534
1
15,215
59,600
18
293
0
5,196
17,458
8
192
0
4,935
17,030
6
31
1
3,959
19,105
33
516
1
14,090
53,593
17
1.2 Category-wise sales projection
1.2.1. LV -1: Domestic
1.2.1.1.
Assumptions for Projecting Unmetered Domestic Sales
In the tariff order for FY 2014-15, Hon’ble Commission had revised the benchmark of billing to unmetered domestic connections in rural areas to 75 units
per month per connection and had continued the same for FY 2015-16 and ensuing years also. Therefore, the petitioners have considered the same for
projecting consumption of unmetered domestic connections.
The projections of consumption of un-metered domestic connections in this petition have been considered as NIL for urban areas (since all domestic
consumers in urban areas have been metered).
1.2.1.2.
RGGVY
In addition to the growth rate assumed for domestic category, the impact of implementation of RGGVY has also been taken into account for future
consumer/load/consumption projections for Central Discom. The implementation roadmap of RGGVY forms the basis of future projections by the Central
Discom. While no consumers and consumption has been estimated for East and West Discoms separately for RGGVY. However, the same has not been
projected separately, but has been included in the overall projection for Domestic category. For Central Discom 1.2 lakh consumers and corresponding
sales of 12.51 MUs for FY 2016-17 have been projected.
After factoring the growth in consumers the following projections has been arrived at for LV-1 category:
18
Table 2: LV-1 Domestic Unit Projection
Area
Urban
Urban
Urban
Urban
Rural
Rural
Rural
Rural
Total
Total
Total
Total
Sub Category
Metered
Un-metered
Temporary
Total
Metered
Un-metered
Temporary
Total
Metered
Un-metered
Temporary
Total
FY 16
1,900
1
18
1,919
1,455
320
2
1,777
3,354
321
20
3,695
East Discom
FY 17 FY 18
2,057
2,225
0
0
18
18
2,074
2,243
2,058
2,781
160
80
2
2
2,220
2,864
4,115
5,006
160
80
20
20
4,294
5,106
FY 19
2,407
0
18
2,425
3,691
40
2
3,733
6,097
40
20
6,157
FY 16
2,508
2
16
2,525
1,029
134
1
1,164
3,360
136
17
3,512
Central Discom
FY 17 FY 18
2,522
2,729
0
0
16
17
2,539
2,746
1,432
1,742
67
67
2
2
1,500
1,811
3,954
4,471
67
67
18
19
4,039
4,557
FY 19
2,953
0
17
2,970
2,302
0
3
2,305
5,254
0
20
5,275
FY 16
2,086
0
20
2,106
1,372
79
2
1,453
3,458
80
21
3,559
West Discom
FY 17 FY 18
2,175
2,268
0
0
21
22
2,196
2,290
1,621
1,910
40
40
2
2
1,662
1,951
3,796
4,177
40
40
22
24
3,858
4,241
FY 19
2,364
0
24
2,388
2,245
0
2
2,246
4,609
0
25
4,634
FY 16
6,317
3
53
6,373
3,856
533
5
4,394
10,172
536
58
10,767
MP State
FY 17 FY 18
6,754
7,222
0
0
55
57
6,809
7,279
5,110
6,433
267
187
5
6
5,382
6,626
11,865 13,655
267
187
60
63
12,192 13,904
FY 19
7,724
0
59
7,783
8,237
40
7
8,284
15,961
40
66
16,067
1.2.1.3.East Discom
The growth percentages assumed for the category for the MYT period are as shown below:
Area
Category
Urban
Growth rate
Metered
Temporary
Growth rate
Consumer
5.42%
2 year CAGR has been considered
Average Load (kW) per Consumer
0.00%
Current year load from Apr'15 to Sep'15
has been considered
2.61%
YoY growth rate has been considered
0.00%
No growth rate has been considered
has been considered
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
Average consumption per consumer
per month
Consumer
Un-metered
Description
Rural
Description
Average Load per Consumer (in kW)
per month
Consumer
Average Load per Consumer (in kW)
0.00%
15.00%
Nominal growth rate has been considered
0.00%
has been considered
13.83%
0.00%
has been considered
19
Area
Category
Urban
Description
has been considered
Growth rate
per month
0.00%
Growth rate
0.00%
Rural
Description
has been considered
1.2.1.4 Central Discom
The growth percentages assumed for the category are as shown below
Area
Category
Growth rate
Consumer
Metered
Average Load (kW) per
Consumer
Average consumption per
consumer per month
Un-metered
Temporary
Consumer
Average Load per
Consumer (in kW)
Urban
Description
Current year growth rate has been
5.96%
considered
No growth rate has been
0.00%
considered
2.11%
considered
0.00%
0.00%
consumer per month
0.00%
Consumer
3.43%
Average Load per
Consumer (in kW)
0.00%
consumer per month
0.00%
Growth rate
Rural
Description
3 year CAGR has been
9.86%
considered
0.00%
considered
15.01%
considered
0.00%
All unmetered consumers are
expected to be metered by the
FY16
YoY growth rate has been
considered
0.00%
0.00%
41.95%
All unmetered consumers are
expected to be metered by the
FY16
considered
0.00%
considered
0.00%
considered
20
1.2.1.5 West Discom
The growth percentages assumed for the category are as shown below:
Area
Category
Urban
Growth rate
Consumer
Metered
Average Load (kW) per
Consumer
Average consumption
per consumer per
month
Consumer
Un-metered
Average Load per
Consumer (in kW)
Average consumption
per consumer per
month
Consumer
Temporary
Average Load per
Consumer (in kW)
Average consumption
per consumer per
month
Description
Rural
Growth rate
Description
4.25%
2 year CAGR has been considered has been
considered
0.00%
Current year load from Apr'15 to Aug'15 has been
considered
0.00%
considered
0.00%
0.00%
No growth rate has been considered has been
considered
0.00%
0.00%
0.00%
considered
0.00%
considered
0.00%
0.00%
6.59%
considered
0.00%
0.00%
considered
0.00%
considered
0.00
10.76%
0.00
YoY growth has been considered has been
considered
21
1.2.2. LV -2: Non-Domestic
The future projections are as below
Table 3: LV-2 Non-Domestic Unit Projection
Sub Category
Metered
Temporary
Total
East Discom
FY 16
735
22
756
FY 17
826
22
848
FY 18
930
22
952
Central Discom
FY 19
1,048
22
1,070
FY 16
735
49
784
FY 17
852
50
901
FY 18
990
51
1,040
West Discom
FY 19
1,150
52
1,202
FY 16
806
39
845
FY 17
872
39
911
FY 18
944
39
983
MP State
FY 19
1,021
39
1,060
FY 16
2,276
110
2,386
FY 17
2,550
110
2,660
FY 18
2,863
111
2,975
FY 19
3,220
112
3,332
1.2.2.1.East Discom
Area
Category
Urban
Growth rate
Metered
Temporary
Consumer
Average consumption per kW per month
Consumer
4.07%
3.43%
2.52%
0.00%
0.00%
Average consumption per consumer per
month
0.00%
Description
Rural
Growth rate
8.24%
2.72%
6.87%
0.00%
0.00%
Description
0.00%
22
1.2.2.2.Central Discom
Area
Category
Growth rate
Metered
Consumer
3.78%
6.91%
5.00%
Consumer
0.00%
Urban
Description
considered
Rural
Description
Growth rate
3.93%
YoY growth has been considered
4.66%
5.00%
Nominal growth rate has been
considered
5.00%
Nominal growth has been considered
Temporary
0.00%
month
1.48%
0.00%
0.00%
1.2.2.3.West Discom
Area
Category
Urban
Growth rate
Metered
Temporary
Consumer
3.39%
Average consumption per kW per
month
Consumer
5.16%
Description
considered
Current year growth has been considered
0.00%
month
0.00%
0.00%
0.00%
Growth rate
4.00%
0.00%
1.46%
0.00%
0.00%
Rural
Description
considered
considered
0.00%
23
1.2.3. LV -3.1: Public Water Works
Considering the anticipated increase in supply hours, the future projections are as follows:
Table 4: LV-3.1 PWW Unit Projection
Sub Category
Municipal Corp.
Nagar Panchayat
Gram Panchayat
Temporary
Total
FY 16
50
63
230
6
350
East Discom
FY 17
FY 18
53
55
70
77
256
285
6
6
384
423
FY 19
57
86
317
6
466
FY 16
79
82
69
4
233
Central Discom
FY 17
FY 18
82
85
92
104
101
149
5
6
280
344
FY 19
89
117
220
7
433
FY 16
41
56
117
5
220
West Discom
FY 17
FY 18
46
51
61
65
130
145
5
5
241
265
FY 19
56
70
161
5
292
FY 16
170
201
417
15
803
MP State
FY 17
FY 18
180
191
222
246
488
579
16
17
906
1,033
FY 19
202
273
698
18
1,191
1.2.3.1.East Discom
Area
Category
Urban
Growth rate
Municipal Corporation
Nagar Panchayat
Gram Panchayat
Description
Rural
Growth rate
Description
Consumer
1.33%
0.00%
2.77%
9.50%
0.00%
0.00%
Consumer
5.55%
considered
15.53%
4.33%
3.82%
considered
month
0.00%
0.00%
Consumer
0.00%
6.22%
4.44%
5.31%
considered
24
Area
Category
Urban
Growth rate
Temporary
month
Consumer
Description
Rural
Growth rate
Description
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
1.2.3.2. Central Discom
Area
Category
Consumer
Nagar Panchayat
Temporary
Growth rate
0.00%
1.00%
3.37%
0.00%
Consumer
6.80%
0.00%
0.38%
0.00%
month
4.95%
18.99%
19.98%
12.62%
3.07%
0.00%
month
8.18%
32.04%
Consumer
0.00%
0.00%
Consumer
Gram Panchayat
Growth rate
0.00%
Urban
Description
considered
0.00%
Rural
Description
considered
considered
considered
considered
25
Area
Category
Growth rate
Urban
Description
Growth rate
8.45%
Rural
Description
0.00%
month
13.88%
0.00%
1.2.3.3. West Discom
Area
Category
Growth rate
Nagar Panchayat
Gram Panchayat
Temporary
Consumer
4.60%
5.71%
month
0.00%
Consumer
6.91%
1.62%
per month
0.00%
Consumer
2.40%
per month
Consumer
per month
10.12%
8.93%
0.00%
0.00%
0.00%
Urban
Description
2 year CAGR has been considered has
been considered
Current year growth has been
considered
been considered
considered
been considered
considered
been considered
Growth rate
0.00%
0.05%
10.00%
Rural
Description
been considered
has been considered
0.00%
0.00%
0.00%
9.29%
0.52%
been considered
0.00%
0.00%
0.00%
0.00%
26
1.2.4. LV -3.2: Street Light
Considering the anticipated increase in supply hours, the future projections are as below:
Table 5: LV-3.2 Street Light Unit Projection
Sub Category
Municipal Corp.
Nagar Panchayat
Gram Panchayat
Total
FY 16
70
51
60
180
East Discom
FY 17
FY 18
84
101
57
64
71
84
212
249
FY 19
121
72
99
293
FY 16
48
57
5
110
Central Discom
FY 17
FY 18
53
57
68
81
6
8
127
146
FY 19
63
96
10
168
FY 16
58
37
49
145
West Discom
FY 17
FY 18
65
72
41
46
54
59
160
176
FY 19
80
50
65
195
FY 16
176
145
114
435
MP State
FY 17
FY 18
201
230
166
190
131
151
498
571
FY 19
263
218
174
656
1.2.4.1.East Discom
The growth percentages assumed for the category are as shown below.
Area
Category
Urban
Growth rate
Nagar Panchayat
Consumer
8.87%
2.36%
7.93%
Consumer
4.21%
7.83%
considered
month
Consumer
Gram Panchayat
Description
considered
month
Rural
Growth rate
0.00%
Description
0.00%
considered
15.07%
10.92%
20.00%
0.00%
0.00%
0.00%
0.00%
19.46%
13.49%
0.00%
4.14%
27
Area
Category
Urban
Growth rate
Nagar Panchayat
Gram Panchayat
Description
Rural
Growth rate
Consumer
4.25%
considered
0.00%
0.02%
0.00%
4.69%
considered
Consumer
6.61%
month
Description
10.00%
0.00%
1.10%
6.06%
10.10%
4.86%
Consumer
32.00%
2.54%
16.29%
considered
4.61%
month
0.00%
No growth has been considered
10.00%
considered
28
1.2.4.3.West Discom
Area
Category
Urban
Growth rate
month
0.00%
Description
considered
0.00%
Consumer
9.85%
0.64%
Consumer
Nagar Panchayat
per month
Consumer
Gram Panchayat
per month
10.96%
0.00%
been considered
been considered
0.00%
0.00%
0.00%
Rural
Growth rate
0.00%
0.00%
0.00%
0.00%
5.87%
2.00%
0.00%
Description
0.00%
10.00%
considered
has been considered
has been considered
29
1.2.5. LV -4.1: Non- Seasonal Industrial
The future projections are as below:
Table 6: LV-4.1 Non-Seasonal Industrial Unit Projection
Sub Category
Upto 25HP
Above 25HP to 100HP
Above 100HP
Temporary
Total
FY 16
168
127
17
10
322
East Discom
FY 17
FY 18
178
189
149
178
20
24
10
10
358
401
FY 19
200
213
29
10
453
FY 16
155
93
6
2
255
Central Discom
FY 17
FY 18
169
184
105
118
7
7
2
3
282
313
FY 19
202
134
8
3
347
FY 16
249
228
61
2
540
West Discom
FY 17
FY 18
259
270
245
263
68
75
2
2
574
610
FY 19
281
283
84
2
649
FY 16
572
447
84
14
1,117
MP State
FY 17
FY 18
606
643
499
559
95
107
14
15
1,214
1,324
FY 19
683
630
121
16
1,449
1.2.5.1.East Discom
The assumptions for sales forecast for the category are given below:
Area
Category
Upto 25HP
Above 25HP to 100HP
Consumer
Temporary
Urban
Description
Growth rate
5.48%
1.17%
0.26%
0.78%
Consumer
8.39%
0.16%
15.63%
3.53%
1.09%
Consumer
Above 100HP
Growth rate
2.91%
1.08%
10.00%
0.00%
6.90%
Consumer
0.00%
considered
considered
Rural
Description
11.83%
20.00%
2.66%
considered
considered
0.00%
0.00%
30
Area
Category
Urban
Growth rate
0.00%
Description
0.00%
Growth rate
0.00%
Rural
Description
0.00%
The growth percentages assumed are as follows
Area
Category
Urban
Growth rate
Upto 25HP
Above 25HP to 100HP
Above 100HP
Temporary
Consumer
7.10%
month
1.02%
Description
considered
0.00%
Consumer
9.64%
month
Consumer
month
0.34%
considered
1.26%
Rural
Growth rate
Description
4.88%
1.11%
5.54%
11.24%
0.53%
8.84%
8.74%
1.48%
14.47%
0.00%
0.00%
10.00%
Consumer
5.73%
30.00%
month
0.00%
0.00%
5.53%
10.00%
Nominal growth has been
considered
considered
Nominal growth has been
considered
31
1.2.5.3.West Discom
The growth percentages assumed are as follows:
Area
Category
Urban
Growth rate
Upto 25HP
Description
Rural
Growth rate
Description
Consumer
2.56%
4.97%
0.24%
0.16%
month
0.00%
1.91%
Consumer
7.55%
3.71%
Current year growth has been considered has
been considered
Above 25HP to 100HP
0.00%
1.88%
month
Consumer
Above 100HP
Temporary
0.00%
10.00%
0.00%
considered
1.00%
1.44%
0.00%
month
0.00%
0.00%
Consumer
0.00%
0.00%
month
0.00%
0.00%
0.00%
0.00%
32
1.2.6. LV -4.2: Seasonal Industrial
The future projections are as follows:
Table 7: LV-4.2 Seasonal Industrial Unit Projection
Sub Category
Upto 25HP
Above 25HP to 100HP
Above 100HP
Total
FY 16
2
2
1
5
East Discom
FY 17
FY 18
2
2
2
3
1
1
5
5
FY 19
2
3
1
6
FY 16
11
4
1
16
Central Discom
FY 17
FY 18
13
16
4
5
1
1
18
21
FY 19
19
5
1
25
FY 16
3
7
0
10
West Discom
FY 17
FY 18
3
3
7
7
0
0
10
10
FY 19
3
7
0
10
FY 16
16
13
2
30
MP State
FY 17
FY 18
18
20
13
14
2
2
33
37
FY 19
24
15
3
41
1.2.6.1.East Discom
The growth percentages assumed are as follows:
Area
Category
Urban
Growth rate
Upto 25HP
Above 25HP to 100HP
Above 100HP
Description
Rural
Growth rate
Consumer
0.00%
0.00%
Consumer
3.18%
0.00%
9.78%
0.00%
2.04%
2.29%
5.00%
considered
6.43%
0.00%
0.00%
0.00%
0.00%
considered
0.00%
month
Consumer
month
20.00%
Description
0.00%
0.00%
33
The growth percentages assumed are as follows
Area
Category
Growth rate
0.00%
Description
Growth rate
0.00%
0.00%
10.00%
2.84%
15.01%
Consumer
month
Consumer
0.00%
0.09%
considered
considered
0.00%
1.96%
Consumer
Upto 25HP
Above 25HP to
100HP
Above 100HP
Urban
month
10.00%
0.00%
0.26%
23.59%
10.00%
Rural
Description
considered
considered
0.00%
0.00%
0.00%
1.2.6.3.West Discom
Nominal growth rate of 5% has been considered for projecting number of consumers @ load of above 25 HP. For the other categories no growth rate has been
considered.
34
1.2.7. LV -5.1: Agricultural
The projections for LV 5.1 Agricultural category are as follows
Table 8: LV-5.1 Agriculture Unit Projection
Area
Urban
Urban
Urban
Urban
Urban
Rural
Rural
Rural
Rural
Rural
Total
Total
Total
Total
Total
Sub Category
Metered General
Metered Temporary
Unmetered General
Unmetered Temporary
Total
Metered General
Metered Temporary
Unmetered General
Unmetered Temporary
Total
Metered General
Metered Temporary
Unmetered General
Unmetered Temporary
Total
FY 16
3
2
320
14
339
3
67
3,975
281
4,326
6
69
4,296
295
4,665
East Discom
FY 17 FY 18
3
3
2
2
327
333
16
17
348
355
3
3
67
67
4,173
4,382
286
300
4,529
4,752
6
6
69
69
4,500
4,715
302
317
4,877
5,106
FY 19
3
2
340
17
362
3
67
4,600
315
4,985
6
69
4,940
332
5,347
FY 16
2
2
202
21
227
28
0
3,615
507
4,150
30
2
3,818
528
4,377
Central Discom
FY 17 FY 18
2
2
2
2
214
227
21
21
239
252
30
33
0
0
4,164
4,841
507
507
4,702
5,381
33
36
2
2
4,378
5,067
528
528
4,940
5,632
FY 19
2
2
240
21
266
36
0
5,689
507
6,233
39
2
5,930
528
6,499
FY 16
0
1
235
16
251
0
0
6,222
646
6,867
0
1
6,457
661
7,119
West Discom
FY 17 FY 18
0
0
1
1
291
361
16
16
307
377
0
0
0
0
7,126
7,835
646
646
7,771
8,481
0
0
1
1
7,417
8,196
661
661
8,079
8,858
FY 19
0
1
449
16
465
0
0
8,616
646
9,261
0
1
9,065
661
9,727
FY 16
5
4
758
51
818
30
67
13,812
1,433
15,343
36
71
14,570
1,484
16,161
MP State
FY 17 FY 18
5
5
4
4
832
921
53
53
894
984
33
36
67
67
15,463 17,057
1,438
1,453
17,002 18,613
38
41
71
71
16,295 17,978
1,491
1,506
17,896 19,597
FY 19
5
4
1,030
54
1,093
39
67
18,905
1,468
20,479
44
71
19,935
1,521
21,572
For unmetered temporary agriculture consumers under this category, the assessed consumption is considered as per the norms stipulated by Hon’ble Commission
in the tariff order for FY 2015-16. The same is shown as below:
Three Phase
Single Phase
Urban
2015-16
220
230
Urban
2016-17
220
230
Rural
2015-16
195
205
Rural
2016-17
195
205
35
1.2.7.1.East Discom
The growth rates assumed for future projections and revised estimates for this category by East Discom are as follows:
Area
Category
Urban
Growth rate
Consumer
Metered General
Unmetered Permanent
Metered Temporary
Description
Growth rate
0.00%
Load
Consumption per HP
Consumer
Load
Consumption per HP
Consumer
Load/ consumer
Consumption per HP
0.00%
0.00%
5.00%
2.00%
0.00%
0.00%
0.00%
0.00%
Rural
Description
0.00%
0.00%
0.00%
4.70%
4.99%
0.00%
0.00%
0.00%
0.00%
Average growth across all slabs
The growth rates assumed for future projections and revised estimates for this category by Central Discom are as follows:
Area
Category
Urban
Description
Growth rate
Metered General
Unmetered Permanent
Metered Temporary
Unmetered Temporary
Consumer
Load
Consumption per HP
Consumer
Load
29.07%
29.15%
0.00%
19.78%
5.71%
Consumption per HP
0.00%
Consumer
Load/ consumer
Consumption per HP
Consumer
Load/ consumer
Consumption per HP
42.52%
8.29%
4.45%
0.00%
0.00%
0.00%
Average growth across all load slabs
No growth considered. As per MPERC
norm
Rural
Description
Growth rate
0.16%
0.00%
9.73%
22.07%
15.19%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
No growth considered. As per MPERC
norm
36
1.2.7.3.West Discom
The growth rates assumed for future projections and revised estimates for this category by West Discom are as follows:
Area
Category
Urban
Description
Growth rate
Metered General
Unmetered
Permanent
Metered Temporary
Consumer
Load
Consumption per HP
Consumer
Load
Consumption per HP
Consumer
Load/ consumer
Consumption per HP
0.00%
0.00%
0.00%
4.25%
23.79%
23.79%
0.00%
0.00%
0.00%
Rural
Description
Growth rate
0.00%
0.00%
0.00%
4.09%
9.95%
14.53%
0.00%
0.00%
0.00%
37
1.2.8. LV -5.2: Other allied agricultural Use
The month-wise segregation of norms for assessed consumption of unmetered permanent agricultural connections are as shown below
Months
April
May
June
July
Aug
Sept
Oct
Nov
Dec
Jan
Feb
March
Urban
2015-16
90
90
90
90
90
90
170
170
170
170
170
170
Three Phase
Urban
Rural
2016-17 2015-16
90
80
90
80
90
80
90
80
90
80
90
80
170
170
170
170
170
170
170
170
170
170
170
170
Rural
2016-17
80
80
80
80
80
80
170
170
170
170
170
170
Urban
2015-16
90
90
90
90
90
90
180
180
180
180
180
180
Single Phase
Urban
Rural
2016-17 2015-16
90
90
90
90
90
90
90
90
90
90
90
90
180
180
180
180
180
180
180
180
180
180
180
180
Rural
2016-17
90
90
90
90
90
90
180
180
180
180
180
180
The projections for LV 5.2 Agricultural category are as follows
Table 9: LV-5.2 Other allied Agriculture Unit Projection
Sub Category
Upto 25HP
25HP to 100HP
Temporary
Total
FY 16
11
0
1
12
East Discom
FY 17
FY 18
14
18
0
0
1
1
15
19
FY 19
24
0
1
24
FY 16
28
0
1
29
Central Discom
FY 17
FY 18
34
41
0
0
1
1
35
42
FY 19
50
0
1
51
FY 16
2
0
0
2
West Discom
FY 17
FY 18
2
2
0
0
0
0
2
2
FY 19
2
0
0
2
FY 16
41
0
2
43
MP State
FY 17
FY 18
50
61
0
0
2
2
52
63
FY 19
75
0
2
77
38
1.2.8.1. East Discom
Area
Category
Urban
Growth rate
Consumer
Upto 3HP
Consumer
Above 3HP to 5HP
Above 5HP to 10HP
month
Consumer
month
Consumer
Above 10HP to 20HP
Above 20HP
Temporary
month
Consumer
month
Consumer
month
13.14%
0.00%
0.00%
12.50%
Description
considered
considered
0.00%
0.00%
17.57%
16.67%
15.47%
considered
0.00%
0.00%
0.00%
25.81%
0.00%
35.99%
0.00%
10.00%
considered
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
10.00%
0.00%
0.00%
0.00%
Growth rate
Rural
Description
considered
0.00%
25.99%
0.00%
0.00%
0.00%
0.00%
0.00%
39
Area
Category
Urban
Growth rate
Consumer
Upto 3HP
0.00%
0.00%
Consumer
Above 3HP to 5HP
month
Consumer
Above 5HP to 10HP
Above 10HP to 20HP
Above 20HP
Temporary
20.00%
25.00%
Description
considered
considered
0.00%
0.00%
17.65%
Growth rate
20.00%
0.00%
0.00%
20.00%
0.00%
20.00%
0.00%
Consumer
0.00%
month
0.00%
0.00%
0.00%
Consumer
0.00%
0.00%
month
Consumer
month
0.00%
0.00%
considered
considered
0.00%
0.00%
20.00%
0.00%
14.29%
0.00%
0.00%
month
0.00%
Rural
Description
considered
considered
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
40
1.2.8.3. West Discom
The growth rates assumed for future projections and revised estimates for this category by West Discom are as follows:
Area
Category
Urban
Growth rate
Upto 3HP
Consumer
5.00%
0.00%
Description
considered
Rural
Growth rate
Description
0.00%
0.00%
Above 3HP to 5HP
Above 5HP to 10HP
0.00%
0.00%
Consumer
0.00%
0.00%
0.00%
month
0.00%
Consumer
5.00%
0.00%
month
Consumer
Above 10HP to 20HP
Above 20HP
Temporary
0.00%
considered
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
month
0.00%
Consumer
5.00%
0.00%
0.00%
month
Consumer
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
5.00%
0.00%
0.00%
0.00%
41
Area
Category
Urban
Growth rate
month
Rural
Description
Growth rate
0.00%
Description
0.00%
1.2.9. HV -1: Railway Traction
The projection of sales for this category is as follows:
Table 10: HV-1 Railway Traction Projection
HV-1 Railway Traction
FY 16
614
East Discom
FY 17
FY 18
672
736
FY 19
807
FY 16
1,039
Central Discom
FY 17
FY 18
1,195
1,375
FY 19
1,581
FY 16
434
West Discom
FY 17
FY 18
434
434
FY 19
434
FY 16
2,087
MP State
FY 17
FY 18
2,301
2,545
FY 19
2,821
1.2.9.1.East Discom
Area
Category
Urban
Description
Growth rate
220 kV
Consumer
Load (kW)
Units (MUS)
132 kV
0.00%
0.00%
10.14%
Rural
Description
Growth rate
0.00%
0.00%
0.00%
Consumer
Load (kW)
0.00%
0.00%
0.00%
0.00%
Units (MUS)
7.71%
0.00%
42
Area
Category
Urban
Description
Growth rate
220 kV
132 kV
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Units (MUS)
0.00%
0.00%
15.00%
0.00%
0.00%
15.00%
Rural
Description
Growth rate
0.00%
0.00%
15.00%
0.00%
0.00%
15.00%
1.2.9.3.West Discom
It has been assumed that no growth would be considered to forecast sales for the Railway Traction category HV 1.
43
1.2.10. HV -2: Coal Mines
The projection of sales for this category is as shown below:
Table 11: HV-2 Coal Mines Projection
Sub Category
132 kV
33 kV
11 kV
Total
FY 16
207
274
4
485
East Discom
FY 17
FY 18
225
244
275
277
4
4
504
525
FY 19
264
279
4
547
FY 16
0
34
1
35
Central Discom
FY 17
FY 18
0
0
34
34
1
1
35
35
FY 19
0
34
1
35
FY 16
0
0
0
0
West Discom
FY 17
FY 18
0
0
0
0
0
0
0
0
FY 19
0
0
0
0
FY 16
207
307
5
520
MP State
FY 17
FY 18
225
244
309
311
5
6
539
560
FY 19
264
312
6
582
1.2.10.1.
East Discom
Growth rate of 8.48% (current year growth rate) for urban consumption @ 132 kV and 2.13% (current year growth rate) for rural consumption @ 33 kV have
been considered to project consumption for FY 2016-17 to FY 2018-19. For other categories, no growth rate has been considered.
1.2.10.2.
Central Discom
Growth rate of 2.52% (current year growth rate) for urban load @ 33 kV and 2.95% (YoY growth rate) for urban consumption @ 11 kV has been considered,
while for other categories, no growth rate has been considered.
1.2.10.3.
West Discom
No growth rate has been considered to project consumption for FY 2016-17.
44
1.2.11. HV-3: Industrial and Non-Industrial
Table 12: HV-3 Industrial and Non-Industrial Projection
Sub Category
Industrial Unit (MU)
Non
Industrial Unit (MU)
Shopping
Mall (MU)
Power
Intensive
Industries
(MU)
220 kV
132 kV
33 kV
11 kV
Total
132 kV
33 kV
11 kV
Total
132 kV
33 kV
11 kV
Total
132 kV
33 kV
Total
FY 16
153
1,800
466
109
2,529
0
138
88
225
0
7
0
7
0
67
67
East Discom
FY 17
FY 18
153
153
2,038
2,307
515
568
121
134
2,826
3,163
0
0
148
159
94
101
242
260
0
0
7
8
0
0
7
8
0
0
74
81
74
81
FY 19
153
2,614
628
148
3,543
0
171
108
279
0
8
0
9
0
90
90
FY 16
0
919
1,172
49
2,140
0
293
113
405
0
0
0
0
0
0
0
Central Discom
FY 17
FY 18
0
0
1,094
1,304
1,240
1,314
53
57
2,387
2,675
0
0
315
340
124
136
439
476
0
0
0
0
0
0
0
0
0
0
0
0
0
0
FY 19
0
1,553
1,395
62
3,010
0
367
150
517
0
0
0
0
0
0
0
FY 16
0
184
2,147
142
2,474
40
221
114
375
0
25
17
42
178
26
204
West Discom
FY 17
FY 18
0
0
184
184
2,147
2,147
142
142
2,474
2,474
40
40
221
221
114
114
375
375
0
0
25
25
17
17
42
42
178
178
26
26
204
204
FY 19
0
184
2,147
142
2,474
40
221
114
375
0
25
17
42
178
26
204
FY 16
153
2,903
3,786
301
7,143
40
651
314
1,005
0
31
17
49
178
93
271
MP State
FY 17
FY 18
153
153
3,316
3,795
3,902
4,030
316
333
7,687
8,311
40
40
684
720
332
351
1,056
1,111
0
0
32
32
17
18
49
50
178
178
100
108
278
286
FY 19
153
4,351
4,171
352
9,027
40
758
373
1,171
0
33
18
50
178
116
294
45
1.2.11.1.
East Discom
The assumptions for sales forecast for the Industrial category HV 3.1 are as given below:
Area
Category
440/220 kV
132 kV
33 kV
Urban
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Units (MUS)
15.29%
10.89%
Consumer
8.31%
0.98%
Load (kW)
4.29%
Current year growth rate has been considered
0.00%
5.00%
1.02%
3.29%
7.17%
Units (MUS)
11 kV
12.76%
Consumer
1.72%
Load (kW)
4.97%
Units (MUS)
Description
Growth rate
0.00%
0.00%
0.00%
0.00%
0.00%
Rural
Description
Growth rate
0.00%
0.00%
0.00%
0.00%
0.00%
11.05%
The assumptions for sales forecast for the Non-Industrial category HV 3.2 are as given below:
Area
Category
Urban
Growth rate
132 kV
33 kV
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Units (MUS)
Description
0.00%
0.00%
0.00%
3.39%
0.00%
8.31%
Rural
Growth rate
Description
0.00%
0.00%
0.00%
3.08%
0.00%
0.00%
46
Area
Category
Urban
Growth rate
11 kV
Description
Rural
Growth rate
Description
Consumer
9.65%
12.50%
Load (kW)
0.00%
1.31%
Units (MUS)
7.09%
10.47%
1.2.11.2.
Central Discom
The assumptions for sales forecast for the Industrial category HV 3.1 are as given below:
Area
Category
Urban
Description
Growth rate
440/220 kV
Consumer
Load (kW)
Units (MUS)
Consumer
0.00%
0.00%
0.00%
20.00%
Rural
Description
Growth rate
0.00%
0.00%
0.00%
0.00%
132 kV
33 kV
Load (kW)
18.50%
Units (MUS)
19.04%
Consumer
10.34%
Load (kW)
7.19%
6.78%
Units (MUS)
3.24%
13.07%
10.00%
Consumer
considered
considered
10.17%
44.22%
20.00%
6.82%
11 kV
Load (kW)
8.76%
Units (MUS)
5.66%
8.76%
considered
68.82%
47
The assumptions for sales forecast for the Non-Industrial category HV 3.2 are as given below:
Area
Category
Urban
Description
Growth rate
132 kV
33 kV
11 kV
Consumer
Load (kW)
Units (MUS)
Consumer
0.00%
0.00%
0.00%
5.52%
Load (kW)
3.46%
Units (MUS)
Consumer
Load (kW)
7.57%
6.96%
7.15%
Units (MUS)
9.81%
Rural
Description
Growth rate
0.00%
0.00%
0.00%
12.50%
10.94%
13.05%
16.67%
25.05%
22.32%
1.2.11.3.
West Discom
It has been assumed that no growth would be considered to forecast sales for the Industrial category HV 3.1 and Non-Industrial category HV 3.2.
48
1.2.12. HV -4: Seasonal
Table 13: HV-4 Seasonal – Projections
Sub Category
33 kV
11 kV
Total
FY 16
9
1
10
East Discom
FY 17
FY 18
10
11
1
1
11
12
FY 19
12
1
13
FY 16
2
0
2
Central Discom
FY 17
FY 18
2
2
0
0
2
2
FY 19
2
0
3
FY 16
4
1
5
West Discom
FY 17
FY 18
4
4
1
1
5
6
FY 19
5
1
6
FY 16
14
3
17
MP State
FY 17
FY 18
15
17
3
3
18
20
FY 19
18
3
21
1.2.12.1.
East Discom
Area
Category
Growth rate
132 kV
33 kV
11 kV
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Units (MUS)
0.00%
0.00%
0.00%
14.47%
0.00%
6.33%
5.00%
0.00%
10.00%
Urban
Description
Rural
Growth rate
0.00%
0.00%
0.00%
0.00%
0.00%
12.75%
0.00%
0.00%
11.58%
Description
49
1.2.12.2.
Central Discom
Growth of 8.06% (3 year CAGR) for urban consumption @ 33 kV and 12.18% (YoY growth rate) for rural consumption @ 33 kV have been considered to
forecast sales for FY 2016-17. While for other categories no growth rate has been considered.
1.2.12.3.
West Discom
Nominal growth of 5% has been considered to project consumers and load in rural area, while 10% has been considered to project rural sales @ 33 kV.
50
1.2.13. HV -5 Water Works, Lift Irrigation & Other allied Agricultural use
Table 14: HV-5 Water Works, Lift Irrigation & Other allied Agricultural use – Projections
Sub Category
Water Works/
Irrigation Units (MU)
Irrigation Units (MU)
Other than
Agricultural Units (MU)
132 kV
33 kV
11 kV
Total
132 kV
33 kV
11 kV
Total
132 kV
33 kV
11 kV
Total
FY 16
0
74
8
83
0
1
0
1
0
13
1
14
East Discom
FY 17 FY 18
0
0
81
89
9
10
90
99
0
0
1
1
0
0
1
1
0
0
15
17
1
1
16
18
FY 19
0
98
10
108
0
2
0
2
0
19
2
21
FY 16
46
96
11
153
0
1
1
1
0
6
1
7
Central Discom
FY 17 FY 18
49
51
100
105
12
13
161
169
0
0
1
1
1
1
2
2
0
0
7
7
1
1
7
8
FY 19
53
110
15
178
0
1
1
2
0
8
1
9
FY 16
271
82
12
365
0
22
0
22
0
6
0
6
West Discom
FY 17 FY 18
271
271
82
82
12
12
365
365
0
0
22
22
0
0
22
22
0
0
6
6
0
0
6
6
FY 19
271
82
12
365
0
22
0
22
0
6
0
6
FY 16
317
253
32
601
0
24
1
25
0
25
2
27
MP State
FY 17 FY 18
319
322
264
276
33
35
617
633
0
0
24
25
1
1
25
26
0
0
27
30
2
3
30
33
FY 19
324
290
37
651
0
25
1
26
0
33
4
36
1.2.13.1.
East Discom
The growth percentages for sales forecast for the HT Water Works category are given below:
Area
Category
Urban
Growth rate
132 kV
33 kV
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Description
0.00%
0.00%
0.00%
15.87%
4.91%
Rural
Growth rate
Description
0.00%
0.00%
0.00%
17.57%
29.18%
51
Area
Category
Urban
Growth rate
11 kV
Description
Rural
Growth rate
Description
Units (MUS)
9.66%
15.40%
Consumer
7.69%
14.47%
Load (kW)
13.12%
21.94%
6.61%
6.11%
Units (MUS)
Nominal growth rate of 5% has been considered to project rural sales @ 33 kV for the HT Irrigation.
The growth percentages for sales forecast for the HT – Other allied Agricultural category are given below
Area
Category
Urban
Description
Growth rate
132 kV
33 kV
11 kV
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Units (MUS)
0.00%
0.00%
0.00%
0.00%
0.00%
2.33%
15.00%
5.00%
18.76%
Rural
Growth rate
Description
0.00%
0.00%
0.00%
0.00%
11.57%
26.36%
0.00%
0.00%
10.00%
52
1.2.13.2.
Central Discom
The growth percentages for sales forecast for the HT water works category are given below:
Area
Category
Urban
Growth rate
132 kV
11 kV
Growth rate
Description
Consumer
0.00%
0.00%
Load (kW)
Units (MUS)
1.00%
4.72%
0.00%
0.00%
Consumer
33 kV
Description
Rural
15.22%
Load (kW)
Units (MUS)
Consumer
Load (kW)
5.82%
3.84%
4.76%
1.38%
Units (MUS)
9.78%
0.00%
16.07%
20.40%
0.00%
0.00%
10.00%
The growth percentages for sales forecast for the HT Irrigation category are given below:
Area
Category
Urban
Description
Growth rate
132 kV
33 kV
11 kV
Consumer
Load (kW)
Units (MUS)
Consumer
0.00%
0.00%
0.00%
0.00%
Rural
Description
Growth rate
0.00%
0.00%
0.00%
0.00%
0.00%
Load (kW)
20.00%
Units (MUS)
47.51%
Consumer
Load (kW)
Units (MUS)
0.00%
0.00%
0.00%
10.00%
0.00%
0.00%
8.01%
53
The growth percentages for sales forecast for the HT- Other allied Agricultural category are given below
Area
Category
Urban
Description
Growth rate
132 kV
33 kV
11 kV
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Units (MUS)
Consumer
Load (kW)
Units (MUS)
0.00%
0.00%
0.00%
7.14%
6.28%
7.33%
0.00%
36.97%
31.69%
Rural
Description
Growth rate
0.00%
0.00%
0.00%
0.00%
0.00%
12.96%
0.00%
0.00%
0.00%
1.2.13.3.
West Discom
It has been assumed that no growth would be considered to forecast sales for the HT- Water Works, HT- Irrigation category and HT – Other allied
Agriculture categories for West Discom.
54
1.2.14. HV -6: Bulk Residential users
Table 15: HV-6 Bulk Residential user – Projections
Sub
Category
33 kV
11 kV
Total
FY 16
262
29
291
East Discom
FY 17
FY 18
262
262
30
32
292
293
FY 19
262
33
295
FY 16
150
13
163
Central Discom
FY 17
FY 18
161
174
16
18
177
192
FY 19
187
22
209
FY 16
24
7
31
West Discom
FY 17
FY 18
24
24
7
7
31
31
FY 19
24
7
31
FY 16
436
49
485
MP State
FY 17
FY 18
447
460
52
56
500
516
FY 19
473
61
534
1.2.14.1.
East Discom
Area
Category
Growth rate
33 kV
11 kV
Urban
Description
Rural
Description
Growth rate
Consumer
Load (kW)
Units (MUS)
5.83%
0.00%
0.00%
Consumer
3.78%
0.00%
Load (kW)
0.00%
0.00%
Units (MUS)
5.00%
0.00%
0.00%
0.00%
0.00%
55
1.2.14.2.
Central Discom
Area
Category
Urban
Description
Growth rate
33 kV
11 kV
Consumer
0.00%
Load (kW)
0.00%
Units (MUS)
7.64%
Consumer
0.00%
Load (kW)
Units (MUS)
0.00%
21.51%
Rural
Description
Growth rate
0.00%
4.88%
8.82%
0.00%
1.85%
15.00%
1.2.14.3.
West Discom
It has been assumed that no growth would be considered to forecast sales for the HT- Bulk Residential user HV-6 category for West Discom.
56
2. Energy Requirement at Discom Boundary and Ex-Bus Energy Requirement
2.1. Conversion of annual sales to monthly sales
The annual sales of the Discoms have been converted into monthly sales using the sales profile observed in the past years for each Discom. This profile is then
used to compute monthly sales for the MYT Period FY 2016-17-FY 2018-19. The profiling for all Discoms is given in the table below:
Table 16: Month-Wise Sales Profiles of Discoms
FY 17
East Discom
West Discom
Central Discom
FY 18
East Discom
West Discom
Central Discom
FY 19
East Discom
West Discom
Central Discom
Apr
8%
8%
8%
Apr
8%
8%
8%
Apr
8%
8%
8%
May
8%
8%
8%
May
8%
8%
8%
May
8%
8%
8%
Jun
7%
7%
7%
Jun
8%
8%
8%
Jun
8%
8%
8%
Jul
7%
7%
7%
Jul
8%
8%
8%
Jul
8%
8%
8%
Aug
8%
8%
8%
Aug
8%
8%
8%
Aug
8%
8%
8%
Sep
9%
9%
9%
Sep
8%
8%
8%
Sep
8%
8%
8%
Oct
10%
10%
10%
Oct
9%
9%
9%
Oct
9%
9%
9%
Nov
10%
10%
10%
Nov
9%
9%
9%
Nov
9%
9%
9%
Dec
9%
9%
9%
Dec
9%
9%
9%
Dec
9%
9%
9%
Jan
9%
9%
9%
Jan
9%
9%
9%
Jan
9%
9%
9%
Feb
9%
9%
9%
Feb
8%
8%
8%
Feb
8%
8%
8%
Mar
8%
8%
8%
Mar
8%
8%
8%
Mar
8%
8%
8%
2.2. MPPTCL Losses
For computation of Intra-State Transmission Losses (MPPTCL Losses), the actual data has been taken from the MP-SLDC online portal for the period November
2014 to October 2015 (52 weeks) and the average of the same has been considered for the ensuing years. The computed average MPPTCL losses work out to be
2.88 % and the same has been assumed to be constant for the MYT period FY 2016-17 to FY 2018-19.
Table 17: MPPTCL Losses: Past Data from MP-SLDC
MPPTCL
Losses
November14
3.00%
December
-14
3.00%
January15
3.00%
February
-15
2.75%
March-15
April-15
May-15
June-15
July-15
2.75%
3.00%
2.50%
3.00%
2.75%
August15
2.75%
Septembe
r-15
3.00%
October15
3.00%
Average
2.88%
57
2.3. Distribution Losses
The Commission in its Regulations on “Terms and conditions for determination of tariff for supply and wheeling of electricity and methods and principles of
fixation of charges” communicated to MPPMCL vide Commission’s Regulation no. 2256 – MPERC.2015 dated 17/12/2015 has notified distribution loss levels
for the MYT period FY 2016-17 to FY 2017-18. The distribution loss level trajectory as specified in the Regulations is given in the table below:
Table 18: Loss level targets (%) for Discoms (as per MPERC regulations)
Loss Targets
East Discom
West Discom
Central Discom
FY 17
18.00%
16.00%
19.00%
FY 18
17.00%
15.50%
18.00%
FY 19
16.00%
15.00%
17.00%
The actual losses of the Discoms are observed at 22.40% for East Discom, 23.31% for Central Discom and 21.17% for West Discom. However for the purpose of
this petition the loss targets specified by the Commission in its Regulations on “Terms and conditions for determination of tariff for supply and wheeling of
electricity and methods and principles of fixation of charges” have been considered for the calculation of Energy Balance and calculation of power purchase costs
of the Discoms.
2.3.1. Conversion of annual Distribution loss levels to monthly losses
The annual distribution loss trajectory is converted into monthly loss trajectory based on the standard deviations of monthly losses from the cumulative annual
losses during the past 5 years. In this method, the actual monthly loss levels and the cumulative annual losses of the Discom for the past years are taken and
standard deviation of loss levels of each month from the cumulative annual average is calculated. The monthly standard deviations are then used to calculate the
monthly loss levels using the annual MPERC loss level trajectory.
As a result, the annual energy requirement at the Discom boundary is grossed up by a higher loss figure than observed as per the MPERC loss trajectory.
The energy requirement is computed for all three Discoms and MP state at the state boundary as shown in tables below:
58
Table 19: Monthly energy requirement at State Boundary (MU) for FY 17- FY 19
Monthly energy requirement at State Boundary - FY '17
August-16 September
OctoberNovember December
-16
16
-16
-16
7%
8%
9%
10%
10%
9%
East Discom
April-16
May-16
June-16
July-16
January17
9%
February17
9%
March-17
Total
Sales profile
8%
8%
7%
8%
100%
Sales (MUs)
1,258
1,258
1,101
1,101
1,180
1,337
1,573
1,494
1,337
1,416
1,416
1,258
15,730
Distribution
loss
Transmissio
n loss
Energy
requirement
at state
boundary
20.30%
19.64%
14.21%
16.00%
18.89%
19.42%
18.93%
19.15%
20.84%
17.68%
15.65%
15.29%
18.00%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
1,626
1,612
1,321
1,350
1,497
1,708
1,998
1,903
1,739
1,771
1,728
1,529
19,783
Central
Discom
Sales profile
April-16
May-16
June-16
July-16
August-16
October16
10%
November
-16
10%
December
-16
9%
January17
9%
February17
9%
March-17
Total
8%
September
-16
9%
8%
8%
7%
7%
8%
100%
Sales (MUs)
1,202
1,202
1,052
1,052
1,127
1,278
1,503
1,428
1,278
1,353
1,353
1,202
15,029
Distribution
loss
Transmissio
n loss
Energy
requirement
at state
boundary
19.42%
18.62%
17.97%
17.24%
18.96%
19.53%
20.25%
20.05%
19.25%
20.18%
18.64%
17.89%
19.00%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
1,536
1,521
1,321
1,309
1,432
1,635
1,940
1,839
1,629
1,745
1,712
1,508
19,126
West
Discom
Sales profile
April-16
May-16
June-16
July-16
August-16
7%
7%
8%
November
-16
10%
December
-16
9%
January17
9%
February17
9%
Total
8%
October16
10%
March-17
8%
September
-16
9%
8%
100%
59
Sales (MUs)
1,423
1,423
1,246
1,246
1,334
1,512
1,779
1,690
1,512
1,601
1,601
1,423
17,793
Distribution
loss
Transmissio
n loss
Energy
requirement
at state
boundary
18.07%
22.49%
17.07%
7.26%
4.55%
8.04%
22.33%
22.68%
21.47%
21.80%
14.38%
11.87%
16.00%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
1,789
1,891
1,546
1,383
1,440
1,693
2,359
2,251
1,983
2,108
1,926
1,663
22,031
MP State
April-16
May-16
June-16
July-16
3,884
3,399
3,399
October16
4,855
November
-16
4,612
Decembe
r-16
4,127
January17
4,370
February
-17
4,370
Total
3,884
September
-16
4,127
March-17
Sales (MUs)
August16
3,641
3,884
48,552
Energy
requirement
at state
boundary
4,951
5,024
4,188
4,041
4,369
5,036
6,297
5,993
5,351
5,624
5,365
4,700
60,939
East Discom
April-17
May-17
June-17
July-17
Total
8%
8%
8%
February18
8%
March-18
Sales profile
January18
9%
8%
100%
Sales (MUs)
1,397
1,397
1,397
1,397
1,397
1,397
1,571
1,571
1,571
1,571
1,397
1,397
17,458
Distribution
loss
Transmissio
n loss
Energy
requirement
at state
boundary
19.30%
18.64%
13.21%
15.00%
17.89%
18.42%
17.93%
18.15%
19.84%
16.68%
14.65%
14.29%
17.00%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
1,782
1,768
1,657
1,692
1,751
1,763
1,971
1,977
2,018
1,942
1,685
1,678
21,682
August-17 September
OctoberNovember December
-17
17
-17
-17
8%
8%
8%
9%
9%
9%
60
Central
Discom
Sales profile
April-17
May-17
June-17
July-17
August-17
October17
9%
November
-17
9%
December
-17
9%
January18
9%
February18
8%
March-18
Total
8%
September
-17
8%
8%
8%
8%
8%
8%
100%
Sales (MUs)
1,362
1,362
1,362
1,362
1,362
1,362
1,533
1,533
1,533
1,533
1,362
1,362
17,030
Distribution
loss
Transmissio
n loss
Energy
requirement
at state
boundary
18.42%
17.62%
16.97%
16.24%
17.96%
18.53%
19.25%
19.05%
18.25%
19.18%
17.64%
16.89%
18.00%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
1,719
1,703
1,689
1,675
1,710
1,722
1,954
1,949
1,930
1,953
1,703
1,688
21,396
West
Discom
Sales profile
April-17
May-17
June-17
July-17
August-17
8%
8%
8%
November
-17
9%
December
-17
9%
January18
9%
February18
8%
Total
8%
October17
9%
March-18
8%
September
-17
8%
8%
100%
Sales (MUs)
1,528
1,528
1,528
1,528
1,528
1,528
1,719
1,719
1,719
1,719
1,528
1,528
19,104
Distribution
loss
Transmissio
n loss
Energy
requirement
at state
boundary
17.57%
21.99%
16.57%
6.76%
4.05%
7.54%
21.83%
22.18%
20.97%
21.30%
13.88%
11.37%
15.50%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
1,909
2,017
1,886
1,688
1,640
1,702
2,265
2,275
2,240
2,249
1,827
1,776
23,473
MP State
April-17
May-17
June-17
July-17
August-17
4,287
4,287
4,287
4,287
November
-17
4,823
December
-17
4,823
January18
4,823
February18
4,287
Total
4,287
October17
4,823
March-18
Sales (MUs)
September
-17
4,287
4,287
53,593
Energy
requirement
at state
5,410
5,487
5,232
5,054
5,101
5,186
6,190
6,201
6,189
6,144
5,215
5,141
66,551
61
boundary
East Discom
April-18
May-18
June-18
July-18
August-18
October18
9%
November
-18
9%
December
-18
9%
January19
9%
February19
8%
March-19
Total
8%
September
-18
8%
Sales profile
8%
8%
8%
8%
8%
100%
Sales (MUs)
1,562
1,562
1,562
1,562
1,562
1,562
1,758
1,758
1,758
1,758
1,562
1,562
19,529
Distribution
loss
Transmissio
n loss
Energy
requirement
at state
boundary
18.30%
17.64%
12.21%
14.00%
16.89%
17.42%
16.93%
17.15%
18.84%
15.68%
13.65%
13.29%
16.00%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
1,969
1,953
1,832
1,871
1,935
1,948
2,179
2,184
2,230
2,146
1,863
1,855
23,965
Central
Discom
Sales profile
April-18
May-18
June-18
July-18
August-18
8%
8%
8%
November
-18
9%
December
-18
9%
January19
9%
February19
8%
Total
8%
October18
9%
March-19
8%
September
-18
8%
8%
100%
Sales (MUs)
1,563
1,563
1,563
1,563
1,563
1,563
1,759
1,759
1,759
1,759
1,563
1,563
19,542
Distribution
loss
Transmissio
n loss
Energy
requirement
at state
boundary
17.42%
16.62%
15.97%
15.24%
16.96%
17.53%
18.25%
18.05%
17.25%
18.18%
16.64%
15.89%
17.00%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
1,949
1,930
1,916
1,899
1,938
1,952
2,215
2,210
2,188
2,213
1,931
1,914
24,256
West
Discom
Sales profile
April-18
May-18
June-18
July-18
August-18
8%
8%
8%
November
-18
9%
December
-18
9%
January19
9%
February19
8%
Total
8%
October18
9%
March-19
8%
September
-18
8%
8%
100%
62
Sales (MUs)
1,642
1,642
1,642
1,642
1,642
1,642
1,848
1,848
1,848
1,848
1,642
1,642
20,528
Distribution
loss
Transmissio
n loss
Energy
requirement
at state
boundary
17.07%
21.49%
16.07%
6.26%
3.55%
7.04%
21.33%
21.68%
20.47%
20.80%
13.38%
10.87%
15.00%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2,039
2,154
2,015
1,804
1,753
1,819
2,418
2,429
2,392
2,402
1,952
1,897
25,072
MP State
April-18
May-18
June-18
July-18
August-18
4,768
4,768
4,768
4,768
November
-18
5,364
December
-18
5,364
January19
5,364
February19
4,768
Total
4,768
October18
5,364
March-19
Sales (MUs)
September
-18
4,768
4,768
59,600
Energy
requirement
at state
boundary
5,957
6,037
5,762
5,573
5,627
5,719
6,812
6,823
6,810
6,761
5,746
5,666
73,293
63
The ex-bus energy to be purchased during the MYT period FY 17 – FY 19 is shown in the following table:
Table 20: Ex-bus energy purchases to be done during MYT FY 17-19
Particulars
East Discom
FY 17
FY 18
Central Discom
FY 19
FY 17
FY 18
West Discom
FY 19
FY 17
FY 18
MP State
FY 19
FY 17
FY 18
FY 19
Total Units sold to LT category (MU)
10,993
12,262
13,816
10,623
12,096
13,999
13,835
15,146
16,570
35,451
39,503
44,385
Total Units sold to HT category (MU)
4,736
5,196
5,713
4,406
4,935
5,543
3,958
3,958
3,958
13,101
14,090
15,214
Total Units Sold by Discom (MU)
15,730
17,458
19,529
15,029
17,030
19,542
17,793
19,104
20,528
48,552
53,593
59,600
Distribution loss (%)
18.00%
17.00%
16.00%
19.00%
18.00%
17.00%
16.00%
15.50%
15.00%
17.67%
16.83%
16.00%
Distribution loss (MU)
3,484
3,600
3,747
3,546
3,750
4,016
3,604
3,694
3,823
10,635
11,045
11,586
Units Input at Distribution Interface
(MU)
Transmission loss (%)
19,214
21,059
23,276
18,576
20,781
23,558
21,398
22,798
24,352
59,187
64,638
71,186
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
2.88%
569
623
689
550
615
697
633
675
721
1,752
1,913
2,107
Input at G-T interface (MU)
19,783
21,682
23,965
19,126
21,396
24,256
22,031
23,473
25,072
60,939
66,551
73,293
WR-PGCIL Lossess
3.77%
3.77%
3.77%
3.77%
3.77%
3.77%
3.77%
3.77%
3.77%
3.77%
3.77%
3.77%
ER-PGCIL Lossess
2.09%
2.09%
2.09%
2.09%
2.09%
2.09%
2.09%
2.09%
2.09%
2.09%
2.09%
2.09%
External Loss (MU)
489
543
601
472
536
609
542
586
627
1,503
1,664
1,837
20,271
22,225
24,566
19,598
21,932
24,865
22,573
24,059
25,699
62,442
68,215
75,130
Transmission loss (MU)
Total Units Purchased (MU)
64
3. Assessment of Availability
This section details the availability of power and related costs for the ensuing years for the state of
Madhya Pradesh. The forecast takes into account the following aspects:



