SOUTHERN POWER DISTRIBUTION COMPANY OF A.P
LIMITED
19-13-65/A, VidyutNilayam, Srinivasapuram, Tirupati
Aggregate Revenue Requirement and Retail supply business and
Retail Supply Tariffs for the FY 2016-17
18th January, 2016
APSPDCL
Page 0
Table of Contents
1
Introduction
2
1.1
1.2
Filings based on Multi-Year Tariff (MYT) Principles
Filing Contents
2
2
2
Analysis of expected performance for Current Year 2015-16 for Retail Supply
Business
4
2.1
2.2
2.3
Introduction
Operating Performance
Financial Performance
3
Power Purchase for Current Year H2 FY 15-16 and Ensuing Year FY 16-17 8
3.1
3.2
3.3
3.4
3.5
3.6
3.7
Basis of estimation of quantity and cost of Power Purchase
PP allocation:
Installed Capacity of Major Generating Stations
Basis of estimation of power availability for H2 FY 2015-16 and FY 2016-17
Power Purchase Cost
Energy Requirement
Summary of Power Purchase for Current Year H2 FY 15-16 and
Ensuing year FY 16-17
8
8
9
18
29
49
4
Losses
52
4.1
4.2
4.3
4.4
4.5
4.6
4.7
4.8
4.9
4.10
4.11
DISCOM losses
TRANSCO losses
Losses external to APTRANSCO system
APTransco Charges
PGCIL and ULDC Charges
SLDC Charges
Distribution Costs (Rs. in Crores)
Interest on Consumer Security Deposits
Supply Margin
Other Costs
Summary of ARR
52
52
52
53
53
54
55
55
56
56
57
5
Revenue Projections
58
5.1
5.2
5.3
Sales Forecast
Revenue from Current Tariffs
Detailed category wise Revenue computation
58
80
83
6
7
Performance Parameters
Retail Supply Business True-up for FY 2014-15 & FY 2015-16
93
103
7.1
7.2
Filing for True-up by the Distribution Licensee
True-up of Aggregate Revenue Requirements components
& Gap from Retail Business for FY 2014-15 & FY 2015-16
Prayer
Detailed Tariff Proposal for Retail Supply Business for FY 2016-17
Other Tariff Proposals
103
7.3
8
9
4
4
6
50
106
107
108
124
COS
RSF
APSPDCL
Page 1
Introduction
1.1 Filings based on Multi-Year Tariff (MYT) Principles
The Andhra Pradesh Electricity Regulatory Commission framed the “Terms and
Conditions for determination of Tariff for Wheeling and retail supply of electricity”
Regulation 4 of
2005 (“Regulation”), lays down the principles for determination of
Aggregate Revenue Requirement (ARR) for (a) Distribution Business and (b) Retail Supply
Business of the licensees. The ARR so determined for each of the businesses will form the
basis for fixation of charges for wheeling and for retail sale of electricity.
In the Regulation, the Commission has also laid down the procedures for filing under
multi-year tariff principles. The multi-year period is defined as the Control Period and the
first Control Period is defined as the three year period starting from financial year 2006-07
and continuing till the end of financial year 2008-09. The second control period was defined
as the five year period starting from FY 2009-10 to 2013-14. The current filing pertains to
the third Control Period (FY 2014-15 to FY 2018-19). The Commission has specified in Para
6.2 of the Regulation the following procedure for ARR filing for the distribution and retail
supply business:
“The ARR filing for the Distribution business shall be for the entire Control Period.
For the Retail Supply business the ARR filing will be on annual basis …...”.
The current filing follows the principles laid down under this Regulation for
determination of the ARR for the retail supply business for the year 2016-17, which is the
Third year of the Third Control Period.
1.2
Filing Contents
The filing is structured in the following way:
Section 2 provides analysis of expected performance for FY 2015-16 for Retail supply
Business comprising:
APSPDCL
Operating Performance
Financial Performance
Page 2
A brief analysis of the financial and operational performance of the licensee during FY
2014-15 and FY 2015-16 (with projections for second half of FY) are given.
Expenditure Projections
o Power Purchase Cost
 Power Purchase and Procurement Cost
o Transmission Charges
o PGCIL & ULDC Charges
o SLDC Charges
o Distribution Cost
o Interest on Consumer Security Deposits
o Supply Margin
o Other Costs
o Aggregate Revenue Requirement for Retail Supply Business
Revenue Projections
o
o
o
o
Sales Forecast
Revenue from Current Tariffs
Non-tariff Income at Current Charges
Revenue at Current Tariffs and Charges
Revenue Gap
o Revenue Deficit / Surplus at Current Tariff and Charges
o Proposals to handle the Deficit / Surplus
The sales forecast has been used to determine the revenue from tariff for retail sale of
electricity for the third year of the third control period and the energy input required for
meeting the demand. The power procurement plan is based on the availability of the
generation sources during FY 2016-17, cost of procurement (fixed, variable and others) and
the merit order dispatch of various sources to meet the demand expected during various
months.
Due to reorganization of the State of Andhra Pradesh, two districts i.e., Anantapur &
Kurnool districts were merged into APSPDCL w.e.f 02-06-2014. In this context, for FY
2013-14 and FY 2014-15 (during Apr & May,2014) all the figures / data considered are
actuals and pertains to six districts of APSPDCL (viz., Krishna, Guntur, Prakasam, SPSR
Nellore, Chittoor & Kadapa). And from June, 2014 to September, 2015 all the figures
considered are actuals and pertains to entire eight districts of APSPDCL including newly
added Anantapur & Kurnool districts. From October, 2015 onwards the estimated /
projected figures are considered for entire 8 districts of the licensee.
APSPDCL
Page 3
2 Analysis of expected performance for Current Year 2015-16 for
Retail Supply Business
2.1
Introduction
This chapter analyses the performance of the licensee during the Current Year as compared
to the previous year. Only the key operating and financial parameters have been considered
for this analysis.
2.2
Operating Performance
Energy Balance
2014-15
Particulars
2015-16
Actuals
MU
18354.75
8006.78
26361.53
Metered Sales
LT Agricultural Sales
Total Sales
EHT Sales
APERC Order
%
62.43%
27.24%
89.67%
3490.59
Discom Input (excl EHT sales)
25907.65
Distribution losses (exl EHT sales)
MU
22856.34
8020.16
30876.50
%
67.55%
23.70%
91.25%
4725.92
88.13%
29398.24
100.00%
29112.76
86.03%
28727.68
10.17%
33838.68
100.00%
10.33%
Loss Including EHT Sales %
MU
21091.83
8392.70
29484.53
%
64.87%
25.81%
90.69%
3783.85
11.72%
Discom Input (excl EHT losses)
Present Estimate
8.75%
88.36%
10.54%
32511.53
100.00%
9.31%
Distribution Loss:
Actual
Year
2009-10
2010-11
2011-12
2012-13
2013-14
2014-15
2015-16 (H1)
APSPDCL
Excl.
EHT
Incl.
EHT
14.03
13.37
12.53
11.87
11.84
11.72
11.58
12.98
12.21
11.29
10.71
10.68
10.33
9.10
No. of 11 KV
T&MHQ feeders
for which energy
audit done
823
853
866
966
1024
1348
1377
11 KV 2 MVAR
capacitor banks
added to the
system
122
136
193
35
75
7
Additional
33/11 KV substations
charged
90
13
67
128
208
75
7
Page 4
As seen from the above table, the actual losses for the FY 2014-15 are 10.33% and reduced
compared to previous year loss of 10.68%. However it is expected to reduce the losses
further with the implementation of the following measures.
 Strict implementation of Restriction and Control measures to ensure the assured
number of hours of supply to agricultural sector.
 Reduction of both technical and commercial losses by vigorously conducting 11 KV
feeder wise energy audits around 1377 Nos. feeders in the company.
 Erection of additional substations, DTRs, 11KV capacitor banks and bifurcation of
feeders, etc.,
 HVDS for agricultural sector
 Utilisation of latest technology in metering, billing etc.,
During the year 2011-12, only 866 Nos. 11 KV Town & MHQ feeders were considered for
energy audit where as during the year 2014-15, 1348 Nos. feeders are available in E-AUDIT
for which energy audit is done on regular basis at corporate office level.
75 Nos. additional 11 KV 2 MVAR capacitor banks proposed during the year 2014-15 and
completed.
For the year 2014-15, 75 Nos. additional 33/11 KV sub-stations were charged and for the
year 2015-16, 70 Nos. additional 33/11 KV sub-stations are proposed out of this 7 Nos. were
already charged to reduce over loaded 33 KV & 11 KV lines and to maintain good voltage
profiles at the consumers end.
Metered Sales
As can be seen from the table above, in 2014-15, the percentage of metered sales is 62.43 %
as aginst 62.00% during 2013-14.
APSPDCL
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The total load curtailment (due to Load relief) during FY 2014-15 is 716.26 MU. In 2015-16,
the metered sales are expected to increase by 2737.08 MU over 2014-15 levels, which is
2.44% increase.
Agricultural Sales
In the previous year 2014-15 the actual Agriculture Consumption is 8006.78 MU. In the
current year 2015-16 during the first half of the year, the agriculture consumption is
3713 MU and projection for the entire year is 8393 MU, which is 373 MU excess over the
approved agricultural sales (2.11%). The increase in the sales is mainly due to increase in
the no.of consumers.
2.3
Financial Performance
The following table provides an overview of APSPDCL’s financial performance for the
current year and compares it with the APERC orders:
Particulars
2015-16
APERC
Present Estimate
Total Expenditure (A)
654.10
836.12
21.05
26.91
Distribution Cost
2153.24
2,153.24
PGCIL Expenses
211.10
211.10
ULDC Expenses
9.71
9.71
12672.00
13,468.64
147.09
565.53
13.13
142.12
38.12
Total Revenue Requirement (C=A+B)
16446.95
16,899.09
Total Revenue Earned
Tariff Income
Non-tariff Income
Revenue from Trading
Surplus/ (Gap)
Subsidy
Net Regulatory Gap
14128.50
12,193.48
12,117.14
76.34
0.00
-4,705.61
Transmission Cost
SLDC Cost
Power purchase
Interest on CSD
Other Costs, if any
Add: Supply Margin (B)
APSPDCL
14128.50
0.00
2318.45
2318.45
0.00
13.13
2,318.45
-2,387.16
Page 6
Revenues from sale of electricity:
The net revenue (excl. NTI) for FY 2015-16 is expected to be Rs 12117.14 Crores.
For the key categories, the licensee has estimated the revenue as below:
2014-15
Category
Actuals
2015-16
APERC
Present
Target
estimate
HT
Industrial
Non-Industrial
Aviation
Irrigation &Agr.
Railway Traction
Colony Lightning
RESCO's
Temporary
HT Total
LT
Domestic
Non-Domestic
Industrial
Cottage Industries
Agricultural
Local Bodies
General Purpose
Temporary
LT Total
Grand Total (LT+HT)
4440.79
478.74
14.42
280.40
475.68
20.07
9.67
0.00
5719.77
7404.24
654.69
73.78
203.16
558.25
28.43
9.33
15.00
8946.88
5184.09
587.69
17.71
294.62
513.60
24.32
7.25
0.00
6629.27
2103.90
1183.26
835.79
12.51
67.56
257.97
52.05
14.69
4527.73
2393.41
1340.12
971.83
13.75
99.13
303.70
58.65
1.03
5181.62
2537.19
1465.43
1043.78
15.54
59.10
289.88
61.45
15.50
5487.86
10247.49
14128.50 12117.14
The actual revenue during FY 2014-15 is Rs. 10247.49 crores excluding non-tariff income.
The NTI during FY 2014-15 is Rs. 73.49 crores. During FY 2015-16, the estimated revenue
from sale of power (exclusive of Non-tariff income) is Rs. 12117.14 crores. The expected
NTI during FY 2015-16 is Rs. 76.34 crores. The estimated revenue from sale of power
(inclusive of Non-tariff income) is Rs. 12193.48 crores.
APSPDCL
Page 7
3
3.1
Power Purchase for Current Year H2 FY 15-16 and Ensuing Year FY 16-17
Basis of estimation of quantity and cost of Power Purchase
This section discusses the methodology and assumptions considered for estimating the
quantum and corresponding cost of power purchase of the Licensee for the second half of the
Financial Year ending March 31, 2016 and for the Financial Year ending March 31, 2017.
As per section 92 read with the Twelfth Schedule of the Andhra Pradesh
Reorganization Act, 2014 for bifurcation of united Andhra Pradesh (Central Act No. 6 of
2014, dated 01.03.2014), the districts of Anantapur and Kurnool which was within the
jurisdiction of the erstwhile Andhra Pradesh Central Power Distribution Company Ltd.
(APCPDCL, now Southern Power Distribution Company of Telangana Limited (TSSPDCL))
was reassigned to the Andhra Pradesh Southern Power Distribution Company Ltd.
(APSPDCL). The proportionate share of power was transferred from the allocated share of
the erstwhile APCPDCL to APSPDCL.
Before the bifurcation of united Andhra Pradesh, with the implementation of MultiBuyer Model (MBM) in the state from June 9, 2005, each of the four Discoms of united
Andhra Pradesh had been allocated a certain share of the generating stations contracted by
APTRANSCO. According to G.O.Ms. No.20 (dated 08.05.2014), based on the last 5 years’
average consumption of Anantapur and Kurnool districts, 17.45% of power earlier allocated
to the erstwhile APCPDCL has to be transferred to APSPDCL. Power allocation percentages
for Andhra Pradesh Discoms and Telangana Discoms have been modified accordingly.