Existing long term allocated generation capacity of MP
New generation capacity additions during the period FY 17-FY 19 for MPPGCL , Central
Sector, Joint venture, UMPP Sasan and by private players awarded through competitive
bidding
Impact of generation capacity allocation in WR and ER
Based on the above available information, power purchase for the ensuing years has been forecasted.
The same has been detailed in the subsequent sections.
3.1. Details of Generation Capacities allocated to Discoms
The various stations in which MP has been allocated share and which are further allocated to the three
MP Discoms are listed in the table below. Allocation to the state of MP from Central Sector stations is
as per Western Regional Power Committee in their letter No.WRPC/CommlI/6/Alloc/2014/10874 dated 3rd December 2014 and for Eastern Region NTPC Kahalgaon 2 vide
GoI MoP letter no. 5/31/2006-Th.2 dated 21st February 2007. As regards DVC, the availability of
500 MW has been mentioned on the basis of following Power Purchase Agreements:

400 MW power as per PPA dated March 3rd, 2006 (200 MW each from MTPS units and
CTPS units)

100 MW power as per PPA dated May 14th, 2007 (Durgapur Steel TPS).
It also includes the specific allocation of 200 MW to Bundelkhend Region as per the MPERC Retail
order dated May 24, 2014 ( vide GoMP letter no- F-5-15/2011/13 dated May 22nd, 2014)
Table 21: Stations with MP Share which are allocated to MP Discoms
Station
Region
Ownership
Capacity
(MW)
MP
Share
(%)
MP
Share
(MW)
NTPC-Korba
WR
NTPC
2,100.00
22.83%
479.48
NTPC-Vindyachal I
WR
NTPC
1,260.00
35.04%
441.50
NTPC-Vindyachal II
WR
NTPC
1,000.00
31.67%
316.71
NTPC-Vindyachal III
WR
NTPC
1,000.00
24.65%
246.45
NTPC-Kawas
WR
NTPC
656.00
21.34%
140.00
NTPC-Gandhar
WR
NTPC
657.00
17.81%
117.00
NTPC - Sipat Stage II
WR
NTPC
1,000.00
18.85%
188.48
NTPC - Kahalgaon 2
ER
NTPC
1,500.00
5.00%
74.98
MP Share Allocation to
Discoms (%)
EZ
32.00
%
31.00
%
30.00
%
25.00
%
35.00
%
32.00
%
30.00
%
27.00
%
WZ
37.00
%
32.00
%
35.00
%
40.00
%
40.00
%
38.00
%
40.00
%
53.00
%
CZ
31.00
%
37.00
%
35.00
%
35.00
%
25.00
%
30.00
%
30.00
%
20.00
%
65
Station
Region
Ownership
Capacity
(MW)
MP
Share
(%)
MP
Share
(MW)
DVC (MTPS, CTPS)
ER
DVC
1,000.00
40.00%
400.00
ATPS - Chachai-Extn
State
MPPGCL
210.00
100.00%
210.00
STPS - Sarani-PH 1, 2
&3
SGTPS - Bir'pur - Extn
State
MPPGCL
830.00
100.00%
830.00
State
MPPGCL
500.00
100.00%
500.00
SGTPS - Bir'pur - PH 1
&2
CHPS-Gandhi Sagar
State
MPPGCL
840.00
100.00%
840.00
State
MPPGCL
115.00
50.00%
57.50
CHPS-RP Sagar &
Jawahar Sagar
Pench THPS
State
MPPGCL
271.00
50.00%
135.50
State
MPPGCL
160.00
66.67%
106.67
Rajghat HPS
State
MPPGCL
45.00
50.00%
22.50
Bargi HPS
State
MPPGCL
90.00
100.00%
90.00
Birsingpur HPS
State
MPPGCL
20.00
100.00%
20.00
Banasgar Tons HPS
State
MPPGCL
315.00
100.00%
315.00
Banasgar Tons HPSSilpara
Banasgar Tons HPSDevloned
Banasgar Tons HPSBansagar IV (Jhinna)
Marhi Khera HPS
State
MPPGCL
30.00
100.00%
30.00
State
MPPGCL
60.00
100.00%
60.00
State
MPPGCL
20.00
100.00%
20.00
State
MPPGCL
60.00
100.00%
60.00
NHDC - Indira Sagar
State
JV
1,000.00
100.00%
1,000.00
Captive
State
17.00
100.00%
17.00
Others(mini micro)
State
Others
29.00
100.00%
29.00
Sardar Sarovar
WR
JV
1,450.00
57.00%
826.50
Omkareshwar HPS
State
JV
520.00
100.00%
520.00
UPPMCL(Rihand
Matatila)
State
Others
55.00
100.00%
55.00
MP Share Allocation to
Discoms (%)
EZ
33.00
%
27.00
%
29.00
%
28.00
%
28.00
%
23.00
%
20.00
%
20.00
%
20.00
%
25.00
%
30.00
%
30.00
%
30.00
%
30.00
%
30.00
%
30.00
%
22.00
%
29.00
%
29.00
%
32.00
%
30.00
%
29.00
%
WZ
53.00
%
33.00
%
32.00
%
32.00
%
32.00
%
27.00
%
30.00
%
40.00
%
40.00
%
50.00
%
50.00
%
40.00
%
40.00
%
40.00
%
40.00
%
50.00
%
53.00
%
41.00
%
41.00
%
43.00
%
45.00
%
38.00
%
CZ
14.00
%
40.00
%
39.00
%
40.00
%
40.00
%
50.00
%
50.00
%
40.00
%
40.00
%
25.00
%
20.00
%
30.00
%
30.00
%
30.00
%
30.00
%
20.00
%
25.00
%
30.00
%
30.00
%
25.00
%
25.00
%
33.00
%
It is to be noted that allocation of infirm power to the state of MP is subject to changes as per
WRPC/ERPC directives from time to time.
It is pertinent to mention that the allocation as per the above table is uneven. The highest share of
power purchase cost is being allocated to West Discom due to which the Aggregate Revenue
Requirement (ARR) of West Discom increases substantially.
66
In order to remove the complexities with respect to allocation of plants among the Discoms and to MPPMCL, the Petitioners have considered all the plants
allocated to Discoms as allocated to MPPMCL. This reduces preparation of separate MoD for the three Discoms as well for MPPMCL. Further, this shall also
remove the issues with respect to deviation settlement mechanism among the three Discoms at Intrastate level. Hence, in order to maintain equitable allocation of
the power purchased cost among all the three Discoms, it is requested to the Commission to reallocate all of the power stations allocated to Discoms to MPPMCL.
In addition, the Petitioners are also pursuing with the Government of Madhya Pradesh to reallocate all the plants to MPPMCL.
For allocation of the overall availability and costs to the Discoms, the Petitioners have considered the monthly energy requirement of the three Discoms at the
state boundary level for the period FY 17-FY 19 as provided in the table below:
Table 22: Allocation percentage for FY 17
FY 17
Apr-16
May-16
Jun-16
Jul-16
Aug-16
Sep-16
Oct-16
Nov-16
Dec-16
Jan-17
Feb-17
Mar-17
Total
East
1,626
1,612
1,321
1,350
1,497
1,708
1,998
1,903
1,739
1,771
1,728
1,529
19,782
Central
1,536
1,521
1,321
1,309
1,432
1,635
1,940
1,839
1,629
1,745
1,712
1,508
19,127
West
1,789
1,891
1,546
1,383
1,440
1,693
2,359
2,251
1,983
2,108
1,926
1,663
22,032
4,951
5,024
4,188
4,041
4,369
5,036
6,297
5,993
5,351
5,624
5,365
4,700
60,939
East
32.84%
32.09%
31.55%
33.40%
34.27%
33.92%
31.73%
31.76%
32.50%
31.48%
32.21%
32.54%
32.52%
Central
31.03%
30.28%
31.53%
32.39%
32.78%
32.46%
30.82%
30.68%
30.44%
31.02%
31.90%
32.08%
31.45%
West
36.13%
37.63%
36.92%
34.22%
32.95%
33.62%
37.46%
37.56%
37.06%
37.49%
35.89%
35.38%
36.03%
FY 18
Apr-17
May-17
Jun-17
Jul-17
Aug-17
Sep-17
Oct-17
Nov-17
Dec-17
Jan-18
Feb-18
Mar-18
Total
East
1,782
1,768
1,657
1,692
1,751
1,763
1,971
1,977
2,018
1,942
1,685
1,678
21,684
Central
1,909
2,017
1,886
1,688
1,640
1,702
2,265
2,275
2,240
2,249
1,827
1,776
23,474
West
1,719
1,703
1,689
1,675
1,710
1,722
1,954
1,949
1,930
1,953
1,703
1,688
21,395
5,410
5,487
5,232
5,054
5,101
5,186
6,190
6,201
6,189
6,144
5,215
5,141
66,550
East
32.93%
32.21%
31.66%
33.47%
34.33%
33.99%
31.84%
31.88%
32.61%
31.60%
32.31%
32.63%
32.62%
Central
35.28%
36.76%
36.05%
33.39%
32.15%
32.81%
36.58%
36.68%
36.20%
36.61%
35.03%
34.54%
35.17%
67
West
31.78%
31.03%
32.29%
33.14%
33.52%
33.20%
31.57%
31.44%
31.19%
31.78%
32.66%
32.83%
32.20%
FY 19
Apr-18
May-18
Jun-18
Jul-18
Aug-18
Sep-18
Oct-18
Nov-18
Dec-18
Jan-19
Feb-19
Mar-19
Total
East
1,969
1,953
1,832
1,871
1,935
1,948
2,179
2,184
2,230
2,146
1,863
1,855
23,965
Central
2,039
2,154
2,015
1,804
1,753
1,819
2,418
2,429
2,392
2,402
1,952
1,897
25,074
West
1,949
1,930
1,916
1,899
1,938
1,952
2,215
2,210
2,188
2,213
1,931
1,914
24,255
5,957
6,037
5,762
5,573
5,627
5,719
6,812
6,823
6,810
6,761
5,746
5,666
73,293
East
33.05%
32.35%
31.80%
33.56%
34.40%
34.06%
31.98%
32.02%
32.74%
31.74%
32.42%
32.74%
32.74%
Central
34.23%
35.67%
34.96%
32.36%
31.16%
31.80%
35.50%
35.60%
35.12%
35.52%
33.97%
33.48%
34.11%
West
32.72%
31.98%
33.24%
34.07%
34.45%
34.13%
32.52%
32.39%
32.13%
32.73%
33.61%
33.78%
33.15%
3.2.1
Availability from MP Discoms’ allocated stations
The basis of projections for all the stations i.e. the Discom allocated stations as well as MPPMCL allocated stations for MYT period FY 17- FY 19 are mentioned
in the following table:
Station
MPPGCL - Shri Singaji STPS Phase -1 (Unit 1)
MPPGCL - Satpura TPS Extension (Unit 10 & 11)
UMPP Sasan
Jaiprakash Power, Nigri
MB Power
BLA Power
Jhabua Power
All other stations
Basis
PLF Taken at 60% since the actual PLF is observed to be
less than 60% for the past two years
PLF Taken at 60% since the actual PLF is observed to be
less than 60% for the past three years
PLF Taken at 80%
PLF Taken at 80%
PLF Taken at 80%
PLF Taken at 80%
PLF Taken at 80%
PLF Taken at the average actual availability of the past 3
years
68
Table 25: Past and Projected ex-bus availability of Stations with MP Share which are allocated to MP Discoms
(MU)
Station
Actual
Projected Ex-Bus Availability (MU)
Availability
FY 15
FY 16
FY 17
FY 18
FY 19
NTPC-Korba
3,473
3,638
3,534
3,500
3,537
NTPC-Vindyachal I
2,746
2,666
2,714
2,709
2,696
NTPC-Vindyachal II
2,063
1,997
2,111
2,057
2,055
NTPC-Vindyachal III
1,667
1,730
1,732
1,710
1,724
NTPC-Kawas
342
249
249
249
249
NTPC-Gandhar
298
222
222
222
222
KAPP
796
683
777
752
737
TAPS
1,603
1,684
1,598
1,628
1,637
1,411
1,310
1,302
1,341
1,317
NTPC - Kahalgaon 2
363
342
309
338
330
DVC (MTPS, CTPS)
1,763
2,254
2,096
2,038
2,129
ATPS - Chachai-Extn
1,449
1,588
1,524
1,520
1,544
STPS - Sarani-PH 1, 2 & 3
SGTPS - Bir'pur - PH 1 & 2
CHPS-Gandhi Sagar
3,610
3,026
3,192
133
3,913
3,567
4,478
146
3,760
3,445
4082
159
3,761
3,346
4,097
146
3,811
3,453
4,159
150
CHPS-RP Sagar & Jawahar Sagar
Pench THPS
317
258
397
248
376
263
363
256
379
256
Rajghat HPS
40
30
33
34
32
Bargi HPS
482
390
468
446
435
Birsingpur HPS
30
24
33
29
29
1,257
1,212
1,457
1,309
1,326
96
96
95
85
105
105
99
96
100
95
Banasgar Tons HPS
Banasgar Tons HPS-Bansagar IV (Jhinna)
Marhi Khera HPS
NHDC - Indira Sagar
2,554
2,486
3,035
2,692
2,738
Captive
66
31
47
36
38
Others(mini micro)
31
30
42
95
56
Sardar Sarovar
33
1,864
2,245
1,910
2,006
Omkareshwar HPS
1,620
1,148
1,296
1,189
1,211
UPPMCL(Rihand Matatila)
Total
1,121
35,936
34
38,541
45
39,164
60
38,028
46
38,497
69
3.2. Details of Generation Capacities allocated to MPPMCL – Existing
and Capacity Addition for the MYT period FY 17-FY 19
The following table lists various stations in which MP has an allocated share and which are further
allocated to MPPMCL. All future capacities within the state or those with MP share are allocated to
MPPMCL. The following table includes the existing MPPMCL allocated stations as well as the future
capacity additions which are expected to become operational till end of MYT period i.e. FY 19.
Table 26: Stations allocated to MPPMCL – Existing and Capacity Addition till FY 19
Sl.No.
Name of Project
Unit
Region
Ownershi
p
Capaci
ty
MP's
Share
(MW)
(MW)
COD/
Expected
COD
Year-wise Capacity Availability (MW)
FY1
5
FY16
FY17
FY18
FY1
9
1
NTPC Korba -III
Unit 7
WR
Central
500
77
Mar-11
77
77
77
77
77
2
NTPC Sipat Stage - 1
3 units
WR
Central
1,980
340
Aug-12
340
340
340
340
340
Unit 10
State
State
250
250
Aug-13
250
250
250
250
250
Unit 11
State
State
250
250
Mar-14
250
250
250
250
250
Unit 1
State
State
600
600
Feb-14
600
600
600
600
600
Unit 2
State
State
600
600
Dec-14
600
600
600
600
600
Unit 1
WR
Central
500
93
Mar-13
93
93
93
93
93
Unit 2
WR
Central
500
78
Mar-14
78
78
78
78
78
Unit 1
WR
Central
500
143
Mar-13
143
143
143
143
143
Unit 2
WR
Central
500
128
Mar-14
128
128
128
128
128
ER
JV
500
50
NA
50
50
50
50
50
3
4
5
6
7
8
9
10
MPPGCL - Satpura
TPS Extension
MPPGCL - Satpura
TPS Extension
MPPGCL - Shri Singaji
STPS Phase -1
STPS Phase -1
NTPC Mouda STPS,
Stage -1
NTPC Mouda STPS,
Stage -1
NTPC Vindhyanchal
MTPS, Stage - 4
NTPC Vindhyanchal
MTPS, Stage - 4
11
DVC DTPS
Unit 1
12
DVC DTPS
Unit 2
ER
JV
500
50
NA
50
50
50
50
50
13
UMPP Sasan
Unit 1
WR
Private
660
247
Aug-13
247
247
247
247
247
14
UMPP Sasan
Unit 2
WR
Private
660
248
Mar-14
248
248
248
248
248
15
UMPP Sasan
Unit 3 & 4
WR
Private
1,320
495
Unit 3Mar'14 &
Unit 4- Apr
14
495
495
495
495
495
16
UMPP Sasan
Unit 5 & 6
WR
Private
1,320
495
Unit 5- Nov
14 & Unit
6- Mar 15
248
495
495
495
495
17
Jaypee Bina Power
Unit 1
State
Private
250
175
Aug-12
175
175
175
175
175
18
Jaypee Bina Power
Unit 2
State
Private
250
175
Apr-13
175
175
175
175
175
Unit 1
WR
Private
660
248
Sep-14
248
248
248
248
248
Unit 2
WR
Private
660
247
Dec-14
247
247
247
247
247
19
20
Jaiprakash Power,
Nigri
Jaiprakash Power,
Nigri
21
MB Power
Unit 1
WR
Private
600
210
Dec-14
210
210
210
210
210
22
MB Power
Unit 2
WR
Private
600
210
Dec-15
-
210
210
210
210
23
BLA Power
Unit 1
State
Private
45
16
Apr-12
16
16
16
16
16
24
BLA Power
Unit 2
State
Private
45
16
Mar-15
-
16
16
16
16
25
Jhabua Power
Unit 1
WR
Private
600
210
Sep-15
-
210
210
210
210
70
Sl.No.
26
27
28
29
30
31
32
33
34
35
36
Name of Project
Lanco Amarkantak
NTPC Vindhyanchal
MTPS, Stage - 5
NTPC Mouda STPS,
Stage 2
Phase-2
Phase-2
NTPC Lara STPS,
Rajgarh
NTPC Gadarwara
STPS,
NTPC Gadarwara
STPS,
NTPC North Karanpura
STPS,
Renewable Energy –
Solar
Renewable Energy Other than Solar
Unit
Region
Ownershi
p
Capaci
ty
MP's
Share
(MW)
(MW)
COD/
Expected
COD
Year-wise Capacity Availability (MW)
FY1
5
FY16
FY17
FY18
FY1
9
Unit 1
WR
Private
300
300
Dec-12
300
300
300
300
300
Unit 1
WR
Central
500
128
Apr-16
-
-
128
128
128
Unit 1, 2
WR
Central
1,320
206
Dec-16
-
-
206
206
206
Unit 1
State
State
660
594
Sep-18
-
-
-
-
594
Unit-2
State
State
660
594
Dec-18
-
-
-
-
594
Unit 1 to
Unit 5
WR
Central
4,000
319
Sep-17
-
-
-
319
319
Unit 1
WR
Central
800
400
Sep-17
-
-
-
400
400
Unit 2
WR
Central
800
400
Mar-18
-
-
-
400
400
Unit 1
WR
Central
660
66
Dec-18
-
-
-
-
66
NA
State
Private
-
550
255
550
550
550
550
NA
State
Private
-
1270
600
847
1270
1270
1270
10,478
6,12
3
7,348
8,105
9,224
10,4
78
Total
*Comm-Plants already commissioned hence date of COD not mentioned.
71
3.2.1.Availability from MPPMCL allocated stations
The projected exbus availability for the period FY 2016-17-FY 2018-19 (for existing MPPMCL
allocated stations) are tabulated below:
Table 27: Stations allocated to MPPMCL – Projected-Ex Bus Availability till FY’19 (MU)
S.No
.
1.
2.
Name of Project
Unit
Actual
Availability
FY 15
Projected Ex-Bus Availability
FY 16
FY 17
FY 18
FY 19
Unit 7
3 units
576
2,474
557
2,206
553
2,220
562
2,300
557
2,242
Unit 10
801
952
1,171
1,256
1,177
Unit 11
1,031
952
1,171
1,332
1,202
Unit 1
2223
2,450
2,917
2,926
2,764
Unit 2
-
2,450
2,917
2,926
2,585
Unit 1
1,935
876
922
1,244
1,014
Unit 2
-
876
922
1,244
1,014
Unit 1
Unit 2
Unit 1
Unit 2
Unit 3 &
4
Unit 5 &
6
Unit 1
Unit 2
98
98
1,124
1,123
159
159
1,181
1,181
128
128
1,604
1,604
128
128
1,704
1,704
139
139
1,704
1,704
2,248
2,362
3,209
3,209
3,209
1123
2,362
3,209
3,209
3,209
1,619
635
886
886
1,161
1,161
1,161
1,161
1,161
1,161
9.
10.
11.
12.
NTPC Korba -III
MPPGCL - Satpura TPS
Extension
Extension
MPPGCL - Shri Singaji STPS
Phase -1
MPPGCL - Shri Singaji STPS
Phase -1
NTPC Vindhyanchal MTPS,
Stage - 4
Stage - 4
DVC DTPS
DVC DTPS
UMPP Sasan
UMPP Sasan
13.
UMPP Sasan
14.
UMPP Sasan
15.
16.
Jaypee Bina Power
Jaypee Bina Power
17.
18.
19.
20.
21.
22.
MB Power
MB Power
BLA Power
BLA Power
Unit 1
Unit 2
Unit 1
Unit 2
Unit 1
Unit 2
846
129
-
569
569
79
79
9
9
1,608
1,608
1,361
1,361
49
49
1,670
1,670
1,361
1,361
49
49
1,696
1,696
1,361
1,361
49
49
23.
24.
Jhabua Power
Lanco Amarkantak
Stage - 5
MPPGCL - Shri Singaji Phase2
MPPGCL - Shri Singaji Phase2
Unit 1
Unit 1
2,013
1,896
1,361
1,992
1,361
1,967
1,361
1,952
Unit 1
-
-
762
830
830
Unit 1
-
-
-
-
1,783
Unit-2
-
-
-
-
782
-
-
-
1,458
2,333
-
-
-
1,501
12
-
2,874
2,537
123
3.
4.
5.
6.
7.
8.
25.
26.
27.
28.
NTPC Lara STPS, Rajgarh
29.
30.
31.
NTPC Gadarwara STPS
NTPC Gadarwara STPS,
NTPC North Karanpura STPS,
Unit 1 to
Unit 5
Unit 1
Unit 2
Unit 1
72
S.No
.
32.
33.
Name of Project
Renewable Energy - Solar
Renewable Energy - Other than
Solar
Total
Unit
Actual
Availability
FY 15
Projected Ex-Bus Availability
FY 16
FY 17
FY 18
FY 19
NA
404
462
912
1,002
1,117
NA
619
936
2,382
2,424
2,544
21,119
25,103
38,442
42,909
49,429
3.3. Overall availability
The overall availability for MP State (from stations allocated to Discoms as well as stations allocated
to MPPMCL) for FY 17-FY 19 is summarized in the below table:
Table 28: Overall availability till FY’19 (MU)
Category
Availability from Stations allocated to MP
Discoms
Availability from Stations allocated to
MPPMCL
Total
FY 15
FY 16
FY 17
FY 18
FY 19
35,936
38,541
39,164
38,028
38,497
21,119
25,103
38,442
42,909
49,429
57,055
63,644
77,606
80,937
87,926
3.4. Backdown of Power
The Petitioners have requested Ministry of Power for surrender of power in respect of stations
mentioned below:
Station Name
NTPC Mouda Stage I(Unit 1 &Unit 2)
ATPS Chachai-Ph 1 & 2
NTPC Kawas
NTPC Gandhar
Basis for Surrender of Power
Owing to high variable costs of the station and reduced
scheduling of the station, GoMP vide letter no. F3/58/2012/13 dtd 10.09.2015 have requested Ministry of
Power to deallocate MP’s share in the power station
MPPGCL vide UO Note no 775 dtd 16.09.2015 have
intimated that no power would be scheduled from this
station
Owing to reduced drawal of the stations , MPPMCL has
requested NTPC Limited vide letter no 05-01/1620 dtd
08.09.2015 to terminate the PPA .
However, the Petitioners for the purpose of calculation has considered partially backing down the
above stations except for NTPC Mouda STPS Stage 1 (Unit 1 & Unit 2), as during the actual
scheduling of the power stations, NTPC Mouda STPS Stage 1 (Unit 1 & Unit 2) with a variable cost
of Rs 4.36 per unit is never scheduled during the whole year. Similarly, Sugen Torrent with a variable
cost of Rs 6.65 per unit is never scheduled during the whole year. Hence the Petitioners have not
considered the availability as well as the fixed and variable costs of such stations for the purpose of
computation of Power Purchase Cost.
After fully meeting the requirement of the State and selling power on the power exchange, the
Petitioners still have to partially back-down plants so as to save on the variable costs being incurred.
73
The Petitioners have applied month-wise merit order dispatch principle on the basis of variable costs
for FY 2016-17 and thereafter, after considering both Discom allocated generating stations as well as
MPPMCL allocated generating stations. The Petitioners have also considered partial backing down of
units/stations which are higher up in the MoD, during those periods when their running is not required
to meet the demand in that period and the market rates do not justify their running either. This
addresses demand fluctuations and ensures that power procured from cheaper sources is fully utilized
and avoids procurement of power from costlier sources. The resultant benefit of reduced power
procurement cost or sale at a higher rate, whichever the case maybe, is in turn being passed on to the
consumers.
The following table shows the stations which are considered for partial backdown:
Stations
FY 17
1,262
3,162
1,808
2,023
MPPGCL - Shri Singaji STPS Phase -1 Unit 1
Backdown of Stations
FY 18
478
1,432
1,568
2,058
FY 19
504
1,203
1,249
1,495
Jaypee Bina Power Unit 1
Jhabua Power
NTPC-Kawas
967
996
1,266
126
765
978
1,133
-
-
-
912
961
905
743
326
Total
11,611
8412
8297
The following table shows the overall station wise availability of Discom allocated stations and
MPPMCL allocated stations after application of merit order dispatch and backdown for the period FY
2017 to FY 2019:
Category
FY 17
FY 18
FY 19
Availability from Stations allocated to MP Discoms
34,613
36,117
36,790
Availability from Stations allocated to MPPMCL
31,383
36,408
42,839
Total
65,995
72,524
79,628
3.5. Inter-State Transmission Losses
The Inter-State transmission losses have been computed separately for Eastern Region and Western
Region stations. For the Western Region, data for past 52 weeks (3-Nov-14 to 9-Nov-15) as available
on the POSOCO/ NLDC website has been taken and an average loss level of 3.77% has been
considered for FY 2015-16 and for MYT period FY 2016-17-FY 2018-19. Similarly, for Eastern
Region, average transmission line loss of 2.09% has been considered for FY 2015-16 and MYT
period FY 2016-17 to FY 2018-19
74
3.6. Management of Surplus Energy
As per the power supply position, the state is expected to have surplus energy in most of the months in
the ensuing year. Currently MPPMCL disposes the surplus power through power exchange (IEX) at
the prevailing rates. MPPMCL tries to sell such surplus power at a cost which is determined by the
market conditions prevailing at that time.
The IEX rate for the past three years is observed to be at Rs 2.55 per unit for FY 2012-13, Rs 2.38 per
unit for FY 2013-14 and Rs 2.49 per unit for FY 2014-15 and average IEX rate comes out to Rs 2.47
per unit. For the purpose of computation of revenue from surplus energy, the IEX rate is taken at Rs
2.50 per unit.
The energy surplus of the Discoms vis-à-vis overall energy availability and energy requirement as
well as the details of revenue from sale of energy are shown in the table below. This revenue has been
subtracted from the variable power purchase costs of MPPMCL allocated stations, while computing
the total power purchase costs of the Discoms.
Table 29: Management of Surplus Energy with Discoms for the MYT period FY 17-FY 19
Particulars
Units
FY17
FY18
FY19
Ex-bus energy available
MU
65,995
72,524
79,628
Ex-bus energy required by Discoms
MU
62,442
68,215
75,130
Surplus Energy
MU
3,553
4,309
4,498
Additional surplus due to RPO obligation
MU
1,677
2,372
3,289
MU
5,230
6,681
7,787
Rs. per unit
2.50
2.50
2.50
Rs. Cr.
1,308
1,670
1,947
Management of Surplus energy
Sale of total surplus energy via IEX
Rate of Sale of Surplus Energy
IEX
Revenue from Sale of Surplus Energy through IEX
75
3.7. Energy Balance
3.7.1. Energy Requirement vis-à-vis Availability and Management
of Shortfall
It is submitted that the energy requirement at Ex-bus of the three Discoms have been estimated to
ensure that Discom-wise shortfall or surplus of energy could be ascertained for planning the power
procurement. Accordingly, the Discom-wise break-up of energy envisaged to be procured from
various sources is shown in table below:
Table 30: Ex-Bus Purchases by Discoms from Various Sources
Particulars
East Discom
FY17
FY18
FY19
Energy Requirement Ex-Bus
20,271
22,225
24,566
Purchase from Discom Allocated Stations
10,430
10,772
11,055
Purchase from MPPMCL allocated Stations
9,841
11,453
13,511
Shortfall
-
-
-
Balance through STPP
Particulars
-
Central Discom
-
FY17
FY18
FY19
19,598
21,932
24,865
10,079
10,626
11,188
9,520
11,306
13,677
Shortfall
-
-
-
Particulars
-
West Discom
-
FY17
FY18
FY19
22,573
24,059
25,699
11,621
11,672
11,561
10,952
12,387
14,138
Shortfall
-
-
-
Particulars
-
MP State
-
FY17
FY18
FY19
62,442
68,215
75,130
32,129
33,069
33,804
30,313
35,146
41,326
Shortfall
-
-
-
-
-
-
76
4. Power Purchase Cost
4.1. Details of Costs for Stations allocated to MP Discoms
The fixed and variable costs of all stations have been considered as per the following methodology:

Discom allocated stations and a few MPPMCL allocated stations have been taken as per the
last 12 months bills i.e. from Nov 14 to Oct 15.
The Commission in clause no 1.24 of its Aggregate Revenue Requirement and retail supply tariff
order for FY 2015-16 has mentioned:
“The petitioners have requested vide letter dated 19th Mar 2015 for recovery of FCA with effect
from 1.4.2015 on the basis of variation in the variable rates of thermal generating stations for the
period from November, 2014 to January, 2015. While working out variable charges in this tariff
order, the Commission has considered the energy rates based on information filed by the
petitioners for the period Feb., 2014 to January, 2015. Therefore, the recovery of the FCA
separately with effect from 1.4.2015 is not required.”
The Petitioners, for the purpose of computation of power purchase costs has considered actual
station wise costs for the period Nov 14 to Oct 15 and requests the Hon’ble Commission to
consider the same and allow the FCA for the period April’16-June’16.
The following table provides a summary of fixed and variable costs for the Discom allocated stations:
Table 31: Fixed and Variable Costs of Discom Allocated Stations for MYT FY 2016-17 to FY 2018-19
Station
NTPC-Korba
NTPC-Vindyachal I
NTPC-Vindyachal II
NTPC-Vindyachal III
NTPC-Kawas
NTPC-Gandhar
KAPP
TAPS
NTPC - Kahalgaon 2
DVC (MTPS, CTPS)
ATPS - Chachai-Extn
CHPS-Gandhi Sagar
Pench THPS
Rajghat HPS
Bargi HPS
Birsingpur HPS
Banasgar Tons HPS
Marhi Khera HPS
Fixed Charges
(Rs. Cr.)
183.93
189.05
141.76
185.71
77.03
74.91
169.34
62.40
364.29
217.77
275.82
413.91
392.41
2.09
10.74
1.12
9.60
3.64
67.26
5.62
9.48
Variable Charge
(Rs./ kWh)
1.08
1.79
1.74
1.70
2.66
1.94
2.38
2.86
1.41
2.39
2.23
1.31
2.27
2.53
3.00
1.08
1.51
0.50
2.33
0.56
0.97
0.90
1.09
2.29
77
Station
Fixed Charges
(Rs. Cr.)
550.15
177.91
426.29
3.33
NHDC - Indira Sagar
Captive
Others(mini micro)
Sardar Sarovar
Omkareshwar HPS
Variable Charge
(Rs./ kWh)
0.40
2.22
3.27
0.82
0.35
0.40
The following table provides a summary of fixed and variable costs of each of the MPPMCL allocated
stations:
Table 32: Fixed and Variable Costs of MPPMCL allocated stations
Name of Project
Unit
MP
Share
(MW)
NTPC Korba -III
Unit 7
77.00
Fixed
Charg
es (Rs.
Cr.)
for
FY'17
83.39
Remarks
3 units
340.00
326.75
MPPGCL - Satpura
TPS Extension
MPPGCL - Satpura
TPS Extension
MPPGCL - Shri
Singaji STPS Phase -1
MPPGCL - Shri
Singaji STPS Phase -1
NTPC Vindhyanchal
MTPS, Stage - 4
NTPC Vindhyanchal
MTPS, Stage – 4
DVC DTPS
Unit
10
Unit
11
Unit 1
250.00
256.15
250.00
256.15
600.00
440.58
Unit 2
600.00
420.80
Unit 1
143.00
161.21
Unit 2
128.00
161.21
Unit 1
50.00
44.81
As per actual bills from Nov
14 to Oct 15
2.06
As per actual bills from
Nov 14 to Oct 15
DVC DTPS
Unit 2
50.00
44.81
Same As Unit no.-I
2.06
Same As Unit no.-I
UMPP Sasan
Unit 1
247.00
31.64
as per quoted tariff
1.15
UMPP Sasan
Unit 2
248.00
31.76
1.15
UMPP Sasan
Unit 3
&4
495.00
63.40
1.15
UMPP Sasan
Unit 5
&6
495.00
63.40
1.15
Jaypee Bina Power
Unit 1
175.00
287.74
14 to Oct 15
3.13
Nov 14 to Oct 15
Jaypee Bina Power
Unit 2
175.00
287.74
14 to Oct 15
3.13
Nov 14 to Oct 15
14 to Oct 15
14 to Oct 15
As per MPERC order dated
08.10.2013
08.10.2013
10.11.2014
18.03.2015
14 to Oct 15
Take as per unit no-1
Variable
Charges
(Rs./
kWh)
for FY
'17
1.06
1.38
2.14
1.99
2.54
2.54
1.74
1.74
Remarks
Nov 14 to Oct 15
Nov 14 to Oct 15
Nov 14 to Oct 15
Nov 14 to Oct 15
Nov 14 to Oct 15
Nov 14 to Oct 15
Nov 14 to Oct 15
Taken as per unit no.-1
78
Name of Project
Unit
MP
Share
(MW)
Jaiprakash Power,
Nigri
Unit 1
248.00
Fixed
Charg
es (Rs.
Cr.)
for
FY'17
237.31
Remarks
Jaiprakash Power,
Nigri
Unit 2
247.00
237.31
14 to Oct 15
0.69
MB Power
Unit 1
210.00
246.36
29th July 2015
1.77
Nov 14 to Oct 15
MB Power
Unit 2
210.00
246.36
29th July 2015
1.77
Taken equal to unit 1
BLA Power
Unit 1
16.00
21.77
14 to Oct 15
2.38
Nov 14 to Oct 15
BLA Power
Unit 2
16.00
21.77
14 to Oct 15
2.38
Taken as per unit 1
Jhabua Power
Unit 1
210.00
246.36
Taken equal to MB power
unit 1
3.13
Taken equal to Jp Bina unit
1
Lanco Amarkantak
Unit 1
300.00
310.17
14 to Oct 15
1.82
Nov 14 to Oct 15
NTPC Vindhyanchal
MTPS, Stage - 5
Unit 1
128.00
144.30
1.74
Taken equal to Vindhyachal
Stage 4
Renewable Energy Solar
NA
550.00
-
Taken proportionately as per
respective MW (i.e 128 M W
/280 MW)
-
7.03
As per Weighted avg
calculation
NA
1270.0
0
-
-
5.58
As per Weighted avg
calculation
14 to Oct 15
Variable
Charges
(Rs./
kWh)
for FY
'17
0.69
Remarks
As per average of the
actual bills from July 15 to
Oct 15
Taken as per unit 1
79
4.2. Merit Order Dispatch (MoD)
As already explained above, all plants have been considered to be allocated to MPPMCL and a
common MoD has been applied to all the plants after considering the backdown of selected stations as
explained above. However, for the ease of understanding, costs for each of the stations have been
given separately for MPPMCL allocated stations and Discom allocated stations. The MoD applied for
FY 17 is given in the following table:
Table 33: MoD of station for FY 17
Sl.No. Station
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
Availability (MU)
KAPP
777
TAPS
1,598
Renewable Energy - Solar
912
Renewable Energy - Other than Solar
2,382
Omkareshwar HPS
1,296
NHDC - Indira Sagar
45
3,035
Pench THPS
263
Bargi HPS
468
Jaiprakash Power, Nigri unit 1
1,608
Jaiprakash Power, Nigri unit 2
1,608
Sardar Sarovar
2,245
Banasgar Tons HPS
1,457
Birsingpur HPS
33
CHPS-Gandhi Sagar
159
105
NTPC Korba -III
553
NTPC-Korba
3,534
UMPP Sasan unit 1
1,604
UMPP Sasan unit 2
1,604
UMPP Sasan unit 3&4
3,209
UMPP Sasan unit 5&6
3,209
ATPS - Chachai-Extn
1,524
2,220
1,302
376
NTPC-Vindyachal III
1,732
NTPC-Vindyachal II
2,111
NTPC Vindhyanchal MTPS, Stage - 4 unit 1
922
NTPC Vindhyanchal MTPS, Stage - 4 unit 2
922
NTPC Vindhyanchal MTPS, Stage - 5
762
MB Power unit 1
1,361
MB Power unit 2
1,361
NTPC-Vindyachal I
2,714
Lanco Amarkantak
1,992
80
Sl.No. Station
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
MPPGCL - Satpura TPS Extension unit 11
Availability (MU)
1,171
NTPC-Gandhar
222
DVC DTPS
128
DVC DTPS
MPPGCL - Satpura TPS Extension unit 10
Captive
128
1,171
47
3,760
DVC (MTPS, CTPS)
2,096
Marhi Khera HPS
105
Rajghat HPS
33
BLA Power unit 1
49
BLA Power unit 2
49
NTPC - Kahalgaon 2
309
2,183
MPPGCL - Shri Singaji STPS Phase -1 unit 1
1,109
MPPGCL - Shri Singaji STPS Phase -1 unit 2
894
NTPC-Kawas
123
920
Jaypee Bina Power unit 1
194
Jaypee Bina Power unit 2
165
Jhabua Power
95
Others(mini micro)
42
Total
65,995
81
The following table shows the Total costs (fixed costs and variable costs) of Discom allocated stations
Table 34: Total Fixed Costs and Variable Costs of Discom Allocated Stations
FY 17
Stations `
East
Fixed Costs
Central
West
Total
East
Variable Costs
Central
West
Total
NTPC-Korba
60
66
58
184
124
138
120
382
NTPC-Vindyachal I
61
68
59
189
158
175
153
486
NTPC-Vindyachal II
NTPC-Vindyachal
III
NTPC-Kawas
46
51
45
142
119
132
115
367
60
67
58
186
96
106
93
294
25
28
24
77
11
12
10
33
NTPC-Gandhar
24
27
24
75
14
16
14
43
KAPP
-
-
-
-
60
58
67
185
TAPS
NTPC - Sipat Stage
II
NTPC - Kahalgaon 2
-
-
-
-
148
144
164
456
55
61
53
169
60
66
58
184
20
22
20
62
24
27
23
74
118
131
115
364
152
168
147
467
71
78
68
218
65
72
63
200
90
99
87
276
278
307
268
853
135
149
130
414
179
202
172
552
128
141
123
392
88
102
86
276
1
1
1
2
6
6
5
17
-
-
-
-
18
20
18
57
3
4
3
11
4
5
4
13
Rajghat HPS
0
0
0
1
2
3
2
8
Bargi HPS
3
3
3
10
9
9
8
26
Birsingpur HPS
1
1
1
4
1
1
1
3
Banasgar Tons HPS
Banasgar Tons HPSBansagar IV
(Jhinna)
Marhi Khera HPS
NHDC - Indira
Sagar
Captive
22
24
21
67
43
47
41
131
2
2
2
6
4
4
4
11
3
3
3
9
8
9
8
24
179
198
173
550
40
44
39
123
-
-
-
-
3
4
3
10
-
-
-
-
4
5
4
14
Sardar Sarovar
58
64
56
178
60
66
58
184
Omkareshwar HPS
UPPMCL(Rihand
Matatila)
Total
139
154
134
426
15
16
14
45
1
1
1
3
1
1
1
2
1,306
1,263
1,447
4,016
1,793
1,733
1,995
5,522
DVC (MTPS, CTPS)
ATPS - ChachaiExtn
STPS - Sarani-PH 1,
2&3
SGTPS - Bir'pur Extn
SGTPS - Bir'pur PH 1 & 2
CHPS-Gandhi Sagar
CHPS-RP Sagar &
Jawahar Sagar
Pench THPS
Others(mini micro)
82
FY 18
Stations
Fixed Costs
Variable Costs
East
Central
West
Total
East
Central
West
Total
NTPC-Korba
60
65
59
184
123
133
122
378
NTPC-Vindyachal I
62
66
61
189
158
171
156
485
NTPC-Vindyachal II
46
50
46
142
117
126
115
358
NTPC-Vindyachal III
61
65
60
186
95
102
93
291
NTPC-Kawas
25
27
25
77
22
23
21
66
NTPC-Gandhar
24
26
24
75
14
15
14
43
KAPP
-
-
-
-
58
58
63
179
TAPS
NTPC - Sipat Stage
II
NTPC - Kahalgaon 2
-
-
-
-
152
150
163
465
55
60
55
169
62
67
61
189
20
22
20
62
26
28
26
81
DVC (MTPS, CTPS)
119
128
117
364
148
160
146
454
ATPS - Chachai-Extn
STPS - Sarani-PH 1,
2&3
CHPS-Gandhi Sagar
CHPS-RP Sagar &
Jawahar Sagar
Pench THPS
71
77
70
218
65
70
64
199
90
97
89
276
278
301
275
854
135
146
133
414
236
257
233
726
128
138
126
392
259
285
255
800
1
1
1
2
5
6
5
16
-
-
-
-
18
19
18
55
4
4
3
11
4
5
4
13
Rajghat HPS
0
0
0
1
3
3
3
8
Bargi HPS
3
3
3
10
8
9
8
25
Birsingpur HPS
1
1
1
4
1
1
1
3
Banasgar Tons HPS
Marhi Khera HPS
22
24
22
67
38
42
38
118
2
2
2
6
4
4
3
11
3
3
3
9
7
8
7
22
NHDC - Indira Sagar
179
194
177
550
36
38
35
109
Captive
-
-
-
-
3
3
3
8
Others(mini micro)
-
-
-
-
10
11
10
31
Sardar Sarovar
58
63
57
178
51
55
51
157
Omkareshwar HPS
UPPMCL(Rihand
Matatila)
Total
139
150
137
426
14
15
13
42
1
1
1
3
1
1
1
3
1,310
1,293
1,412
4,016
2,014
1,988
2,183
6,185
83
FY 19
Fixed Costs
Stations
Variable Costs
East
Central
West
Total
East
Central
West
Total
NTPC-Korba
60
63
61
184
125
130
127
382
NTPC-Vindyachal I
62
64
63
189
158
165
160
483
NTPC-Vindyachal II
46
48
47
142
117
122
118
358
NTPC-Vindyachal III
61
63
62
186
96
100
97
293
NTPC-Kawas
25
26
26
77
22
23
22
66
NTPC-Gandhar
25
26
25
75
14
15
14
43
-
-
-
-
57
58
60
175
-
-
153
155
159
467
KAPP
TAPS
NTPC - Sipat Stage
II
NTPC - Kahalgaon 2
-
-
55
58
56
169
61
63
62
186
20
21
21
62
26
27
26
79
DVC (MTPS, CTPS)
119
124
121
364
155
162
157
475
ATPS - Chachai-Extn
STPS - Sarani-PH 1,
2&3
CHPS-Gandhi Sagar
CHPS-RP Sagar &
Jawahar Sagar
Pench THPS
71
74
72
218
66
69
67
202
90
94
91
276
283
295
287
865
136
141
137
414
244
256
247
746
128
134
130
392
289
305
293
887
1
1
1
2
5
6
5
16
-
-
-
-
19
20
19
57
4
4
4
11
4
4
4
13
Rajghat HPS
0
0
0
1
2
3
2
7
Bargi HPS
3
3
3
10
8
8
8
24
Birsingpur HPS
1
1
1
4
1
1
1
3
Banasgar Tons HPS
Marhi Khera HPS
22
23
22
67
39
41
40
119
2
2
2
6
4
4
4
11
3
3
3
9
7
7
7
22
NHDC - Indira Sagar
180
188
182
550
36
38
37
111
Captive
-
-
-
-
3
3
3
8
Others(mini micro)
-
-
-
-
6
6
6
18
Sardar Sarovar
58
61
59
178
54
56
55
165
Omkareshwar HPS
UPPMCL(Rihand
Matatila)
Total
140
145
141
426
14
14
14
42
1
1
1
3
1
1
1
2
1,315
1,331
1,370
4,016
2,069
2,094
2,163
6,326
84
The following table shows the Total costs (i.e. fixed costs and variable costs) of MPPMCL allocated
stations:
Table 35: Total Fixed and Variable Costs of fixed and variable costs of MPPMCL allocated stations
FY 17
Stations
NTPC Korba -III
Fixed
Costs (Rs
Cr)
83
FY 18
Variable
Costs (Rs
Cr)
59
Fixed
Costs (Rs
Cr)
83
FY 19
Variable
Costs (Rs
Cr)
60
Fixed
Costs (Rs
Cr)
83
Variable
Costs (Rs
Cr)
59
Extension Unit 10
Extension Unit 11
STPS Phase -1 Unit 1
STPS Phase -1 Unit 2
NTPC Vindhyanchal
MTPS, Stage - 4 Unit 1
NTPC Vindhyanchal
MTPS, Stage - 4 Unit 2
DVC DTPS Unit 1
327
306
327
317
327
309
256
251
256
269
256
252
256
233
256
265
256
239
441
282
441
345
441
385
421
227
421
220
421
277
161
160
161
217
161
176
161
160
161
217
161
176
45
26
45
26
45
29
DVC DTPS Unit 2
45
26
45
26
45
29
UMPP Sasan Unit 1
32
184
32
196
32
196
UMPP Sasan Unit 2
32
184
32
196
32
196
UMPP Sasan Unit 3&4
63
369
63
369
63
369
UMPP Sasan Unit 5&6
63
369
63
369
63
369
288
61
288
124
288
78
Unit 1
Unit 2
MB Power Unit 1
288
52
288
57
288
63
237
111
237
115
237
117
237
111
237
115
237
117
246
241
246
241
246
241
MB Power Unit 2
246
241
246
241
246
241
BLA Power Unit 1
22
12
22
12
22
12
BLA Power Unit 2
22
12
22
12
22
12
Jhabua Power
246
30
246
71
246
143
Lanco Amarkantak
NTPC Vindhyanchal
MTPS, Stage - 5
Phase-2, Unit 1
Phase-2, Unit 2
NTPC Lara STPS,
Rajgarh
Unit 1
Unit 2
310
363
310
358
310
355
144
133
144
144
144
144
-
-
-
-
421
264
-
-
-
-
421
116
-
-
345
155
345
247
-
-
433
159
433
305
-
-
433
1
433
269
85
FY 17
Stations
Fixed
Costs (Rs
Cr)
NTPC North Karanpura
STPS,
Renewable Energy Solar
Total
FY 18
Variable
Costs (Rs
Cr)
Fixed
Costs (Rs
Cr)
FY 19
Variable
Costs (Rs
Cr)
Fixed
Costs (Rs
Cr)
Variable
Costs (Rs
Cr)
-
-
-
-
71
13
-
641
-
704
-
785
-
1,329
-
1,353
-
1,420
4,673
6,171
5,885
6,953
6,798
8,000
The above MPPMCL costs after being adjusted for Surplus are again distributed among the three
Discoms according to the monthly energy requirement at state boundary for individual Discom .The
following table shows the segregation of MPPMCL costs among the three Discoms as per the
allocation for FY 17, FY 18 and FY 19 specified in table 22, 23 and 24 respectively:
Costs
Amount in Rs Cr
FY 17
FY 18
FY 19
Fixed Cost
4,673
5,885
6,798
Variable Cost
6,171
6,953
8,000
Total Costs
10,844
12,838
14,799
Less: Revenue from sale of surplus
(1,307)
(1670)
(1,947)
(236)
(291)
(320)
936
1,322
1,825
10,236
12,199
14,357
East Discom
3,322
3,975
4,694
Central Discom
3,212
3,923
4,751
West Discom
3,702
4,301
4,911
Net MPPMCL Costs
Additional RPO obligation
Total MPPMCL Costs
Share of :
86
4.3. RPO Cost
The Commission has notified Fifth Amendment to MPERC (Co-generation and generation of
electricity from Renewable sources of energy) (Revision-I) regulation, 2010 [ARG-33(I)(v)of 2015]
vide notification dated October 02, 2015. The Commission has considered procurement of power from
renewable energy sources through PPA or short term market to ensure RPO compliance.
As per regulation 4.1 of notified MPERC (Co-generation and generation of electricity from
Renewable sources of energy) (Revision-I) regulation, 2010 [ARG-33(I)(v)of 2015], the minimum
quantum of electricity is 1.25% for Solar and 6.50% for Non-Solar for FY 2016-17, 1.50% for Solar
and 7.00% for Non-Solar for FY 2017-18 and 1.75% for Solar and 7.50% for Non-Solar for FY 201819.
Accordingly the Petitioners have calculated the RPO requirement (which is already included in the
power purchase cost) is shown in the following table:
Table 36: RPO Obligation for MYT FY 17-FY 19
Renewable Purchase Obligation Computations
Solar
Other than Solar
Total
Exbus renewable energy requirement to fulfill RPO (MU)
Solar
Other than Solar
%
%
%
FY 17
1.25%
6.50%
7.75%
FY 18
1.50%
7.00%
8.50%
FY 19
1.75%
7.50%
9.25%
MU
MU
MU
781
4,059
4,839
1,023
4,775
5,798
1,315
5,635
6,950
MU
MU
MU
912
2,382
3,294
1,002
2,424
3,426
1,117
2,544
3,661
Shortfall
Solar
Other than Solar
MU
MU
1,677
21
2,351
198
3,091
Extra Surplus available after meeting RPO obligations
IEX rate
Additional revenue from sale of surplus due to RPO obligation
MU
Rs/unit
Rs Cr
1,677
2.50
419.21
2,372
2.50
593.07
3,289
2.50
822.15
Rs./unit
Rs./unit
5.05
5.58
5.05
5.58
5.05
5.58
Rs. Cr.
Rs. Cr.
Rs. Cr.
935.68
935.68
10.72
1,311.89
1,322.62
99.90
1,724.65
1,824.55
Energy Available from existing Renewable Sources
Solar
Other than Solar
Renewable Energy purchase Rates
Solar
Other than Solar
Additional Cost due to RPO Obligation
Solar
Other than Solar
RE Power Purchase from new/other sources to fulfill RPO
87
4.4. Estimation of Other Power Purchase Costs
4.4.1.Inter-State Transmission Charges
The Inter-State transmission charges to be paid by MP consist of charges to be paid for transmission
system of WR and ER. The actual inter-state transmission charges for FY 2013-14 amounted to Rs
1,235 Cr and the actual interstate transmission charges for FY 2014-15 amounted to Rs 1419 Cr. This
suggests an increase in inter-state transmission charges by 14.97% .However, only 2% has been
considered for projecting the Interstate transmission charges for FY 17 –FY 19.
Thus, the estimated Interstate transmission charges for FY 2016-17 –FY 2018-19 amounts to Rs 1,477
Cr, Rs 1,506 Cr and Rs 1,536 Cr respectively. These costs have then been allocated to Discoms based
on past trend of actual costs have been mentioned below:
Table 37: Inter-State Transmission Charges
Discom
FY 17
FY 18
FY 19
East Discom
456
465
475
Central Discom
441
592
603
West Discom
580
449
458
1,477
1,506
1,536
Total
4.4.2.Intra-State Transmission Charges – MPPTCL fixed costs excluding
Terminal Benefits (Cash Outflow)
For the purpose of calculation of intra-state transmission costs, the various expense items of
MPPTCL (other than terminal benefits liabilities) have been taken as approved by MPERC via
MYT Tariff Order for MPPTCL dated 2nd April’13.
The table below consists of two main components:
1. MPPTCL fixed costs as approved by MPERC in its order dated 2nd April’13 for FY 201516
2. SLDC charges as approved by MPERC via its order dated March 31, 2015 to the tune of
Rs. 9.70 Crores have been considered for FY’16. For FY’17, the annual SLDC charges
have been computed based on the transmission capacity of Discoms and the rate for Longterm Access Customers of Rs. 6674.96/ MW as approved by MPERC in the SLDC tariff
order for FY 15.
88
Table 38: Intra-state Costs – excluding Terminal Benefits
Sr.No.
1
2
3
4
5
6
7
A
B
Particulars
O&M Expenses
Depreciation
Interest & Finance charges
Interest on working capital
Return on Equity
MPERC Fees & Taxes
Less Non- tariff income
MPPTCL fixed cost approved by MPERC ( excluding terminal benefits)
SLDC Charges
Intra-State Transmission Charges allocated to Discoms
( excluding terminal benefits)
FY15-16 (MPERC order)
Rs Cr
390.09
297.16
92.92
52.69
305.57
1.27
-20.98
1,118.72
9.60
1,128.32
4.4.3.Intra-State Transmission Charges – Terminal Benefits (Cash
Outflow) to be included in MPPTCL costs
As per the provisions of the regulations, the liability towards pension and other Terminal Benefits
of the Pensioners and Personnel of the Board and its Successor Entities shall comprise of cash
outflow in each fiscal year for making payment to all the Pensioners including Existing Pensioners
subject to the provision of Regulation 3 (8)
As per the regulations, the aforementioned terminal benefits cash outflow has three parts:
a. For employees who have retired up to 01.06.2005 for services rendered up to 01.06.2005
b. For employees who will retire after 01.06.2005 for services rendered up to 01.06.2005
c. For employees who will retire after 01.06.2005 for services rendered after 01.06.2005
In the Retail Supply Tariff order for FY 2015-16, Hon’ble Commission under 3.86 stated as below:
“The Commission has allowed the terminal benefits and pension expenses for the FY 2015-16 on
provisional basis on ‘pay as you go’ principle payable to MP Transco to the extent of Rs.677
Crore.”
The Commission in the order dated August 12, 2015 vide order no-26/2015 has allowed terminal
benefits for FY 15-16 at Rs 1185.97 Cr. Hence the Intra-State Transmission charges come out to Rs.
2,315 cr. For projecting the Intra State Transmission charges for the period FY 2016-17-FY 2018-19 a
growth rate of 7% has been considered.
The following table shows the detail of total Intra-state Transmission Costs including the Terminal
Benefits (Cash Outflow) and its allocation amongst Discoms based on the past trend:
89
Table 39: Total Intra-State Transmission Costs and Allocation to Discoms (Rs Cr)
Sr.No.
Particulars
Total Intra-State Transmission Charges (including Terminal Benefits)
Allocation to Discoms
East Discom
West Discom
Central Discom
FY 17
2,476
FY 18
2,649
FY 19
2,835
740
957
779
792
1,024
834
847
1,095
892
Any difference over and above the claimed amount towards Terminal Benefits is proposed to be filed
as true-up petitions for the respective years.
4.4.4.MPPMCL Costs
The details of the MPPMCL expenses that have been allocated to Discoms for the MYT years are
related to the various roles, responsibilities and administrative functions of MPPMCL and have been
detailed in the Chapter 8. These expenses are allocated to the three Discoms based on the total energy
requirement at state boundary.
The details of these expenses and Discoms allocation are given in the table below:
Table 40: MPPMCL Costs: Details and Discoms Allocation (Rs Cr)
Particulars
FY '17
(estimated)
FY '18
(estimated)
FY '19
(estimated)
Purchase of Power
1.00
1.55
1.70
47.57
51.34
56.47
Depreciation Expenses
7.53
7.58
8.34
Interest and Finance Charges
29.16
14.42
15.86
Repairs and Maintenance Expenses
3.64
3.92
4.32
Employee Expenses
63.62
58.57
64.43
A&G Expenses
47.65
51.43
56.57
Other Expenses
-
-
-
MPPMCL Costs
200.17
188.81
207.69
Less: Other Income
436.03
479.63
527.60
Net MPPMCL costs
(235.86)
(290.82)
(319.90)
FY '17
FY '18
FY '19
East Discom
(75.15)
(91.92)
(100.16)
West Discom
(83.69)
(99.51)
(104.79)
Central Discom
(77.03)
(99.39)
(114.96)
Total
(235.86)
(290.82)
(319.90)
90
4.4.5.Total Power Purchase Costs
Based on the various cost components discussed above, the tables below detail the total power
purchase cost for MP state and for each of the Discoms.
Table 41: Total Power Purchase Costs - FY'17 to FY'19
Particulars
East Discom
FY '17
FY '18
FY '19
A
Ex-bus Units Purchased (MU)
20,271
22,225
24,566
B
Fixed Cost (Rs. Crs.)
2,826
3,230
3,540
C
Variable Cost (Rs. Crs.)
3,672
4,164
4,642
D
MPPMCL costs
(76.57)
(94.75)
(104.60)
E = B+C+D
Total Power Purchase Cost - Ex Bus (Rs. Crs.)
6,421
7,300
8,078
E/A
Rate of Power Purchase (Rs. / kWh)
3.17
3.28
3.29
H
External Losses (MU)
489
543
601
I
Inter State Transmission Cost (Rs. Crs.)
456
465
475
J = (A - H)
Units Purchased at State Periphery (MU)
19,783
21,682
23,965
K = (I + E)
Total Power Purchase Cost at State Boundary (Rs. Crs.)
6,877
7,765
8,552
J/K
Rate of Power Purchase at State Boundary (Rs. / kWh)
3.48
3.58
3.57
L
Intra State Transmission Cost - MPTransco including SLDC (Rs. Crs.)
740
792
847
M = (K+L)
Total Power Purchase Cost at Discom Interface (Rs. Crs.)
7,617
8,557
9,400
N
Transmission Loss (MU)
O = (K - N)
Units Purchased at Discom Boundary (MU)
O/M
Rate of Power Purchase at Discom Boundary (Rs. / kWh)
569
623
689
19,214
21,059
23,276
3.96
4.06
4.04
Particulars
Central Discom
FY '17
FY '18
FY '19
A
19,598
21,932
24,865
B
2,733
3,188
3,584
C
3,550
4,110
4,698
D
MPPMCL costs
(74)
(93)
(106)
E = B+C+D
6,209
7,204
8,177
E/A
3.17
3.28
3.29
H
472
536
609
I
441
449
458
J = (A - H)
19,126
21,396
24,256
K = (I + E)
6,649
7,654
8,635
J/K
3.48
3.58
3.56
L
779
834
892
M = (K+L)
7,429
8,488
9,527
N
550
615
697
91
O = (K - N)
O/M
18,576
20,781
23,558
4.00
4.08
4.04
Particulars
West Discom
FY '17
FY '18
FY '19
A
22,573
24,059
25,699
B
1,447
1,412
1,370
C
5,782
6,586
7,183
D
MPPMCL costs
(85)
(103)
(109)
E = B+C+D
7,144
7,896
8,444
E/A
3.16
3.28
3.29
H
542
586
627
I
580
592
603
J = (A - H)
22,031
23,473
25,072
K = (I + E)
7,724
8,488
9,047
J/K
3.51
3.62
3.61
L
957
1,024
1,095
M = (K+L)
8,680
9,511
10,143
N
633
675
721
O = (K - N)
21,398
22,798
24,352
O/M
4.06
4.17
4.17
Particulars
MP State
FY '17
FY '18
FY '19
A
62,442
68,215
75,130
B
8,689
9,901
10,814
C
11,321
12,790
14,205
D
MPPMCL Costs
(236)
(291)
(320)
E = B+C+D
19,773
22,400
24,698
E/A
3.17
3.28
3.29
H
1,503
1,664
1,837
I
1,477
1,506
1,536
J = (A - H)
60,939
66,551
73,293
K = (I - E)
21,250
23,906
26,235
J/K
3.49
3.59
3.58
L
2,476
2,649
2,835
M = (K+L)
23,726
26,556
29,070
N
1,752
1,913
2,107
O = (K - N)
59,187
64,638
71,186
O/M
4.01
4.11
4.08
92
5. O&M Expenses - Discoms
The O&M expenses based on the provisions of the regulation are as below:-
5.1. Employee Costs
As per the provision of the regulations, employee costs have been calculated as below:Table 42: Employee Cost
Particular
Employees Expenses
excluding arrears, DA, Terminal
Benefits
and incentives
Arrears
DA
Leave encashment
NPS/GTIS/EPF/PF and Others
Incentives
Total
East Discom
FY '17 FY '18 FY '19
Central Discom
West Discom
FY '17 FY '18 FY '19 FY '17
FY '18 FY '19
385
396
408
359
370
381
403
415
428
0
504
19
18
0
927
0
566
21
20
0
1,003
0
632
23
21
0
1,085
23
470
10
10
10
883
25
529
11
11
11
957
27
591
12
12
12
1,035
0
528
13
6
1
950
0
593
13
6
1
1,029
0
663
14
7
1
1,113
Major assumptions considered for calculation of Employee Costs for three Discoms are:
a. For the calculation of the DA, basic pay has been taken at the same level as notified in the
MPERC regulations. For computation of Dearness allowance, a 6% increase has been
considered for every six months for all three Discoms (every year in January and July).
Based on this, the DA as a percentage of Basic Salary (approved by MPERC) is shown in
the table below:
DA as percentage of Basic for first quarter - Apr to June
DA as percentage of Basic for 2nd and 3rd quarter - July to Dec
DA as percentage of Basic for 4th quarter - Jan to March
FY '17
125%
131%
137%
FY '18
137%
143%
149%
FY '19
149%
155%
161%
b. Incentive/ Bonus to be paid to the employees have been considered as per the previous
trend in the Audited Accounts.
c. Leave Encashment and PF/CFA/GTIS/NPS:
 It is pertinent to mention that MPPTCL is providing fund to Discoms, only to meet out
Terminal Benefits liability of Gratuity, Pension and Commutation of pension.

Other than these components, Discoms make payment of Leave Encashment and
PF/CFA/GTIS/NPS. Hence, expenses incurred on account of Leave Encashment and
PF/CFA/GTIS/NPS have been claimed separately in addition to the terminal benefits costs
claimed as part of Intra-State Transmission Charges in the total Power Purchase Costs of
Discoms.
d. The employee cost arising due to the eligibility of 3rd higher pay scale under assured
career progression scheme cannot be ascertained at this stage. Hence expenditure on this
account is not being considered in this petition. However, the same shall be accounted for
in true-up petition.
93
5.2. Administrative & General Expenses
As per the provision of regulation, A&G expenses have been calculated as below:Table 43: Administrative and General Expenses-As per Regulation (Rs. Cr.)
Particulars
A&G Expenses excluding MPERC fees and Taxes
Taxes payable to Government
MPERC Fees
Total
East Discom
FY
FY
FY
'17
'18
'19
168
179
192
4
5
5
1
1
1
173
184
198
Central Discom
FY
FY
FY
'17
'18
'19
96
103
110
2
2
2
1
1
1
98
106
113
West Discom
FY
FY
FY
'17
'18
'19
129
138
147
12
13
13
1
1
1
141
151
161
Major assumption considered for calculation of above A&G Expenses:
a. As per the provision of the para 34.1 of the regulation, norms of A&G expenses notified in
the regulation excludes Fees paid to the MPERC and Taxes payable to the government.
b. In view of above, Fees paid to the MPERC and Taxes payable to the government are
considered over & above the cost notified in the regulation.
5.3. Repair and Maintenance Expenses
As per the provision of regulation, R&M expenses have been calculated as below:Table 44: Repair and Maintenance Expenses-As per Regulation (Rs. Cr.)
Particulars
Opening GFA of FY year
R&M Expenses as 2.3% of GFA
East Discom
FY '17 FY '18 FY '19
6,920
8,348 10,006
159
192
230
Central Discom
FY '17 FY '18 FY '19
7,728
8,993 10,308
178
207
237
West Discom
FY '17 FY '18 FY '19
5,344
6,180
7,258
123
142
167
5.4. Gist of O&M Expenses
The Gist of O&M expenses as per the provisions of the regulation is summarized as below:Table 45: Gist of O&M expenses-As per Regulation (Rs. Crores)
Particulars
Employee Cost
(including arrears, DA and others)
A&G Expenses
R&M expenses
Terminal Benefits (Cash Outflow)
MPERC Fees
Total O&M expenses
FY '17
East Discom
FY '18 FY '19
Central Discom
FY '17 FY '18 FY '19
West Discom
FY '17 FY '18 FY '19
927
1,003
1,085
883
957
1,035
950
1,029
1,113
172
159
0
1
1,259
184
192
0
1
1,380
197
230
0
1
1,513
98
178
0
1
1,159
105
207
0
1
1,270
112
237
0
1
1,385
141
123
0
1
1,214
151
142
0
1
1,322
160
167
0
1
1,441
94
6. Investment Plan – Discoms
6.1.1. Capital Investment Plan
The three Discoms are undertaking various projects in the coming years for system strengthening and
reduction of distribution losses. The focus is on creation of new 33/11 kV S/s, bifurcation of
overloaded 33 kV feeders, feeder bifurcation of agricultural feeder at 11 kV level, Addl. / Aug of
PTRs, Installation of DTRs, conversion of bare LT line into AB Cables and replacement of service
lines etc.
The overall distribution loss of the system is the sum of technical and commercial losses. The
technical losses are mainly due to poor infrastructure which needs strengthening, renovation and upgradation of the capacity of lines, sub-stations and associated infrastructures. The commercial losses
are mainly due to pilferage of energy which can also be reduced to a large extent by re-engineering of
the system which requires capital investment and directed efforts. Discoms are working on both the
issues and the distribution losses have considerably come down but not up to the normative loss
levels.
Scheme wise Capital Expenditure Plan of Discoms for FY’16 to FY’19 is given in table below:
Table 46: Capital expenditure Plan (Rs. Crores)
Name of Scheme
New Ag Pumps-Kisan Anudan Yojna
System Strengthening (STN / TSP / SCSP)
ADB
Feeder Bifurcation -ADB
Feeder Bifurcation –REC
New EAP Scheme
RGGVY
R-APDRP(A+B)
Miscellaneous
SCADA
R-APDRP Part "B" CPF (75%)
DDUGJY
IPDS
Total
FY '17
Name of Scheme
FY '17
System Strengthening
Feeder Separation
New Pump Connection
ADB II
ADB III
RGGVY
RAPDRP Part A
RAPDRP Part B
HUDCO
IPDS
DDUGJY
112.50
396.50
18.00
74.40
77.60
121.00
144.00
57.16
1.22
2.32
116.51
410.32
192.00
1,723.53
87.87
224.70
168.23
98.45
66.17
129.80
29.82
92.68
0.00
68.00
404.69
East Discom
FY '18
106.50
323.33
3.60
174.40
94.40
27.00
150.00
12.01
0.00
0.00
24.49
355.30
204.00
1,475.03
Central Discom
FY '18
24.58
273.00
223.82
45.45
50.40
179.08
21.25
48.50
0.00
212.00
250.52
FY '19
105.00
421.01
0.00
40.00
20.00
0.00
163.50
0.00
0.00
0.00
0.00
65.26
40.00
854.76
FY '19
0.00
171.00
207.12
14.08
23.24
207.91
9.04
19.00
0.00
128.60
115.62
95
1,370.41
Total
Name of Scheme
FY '17
0.00
436.24
0.00
150.51
0.00
173.69
0.00
0.00
0.00
0.00
28.89
0.00
24.00
214.37
270.00
179.20
1,476.90
ADB
TSP and SCSP
GOMP (Equity)
FSP - ADB Loan
FSP Equity
New Agricultural pumps
Grant for Simhastha Mela
PFC Loan (ADB Counter Funds)
REC Loan (FS) Phase - I
ADB Loan (FS) Phase - II
RAPDRP (GOI)
JBIC
Others (New EAP)
RGGVY
IPDS
DDUGVY
Total
1,328.60
West Discom
FY '18
0.00
266.39
0.00
44.10
0.00
146.52
0.00
0.00
0.00
0.00
3.56
0.00
0.00
126.81
210.00
172.18
969.56
895.60
FY '19
0.00
251.58
0.00
0.00
0.00
172.16
0.00
0.00
0.00
0.00
3.56
0.00
0.00
48.09
0.00
98.39
573.78
6.1.2. Scheme Wise Capitalization
Following is the proposed scheme wise Capitalization Plan of Discoms:
Table 47: Scheme Wise Capitalization (Rs. Crores)
Name of Scheme
Capitalization of Opening CWIP
New Ag Pumps-Kisan Anudan Yojna
System Strengthening (STN / TSP / SCSP)
ADB
Feeder Bifurcation -ADB
Feeder Bifurcation -REC
New EAP Scheme
RGGVY
R-APDRP(A+B)
Miscellaneous
SCADA
R-APDRP Part "B" CPF (75%)
DDUGJY
IPDS
Total
Name of Scheme
System Strengthening
Feeder Separation
New Pump Connection
ADB II
ADB III
RGGVY
RAPDRP Part A
FY '17
189.41
83.25
293.40
13.32
57.36
62.80
76.10
100.80
39.55
2.07
3.94
80.51
245.10
115.20
1,362.80
FY '17
146.44
221.66
143.54
135.22
50.20
106.83
28.30
East Discom
FY '18
FY '19
126.27
0.00
105.00
106.95
344.05
386.80
10.08
4.68
122.96
87.20
86.48
53.84
60.20
32.30
137.40
155.55
30.46
15.03
1.34
0.24
2.55
0.46
62.03
30.65
327.37
221.28
172.40
119.60
1,588.60
1,214.60
Central Discom
FY '18
FY '19
74.64
24.95
247.00
212.34
187.66
204.35
84.05
40.37
54.40
39.97
145.15
183.64
25.48
16.86
96
136.73
0.00
35.50
260.17
1,264.59
RAPDRP Part B
HUDCO
IPDS
DDUGJY
Total
Name of Scheme
ADB
TSP and SCSP
GOMP (Equity)
FSP - ADB Loan
FSP Equity
New Agricultural pumps
Grant for Simhastha Mela
PFC Loan (ADB Counter Funds)
REC Loan (FS) Phase – I
ADB Loan (FS) Phase – II
RAPDRP (GOI)
JBIC
Others (New EAP)
RGGVY
IPDS
DDUGY
Central Govt. Assistance (FS)
REC(Departmental Works)
Equity for Nepa Ltd, Nepanagar
Capitalization of Opening CWIP
Total
FY '17
0.00
215.81
0.00
92.76
0.00
70.90
0.00
0.00
0.00
0.00
21.99
0.00
20.00
71.49
102.50
63.25
0.00
0.00
0.00
176.66
835.36
84.89
0.00
127.40
285.22
1,315.87
West Discom
FY '18
0.00
282.41
0.00
103.78
0.00
107.53
0.00
0.00
0.00
0.00
22.88
0.00
20.00
103.20
155.00
106.29
0.00
0.00
0.00
176.66
1,077.75
42.59
0.00
141.50
213.91
1,120.46
FY '19
0.00
345.30
0.00
103.78
0.00
150.57
0.00
0.00
0.00
0.00
23.77
0.00
20.00
115.22
155.00
130.89
0.00
0.00
0.00
176.66
1,221.19
6.1.3. CWIP
Following table shows the year wise bifurcation of CWIP of the three Discoms.
Table 48: CWIP (Rs. Cr.)
Particulars
Opening Balance of CWIP
Fresh Investment during the year
Investment capitalised
Closing Balance of CWIP
East Discom
FY '17 FY '18 FY '19
835
1,196
1,082
1,724
1,475
855
1,363
1,589
1,215
1,196
1,082
722
Central Discom
FY '17 FY '18 FY '19
943
943
943
1,370
1,329
896
1,265
1,316
1,120
1,049
956
718
West Discom
FY '17 FY '18 FY '19
2,192
2,834
3,015
1,477
970
574
835
788
562
2,834
3,015
3,026
97
6.1.4. Fixed Assets Addition
The year wise fixed assets addition is as follows:
Table 49: Fixed Assets Addition (Rs. Cr.)
Particulars
Land & land rights
Buildings
Hydraulic works
Other civil works
Plant & machinery
Lines, cables, networks
Vehicles
Furniture & fixtures
Office equipments
Capital Assets not belonging to the board
Intangible Assets
Total
East Discom
FY
FY
'18
'19
0
0
0
13
15
11
0
0
0
0
0
0
228
266
204
785
915
700
0
0
0
0
0
0
5
6
5
331
386
295
0
0
0
1,363
1,589
1,215
FY
'17
Central Discom
FY
FY
'18
'19
0
0
0
11
11
10
0
0
0
0
0
0
416
433
368
693
721
614
0
0
0
0
0
0
39
41
35
0
0
0
106
110
94
1,265
1,316 1,120
FY
'17
West Discom
FY
FY
'18
'19
0
0
0
12
14
16
0
0
0
2
2
2
193
240
269
473
586
658
0
0
0
1
1
2
15
18
21
135
209
246
5
6
7
835
1,078
1,221
FY
'17
98
7. Other Costs/ Income – Discoms
7.1. Depreciation
According to the applicable norms, Discoms have developed detailed depreciation model based on
rates specified by the Hon’ble commission in annexure-II of said regulation. The depreciation during
the year so worked out for FY’17 till FY’19 is shown below:
Table 50: Depreciation – as per regulation (Rs. Cr.)
Particulars
Land under Lease
Building
Hydraulic Works
Other Civil Works
Plant & Machinery
Line Cable Networks etc.
Vehicles
Furniture & fixtures
Office Equipments
Others (Assets not belonging to Company)
Intangible Assets
Total
East Discom
FY
FY
'18
'19
0
0
0
2
3
3
0
0
0
0
0
0
78
92
105
173
223
265
0
0
0
0
0
0
4
5
5
25
38
42
0
0
0
283
361
421
FY
'17
Central Discom
FY
FY
'18
'19
0
0
0
3
3
3
1
1
1
0
0
0
136
148
122
202
180
191
0
0
0
0
0
0
12
13
14
0
0
0
24
27
30
378
372
361
FY
'17
West Discom
FY
FY
'18
'19
0
0
0
3
0
0
0
3
4
0
0
0
85
92
99
111
126
143
0
0
0
0
0
0
2
2
3
30
35
42
2
2
3
234
262
294
FY
'17
7.2. Interest and Finance Charges
7.2.1. Interest on Project Loans
Regulation 31 provides the method of calculation of interest and finance charges on loan capital.
The methodology adopted for calculating Interest and Finance charges on project loan in tariff order
FY’16 has been adopted for projecting the interest and finance charges on project loan. The details are
elaborated in following table:
Table 51: Interest on Project Loans (Rs. Cr.)
Particulars
1. Opening balance of GFA identified as funded through debt
2. Addition to GFA during the year
3. Consumer contribution during the year/ Asset Constructed Under
RGGVY During the year
4. Net addition to GFA during the year (2-3)
5. 30% of addition to net GFA considered as funded through equity
(5=4*30%)
6. Balance addition to net GFA during the year funded through debt
(6=4-5)
7. Debt Repayment due during the year (equal to the depreciation
claim)
FY '17
1,793.03
1,362.80
603.49
East Discom
FY '18
2,041.46
1,588.60
577.08
FY '19
2,388.67
1,214.60
315.30
759.31
227.79
1,011.52
303.46
899.30
269.79
531.51
708.06
629.51
283.08
360.85
420.59
99
8. Closing balance of GFA identified as funded through debt
9. Average of loan balances
10. Weighted average rate of interest % on all loans
11. Total Interest on project loans (11=9*10)
12. Finance Charges
13. Total Interest on project loan and Finance charges
2,041.46
1917.24
10%
183.54
13.06
196.60
Particulars
(5=4*30%)
(6=4-5)
claim)
10. Total Interest on project loans
11. Finance Charges
FY '17
2,715.86
1,264.59
0.00
Particulars
(5=4*30%)
(6=4-5)
claim)
9. Average of loan balances
11. Total Interest on project loans (11=9*10)
12. Finance Charges
2388.67
2597.59
2215.06
2493.13
10%
10%
219.52
244.17
13.95
14.90
233.47
259.06
Central Discom
FY '18
FY '19
3,222.67
3,771.66
1,315.87
1,120.46
0.00
0.00
1264.59
379.38
1315.87
394.76
1120.46
336.14
885.21
921.11
784.32
378.40
372.12
361.49
3222.67
9%
289.05
33.33
322.37
4194.50
8%
322.97
29.57
352.54
FY '17
1173.83
658.70
0
3771.66
8%
311.32
32.54
343.86
West Discom
FY '18
1525.04
901.09
0
658.70
197.61
901.09
270.33
1,044.53
313.36
461.09
630.76
731.17
233.54
262.00
294.25
1,525.04
1,349.44
8%
102.90
9.77
112.67
2,017.46
1,771.25
9%
161.02
10.75
171.77
2,578.04
2,297.75
10%
234.05
11.82
245.87
FY '19
2017.46
1,044.53
0
100
7.2.2. Interest on Working Capital
The interest on working capital has been calculated on the basis of provisions of the Regulation and
shown in the table given below.
Hon’ble Commission while calculating working capital requirement deducts the amount of closing
balance of consumer security deposit from the gross requirement of working capital resulting which
the net working capital requirement for the Discoms is coming as negative. The Commission while
considering the negative working capital requirement has not allowed any amount towards interest on
working capital. Further it is prayed to the commission that consumer security deposit received during
the year can only be used as one of the component to calculate working capital, therefore it is prayed
to the commission to consider the consumer security deposit received during the year only for the
purpose of computing working capital requirement. Thus the licensees pray to allow expenses on
account of Working Capital interest after deducting the consumer security deposit received only
during the year.
Table 52: Interest on Working Capital (Rs. Cr.)
Particulars
A) 1/6th of annual requirement of inventory for previous year
B) O&M expenses
R&M expenses
A&G expense
Employee expenses
i) Total of O&M expenses
ii) 1/12th of total
C) Receivables
i) Annual Revenue from wheeling charges**
ii) Receivables equivalent to 2 months average billing of wheeling
charges
Total Working capital (A+B ii) - C ii))
Rate of Interest *
Interest on Working capital
For Retail Sale activity
Particulars
B) Receivables
i) Annual Revenue from Tariff and charges**
ii) Receivables equivalent to 2 months average billing
C) Power Purchase expenses
i) 1/12th of power purchase expenses
D) Consumer Security Deposit
Total Working capital (A+B ii) - C i) - D)
Rate of Interest *
Total Interest on working capital from wheeling activities
Total Interest on working capital from retail activities
Net Interest from working capital
Particulars
FY '17
10.86
East Discom
FY '18
13.02
FY '19
15.53
157.75
173.05
926.92
1257.73
104.81
0.00
0.00
0.00
189.10
184.40
1002.94
1376.43
114.70
0.00
0.00
0.00
225.64
197.81
1084.36
1507.80
125.65
0.00
0.00
0.00
115.67
10.0%
11.57
127.72
10.0%
12.77
141.18
10.0%
14.12
0.57
0.69
0.82
8071.03
1345.17
7617.47
634.79
520.24
190.72
10%
19.07
11.57
19.07
30.64
FY '17
9007.23
10028.77
1501.20
1671.46
8556.81
9399.79
713.07
783.32
555.61
593.39
233.21
295.57
10%
10%
23.32
29.56
12.77
14.12
23.32
29.56
36.09
43.68
Central Discom
FY '18
FY '19
101
10.40
12.24
14.24
177.74
98.29
883.25
1,159.29
96.61
206.83
105.59
957.39
1,269.81
105.82
237.09
112.97
1,034.57
1,384.63
115.39
107.01
10.00%
10.70
118.05
10.00%
11.81
129.62
10.00%
12.96
0.55
0.64
0.75
8,121.28
1,353.55
7,428.56
619.05
9,228.23
1,538.04
8,487.56
707.30
10,599.07
1,766.51
9,527.31
793.94
798.34
(63.29)
798.34
(50.81)
798.34
7.26
Rate of Interest *
10.00%
10.00%
10.00%
(6.33)
(5.08)
0.73
10.70
(6.33)
4.37
12.96
0.73
13.69
7.13
11.81
(5.08)
6.72
West Discom
FY '18
8.24
122.92
141.37
949.94
1,214.24
101.19
142.14
151.21
1,028.76
1,322.10
110.18
166.92
161.11
1,113.09
1,441.12
120.09
2.88
0.48
2.88
0.48
2.88
0.48
108.79
10.00%
10.88
118.90
10.00%
11.89
130.25
10.00%
13.03
1.78
2.06
2.42
9247.92
9925.58
10828.77
1541.32
1654.26
1804.79
B) O&M expenses
R&M expenses
A&G expense
Employee expenses
ii) 1/12th of total
C) Receivables
charges
Rate of Interest *
Particulars
B) Receivables
Particulars
B) O&M expenses
R&M expenses
A&G expense
Employee expenses
ii) 1/12th of total
C) Receivables
charges
Rate of Interest *
Particulars
B) Receivables
FY '17
FY '19
9.68
102
Rate of Interest *
7143.62
7896.22
8443.89
595.30
658.02
703.66
1162.74
-214.94
10.00%
1275.86
-277.55
10.00%
1388.98
-285.42
10.00%
-21.49
10.88
-21.49
0.00
-27.76
11.89
-27.76
0.00
-28.54
13.03
-28.54
0.00
7.2.3. Interest on Consumer Security Deposit
Interest on consumer security deposit has been paid to the consumers according to the Hon’ble
Commission’s regulation for security deposit. The table below shows the projections of Interest on
Consumer Security Deposit:
Table 53: Interest on consumer security deposit as per regulation (Rs. Crores)
Particulars
Interest on Consumer
Security Deposits
FY '17
East Discom
FY '18
FY '19
47
50
Central Discom
FY '17
FY '18
FY '19
53
72
79
FY '17
87
West Discom
FY '18
FY '19
105
115
125
As per regulations, interest on consumer security deposit has been calculated as per the bank rate of
RBI as on 1st April of relevant year which is at present 9% p.a.
103
7.3. Other Income
The main components of Non-Tariff Income are meter rent, wheeling charges, supervision charges,
sale of scrape and miscellaneous charges from consumers. Meter rent and miscellaneous charges have
been projected as a percentage of tariff income. Discoms have projected their Other Income based on
the actual revenue received during the previous years. The following table summarizes the same:
Table 54: Other Income (Rs. Cr.)
Particulars
Income from Investment, Fixed & Call Deposits
Interest on loans and Advances to staff
Interest on Advances to Suppliers / Contractors
Income/Fee/Collection against staff welfare activities
Miscellaneous receipts
Misc. charges from consumers (meter rent, etc)
Deferred Income (Consumer Contribution)
Wheeling charges
Income from Trading other than Power
(i.e sale of scrape, tender form)
Supervision charges
Total
East Discom
Central Discom
West Discom
FY '17 FY '18 FY '19 FY '17 FY '18 FY '19 FY '17 FY '18 FY '19
6
5
6
26
28
27
18
12
6
0
0
0
0
0
0
0
0
0
2
2
2
9
10
10
5
6
5
0
0
0
0
0
0
0
0
0
88
94
101
73
88
68
26
30
28
54
58
61
79
79
79
47
47
47
101
108
115
1
1
1
0
0
0
0
0
0
3
3
3
3
3
3
23
24
26
1
1
1
21
16
11
0
275
0
292
0
312
0
192
0
209
0
187
13
134
14
128
14
115
104
7.4. Return on Equity
Based on the provision of regulation, the calculation of return on equity is as follows:
Table 55: Return on equity as per regulation (Rs. Crores)
Sr. no.
FY '17
A1
Particulars
Gross Fixed Assets at the beginning of year (net of consumer
contributions)
Opening balance of GFA identified as funded through equity
A2
Opening balance of GFA identified as funded through debt
A
B
B1
B2
C1
C2
D1
D2
E
Sr. no.
A
A1
A2
B
B1
B2
C1
C2
D1
D2
E
Sr. no.
Proposed capitalisation of assets as per the investment plan (net of
consumer contribution)
Proportion of caplitalised assets funded out of equity, internal reserves
Balance Proportion of capitalised assets funded out of project loans (B - B1)
Normative additional equity (30% of B)
Normative additional debt (70% of B)
Excess / shortfall of additional equity over normative (B1-C1)
Excess / shortfall of additional debt over normative (B2-C2)
Equity eligible for Return (A1+(C1/2)) OR (A1+(B1/2)), whichever is
lower
Return on Equity (16% on E)
Particulars
contributions)
lower
B1
Particulars
contributions)
B2
A
A1
A2
B
East Discom
FY '18
FY '19
5,391.29
6,150.59
7,162.11
1,617.39
1,845.18
2,148.63
3,773.90
4,305.41
5,013.48
759.31
1,011.52
899.30
227.79
531.51
227.79
531.51
0.00
0.00
303.46
708.06
303.46
708.06
0.00
0.00
269.79
629.51
269.79
629.51
0.00
0.00
1,950.84
2,216.46
2,503.09
312.13
354.63
400.49
FY '17
Central Discom
FY '18
FY '19
7,727.95
8,992.54
10,308.41
2,318.38
5,409.56
2,697.76
6,294.78
3,092.52
7,215.89
1,264.59
1,315.87
1,120.46
860.49
404.10
379.38
885.21
481.11
-481.11
597.39
718.48
394.76
921.11
202.63
-202.63
366.15
754.31
336.14
784.32
30.01
-30.01
2,508.07
2,895.14
3,260.59
401.29
463.22
521.69
FY '17
West Discom
FY '18
FY '19
1,342.05
1,173.83
1,592.65
1,525.04
1,915.98
2,017.46
658.70
901.09
1,044.53
197.61
270.33
313.36
461.09
630.76
731.17
105
C1
C2
D1
D2
E
lower
0.00
0.00
197.61
461.09
0.00
0.00
270.33
630.76
0.00
0.00
313.36
731.17
1,467.35
1,754.32
2,099.16
234.78
280.69
335.87
7.5. Bad and Doubtful Debts
It is submitted that the Commission as per its Tariff Regulations has allowed bad and doubtful debts to
the extent of 1% of revenue from sale of power. The same provisions have been provided in the
previous year’s MYT regulations also. However, the Commission may observe that the Discoms have
actually been writing off bad debts of amount more than the prescribed 1% of revenue. Based on the
actual bad debts written off during the past years, the Discoms have projected the following as bad
and doubtful debts that may arise during the ensuing years.
Table 56: Bad and Doubtful Debts – As per regulation (Rs. Crores)
East Discom
Particulars
FY '17
FY '18
81
Central Discom
West Discom
FY '19 FY '17 FY '18 FY '19 FY '17 FY '18 FY '19
90
100
81
92
106
91
98
107
106
8. Income/Expenses of MPPMCL
As per item No.8 (ii) of State Govt. Notification No.2260-F-3-24-2009-XIII dt. 19/03/2013, M.P.
Power Management Company Limited has been supplying power to the Discoms at the tariff
determined/approved by MPERC and its own expenses are being distributed on actual basis in
proportion to the energy drawn by respective Discoms.
MPPMCL has been operating on “No Profit and No Loss” basis. Therefore, till now at the end of each
financial year, all the credits received by MPPMCL which formed the part of income of MPPMCL
(shown as “other income” in Form S-1) were being passed on to the Discoms in proportion to the
energy drawl by respective Discoms as a part of their Power Purchase Costs. The major components
of Annual Revenue Requirement of MPPMCL are detailed in this section.
8.1
Income
8.1.1
Revenue from operations (including Revenue Subsidy)
The revenue from sale of electricity is taken by Discoms in their ARR therefore it is not taken
in the ARR of M.P. Power Management Company Ltd.
8.1.2
Other Income
For FY 2014-15 other income is Rs 360.36 Crs of MPPMCL .The major components which
form part of other income are mainly the rebate received from the long term power suppliers
against timely payment made and credit on account of short term open access received from
PGCIL. The details of other income of MPPMCL received in FY 14-15 are as follows:
Particulars
Amount (in Crs)
i) Credit on A/c of open access share from long term transmission service providers
(PGCIL)
162.16
ii) rebate received on a/c of timely/prompt payments
173.71
iii) Generation based incentive
7.31
iv) Interest received (Includes interest on commitment advances)
2.72
v) Common Expense recoverable
v) Other Income
TOTAL
14.34
0.12
360.36
The other income for FY 15-16 and onwards is worked out by increasing the income of FY
2014-15 by 10%.
107
8.2
Expenses
In the Discom-wise ARR, the Discoms have considered power purchase cost station-wise and
their own O&M Expenses, Depreciation, Interest Charges etc. as per the provisions of
MPERC regulations.
However, there are certain costs pertaining to power purchase (as detailed below) which could
not be considered by the Discoms being not in their control/action. Such costs are therefore
included in the power purchase costs of Discoms as MPPMCL specific costs and are taken into
consideration in the ARR of MPPMCL, the details of which are given hereunder:-
8.2.1
Energy Purchase
For FY 2013-14 it includes:
a.
b.
c.
d.
Bills of power purchase of Rs. 41.43 Crs.
Liability for banking of energy of Rs (39.10) Crs.
Share of credit due to deviation in the bill of PGCIL of Rs. (3.68) Crs.
Purchase from others of Rs. 2.17 Crs.
(a) Bills of Power Purchase:
FY 2014-15 includes bills of generators listed above, which could not be passed to Discoms
through monthly bills. From FY 2015-16 onwards all the bills are likely to be passed through
the monthly bills to the Discoms, hence will be considered in ARR of Discoms.
(b) Liability for banking:
Beginning from the year 2007-08, MPPMCL has started the practice of exchange/banking of
energy with third parties outside the State of Madhya Pradesh whereby during availability of
surplus power in the state, energy is supplied to the parties facing shortage of power and in
case of power deficit in the sate the banked energy is taken by the Company. The Banking and
Exchange transactions do not involve any payment or receipts in terms of money for the power
transacted except the charges related to open access and trading margin payable to the party
through which such transaction is facilitated.
(c) Liability for Banking of energy of Rs. (39.10) Crs:
The Company has a liability to return 743.5 MU of banked energy, received during 2014-15,
which translates into a financial liability of about Rs.256.08 Cr considering cost per unit of Rs.
3.44 i.e. the average power purchase rate for 2014-15 calculated on the basis of total power
purchase cost except banking for FY 2014-15. During FY 2014-15, the Company had returned
885.13 MU of banked power received in 2013-14. This was translated in to a financial liability
of Rs.296.94 Cr @ Rs 3.35 per unit which was the average cost of power purchase for the year
2013-14. Therefore, a net banking liability of Rs. (39.10) Crs. is booked in FY 2014-15.For FY
14-15, the liability for banking of energy is calculated as follows:
108
Particulars
MUs to be returned at the end of FY 2014-15 =
743.50
MUs to be returned at the end of FY 2015-16 (decreasing the units of FY 2014-15 by
10%) =
669.15
Average purchase cost for F.Y. 14-15 =
3.44
Average purchase cost for F.Y. 15-16 (Increasing the rate of FY 2014-15 by 10%) =
3.78
Total amount of Banking Liability for FY 15-16 (Rs. Cr)
253.21
Credit for 743.5 MUs billed to Discoms in 2014-15 @ 3.44 Rs/unit
256.08
Net liability to be passed to Discoms for FY 15-16
-2.87
For FY 16-17 (Decreasing cost for FY 15-16 by 10%)
-2.59
For FY 17-18 (Decreasing cost for FY 16-17 by 10%)
-2.33
(d) Interstate Transmission charges
It includes open access charges for short term of Rs. 0.31 Crs. and open access charges for
banking of power of Rs. 40.53 Crs. The transmission charges for FY 2015-16 and onwards are
taken by increasing the expenses of FY 2014-15 by 7.93% p.a.
(e) Bills of PGCIL Transmission charges
In FY 2014-15, PCGIL passed the credit due to deviation in transmission charges of Rs. (3.68)
Crs. on MPPMCL. From FY 2015-16 onwards all such credits are likely to be passed through
the monthly bills to the Discoms, hence will be considered in ARR of Discoms.
8.2.2.
Power procurement cost:
Apart from the direct bill of power purchase as per REA/SEA and other heads under energy
purchase, some other expenses like open access charges etc on banking and short term power
purchase & sale have been included under this head.
The demand supply gap on day to day basis is managed through short term power procurement
and in case of surplus energy, the same is disposed off. Therefore, short term sale of power and
short term purchase of power are important activities undertaken to meet the power demand of
the State. Similarly, MPPMCL makes arrangements for energy banking with various utilities
throughout the year to meet the uneven demand of power in the State during monsoon season
and rabi period. Energy banking is a barter system, wherein units of energy are exchanged
without any financial transaction between the partners in banking arrangement, although some
operational expenses like trading margin, open access charges, RLDC/SLDC permission
charges etc. are incurred. The charges towards "banking of energy" reflect the notional cost of
the net liability of energy to be returned in the subsequent year and it is based on average
power purchase cost of the financial year concerned.
109
For all such short time arrangements for arranging power and disposing off power, the cost of
"open access charges" has also to be paid up to the delivery point.
All the above mentioned costs are included in the item 5 under the head "purchase of power
from other sources and Inter State Transmission charges" in Form S-1 submitted herewith in
respect of MPPMCL which contains relevant explanatory notes in respect of all the items
shown therein.
8.2.3.
Depreciation:
Depreciation is calculated as under:
Particulars
FY15
FY16
FY17
FY18
FY 19
Fixed assets
(i) Tangible assets
Gross Block
84.83
89.83
90.83
91.83
92.83
Depreciation*
2.52
3.11
3.58
3.64
4.39
(ii) Intangible assets
Gross Block
2.15
26.31
26.31
26.31
26.31
Depreciation**
0.31
2.13
3.95
3.95
3.95
Total Depreciation (i + ii)
2.83
5.24
7.53
7.58
7.62
*In case of tangible assets, here is an addition of Rs. 4 Crs on account of ERP Hardware in FY 2015-16. Apart from this,
an addition of Rs. 1 Crs. depreciable @ 10% appox is assumed for FY 2015-16 and onwards.
**In case of intangible assets, there is an addition of Rs. 24.16 crs on account of ERP development in FY 2015-16. For FY
2016-17 and onwards, no addition is assumed.
8.2.4.
Interest and Finance charges for power procurement:
As per the existing power purchase agreements, facility of Letter of Credit is to be provided to
power suppliers. The cost towards extending this facility of LC and other bank charges are
covered under item "Interest & finance charges" in Form S-1.
Further, interest & Finance charges also include the financing cost towards installment facility
in case of power purchase bills, interest due to tariff revision, Bank charges, Guarantee
Charges, commitment charges, Stamp duty, processing charges etc. FY 2014-15 these amount
to Rs. 84.85 Crs.
Interest paid to NHDC in FY 14-15 is Rs. 75.36 Crs. The total interest payable to NHDC as
per the financial arrangement for FY 2015-16 and onwards is as below:


FY 2015-16
FY 2016-17
FY 2017-18
Rs. 50.26 Crs.
Rs. 18.11Crs.
Rs. 2.49 Crs.
The other charges of Rs. 9.49 Crs. (i.e. Rs.84.85 Crs - Rs.75.36 Crs.) for FY 14-15 and
onwards is taken by increasing the expenses of FY 14-15 by 7.93% p.a
110
8.2.5.
Repairs and Maintenance:
For FY 2014-15 Repairs and Maintenance expenses consist of expense of Rs. 3.12 cr. The
Repairs and Maintenance expenses for FY 15-16 and onwards is taken by increasing the
expenses of FY 14-15 by 7.93% p.a.
8.2.6.
Salary, A&G and Asset management expenses:
(a) Employee expenses:
The employee costs for FY 14-15 is Rs. 57.81 Crs. The employee cost for FY 2015-16 and
onwards is calculated as under:Table 60: Employee particulars
Particulars
FY15
(a) Total Employee Cost (In Rs. Crs.)
(b) No of employees
57.81
754
(c) Cost per employee (a/b)
0.077
(d) (Basic + grade pay)/ per employee (assumed to
be 50% of total salary)
0.038
Table 61: Employee expenses (Rs. Cr.)
Particulars
FY16
(a) Total Employee Cost (In Rs. Crs.)
FY17
FY18
FY19
733
705
627
667
(b) (Basic + grade pay)/ per employee (Increased
by 3% every year)
0.038
0.039
0.039
0.039
(c) DA and other cost per employee (DA assumed
to increase by 7.5% each year.)
0.049
0.052
0.055
0.058
(d) Total per employee Cost (b + c)
0.087
0.090
0.093
0.097
(e) Total employee cost in Rs. Crs. ( d*a)
63.84
63.62
58.57
64.43
(b) Administration and General expenses:
It includes expenses on sale of power i.e. in case of short term sale of energy by MPPMCL to
third parties, MPPMCL incurs:
i) Open Access Charges to the point of delivery as per agreement.
ii) Prompt payment rebate to the purchasers as per PPA.
Similarly, in case of sale of power through the power exchanges, MPPMCL bears the:
i) Transmission open access charges
ii) Fee of Rs.0.02 per unit payable to the concerned exchange for facilitating trading
through the exchange
The total A&G expenses for FY 14-15 amounts to Rs 40.91 Crs. The administration expenses
for FY 15-16 and onwards is taken by increasing the expenses of FY 14-15 by 7.93% p.a.
111
The rate (7.93% p.a.) by which expenses have been increased each year for projection is equal
to the inflation rate given in clause 34.6 of the MPERC regulation " Regulation for the control
period from FY 13-14 to FY 15-16 on terms and condition for determination of tariff for
supply and wheeling of electricity and methods of principles for fixation of charges."
112
9. Annual Revenue Requirement
9.1. Annual Revenue Requirement of MPPMCL
The table below details the Annual Revenue Requirement of MPPMCL. The Net Expenses are
included as a part of Power Purchase Costs of Discoms.
Table 62: Summary of ARR for MPPMCL (Rs. Cr.)
Particulars
Expenses:
Purchase of Power
Inter-State Transmission charges
Intra-State Transmission (MP Transco) Charges
SLDC Charges
Depreciation and amortization expenses
Interest & Finance Charges
Repairs and Maintenance
Employee costs
Administration and General expenses
Net prior period credit charges
Other Expenses
Total Expenses
Revenue from Operations
Profit/(Loss) for the period
FY 17
FY 18
FY 19
1.00
47.57
1.55
51.34
1.70
56.47
7.53
29.16
3.64
63.62
47.65
0
0
200.17
436.03
235.86
7.58
14.42
3.92
58.57
51.43
0
0
188.81
479.63
290.82
8.34
15.86
4.32
64.43
56.57
0
0
207.69
527.60
319.90
9.2. Annual Revenue Requirement of Discoms
Summary of the Aggregate Revenue Requirement of the Discoms calculated on the basis of
provisions of the regulation (including the impact of true up costs of Discoms for FY 2005-06;
Transco true up of FY 2013-14 and MPGenco true-up for FY 2012-13) is detailed in the table on next
page.
113
Table 63: Summary of ARR of Discoms as per the Regulation (Rs. Crores)
Particulars
FY '17
Revenue
Revenue from sale of power (Inclusive of tariff subsidy)
Other income (excluding DPS)
Total Revenue or Income
Expenditure
Purchase of Power cost (Ex-Bus, including MPPMCL costs allocated to
Discoms)
Inter-State Transmission charges
Intra-State Transmission charges (MPPTCL costs including SLDC
charges)
Repairs and Maintenance
Employee costs
Administration and General expenses (including MPERC fees)
Other Expenses
Less :Expenses Capitalised
Total Expenses
PBDIT
Depreciation and Related debits
PBIT
Interest & Finance Charges
Profit/Loss before Tax and ROE
Tax
RoE
Profit/Loss after Tax and RoE
ARR (Income from Sale of power + Gap)
Average Cost of supply
East Discom
FY '18 FY '19
Central Discom
FY '17 FY '18 FY '19
FY '17
West Discom
FY '18 FY '19
FY '17
MP State
FY '18 FY '19
8,071
275
8,346
9,007
292
9,299
10,029
312
10,341
8,121
192
8,313
9,228
209
9,438
10,599
187
10,787
9,114
134
9,248
9,797
128
9,926
10,714
115
10,829
25,306
601
25,907
28,033
629
28,662
31,342
614
31,956
6,421
7,300
8,078
6,209
7,204
8,177
7,144
7,896
8,444
19,773
22,400
24,698
456
465
475
441
449
458
580
592
603
1,477
1,506
1,536
740
792
847
779
834
892
957
1,024
1,095
2,476
2,649
2,835
158
927
173
1
81
0
8,957
189
1,003
184
1
90
0
10,024
226
1,085
198
1
100
0
11,009
178
883
98
0
81
0
8,669
207
957
106
0
92
0
9,850
237
1,035
113
0
106
0
11,018
123
950
141
0
91
0
9,986
142
1,029
151
0
98
0
10,932
167
1,113
161
0
107
0
11,691
458
2,760
413
1
253
0
27,612
538
2,989
441
1
280
0
30,806
630
3,232
472
1
313
0
33,718
-611
283
-894
274
-1,168
-725
361
-1,086
320
-1,406
-668
421
-1,089
356
-1,445
-356
378
-735
399
-1,133
-412
372
-784
430
-1,214
-231
361
-593
453
-1,046
-738
233.54
-971
217.32
-1,189
-1,006
262
-1,268
287
-1,554
-862
294
-1,156
371
-1,527
-1,705
895
-2,600
890
-3,490
-2,144
995
-3,138
1,036
-4,175
-1,762
1,076
-2,838
1,180
-4,018
312
-1,480
355
-1,761
400
-1,845
401
-1,534
463
-1,677
522
-1,568
234.78
-1,423
281
-1,835
336
-1,863
948
-4,438
1,099
-5,273
1,258
-5,276
9,551
6.07
10,768
6.17
11,874
6.08
9,656
6.42
10,906
6.40
12,167
6.23
10,537
5.92
11,633
6.09
12,577
6.13
29,744
6.13
33,306
6.21
36,618
6.14
114
Particulars
FY '17
Impact of True-up for MP Discoms for FY2005-06
Impact of True up for MP Transco for FY 2013-14
Impact of True up for MP Genco for FY 2012-13
Total ARR (Including True Up)
Total Revenue Gap (including True-up)
Average Cost of Supply (including true-up)
East Discom
FY '18 FY '19
104
-34
91
9,713
-1,642
6.17
10,768
-1,761
6.17
11,874
-1,845
6.08
Central Discom
FY '17 FY '18 FY '19
125
-32
87
9,835
-1,714
6.54
10,906
-1,677
6.40
12,167
-1,568
6.23
FY '17
West Discom
FY '18 FY '19
138
-38
103
10,740
-1,626
6.04
11,633
-1,835
6.09
12,577
-1,863
6.13
FY '17
366
-104
281
30,288
-4,982
6.24
MP State
FY '18 FY '19
33,306
-5,273
6.21
36,618
-5,276
6.14
115
10. Terminal Benefits (Pension, Gratuity and Leave Encashment) Provision
The Terminal Benefit of the employees have been calculated as per the provisions of “MPERC (Terms and Conditions for allowing pension and terminal benefits
liabilities of personnel of Board and successor entities) regulations, 2012 (G-38 of 2012)” notified in the MP gazette notification dated 20th April 2012. In view of
provisions of the MPERC (Terms and Conditions for allowing pension and terminal benefits liabilities of personnel of Board and successor entities) regulations,
2012, Discoms claim both provision as per the rate prescribed in actuary report & actual cash out flow on account of terminal benefits.
According to actuarial valuation the liability as on 31st March 2009 for the three Discoms was determined. In addition to this liability, the Actuary valuation has
prescribed the following percentage for the future contribution rate (as a % age of Basic Pay + Grade pay + DA) required to be made by the three Discoms for
meeting the liabilities arising due to future service:
Table 64: Future Contribution rate of liability on account of Actuary
Assumption
Pension
Contribution
rate
Discount rate
21.73%
East Discom
Gratuity
Leave
Encashme
nt
4.95%
0.77%
7.00%
7.00%
Total
7.00%
Pension
27.45%
20.15%
7.00%
7.00%
Central Discom
Gratuity
Leave
Encashme
nt
4.56%
0.54%
7.00%
7.00%
Total
Pension
25.25%
20.28%
7.00%
7.00%
West Discom
Gratuity
Leave
Encashme
nt
4.67%
0.59%
7.00%
Total
25.54%
7.00%
7.00%
According to the above prescribed methodology, liability for FY 2016-17 to FY 2018-19 has been worked out and this liability is pertaining to all the employees
of licensee, eligible for such benefits. Terminal Benefits Provisions calculations are provided in table below:
Table 65: Calculation of Terminal Benefits Provisions (Rs. Crores)
FY '17 - East Discom
Leave
Gratuit encash
Pension
y
ment
Provision as on
31.03.2016
1,505
303
67
Total
1,874
FY '17 - Central Discom
Leave
Pensio Gratuit encash
n
y
ment
Total
1,260
220
70
1,550
FY '17 - West Discom
Leave
n
y
ment
Total
1,236
252
57
1,545
Pensio
n
4,001
FY '17 – MP State
Leave
Gratuit encashm
y
ent
775
195
Total
4,970
116
Discount @7%
Current Service cost
Yearly salary
Contribution
Total Provision for
FY 2017
105
21
5
889
889
889
193
44
7
298
65
12
Leave
Gratui encashm
Pension
ty
ent
Provision as on
31.03.2017
Discount @7%
Yearly salary
Contribution
Total Provision for
FY 2018
88
15
5
829
829
829
244
167
38
4
375
255
53
9
Total
109
87
18
4
931
931
931
209
189
43
5
318
276
61
9
Leave
n
y
ment
Total
368
79
2,250
1,515
274
79
1,868
1,512
313
67
126
26
6
157
106
19
6
131
106
22
5
962
209
962
48
962
7
264
899
181
899
41
899
5
227
1,008
205
1,008
47
335
73
13
422
287
60
10
358
310
69
Total
Leave
n
y
ment
Total
108
280
54
14
2,540
2,540
2,540
238
527
120
16
664
346
829
179
30
1,039
FY '18 – MP State
Leave
Gratuit encashm
y
ent
Total
Leave
n
y
ment
Total
1,803
Leave
Gratuit encash
Pension
y
ment
Provision as on
31.03.2018
Discount @7%
Yearly salary
Contribution
Total Provision for
FY 2019
131
1,891
Pensio
n
348
4,830
954
225
6,009
132
338
67
16
421
1,008
6
258
2,870
595
2,870
136
2,870
18
749
11
390
933
203
34
1,169
Leave
n
y
ment
Total
2,139
441
92
2,671
1,803
334
90
2,226
1,822
382
78
150
31
6
187
126
23
6
156
128
27
5
1,040
226
1,040
51
1,040
8
286
972
196
972
44
972
5
245
1,091
221
1,091
51
376
82
14
473
322
68
12
401
349
78
2,281
Pensio
n
FY '19 – MP State
Leave
Gratuit encash
y
ment
Total
5,763
1,157
259
7,179
160
403
81
18
503
1,091
6
279
3,103
643
3,103
147
3,103
20
810
12
438
1,047
228
38
1,312
The Discoms are mandated to contribute an annual contribution towards the Trust for the purpose of Terminal Benefits. An amount of Rs. 4,970 crores is
expected to have got accumulated until FY2016. However, the Discoms have not been able to contribute the same towards the Trust as the Hon’ble Commission
117
has not allowed any amount for the same. The table given below indicates the actual provisions that are to be made by the Discoms against this liability in the
annual accounts of the company from FY 2009-10 till FY 2014-15 and projected for FY 2015-16 to FY 2018-19:
Table 66: Terminal Benefits Provisions Liability for Discoms (Rs. Cr.)
Particular
Past Service Liability
as determined by
actuary
(From 1.6.2005 to
31.3.2009)
2009-10
2010-11
2011-12
2012-13
2013-14
2014-15
2015-16
Total up 2016
2016-17
2017-18
2018-19
Total up 2019
Pensio
n
East Discom
Leave
Grat
Encash
uity
ment
Total
Liabilit
y
Pensio
n
Central Discom
Leave
Gratuity Encash
ment
Total
Liabilit
y
Pensio
n
West Discom
Leave
Gratui
Encash
ty
ment
Total
Liabilit
y
Pensio
n
MP State
Leave
Gratui
Encashme
ty
nt
Total
Liabilit
y
362
58
21
441
326
53
21
399
349
52
20
421
1,037
163
62
1,261
101
119
139
157
185
205
236
1,505
298
21
25
30
34
40
44
51
303
65
4
5
6
6
7
8
9
67
12
126
150
174
197
232
258
297
1,874
375
103
80
78
90
170
190
222
1,260
255
17
13
13
15
26
39
46
220
53
7
5
5
6
11
7
8
70
9
127
99
96
111
207
236
276
1,550
318
102
74
79
83
166
183
201
1,236
276
23
17
18
20
36
40
44
252
61
3
2
2
10
6
7
7
57
9
128
93
99
113
208
230
253
1,545
346
305
273
296
330
521
579
659
4,001
829
61
55
61
68
102
124
141
775
179
14
12
13
22
24
22
25
195
30
381
341
370
420
648
724
826
4,970
1,039
335
376
2,514
73
82
523
13
14
106
422
473
3,144
287
322
2,124
60
68
401
10
12
101
358
401
2,627
310
349
2,171
69
78
460
11
12
89
390
438
2,719
933
1,047
6,810
203
228
1,385
34
38
297
1,169
1,312
8,490
The Discoms humbly pray to the Hon’ble Commission to allow at least a nominal amount towards the Trust so as to enable the Discoms to contribute to the Trust
and avoid a one-time burden on the Discoms. It is pertinent to mention that such terminal benefits liabilities provision has not been included in the
computation of final Annual Revenue Requirement for Discoms. Instead, the terminal benefits (Cash Outflow), based on actual trends have been included as
part of Intra-State Transmission Charges in the total Power Purchase Costs of Discoms.
118
ARR and Tariff Petition for FY 2016-17
11. Power Purchase Cost Adjustment (PPCA)
11.1. The Hon’ble Commission in Tariff Order for FY’16 has specified formula for deriving
Fuel Cost Adjustment (“FCA”) for recovery/adjustment of un-controllable costs due to
increase or decrease in the cost of fuel in case of coal, oil, and gas for generating plants
only. The petitioners in their last year petition also submitted that the then existing PPCA
calculation mechanism did not cover the recovery of incremental power purchase, which
includes shortage in supply from identified power supply sources in the tariff order
requiring distribution licensee to purchase power at higher price from the power market or
other sources to meet the demand.
11.2. Distribution 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. For the purpose of tariff determination,
the average power purchase cost per unit based on the prudent cost may be considered.
This means that the cost based on the average power purchase cost per unit on the quantum
of power based on normative loss should be passed on to the consumer and any cost in
excess of that shall be borne by the licensee. In any case, the full fixed cost element of the
power purchase cost should also be passed on to the consumer as a legitimate cost. This
methodology shall maintain proper balance between the interests of the consumers and the
licensee, as it is based on overall averaging method, so that impact of all the factors over
an annual cycle are covered and distributed equitably.
11.3. The Commission however on the analysis of the same has come out with the following
formula
𝒑
𝑰𝑽𝑪 (𝑹𝒔. 𝒊𝒏 𝑪𝒓. )𝒙𝟏𝟎𝟎𝟎
𝑭𝑪𝑨 𝒇𝒐𝒓 𝒃𝒊𝒍𝒍𝒊𝒏𝒈 𝒒𝒖𝒂𝒓𝒕𝒆𝒓 ( ) =
𝒖
𝑵𝒐𝒓𝒎𝒂𝒕𝒊𝒗𝒆 𝑺𝒂𝒍𝒆 (𝑴𝑼𝒔)
 Where,
 IVC = sum of – (a) difference in per unit variable cost actually billed by each long term
coal or gas based power generator and variable cost as allowed in the Tariff Order,
multiplied by (b) units availed from each such generating station in the preceding
quarter. Variable costs of Hydel Generating Stations shall not be considered for the
purpose of working out the increase in variable Cost of Power Purchase.
 Preceding Quarter = the period of preceding three months excluding the period of two
months immediately preceding to the billing quarter,
 Billing Quarter = the period of three months for which FCA is to billed and shall be a
period commencing on first day to last day of quarter for the quarter commencing from
1st April ending 30th June and so on
119
11.4. However the petitioners feel that the average power purchase cost should be considered
instead of the variable costs only. Hence, the Distribution Licensee, in line with the above
provision resubmits the following formula for computation of Power Purchase Cost
Adjustment (PPCA) factor for Hon’ble Commission’s kind consideration:
𝑝
𝐴𝑃𝑃𝐶 (𝑅𝑠. 𝑖𝑛 𝐶𝑟. )𝑥1000
𝑃𝑃𝐶𝐴 𝑓𝑜𝑟 𝑏𝑖𝑙𝑙𝑖𝑛𝑔 𝑞𝑢𝑎𝑟𝑡𝑒𝑟 ( ) =
𝑢
𝑁𝑜𝑟𝑚𝑎𝑡𝑖𝑣𝑒 𝑆𝑎𝑙𝑒 (𝑀𝑈𝑠)
 Wherein,
 “APPC” shall mean Average Power Purchase Cost which is sum of – (a) difference in
per unit average cost actually billed by each power generator/sources and as allowed in
the tariff order, multiplied by (b) units availed from each such generating station in the
preceding quarter.
 “Preceding Quarter” means period of preceding three months excluding the period of
two months immediately preceding to the billing quarter.
 “Billing quarter” means the period of three months for which PPCA is to be billed and
shall be a period commencing on first day to last day of quarter for the quarter
commencing from 1st April ending 30th June and so on.
 “Normative Sale” means the sale grossed down from the total actual ex-bus drawl from
all sources (Generators + Other sources) during preceding quarter by the normative
PGCIL, transmission and distribution losses for the months of the preceding quarter as
provided in the tariff Order.
11.5. PPCA charge shall be in the form of paise per unit (kWh) rounded off to the nearest
integer. For this purpose, fraction up to 0.5 shall be ignored and fraction higher than 0.5
shall be rounded off to the next higher integer. This charge shall be added to or deducted
from, as the case may be, the energy charges as per the existing tariff for the energy billed
to every consumer and shall be treated as part of energy charge.
11.6. The PPCA charge shall be uniformly applicable to all categories of consumers of the
Distribution Companies in the State. The PPCA charge shall also be uniformly applicable
to all categories of open access consumers for the quantum of such supply as is availed by
them from the Distribution Companies.
11.7. The National Tariff Policy prescribes the following formula for determination of crosssubsidy surcharge for various categories of consumers.
“8.5 Cross-subsidy surcharge and additional surcharge for open access
Surcharge formula:
S = T – [C (1+L/100) D]
120
Where,
S is the surcharge
T is the Tariff payable by the relevant category of consumers;
C is the Weighted average cost of power purchase of top 5% at the margin excluding
liquid fuel based generation and renewable power.”
D is the Wheeling charge
L is the system Losses for the applicable voltage level, expressed as a percentage
Since on PPCA charge is a part of energy charge and uniformly applicable to all categories
of consumers, therefore average tariff will change to the tune of applicable PPCA charge.
Therefore it will be more appropriate to add per unit PPCA rate in the formula for
determination of cross subsidy surcharge for various categories of consumers under the
term “T”.
11.8. The M.P. Power Management Co. Ltd., Jabalpur is a holding company and has been
authorized by the Distribution Companies to procure power on behalf of them for retail
supply to consumers. The responsibility of working out the rate of PPCA every quarter
shall rest with the M.P. Power management Co. Ltd., Jabalpur.
11.9. The M.P. Power management Co. Ltd., Jabalpur shall workout change in average cost of
power purchase during the preceding quarter based on the bills received by them from the
Generators. The information shall be prepared in the manner as decided by Commission in
the Tariff Order for every month of the “preceding quarter” and summated thereafter for
the quarter:
11.10. The M.P. Power management Co. Ltd., Jabalpur shall workout “normative sale”. For this
purpose normative PGCIL, transmission and distribution loss (percentage /quantum) for
the months of preceding quarter, as provided in the Tariff Orders, shall be subtracted from
the total ex-bus power drawn during the preceding quarter to arrive at normative sale.
11.11. PPCA charge shall be worked out by the M.P. Power management Co. Ltd., Jabalpur based
on the formula provided by the Commission. The Distribution Companies of the State shall
be advised by them from time to time to incorporate the PPCA charge for billing purposes
for the billing quarter. This exercise should be completed at least 15 days before the
commencement of the billing quarter. The M.P. Power management Co. Ltd., Jabalpur
shall simultaneously submit all relevant details of calculations along with supporting
details to the Commission within 7 days of the completion of the exercise.
121
11.12. If the Commission finds after reviewing the details submitted by the M.P. Power
management Co. Ltd. Jabalpur, any over or under recovery of PPCA charge, it may direct
the M.P. Power management Co. Ltd., Jabalpur and the Distribution Companies of the
State to make required changes in PPCA charge billing and any further adjustments in
consumer bills that it may consider appropriate.
11.13. The Distribution Companies of the State shall commence billing of PPCA charge from the
first day of the billing quarter.
11.14. Following illustration is given for the purpose of understanding:
If the “billing quarter” is say “July to Sept”, then the “preceding quarter” shall mean the period
“Feb to April” and the period of May and June months is allowed to collect the data/ details and
finalization of PPCA charge.
11.15. The details of the normative losses for PGCIL System and MPPMCL System and
normative distribution losses may be provided by the Commission in the Tariff Orders.
122
12. Tariff Proposal for FY 2016-17
It is submitted that there has not been any substantial tariff hike for the years FY14 and FY15 in the state of Madhya
Pradesh which has severely affected the financial health of the Discoms. For FY16, the Hon’ble Commission had
approved tariff hike of 9.83%. However the Discoms are finding it extremely difficult to sustain its operations at the
present tariff levels because of intrinsic rise in expenditure due to inflationary pressures, and consistent rise in power
and energy demands, an ambitious normative loss reduction trajectory and benchmarks set by the Hon’ble
Commission, and obligations to be met under the policy objectives of the State and Central governments.
Therefore, it is necessary for the licensee to seek an appropriate hike in the tariff, up to the level as proposed and
detailed in this petition. An analysis of the tariff proposal will reveal that a small portion of the gap has been left
uncovered by the petitioners through tariff hike. This uncovered gap is proposed to be bridged either through (1) sale
of surplus power at a better rate (2) Efficiency improvements and cost reduction by the Discoms. It is submitted to
the Hon’ble Commission that the Petitioners have proposed sale of surplus energy at the prevailing IEX rates. The
current rates are reflective of the ongoing demand-supply scenario in the country, however, in case these rates
improve during the ensuing years, the Petitioners would leverage the opportunity to increase their revenue from sale
of surplus power by better rates and increased sale. Furthermore, the Petitioners are currently taking several
initiatives to reduce their costs and bring efficiency into the system, thereby not burdening the consumers. The
uncovered gap would challenge them to find innovative ways to reduce the same and thus have not considered it part
of the present tariff proposal. This would also ensure that some onus is kept on the petitioner and not passing the
entire burden on Consumers.
In view of the above submission, the Petitioners are proposing a hike lesser than the existing revenue gap. It would
just not be possible for the Discom to maintain its operational viability at the least, without an appropriate hike in the
retail tariff sought through this petition.
A summary of the proposed tariff hike and resultant additional revenue is given in the table below:
Table 67: Summary of proposed tariff for FY 2016-17
Particulars
A
B
C=A+B
D
E=C-D
F
G=F+D
H=G-C
Total ARR excluding True-Up Impact
True-Up Impact
Total ARR including True-Up Impact
Revenue at Existing Tariffs
Gap to be recovered
Average Cost of Supply
Proposed average tariff
Additional Revenue from Proposed Tariffs
Total Revenue at Proposed Tariff
Remaining revenue Gap
East
Discom
9,551
161
9,713
8,071
1,642
6.17
5.88
1,182
9,253
(460)
Central
Discom
9,656
180
9,835
8,121
1,714
6.54
West
Discom
10,537
203
10,740
9,114
1,626
6.04
Total MP
State
29,744
544
30,288
25,306
4,982
6.24
6.17
1,159
9,280
(555)
5.94
1,451
10,564
(175)
5.99
3,791
29,097
(1,190)
The Discoms request the Hon’ble Commission to consider and approve the said tariff proposal for FY 2016-17
to recover the costs for the ensuing year for the State as a whole. Even after the increased revenue of Discoms
as per proposed tariff hike as well as the various operational efficiency measures being undertaken by Discoms
and MPPMCL, any remaining gap is proposed to be recovered during annual true-up by the Discoms.
The detailed category-wise tariff proposal is being submitted in the tariff schedules as part of Chapter 15 of the
current petition. The impact on category-wise revenue due to the proposed tariff is given below:
123
Table 68: Category-wise proposed revenue for FY 2016-17
East Discom
Sales Category
Revenue at
current tariffs
Central Discom
Revenue at
proposed
tariffs
Revenue at
current tariffs
West Discom
Revenue at
proposed
tariffs
Revenue at
current tariffs
MP State
Revenue at
proposed
tariffs
Revenue at
current tariffs
Revenue at
proposed
tariffs
LT CATEGORIES
LV-1: Domestic
LV-2: Non-Domestic
LV 3: Public Waterworks and Street Light
LV 4: LT Industry
LV 5.1: Agriculture
LV 5.3: Other allied agricultural use
Total LT
2,082.90
602.38
264.84
250.37
2,008.59
6.64
5,215.72
2,393.46
677.12
315.36
285.52
2,436.39
7.94
6,115.79
2,085.75
668.47
186.36
208.52
2,221.99
14.63
5,385.72
2,383.45
748.73
224.02
235.81
2,650.32
17.54
6,259.86
1,856.36
673.75
197.73
409.19
3,490.88
1.02
6,628.93
2,131.57
765.40
237.12
460.51
4,173.69
1.21
7,769.49
6,025.01
1,944.60
648.93
868.09
7,721.46
22.29
17,230.37
6,908.48
2,191.25
776.50
981.84
9,260.39
26.69
20,145.14
HT CATEGORIES
HV1: Railway Traction
HV 2: Coal Mines
HV 3.1: Industrial Use
HV 3.2: Non-Industrial and Shopping Mall
HV 3.4: Power Intensive Industries
HV 4 Seasonal & Non Seasonal
HV 5: HT Irrigation and Water Works
HV 6: Bulk Residential Users
HV 7: Synchronization/Start Up Power
Total HT
Total (LT+HT)
408.39
337.42
1,685.20
168.93
42.99
6.73
54.33
151.31
2,855.31
8,071.03
428.24
348.31
1,870.51
184.70
52.95
7.36
64.71
180.30
3,137.08
9,252.87
727.90
27.03
1,392.47
314.74
100.23
1.35
81.11
90.58
0.14
2,735.55
8,121.28
769.00
27.84
1,548.42
343.66
124.98
1.48
96.58
108.03
0.17
3,020.14
9,280.00
272.78
1,617.94
288.00
101.63
4.60
182.68
16.56
0.44
2,484.62
9,113.55
289.53
1,816.41
316.13
127.05
5.03
220.37
19.69
0.52
2,794.73
10,564.22
1,409.07
364.45
4,695.62
771.67
244.84
12.68
318.13
258.45
0.57
8,075.49
25,305.85
1,486.77
376.15
5,235.33
844.48
304.98
13.87
381.66
308.02
0.69
8,951.95
29,097.09
124
12.1. Salient Features of the Tariff Proposal
The licensees have proposed increase in tariff rates along with certain changes in general terms and
conditions of LT and HT tariff. The proposed schedule of the Retail Tariff for FY 2016-17 is enclosed
with this petition.
The salient features of the proposed changes are as elaborated below:
12.1.1. Merging of tariff slabs of 0 to 50 units and 51 to 100 units as 0 to 100 units in LV 1.2
Domestic Category
Reasons for proposed changes: To make the lifeline consumption slab broader from 0 to 50
units to 0 to 100 units and also to make the tariff structure simpler, this change in tariff
structure is proposed. This would also prevent the consumers who used to consume more
than 50 units in a month from going into the higher slab. The tariff has been accordingly
designed to reduce the tariff impact on consumers who consumed less than 50 units per
month.
12.1.2. Removal of optional demand based tariff (only for contract demand above 10 kW and upto
20 kW) in LV 2.1 and LV 2.2 Non Domestic category
Reasons for proposed changes: To make the tariff structure simpler and also to bring all
consumers upto contract demand of 20 kW under sanctioned load based tariff, this step has
been taken. Consumers above 20 kW will continue to be billed under mandatory demand
based tariff.
12.1.3. Merging of LV 3.1 Public Water Works and LV 3.2 Street Light categories
Reasons for proposed changes: The tariff structure for both the sub-categories was similar
and there was a marginal difference between the tariffs of the two categories. Also, both
these sub-categories belonged to government owned organizations. Thus, in order to make
the tariff structure simpler, the two categories are proposed to be merged.
12.1.4. Rebate to all LT consumers for online payment of bills
Reasons for proposed changes: It is proposed that all LT consumers who have no arrears
shall be given rebate of Rs 5 per bill for online payment of the energy bill in full. This is
being done to encourage online payment of bills among consumers. It is also estimated to
improve timely payment by consumers and simultaneously cash in hand for the Discoms.
125
12.1.5. Permission to use 10% of connected load/ contracted demand for temporary usage by LT
consumers
Reasons for proposed changes: It is proposed that LT permanent consumers except LT
Agricultural consumers shall be allowed to use not more than 10% of their sanctioned load /
contract demand for any such usage which comes under the definition of temporary
connection for the same purpose, subject to the condition that the combined load/ demand
shall not exceed the sanctioned load/ contract demand. This will facilitate the consumers to
use connection for temporary purposes also subject to the terms and conditions.
12.1.6. Limiting the sanctioned load/ connected load under LT connection to 75 kW/ 100 HP
Reasons for proposed changes: It is proposed that the load limit for availing LT connection
be reduced 75 kW instead of existing 112.5 kW/ 150 HP. This step would be a stepping
stone for the Discoms to reduce their distribution losses. The higher the load catered or
energy supplied at LT voltage, the higher is the distribution losses. If all such consumers
having connected load more than 75 kW at LT are converted to HT, then the distribution
losses will reduce significantly. The existing LT consumers having sanctioned load more
than75 kW/ 100 HP shall be asked to be converted to avail supply on HT by the end of FY
2016-17.
12.1.7. Merging of HV 3.2 Non Industrial use and HV 3.3 Shopping Mall
and there was a marginal difference between the tariffs of the two categories. Also, the
nature of business under both the categories belonged to non-industrial or commercial use.
Thus, in order to make the tariff structure simpler, the two categories are proposed to be
merged.
12.1.8. Merging of HV 5.1 Public Water Works and HV 5.2 Other Allied Agricultural use
and there was a marginal difference between the tariffs of the two categories. Also, the
nature of business for both these categories was non- agricultural. Thus, in order to make the
tariff structure simpler, the two categories are proposed to be merged.
126
12.1.9. Addition of apartments/ colonies/ townships in HV 6.2 Bulk Residential Use
Reasons for proposed changes: It is proposed to extend the benefit of this category to
apartments, colonies and townships also. These establishments are used for residential
purposes and hence stand eligible for this category. This shall be subject to the term that
common facilities like lifts, lights, pumps, etc. and all non-domestic loads shall not be
more than 20% of the total connected load/ sanctioned demand of the establishment.
12.1.10. Rebate on energy charges for incremental load factor for HT consumers
Reasons for proposed changes: It is proposed that all HT consumers shall be given rebate
of 50 paise per unit of energy for incremental load factor on monthly basis as compared to
past year. This benefit is provided to increase the economic development of the state and
also to encourage the HT consumers to consume more energy at reduced prices.
12.1.11. Rebate for online bill payment by HT consumers
Reasons for proposed changes: In order to encourage online bill payment by HT
consumers it is proposed that all HT consumers who have no arrears shall be given a rebate
Rs 100 per bill for online payment of energy bill in full. This facility shall also improve the
cash in hand for the Discoms.
12.1.12. ToD surcharge reduced to 0% for HT consumers
Reasons for proposed changes: Madhya Pradesh is a power surplus state and it does not
have to procure power at short term rates, hence no additional costs are borne by the State to
procure power during peak hours. In order to extend this benefit to the HT consumers, the
ToD surcharge during peak hours is proposed to be reduced to 0%.
12.1.13. Additional Charges for energy for Excess Demand by HT consumers
Reasons for proposed changes: The HT consumers shall not be charged additional energy
charges in case their maximum demand recorded in any month is exceeds 105% of their
contract demand. They shall be billed at the same tariff for energy charge as per their
schedule. However, the fixed charges shall be levied as per the existing terms and
conditions. This is done to reduce the effect of additional charges if the demand exceeds
105% of the contract demand. This provision is also applicable for excess demand in HT
temporary connections.
127
12.1.14. Rebate of 5 paise per unit for all domestic and non-domestic consumers having prepaid
meters
Reasons for proposed changes: In order to promote prepaid metering in the state, it is
proposed that the Discoms shall offer a rebate of 5 paise per unit for all domestic and nondomestic consumers having or opting prepaid meters. The existing provision of 1% rebate
on energy and fixed charges is proposed to be discontinued on account of inherent
complication in the prepaid billing software.
128
13. Voltage-Wise Cost of Supply
13.1. Commission Directives
The Hon’ble MPERC has directed the Discom’s of MP to determine the voltage wise cost of
supply vide its letter dated 25 October 2013 with memo no. MPERC/RE/2013/2780. The
Hon’ble Commission referred to the judgment passed by Appellate Tribunal for Electricity
(APTEL) in Appeal No. 103 of 2010 & IA Nos. 137 & 138 of 2010 regarding determination of
voltage level wise Cost of Supply.
The extract of APTEL’s order is elaborated as below.
Extract of APTEL’s order
“32. Ideally, the network costs can be split into the partial costs of the different voltage level and the
cost of supply at a particular voltage level is the cost at that voltage level and upstream network.
However, in the absence of segregated network costs, it would be prudent to work out the voltagewise cost of supply taking into account the distribution losses at different voltage levels as a first
major step in the right direction. As power purchase cost is a major component of the tariff,
apportioning the power purchase cost at different voltage levels taking into account the distribution
losses at the relevant voltage level and the upstream system will facilitate determination of voltage
wise cost of supply, though not very accurate, but a simple and practical method to reflect the actual
cost of supply.
33. The technical distribution system losses in the distribution network can be assessed by carrying
out system studies based on the available load data. Some difficulty might be faced in reflecting the
entire distribution system at 11 KV and 0.4 KV due to vastness of data. This could be simplified by
carrying out field studies with representative feeders of the various consumer mix prevailing in the
distribution system. However, the actual distribution losses allowed in the ARR which include the
commercial losses will be more than the technical losses determined by the system studies. Therefore,
the difference between the losses allowed in the ARR and that determined by the system studies may
have to be apportioned to different voltage levels in proportion to the annual gross energy
consumption at the respective voltage level. The annual gross energy consumption at a voltage level
will be the sum of energy consumption of all consumer categories connected at that voltage plus the
technical distribution losses corresponding to that voltage level as worked out by system studies. In
this manner, the total losses allowed in the ARR can be apportioned to different voltage levels
including the EHT consumers directly connected to the transmission system of GRIDCO. The cost of
supply of the appellant’s category who are connected to the 220/132 KV voltage may have zero
technical losses but will have a component of apportioned distribution losses due to difference
between the loss level allowed in ARR (which includes commercial losses) and the technical losses
determined by the system studies, which they have to bear as consumers of the distribution licensee.
129
34. Thus Power Purchase Cost which is the major component of tariff can be segregated for different
voltage levels taking into account the transmission and distribution losses, both commercial and
technical, for the relevant voltage level and upstream system. As segregated network costs are not
available, all the other costs such as Return on Equity, Interest on Loan, depreciation, interest on
working capital and O&M costs can be pooled and apportioned equitably, on pro-rata basis, to all
the voltage levels including the appellant’s category to determine the cost of supply. Segregating
Power Purchase cost taking into account voltage-wise transmission and distribution losses will be a
major step in the right direction for determining the actual cost of supply to various consumer
categories. All consumer categories connected to the same voltage will have the same cost of supply.
Further, refinements in formulation for cost of supply can be done gradually when more data is
available.”
It is most humbly submitted that the above mentioned order of APTEL has been challenged in
the Hon’ble Supreme Court of India by the Respondents in the case and the matter is under
consideration before the Apex Court. However, as per the directives of the Hon’ble Commission
the Discoms submit the details of calculation of the voltage wise cost of supply as per the
methodology provided by the APTEL.
13.2. Voltage-wise Losses
It is submitted that the MPERC Tariff Regulations do not provide segregation of normative losses for
the Distribution Licensees into voltage wise normative losses in respect of technical and commercial
losses. Therefore, the Petitioners face difficulty in segregation of normative losses in voltage level
wise technical and commercial losses.
Determination of voltage-wise losses would require detailed technical studies of the Distribution
network of the three Discoms. For the purposes of illustrative computation of voltage-wise Cost of
Supply, the petitioners have assumed voltage-wise losses, the data therein is not verified and so,
should not be relied upon.
13.2.1. Methodology
The Discoms have proposed the methodology for Voltage-wise Cost of Supply computation for three
categories, namely:
c. EHT System (400 kV, 220 kV and 132 kV)
d. 33 KV System
e. 11 KV + LT System
For determination of Voltage-wise Cost of Supply, the proposed methodology involved the following
steps:
1.
Determine the voltage-wise Sales for three voltage levels.
130
2.
3.
4.
5.
6.
7.
Projection of voltage-wise loss levels based on historical numbers. It is pertinent to mention
here that the loss levels so determined are on assumption basis and it would require a detailed
technical study of the Distribution Network for the technical verification of the same. The
Inter-state PGCIL and Intra-state MPPTCL losses are allocated to the EHT System (400 kV,
220 kV and 132 kV).
a. It may also be noted that the percentage of EHT losses allocated to the three Discoms
are different due to the fact that different generating stations are assigned to the
different Distribution company and each draws its power from different 132 kV
substation.
Determine the voltage-wise energy input based on sales and the losses. The sales numbers
have been escalated by the T&D loss% of the current voltage level as well as the next higher
voltage level.
Since the breakup of technical and commercial losses at 11 kV +LT system is not available,
50% of the total loss at this voltage level has been assumed as purely technical loss and
remaining 50% loss has been assumed as commercial loss which has been loaded to various
voltage levels in the proportion of their sales.
The total Power Purchase Costs of each Discom is allocated to the three voltage levels based
on the voltage-wise input energy. All other costs of the Discom are allocated based on the
sales to each voltage-level.
Non-tariff income has been assumed to be part of the revenue from 11 kV + LT, 33kV and
EHT voltage levels.
Sum of total costs (less non-tariff income) divided by net energy input gives the voltage wise
cost of supply for the respective voltage level.
13.3. Calculation
The calculation for Voltage wise Cost of Supply for MP state is as shown below:
Table 69: Cost of Supply Calculation for East Discom for FY17
East Discom
Sales
Loss %
Energy Input
Energy Lost (Technical upto 33 kV voltage & 11 kV +LT
technical and Commercial)
Commercial Loss assumed as 50% of 11 kV and LT overall
losses
Balance 50% Commercial loss for all voltage in proportion to
Sales
Net Energy Input
MU
%
MU
MU
EHT
System (400
kV, 220 kV
& 132 kV)
3,088
5.26%
3,259
33
KV
Syste
m
1,387
6.62%
1,568
11
KV +
LT
System
11,254
17.64%
15,444
171
181
4,189
MU
MU
MU
Total
15,730
22.40%
20,271
2,095
411
185
1,499
3,670
1,753
14,848
20,271
131
Power Purchase Costs - allocated based on voltage-wise losses
Other costs - allocated based on voltage-wise sales
Less: Other income - allocated based on voltage-wise sales
Total Costs (ARR requirement)
Total Costs (ARR requirement)- Including True Up
Rs Cr
Rs Cr
Rs Cr
Rs Cr
Rs Cr
ACoS (excluding true-up)
ACoS (including true-up)
Rs/kWh
Rs/kWh
1,379
436
54
1,759
1,788
659
196
24
829
843
5,580
1,590
197
6,963
7,081
7,617
2,222
275
9,551
9,713
5.70
5.79
5.98
6.08
6.19
6.29
6.07
6.17
Table 70: Cost of Supply Calculation for Central Discom for FY17
Central Discom
Sales
Loss %
Energy Input
losses
Sales
Net Energy Input
MU
%
MU
MU
Rs/kWh
Rs/kWh
EHT
System
(400 kV,
220 kV &
132 kV)
2,339
5.26%
2,468
33
KV
System
11 KV
+ LT
System
Total
1,860
6.09%
2,090
10,831
19.07%
15,040
15,029
23.31%
19,598
130
230
4,208
MU
2,104
MU
MU
RsCr
RsCr
RsCr
RsCr
RsCr
327
2,796
1,060
376
30
1,406
1,432
260
2,351
891
299
24
1,167
1,188
1,516
14,452
5,478
1,743
138
7,083
7,215
19,598
7,429
2,419
192
9,656
9,835
6.01
6.13
6.27
6.39
6.54
6.66
6.42
6.54
Table 71: Cost of Supply Calculation for West Discom for FY17
West Discom
Sales
Loss %
Energy Input
losses
MU
%
MU
MU
MU
EHT
System
(400 kV,
220 kV &
132 kV)
1,106
5.23%
1,167
33
KV
System
11
KV +
LT
System
Total
2,558
5.47%
2,855
14,129
14.98%
18,550
17,793
21.17%
22,573
61
297
4,421
2,210
132
West Discom
Sales
Net Energy Input
MU
Rs/kWh
Rs/kWh
MU
RsCr
RsCr
RsCr
RsCr
RsCr
EHT
System
(400 kV,
220 kV &
132 kV)
33
KV
System
11
KV +
LT
System
Total
137
318
1,755
1,305
502
124
8
617
629
3,173
1,220
286
19
1,487
1,516
18,095
6,958
1,581
107
8,433
8,595
22,573
8,680
1,991
134
10,537
10,740
5.58
5.69
5.81
5.93
5.97
6.08
5.92
6.04
Table 72: Cost of Supply Calculation for MP State for FY17
MP State
Sales
Loss %
Energy Input
losses
Balance 50% Commercial loss for all voltage in proportion
to Sales
Net Energy Input
Power Purchase Costs - allocated based on voltage-wise
losses
Total Costs (ARR requirement) - Excluding True Up
MU
%
MU
MU
Rs/kWh
Rs/kWh
EHT
System
(400
kV, 220
kV &
132 kV)
6,532
5.25%
6,895
33
KV
System
11 KV
+ LT
System
Total
5,805
5.94%
6,514
36,215
17.13%
49,034
48,553
22.24%
62,442
362
709
12,819
13,889
MU
MU
6,409
876
763
4,770
MU
Rs Cr
7,771
7,277
47,395
62,442
2,941
2,770
18,016
23,726
Rs Cr
Rs Cr
Rs Cr
Rs Cr
934
92
3,782
3,851
780
67
3,483
3,547
4,905
442
22,479
22,890
6,619
601
29,744
30,288
5.79
5.90
6.00
6.11
6.21
6.32
6.13
6.24
133
13.4. Determination of Cross-Subsidy Surcharge
The Tariff Policy provides for the determination of cross- subsidy surcharge for various categories
of consumers. As per Clause 8.5.1 of the Tariff policy, the basis for determination of the
aforementioned cross-subsidy surcharge is the aggregate of top 5 % at the margin of the power
purchase costs.
It is pertinent to mention here that Discoms have employed Merit-order dispatch while scheduling
power from various stations so as to procure the cheapest power available. Also the Petitioners have
also considered backing down of units/stations where variable cost is more than Rs 2.50 per unit
(based on average IEX rate available in the market for sale) to ensure that power procured from
cheaper sources is fully utilized and to avoid procurement of power from costlier sources. The
resultant benefit of reduced power procurement cost is in turn being passed on to the consumers, along
with backdown of few stations.
Hence, in light of above, the petitioners submit that the basis for determination of the aforementioned
cross-subsidy surcharge to be taken as cost of marginal power purchase of top 5% power
scheduled by the Discom as per the Merit-Order-Dispatch.
In addition, it is submitted that as per the formula provided in the National Tariff Policy for
determination of cross subsidy surcharge, the open access consumer is required to pay the difference
of average tariff and the total cost (Rs./Unit) at a particular voltage level. The Hon’ble Commission
has determined the average tariff based on the power purchase cost as per previous year’s available
data. Any variation on account of such change in fuel cost is also passed on to the consumer through
FCA, which will result in an increase in average tariff by FCA amount. Therefore, it will be
appropriate to increase the cross subsidy surcharge to the extent of FCA charges payable for a
particular period.
134
14. Compliance on Tariff Order FY 2015-16
The response of Discoms on the directives issued by Hon’ble Commission in retail supply tariff order
for FY-16 is given below:
14.1.1. Distribution losses
14.1.1.1. Commission’s Directives:
Although the Discoms have shown reducing trend of losses, efforts to reduce losses
need to be further intensified. The Discoms should not only endeavour to achieve the
benchmarks but to improve further to justify capital invested on loss reduction and
system improvement. The Discoms have been directed to prepare and implement
appropriate loss reduction strategies and schemes with a focus on prevention of theft of
electricity.
14.1.1.2. East Discom submission
(A) System strengthening work/Aug. of transmission capacity:
Distribution losses of East Discom are going down consistently year on year, but the
company is yet to achieve the normative loss level as specified by the Commission.
The company is implementing various measures to achieve the targets. It is
envisaged to minimize the technical losses by efficiently strengthening the system /
augmenting the system capacity.
Following addition in distribution system has been made till Oct’.2015
Sr.
no.
1
2
3
4
5
6
7
8
Particulars
Unit
As on
Mar’14
33/11KV S/S
PTR
PTR capacity
33 KV line
11 KV line
L.T. line
DTR
DTR Capacity
No.
No.
MVA
Km
Km
Km
No.
MVA
947
1597
6776.65
16045
105542
113005
132001
7045.55
Added DY
2014-15
17
97
716.35
770
7788
2549
11279
457.05
As on
Mar’15
964
1694
7493
16815
113330
115554
143280
7502.60
Added DY 201516 (Upto Oct-15)
(Over all)
10
33
346.5
404
3814
1020
4171
157.49
System strengthening in Company area that has been covered against ADB loan No.
3066. The provision and progress is as under:
135
Particulars
Unit
Provision
Achievement
during FY
14-15
Total
achievement
up to Nov’15
128.28
-
Achievement
during FY
15-16 up to
Nov’15
328.26
5
33kV Line
New 33/11kV SubStation.
11kV Line
Ckt Km
No.
1366
30
Ckt Km
193
1.3
46.24
47.54
456.54
5
It is expected that the whole work of ADB scheme will be completed in FY 201516.
(B)
Implementation of Non-RAPDRP Scheme:
In order to bring down the Distribution losses various works under Non-RAPDRP
scheme are being carried out in selected Non-RAPDRP towns.
In Phase-I of the scheme 21 towns were selected. Average loss level of these towns
has reduced from 47.28% in the month of March-10 to 14.70% in the month of Mar15.
In Phase-II of the scheme 27 towns were selected. Average loss level of these towns
has reduced from 53.26% to 16.27% in the month of Mar-15.
In Phase-III of the scheme 35 towns were selected. Work in 35 towns is being
executed with ADB assistance with estimated cost of Rs.67.44 Cr. Average loss
level of these towns has reduced from 57.66% to 18.65% as on Mar-15.
Further in Phase IV of the scheme 35 towns have been selected with the estimated
cost of Rs 49.58 Cr. The average loss levels of these towns have reduced from 50%
to 21.47% as on Mar-15. Besides this, similar work in 98 Gram Panchayats (Rural
DC Head Quarters) was also carried out with an estimated cost of Rs.27.57 Cr.
14.1.1.3. Central Discom submission
It is submitted that the Central Discom is sincerely striving for reduction in line losses
to bring it to the normative level. The details of achievement in loss level as compared
to the previous financial year 2014-15 for the period from April to July are as under:Month
April
May
June
July
2014-15
Loss %
29.00
29.77
25.03
23.59
2015-16
Loss %
26.76
29.06
20.19
21.88
Moreover vigilance unit of Discom is conducting regular raids to check the
theft/pilferage of energy. The progress from Apr.15 to Oct.15 is as under:136
No. of
Connecti
on
Checked
1
88108
Progress of Vigilance checking during 01-04-15 to 31-10-15
No. of Irregularities
Amount billed (Rs.in
Amount realised (Rs.in Lacs)
detected
Lacs)
Theft
Mal Practice
Total
Mal
Mal
Theft Practice Total
Theft
Total
Practice
No.
Amt.
No.
Amt.
No.
Amt.
2
3
4
5
6
7
8
9
10
11
12
13
19305
11067
30372
3925.80
2350.73
6276.53
8074
1300.26
6574
1145.46
14648
2445.72
14.1.1.4. West Discom submission
Considering the Hon’ble Commission’s directive, the Discom has been sincerely
striving for reducing the line losses and bringing it within the line loss trajectory as
notified by GoMP/ Commission. The Discom humbly submits that it is only due to the
sincere efforts made by it the line losses are showing the declining trend over the years.
The Discom humbly submits, the reduction in loss levels achieved by the Discom over
the past years for the Hon’ble Commission’s kind perusal and consideration, as
follows:
Distribution Loss
40
35
30
25
20
15
10
5
0
It is submitted that due to increase in supply hours and adverse ground realities,
Discom is facing difficulties to achieve distribution loss level according to loss
trajectory defined by the Commission. Discom has strengthened vigilance wing and
launched intensive checking drives to curb pilferage of energy. Vigilance cell has
conducted regular raids to check and to keep surveillance on pilferage of energy.
Details from April 2015 to October 2015 are given as below:-
Connections
checked
72893
No of cases of irregularities/theft
detected during the year
Direct
Theft
13589
Malpractice
5796
Total
19385
Total amount billed(Rs in lacs)
Direct
Theft
3482.44
Malprac
tice
1952.33
Total amount realized(Rs in
lacs)
Total
Direct
Theft
5434.77
3038.62
Malprac
tice
3755.11
Total
6793.73
137
Feeder separation and other schemes: Discom has launched the feeder separation
scheme in two phases. Phase one covers Indore, Dhar, Khandwa, Khargone, Barwani,
Burhanpur and Ratlam districts while phase two covers Ujjain, Dewas, Mandsaur,
Neemuch, Alirajpur, Jhabua and Shajapur Districts.
Feeder separation works are completed in the following districts namely,