Andhra Pradesh has been allocated a percentage of 46.11% of the erstwhile Andhra Pradesh
share. The revised power allocation percentages for the two Discoms of Andhra Pradesh
(APEPDCL and APSPDCL) are mentioned below.
3.2

PP allocation:
Energy availability for upcoming GENCO (APGENCO and TSGENCO) stations - KTPP
Stage II, DSTPP Stages I & II has been considered as per geographical location.

Power from GENCO (APGENCO and TSGENCO) hydel stations have been allocated
based on their geographical location.

Non-conventional Energy sources have been allocated to the DISCOMs based on their
geographical presence/location.
APSPDCL
Page 8

The two mini-power plants LVS and Srivathsa have been allocated to APEPDCL.

Entire energy available from Hinduja thermal power plant has been allocated to Andhra
Pradesh.

Allocation percentage for existing APGENCO thermal stations, CGS stations and Gas
IPPs is 46.11% of united AP share (based on the last 5 years’ average consumption of
Anantapur and Kurnool districts).

The allocation percentages (as on 02.06.2014 as per G.O. Ms. No. 20) for the two
Discoms of Andhra Pradesh (among all the 4 Discoms of erstwhile Andhra Pradesh) for
GENCO thermal stations and all the other sources(Excluding Bilateral Purchases) has
been doneas follows:

S. No.
Name of the Distribution Company
Allocation Percentage
1
APEPDCL
15.80 %
2
APSPDCL
30.31 %
The energy deficit in each Discom if any is then met through procurement through
bilateral sources

Month-wise surplus has been estimated based on the availability and requirement. A part
of this surplus is assumed to be sold through bilateral contracts and a part through open
market.
In the following paragraphs, the capacities and availabilities of all the generating sources
have been described. The actual energy availability in MU for each Discom has been
projected based on the above allocation principles.
3.3
Installed Capacity of Major Generating Stations
3.3.1
GENCO (ANDHRA PRADESH GENCO & TELENGANA STATE GENCO)
The table below shows the projected capacities of the Thermal and Hydel generating stations
of GENCO including the share in the interstate projects.
APSPDCL
Page 9
3.3.1.1 APGENCO
Energy allocation for existing APGENCO thermal stations has been considered as 46.11% of
united Andhra Pradesh share as per G.O. Ms. No. 20.while 100% has been considered from
Damodaram Sanjeevaiah TPP I & II. For APGENCO Hydel stations allocation is as per
geographical location (100%). Allocation for interstate hydel projects have been taken as per
G.O.Ms. No. 20.
Source
Projected erstwhile AP share Projected AP share (MW)
(MW)
THERMAL
Dr. NTTPS ( I, II, III)
Dr. NTTPS – IV
1,260
500
581
231
420
420
210
800
800
194
194
97
800
800
4,410
2,896
Machkund, Orissa (AP share 70%)
84
39
T.B. Station, Karnataka (AP share
58
27
State
80%) projects:
Donkarayi
Upper Sileru
Lower Sileru
Srisailam right bank PH
25
240
460
770
25
240
460
770
Nagarjuna Sagar right canal PH
PABM
Mini hydro
Nagarjuna Sagar Tail Pond
90
20
1
50
90
20
1
50
1,798
6,208
1,721
4,617
RTPP-I
RTPP-II
RTPP- III
Damodaram Sanjeevaiah TPP I
Damodaram Sanjeevaiah TPP II
TOTAL THERMAL
HYDEL
Interstate projects:
TOTAL HYDEL
TOTAL APGENCO
APSPDCL
Page 10
3.3.1.2 TSGENCO
Energy allocation for existing TSGENCO stations has been considered as 46.11% of united
Andhra Pradesh share as per G.O. Ms. No. 20. No availability considered from KTPP Stage
II. For TSGENCO hydel stations allocation is as per geographical location (0%).
Source
Projected erstwhile AP
Projected AP share
share (MW)
(MW)
Kothagudem-(A,B,C)
Kothagudem-D
Kothagudem-VI
720
500
500
332
231
231
Ramagundam-B
63
29
KTPP -I
500
THERMAL
TOTAL THERMAL
2,283
231
1,054
TOTAL TSGENCO
2,283
1,054
3.3.2
CENTRAL GENERATING STATIONS
AP Discoms have Power Purchase Agreements with Central Generating Stations to purchase
power from NTPC (SR), NTPC (SR) Stage-III, NTPC -Talcher-II, NTPC Simhadri-I &II,
Vallur (JV) Power Project, Tuticorin Thermal Power Plant (upcoming), Neyveli Lignite
Corporation Ltd (“NLC”), Madras Atomic Power Station (“MAPS”) and Kaiga Atomic
Power Station (“KAPS”). Allocation percentage for CGS stations has been considered as
46.11% of united AP share (based on the last 5 years’ average consumption of Anantapur
and Kurnool districts as per G.O.Ms. No. 20).
APSPDCL
Page 11
Name of the Station
Total
Projected erstwhile
Installed
AP share
Projected AP share
Capacity
MW
MW
% (of
MW
% (of Total
Total
Installed
Installed
Capacity)
Capacity)
NTPC-(SR) Ramagundam I &
2,100
679
32.32
313
14.91
500
170
33.92
78
15.68
NTPC-Talcher-II
2,000
400
20.01
184
9.22
NTPC Simhadri StageI
1,000
1,000
100.00
461
46.11
NTPC Simhadri StageII
1,000
460
46.01
212
21.21
NLC TS II Stage-I
630
116
18.33
53
8.49
NLC TS II Stage-II
840
204
24.33
94
11.20
NPC-MAPS
440
44
9.90
20
4.61
NPC-Kaiga 1 & 2
440
136
30.82
63
14.25
NPC-Kaiga 3 & 4
440
144
32.64
66
15.09
1,500
221
14.75
102
6.79
NLC-TNPL Tuticorin*
1,000
255
25.46
118
11.76
NTPC-Kudgi*
2,400
419
17.5
201
8.36
TOTAL CGS
14,290
3,829
II
NTPC-(SR) Stage –
Ramagundam- III
Vallur (JV) NTPC with
TANGEDCO
1,965
* 1000 MW (2x500 MW) Tuticorin Thermal Power Station, is a Joint Venture Company
formed between Neyveli Lignite Corporation Limited (NLC) and Tamil Nadu Electricity
Board (TNEB) with a equity ratio of 89 : 11 respectively. Minister of Power, Government of
India has allocated 254.6 MW as firm power to erstwhile Andhra Pradesh (117.40 MW for
residuary Andhra Pradesh). Accordingly, APDISCOMs have signed a Power Purchase
APSPDCL
Page 12
Agreement with NLC-Tamil Nadu Power Limited (A Joint Venture Company) on
30.11.2010. 1st Unit of 500 MW was pronounced COD on 18.6.2015 and Unit 2 on
29.8.2015.
** 2400 MW (3x800 MW) Thermal Power Project is being setting up by M/s. NTPC Ltd at
Kudgi, Karnataka. The then APDiscoms have signed a PPA with NTPC on 23.09.2010.
Power shall be allocated as per the Gadgil formula. However, the same is yet to allocate by
MoP, GoI. Tentatively, as per the Gadgil formula, the residuary A.P may get 8.36% power
i.e. 200.62 MW from the said Power Project. As informed by NTPC, the scheduled COD of
1st unit (800 MW) in September 2016 and the scheduled COD of 2nd (800 MW) in March
2017.
3.3.3
INDEPENDENT POWER PRODUCERS (IPPs)
The following IPPs are under commercial operation in the Andhra Pradesh:
a) 216.82 MW gas-based plant at Jegurupadu by GVK Industries (“GVK”); Up on the
expiry of PPA on 20.06.2015, APDISCOMs have issued Buyout notice to M/s GVK-I
and M/s GVK-I is scheduling entire power only to APDISCOMs w.e.f. 20.06.2015.
b) 208.31 MW gas-based plant at Kakinada by Spectrum Power Generation Ltd.,
c) 355 MW (ISO) gas-based plant at Vijayawada by Lanco Kondapalli Power Ltd (“Lanco
Kondapalli”); the present PPA gets expired by 01.01.2016 and the negotiations for
renewal of PPA is under progress.
d) 220 MW gas based plant at Samalkota, East Godavari District by M/s. Reliance Power
Ltd. (formerly M/s. BSES).
The Plant Load Factor (PLF) of above four IPPs has been considered at 40% for the second
half of FY 15-16 and FY16-17
Energy allocation for gas-based IPPs has been taken as 46.11% of united Andhra Pradesh
share as per G.O. Ms. No. 20. Projected erstwhile Andhra Pradesh share and residuary
Andhra Pradesh share are as mentioned below.
APSPDCL
Page 13
Source
Projected erstwhile AP share Projected AP share (MW)
(MW)
GVK
Spectrum
Lanco Kondapalli (Gas)
Reliance BSES
TOTAL GAS-BASED IPPs
216
96
164
101
577
216
208
355
220
999
GVK Extension (220 MW), GMR Vemagiri (370 MW), Gowthami (464 MW), and
Konaseema (444.08 MW) are the new IPPs which have been commissioned in XIth Five
Year Plan.
Project Name
Capacity
Installed
corresponding
Capacity
to 50% PLF
(MW)
(MW)
AP share
under e-bid
RLNG
scheme for
FY 201516(H2)
AP share
under e-bid
RLNG
scheme for
FY 2016-17
Remarks
46.11% as
GVK Extension
(IPP)
220.00
110
50.72
50.72
per
G.O.Ms.No
20
GMR Vemagiri
370.00
185
85.30
85.30
-do-
Gautami (IPP)
464.00
232
0
106.98
-do-
Konaseema (IPP)
444.08
222
102.38
102.38
-do-
LKPL (MPP)*
1108.00
554
277
277
---
GREL (MPP)**
768.00
384
384
384
----
(IPP)
* M/s LKPL offered 50 % of capacity under e-bid RLNG to AP during the period from
01.10.2015 to31.03.2016. It is assumed that M/s LKPL will offer 50 % of capacity under ebid RLNG to AP during the period from 01.04.2016 to 31.03.2017 also.
** M/s GREL offered 100 % of capacity under e-bid RLNG to AP during the period from
01.10.2015 to 31.03.2016. It is assumed that M/s GREL will offer 100 % of capacity under
e-bid RLNG to AP during the period from 01.04.2016 to 31.03.2017 also.
APSPDCL
Page 14
The Natural gas supplies from RIL KG D-6 fields to the aforesaid IPPs became zero from
01.03.2013 onwards hence there is no generation under long term PPA. The availability is
subject to natural gas supply from M/s RIL.
Energy availability has not been considered from these IPPs in the absence of RIL D-6 gas
supplies.
3.3.4
AP Gas Power Corporation Ltd (“APGPCL”): Joint Sector
APGPCL is a joint sector gas-based power project. The allocation of power from this
project is in proportion to the equity share capital of participating industries. The total
installed capacity of the project along with the DISCOMs share is as given below:
Source
Installed
Capacity (MW)
Stage I
Stage II
Total
100
172
272
3.3.5
Projected
erstwhile AP
Share (MW)
16
43
59
Erstwhile AP
Share (%)
Projected AP
Share (MW)
AP Share (%)
16%
25%
22%
7
20
27
7%
12%
10%
Non-Conventional Energy (NCE) Sources
The installed capacities of NCE projects in Andhra Pradesh projected for FY 2015-16
2nd half and FY 2016-17 are as given below. NCE based projects have been allocated to the
AP Discoms based on their geographical presence/location (NCE projects have signed PPAs
with Discoms where they are located. Hence the entire power is allocated to that Discom.)
APSPDCL
Page 15
Type of Project
Bio Mass Power Projects including Co-gen
Bagasse Cogeneration Projects.
Wind Power Projects
Mini Hydel Power Projects
Industrial Waste Based Power Projects
Municipal Waste Based Power Projects
NCL Energy Ltd. (TB Dam)
Solar Power Projects
Solar Parks
Total
3.3.6
Projected AP
Share (MW) FY 2015-16
143.75
105.20
914.25
48.50
21.66
6.14
16.5
135
0
1391
Projected AP
Share (MW) FY 2016-17
141
105.20
1414.25
62.50
21.66
6.14
16.5
635
250
2652.25
Mini-Power Plants
APTRANSCO had entered into a Power Purchase Agreement with LVS (36.8 MW)
on 3rd January, 2009 for purchase of power in compliance with the Orders issued by Hon’ble
Supreme Court and had entered into another Power Purchase Agreement with Srivathsa
(17.20 MW)powerplant. These projects have been allocated completely to APEPDCL.
3.3.7
HNPCL
GoAP directed the then APDiscoms as the successor entities of erstwhile APSEB to
enter into a continuation agreement to the PPA dated 15.04.1998 which was entered by
erstwhile APSEB with HNPCL. As such, a memorandum of agreement (MoA) was entered
between the then APDiscoms and HNPCL on 17.05.2013. As per the directions of GoAP and
MoA dated 17.05.2013, the preparation of amendments to the PPA dated 15.04.1998 is under
finalization and it would be signed, shortly, by two DISCOMs of residuary A.P. 1st unit (520
MW) was synchronized on 06.12.2015 and the 2nd unit (520 MW) may be synchronized in
June 2016. As per the projections in ARR for FY 2015-16 filed by APDiscoms and the same
was approved by APERC in its Retail Tariff Order for FY 2015-16, the entire energy
available from HNPCL Thermal Power Plant has been considered for Andhra Pradesh.