Indore

Burhanpur

Alirajpur

Ratlam

Neemuch

Mandsaur and

Ujjain

Jhabua
While works in Shajapur, Dewas, Dhar, Barwani, Khandwa and Khargone districts are
under execution. The likely date for completion of remaining work is January 2016.
Discom has also launched various schemes for system strengthening under GoMP ,
TSP, SCSP, Feeder bifurcation, new irrigation pumps, ADB Third, RGGVY(11th and
12th Plan), IPDS AND DDUGJY.
Sr.
no
Particulars
At the Start of
year
FY 2014-15
Additions during
the year
At the end
of year
1
Length of lines (ckt-km)
- 33kV
- 11kV
- LT
Total
2
Number of 33/11kV substations
1,140
20
1,160
2,027
64
2,091
3
No. of Power Transformers
Total MVA capacity of power
transformers
8,703
663
9,366
Number of Distribution Transformers
Total MVA capacity of Distribution
Transformer
146,768
16707
163,475
4
10,984
691
11,675
13,942
95,603
147,621
257,166
454
5242
2551
8,247
14,396
100,845
150,172
265,413
138
14.1.2. Meterization of unmetered connections
The Commission directed the Discoms to expedite feeder meterisation and DTR
meterisation on priority basis. Discoms should file a detailed plan in this regard to the
Commission by 31st May 2015. Further, the Commission has observed that the
Discoms have committed for 100% meterisation of rural domestic connections by 31
March, 2015. A status report in this regard be filed by 31 May 2015. The Commission
shall review the status in June 2015.
14.1.2.2. East Discom submission:
(a) Feeder Meterization: All metering points of 33kV feeders and 11kV feeders have
been provided with meters.
(b) Meterization of un-metered domestic connections: Meters have been provided on all
unmetered domestic connections of urban area. As far as rural area is concerned,
during 2013-14 total 3,49,845 and during 2014-15 total 1,68,828 meters have been
provided on rural unmetered domestic connections. Thus unmetered DLF connections
of rural area have reduced from 9,41,085 as on March-13 to 3,55,209 as on Mar-15.
Further during the year 2015-16 up to Sept-15 total 20106 meters have been provided
on unmetered DLF connections, thus at the end of Sept’15 total 3,35,103 unmetered
DLF connections are remaining. It is planned to provide meters on unmetered
connections up to Sept.-2016.
(c) Meterization of Agricultural DTRs: The Company as on Sept-15 is having 66219
agricultural predominant DTRs out of which 5156 DTRs have been provided with
DTR meters. Further meterisation of 20,000 DTRs is being taken up in the year 201516. The meterisation of agricultural DTRs is not covered under any scheme. If
additional fund is provided to the company under supplementary DDUGJY Scheme,
then the same shall be taken up accordingly.
14.1.2.3. Central Discom submission:
The status of meterisation is as under:S.No.
1
2
3
Category
Total No.as on Oct.15
Domestic rural consumers
Feeder meter 33/11 KV (point)
DTR
meter
(Agricultural
predominant)
11,87,790
5892
1,13,980
No. of unmetered
connections as on Oct.15
1,40,445
439
81,536
139
As directed by the Commission the detailed plan for meterisation is given below:Region-wise feeder meterisation
Plan for Meterization
Unmetered
Feeder
(Points) as
on 30.06.15
Region
Bhopal
Gwalior
MPMKVVCL
Aug15
Sep-15
9
9
20
33 KV - 69
11 KV –
157
33 KV - 53
11 KV –
189
33 KV 122
11 KV - 346
Oct15
Nov-15
Dec-15
Jan-16
Feb16
Mar16
Total
9
9
9
8
8
8
69
20
20
20
20
19
19
19
157
7
7
7
7
7
7
7
6
55
25
25
25
24
24
24
24
24
195
16
16
16
16
16
14
14
14
122
45
45
45
44
44
43
43
37
346
Region-wise unmetered rural DLF meterisation
Region
Bhopal
Balance
Unmetered
DLF conn.
as on
30.06.15
116241
Aug15
Sep15
Oct15
Nov15
Dec15
Jan16
Feb16
Mar16
Total
14500
14500
14500
14500
14500
14500
14500
14741
116241
41947
5200
5200
5200
5200
5200
5200
5200
5547
41947
158188
19700
19700
19700
19700
19700
19700
19700
20288
158188
Gwalior
MPMKVVCL
Region-wise Agri Predominant DTR Meterisation
Region
Bhopal
Gwalior
MPMKVVCL
Balance
Unmetered
as on
30.06.15
35660
45571
81231
Aug15
Sep15
Oct15
Nov15
Dec15
Jan16
Feb16
Mar16
Apr16
May16
Jun16
Jul16
Aug16
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
1780
2280
4060
Balance
Unmetered
as on
30.06.15
Sep16
Oct16
Nov16
Dec16
Jan17
Feb17
Mar17
Total
Bhopal
35660
1780
1780
1780
1780
1780
1780
1840
35660
Gwalior
45571
2280
2280
2280
2280
2280
2280
2251
45571
MPMKVVCL
81231
4060
4060
4060
4060
4060
4060
4091
81231
Region
140
14.1.2.4. West Discom submission:
Discom is expediting feeder meterisation and DTR meterisation. The progress is
submitted for Commission’s kind perusal and consideration.
Feeder Existing
33 KV (From
EHV)*
Total
Metered
719
Feeder Existing
Percentage of
total
%
Total
100
5292
719
11 KV
Metered
5040
Percentage of total
%
95.24
Out of total 168,995 Distribution Transformers 43,119 has been metered till
Sep’15.The company made a meterisation plan of agriculturally predominant DTRs
which has shear dependency on availability of funds. The company is trying to arrange
funds for the meterization work on priority basis. The Company is preparing Detailed
Project Report for obtaining financial assistance from other financial Institutions.
Compliance of the Directives provisions in Retail Supply Tariff Order for FY 2015-16
has been submitted before Hon’ble commission vide letter no 13794 dated 31.07.2015.
The company has prepared circle wise month wise target and is planning to achieve
100% meterisation by the end of December’2015. The Company is facing challenges in
meterisation especially in Jhabua circle. The MP report on Human Development Index
reports that Jhabua district has one of the lowest HDI. The rural poverty level of
Jhabua is very high and population mix of Jhabua has a large no. of Scheduled Tribes
and daily labourers, which are living in small Majra-Tolas. These Majra-Tolas
frequently changes their location. For the said reasons Jhabua has the least meterisation
in respect of domestic connections. However, the petitioner has made concrete plan for
the circle and has set the target to achieve 100% meterisation till June 2016 by way of
procuring meter at the earliest.
Meterization of domestic connections in Rural area is being carried at faster pace and
only 2.85% consumers are left Un-Metered till September 2015.
14.1.3. Capex plan for reduction in technical losses
The licensees should closely monitor progress of implementation of the Capex plans to
avoid slippages. The Discoms should monitor the benefits accrued after execution of
schemes under the Capex plan and ensure that additional capex does lead to actual
payback in commercial and technical terms as per provisions envisaged in the schemes.
Company is continuously monitoring the benefits accrued after execution of schemes
under the capex plan. Year wise investment and reduction in T&D losses achieved is
shown as below:
141
Particular
2012-13
2013-14
2014-15
Investment (Cr.)
857.63
1016.47
806.58
T&D losses (%)
26.02
23.68
21.69
Thus investment has resulted in reduction of losses.
The directives of the Commission are being adhered to.
Implementation of the Capex schemes is under progress. Benefits on account of
schemes under execution are evident in improved supply arrangements and continuous
supply. Further, implementation of these schemes is resulting in reduction of losses.
Loss Reduction schemes have helped in considerably reducing the loss levels. The
petitioner has considerably saved in power purchase cost due to lower Distribution loss
levels.
The below table depicts the reducing trend of losses over past years:
Distribution Loss
40
30
20
10
0
The below table depicts the progress made by petitioner in implementing capex plan.
The year wise total progress (Financial) made by the Discom is as submitted as shown
below for Hon’ble Commission’s kind perusal.
MPPKVVCL, Indore
Year wise Impact assessment of Capital Expenditure Plan Fy-2011-12 to 2015-16(Financial Progress)
Year wise Achievement up to Aug' 2015
S No
Scheme
2011-12
2012-13
2013-14
2014-15
2015-16
Total
142
Upto
Aug 15
1
System Strengthening Scheme
i
GoMP (N)
23.35
82.12
279.05
152.07
63.56
600.15
ii
Schedule Cast Sub Plan (SCSP)
28.85
35.79
37.52
36.33
12.50
150.99
iii
Tribal Sub Plan (TSP)
17.96
25.49
47.83
53.90
16.37
161.55
2
Feeder Separation
309.87
693.48
138.56
73.47
18.42
1233.80
6
New Pump Connections
39.26
127.11
71.34
109.98
55.51
403.20
7
ADB
139.59
122.69
35.73
49.07
5.73
352.81
8
RGGVY
93.08
80.73
74.66
100.84
66.57
415.88
9
RAPDRP Part-A & Part-B
70.40
138.30
97.30
106.87
24.40
437.27
10
Simhanstha 2016
3.09
2.00
2.78
4.37
6.76
19.00
725.45
1307.71
784.77
686.90
269.81
3774.65
Total(Crores)
The petitioner has demonstrated good progress in schemes such as ADB, New pump
connections & GoMP (N) and is also implementing other schemes of Capex plan.
14.1.4. Segregation of rural feeders into agricultural and others
The Commission is in receipt of progress in the matter. Feeder separation is reported
to be completed in a majority of feeders under the schemes. However, other provisions
of the schemes like installation of DTRs, meters, laying of LT cables etc. are lagging
behind. It is obvious that the present status of implementation has been below
expectations. Petitioners are directed to complete all works envisaged under these
schemes expeditiously.
East Discom is regularly submitting the progress report of feeder separation work
according to the directives of MPERC. The balance work of feeder separation like
cabling, meters etc. is also being carried out. Actions have been taken against turnkey
contractors who have not performed as per given targets. Nine contracts have been
143
terminated and against the terminated contracts six have been re-awarded, the price
bids of the rest three contracts has been opened and re-award in under process. The
corporate office is regularly monitoring the progress of FSP and all necessary action is
being taken to expedite the progress and to complete the balance work.
The progress for the year 2014-15 and 2015-16 (upto Oct.15) and targets for the year
2016-17 is as under:Year Wise Status of Physical and Financial Progress of Discom
Particulars
FSP
Fy-14-15
Fy-15-16 (as
on Oct-15)
143
Particulars
FSP
Fy-14-15
Fy-15-16 (as
on Oct-15)
2940
Contract Price
RGGVY ADB
Rs. In Cr.
34
44
85
2133
42
12
DTR's
RGGVY ADB
No
657 2951
1412
472
Total
FSP
221
1685
140
947
Total
FSP
6548
1164
4017
1199
11 KV line
RGGVY ADB
Km
944
171
713
0
Cabling
RGGVY ADB
Km
313
250
297
2800
11kv bay with VCB
RGGVY ADB Total
No
54
0
0
54
1660
42
Total
0
0
42
1727
Connection served
RGGVY ADB Total
No
No
50781
37973 5824 94578
1496
56361
Total
0
FSP
FSP
13100
2660
72121
Target for the year 2016-17
S.N
1
2
3
4
5
6
7
a
b
Particulars
Financial in CR.
11 kv Feeder
11 kv Add.Bay
11 kv Line
New DTR
LT Cabling
Connection Served
NSC
Renovation of service connection
Unit
Rs.in Cr.
No
No
Km
No
Km
No
No
No
Target for
2016-17
280.00
468
150
3000
6000
3500
100000
50000
50000
Discom has launched the feeder separation scheme in two phases. Phase one covers
Indore, Dhar, Khandwa, Khargone, Barwani, Burhanpur and Ratlam districts while
phase two convers Ujjain, Dewas, Mandsaur, Neemuch, Alirajpur, Jhabua Shajapur
Districts Works are completed in Indore, Burhanpur, Alirajpur, Ratlam, Neemuch,
Mandsaur, Jhabua and Ujjain while works in Shajapur, Dewas, Dhar, Barwani,
144
Khandwa and Khargone are under execution. The likely date for completion of
remaining work is January’ 2016.
14.1.5. Issue of tariff card with first bill based on new tariff
The Commission directs that the practice of providing tariff cards should be continued
for tariff order of FY 2015-16.
East Discom has arranged to print tariff cards for tariff order FY 2015-16 for different
categories of the consumers and the same were provided to the consumers.
Tariff cards were issued to LT consumers. In addition, tariff schedule booklets were
provided to all HT consumers.
The information related to tariff for FY2015-16 was issued to consumers of the
Company.
14.1.6. Filing of ARR and tariff proposals in Hindi language
Subsequent to the filing of the ARR/Tariff Petition in English, Discoms have submitted
its Hindi version which was made available to stake-holders. The next filing of ARR/
tariff proposals should also be made in Hindi and English. In addition the Discoms are
directed to submit replies to objectors in the language English/ Hindi in which
objections are filed.
The Hindi version of the subject petition will be submitted in due course after filing of
petition in English.
145
Hindi version of the ARR/Tariff proposals petition is being submitted subsequent to
filing of petition in English. The Discom will also make sure to submit replies to the
objectors in the language English/Hindi in which objections are filed.
Hindi version of the main petition will be submitted subsequent to filing of petition in
English.
14.1.7. Accounting of rebates/incentives/surcharge
The Discoms are directed to continue to compile the requisite details in respect of HT
consumers and submit with their next ARR/tariff proposal. They should also collect and
submit the details in respect of LT consumers.
The requisite information in respect of HT Consumers is being submitted in soft copy.
However, in case of LT consumers, the information is voluminous and is required to be
extracted from two different billing systems i.e. RMS and CC&B softwares as billing
of most of the R-APDRP towns has been switched over to CC&B from RMS. The
RMS billing system is de-centralized and therefore data has to be collected from 28
servers at 28 locations and compiled to make it presentable to MPERC. Both the
software cells have been requested to provide the desired information which will
require much more time to retrieve the information in RMS and consolidate it.
Therefore, the requisite information in respect of LT consumers shall be submitted
separately in due course.
The Discom will comply with the directives of the Commission.
146
Discom has complied with the Commission’s directive in respect of HT consumers.
This year the petitioner is trying to include LT consumers too in this ambit through
rolling out CCNB software at strategic locations.
14.1.8. Maintaining uniform accounts
The Commission reiterates that Discoms should bring uniformity in maintaining the
accounts at an early date. MPPMCL, as holding Company of all the Discoms, is
directed to coordinate with the Discoms to bring about such uniformity.
From FY 2011-12 onwards East Discom is preparing Annual Accounts as per revised
schedule VI of the Companies Act, 1956 (now Companies Act 2013).
Central Discom has prepared its accounts as per the common accounting policy
prescribed by the MPPMCL.
Discom was incorporated on 31st May 2002 under Companies Act 1956 (now
Companies Act 2013). However, the commercial operations commenced from 1st June
2005 pursuant to Government of Madhya Pradesh Notification No. 226 dated 31st May
2005. Schedule III to the Companies Act, 2013 provides the manner in which every
company shall prepare its Balance Sheet, Statement of Profit and Loss and notes
thereto.
The company is preparing its accounts as per Schedule III of the Companies Act 2013
and as per the Accounting Standards notified by the Companies (Accounting Standard)
Rules 2006. Further it is submitted that from FY 2014-15 onwards, as per provision of
Companies Act 2013, consolidated accounts is required to prepared by every holding
company. For this purpose MP Power Management Company after due discussion with
all three distribution company prescribed the accounting policies which are to be
followed by all three companies. West Discom has prepared its accounts as per the
common accounting policy prescribed by the MP PMCL.
147
14.1.9. Compliance of Regulations
The compliance of the directives should be maintained in future also.
The instant Petition is according to the provisions of the prevailing Regulations of
MPERC.
It is submitted that the Petition has been filed in accordance with the provisions of the
Regulations.
The petitioner humbly submits that it considers the directives of Hon’ble Commission
with utmost priority and compliance to the same is ensured everywhere possible.
14.1.10. Mandatory demand based tariff for all Non-domestic LV consumers having load
in excess of 25 HP
The Commission directs the Central Discom to expedite the installation of AMR meters
on remaining installations.
The given directive is not applicable to the East Discom.
It is submitted that all HT consumers have already been provided with AMR facility
and AMR meters have been provided to LV non-domestic high value consumers
having load in excess of 25 HP.
148
Not applicable for West Discom
14.1.11. Assessment of consumption for billing to consumers
The Commission directs the Discoms to strictly comply with the provisions of the
Regulations in the matter and take stringent action in cases where noncompliance in
the matter is found.
East Discom is strictly adhering to the directives of the Commission and accordingly
necessary instructions have already been issued to all the field officers to ensure
assessment for billing strictly as per the provisions of the Supply Code and the tariff
order as amended from time to time.
The Discom is complying with the directives of the Commission.
It is submitted that the West Discom is strictly adhering to the directive, and unless the
meter is found defective/ dysfunctional/ tampered or an evidence of theft of energy in
the premises is established, no consumer is billed on assessment basis.
14.1.12. Technical studies of the Distribution network to ascertain voltage-wise cost of
supply
The Commission directs the petitioners to carry out detailed technical studies of the
Distribution network required for computing voltage-wise losses.
149
The energy audit section of company is working out 33kV system losses and 11kV &
LT system losses. No specific study has been performed yet but the company is
exploring possibilities for computing the voltage wise losses.
Initiatives are being taken to carry out technical studies of distribution network
required for computing voltage wise losses.
Discom is pursuing technical studies in this regard.
150
TARIFF SCHEDULES
151
TARIFF SCHEDULES FOR LOW TENSION CONSUMERS
Tariff Schedules
Page No
LV 1- Domestic
153
LV 2- Non Domestic
156
LV 3- Public Water Works and Street Lights
159
LV 4- LT Industrial
161
LV 5- Agricultural and allied activities
164
General Terms and Conditions
169
152
15. TARIFF SCHEDULES
Tariff Schedule – LV1 – DOMESTIC
Applicability:
This tariff is applicable for light, fan and power for residential use only. Dharamshalas,
Gaushalas, old age homes, day care centres for senior citizens, rescue houses, orphanages,
places of worship and religious institutions will also be covered under this category.
Tariff:
LV 1.1 (Consumers having sanctioned load not more than 100 watts (0.1 kW) and
consumption not more than 30 units per month)
(a) Energy Charge and Fixed Charge – For metered connection
Particular
Energy Charge (paise per unit)
Urban and Rural
Existing
Proposed
290
330
Monthly Consumption
(units)
LV1.1
Up to 30 units
Monthly Fixed Charge
Existing
NIL
Proposed
NIL
(b) Minimum Charges: Rs. 40 per connection per month as minimum charges is
applicable to this category of consumers.
LV 1.2
(a) Energy Charge and Fixed Charge – For metered connection.
Monthly
Consumption
Slab (units)
Up to 50 units
Energy Charge with
telescopic benefit(paise per
unit)
Urban/Rural areas
Existing
Proposed
340
425
(Rs)
Existing
Urban areas
Rural areas
40 per
25 per
connection
connection
70 per
45 per
connection
connection
Proposed
Urban areas
Rural areas
75 per
connection
50 per
connection
51 to 100 units
405
101 to 300 units
520
550
80 for each
0.5KW of
authorized load
60 for each
0.5KW of
authorized load
110 for each 0.5
kW of authorized
load
90 for each 0.5
kW of
authorized load
Above 300 units
570
600
85 for each
0.5KW of
authorized load
80 for each
0.5KW of
authorized load
115 for each 0.5
kW of authorized
load
110 for each 0.5
kW of
authorized load
* It has been proposed to merge the slabs of 0 to 50 units and 51 to 100 units as 0 to 100 units
153
Minimum Charges: Rs. 60 per connection per month as minimum charges towards
energy charges are applicable for above categories.
Note: The Authorized Load shall be as defined in the Madhya Pradesh Electricity Supply Code,
2013, as amended from time to time. (Every 75 units of consumption per month or part thereof
shall be considered equal to 0.5 kW of authorized load. Example: If consumption during the
month is 125 units, then the authorized load will be taken as 1 kW. In case the consumption is
350 units then the authorized load will be taken as 2.5 kW.)
Temporary/ DTR
meter connection
Temporary
connection for
construction of
own house (max.
up to one year).
Energy Charge –
Urban and Rural
Area
Existing Proposed
730
810
Existing
Proposed
Urban areas
330 for each one
kW of
sanctioned or
connected or
recorded load,
whichever is the
highest
Rural areas
250 for each one
kW of
sanctioned or
connected or
recorded load,
whichever is the
highest
Urban areas
350 for each one
kW of
sanctioned or
connected or
recorded load,
whichever is
highest
Rural areas
280 for each one
kW of
sanctioned or
connected or
recorded load,
whichever is the
highest
35 for each one
KW of
sanctioned or
connected or
recorded load
whichever is
highest for each
24 hours
duration or part
thereof
70 for each one
kW of
sanctioned or
connected or
recorded load,
whichever is
highest for each
24 hours
duration or part
thereof
50 for each one
kW of
sanctioned or
connected or
recorded load,
whichever is the
highest for each
24 hours
duration or part
thereof
NIL
NIL
NIL
Temporary
connection for
social/ marriage
purposes and
religious
functions.
730
810
50 for each one
kW of
sanctioned or
connected or
recorded load
whichever is
highest for each
24 hours
duration or part
thereof
Supply through
DTR meter for
clusters of
Jhuggi/Jhopadi till
individual meters
are provided
300
345
NIL
Minimum Charges: Rs. 1000/- per connection per month is applicable towards energy charges for
temporary connection and no minimum charges are applicable for supply through DTR meter for
clusters of Jhuggi/Jhopadi.
154
Energy Charge and Fixed Charge for un-metered domestic connections:
Units and Energy Charge to be billed per month for
unmetered connections (Paise per Unit)
Particulars
Un-metered connection
in urban areas
Un-metered connection
in rural areas
Existing
Proposed
100 units @ 470 per unit
Existing
85 per
connection
40 per
connection
Proposed
105 per
connection
70 per
connection
Minimum charges: No minimum charges are applicable to this category of consumers
Specific Terms and Conditions for LV-1 category:
a)
The Energy Charges corresponding to consumption recorded in DTR meter shall be
equally divided amongst all consumers connected to that DTR for the purpose of
billing. The Distribution Licensee will obtain consent of such consumers for billing as
per above procedure.
b) In case Energy Charges for actual consumption are less than minimum charges,
minimum charges shall be billed towards energy charges. All other charges, as
applicable, shall also be billed.
c)
Other terms and conditions shall be as specified under General Terms and Conditions
for Low Tension Tariff.
d) In case of prepaid consumers, a rebate of 5 paise per unit is applicable on all energy
units consumed on monthly basis and all other charges should be calculated on the
Tariff applicable after rebate. A consumer opting for prepaid meter shall not be
required to make any security deposit for the energy charge.
155
Tariff Schedule – LV-2 – NON DOMESTIC
LV 2.1
Applicability:
This tariff is applicable for light, fan and power to Educational Institutions including workshops and
laboratories of Engineering Colleges / Polytechnics/ITIs (which are registered with /affiliated/
recognized by the relevant Govt. body or university), Hostels for students or working women or
sports persons (run either by Govt. or individuals)
Energy Charge
(paise/unit)
Urban/ Rural areas
Existing
Proposed
Sub category
Sanctioned load based
tariff ( only for connected
load up to 20KW)
540
Monthly Fixed Charge (Rs.)
Existing
Urban Area
Rural Area
Proposed
Urban Area
Rural Area
615
100 per kW
70 per kW
120 per kW
90 per kW
615
200 per kW or
160 per kVA
of billing
demand
140 per kW or
112 per KVA
of billing
demand
220 per kW or
176 per kVA
of billing
demand
160 per kW or
128 per KVA
of billing
demand
Demand Based Tariff:
Optional: Only for
contract demand above 10
kW and up to 20 kW
(Proposed to be
removed)
540
Mandatory: for contract
demand above 20 kW
LV 2.2
Applicability:
This tariff is applicable for light, fan and power to Railways (for purposes other than traction and
supply to Railway Colonies/water supply), Shops/showrooms, Parlors, All Offices, Hospitals and
medical care facilities including Primary Health Centers, clinics, nursing homes belonging to either
Govt. or public or private organizations, public buildings, guest houses, Circuit Houses, Government
Rest Houses, X-ray plant, recognized Small Scale Service Institutions, clubs, restaurants, eating
establishments, meeting halls, places of public entertainment, circus shows, hotels, cinemas,
professional's chambers (like Advocates, Chartered Accountants, Consultants, Doctors etc.), bottling
plants, marriage gardens, marriage houses, advertisement services, advertisement boards/
hoardings, training or coaching institutes, petrol pumps and service stations, tailoring shops,
laundries, gymnasiums, health clubs, telecom towers for mobile communication and any other
establishment (except those which are covered in LV 2.1), who is required to pay Commercial
tax/service tax/value added tax (VAT)/entertainment tax/luxury tax under any Central/State Acts.
Sub category
On all units if
monthly
consumption is
Energy Charge (paise/unit)
Urban/Rural areas
Existing
Proposed
575
650
Urban areas
Rural areas
Urban areas
Rural areas
Existing
Proposed
55 per kW
35 per kW
75 per kW
55 per kW
156
Sub category
not more than 50
units
On all units in
case monthly
consumption
exceeds 50 units
Demand based
Tariff
Optional: Only
for contract
demand above 10
kW and up to 20
kW (Proposed to
be removed)
Energy Charge (paise/unit)
Urban/Rural areas
Existing
Proposed
650
555
Urban areas
Rural areas
Urban areas
Rural areas
Existing
Proposed
720
95 per kW
70 per kW
115 per kW
100 per kW
615
210 per kW
or 168 per
KVA of
billing
demand
140 per kW
or 112 per
KVA of
billing
demand
220 per kW
or 176 per
KVA of
billing
demand
160 per kW
or 128 per
KVA of
billing
demand
850
150 per kW
or part
thereof of
sanctioned
load or
connected or
recorded load
whichever is
highest
115 per kW
or part
thereof of
sanctioned
load or
connected or
recorded load
whichever is
highest
170 per kW
or part
thereof of
sanctioned
load or
connected or
recorded load
whichever is
highest
135 per kW
or part
thereof of
sanctioned
load or
connected or
recorded load
whichever is
highest
Mandatory: For
contract demand
above 20 KW
Temporary
connections
including Multi
point temporary
connection at LT
for Mela *
Temporary
connection for
marriage purposes
at marriage
gardens or
marriage halls or
any other premises
covered under LV
2.1 and 2.2
categories
For X-Ray plant
Single Phase
Three Phase
Dental X-ray
machine
775
775 (Minimum
consumption
charges shall be
billed @ 6
Units per kW
or part thereof
of sanctioned
or connected or
recorded load,
whichever is
the highest for
each 24 hours
duration or part
thereof subject
to a minimum
of Rs. 500)
850 (Minimum
consumption
charges shall
65 for each
45 for each
80 for each
be billed @ 6
kW or part
kW or part
kW or part
Units per kW
thereof of
thereof of
thereof of
or part thereof
sanctioned or sanctioned or sanctioned or
of sanctioned
connected or
connected or
connected or
or connected or recorded load recorded load recorded load
recorded load,
whichever is
whichever is
whichever is
whichever is
the highest
the highest
the highest
the highest for
for each 24
for each 24
for each 24
each 24 hours
hours
hours
hours
duration or part
duration or
duration or
duration or
thereof subject
part thereof
part thereof
part thereof
to a minimum
of Rs. 500)
Additional Fixed Charge (Rs. per machine per month)
Existing
Proposed
475
600
685
850
75
55 for each
kW or part
thereof of
sanctioned or
connected or
recorded load
whichever is
the highest
for each 24
hours
duration or
part thereof
100
* In case permission for organizing Mela is granted by Competent Authorities of the Government of
Madhya Pradesh
157
a) Minimum consumption: The consumer shall guarantee a minimum annual
consumption of 360 units per kW or part thereof in urban areas and 180 units per kW or
part thereof in rural areas of sanctioned load or contract demand (in case of demand
based charges) . However, the load of X-Ray unit shall be excluded while considering the
load of the consumer for calculation of minimum consumption. The method of billing
minimum consumption shall be as given in General Terms and Conditions of Low
Tension tariff.
b) Additional Charge for Excess demand: Shall be billed as given in General Terms and
Conditions of Low Tension tariff.
c) Rebate in Energy Charges for connection of Telecom Infra Structure situated in
rural areas: In order to give impetus to proliferation of telecommunication services in
the rural areas in the State, a rebate of paisa 15 per unit in energy charges shall be given
to the connections of mobile communication towers situated in rural areas.
d) Other terms and conditions shall be as specified under General Terms and Conditions of
Low Tension Tariff.
e) For the consumers having contract demand in excess of 20 kW, demand based tariff is
mandatory. The Distribution Licensee shall provide Trivector /Bivector Meter capable of
recording Demand in kVA/kW, kWh, kVAh.
f) In case of prepaid consumers, a rebate of 5 paise per unit is applicable on all energy units
consumed on monthly basis and all other charges should be calculated on the Tariff
applicable after rebate. A consumer opting for prepaid meter shall not be required to
make any security deposit for the energy charge.
158
Tariff Schedule – LV-3 – PUBLIC WATER WORKS AND STREET LIGHTS
Applicability:
It is proposed that the existing subcategories LV 3.1 for Public Water Works and LV 3.2 for
Street Light be merged.
The tariff is applicable for Public Utility Water Supply Schemes, Sewage Treatment Plants,
Sewage Pumping Installations run by P.H.E. Department or Local Bodies or Gram Panchayats or
any other organization authorized by the Government to supply/ maintain public water works /
sewerage installations and shall also be applicable to electric crematorium maintained by local
bodies/trusts.
The tariff shall also be applicable to traffic signals and lighting of public streets or public places
including parks, town halls, monuments and its institutions, museums, public toilets, public
libraries, reading rooms run by the Government or Local Bodies, and Sulabh Shochalaya
Note: Private water supply scheme, water supply schemes run by institutions for their own
use/employees/townships etc. shall not fall in this category. These shall be billed under the
appropriate tariff category to which such institution belongs. In case water supply is being
used for two or more different purposes then entire consumption shall be billed for purpose
for which the tariff is higher.
Category of consumers/area of applicability
Public Water Works
Energy Charge
(Paise per unit)
(Rs per KW)
Existing
Proposed
Existing
Proposed
Municipal Corporation/ Cantonment board
405
485
190
300
Municipality/ Nagar Panchayat
405
485
170
280
Gram Panchayat
405
485
75
80
Temporary supply
Street light (Merged with Public Water
Works)
Municipal Corporation/ Cantonment board
Minimum
charges
No
minimum
charges
1.3 times the applicable tariff
Merged
with
Municipality/ Nagar Panchayat
410
270
Public
Water
Gram Panchayat
410
65
Works
*It has been proposed to merge the categories of Public Water Works and Street Light
415
Merged with
Public
Water
Works
290
No
Minimum
charges
159
(a)
Incentives for adopting Demand Side Management:
An incentive equal to 5 % of Energy Charges shall be given on installation and use
of energy saving devices (such as ISI energy efficient motors for pump sets and
programmable on-off/ dimmer switch with automation for street lights). Incentive
will be admissible only if full bill is paid within due dates failing which all
consumed units will be charged at normal rates. Such incentive will be
admissible from the month following the month in which energy saving devices are
put to use and are verified by a person authorized by the Distribution Licensee.
This incentive will continue to be allowed till such time these energy saving devices
remain in service. The Distribution Licensee is required to arrange wide publicity of
above incentive.
(b)
Other terms and conditions shall be as specified under General Terms and
Conditions of Low Tension Tariff.
160
Tariff Schedule – LV-4 – LT INDUSTRIAL
Applicability:
Tariff LV-4 is applicable to light, fan and power for operating equipment used by printing
press and any other industrial establishments and workshops (where any processing or
manufacturing takes place including tyre re-treading). These tariffs are also applicable to cold
storage, gur (jaggery) making machines, flour mills, Masala Chakkies, hullers, khandsari units,
ginning and pressing units, sugar cane crushers (including sugar cane juicing machine), power
looms, dal mills, besan mills, and ice factories and any other manufacturing or processing units
(excluding bottling plant) producing/processing food items or processing agriculture produce for
preservation/increasing its shelf life and Dairy units ( where milk is processed to produce other
end products of milk other than chilling, pasteurization etc.)
Category of
consumers
4.1
Existing
Urban Areas Rural Areas
Non seasonal consumers
4.1a
Demand based
tariff (Contract
demand up to
150HP for existing
tariff and up to 100
HP for proposed
tariff)
4.1 b
Temporary
connection
260 per kW
or 208 per
KVA of
billing
demand
145 per kW
or 116 per
KVA of
billing
demand
Proposed
Urban Areas Rural Areas
290 per kW
or 232 per
KVA of
billing
demand
210 per kW
or 168 per
KVA of
billing
demand
Energy Charge (paise
per unit)
Urban/Rural area
Existing Proposed
570
635
1.3 times of the applicable tariff
*In case of consumers having contract demand up to 25 HP, the energy charges and fixed
charges shall be billed at a rate 30% less than the charges shown in above table for tariff
category 4.1a.
4.2 Seasonal Consumers (period of season shall not exceed 180 days continuously). If the declared season or off-season