APSPDCL
Page 16
3.3.8
Long Term andMedium Term Purchases
3.3.8.1 LongTerm – Thermal PowerTech Corporation India Limited
APDiscoms and Telangana Discoms have signed a Power Purchase Agreement with
M/s. Thermal PowerTech Corporation India Limited (TPCIL) for a contracted capacity of
500 MW under long term basis through Case-I bidding route for a period of 25 years.
APDiscoms have been allocated a share of 46.11% (as per G.O. Ms. No. 20) i.e. 231 MW out
of the total contracted capacity of 500 MW. Variable cost per unit of Rs.1.76/kWh and fixed
cost of Rs. 289.30 Crs have been considered for FY 2015-16. Variable Cost of Rs.1.81/kWh
and fixed cost of Rs.302.82 Crs have been considered for FY 16-17. As per the PPA, the
scheduled date of delivery for supply of 500 MW to APDiscoms and Telangana Discoms is
01.04.2017. However, TPCIL has requested for preponement of schedule delivery date from
01.04.2017 to 01.04.2015 since early commission of their units (2x660 MW) and the same is
under consideration by AP Discoms.
3.3.8.2 Long Term – 1000MW DBFOO Bidding
AP DISCOMS are planning to procure electricity of 1000MW on long term basis
from Power Stations on BDFOO basis and the bidding process is under progress. The energy
from these sources is considered from June 2016 at an energy availability of 90% PLF.
3.3.8.3 Medium Term – KSK Mahanadi
In the recently concluded medium term bidding for 3 years i.e. up to 15th June 2016,
the AP & Telangana Discoms have signed the Power Purchase Agreement with KSK
Mahanadi for 400 MW and are availing power since 14.08.2013. APDiscoms have been
allocated a share of 46.11% (as per G.O. Ms. No. 20) i.e. 184 MW out of the total contracted
capacity of 400 MW.
AP DISCOMS have signed the Power Purchase Agreement with KSK Mahanadi for
400MW for 100% of its share from 15th June 2016 to March 31st 2017. APERC has
APSPDCL
Page 17
accorded approval for the plan under Agreement with M/s KSK Mahanadi vide O.P. No.03
of 2015 on 19.08.2015.
The licensees had also signed a PPA with Corporate Power for 150 MW, but the
energy would not be available from the source due to non-allocation of transmission capacity
by PGCIL.
3.3.9
Short Term and Bilateral/ Inter-State purchases
3.3.9.1 Bilateral Purchases
The licenseehas placed order of an average of 800MW to procure short term power
from June 2015 to May 2016 to bridge the power deficit.
3.4
Basis of estimation of power availability for H2 FY 2015-16 and FY 2016-17
3.4.1
3.4.1.1
GENCO (ANDHRA PRADESH GENCO & TELENGANA STATE GENCO)
Thermal Energy:
The Energy availability for H2 of FY 2015-16 has been projected based on the actual
performance of the plants up to September 2015 and projected performance estimated by
GENCO from October 2015 to March 2016. For FY 2016-17, the energy availability has
been projected based on the projected performance estimated by GENCO and maintenance
schedules of the plants.
The following GENCO plants have been commissioned/ assumed to be commissioned in FY
2015-16 and FY 2016-17:
1. The COD of Damodaram Sanjeevaiah Thermal power plant unit I (APGENCO,
800 MW) was declared on 05.02.2015.
2. The COD of Damodaram Sanjeevaiah Thermal power plant unit II (APGENCO,
800 MW) is was declared on 24.08.2015.
3. KTPP Stage-II (TSGENCO, 600 MW) is expected to be commissioned in
December 2015
APSPDCL
Page 18
GENCO Thermal (Net Energy Availability- MUs)
S. No.
Station Name
H2 FY 2015-16
FY 20156-167
APGENCO
1
Dr NTTPS-I,II,III
1857.64
3709.03
2
Dr NTTPS-IV
658.97
1494.52
3
RTPP-I
617.52
1235.04
4
RTPP-II
617.52
1235.04
5
RTPP-III
308.76
617.52
2614.48
5242.66
2614.48
5242.66
Total APGENCO
9289.38
18776.45
1
KTPS-(A,B,C)
1024.37
2084.55
2
KTPS-D
735.14
1470.28
3
KTPS-VI
747.26
1494.52
4
RTS-B
91.89
183.79
5
KTPP-I
739.30
1494.52
Total TSGENCO
3337.97
6727.65
Total
12627.35
25504.11
6
7
Damodaram Sanjeevaiah
Thermal Station-I
Damodaram Sanjeevaiah
Thermal Station-II
TSGENCO
3.4.1.2 Hydro Energy:
The hydro energy availability for H2 FY 2015-16 is expected to be 942.37MU and
3241.44 MU for FY 2016-17. Energy allocation for hydel stations is based on geographical
location and therefore, energy availability from TS GENCO stations has not been considered.
It has been observed over the past few years that the actual availability from hydel
stations has been consistently lower than the value approved in the Tariff Orders issued by
APERC. The table below shows the actual hydro energy availability from FY 2002-03 to FY
APSPDCL
Page 19
2014-15 (for erstwhile AP). In this regard, the hydel projections have been considered to be
similar to the 10 year average availability.
Year
2002-03
Approved hydro
energy availability
in MU (As per
Tariff Orders)1
6,999
Actual hydro
energy
availability in
MU1
3,337
Variation between
Approved
and
Actual
hydro
energy availability
(%)
-52%
2003-04
6,757
2,959
-56%
2004-05
6,423
5,267
-18%
2005-06
5,979
7,873
32%
2006-07
7,586
9,328
23%
2007-08
8,592
9,566
11%
2008-09
9,046
7,729
-15%
2009-10
8,969
5,499
-39%
2010-11
7,662
6,751
-12%
2011-12
8238
6221
-24%
2012-13
6407
3171
-50%
2013-14
7057
6761
-36.55
The following table shows the station-wise projected availability for H2 FY 2015-16 and FY 2016-17:
APGENCO Hydel ( Net Energy Availability-MUs)
H2 FY 2015-
S. No.
Station Name
1
MACHKUND PH AP Share
65.19
153.89
2
TUNGBHADRA PH AP Share
37.80
66.39
3
USL
207.90
445.38
4
LSR
501.93
1103.60
5
DONKARAYI
30.71
98.30
6
SSLM (Right Bank)
72.29
1045.25
16
FY 2016-17
1
For erstwhile AP
APSPDCL
Page 20
APGENCO Hydel ( Net Energy Availability-MUs)
S. No.
Station Name
7
NSRCPH
8
PABM
9
Mini hydro(Chettipeta)
10
16
FY 2016-17
12.59
146.76
2.20
5.98
1.78
2.62
9.98
173.25
942.37
3241.44
Nagarjuna sagar tail pond dam
PH
Total
3.4.2
H2 FY 2015-
CENTRAL GENERATION STATIONS
The energy availability for H2 of FY 2015-16 has been projected based on the actual
performance upto August/September 2015 for CGS. For FY 16-17, the energy availability
has been projected based on the projected performance estimated by CGS and maintenance
schedules of the plants and also based on the details of energy availabilities received from
respective generators.
The Vallur Thermal Power Plant which is under generation (present capacity of 1,000
MW) has a total installed capacity of 1,500 MW. In this project, erstwhile AP had a share of
14.75%. The COD of the second unit of Vallur Power Project was 25.08.2013.
Capacity addition from Tuticorin Thermal Power Plant Station is 118 MW (as per AP
share).COD for unit 1 has been considered to be in February2015 and for unit 2 to be in
March 2015.
The Kudgi Thermal Power Plant has a total installed capacity of 2,400 MW. In this
project, the residuary A.P is likely to get a share of 8.36% i.e. 200.62 MW. Now, the Project
is in advanced stage of construction. The anticipated COD of first unit of Kudgi Power
Project will achieve in September 2016 and second unit in March 2017.
APSPDCL
Page 21
Energy availability projections from CGS for H2 FY 2015-16 and FY 2016-17 are
tabulated below:
Central Generating Stations ( Net Energy Availability - MUs )
S. No.
Station Name
H2 FY 2015-16
FY 2016-17
1
NTPC-(SR) Ramagundam I & II
1130
2228
2
NTPC-(SR) Stage – Ramagundam- III
293
521
3
NTPC-Talcher-II
705
1361
4
NTPC- Simhadri Stage-I
1487
3129
5
NTPC- Simhadri Stage –II (Unit 3 &4)
692
1336
5
NLC TS II Stage-I
120
297
6
NLC TS II Stage-II
269
503
7
NPC-MAPS
55
120
8
NPC-Kaiga 1 & 2
193
403
9
NPC-Kaiga 3 & 4
202
392
11
Bundled Power under JVNSM
182
354
10
Vallur (JV) NTPC with TANGEDCO
277
526
11
Tuticorin Thermal Power Plant
166
961
12
NTPC - Kudigi
0
306
5707
12436
TOTAL
3.4.3
APGPCL
The projections for APGPCL – I and APGPCL – II are as shown below. The actuals
till September, 2015 have been factored while estimating energy availability for H2 FY
2015-16.40% PLF has been assumed for these plants for FY 2016-17
APGPCL Allocated Capacity (Energy Availability- MUs )
S. No.
APSPDCL
Station Name
H2 FY 2015-16
FY 2016-17
1
APGPCL I - Allocated capacity
14
31.66
2
APGPCL II - Allocated capacity
46.81
84.84
Total
60.81
116.50
Page 22
3.4.4
IPPS
The availability of power from the generating stations of GVK, Spectrum, Lanco Kondapalli
and Reliance (BSES) have been projected based on the current gas supply levels. Actual
energy availability till September, 2015 has been factored while estimating energy
availability for H2 FY 2015-16. For FY 2016-17 40% PLF has been assumed. The PPA
subsisting with M/s GVK Phase-I was expired on 20.06.2015. APDISCOMs have issued
Buyout notice and M/s GVK-I is scheduling entire power only to APDISCOMs w.e.f.
20.06.2015. There is no share for TSDISCOMs up on expiry of PPA in respect of M/s GVK.
The PPA subsisting with M/s SPGL is going to expire by 18.04.2016. The APDISCOMs
would opt for either Renewal of PPA or Buyout of the project as per the terms of PPA. M/s
LANCO PPA gets completed by 01.1.2016, but the projections are furnished expecting that
the PPA gets renewed.
Old IPPs (Energy Availability-MU)
S. No.
Station Name
H2 FY 2015-16
FY 2016-17
1
GVK
367.19
727.27
2
Spectrum
349.04
711.67
3
Lanco Kondapalli (Gas)
494.42
1263.95
4
Reliance BSES
179.70
350.90
Total
1390.34
3053.79
Energy availability form the New IPPs viz; GVK EXtn, GMR Vemagiri, Gautami&
Konaseema and Merchant Power Plants viz., GREL, LKPL is considered to be zero.
S.No
APSPDCL
New IPPs
FY 15 H2 (MU)
FY 16-17
(MU)
1
GVK Extension Project
0
0
2
Vemagiri Power Generation Ltd
0
0
3
Gautami Power Ltd
0
0
4
Konaseema EPS Oakwell Power Ltd.
0
0
5
Lanco Kondapalli Power Ltd.
0
0
6
GMR Rajahmundry Energy Ltd.
0
0
Page 23
3.4.5
Non-Conventional Energy (NCE) Sources
Wind:
1. For the existing Projects, the newly commissioned & to be commissioned wind
projects energy is anticipated based on the threshold PLF of 23.5% considered in
APERC Regulation 1 of 2015.
2. Monthly generation is assumed in proportion to the actual monthly generation values
of FY14-15
3. Capacity in MWs indicated for the FY: 2015-16 (H2) is actual installed capacity
commissioned under Power Purchase Agreements (Preferential & REC mechanism).
4. Capacity in MWs indicated for the FY: 16 -17 is actual installed capacity
commissioned under Power Purchase Agreements upto 15-16 plus
anticipated
capacity of 500MW of the proposed 1016.4 MW by NREDCAP .
5. Tariff for the upcoming wind projects is assumed @ Rs.4.83/unit as per APERC
orders dt: 01.08.2015. Further, Income Tax/MAT and ED are pass through and same
are to be paid by DISCOMs to the developers over and above the tariff.
Solar:
1. For the existing projects the newly commissioned & to be commissioned solar
projects energy is anticipated based on the threshold PLF of 19%.
2. Capacity in MWs indicated for the FY: 2015-16 (H2) is actual installed capacity
commissioned under Power Purchase Agreements and anticipated capacity considered
based on the target time lines envisaged in the Power Purchase agreements entered by
the solar developers with DISCOMs.
3. Monthly generation for FY 16-17 is assumed in proportion to the actual monthly
generation values of FY14-15
4. Capacity in MWs indicated for the FY: 16 -17 is anticipated capacity considered
based on the target time lines envisaged in the Power Purchase agreements entered by
the solar developers with DISCOMs.
APSPDCL
Page 24
5. Tariff for solar projects taken as per the PPA and the same was adopted by APERC.
6. GoAP issued the G.O. Ms No. 46, dated:27.11.2012 for purchasing Solar power of
1000MW through competitive bidding route. Accordingly AP Discoms had initiated
the bidding process for procurement of 1000 MW of solar power during 2012-13 and
PPA’s were entered with solar power developers for a capacity of 33 MW at the tariff
of Rs. 6.49/kWh for 20 years. Out of the PPA capacity of 33 MW,8 MW was
commissioned so far.
7. Further, GoAP issued the G.O Ms. No.8, dated: 12.02.2015 and directed
APDISCOMs for procurement of 1000 MW Solar Power through competitive bidding
process .
Accordingly bidding process conducted by APPCC/APSPDCL for
procurement of 500 MW solar power in phase-1, the minimum first year tariff
obtained was Rs. 5.25/unit and the cut-off first year tariff considered was
Rs.5.999/unit. This tariff will be escalated at the rate of 3% per year till 10th year and
the 10th year tariff will be continued for the remaining 15 years. The corresponding
minimum levelised tariff is Rs. 6.17/unit and maximum Rs. 7.05/unit. and
APDISCOMs entered PPAs for a capacity of 619 MW with consent of APERC. Out
of 619 MW, 15MW has been commissioned; 500MW of the balance capacity is
expected to be commissioned by March 31, 2016.
8. Further, GoAP also targeted to set up 3500 MW solar capacity through Solar Parks in
Kurnool and Anantapur districts with the support of Govt. of India. As a part of this,
GoAP has entered MoU with NTPC on 16.09.2014 for setting up of 1000MW solar
park in Anantapur dist. Subsequently as per the directions of GoAP, APDISCOMs
had entered PPAs with M/s NTPC for purchase of solar power from the proposed 250
MW (Phase-1) solar park at NP kunta, Anantapur Dist on 24.04.2015 and the 250
MW (Phase-1) will be commissioned by April-2016.
APSPDCL
Page 25
Mini Hydel:
1. For the existing Projects anticipated energy for the FY 2015-16 (H2) & FY: 2016-17
has been arrived based on the PLFs for the actual energy supplied for the FY 201415 & FY 2015-16 (H1).
2. For upcoming Minihydel projects energy is anticipated @ 32% PLF.
3. Capacity in MWs indicated for the FY: 2015-16 (H2) and FY: 2016-17 is actual
installed capacity commissioned under Power Purchase Agreements and anticipated
capacity as per the information given by the NREDCAP.
4. Tariff for the upcoming projects is assumed as Rs. 4/unit since the APERC yet to
determine the tariff for new MiniHydel projects.
5. Presently, Minihydel developers are being paid APERC tariff which is exclusive of Electricity
Duty, Royalty charges and MAT/Income Tax. As and when claimed by the developers, the same
needs to be reimbursed.
Biomass, Bagasse, Industrial Waste & Municipal Solid Waste:
1. For the all existing Projects anticipated energy for the FY 2015-16 (H2) & FY: 201617
has been arrived based on the PLFs for the actual energy supplied for the FY
2014-15 & FY 2015-16 (H1).
2. Capacity in MWs indicated for the FY: 2015-16 (H2) and FY: 2016-17 is actual
installed capacity commissioned under Power Purchase Agreements.
3. Upcoming projects in these categories are nil.
4. Presently, the Biomass, Bagasse, Industrial Waste & Municipal Solid Waste
developers are being paid APERC tariff which is exclusive of Electricity Duty and
MAT/Income Tax. As and when claimed by the developers, the same needs to be
reimbursed.
Energy availability projections for H2 FY 2015-16 and FY 2016-17 from various NCE
sources is as summarized in the following table:
APSPDCL
Page 26
Non-Conventional Energy Sources ( Net Energy Availability - MUs )
S. No.
Station Name
H2 FY 2015-16
FY 2016-17
1
Bio Mass Power Projects including Co-gen
162.86
320.20
2
Bagasse Cogeneration Projects.
86.56
98.54
3
Wind Power Projects
548.19
2911.38
4
Mini Hydel Power Projects
56.02
113.45
5
Industrial Waste Based Power Projects
17.16
32.96
6
Municipal Waste Based Power Projects
0.18
0.36
7
NCL Energy Ltd.
16.43
24.84
8
Solar Power Projects
147.61
1046.91
9
Solar Parks
0
416.10
1035.00
4964.74
Total
3.4.6
Mini Power Plants
The energy availability projections for FY 2015-16 H2 and FY 16-17 have been
projected as declared by the station at PLF 0% for Srivathsa for FY 15 H2 and at PLF 25%
for FY 16-17. The energy for LVS for FY 15 H2 and FY 16-17 would not be dispatched
owing to high variable cost.
Mini-Power Plants Allocated to EPDCL (Energy Availability-MUs)
3.4.7
S, No.
Station Name
FY 15 H2
FY 16-17
1
Srivathsa
0
38.14
2
LVS
0
0
Total
0.00
38.14
Hinduja National Power Corporation Limited
Energy availability of 606.12 MU and 6,082.77 MU has been considered from
Hinduja power plant for H2 of FY 2015-16 and FY 2016-17 respectively considering 80%
PLF. As per the projections in ARR for FY 2015-16 filed by APDiscoms and the same was
approved by APERC in its Retail Tariff Order for FY 2015-16, the entire energy available
from HNPCL Thermal Power Plant has been considered for Andhra Pradesh.
APSPDCL
Page 27
3.4.8
Long Term and Medium Term Purchases
LongTerm – Thermal PowerTech Corporation India Limited
The licensees (AP & Telangana Discoms) have signed a Power Purchase Agreement with
M/s. Thermal PowerTech Corporation India Limited (TPCIL) for a contracted capacity of
500 MW under long term basis through Case-I bidding route for a period of 25 years. In case
licensees accepts the revised schedule date of delivery as requested by TPCIL, the supply of
said power will commence from 01.04.2015 and the energy availability projected from this
plant for AndhraPradesh is 1,716 MU for FY 2016-17, which has been considered.
Long Term – 1000MW DBFOO Bidding
Energy availability has been considered from June 2016 at 90% PLF (ex-bus). The energy
availability projected from 1000MW DBFOO bidding is 6,566 MU for FY 2016-17.
Medium Term – KSK Mahanadi
AP and Telangana Discoms have signed PPA’s with KSK Mahanadi and Corporate
Power for supply of power through medium term basis starting from June 2013 for a period
of 3 years. But, the energy from Corporate Power has not been considered as the PGCIL has
not granted its transmission access.80% PLF (599.44 MU for H2 FY 2015-16 and 2,295.64
MU for FY 2016-17) has been considered from KSK Mahanadi.
3.4.9
Short Term and Bilateral/ Inter-State purchases
Bilateral Purchases
Energy availability considered from bilateral sources for FY 2015-16 is 3,406 MUs at a PLF of
85% and 821.81 MUs at a PLF of 85% for FY16-17 in the month of April and May 2016.
3.4.10 Summary
A summary of the source wise current estimate of energy available for H2 FY 2015-16 and FY
2016-17 is presented below.
APSPDCL
Page 28
Energy Availability (MU)
Generating Station
H2 FY 2015-16
FY 2016-17
12627.35
25504.11
942.37
3241.44
5707.51
12436.63
60.81
116.50
IPPS
1390.34
3053.79
NCEs
1035.00
4964.74
0.00
38.14
HNPCL
606.12
6,082.77
Long Term & Medium Term
1484.03
10,578.73
Short Term & Bilateral Purchases
3,406
821.81
Total
27,323
66,839
Genco (APGenco & TSGenco)Thermal
Genco (APGenco & TSGenco)Hydel
CGS
APGPCL
Mini Power Plants
3.5
Power Purchase Cost
3.5.1
GENCO (Andhra Pradesh GENCO &Telengana State GENCO)
The annual fixed costs for all APGENCO stations for FY 2015-16 have been
considered as approved by APERC in its order dated 31.05.2014 in OP No.15/2009 filed by
APGENCO for determination of tariff for FY 2009-14 which includes the year 2013-14. The
fixed cost for FY 2014-15 was admitted as per approved tariff order for FY 2013-14 and
subsequently, truing up of fixed cost for FY 2014-15 was done as per orders of APERC dt
31.05.2014 in OP No.15/2009.The fixed costs have been considered as per the projections of
APGENCO for FY 2016-17.
APSPDCL
Page 29
The total fixed costs for all the GENCO thermal and hydel stations2 including both
existing and new stations is Rs. 2,571.34 Crs for H2 of FY 2015- 16 and Rs. 5,704.87 Crs for
FY 2016-17. The fixed costs for GENCO Thermal and Hydel stations have been tabulated
below:
Station
Fixed Costs for FY
Fixed Costs for FY
2015-16 H2 (Rs. Cr.)
2016-17 (Rs. Cr.)
VTPS I
45.01
91.71
VTPS II
45.01
91.71
VTPS III
45.01
91.71
VTPS IV
146.86
295.62
RTPP I
68.38
138.86
RTPP Stage-II
138.87
279.51
RTPP Stage-III
91.36
183.61
582.30
1484.45
power station -II
582.30
1484.45
APGENCO Thermal Total
1745.11
4141.63
KTPS A
49.57
68.00
KTPS B
49.57
68.00
KTPS C
49.57
68.00
KTPS D
79.12
127.50
KTPS Stage VI
170.86
363.55
APGENCO-Thermal
Damodaram Sanjeevaiah Thermal
power station -I
Damodaram Sanjeevaiah Thermal
TSGENCO-Thermal
2
The fixed costs for TSGENCO stations have not been mentioned because energy availability from only APGENCO hydel
stations have been considered (allocation based on geographical location).
APSPDCL
Page 30
Station
Fixed Costs for FY
Fixed Costs for FY
2015-16 H2 (Rs. Cr.)
2016-17 (Rs. Cr.)
RTS B
18.26
24.44
Kakatiya Thermal Power Plant Stage I
176.19
364.87
TSGENCO Thermal Total
593.14
1084.36
Total Thermal
2338.25
5225.99
MACHKUND PH AP Share
4.65
9.30
TUNGBHADRA PH AP Share
3.19
6.38
USL
28.25
57.40
LSR
54.15
110.02
DONKARAYI
2.95
5.98
103.52
209.56
NSRCPH
9.76
19.67
PABM
5.73
11.60
Mini hydro
0.35
0.72
Nagarjuna sagar tail pond dam PH
20.54
48.26
Total Hydro
233.09
478.88
TOTAL GENCO
2571.34
5704.87
APGENCO –Hydel
SSLM
For existing GENCO thermal stations, the actual variable cost (including FCA) for
H1 of FY 2015-16 has been considered for H2 of 2015-16. For projecting FY 2016-17
variable cost for APGENCO stations, an escalation of 3% is taken on actual H1 FY 2015-16
variable cost per unit, whereas an escalation of 3% has been considered even for TSGENCO
stations. For Damodaram Sanjeevaiah Thermal power station unit I variable cost per unit for
H2 FY 2015-16 has been estimated to be Rs. 2.52/unit considering that 30% imported coal,
30% MCL washed coal and 40% domestic coal to be used. Rs. 2.20/unit for FY16-17
variable cost has been assumed as the units will be running at 85%PLFfor FY 2016-17.Same
variable cost per unit has been considered for Damodaram Sanjeevaiah Thermal power
station unit II for FY 2016-17
APSPDCL
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It has been observed over the past few years that usage of imported coal has become
necessary to bridge fuel shortfall, leading to a steady increase in the variable cost over the
past few years. The station-wise variable rates that have been projected for APGENCO
thermal plants & TSGENCO thermal Plants for H2 FY 2015-16 H2 and for FY 2016-17are
as follows:
Station
Variable rate (Rs./kWh)
Variable rate (Rs./kWh)
H2 FY 2015-16
FY 2016-17
VTPS (I, II, III)
3.30
3.34
VTPS-IV
3.21
3.3
RTPP-I
3.76
3.87
RTPP-II
3.76
3.87
RTPP-III
3.76
3.87
APGENCO Stations
Damodaram
SanjeeviahTPS-I
Damodaram
SanjeeviahTPS-II
2.52
2.52
2.20
2.20
TSGENCO Stations
KTPS (A, B, C)
1.64
1.69
KTPS- D
1.50
1.55
KTPS-VI
2.74
2.82
RTS- B
3.01
3.10
KTPP-I
2.42
2.50
The incentives for GENCO thermal stations are calculated based on APERC
Regulation No 1 of 2008, at a flat rate of 25 paisa/kWh for ex-bus scheduled energy
corresponding to scheduled generation in excess of ex-bus energy corresponding to target
Plant Load Factor.
APSPDCL
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3.5.2
CGS:
NTPC (SR) (2100 MW)
CERC had notified the terms & conditions of tariff regulations for the control period
FY 2014-19 i.e., for a period of 5 years and the regulations, 2014 waspublished by CERC by
end of February 2014.
CERC had modified the terms & conditions for determination of
fixed charges as well as energy charges to the ensuing control period for inter-state
generating stations. CERC provided the revised regulations stating that beneficiaries would
pay the fixed charges for FY 2016-17 and energy charges to the Inter-State Generating
stations based on the approved charges for FY 2013-14 and energy charges norms as per the
regulations, 2009 till the finalization of orders for the respective inter-state generating station
ie, NTPC & NLC, JV. Due to non-availability of orders of CERC, the fixed charges were
considered based on the CERC approved charges for FY 2013-14. The incentives payable
had been considered as 50 paise per unit based on the actual PLF above threshold level of
85% as per the prevailing regulations of CERC, 2014. In the orders of CERC for FY 201314, the income tax was grossed up in ROE component as per the regulations, 2009 and
hence, the fixed charges determined for H2 FY 2015-16 and FY 2016-17 are inclusive of
income tax. Based on the availability projections, the fixed charges along with payable
incentives are computed for H2 FY 2015-16 and FY 2016-17 for Ramagundam I & II. AP
has a share of 14.91% from Ramagundam I & II. Variable cost per unit for H2 FY 2015-16
has been considered same as actual per unit variable cost as H1 FY 2015-16. FY 2016-17
per unit variable cost has been projected by considering 3% escalation on the VC of H1 FY
2015-16.