spreads over two tariff periods, then the tariff for the respective period shall be applicable.
4.2 a
During
season
Normal tariff as for Non seasonal
consumers
Normal tariff as for non-seasonal
consumers
Normal tariff as for nonseasonal consumers
4.2 b
During
Off season
Normal tariff as for Non Seasonal
Consumers on 10% of contract
demand or actual recorded demand
whichever is more
Normal tariff as for Non
Seasonal Consumers on 10% of
contract demand or actual
recorded demand whichever is
more
120 % of normal tariff as
for Non-seasonal
consumers
161
Terms and Conditions:
(a)
The maximum demand of the consumer in each month shall be reckoned as four times the
largest amount of kilovolt ampere hours delivered at the point of supply of the consumer
during any continuous fifteen minutes in that month.
(b)
Demand based tariff is mandatory for all the LT industrial consumers and the licensee
shall provide Tri vector/ Bi vector Meter capable of recording Demand in kVA/ kW,
kWh, kVAh and Time of Use consumption within two months. For consumers presently
covered under the connected load LT industrial tariff category, licensee shall execute the
agreement based on the contract demand declared by such consumers within two months.
Till declaration of contract demand by the consumers and execution of the agreement, the
billing to such consumers shall be made treating their sanctioned load as the contract
demand
(c) Minimum Consumption: Shall be as per following:
i.
For LT Industries in rural areas: The consumer shall guarantee a minimum
annual consumption (kWh) based on 240 units per HP or part thereof of contract
demand irrespective of whether any energy is consumed or not during the year.
ii.
For LT Industries in urban areas: The consumer shall guarantee a minimum
annual consumption (kWh) based on 420 units per HP or part thereof of contract
demand irrespective of whether any energy is consumed or not during the year.
iii.
The consumer shall be billed monthly minimum 20 units per HP per month in rural
area and 35 units per HP per month in urban area in case the actual consumption is
less than above specified units.
iv.
Method of billing of minimum consumption shall be as given in the General Terms
and Conditions of Low Tension tariff.
(d)
Additional Charge for Excess Demand: Shall be billed as given in the General Terms
and Conditions of Low Tension Tariff.
(e)
Other terms and conditions shall be as specified under General Terms and Conditions of
Low Tension Tariff.
(f)
Other Terms and conditions for seasonal consumers:
i.
The consumer has to declare months of season and off season for the financial year
2016-17 within 60 days of issue of Tariff Order and inform the same to the
Distribution Licensee. If the consumer has already declared the period of season
and off-season during this financial year prior to issue of this Order, same shall be
taken into cognizance for the purpose and accepted by the Distribution Licensee.
ii.
The seasonal period once declared by the consumer cannot be changed during the
financial year.
162
iii.
This tariff is not applicable to composite units having seasonal and other category of
loads.
iv.
The consumer will be required to restrict his monthly off season consumption
to 15% of the highest of average monthly consumption during the preceding three
seasons. In case this limit is exceeded in any off season month, the consumer will be
billed under Non seasonal tariff for the whole financial year as per the tariff in force.
The consumer will be required to restrict his maximum demand during off season up to
30 % of the contract demand. In case the maximum demand recorded in any month of
the declared off season exceeds this limit, the consumer will be billed under Non
seasonal tariff for the whole financial year as per the tariff in force.
v.
163
Tariff Schedule – LV - 5 – AGRICULTURE AND ALLIED ACTIVITIES
Applicability:
The tariff LV-5.1 shall apply to connections for agricultural pump, chaff cutters, threshers,
winnowing machines, seeding machines and irrigation pumps of lift irrigation schemes including
water drawn by agriculture pumps for use by cattle.
The tariff LV-5.2 shall apply to connections for nurseries, farms growing flowers/ plants/ saplings/
fruits, mushroom and grasslands.
The tariff LV-5.3 shall apply to connections for fisheries ponds, aquaculture, sericulture,
hatcheries, poultry farms, cattle breeding farms and those dairy units only where extraction
of milk and its processing such as chilling, pasteurization etc. is done.
The tariff LV- 5.4 shall apply to connections for permanent agricultural pump, chaff cutters,
threshers, winnowing machines, seeding machines and irrigation pumps of lift irrigation schemes
including water drawn by agriculture pumps for use by cattle to whom flat rate tariff is
applicable.
S. No.
Sub-Category
Monthly Fixed
charges (Rs.)
Energy charges
(Paise per unit)
Monthly
Fixed
charges
(Rs.)
Existing
Energy charges
(Paise per unit)
Proposed
LV- 5.1
a)
(i)
(ii)
(iii)
b)
c)
First 300 units per
month
Above 300 units up to
750 units in the month
Rest of the units in the
month
Temporary
connections
DTR metered group
consumers
355
25
420
425
50
450
480
525
25
462
50
550
NIL
325
NIL
380
LV-5.2
a) (i)
(ii)
(iii)
b)
First 300 units per
month
Above 300 units up to
750 units in the month
Rest of the units in the
month
Temporary
connections
355
25
420
425
50
450
480
525
25
462
50
550
65 per HP
410
75 per HP
490
35 per HP
400
50 per HP
480
180 per kW or 144
500
200 per kW or
580
LV-5.3
a)
b)
c)
Up to 25 HP in urban
areas
Up to 25 HP in rural
areas
Demand based tariff (
164
S. No.
d)
Sub-Category
Contract demand and
connected load up to
100 HP) in urban
areas
Demand based tariff (
Contract demand and
connected load up to
100 HP) in rural areas
Monthly Fixed
charges (Rs.)
Energy charges
(Paise per unit)
Existing
per kVA of billing
demand
85 per kW or 68 per
kVA of billing
demand
Monthly
Fixed
charges
(Rs.)
Energy charges
(Paise per unit)
Proposed
160 per kVA
of billing
demand
500
100 per kW or
80 per kVA of
billing
demand
580
LV 5.4
Agriculture flat rate
exclusive of subsidy
*
a)
b)
c)
d)
Rate payable by the
consumer in Rs per
HP per month for
months of April to
September
Three phase- urban
Three phase- rural
Single phase urban
Single phase rural
100
100
100
100
Rate payable by
the consumer in
Rs per HP per
month for the
months of October
to March
100
100
100
100
Same as previous tariff order
* see para 1.2 of terms and conditions
165
1.1.
Billing of consumers under tariff schedule LV 5.1: Billing to the
consumers covered under tariff schedule LV 5.1 shall be done on a monthly basis based
on the consumption recorded in the meter. Unmetered temporary connection under this
schedule shall be billed on the basis of assessment of consumption provided under
condition 1.3 (iii) of this schedule.
1.2.
Billing of consumers under tariff schedule LV 5.4: Rates payable by the consumer
under tariff schedule LV 5.4 are exclusive of subsidy. The bill for the consumer covered
under the tariff schedule LV 5.4 shall be calculated at the rates specified under the tariff
schedule LV 5.1 based on norms for assessment of units per HP specified under condition
1.3 of this schedule. The consumer shall be required to pay at the rates specified under
tariff schedule LV 5.4 and the balance amount of the bill shall be paid by the State
Govt. as advance subsidy to the Distribution licensee.
1.3. Basis of energy audit and accounting for categories LV 5.1 and LV 5.4:
i)
For energy audit and accounting purposes, actual billed consumption of metered
consumers covered under tariff schedule LV 5.1 and LV 5.4 shall be considered.
ii)
For unmetered agriculture consumers under LV 5.4 category, assessed consumption
shall be as per following norms
Particulars
Type of Pump Motor
Three Phase
Single Phase
iii)
No. of units per HP or part thereof of sanctioned load per
month
Urban Area
Rural Area
April to
Oct to
April to
Oct to
Sept
March
Sept
March
90
170
80
170
90
180
90
180
For unmetered temporary agriculture consumers under LV 5.1 category, assessed
consumption shall be as per following norms:
Particulars
Type of Pump Motor
Three Phase
Single Phase
No. of units per HP or part thereof of sanctioned load per
month
Urban Area
Rural Area
220
195
230
205
1.4. Agricultural consumers opting for temporary supply shall have to pay the charges in
advance for three months including those who request to avail connection for one
month only subject to replenishment from time to time for extended period and
adjustment as per final bill after disconnection. Regarding temporary connection for
the purpose of threshing the crops, temporary connection for a period of one month
166
can be served at the end of Rabi and Kharif seasons only with payment of one month’s
charges in advance.
1.5.
Following incentive* shall be given to the metered agricultural consumers on
installation of energy saving devices –
S. No.
1.
2.
3.
Particulars of Energy Saving Devices
ISI / BEE star labeled motors for pump sets
ISI / BEE star labeled motors for pump sets and use of frictionless
PVC pipes and foot valve
ISI / BEE star labeled motors for pump sets and use of frictionless
PVC pipes and foot valves along with installation of shunt
capacitor of appropriate rating
Rate of rebate
15 paise per unit
30 paise per unit
45 paise per unit
*Incentive shall be allowed on the consumer’s contribution part of the normal tariff (full tariff
minus amount of Govt. subsidy per unit, if any) for installation of energy saving devices under
demand side management. This incentive will be admissible only if full bill is paid within due dates
failing which all consumed units will be charged at normal rates. Incentive will be admissible from
the month following the month in which Energy Saving Devices are put to use and its verification
by a person authorized by the Distribution Licensee. The Distribution Licensee is required to
arrange wide publicity to above incentive in rural areas. The licensee is required to place quarterly
information regarding incentives provided on its web site.
1.6. Minimum consumption
(i)
For Metered agricultural consumers (LV-5.1 and LV-5.2): The consumer shall
guarantee a minimum consumption of 30 units per HP or part thereof of connected load
per month for the months from April to September and 90 units per HP or part thereof of
connected load per month for the months from October to March irrespective of whether
any energy is consumed or not during the month.
(ii)
For other than agricultural use (LV-5.3) :
a)
The consumer will guarantee a minimum annual consumption (kWh) based
on 180 units/HP or part thereof of contract demand in notified rural areas and 360
units/HP or part thereof of contract demand in urban areas irrespective of whether any
energy is consumed or not during the year.
b)
The consumer shall be billed monthly minimum 15 units per HP per month
in rural area and 30 units per HP per month in urban area in case the actual
consumption is less than monthly minimum consumption (kWh).
c)
Method of billing of minimum consumption shall be as given in the
General Terms and Conditions of Low Tension Tariff.
1.7.Additional Charge for Excess Demand: Shall be billed as given in the General Terms and
Conditions of LT Tariff.
167
1.8.Delayed payment surcharge in case of agriculture consumers on LV - 5.4 flat rate tariff
shall be levied @ of Rs 1 every month for each block or part thereof of arrears of Rs.100/-. For
other sub categories of this Tariff Schedule, the delayed payment surcharge shall be billed
as specified under General Terms and Conditions of Low Tension Tariff.
1.9.Specific conditions for DTR metered consumers:
a. All the consumers connected to the DTR shall pay the energy charges for the units
worked out based on their actual connected load.
b. The Distribution Licensee will obtain consent of such connected consumers for
billing as per procedure specified in (a) above.
1.10.
One CFL/ LED/ bulb up to 20 W is permitted at or near the pump in the power
circuit.
1.11.
The use of three phase agriculture pump by installing external device during the
period when the supply is available on single phase, shall be treated as illegal
extraction of energy and action as per prevailing rules and Regulations shall be taken
against the defaulting consumer.
1.12.
Other terms and conditions shall be as specified under General Terms and Conditions
of Low Tension Tariff.
168
GENERAL TERMS AND CONDITIONS OF LOW TENSION TARIFF
1. Rural Areas mean those areas notified by the GoMP vide notification no.
2010/F13/05/13/2006 dated 25th March 2006 as may be amended from time to time.
Urban areas mean all areas other than those notified by the GoMP as Rural Areas.
2. Rounding off: All bills will be rounded off to the nearest rupee i.e. up to 49 paisa shall be
ignored and 50 paisa upwards shall be rounded off to next Rupee.
3. Billing Demand: In case of demand based tariff, the billing demand for the month shall be
the actual maximum kVA demand of the consumer during the month or 90% of the contract
demand, whichever is higher. The billing demand shall be rounded off to the nearest integer
number i.e. fraction of 0.5 or above will be rounded to next higher integer and the fraction of
less than 0.5 shall be ignored.
4. Fixed charges billing: Unless specified otherwise, fractional load for the purposes of billing
of fixed charges shall be rounded off to nearest integer i.e. fraction of 0.5 or above will be
rounded to next higher integer and the fraction of less than 0.5 shall be ignored. However
for loads less than one kW/HP, it shall be treated as one kW/HP.
5. Method of billing of minimum consumption:
A. For metered agricultural consumers and other than agricultural consumers’
horticulture activity - LV 5.1 and LV 5.2: The consumer shall be billed minimum
monthly consumption (kWh) specified for his category for the month in which his
actual consumption is less than prescribed minimum consumption.
B. For other consumers where applicable :
a. The consumer shall be billed one twelfth of guaranteed annual minimum
consumption (kWh) specified for his category each month in case the actual
consumption is less than above mentioned minimum consumption.
b. During the month in which actual cumulative consumption equals or is greater than
the annual minimum guaranteed consumption, no further billing of monthly minimum
consumption shall be done in subsequent months of the financial year and only actual
recorded consumption shall be billed.
c. Tariff minimum consumption shall be adjusted in the month in which cumulative
actual or billed monthly consumption exceeds cumulative monthly prorated minimum
annual guaranteed consumption. If actual cumulative consumption does not get fully
adjusted in that month, adjustment shall continue to be provided in subsequent
months of the financial year. The following example illustrates the procedure for
monthly billing of consumption where prorated monthly minimum consumption is
100 kWh based on annual consumption of 1200 kWh.
169
Month
Actual
cumulative
consumption
(kWh)
Cumulative
minimum
consumption
(kWh)
Higher of 2
and 3
(kWh)
Already
billed in the
year (kWh)
To be billed
in the month
= (4-5)
(kWh)
1
2
3
4
5
6
April
95
100
0
100
May
215
100
200
215
100
115
June
315
300
315
215
100
July
395
400
400
315
85
Aug
530
500
530
400
130
Sept
650
600
650
530
120
Oct
725
700
725
650
75
Nov
805
800
805
725
80
Dec
945
900
945
805
140
Jan
1045
1000
1045
945
100
Feb
1135
1100
1135
1045
90
March
1195
1200
1200
1135
65
6. Additional Charge for Excess connected load or Excess Demand: Shall be billed as per
following procedure:
a) Consumers opting for demand based tariff: The consumers availing supply at
demand based tariff shall restrict their actual maximum demand within the contract
demand. However, in case the actual maximum demand recorded in any month
exceeds 105% of the contract demand, the tariff in this schedule shall apply to the
extent of 105 % of the contract demand only. The consumer shall be charged for
demand recorded in excess of 105% of contract demand (termed as Excess Demand)
and consumption corresponding thereto at the following rates:i.
Energy charges for Excess Demand: The consumer shall pay charges @ 1.3
times the tariff for energy charges for consumption corresponding to excess
demand in case the maximum demand recorded exceeds the 105% of the contract
demand.
Example: If a consumer having a contract demand of 50 kVA records a maximum demand of
60 kVA, the billing of energy charges for excess demand of (60 kVA-52.5 kVA)= 7.5 kVA
shall be = (total consumption recorded during the month*7.5 kVA/maximum recorded
demand)*1.3* energy charge unit rate.
ii.
Fixed Charges for Excess Demand: These charges shall be billed as per following:
1.
Fixed Charges for Excess Demand when the recorded maximum demand
is up to 115% of the contract demand: Fixed Charges for Excess Demand over
and above 105% of the contract demand shall be charged at 1.3 times the normal
rate of Fixed Charges.
170
2.
Fixed Charges for Excess Demand when the recorded maximum demand
exceeds 115% of contract demand: In addition to Fixed Charges in 1 above,
recorded demand over and above 15 % of the contract demand shall be charged
at 2 times the normal rate of Fixed Charges.
b) Consumers opting for connected load based tariff: The consumers availing supply
at connected load based tariff shall restrict their actual connected load within the
sanctioned load. However, in case the actual connected load in any month exceeds
105% of the sanctioned load, the tariff in this schedule shall apply to the extent of
105% of the sanctioned load only. The consumer shall be charged for the connected
load found in excess of 105% of the sanctioned load (termed as Excess Load)
and consumption corresponding thereto at the following rates:i.
Energy charges for Excess Load: The consumer shall pay charges @ 1.3
times the tariff for energy charges for consumption corresponding to excess
load in case the connected load found at the consumer’s premises exceeds
105% of the sanctioned load for the entire period for which such use of
excess load has taken place and if, however, the period during which such
use of excess load has taken place cannot be ascertained, such period shall
be limited to a period of twelve months immediately preceding the date of
inspection.
Example: If a consumer having a sanctioned load of 100 kW and connected load
is found of 107 kW, the billing of energy charges for excess load of (107 kW- 105
kW)= 2 kW shall be = (total consumption recorded during the month* 2kW
connected load found)*1.3* energy charge unit rate.
ii.
Fixed Charges for Excess load: These charges shall be billed as per
following, for the period for which the use of excess load is determined in
condition i) above:
1.
Fixed Charges for Excess load when the connected load is found up to
115% of the sanctioned load: Fixed Charges for Excess load over and
above 105% of the sanctioned load shall be charged at 1.3 times the
normal rate of Fixed Charges.
2.
Fixed Charges for Excess load when the connected load exceeds 115%
of sanctioned load: In addition to Fixed Charges in 1 above, connected
load found over and above 15% of the sanctioned load shall be charged
at 2 times the normal rate of Fixed Charges.
c) The above billing for Excess connected Load or Excess Demand, applicable to
consumers is without prejudice to the Distribution Licensee’s right to ask for revision of
agreement and other such rights that are provided under the Regulations notified by
the Commission or under any other law.
171
The maximum demand of the consumer in each month shall be reckoned as four times the
largest amount of kilovoltampere hours delivered at the point of supply of the consumer
during any continuous fifteen minutes in that month.
7. Other Terms and Conditions:
(a)
For advance payment made before commencement of consumption period for
which bill is prepared, a rebate of 1 % per month on the amount (excluding
security deposit) which remains with the Distribution Licensee at the end of
calendar month shall be credited to the account of the consumer after adjusting
any amount payable to the Distribution Licensee.
(b)
Incentive for prompt payment: An incentive for prompt payment @0.25% of
the bill amount (excluding arrears, security deposit, meter rent and Government
levies viz. Electricity Duty and Cess etc.) shall be given in case the payment is
made at least 7 days in advance of the due date of payment. The consumers in
arrears shall not be entitled for this incentive.
(c)
All LT consumers who have no arrears shall be given rebate of Rs 5 per bill for
online payment of the energy bill in full.
(d)
The Sanctioned Load or Connected Load or Contract Demand should not exceed
75 kW / 100 HP except where a higher limit is specified or the category is
exempted from the ceiling on connected load. If the consumer exceeds his
connected load or contract demand beyond this ceiling on more than two
occasions in two billing months during the tariff period, the Distribution Licensee
may insist on the consumer to avail HT supply.
(e)
Metering Charges shall be billed as per schedule of Metering and Other Charges
as prescribed in MPERC (Recovery of Expenses and other Charges for providing
Electric Line or Plant used for the purpose of giving supply), Regulations
(Revision-I), 2009. Part of a month will be reckoned as full month for purpose of
billing.
(f)
In case the cheque presented by the consumer is dishonoured, without prejudice
to Distribution Licensee’s rights to take recourse to such other action as may be
available under the relevant law, a service charge of Rs. 200 per cheque shall be
levied in addition to delayed payment surcharge
(g)
Other charges as stated in Schedule of Miscellaneous Charges shall also be
applicable.
(h)
Welding Surcharge is applicable to installations with welding transformers, where
the connected load of welding transformers exceeds 25% of the total connected
load and where suitable capacitors of prescribed capacity have not been installed to
ensure power factor of not less than 0.8 (80%) lagging. Welding Surcharge of 75
(seventy five) paisa per unit shall be levied for the consumption of the entire
installation during the month. However, no welding surcharge shall be levied when
172
recorded power factor is 0.8 or more
(i)
For purposes of computing the connected load in kW of the welding transformers, a
power factor of 0.6 (60%) shall be applied to the maximum current or kVA
rating of such welding transformers.
(j)
Existing LT power consumer shall ensure that LT capacitor of proper rating is
provided. In this regard, the Madhya Pradesh Electricity Supply Code, 2013, as
amended from time to time may be referred for guidance. It shall be the
responsibility of the consumer to ensure that overall average power factor during
any month is not less than 0.8 (80%) failing which the consumer shall be liable to
pay low power factor surcharge on the entire billed amount against energy
charges during the month at the rates given below:
1. For the consumer whose meter is capable of recording average power
factor:
a. Surcharge @ 1 % of energy charges for every 1% fall in power factor
below 80% up to 75 %.
b. Surcharge of 5% plus 1.25% of energy charges for every 1% fall in
power factor below 75% up to 70%.
The maximum limit of surcharge will be 10 % of the energy charges billed
during the month.
2. For LT consumer having meter not capable of recording average power
factor: The consumer shall ensure that LT capacitors of proper rating are
provided and are in good working condition. In this regard, the Madhya
Pradesh Electricity Supply Code, 2013, as amended from time to time may be
referred for guidance. In case of failure to meet the above criteria, the
consumer would be levied a low power factor surcharge of 10% on the entire
billed amount against energy charges during the month and would be
continued to be billed till such time the consumer meets the above criteria .
(k)
Levy of welding / power factor surcharge as indicated hereinabove shall be without
prejudice to the rights of the Licensee to disconnect the consumer’s installation,
if steps are not taken to improve the power factor by installing suitable shunt
capacitors.
(l)
Load Factor incentive: Following slabs of incentive shall be allowed for consumers
billed under demand based tariff:
173
Load factor
For load factor above 25% and up to 30 % load
factor on contract demand
Concession in energy charges
12 paise per unit concession on the normal energy charges for
all energy consumption over and above 25% load factor during
the billing month
For load factor above 30% and up to 40 % load
factor on contract demand
In addition to load factor concession available up to 30% load
factor , concession at the rate of 24 paise per unit on the
normal energy charges for all energy consumption over
and above 30 % load factor during the billing month
For load factor above 40% load factor on contract
demand
In addition to load factor concession available up to 40% load
factor, concession at the rate of 36 paise per unit on the
normal energy charges for all energy consumption over
and above 40% load factor during the billing month
The load factor shall be calculated as per the following formula:
Monthly consumption X 100
Load factor (%) = -----------------------------------------------------------------No. of hours in the billing month X Demand X PF
i.
Monthly consumption shall be units (kWh) consumed in the month excluding
those received from sources other than Licensee.
ii.
No. of Hours in billing month shall exclude period of scheduled outages in hours.
iii.
Demand shall be maximum demand recorded or contract demand whichever is
higher.
iv.
Power factor shall be 0.8 or actual monthly power factor whichever is higher
Note: The Load Factor (%) shall be rounded off to the nearest lower integer. The billing
month shall be the period in number of days between the two consecutive dates of meter
readings taken for the purpose of billing to the consumer for the period under
consideration as a month.
(l)
In case of any dispute on applicability of tariff on a particular LT category, the
decision of the Commission shall be final.
(m)
The tariff does not include any tax, cess or duty, etc. on electrical energy that may
be payable at any time in accordance with any law then in force. Such charges, if
any, shall also be payable by the consumer in addition to the tariff charges and
applicable miscellaneous charges.
(n)
Delayed payment Surcharge for all categories: Surcharge at the rate of 1.25 % per
month or part thereof on the amount outstanding (including arrears) will be payable
if the bills are not paid up to due date subject to a minimum of Rs.5/- per month for
total outstanding bill amount up to Rs. 500/- and Rs 10/ per month for amount of bill
more than Rs.500/. 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
174
permanently disconnected. This provision shall not be applicable to that category
where the levy of delayed payment surcharge has been prescribed separately.
(o)
In case of conversion of LT connection into HT connection, it is mandatory on the
part of both the consumer and the licensee to get the HT agreement executed
before availing supply at HT.
(p)
Power Factor Incentive:
If the average monthly power factor of the consumer is equal to or more than 85%,
incentive shall be payable as follows:
Power Factor
Above 85% up to 86%
Above 86% up to 87%
Above 87% up to 88%
Above 88% up to 89%
Above 89% up to 90%
Above 90% up to 91%
Above 91% up to 92%
Above 92% up to 93%
Above 93% up to 94%
Above 94% up to 95%
Above 95% up to 96%
Above 96% up to 97%
Above 97% up to 98%
Above 98% up to 99%
Above 99%
Percentage incentive payable on billed energy charges
0.5
1.0
1.5
2.0
2.5
3.0
3.5
4.0
4.5
5.0
6.0
7.0
8.0
9.0
10.0
For this purpose, the “average monthly power factor” is defined as the ratio in
percentage of total kilowatthours to the total kilovoltampere hours recorded during the
month.
(q)
Use of mix loads in one connection: Unless otherwise permitted specifically in the
tariff category, the consumer requesting for use of mix loads for different
purposes shall be billed for the purpose for which the tariff is higher.
(r)
All LT permanent consumers excluding LT Agricultural consumers shall be
allowed to use not more than 10% of their sanctioned load / contract demand for
any such usage which comes under the definition of temporary connection for the
same purpose, subject to the condition that the combined load/ demand shall not
exceed the sanctioned load/ contracted demand.
(s)
Consumers in the notified Industrial Growth Centres area receiving supply under
urban discipline shall be billed urban tariff.
(t)
No change in the tariff or the tariff structure including minimum charges for any
category of consumer is permitted except with prior written permission from the
175
Commission. Any action taken without such written permission of the
Commission shall be treated as null and void and shall also be liable for action
under relevant provisions of the Electricity Act, 2003.
(u)
All conditions prescribed herein shall be applicable to the consumer
notwithstanding if any contrary provisions exist in the agreement entered into by
the consumer with the licensee.
8. Additional conditions for Temporary Supply at LT:
(a)
Temporary supply cannot be demanded by a prospective/ existing consumer as a matter of
right but will normally be arranged by the Distribution Licensee when a requisition giving due
notice is made. The temporary additional supply to an existing consumer also shall be
treated as a separate service and charged subject to following conditions. However service
under Tatkal Scheme shall be made available within 24 hours according to the charges
specified in the order of the Commission regarding Schedule of Miscellaneous Charges.
(b)
Fixed Charge and Energy Charge for temporary supply shall be billed at 1.3 times the normal
charges as applicable to relevant category if not specified otherwise specifically.
(c)
Estimated bill amount is payable in advance before serving the temporary connection
subject to replenishment from time to time and adjustment as per final bill after disconnection.
No interest shall be given to consumers for this advance payment.
(d)
The Sanctioned load or connected load shall not exceed 75 kW / 100 HP.
(e)
The month for the purpose of billing of charges for temporary supply shall mean 30 days
from the date of connection. Any period less than 30 days shall be treated as full month for
the purpose of billing.
(f)
Connection and disconnection charges and other miscellaneous charges shall be paid
separately as may be specified in the Schedule of Miscellaneous Charges.
(g)
Load factor concession shall not be allowed on the consumption for temporary connection.
(h)
Power factor incentive/penalty shall be applicable at the same rate as applicable for
permanent connection
176
TARIFF SCHEDULES FOR HIGH TENSION CONSUMERS
Tariff Schedules
Page No
HV1- Railway Traction
178
HV2-Coal Mines
180
HV3- Industrial, Non-Industrial and Shopping Malls
181
HV4- Seasonal and Non-Seasonal
184
HV5- Irrigation, Public Water Works and Other than
Agricultural
186
HV6- Bulk Residential Users
188
HV7- Synchronization and Start up Power for Generators
connected to the grid
190
General Terms and Conditions of High Tension Tariff
191
177
Tariff Schedule-- HV-1 – RAILWAY TRACTION
Applicability:
This Tariff shall apply to the Railways for Traction loads only.
Tariff:
Monthly
Fixed
Energy
Charge (Rs. per
Charge
kVA
of
billing
(paise / unit)
demand per month)
Existing
Category of
consumer
Railway Traction
on 132 kV / 220
kV
280
540
Monthly
Fixed
Charge (Rs. per
kVA
of
billing
demand per month)
Energy
Charge (paise /
unit) for LF
<50%
Proposed
350
600
Energy Charge
(paise / unit) for
LF>50%
550
In order to facilitate Railways strengthen its network and infrastructure in the state of Madhya
Pradesh, the tariff has been proposed to be increased marginally as compared to the overall
required tariff increase, to meet the existing the revenue-expenditure gap.
Specific Terms and Conditions:
(a)
In order to give impetus to electrification of Railway network in the State, a rebate of
10% in energy charges for new Railway traction projects shall be allowed for a period
of five years from the date of connection for such new projects for which agreements for
availing supply from licensee are finalized during 2016-17. The rebate provided in earlier
Orders shall remain in force at the rate and for the duration as mentioned in those Tariff
Orders.
(b)
The dedicated feeder maintenance charges shall not be applicable.
(c)
Guaranteed Annual Minimum Consumption shall be 1500 units (kWh) per kVA of
Contract Demand. The method of billing of minimum consumption shall be as given in
General Terms and Conditions of High Tension Tariff.
(d)
Power Factor Penalty:
i.
If the average monthly power factor of the consumer falls below 90 percent, penalty will
be levied at the rate of one percent of total energy charges for the month for each one
percent fall in the average monthly power factor below 90 percent. For determination of
power factor, lag only logic shall be used and no power factor penalty shall be
levied if leading power factor is recorded.
iii. If the average monthly power factor of the consumer falls below 85 percent, the
consumer shall be levied a penalty of 5% (five percent) plus @ 2% (two percent) for
each one percent fall in his average monthly power factor below 85 percent, on the total
amount of bill under the head of “Energy Charge”.
178
This penalty shall be subject to the condition that overall penalty on account of low
power factor does not exceed 35%.
iv. For this purpose, the “average monthly power factor” is defined as the ratio expressed
in percentage of total kilowatthours recorded to the total kilovoltampere hours
recorded during the billing month. This ratio (%) shall be rounded off to the nearest
integer figure and the fraction of 0.5 or above will be rounded to next higher integer and
the fraction of less than 0.5 shall be ignored.
v. Notwithstanding what has been stated above, if the average power factor of a new
connection of the consumer is found to be less than 90% in any month during the first 6
(six) months from the date of connection, the consumer shall be entitled to a maximum
period of six months to improve it to not less than 90% subject to following conditions:

This period of six months shall be reckoned from the month in which the
average power factor was found for the first time to be less than 90%.