The recoverable PLF of fixed charges are 83% only based on the availability of
generating station subject to any coal shortages occur, as per new regulations, 2014. Due to
non-finalization of fixed charges in every year of the control period FY 2014-19, the
prevailing fixed charges for FY 2013-14 had been recovered by NTPC by considering 83%
PLF on availability. NTPC had submitted the tariff petition of Ramagundam I & II as per
Regulations, 2014 before Hon’ble CERC for determination of fixed charges to the control
period 2014-19.
APSPDCL
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NTPC (SR) STAGE-III (500 MW)
CERC had notified the terms & conditions of tariff regulations for the control period
FY 2014-19 i.e., for a period of 5 years and the regulations, 2014 was published by CERC by
end of February 2014.
CERC had modified the terms & conditions for determination of
fixed charges as well as energy charges to the ensuing control period for inter-state
generating stations. CERC provided the revised regulations stating that beneficiaries would
pay the fixed charges for FY 2016-17 and energy charges to the inter-state generating
stations based on the approved charges for FY 2013-14 and energy charges norms as per the
regulations, 2009 till the finalization of orders for the respective inter-state generating
stations ie, NTPC & NLC, JV. Due to non-availability of orders of CERC, the fixed charges
were considered based on the CERC approved charges for FY 2013-14. The incentives
payable had been considered as 50 paise per unit based on the actual PLF above threshold
level of 85% as per the prevailing regulations of CERC, 2014. In the orders of CERC for FY
2013-14, the income tax was grossed up in ROE component as per the regulations, 2009 and
hence, the fixed charges determined for H2 FY 2015-16 and FY 2016-17 are inclusive of
income tax. Based on the availability projections, the fixed charges along with payable
incentives are computed for H2 FY 2015-16 and FY 2016-17 in case of Ramagundam III.
AP has a share of 15.68% from Ramagundam III. Variable cost per unit for H2 FY 2015-16
has been considered same as actual per unit variable cost as H1 FY 2015-16. FY 2016-17
per unit variable cost has been projected by considering 3% escalation on the VC of H1 FY
2015-16. The recoverable PLF of fixed charges are 83% only based on availability of
generating station subject to any coal shortages occur, as per new regulations, 2014. Due to
non-finalization of fixed charges in every year to the control period 2014-19, the prevailing
fixed charges for FY 13-14 had been recovered by NTPC by considering 83% PLF on
availability. NTPC had submitted the tariff petition of Ramagundam III as per Regulations,
2014 before Hon’ble CERC for determination of fixed charges to the control period 2014-19.
NTPC-TALCHER -II (2000 MW)
CERC had notified the terms & conditions of tariff regulations for the control period
FY 2014-19 i.e., for a period of 5 years and the regulations, 2014 was published by CERC
APSPDCL
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by end of February 2014. CERC had modified the terms & conditions for determination of
fixed charges as well as energy charges for the ensuing control period for inter-state
generating stations. CERC provided the revised regulations stating that beneficiaries would
pay the fixed charges for FY 2016-17 and energy charges to the inter-state generating
stations based on the approved charges for FY 2013-14 and energy charges as per the
regulations, 2009 till the finalization of orders for the respective inter-state generating station
ie, NTPC & NLC, JV. Due to non-availability of orders of CERC, the fixed charges were
considered based on the CERC approved charges for FY 2013-14. The incentives payable
had been considered as 50 paise per unit based on the actual PLF above threshold level of
85% as per the prevailing regulations of CERC, 2014. In the orders of CERC for FY 201314, the income tax was grossed up in ROE component as per the regulations, 2009 and
hence, the fixed charges determined for H2 FY 2015-16 and FY 2016-17 are inclusive of
income tax. Based on the availability projections, the fixed charges along with payable
incentives are computed for H2 FY 2015-16 and FY 2016-17 for Talcher-II. AP has a share
of 9.22% from Talcher-II. Variable cost per unit for H2 FY 2015-16 has been considered
same as actual per unit variable cost as H1 FY 2015-16. FY 2016-17 per unit variable cost
has been projected by considering 3% escalation on the VC of H1 FY 2015-16. The
recoverable PLF of fixed charges are 83% only based on availability of generating station
subject to any coal shortages occur, as per new regulations, 2014. Due to non-finalization of
fixed charges in every year of the control period FY 2014-19, the prevailing fixed charges for
FY 2013-14 had been recovered by NTPC by considering 83% PLF on availability. NTPC
had submitted the tariff petition of Talcher II as per Regulations, 2014 before Hon’ble CERC
for determination of fixed charges to the control period 2014-19.
NTPC SIMHADRI STAGE-I (1000 MW)
CERC had notified the terms & conditions of tariff regulations for the control period
FY 2014-19 i.e., for a period of 5 years and the regulations, 2014 waspublished by CERC by
end of February 2014.
CERC had modified the terms & conditions for determination of
fixed charges as well as energy charges to the ensuing control period for inter-state
generating stations. CERC provided the revised regulations stating that beneficiaries would
APSPDCL
Page 35
pay the fixed charges for FY 2016-17 and energy charges to the inter-state generating
stations based on the approved charges for FY 2013-14 and energy charges norms as per the
regulations, 2009 till the finalization of orders for the respective inter-state generating station
ie, NTPC & NLC, JV. Due to non-availability of orders of CERC, the fixed charges were
considered based on the CERC approved charges for FY 2013-14. The incentives payable
had been considered as 50 paise per unit based on the actual PLF above threshold level of
85% as per the prevailing regulations of CERC, 2014. In the orders of CERC for FY 201314, the income tax was grossed up in ROE component as per the regulations, 2009 and
hence, the fixed charges determined for H2 FY 2015-16 and FY 2016-17 are inclusive of
income tax. Based on the availability projections, the fixed charges along with payable
incentives are computed for H2 FY 2015-16 and FY 2016-17 in case of Simhadri Stage-I.
AP has a share of 46.11% from Simhadri Stage-I. Variable cost per unit for H2 FY 2015-16
has been considered same as actual per unit variable cost as H1 FY 2015-16. FY 2016-17
per unit variable cost has been projected by considering 3% escalation on the VC of H1 FY
2015-16. The recoverable PLF of fixed charges are 83% only based on availability of
generating station subject to any coal shortages occur, as per new regulations, 2014. Due to
non-finalization of fixed charges in every year of the control period FY 2014-19, the
prevailing fixed charges for FY 2013-14 had been recovered by NTPC by considering 83%
PLF on availability. NTPC had submitted the tariff petition of Simhadri Stage I as per
Regulations, 2014 before Hon’ble CERC for determination of fixed charges to the control
period 2014-19.
NTPC- SIMHADRI II (1000 MW)
CERC had notified the terms & conditions of tariff regulations for the control period
FY 2014-19 i.e., for a period of 5 years and the regulations, 2014 was published by CERC
by end of February 2014. CERC had modified the terms & conditions for determination of
fixed charges as well as energy charges for the ensuing control period for inter-state
generating stations. CERC provided the revised regulations stating that beneficiaries would
pay the fixed charges for FY 2016-17 and energy charges to the inter-state generating
stations based on the approved charges for FY 2013-14 and energy charges as per the
APSPDCL
Page 36
regulations, 2009 till the finalization of orders for the respective inter-state generating station
ie, NTPC & NLC, JV. Due to non-availability of orders of CERC, the fixed charges were
considered based on the CERC approved charges for FY 2013-14. The incentives payable
had been considered as 50 paise per unit based on the actual PLF above threshold level of
85% as per the prevailing regulations of CERC, 2014. In the orders of CERC for FY 201314, the income tax was grossed up in ROE component as per the regulations, 2009 and
hence, the fixed charges determined for H2 FY 2015-16 and FY 2016-17 are inclusive of
income tax. Based on the availability projections, the fixed charges along with payable
incentives are computed for H2 FY 2015-16 and FY 2016-17 in case of Simhadri Stage-II.
AP has a share of 21.11% from Simhadri Stage-II. Variable cost per unit for H2 FY 2015-16
has been considered same as actual per unit variable cost as H1 FY 2015-16. FY 2016-17
per unit variable cost has been projected by considering 3% escalation on the VC of H1 FY
2015-16. The recoverable PLF of fixed charges are 83% only based on availability of
generating station subject to any coal shortages occur, as per new regulations, 2014. Due to
non-finalization of fixed charges in every year of the control period FY 2014-19, the
prevailing fixed charges for FY 2013-14 had been recovered by NTPC by considering 83%
PLF on availability.
NLC Stage –I (630 MW)
For the APDISCOMs share of 8.49 % of 630 MW, the payable fixed charges and
lignite cost for the Control Period of FY 2009-14 was determined by CERC in its final orders
of NLC TPS-II (Stage-I). The lignite costs for the Control Period of FY 2014-19 is yet to be
determined by Ministry of Coal, GOI. Variable cost per unit for H2 FY 2015-16 has been
considered same as actual per unit variable cost as H1 FY 2015-16.
FY 2016-17 per unit
variable cost has been projected by considering 3% escalation on the VC of H1 FY 2015-16.
NLC Stage –II (840 MW)
For the APDISCOMs share of 11.20 % of 840 MW, the payable fixed charges and
lignite cost for the Control Period of FY 2009-14 was determined by CERC in its final orders
of NLC TPS-II. (Stage-II). The lignite cost for the Control Period FY 2014-19 is yet to be
determined by Ministry of Coal, GOI. Variable cost per unit for H2 FY 2015-16 has been
APSPDCL
Page 37
considered same as actual per unit variable cost as H1 FY 2015-16.
FY 2016-17 per unit
variable cost has been projected by considering 3% escalation on the VC of H1 FY 2015-16.
KAIGA ATOMIC POWER STATION 1 & 2 (440 MW) and 3 & 4 (440MW):
The AP share from Kaiga 1 & 2 is 14.25% and from Kaiga 3 &4 is 15.09%. The tariff
for Kaiga 1&2 and Kaiga 3&4 for H2 FY 2015-16 has been considered same as the tariff in
H1 FY 2015-16. FY 2016-17 per unit variable cost has been projected by considering 3%
escalation on the VC of H1 FY 2015-16.
Vallur Thermal JV Power Project (NTPC & TANGEDCO):
Ministry of Power, GOI had allocated firm share of 11.87% from total capacity of 1500 MW
to erstwhile AP and 12.25% was considered for erstwhile AP inclusive unallocated power.
Presently, Units 1, 2 & 3 are under generation and 93 MW is being availed by AP Discoms
from this power project. NTECL had made filings before CERC for determination of tariff
for the control period 2014-19 for this JV Project and provisional orders were yet to be
issued by CERC for payment of fixed charges. The fixed charges for H2 FY 2015-16 and
FY 2016-17 are computed based on the 85% of AFC (for units 1,2&3) as approved by
CEO(NTECL) pending tariff order from Hon'ble CERC for FY 2014-15 for Vallur power
project. Variable cost per unit for H2 FY 2015-16 has been considered same as actual per
unit variable cost as H1 FY 2015-16. FY 2016-17 per unit variable cost has been projected
by considering 3% escalation on the VC of H1 FY 2015-16.The incentives payable have
been factored into the fixed charges. In the orders of CERC, the income tax was grossed up
in ROE component as per the regulations, 2009 and hence, the fixed charges determined for
H2 FY 2015-16 and FY 2016-17 are inclusive of income tax. As per the Central Electricity
Regulatory Commission (Terms and Conditions of Tariff) Regulations, 2009, incentives are
also part of fixed charges which are to be computed every month based on the formulae provided
in the Regulations. Based on the availability projections, the fixed charges along with payable incentives
are considered for H2 FY 2015-16 and FY 2016-17.
NLC-TNPL Tuticorin
A joint venture power project of NLC and TNEB had implemented at Tuticorin with an
installed capacity of 1000MWs. Both the units were declared the COD and presently, AP is
APSPDCL
Page 38
availing 132 MWs from this power project. M/s.NTPL had filed the tariff petition before
Hon’ble CERC for determination of fixed charges to the control period 2014-19. Based on
these filings, CERC had issued the provisional orders. The fixed charges are computed
based on the availability projections duly considering the 30% PLF for
H2 FY 15-16 and
with 100% PLF for FY 16-17, as submitted by NTPL. Variable cost per unit for H2 FY
2015-16 has been considered same as actual per unit variable cost as H1 FY 2015-16. FY
2016-17 per unit variable cost has been projected by considering 3% escalation on the VC of
H1 FY 2015-16. The payable incentives were computed by considering the regulations,
2014 i.e., 50 paise per unit above the threshold PLF of 85%.
NTPC-Kudgi
As informed by NTPC, the estimated total cost per unit is Rs. 4.20 (Fixed Cost of Rs. 2.31
and Variable Cost of Rs. 1.89) during the first year. A petition will be filed before Hon’ble
CERC for determination of tariff based on the capital cost before synchronization of the first
unit i.e. in March 2016. For the period between the achievement of CoD and determination
of tariff by CERC, the Company will raise bills based on the provisional tariff and
reconciliation will be done after finalization of tariff by CERC.
3.5.3
APGPCL
The power purchase cost incurred by APDISCOMs for procurement from APGPCL for H2
FY 2015-16 and FY 2016-17 are as per the projections given by APGPCL.
The calculations were done on the basis of availability of 0.65 MSCMD of Natural Gas with
the usage of part load i.e., about 172MW (out of 272 MW). As a result, about 100 MW was
kept as idle for want of Natural Gas. Consequently, the fixed cost has gone up steeply.
Cost components for H2 FY 2015-16 and FY 2016-17
Particulars
H2 FY 2015-16
FY 2016-17
Fixed cost (Rs. Crs.)
0.69
0.98
Variable cost (Rs. / kWh)
2.78
2.87
Stage-I
APSPDCL
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Cost components for H2 FY 2015-16 and FY 2016-17
Stage –II
Fixed cost (Rs. Crs.)
1.60
Variable cost (Rs. / kWh)
2.79
3.04
2.87
During FY 2014-15, Natural Gas dollar rate had been drastically increased from USD 59.00
to USD 62.00 Fixed cost also increased due to non-supply of natural gas due to gas pipe line
blast at Nagaram Village, East Godavari Dist on 27.06.2014. APGPCL plants were totally
closed for about Four and Half months.
Proposed gas cost is USD 3.82 per MMBTU which is effective from October 2015.
S. No
Particulars
H2 FY 2015-2016
FY 2016-2017
1
Gas Availability in SCMD
6,50,000
6,50,000
2
Gas Rate - per MMBTU
3.82 USD
3.82 USD
3
Exchange Dollar Rate [$]
65
65
4
Variable Cost Unit Rate : Rs.
Stage-I
2.78
2.87
Stage-II
2.79
2.87
As plants are running with part load, the gas consumption i.e. SFC (Specific Fuel
Consumption) is also more which is contributing to increase in the variable cost and fixed
cost.
3.5.4
IPPs
GVK JEGURUPADU POWER PROJECT
The fixed cost is fully recoverable at 68.50 % PLF. The variable charge of H2 FY 15-16 is
considered same as APERC approved FY 15-16 value of Rs 2.62/ kWh and 3% escalation on
APERC approved FY15-16 value has been considered for FY 2016-17.
The capital cost of this plant is Rs. 816 Crs. The estimated fixed cost for Andhra Pradesh is
Rs. 68.84 Crs per annum for FY 2015-16 (H2) and Rs.123.87 Crs (estimated) for FY 2016APSPDCL
Page 40
17 (.The PPA subsisting with M/s.GVK was expired on 20.06.2015. APDISCOMs had
issued Buyout notice and M/s.GVK is scheduling entire power only to APDISCOMs w.e.f.
20.06.2015. There is no share for TSDISCOMs upon expiry of PPA in respect of M/s.GVK).
The fixed cost includes foreign exchange variations payable by APDISCOMs to the
generator as per the provisions of Power Purchase Agreement. The actual fixed cost as
settled by the licensee may be different from the estimates as presented above on account of
the monthly Foreign Exchange Rate Variation (FERV). The licensee submits to the Hon’ble
Commission to allow the licensee to subsequently claim the change in fixed cost on account
of FERV.
Deemed / Notional generation claims will be payable to the generator up to 85 % PLF as per
the incentive formulae provided in the PPA.
Computation of incentive has been carried out based on the formula provided in the PPA. As
there is gas deficit the expected PLF for H2 FY 2015-16 and for FY 2016-17 is 40%. Hence
incentive may not be applicable for H2 FY 2014-15 and FY 2015-16.
Incentive payment
= Equity x (PLF - 68.50) x 0.00525;
Equity
= Rs. 244.80 Crs;
Projected incentive for H2 FY 2015-16 is Rs. 0.00 Crs and for FY 2016-17 is Rs. 0.00 Crs
(as there is deficit of gas).
SPECTRUM
The fixed cost is fully recoverable at 68.50 % PLF. The variable charge of H2 FY 15-16 is
considered same as APERC approved FY 15-16 value of Rs 2.76/ kWh and 3% escalation on
APERC approved FY15-16 value has been considered for FY 2016-17.
The estimated fixed cost for Andhra Pradesh is Rs. 63.12 Crs per annum for FY 2015-16 and
Rs.5.60 Crs for FY 2016-17 (In respect of M/s.SPGL power is sharing by AP & TS
DISCOMs as per G.O.Ms.No.20 Dt.08.05.2014 but Projections are made considering full
capacity of the plant (not AP share). Further, the PPA subsiding with M/s.SPGL is going to
APSPDCL
Page 41
expire by 18.04.2016. The APDISCOMs yet to decide for choosing the options either
Renewal of PPA or Buyout of the project. Hence the projections are shown only up to
18.04.2016). The fixed cost is inclusive of foreign exchange variations payable by
APDISCOMs to the generator as per the provisions of Power Purchase Agreement.
The actual fixed cost as settled by the licensee may be different from the estimates as
presented above on account of the monthly Foreign Exchange Rate Variation (FERV). The
licensee submits to the Hon’ble Commission to allow the licensee to subsequently claim the
change in fixed cost on account of FERV.
Deemed / Notional generation claims will be payable to the generator up to 85% PLF as per
the incentive formulae provided in the PPA.
Computation of incentive has been carried out based on the formula provided in the PPA. As
there is gas deficit the expected PLF for H2 FY 2015-16 and for FY 2016-17 is 40% (The
projections are taken only up to 18.04.2016). Hence incentive may not be applicable for H2
FY 2014-15 and FY 2015-16.
Incentive payment
= Equity x (PLF - 68.50) x 0.004 (if PLF > 68.50 < 80.50);
Incentive payment
= Equity x (PLF - 68.50) x 0.005 (if PLF > 80.50 < 85.50);
Incentive payment
= Equity x (PLF - 68.50) x 0.006 (if PLF > 85.50);
Equity (considered provisionally) = Rs. 117.92 Crs;
Projected incentive for H2 FY 2015-16 is Rs. 0.00 Crs and for FY 2016-17 is Rs. 0.00 Crs
(as there is deficit of gas).
LANCO KONDAPALLI
The fixed charges are fully recoverable at 80% PLF. The variable charge of H2 FY 15-16 is
considered same as APERC approved FY 15-16 value of Rs 2.28/ kWh and 3% escalation on
APERC approved FY15-16 value has been considered for FY 2016-17.
APSPDCL
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Estimated fixed costs for Andhra Pradesh for FY 2015-16 upto 01.01.2016 is Rs.43.62 Cr.
The subsisting PPA with LANCO expires by 01.01.2016.
As per the existing PPA of Lanco Kondapalli with APDiscoms, the FDSC component of the
fixed charge will not be payable by APDiscoms after completion of 12 years from the date of
commencement of supply of power. This 12 year duration was completed by December
2012. Hence, no FDSC component are payable.
In case the plant achieves a PLF (I) greater than 80% for a tariff year, then the Board shall
pay to the generator incentive (as a percentage of the other fixed charges) for any additional
unit generated beyond the actual generation in excess of a PLF (I) of 80%. The incentive
structure is as shown below:
PLF (I) %
Incentive (%)
Up to 80 %
Nil
Above 80 % and up to 85 %
2 % for every 1 % increase in PLF(I) (i.e. for a PLF(I) of 85 %,
the incentive will be 10 % of the Other Fixed Charge)
Above 85 % and up to 90 %
3 % for every 1 % increase in PLF(I) (i.e. for a PLF(I) of 90 %,
the Incentive will be 10 % + 15 % = 25 % of the Other Fixed
Charge)
Above 90 %
Same as for 90% i.e. 25% of the Other Fixed Charge.
Projected incentive for H2 FY 2014-15 is Rs. 0.00 Crs and for FY 2015-16 is Rs. 0.00 Crs.
RELIANCE INFRASTRUCTURE LTD. (BSES)
The fixed charge is fully recoverable at 85 % PLF. The variable charge of H2 FY 15-16 is
considered same as APERC approved FY 15-16 value of Rs 2.93/ kWh and 3% escalation on
APERC approved FY15-16 value has been considered for FY 2016-17.
Based on the formula provided in the PPA and considering 46.11% of the fixed cost for
erstwhile Andhra Pradesh (as per G.O. Ms. No. 20), the fixed costs for Andhra Pradesh for
FY 2015-16 and FY 2016-17 are Rs. 3.41 Crs and Rs. 6.82 Crs respectively. Since payment
of FDSC component got over by December 2013 and only OFC is payable, fixed charges are
APSPDCL
Page 43
being paid as per the actual PLF achieved during the month as there is no alternate fuel
facility.
In case the plant achieves a PLF (I) greater than 85% for a tariff year, then the incentive (as a
percentage of the other fixed charges) payable for any additional unit of actual generation in
excess of a PLF (I) of 85 %. The incentive structure is as shown below:
PLF (I) %
Incentive (%)
Up to 85 %
Nil
Above 85 % and up to 90 %
2 % for every 1 % increase in PLF(I) (i.e. for a PLF(I) of 90 %,
the Incentive will be 10 % of the Other Fixed Charge
Above 90 %
Same as for 90% i.e. 10 % of the Other Fixed Charge.
Projected incentive for H2 FY 2015-16 is Rs. 0.00 Crs and for FY 2016-17 is Rs. 0.00 Crs.
The licensee shall not bear the tax on incentives payable to the generator.
New IPPs & Merchant Plants
No fixed and variable charges are considered from the new IPP plants.
3.5.5
NON CONVENTIONAL ENERGY (NCE) SOURCES:
The Commission issued orders on 20.03.2004, fixing power purchase price applicable for
NCE Projects (Biomass/Industrial Waste, Bagasse & Mini Hydel) from 01.04.2004 to
31.03.2009. The NCE Project Developers filed cases before the Appellate Tribunal against
the APERC orders. The Appellate tribunal set aside APERC Orders dated. 20.03.2004.
APTRANSCO and APDISCOMs filed Appeals before Supreme Court against ATE Orders.
The Hon’ble Supreme Court passed Orders dated. 08.07.2010 setting aside ATE Orders. The
Supreme Court remanded the matter to APERC with a direction to hear NCE Project
developers afresh and determine /fix tariff/power purchase price. APERC has initiated the
public hearing in this matter from 28.09.2010 and passed three divergent orders vide its order
dt:12.09.2011. The APERC orders are challenged before Appellate Tribunal for Electricity
by NCE developers & APDISCOMs.
APSPDCL
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The Appellate Tribunal in its order dt:20.12.2012, while fixing the parameters, directed
APERC to fix the tariff accordingly to be payable to Non-conventional Energy Developers
for the period 2004-2009. Aggrieved by the APTEL order dt:20.12.2012, APDISCOMs filed
Civil Appeals Nos 1376-1385 of 2013 before Hon’ble Supreme Court. The apex court
admitted the appeals and are pending for disposal.
The APDISCOMs filed an application I.A. No.22 of 2013 in O.P. No.1075 of 2000 praying
the APERC to defer the hearing of the remand proceedings on NCE tariff cases as ordered by
the Appellate Tribunal for Electricity in order dt:20.12.2012 till the final disposal of civil
appeals (1376 to 1385) filed before Hon’ble Supreme Court. The APERC dismissed the I.A.
No.22 of 2013 with the opinion that DISCOMs cannot ask for deferment of the tariff order to
give effect to the APTEL order on the plea that the petition has been filed before Hon’ble
Supreme Court and the same is admitted for hearing. The APERC issued order
dt:22.06.2013, pursuant to APTEL order dt:20.12.2012, determining the tariff payable to
NCE developers for the period 01.04.2004 to 31.03.2009. The DISCOMs filed Special Leave
Petition in the Hon'ble Supreme Court against the order dated 22.6.2013 passed by the
APERC vide SLP (Civil) No. 30416 to 30428 of 2013.
APERC issued suo-moto order dt:6.8.13 determining variable cost tariff in respect of
Bagasse & Biomass (including Industrial Waste) projects giving consequential effect to the
order dated 31.03.2009 in O.P No.5 of 2009 based on Hon’ble APTEL order dated
20.12.2012 & 30.04.2013. DISCOMs filed SLP against APERC order dated 06.08.2013 in
the Hon'ble Supreme Court vide SLP (Civil) No. 19508 of 2013.
The Special Leave Petitions (Civil) 30416-28 filed against APERC order dt:22.6.13 & 19508
filed against APERC order dt:06.08.13 came up for admission on 28.10.2013 and the
Lordships were not inclined to grant permission to file Special Leave Petitions directly
against the orders of APERC and directed to withdraw the Special Leave Petitions.
Accordingly, the Special Leave Petitions were withdrawn.
APSPDCL
Page 45
As such, IAs were filed in C.A 1376-85 of 2013 before Hon’ble Supreme Court requesting
for grant of stay of APERC orders dt:22.06.2013 & 06.08.2013 and Appeal Nos. 83 & 84 of
2014 were filed before APTEL against APERC orders dt:22.06.2013 & 06.08.2013. The
same were dismissed by APTEL vide order dt: 21.07.2014 as not maintainable.
Subsequently, appeals 10448 & 10499 are filed before Hon’ble Supreme Court against the
orders of APTEL dt: 21.07.2014. The appeals are tagged with CA 1376-85 of 2013 and are
likely to be listed on 20.01.2016.
About Rs. 406 Crs was already paid to the NCE developers in accordance with the various
court orders (in the united Andhra Pradesh state).
However, upon the directions of Hon’ble Supreme Court dt: 16.12.2013, APDISCOMs are
implementing tariff to the NCE developers as per APERC order dt: 22.06.2013 from the date
of order, viz., 22.06.2013.