In all cases, the consumer will be billed penal charges for low power factor, but in
case the consumer maintains the average power factor in subsequent three months
(thus in all four months) to not less than 90%, the charges on account of low
power factor billed during the said six months period, shall be withdrawn and
credited in next monthly bills.

The facility, as mentioned herein, shall be available not more than once to new
consumer whose average power factor is less than 90% at any time during 6 months
from the date of connection. Thereafter, the charges on account of low average
power factor, if found less than 90%, shall be payable as by any other consumer.
(e)
Emergency feed extension: Provided that if as a result of the emergency in the traction
substation or in the transmission line supplying load or part thereof is transferred to an
adjacent traction substation, the M.D. for the month for that adjacent traction substation
shall be as the average of M.D. for previous three months during which no emergency had
occurred.
(f)
Other terms and conditions shall be as mentioned in the General Terms and Conditions of
High Tension Tariff.
179
Tariff Schedule – HV - 2 – COAL MINES
Applicability:
This Tariff shall apply to the Coal Mines for power, ventilation, lights, fans, coolers, etc. which shall
mean and include all energy consumed for coal mines and lighting in the offices, stores, canteen,
compound lighting etc. and the consumption for residential use therein.
Sub
category
Coal
Mines
11 kV
supply
33 kV
supply
132 kV
supply
220 kV
supply
(Rs./kVA of billing
demand per month)
Existing
Proposed
Energy Charge for
consumption up to
50% load factor
(Paise/unit)
Energy Charge for
consumption in excess of
50% load factor
(paise/unit)
Existing
Proposed
Existing
Proposed
560
570
580
605
520
530
570
580
570
590
500
510
580
600
555
575
490
500
590
625
540
560
480
490
a. Guaranteed Minimum Consumption shall be on the following basis :
Supply Voltage
For supply at 220 / 132 kV
For supply at 33 / 11 kV
Guaranteed
annual
minimum consumption in units
(kWh) per kVA of contract
demand
1620
1200
Note: The method of billing of minimum consumption shall be as given in General Terms and
Conditions of High Tension Tariff.
b. Load Factor Incentive: The consumer shall be eligible for Load Factor incentive on
energy charges as per the scheme given in General Terms and Conditions of High Tension
Tariff.
c. Time of Day Surcharge / Rebate: This surcharge/ rebate shall be as specified in
d. Other terms and conditions shall be as specified under General Terms and Conditions of
High Tension Tariff.
180
Tariff Schedule – HV - 3 – INDUSTRIAL, NON-INDUSTRIAL AND SHOPPING MALLS
Applicability:
The tariff HV-3.1(Industrial) shall apply to all HT industrial consumers including mines (other than
coal mines) for power, light and fan etc. which shall mean and include all energy consumed for
factory and lighting in the offices, main factory building, stores, canteen, residential colonies of
industries, compound lighting, common and ancillary facilities such as Banks, General purpose
shops, Water supply, Sewage pumps, Police Stations etc. in the premises of the industrial units
and Dairy units where milk is processed (other than chilling, pasteurization etc.) to produce other
end products of milk.
The sub-categories HV 3.2 Non Industrial and HV 3.3 (Shopping Malls) are proposed to be merged
considering the non-industrial and commercial nature of the business of the establishments.
The tariff HV-3.2 (Non Industrial and Shopping Malls) shall apply to establishments like Railway
Stations, Offices, Hotels, Hospitals, Institutions etc. (excluding group of consumers) having mixed
load for power, light and fan etc. which shall mean and include all energy consumed for lighting in
the offices, stores, canteen, compound lighting etc. This shall also cover all other categories of
consumers, defined in LT non-domestic category subject to the condition that the HT consumer
shall not redistribute/sub-let the energy in any way to other person. The tariff shall also apply to
establishments of shopping malls having group of non-industrial consumers subject to the specific
terms and conditions specified in (e) of this schedule.
Shopping Mall shall be a multistoried shopping centre in an urban area having a system of
enclosed walkways with collection of independent retail stores, services and parking areas
constructed and maintained by a management firm/ developer as a unit.
The tariff HV-3.4 (Power intensive industries) shall apply to Mini Steel Plants (MSP), MSP with
rolling mills/ sponge iron plants in the same premises, electro chemical/ electro thermal industry,
Ferro alloy industry, which shall mean and include all energy consumed for factory and lighting in
the offices, main factory building, stores, canteen, residential colonies of industries, compound
lighting etc.
S.
No.
SubCategory of
consumer
Monthly
Fixed
Charge
(Rs/KVA) of
billing
demand per
month
Energy
Charge for
consumption
on up to
50% load
factor
(paise/unit)
Energy
Charge for
consumption
in excess
50% load
factor
(paise/unit)
Monthly
Fixed
Charge
(Rs/KVA) of
billing
demand per
month
Existing
3.1
3.2
Energy
Charge for
consumption
on up to
50% load
factor
(paise/unit)
Energy
Charge for
consumption
in excess
50% load
factor
(paise/unit)
Proposed
Industrial
11 kV supply
280
575
520
300
650
605
33 kV supply
435
565
470
465
635
550
132 kV supply
220/400 kV
supply
NonIndustrial
525
525
455
555
585
515
560
505
435
600
570
500
181
S.
No.
3.3
3.4
SubCategory of
consumer
Monthly
Fixed
Charge
(Rs/KVA) of
billing
demand per
month
Energy
Charge for
consumption
on up to
50% load
factor
(paise/unit)
Energy
Charge for
consumption
in excess
50% load
factor
(paise/unit)
Monthly
Fixed
Charge
(Rs/KVA) of
billing
demand per
month
Energy
Charge for
consumption
on up to
50% load
factor
(paise/unit)
Energy
Charge for
consumption
in excess
50% load
factor
(paise/unit)
11 kV supply
250
605
545
300
660
615
33 kV supply
370
590
530
400
640
560
132 kV supply
Shopping
Malls (to be
merged with
Non
Industrial)
11 kV supply
475
540
485
500
605
550
230
615
540
33 kV supply
340
595
525
132 kV supply
Power
intensive
industries*
33 kV supply
450
540
485
Merged with
Non
Industrial
Merged with
Non
Industrial
Merged with
Non
Industrial
470
430
430
540
550
550
132 kV supply
570
410
410
630
510
510
220 kV supply
610
400
400
670
500
500
* It has been proposed to merge the categories HV 3.2 Non Industrial and HV 3.3 Shopping Malls.
*Category HV 3.4 shall not be entitled to load factor incentive. Further energy charges for this
category shall be same for entire consumption irrespective of load factor.
182
1. Guaranteed Minimum Consumption for all the above categories shall be on following
basis :
Supply Voltage
For supply at
220/132 kV
For supply at 33 /
11 kV
Sub- category
Rolling Mills
Educational institutions
Others
Educational institutions
Contract demand up to 100 kVA
Others
Guaranteed annual minimum
consumption in units (kWh) per kVA
of contract demand
1200
720
1800
600
600
1200
Note: The method of billing of minimum consumption shall be as given in General Terms
and Conditions of High Tension Tariff.
2. Load Factor Incentive: The consumer shall be eligible for Load Factor incentive on energy
charges as per the scheme given in General Terms and Conditions of High Tension Tariff.
However consumers under category HV 3.4 shall not be entitled to load factor incentive.
3. Time of Day Surcharge / Rebate: This surcharge/ rebate shall be as specified in General
Terms and Conditions of High Tension Tariff.
4. Rebate for supply through feeders feeding supply to predominantly to rural areas : HT
consumers of this category receiving supply through rural feeders shall be entitled to 5 %
rebate on Fixed Charges and 20 % reduction in Minimum Consumption (kWh) as specified
above for respective voltage levels.
5. Additional specific terms and conditions for shopping mall
(i) Individual end user shall not be levied a rate which is exceeding non-domestic- commercial
tariff (LV 2.2) in case of LT connection, as determined by the Commission.
(ii) All end-users shall enter into a tripartite agreement with the Management Firm /developer of
the shopping mall and the licensee for availing supply of electricity in the shopping mall in
order to get the benefit of the tariff under this category.
6. Other terms and conditions shall be as specified under General Terms and conditions
of High Tension Tariff.
183
Tariff Schedule – HV - 4 – SEASONAL and NON SEASONAL
Applicability:
This tariff shall be applicable to such seasonal industries / consumers requiring energy for the
production purposes for maximum continuous one hundred eighty days and for a minimum
period of three months. If the declared season/off-season spreads over two tariff periods,
then the tariff for the respective period shall be applicable.
The licensee shall allow this tariff to any industry having seasonal use only.
This tariff shall also be applicable to mini/micro and small hydel plants to meet the
essential requirement of power to maintain the plants without any ceiling as to the period for
which supply shall be taken.
Tariff:
Category of
consumers
(Rs./kVA of billing demand
per month)
Energy Charge for
consumption up to 50%
load factor (paise / unit)
Energy Charge for
consumption in excess of
50% load factor (paise
per unit)
During Season
Existing
Proposed
Existing
Proposed
Existing
Proposed
11 kV supply
290
320
550
600
495
545
33 kV supply
320
350
540
590
480
535
11 kV supply
33 kV supply
Rs. 290 on
10% of
contract
demand or
actual
recorded
demand
during the
season
whichever is
higher
Rs. 320 on
10% of
contract
demand or
actual
recorded
demand
during the
season
whichever is
higher
During Off-Season
Rs. 320 on
10% of
contract
demand or
654 i.e.
actual
120% of
recorded
seasonal
demand
energy
during the
charge
season
whichever is
higher
Rs. 350 on
10% of
contract
demand or
642 i.e.
actual
120% of
recorded
seasonal
demand
energy
during the
charge
season
whichever is
higher
715 i.e.
120% of
seasonal
energy
charge
Not
applicable
Not
applicable
700 i.e.
120% of
seasonal
energy
charge
Not
applicable
Not
applicable
184
1.
2.
3.
4.
5.
6.
7.
8.
9.
Guaranteed Annual Minimum Consumption shall be 900 units (kWh) per kVA of contract
demand. The method of billing of minimum consumption shall be as given in General Terms
and Conditions of High Tension Tariff
Load Factor Incentive: The consumer shall be eligible for Load Factor incentive on energy
charges as per the scheme given in General Terms and Conditions of High Tension Tariff.
Time of Day Surcharge / Rebate: This surcharge/ rebate shall be as specified in General Terms and
The consumer has to declare months of season and off season for the tariff year 2016-17 within
60 days of issue of tariff order and inform the same to the licensee. If the consumer has
already informed the Licensee of his season/offseason months during this financial year prior to
issue of this order, same shall be accepted and shall be valid for this Tariff Order.
The seasonal period once declared by the consumer cannot be changed during the year.
This tariff schedule is not applicable to composite units having seasonal and other category loads.
The consumer will be required to restrict his monthly off season consumption to15% of highest
of the average monthly consumption of the preceding three seasons. In case this limit is exceeded
in any off season month, the consumer will be billed under HV-3.1 Industrial Schedule for the
whole tariff year.
The consumer will be required to restrict his maximum demand during off season to 30 % of the
contract demand. In case the maximum demand recorded in any month during the declared offseason exceeds this limit, the consumer will be billed under HV-3.1 Industrial Schedule for the
whole year.
Other terms and conditions shall be as per the General Terms and Conditions of High Tension
Tariff.
185
Tariff Schedule – HV - 5 – IRRIGATION, PUBLIC WATER WORKS AND OTHER THAN
AGRICULTURAL
Applicability:
The tariff categories HV 5.1 and HV 5.2 are proposed to be merged as HV 5.
The Tariff Category shall apply to supply of power to lift irrigation schemes, group
irrigation, Public Utility Water Supply schemes, sewage treatment plants /sewage pumping
plants and for energy used in lighting pump house.
The tariff category shall also apply to supply of power to other allied agriculture pump
connections i.e. the connection for hatcheries, fisheries ponds, poultry farms, cattle
breeding farms, grasslands, vegetables/ fruits/ floriculture/ mushroom growing units etc. and
dairy ( for those dairy units where only extraction of milk and its processing such as chilling,
pasteurization etc. is done). However, in units where milk is processed to produce other
end products of milk, billing shall be done under HV-3.1 (Industrial) category.
Note: Private water supply scheme, water supply schemes run by institutions for their
own use/employees/townships etc. will not fall in this category but billed under the
appropriate tariff category to which such institution belongs. In case water supply is
being used for two or more different purposes then the highest tariff shall be
applicable.
Tariff:
No.
Monthly Fixed Charge (Rs. KVA
of billing demand per month)
Sub-Category
Energy Charge (paise per unit)
Public Water Works, Group Irrigation and Lift Irrigation Schemes
Existing
Proposed
Existing
Proposed
11 kV supply
195
280
445
505
33 kV supply
215
300
420
485
132 kV supply
240
330
400
470
Other allied agricultural use
11 kV supply
210
33 kV supply
230
132 kV supply
250
455
Merged with
Public Water
Works
435
Merged with
Public Water
Works
420
186
(a) Guaranteed Annual Minimum Consumption shall be 720 units (kWh) per kVA of
contract demand. The method of billing of minimum consumption shall be as given in
(b) Time of Day Surcharge / Rebate: This surcharge/ rebate shall be as specified in
(c) Incentive for adopting Demand Side Management
An incentive equal to 5 % energy charges shall be given on installation and use of
energy saving devices (such as ISI energy efficient motors for pump sets).
Incentive will only be admissible if full bill is paid within due dates failing which all
consumed units will be charged at normal rates as the case may be. Such incentive
will be admissible from the month following the month in which energy saving devices
are put to use and its verification by a person authorized by the licensee. The
incentive will continue to be allowed till such time these energy saving devices
remain in service. The Distribution Licensee is required to arrange wide publicity for
above incentive. The Distribution Licensee is required to place quarterly information
regarding incentives provided on its web site.
(d) Other terms and conditions shall be per the General Terms and Conditions of High
Tension Tariff.
187
Tariff Schedule – HV – 6 BULK RESIDENTIAL USERS
Applicability:
The tariff category HV-6.1 is applicable for supply to industrial or any other township (e.g.
that of University or academic institutions, hospitals, MES and Border villages etc.) for
domestic purpose only such as lighting, fans, heating etc. provided that the connected load for
essential common facilities such as Non-domestic supply in residential area, street lighting
shall be within the limits specified hereunder:(i)
Water supply and Sewage pumping, Hospital - No limit
(ii)
Non-domestic/Commercial and other General purpose put together - 20 % of
total connected load.
The tariff category HV-6.2 is applicable for supply to Registered Cooperative Group
Housing Societies as per the Ministry of Power’s notification no. S.O.798 (E) dated 9th June,
2005 and also to other Registered Group Housing Societies and individual domestic user. The
Terms and Conditions to this category of consumers shall be applicable as per relevant
provisions of the Madhya Pradesh Electricity Supply Code, 2013 as amended from time to
time.
It is also proposed that this tariff category shall also be applicable to residents welfare
societies/associations and residential complexes/ apartments/ colonies/ townships where supply
is used for residential purposes such as lighting, fans, heating etc. provided that the connected
load for essential common facilities such as Non-domestic supply in residential area, street
lighting, lift, etc. shall be within the limit of 20% of the sanctioned contracted demand/
connected load.
Tariff:
S.
No.
Category
of
consumers
Monthly
Fixed
Charge
(Rs/KVA)
of Billing
demand
per month
Energy
Charge for
Consumption
up to 50%
load factor
(paise/unit)
Energy
Charge for
Consumption
in excess of
50% load
factor
(paise/unit)
Monthly
Fixed
Charge
(Rs/KVA)
of Billing
demand
per month
Existing
1
2
For Tariff Sub-Category 6.1
11 kV
230
supply
33 kV
250
supply
132 kV
265
supply
For Tariff Sub-Category 6.2
11 kV
155
supply
33 kV
160
supply
132 kV
165
supply
Energy
Charge for
Consumption
up to 50%
load factor
(paise/unit)
Energy
Charge for
Consumption
in excess of
50% load
factor
(paise/unit)
Proposed
505
455
280
600
550
480
430
300
570
520
460
415
320
550
505
505
460
190
600
555
495
450
200
585
540
480
430
210
570
520
188
(a)
Guaranteed Annual Minimum Consumption shall be 780 units (kWh) per kVA of
contract demand. The method of billing of minimum consumption shall be as given in
(b)
Load Factor Incentive: The consumer shall be eligible for Load Factor incentive on
energy charges as per the scheme given in General Terms and Conditions of High
Tension Tariff.
(c)
All individual end-users shall enter into a tripartite agreement with the
Management of the Group Housing Society and the licensee for availing supply of
electricity in the Society in order to get the benefit of the tariff under this
category. The individual end user shall not be levied a rate exceeding the tariff
applicable to the corresponding LT category.
(d)
The consumer/owner having single point connection for residential welfare
societies/associations and residential complexes/ apartments/ colonies/
townships shall not provide supply to the individual consumers at a rate which
is exceeding domestic tariff (LV 1.2) in case of LT connection, as determined
by the Commission.
(e)
Other terms and conditions shall be as specified under General Terms and
189
Tariff Schedule – HV – 7 SYNCHRONIZATION AND START UP POWER FOR
GENERATORS CONNECTED TO THE GRID
Applicability:
This Tariff shall apply to those generators who are already connected to the grid but who are
not consumers of the Distribution Licensee and seek to avail power for synchronization with
the grid or for start-up.
Tariff for all voltages:
S.
No.
Category of consumers
Generators for Startup power
or synchronization with Grid
Energy
(paise/unit)
Energy
(paise/unit)
Existing
Proposed
625
750
(a)
The supply for synchronization with the grid or for start-up power shall not
exceed 15% of the capacity of unit of highest rating in the Power Plant.
(b)
The condition for minimum consumption shall not be applicable to the generators
including CPP. Billing shall be done for energy recorded on each occasion of
availing supply.
(c)
The supply shall not be allowed to the CPP for production purpose for which they
may avail stand-by support under the relevant Regulations.
(d)
The synchronization with the grid or the start-up power shall only be made
available after commissioning of plant and in the event of outages for annual
planned maintenance, other maintenance, forced outages of generating units or
also in the event of separation of generator from grid.
(e)
The synchronization with the grid, power shall be provided for a maximum
period of 2 hours on each occasion. This time limit shall not be applicable to start
up activity
(f)
The generator including CPP shall execute an agreement with the Licensee for
meeting the requirement of synchronization with the grid or for start-up power
incorporating the above terms and conditions..
190
GENERAL TERMS AND CONDITIONS OF HIGH TENSION TARIFF
The following terms and conditions shall be applicable to all HT consumer categories subject to
specific terms and conditions for that category as mentioned in the tariff schedule of respective
category:
i.
The contract demand shall be expressed in whole number only.
ii.
Character of Service: The character of service shall be as per Madhya Pradesh Electricity
Supply Code, 2013 as amended from time to time.
iii.
Point of Supply:
a. The power will be supplied to the consumer ordinarily at a single point for the entire
premises.
b. In case of Railway Traction, the supply at each sub-station shall be separately
metered and charged.
c. In case of coal mines, the power will be supplied ordinarily at a single point for the
entire premises. The power may, however, be supplied, on the request of the
consumer, at more than one point subject to technical feasibility. In such cases,
metering and billing will be done for each point of supply separately.
iv.
Determination of Demand: The maximum demand of the supply in each month shall be
four times the largest number of kilovolt ampere hours delivered at the point of supply
during any continuous 15 minutes during the month as per sliding window principle of
measurement of demand.
vi.
Billing demand: The billing demand for the month shall be the actual maximum kVA
demand of the consumer during the month or 90% of the contract demand, whichever is
higher. The billing demand shall be rounded off to the nearest integer number i.e. the
fraction of 0.5 or above will be rounded off to next integer figure and the fraction of less
than 0.5 shall be ignored.
vii.
Tariff minimum consumption shall be billed as follows:
a. The consumer shall be billed for guaranteed annual minimum consumption (kWh)
based on number of units per kVA of contract demand specified for his category,
irrespective of whether any energy is consumed or not during the year.
b. The consumer shall be billed one twelfth of guaranteed annual minimum
consumption (kWh) specified for his category each month in case the actual
consumption is less than above mentioned minimum consumption.
c. During the month in which actual cumulative consumption equals or greater than the
annual minimum guaranteed consumption, no further billing of monthly minimum
consumption shall be done in subsequent months of the financial year.
191
d. Tariff minimum consumption shall be adjusted in the month in which cumulative
actual or billed monthly consumption exceeds cumulative monthly prorated
minimum annual guaranteed consumption. If actual cumulative consumption does
not get fully adjusted in that month, adjustment shall continue to be provided in
subsequent months of the financial year. The following example illustrates the
procedure for monthly billing of consumption where prorated monthly minimum
consumption is 100 kWh based on annual consumption of 1200 kWh.
Month
1
Actual cumulative
consumption
Cumulative minimum
consumption
Higher of 2
and 3
Already billed in
the year
To be billed in the
month = (4-5)
(kWh)
(kWh)
(kWh)
(kWh)
(kWh)
2
3
4
5
6
April
95
100
100
0
100
May
215
200
215
100
115
June
315
300
315
215
100
July
395
400
400
315
85
Aug
530
500
530
400
130
Sept
650
600
650
530
120
Oct
725
700
725
650
75
Nov
805
800
805
725
80
Dec
945
900
945
805
140
Jan
1045
1000
1045
945
100
Feb
1135
1100
1135
1045
90
March
1195
1200
1200
1135
65
vii.
Rounding off: All bills will be rounded off to the nearest rupee i.e. up to 49 paise shall be
ignored and 50 paise upwards shall be rounded off to next Rupee.
Incentive/ Rebate / penalties
viii.
Power Factor Incentive: Power factor incentive shall be payable as follows:
Power Factor
Above 95% and up to 96%
1.0 ( one percent)
2.0 ( two percent)
3.0 ( three percent)
Above 98 % up to 99%
Above 99 %
ix.
Percentage incentive payable on billed energy charges
5.0 (five percent)
7.0 (seven percent)
Load factor calculation
a. The load factor shall be calculated as per the following formula:
Monthly consumption X 100
192
Load factor (%) = ---------------------------------------------------------------No. of hours in the billing month X Demand X PF




Monthly consumption shall be units consumed in the month excluding those received
from sources other than Licensee
No of Hours in billing month shall exclude period of scheduled outages in hours.
Demand shall be maximum demand recorded or contract demand whichever is higher
Power factor shall be 0.9 or actual average monthly power factor whichever is higher
Note: The load factor (%) shall be rounded off to the nearest lower integer. In case
the consumer is getting power through open access, units set off from other sources,
the net energy (after deducting units set off from other sources, from the consumed
units) billed to consumer shall only be taken for the purpose of working out load
factor. The billing month shall be the period in number of days between the two
consecutive dates of meter readings taken for the purpose of billing to the consumer.
b. Load factor (LF) incentive shall be calculated as per the following scheme and
shall be given to those categories of consumers where it is specified:
LF Range
Incentive
Computation of % incentive
on energy charge (LF = x%)
LF <= 75%
No incentive
=0.00
LF > 75%
Incentive of 0.10 % for every 1%
increase in LF above 75% on the
energy charges for incremental
consumption above 75% load factor
=(x-75)*0.10
Example,

Consumer having 72% load factor would not be getting any incentive on energy charges

Consumer having 82% load factor will get incentive of [0.10 * (82-75) %] = 0.7% on
energy charges for incremental consumption above 75% load factor.
Note: For working out incremental consumption, consumption corresponding to 75 % load
factor shall be deducted from total consumption. The above load factor incentive shall apply
only to energy charges corresponding to such incremental consumption for which separate rates
have been specified.
x.
All HT consumers shall get a rebate of 50 paise per kWh in energy charges for incremental
load factor on monthly consumption as compared to corresponding month of the past year.
The calculation of energy units for the rebate shall be as follows:
Difference in load factor in percentage (L) = Lcy – Lpy
193
If L >0, Rebate = L x CDcy x NDM x 24 hours x Rs 0.50 per unit
Where Lcy is load factor of the current billing month
Lpy is the load factor of the corresponding month in the past year
CDcy is contract demand of the current billing month
NDM is the number of days in the billing month
L is difference of load factor in the corresponding billing month of past year
This rebate shall not be applicable if “L” is zero or negative
xi.
For advance payment made before commencement of consumption period for which bill is
prepared, an incentive of 1 % per month on the amount which remains with the licensee at
the end of calendar month (excluding security deposit) shall be credited to the account of the
consumer after adjusting any amount payable to the licensee.
xii.
All HT consumers who have no arrears shall be given rebate of Rs 100 per bill for online
payment of the energy bill in full.
xiii.
An incentive for prompt payment @0.25% of bill amount (excluding arrears, security
deposit, meter rent and Government levies viz. Electricity Duty and Cess) shall be given in
case the payment is made at least 7 days in advance of the due date of payment. The
consumers in arrears shall not be entitled for this incentive.
xiv.
Time of Day (ToD) Surcharge / Rebate: This scheme is applicable to the categories of
consumers where it is specified. This is applicable for different periods of the day i.e.
normal period, peak load and off-peak load period. The surcharge / rebate on energy charges
according to the period of consumption shall be as per following table:
S. No.
Peak / Off-peak Period
Surcharge / Rebate on energy charges on
energy consumed during the
corresponding period
1.
Evening peak load period (6PM to 10 PM)
0% surcharge
2.
Off peak load period (10 PM to 6 AM next day)
15% of Normal rate of Energy Charge as
Rebate
Note: Fixed charges shall always be billed at normal rates i.e. ToD Surcharge / Rebate shall
not be applied on Fixed Charges
xv.
Power Factor Penalty ( For consumers other than Railway Traction HV-1)
a. If the average monthly power factor of the consumer falls below 90 percent, the
consumer shall be levied a penalty @ 1% (one percent), for each one percent fall in
his average monthly power factor below 90 percent, on total amount of bill under the
head of “Energy Charges”.
b. If the average monthly power factor of the consumer falls below 85 percent, the
consumer shall be levied a penalty of 5% (five percent) plus @ 2% (two percent) for
194
each one percent fall in his average monthly power factor below 85 percent, on the
total amount of bill under the head of “Energy Charges”. This penalty shall be
subject to the condition that overall penalty on account of low power factor does not
exceed 35%.
c. Should the average monthly power factor fall below 70%, the Distribution Licensee
reserves the right to disconnect the consumer’s installation till steps are taken to
improve the same to the satisfaction of the Distribution Licensee. This is, however,
without prejudice to the levy of penalty charges for low power factor in the event of
supply not being disconnected.
d. For this purpose, the “average monthly power factor” is defined as the ratio
expressed in percentage of total kilowatthours to the total kilovoltampere hours
recorded during the billing month. This ratio (%) shall be rounded off to the nearest
integer figure and the fraction of 0.5 or above will be rounded to next higher integer
and the fraction of less than 0.5 shall be ignored.
e. Notwithstanding what has been stated above, if the average monthly power factor of
a new consumer is found to be less than 90% in any month during the first 6 (six)
months from the date of connection, the consumer shall be entitled to a maximum
period of six months to improve it to not less than 90% subject to following
conditions:
i. This period of six months shall be reckoned from the month following the
month in which the average power factor was found for the first time to be
less than 90%.
ii. In all cases, the consumer will be billed the penal charges for low power
factor, but in case the consumer maintains the average monthly power factor
in subsequent three months (thus in all four months) to not less than 90%, the
charges on account of low power factor billed during the said six months
period, shall be withdrawn and credited in next monthly bills.
iii. The facility, as mentioned herein, shall be available not more than once to
new consumer whose average monthly power factor is less than 90% in any
month during 6 months from the date of connection. Thereafter, the charges
on account of low average power factor, if found less than 90%, shall be
payable as applicable to any other consumer.
xvi.
Additional Charges for Excess Demand
a) The consumer shall at all times restrict their actual maximum demand within the
contract demand. In case the actual maximum demand in any month exceeds 105%
of the contract demand, the tariffs given in various schedules shall apply to the
extent of 105% of the contract demand only. The consumer shall be charged for
excess demand computed as difference of recorded maximum demand and 105% of
the contract demand on energy charges and fixed charges and while doing so, the
195
other terms and conditions of tariff, if any, shall also be applicable on the said
excess demand. The excess demand so computed, if any, in any month shall be
charged at the following rates from all consumers except Railway Traction.
b) Energy charges for excess demand: The consumer shall pay energy charges as
per the tariff for consumption corresponding to excess demand in case the
maximum demand recorded exceeds the contract demand.
c) Fixed charges for excess demand: These charges shall be billed as per following:
i. Fixed charges for Excess Demand when the recorded maximum demand
is up to 115% of the contract demand: Fixed charges for Excess Demand
over and above 105% of the contract demand shall be charged at 1.3 times
the normal fixed charges.
ii. Fixed charges for Excess Demand when the recorded maximum demand
exceeds 115% of contract demand: In addition to fixed charges in 1 above,
recorded demand over and above 15 % of the contract demand shall be
charged at 2 times the normal fixed charges.
Example for fixed charges billing for excess demand: If the contract demand
of a consumer is 100 kVA and the maximum demand recorded in the billing
month is 140 kVA, the consumer shall be billed towards fixed charges as
under:-1. Up to 105 kVA at normal tariff.
2. Above 105 kVA up to 115 kVA i.e. for 10 kVA at 1.3 times the
normal tariff.
3. Above 115 kVA up to 140 kVA i.e. for 25 kVA at 2 times the normal
tariff.
d) In case of Railway Traction the excess demand so computed as per above, if any,
in any month shall be charged at the following rates:
1. When the recorded maximum demand is up to 115% of contract
demand- Excess Demand over and above 105% of the contract
demand—at the rate of Rs. 385 per kVA
2. When the recorded maximum demand exceeds 115% of contract
demand: - In addition to fixed charges in (a) above, recorded demand
over and above 15 % of the contract demand shall be charged—at the
rate of Rs. 525 per kVA
While doing so, other provisions of electricity tariff (such as tariff minimum charge
etc.) will also be applicable on aforesaid excess demand.
e) The excess demand computed in any month will be charged along with the monthly
bill and shall be payable by the consumer.
196
f) The billing of excess demand at higher tariff is without prejudice to the Licensee’s
right to discontinue the supply in accordance with the provisions contained in the
Madhya Pradesh Electricity Supply Code, 2013.
xvii.
Delayed Payment Surcharge: Surcharge at the rate of 1.25 % per month or part thereof on
the amount outstanding (including arrears) 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 applicable after
supply to the consumer is permanently disconnected.
xviii.
Service Charge for Dishonoured Cheques: In case the cheque(s) presented by the
consumer are dishonoured, a service charge at the rate of Rs. 1000/- per cheque shall be
levied in addition to delayed payment surcharge as per rules. This is without prejudice to the
Distribution Licensee’s rights to take action in accordance with any other applicable law.
xix.
Temporary supply at HT: If any consumer requires supply for a temporary period, the
temporary supply shall be treated as a separate service and charged subject to the following
conditions:
a. Fixed Charges and Energy Charges shall be charged at 1.3 times the normal tariff.
The fixed charges shall be recovered for the number of days for which the
connection is availed during the month by prorating the monthly fixed charges.
Month shall be considered as the number of total days in that calendar month.
b. The consumer shall guarantee minimum consumption (kWh) as applicable to the
permanent consumers on pro-rata basis based on number of days as detailed below:
Minimum consumption
for additional supply
for temporary period
Annual minimum consumption as applicable to
permanent supply X No. of days of temporary
connection
No. of days in a year
=
c. The billing demand shall be the demand requisitioned by the consumer or the highest
monthly maximum demand during the period of supply commencing from the month
of connection ending with the billing month, whichever is higher. For example:
Month
Recorded Maximum Demand (kVA)
Billing Demand (kVA)
April
100
100
May
90
100
June
80
100
July
110
110
August
100
110
September
80
110
197
October
90
110
November
92
110
December
95
110
January
120
120
February
90
120
March
80
120
d. The consumer shall pay the estimated charges in advance, before serving the
Temporary Connection subject to replenishment from time to time and adjustment as
per final bill after disconnection. No interest shall be given on such advance
payment.
e. The consumer shall pay rental for the metering system.
f. Connection and Disconnection Charges shall also be paid.
g. In case of existing HT consumer, the temporary connection may be given through
existing permanent HT connection on following methodology of assessment:
i. Deemed contract demand (DCD) = CD for permanent connection +
sanctioned demand for temporary connection.
ii. Billing demand for the month shall be worked out in the following manner :
1. Fixed Charges shall be charged at 1.3 times the normal tariff.
2. Deemed contract demand (DCD) = CD for permanent connection +
sanctioned demand for temporary connection.
3. Billing demand and fixed charges for the month shall be worked out
in the following manner:
a) When recorded MD in the month is found to be less than deemed
CD for the month, fixed charges for the month shall be sum of
fixed charges at temporary tariff on 100% temporary sanctioned
demand + fixed charge at normal tariff on highest of a or b.
where a is Recorded MD minus temporary sanctioned demand
and b is 90% CD of permanent connection.
b) When recorded MD in the month is found to be equal to deemed
CD for the month, fixed charges for the month shall be sum of
fixed charges at normal tariff on 100% CD for permanent
connection + fixed charges at temporary tariff on 100% temporary
sanctioned demand.
c) When recorded MD in the month is found to be in excess of
deemed CD for the month, fixed charges for the month shall be sum
198
of fixed charges at normal tariff on 100% CD for permanent
connection + fixed charges at temporary tariff on 100% temporary
sanctioned demand + fixed charges on 100% excess demand over
and above deemed CD at 1.5 times of temporary tariff.
d) The fixed charges shall be recovered for the number of days for
which the connection is availed during the month by prorating the
monthly fixed charges. Month shall be considered as the number of
total days in that calendar month.
4. The consumption corresponding to Permanent connection i.e. (A)
during the month shall be billed in the following manner:
Contract demand (Permanent)
A =
--------------------------------------------------- X Total
consumption
Deemed contract demand
or actual demand whichever is higher
5. The consumption corresponding to temporary sanctioned demand
during the month i.e. (B) shall be billed at 1.3 times the normal
energy charges and shall be billed in the following manner:
Sanctioned demand for temporary connection
B =
--------------------------------------------------- X Total
consumption
Deemed contract demand
or actual demand recorded whichever is higher
6. Consumption during the month corresponding to excess demand i.e.
(C), if any, shall be calculated in the following manner:
C= total recorded consumption minus (consumption corresponding to
permanent connection i.e. A + consumption corresponding to
temporary sanctioned demand i.e. B)
7. The demand recorded in excess of deemed contract demand shall be
treated as Excess Demand. For billing purposes such Excess demand,
if any, in any month shall be treated as pertaining to temporary
connection load and shall be charged at 1.5 times the normal fixed
and one time energy charges of temporary connection. Additional
charges for excess demand recorded during the period of temporary
connection shall be calculated as given below :
Fixed charges for excess demand = fixed charges per kVA for temporary
connection * excess demand* 1.5 (one and half)
199
Energy charges for consumption corresponding to excess demand =
energy charges per unit for temporary connection * (consumption
corresponding to excess demand i.e. C)
h. Load factor incentive shall not be allowed on the consumption for temporary
connection.
i. Power factor incentives/penalties and the condition for Time of Day Surcharge/
rebate shall be applicable at the same rate as for permanent connection.
Other Terms and Conditions for permanent connections:
xx.
The existing 11 kV consumer with contract demand exceeding 300 kVA who want to
continue to avail supply at 11 kV at his request, shall be required to pay additional charge at
5 % on the total amount of Fixed Charges and, Energy Charges billed in the month.
xxi.
The existing 33 kV consumer with contract demand exceeding 10,000 kVA who want to
continue to avail supply at 33 kV at his request, shall be required to pay additional charge at
3% on the total amount of Fixed Charges and Energy Charges billed in the month.
xxii.
The existing 132 kV consumer with contract demand exceeding 50,000 kVA who want to
continue to avail supply at 132 kV at his request, shall be required to pay additional charge
at 2% on the total amount of Fixed Charges and Energy Charges billed in the month.
xxiii.
Metering Charges shall be billed as per schedule of Metering and Other Charges as
prescribed in MPERC (Recovery of Expenses and other Charges for providing Electric Line
or Plant used for the purpose of giving Supply), Regulations (Revision-I), 2009 as amended
from time to time. Part of a month will be reckoned as full month for purpose of billing.
xxiv.
The tariff does not include any tax or duty, etc. on electrical energy that may be payable at
any time in accordance with any law then in force. Such charges, if any, shall be payable by
the consumer in addition to the tariff charges.
xxv.
In case any dispute arises regarding interpretation of this tariff order and/or applicability of
this tariff, the decision of the Commission will be final and binding.
xxvi.
No changes in the tariff or the tariff structure including minimum charges for any category
of consumer are permitted except with prior written permission of the Commission. Any
order without such written permission of the Commission will be treated as null and void
and also shall be liable for action under relevant provisions of the Electricity Act, 2003.
xxvii.
In case a consumer, at his request, avails supply at a voltage higher than the standard supply
voltage as specified under relevant category, he shall be billed at the rates applicable for
actually availed supply voltage and no extra charges shall be levied on account of higher
voltage.
xxviii.
All consumers to whom fixed charges are applicable are required to pay fixed charges in
each month irrespective of whether any energy is consumed or not.
200
xxix.
All conditions prescribed herein shall be applicable notwithstanding if any contrary
provisions, exist in the agreement entered into by the consumer with the licensee.
201

aggregate revenue requirement and tariff petition for fy 2016-17

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