Further, vide orders dt:11.03.2014 & 13.03.2014, Hon’ble Supreme Court of India directed
to release 50% amount due to the NCE developers. Accordingly, the NCE developers were
paid Rs.214.96 Crs in erstwhile Andhra Pradesh.
APERC determined the variable cost for the control period FY 2014-19 vide APERC order
dt: 16.05.2014. Further, APERC determined the fixed cost tariff for the Biomass, Bagasse,
Mini Hydel & Industrial Waste projects for beyond 10 years of operation vide APERC
orders dt:19.07.2014, 05.08.2014, 23.08.2014 & 01.09.2014 respectively. The fixed cost &
variable cost are adopted as per the above orders for cost projections for H2 FY 2015-16 and
FY 2016-17. However, review petitions have been filed by APDiscoms on APERC orders dt:
19.07.2014, 05.08.2014, 23.08.2014& 01.09.2014.
The Hon’ble Commission dismissed
/rejected these review petitions. Hence, appeals DFR Nos. 645 &646 of 2015 were filed
before APTEL.
Further, the Biomass developers filed appeals before APTEL on APERC order dt:
16.05.2014& 19.07.2014 wherein APERC determined variable cost tariff for FY 2014-19 &
APSPDCL
Page 46
fixed cost tariff for biomass projects beyond 10 years of operation respectively. Also,
bagasse developers preferred appeal before APTEL against APERC order dt: 16.05.2014.
The Mini Hydel developers also preferred appeal before APTEL against APERC order dt:
23.08.2014.
The Commission vide its order dt: 31.03.2009 fixed single part tariff for existing Wind and
Municipal waste projects for the period from 1.4.2009 to 31.3.2014. Further APERC issued
orders dt: 15.11.2012 duly fixing new tariff @Rs 4.70/unit for upcoming wind power
projects upto 31.03.2015. The said tariff order was extended till 31.07.2015. Vide order
dt:01.08.2015, APERC determined the tariff for the upcoming wind projects for FY2015-16
@ Rs.4.83/unit without AD and @Rs.4.25/unit with AD based on the regulation no 1 of 2015
pertaining to terms and conditions for tariff determination for wind projects in the state of AP
for the period from FY 2015-16 to 2019-20.
The weighted average costs per unit (or Tariff Order rates) for NCE sources considered for
FY 2016-17 are shown in the table below:
Weighted average Cost / Tariff
Weighted average Cost / Tariff
Order Rate Considered for H2
Order Rate Considered for FY
FY 2015-16 (Rs. / kWh)
2016-17 (Rs. / kWh)
5.91
6.18
4.15
4.33
NCE – Municipal Waste to Energy
5.91
6.18
NCE – Industrial Waste based power project
5.93
6.11
NCE – Wind Power
4.27
4.40
NCE – Mini Hydel
2.63
2.30
NCE – NCL Energy Ltd.
1.62
1.67
NCE – Solar Power
6.82
6.80
NCE – Solar Parks
-
6.16
Project Type
NCE – Bio-mass including Co - Gen
NCE – Bagasse
APSPDCL
Page 47
3.5.6
MINI POWER PLANTS
SRIVATHSA POWER PROJECTS LTD (17.202 MW)
The recovery of fixed charges is limited to the delivery of 110 MU energy units. The fixed
cost payable is Rs. 0.00 Crs for FY 15 and
Rs. 1.726727 Crs for FY 16-17. The variable
tariff for H2 FY 2015-16 has been considered same as the tariff in H1 FY 2015-16. FY 201617 per unit variable cost has been projected by considering 3% escalation on the VC of H1
FY 2015-16.
Incentives: In case the project achieves delivered energy in excess of 110 MU in a tariff year,
the APDISCOMs shall pay to the generator, an incentive of Rs.0.05 (Rupees Zero and Five
Paise only) / kWh for each additional unit of actual delivery of energy at the Interconnection
Point.
3.5.7
HNPCL
M/s. HNPCL has filed an application vide O.P.No. 21/2015 before Hon’ble APERC for
determination of tariff of 1040 MW Coal fired Thermal Power Plant to be set up at
Visakhapatnam under cost plus basis and the hearings are under progress. Pending
determination of Tariff by APERC, M/s. HNPCL has claimed the variable cost per unit of
Rs. 1.8/kWh and fixed cost of Rs. 2.16/kWh at 85% avaiability for FY 2016-17.
3.5.8
Long Term&Medium Term
Long Term – Thermal PowerTech Corporation India Limited
Variable cost per unit of Rs.1.76/kWh have been considered for H2 FY 2015-16. And 3%
escalation for FY 16-17. Fixed cost per unit of Rs.1.76/kWh have been considered for FY
16-17.
Long Term – 1000MW DBFOO Bidding
Total cost per unit considered for FY 16-17 is Rs.3.87/kWh. With variable cost of
Rs.1.41/kWh
APSPDCL
Page 48
Medium Term – KSK Mahanadi
Total cost per unit considered for FY 2016-17 is Rs. 3.79/kWh.
3.5.9
Short Term and Bilateral/ Inter-State purchases
Month-wise shortfall has been estimated based on the availability and requirement. A part of
this deficit would be met from external sources such as power traders and power exchange.
The cost of power purchase is considered at Rs.5.17/kWh same as of H1 FY 15-16
3.5.10 Bilateral Purchases/Sale of Surplus Power
Month-wise surplus has been estimated based on the availability and requirement. A part of
this surplus is assumed to be sold through bilateral contracts at a price of Rs.4.89/kWh. The
estimated sale of such surplus power is 4,334 MUs and the remaining will be sold in the open
market provided the variable cost is lower than market price. (Monthly Market Price for
FY16-17 is assumed to remain same as S2 grid market price of FY 2015-16.The estimated
sale from such external sources are estimated to be 2,808 MUs for FY 2016-17.
3.5.11 D-D Purchases
Month-wise availability of each APDiscom has been calculated based on PPA allocation.
The requirement of each Discom at APTRANSCO periphery has been calculated, by
grossing up the sales with losses. The D-D purchases / sales for each Discom have been
estimated after taking into account the respective allocations to each Discom as per the Final
Transfer Scheme. The D-D pool price has been considered at Rs. 5.17/kWh for FY 2016-17
(price of energy from bilateral purchases).
3.6
Energy Requirement
Based on the availability shown above and the energy requirement from all the Discoms, the
actual energy to be purchased Discom-wise has been projected as follows:
APSPDCL
Page 49
H2 FY 2015-16
FY 2016-17
MU
MU
DISCOMS
APEPDCL
8,409
19,085
APSPDCL
17,878
38,481
Total
26,288
57,566
The above energy requirement of the licensees has been arrived at by grossing up the sales of
the licensee sales with appropriate transmission and distribution losses. The external loss on
the power purchased from CGS and KSK Mahanadi only has also been factored in the above
energy requirement.
3.7
Summary of Power Purchase for Current Year H2 FY15-16andEnsuing year FY16-17
Based on the availability, requirement and costs for each source, the summary of power
purchase cost for Andhra Pradesh for H2 FY 2015-16 is projected as follows:
2015 -16 H2 Projection
Source
Power Purchase
(MU) Available
Power Purchase
(MU) Despatch
Costs (INR
Crs)
PP Cost (INR/kWh)
APGENCO Thermal
9,289
9,289
4,467
4.81
TSGENCO Thermal
3,338
3,338
1,287
3.86
942
942
233
2.47
-
-
-
APGENCO Hydel
TSGENCO Hydel
CGS
5,771
5,771
1,966
3.41
61
61
19
3.16
IPPs - Gas
1,390
1,390
482
3.46
NCE
1,035
1,035
492
4.76
Others*
2,090
2,090
700
3.35
Market
3,406
2,335
1,207
5.17
27,323
26,252
10,853
4.13
APGPCL
Total
APSPDCL
Page 50
*Others include Srivathsa, Long term and Medium term purchases, Hinduja
Based on the availability, requirement and costs for each source, the summary of power
purchase cost for Andhra Pradesh for FY 2016-17 is projected as follows:
FY 16-17 Projection
Source
Power Purchase
(MU) Available
Power Purchase
(MU) Despatch
PP Cost
(INR/kWh)
Costs (INR Crs)
APGENCO Thermal
18,776
16,915
8,703
5.14
TSGENCO Thermal
6,728
6,720
2,514
3.74
APGENCO Hydel
3,241
3,241
479
1.48
TSGENCO Hydel
-
-
-
12,437
12,437
4,252
3.42
117
107
35
3.25
IPPs - Gas
3,054
3,048
1,119
3.67
NCE
4,965
4,965
2,539
5.11
Others*
16,700
16,700
6,440
3.86
Market
822
575
297
5.17
66,839
64,706
26,378
4.08
57,566
57,566
23,533
3.97
9,274
7,142
(3,502)
(4.90)
CGS
APGPCL
Total
DISCOM
Requirement
Energy
Sale of Surplus Power
*Others include Srivathsa, Long term and Medium term purchases, Hinduja
APSPDCL
Page 51
4
4.1
Losses
DISCOM losses
The DISCOM losses for H2 FY 15-16 is taken as per APERC approved values and 5%
reduction is considered for FY16-17
The below table provides the voltage level losses for projecting the energy requirement for
H2 FY 2015-16 and FY 2016-17.
APSPDCL - DISCOM losses
Voltage Level
H2 FY 2015-16
FY 2016-17
33 kV
3.80%
3.61%
11 kV
3.84%
3.65%
LT
5.00%
4.75%
The following table gives the details of losses excluding EHT sales projected by
APSPDCL for 2015-16 and 2016-17.
Approved by APERC
Projection of APSPDCL
4.2 TRANSCO losses
2015-16
Excl. EHT
Incl. EHT
10.17 %
8.75 %
10.54 %
9.31 %
2016-17
Excl. EHT
Incl. EHT
9.97 %
8.44 %
The Transco losses for H2 FY 2015-16have been taken as per approved. And for FY 16-17
Transco losses for FY 15-16 H1 actuals are considered
Transmission Losses
H2 FY 2015-16
3.95%
4.3
Transmission Losses
FY 2016-17
3.34%
Losses external to APTRANSCO system
The losses external to the APTRANSCO system are considered to be 3.57 % for H2 FY 1516 and also for FY16-17 APERC approved values for FY15-16. This is applicable for
procurement of power from Central Generating Stations and other medium and short term
purchases. However, external losses have not been considered for bilateral / inter-state
purchases due to considering average landed power purchase cost at APTransco periphery.
APSPDCL
Page 52
4.4
APTransco Charges
The Transmission Cost has been computed based on the Transmission Tariff order for
the FYs 2013-14, FY 2014-15, 2015-16 and 2016-17and is tabulated below:
Form - 1.1 – Transmission Cost
Name of
Transmission
service
provider
Load not eligible for Open Access
Open Access
Load Eligible for Open Access
Tariff
Cost
MW
(Rs./kW/month) (Rs. Crs.)
MW
Tariff
(Rs./kW/month)
Cost
(Rs. Crs.)
1
APTransco
2
3
4
5
6
7
2013-14
2014-15
2015-16
2016-17
3050.55
4131.55
4624.44
4806.22
61.03
65.30
76.66
91.36
144.83
301.61
425.41
348.56
1388.45
2259.99
2485.99
2734.59
61.03
65.30
76.66
91.36
101.68
177.09
228.69
299.80
As per revised regulatory formats the transmission load has been apportioned between
load not eligible for open access & load eligible for open access and the transmission cost is
arrived by applying the respective transmission tariff.For the FY 2014-15, contracted
demand of APSPDCL of six districts are considered for entire 12 months and contracted
demand of newly added Anantapur &kunool districts are considered for 10 months for
computation of transmission charges. Contracted load of Anantapur &kurnool districts is
taken as 17.45% of contracted load of erstwhile APCPDCL. The licensee has considered the
true-up order for 2nd control period regarding transmission charges, issued by Honourable
APERC on 7-11-15 in OP.No. 13 of 2015.
4.5
PGCIL and ULDC Charges
The PGCIL and ULDC charges have been computed based on the information sought by the
licensee from APTransco. For FY 2014-15 the figures shown are actuals. For FY 2015-16,
charges approved in the Tariff Order have been adopted and the licensee has projected the
PGCIL & ULDC charges for FY 2016-17 with 10% growth. The details of the PGCIL &
ULDC charges are as shown in the table below:
2013-14
PGCIL (Rs. Crs.)
ULDC (Rs. Crs.)
APSPDCL
2014-15
2015-16
2016-17
128.19
217.12
211.10
232.21
5.90
6.89
9.71
10.68
Page 53
4.6
SLDC Charges
The SLDC Charges have been adopted as per the tariff orders. The charges have been
apportioned based on load not eligible for open access and load eligible for open access. The
projected SLDC charges for 2015-16 are Rs. 21.05 Crs. and Rs.23 Crs. for 2016-17. For the
FY 2014-15, contracted demand of APSPDCL of six districts are considered for entire 12
months and contracted demand of newly added Anantapur &kunool districts are considered
for 10 months for computation of transmission charges. Contracted load of Anantapur
&kurnool districts is taken as 17.45% of contracted load of erstwhile APCPDCL.
Form – 1.2 SLDC Charges
2013-14
Annual Fee
Tariff
(Rs./MW/year)
Cost
(Rs. Crs.)
3190.88
4755.66
1.52
1388.45
4755.66
0.66
0.00
0.00
MW
Load not eligible for Open Access
Open Access
Load Eligible for Open Access
Availed (within area of supply)
Availed ( Outside Area of supply)
Charges
Tariff
(Rs./MW/month)
Cost
(Rs. Crs.)
3190.88
1406.08
5.38
6.90
1388.45
1406.08
2.34
0.00
0.00
3.00
0.00
0.00
MW
Total Cost
(Rs. Crs.)
2014-15
Annual Fee
Tariff
(Rs./MW/year)
Cost
(Rs. Crs.)
4131.55
2535.65
1.05
2259.99
2535.65
0.57
0.00
0.00
MW
Load not eligible for Open Access
Open Access
Load Eligible for Open Access
Availed (within area of supply)
Availed ( Outside Area of supply)
Charges
Tariff
(Rs./MW/month)
Cost
(Rs. Crs.)
4131.55
2378.11
11.79
12.84
2259.99
2378.11
6.45
0.00
0.00
7.02
0.00
0.00
MW
Total Cost
(Rs. Crs.)
2015-16
Annual Fee
Tariff
(Rs./MW/year)
Cost
(Rs. Crs.)
4624.44
3092.78
1.43
2485.99
3092.78
0.77
0.00
0.00
MW
Load not eligible for Open Access
Open Access
Load Eligible for Open Access
Availed (within area of supply)
Availed ( Outside Area of supply)
Charges
Tariff
(Rs./MW/month)
Cost
(Rs. Crs.)
4624.44
2209.34
12.26
13.69
2485.99
2209.34
6.59
0.00
0.00
7.36
0.00
0.00
MW
Total Cost
(Rs. Crs.)
2016-17
Annual Fee
Tariff
(Rs./MW/year)
Cost
(Rs. Crs.)
4806.22
3533.18
1.70
2734.59
3533.18
0.97
0.00
0.00
MW
Load not eligible for Open Access
Open Access
Load Eligible for Open Access
Availed (within area of supply)
Availed ( Outside Area of supply)
APSPDCL
Charges
Tariff
(Rs./MW/month)
Cost
(Rs. Crs.)
4806.22
2247.62
12.96
14.66
2734.59
2247.62
7.38
0.00
0.00
8.34
0.00
0.00
MW
Total Cost
(Rs. Crs.)
Page 54
4.7
Distribution Costs (Rs. in Crores)
Open Access
Load not eligible for Open Access
Load Eligible for Open Access
Year
1
2013-14
2014-15
2015-16
2016-17
Total
MW
Tariff
(Rs./kW/month)
2
3
Cost
(Rs. Crs.)
MW
Tariff
(Rs./kW/month)
Cost
(Rs. Crs.)
5
6
4
7
8=4+7
962.27
53.54
1273.30
1453.35
945.20
28.24
1481.60
2106.73
1034.90
46.50
2153.24
2332.71
1133.33
50.44
2383.14
3617.05
1219.76
6350.00
8054.18
9256.06
The distribution cost as per the Tariff Orders are considered. For FY 2013-14, the
distribution cost of APSPDCL with six districts are considered. For FY 2014-15, the
distribution cost of APSPDCL with six districts and distribution cost of Anantapur &
Kurnool districts are considered for 10 months duly taking a proportion of distribution cost
of erstwhile APCPDCL (17.45% of 1996.63 Crs.) are considered for arriving distributin cost.
For FY 2015-16& FY 2016-17, the distribution cost of APSPDCL with six districts and for
Anantapur &kurnool districts a proportion of distribution cost of erstwhile APCPDCL
(17.45% of Rs.2215.69 Crs.) are considered for arriving total distribution cost.
4.8
Interest on Consumer Security Deposits
Interest on Security Deposit are calculated based on the past trend. The interest is
calculated @ 9.50% per annum for 2015-16 and 2016-17 on the average of opening and
closing balances. For previous year 2014-15 the actual average rate of interest is found to be
9.89% per annum.
Form 1.5: The computation on Interest on Consumer Security Deposit is given below
Revenue Requirement Item (Rs. Crs.)
A Opening Balance
B Additions during the Year
C Deductions during the Year
D Closing Balance
E Average Balance ((A+D)/2)
F Interest @ % p.a. #
G Interest Cost (E*F)
APSPDCL
2013-14
2014-15
2015-16
2016-17
1007.27
187.05
1118.07
359.28
1365.86
377.24
1626.04
396.11
76.25
111.49
117.06
122.92
1118.07
1365.86
1626.04
1899.23
1062.67
1241.97
1495.95
1762.63
8.52
9.89
9.50
9.50
90.53
122.83
142.12
167.45
Page 55
As per APERC Regulation 6 of 2004 stipulates "Security Deposit amount shall be two months charges in
case of monthly billing and 3 months charges for bi-monthly billing".
.....
"The interest accruing to the credit of the consumer shall be adjusted annually against the
amounts outstanding from the consumer to the Licensee as on 1st May of every year and the amounts
becoming due from the consumer to the Licensee immediately thereafter."
In this regard, the Licensee would like to submit that the Power Purchase Cost contributes to nearly
80% of the total Retail ARR and certainty in projection of power purchase cost has become very critical.
Any deviation in power purchase cost has to be funded through internal sources and to be recovered in
subsequent years through ARR. On the other hand, Subsidy from government contributes to be more than
12% of the Retail ARR. This would mean that Discoms are effectively getting 2 months consumer
security deposit on 88% of retail ARR. While payments to generators is being done on a monthly basis,
the revenue cycle is nearly 2 months. Hence, the working capital requirement of the Distribution
Licensees has become difficult to manage in recent time and hence the Licensee requests the Hon'ble
Commission to increase the duration of Security Deposit from the current two month charges to 75 days
charges in case of monthly billing while continuing with 3 months charges for bi-monthly billing. This
would ensure the Working Capital Requirements of the Licensees are met.
4.9
Supply Margin
The licensee has projected Supply Margin for FY 2015-16 and FY 2016-17. The supply
margin for 2013-14, 2014-15, 2015-16 and 2016-17are as follows.
Form – 1.6
- Supply Margin
Supply Margin Amount
Rs. in Crores
2013-14
2014-15
2015-16
2016-17
12.33
12.12
13.13
13.00
4.10 Other Costs
The licensee has projected the following expenditure under other costs :
1) Amount payable towards DELP to M/s EESL, New Delhi
2) Amount payable towards solar pumpsets
APSPDCL
Page 56
DELP :
The licensee with the approval of Honourable Commission is distributing 2 Nos. LED bulbs
in all the districts of its jurisdiction. In accordance with the approval of the Honourable
Commission, the licensee has projected the amounts payable to M/s EESL, New Delhi.
Solar pumpsets :
The licensee has erected 1000 Nos. solar pumpsets and planned to erect another 1000 Nos. in
the FY 2016-17. The consumer contribution is 11% of the project cost, the MNRE, Govt. of
India provides 33% of the project cost as subsidy and balance 56% is to be borne by the
licensee. The licensee has projected payment towards this project in FY 2016-17.
The other costs during FY 2015-16 & FY 2016-17are submitted below :
Particulars
Payments to M/s.EESL
towards DELP
Solar pumpsets
Total
2015-16
38.12
38.12
2016-17
50.13
11.38
61.51
4.11 Summary of ARR
Aggregate Revenue Requirement (ARR) for Retail Supply Business
(Form-1)
Revenue Requirement Item (Rs. Crs.)
2013-14
2014-15
2015-16
2016-17
246.51
478.70
654.10
648.35
9.90
19.86
21.05
23.00
1
Transmission Cost
2
SLDC Cost
3
Distribution Cost
1,273.30
1,481.60
2,153.24
2,383.14
4
PGCIL Expenses
128.19
217.12
211.10
232.21
5
ULDC Charges
5.90
6.89
9.71
10.68
6
Network and SLDC Cost (1+2+3+4+5)
1,663.80
2,204.17
3,049.20
3,297.39
7
Power Purchase / Procurement Cost
7,663.14
12,217.29
13,468.63
15,380.80
8
Interest on Consumer Security Deposits
90.53
122.83
142.12
167.45
9
Supply Margin in Retail Supply Business
12.33
12.12
13.13
13.00
10
Other Costs, if any
0.00
0.00
38.12
61.51
11
Supply Cost (7+8+9+10)
7,765.99
12,352.24
13,662.00
15,622.76
12
Aggregate Revenue Requirement (6+11)
9,429.79
14,556.41
16,711.20
18,920.15
APSPDCL
Page 57
5 Revenue Projections
5.1
Sales Forecast
The factors affecting the actual consumption are numerous and often beyond the
control of the licensee due to factors such as Government Policy, economic climate, weather
conditions and force majeure events like natural disasters. Therefore, an accurate pointestimate of the consumption (sales by licensee) is not possible. Under such a situation, the
attempt is to look into various factors and estimate the interrelationships to arrive at a
reasonably accurate forecast within a range and use a single point-estimate within the range
for the limited purpose of estimating future costs / revenues. The actual sales for FY 2009-10
to FY 2014-15 are given below :
Category
2009-10
2010-11
2011-12
2012-13
2013-14
2014-15
Actual sales in MU
LT Category
9968.21
9716.43
10951.15
11223.49
12181.94
17262.87
Domestic
3605.65
3861.84
4121.19
4221.00
4428.14
5946.78
Non-domestic/Commercial
850.52
901.31
986.59
983.56
977.02
1314.61
Industrial
740.82
796.76
989.83
965.28
866.11
1380.24
24.52
25.01
24.42
22.17
21.58
32.32
4167.82
3664.49
4366.34
4587.91
5513.46
8006.78
533.87
419.62
412.35
394.51
327.53
489.42
43.69
46.87
49.02
48.47
47.13
77.14
1.31
0.55
1.40
0.59
0.96
15.57
HT Category
3729.07
4724.81
5437.06
5221.36
5842.52
9098.66
HT I : General
2600.28
3530.74
4115.62
3889.21
4412.70
6932.50
HT II: Others
328.43
352.45
379.60
422.86
446.79
553.31
Cottage Industries, Dhobighats& Others
Irrig& Agriculture
Local Bodies, St. Lighting & PWS
General Purpose
Temporary Supply
0.00
0.00
0.00
1.28
8.56
17.87
29.37
27.45
61.31
36.27
48.69
528.35
522.15
521.40
569.54
609.65
646.15
747.84
48.60
51.03
35.47
27.35
22.16
34.48
HT VII: Green Power
0.00
0.00
0.00
0.00
0.00
0.00
HT VIII: Temporary
0.80
0.00
0.00
0.00
0.08
0.00
199.44
241.74
275.53
234.74
257.40
284.31
13697.27
14441.24
16388.21
16444.85
18024.46
26361.53
HT III: Airports, Bus Stations and Railway Stations
HT IV Government LIS & Agl.
HT V: Railway Traction
HT VI: Townships & Residential Colonies
Category: RESCOs
Total (LT+HT)
APSPDCL
Page 58
Trend Method
This method is a non-causal model of demand forecasting which assumes that the underlying
factors, which drive the demand for electricity, are expected to follow the same trend as in
the past and hence the forecast for electricity is also based on the assumption that the past
trend in consumption of electricity will continue in the future. The strength of this method,
when used with balanced judgment, lies in its ability to reflect recent changes and therefore
is probably best suited for a short-term projection as used for the ARR/ Tariff filing.
However, the trend-based approach has to be adjusted for judgment on the characteristics of
the specific consumer groups/ categories. For example, while this method may provide a
better estimate of consumption by the domestic and commercial categories of consumers, it
may not be very suitable for the industrial category because of the high dependence of
demand on the end-use and also on the macroeconomic variables.
In any case, the forecasts arrived at by using the trend method need to be modified for impact
of any other considerations like increasing commercialization/ development in certain
districts/ regions to incorporate the impact of econometric variables and the load reliefs
issued in the past. The Licensee has projected the category –wise sales based on the modified
trend approach. Sales Forecast for the ensuing year has been developed based primarily on
analysis of historic data for the period FY 2009-10 to H1 of FY 2015-16. The following
inputs have been taken to arrive at sales consumption for H2 of FY 15-16 and FY 2016-17.
 Actual sales (6 districts + Anantapur & Kurnool) captured from FY 2009-10 to FY
2014-15
 CAGR computed for historical sales for FY 2009-10 to FY 2014-15
 Actual sales (6 districts + Anantapur & Kurnool) captured for FY 2015-16 H1
 Sales projected for FY 2015-16 H2 using CAGR as growth rate over FY 2014-15 H2
actual sales (except for LT Agriculture where growth rate is linked to the growth in
connections)
 CAGR computed for actual sales from FY 2009-10 to FY 2015-16
 Growth rate used on FY 2015-16 projected sales to forecast sales for FY 2016-17
APSPDCL
Page 59
 Additional loads for Lift irrigation schemes etc., added for projecting FY 2015-16&
FY 2016-17 restricted sales
 Load restrictions captured for FY 2014-15 H1& H2 and FY 15-16 H1
 Load shifting has been considered for modifying historical load restrictions
 No Load restrictions are expected in H2 FY 2015-16&FY 2016-17
 Hence, sales for FY 2015-16 (H1 FY 2015-16 actuals and H2 FY 2015-16
projections) and FY 2016-17 projected after considering additional loads & LRs on
actual sales
From June, 2014 onwards the actual / projected figures are pertains to entire 8
districts of APSPDCL (including newly added Anantapur &Kurnool districts). The sales
growth rates are considered based on the present year and previous year figures both pertains
to entire 8 districts of APSPDCL. The growth rate for each category is calculated with
respect to sales of 8 districts for FY 2014-15,FY 2015-16 &FY 2016-17.
5.1.1
LT Sales forecast
Sales Forecast for FY 2016-17 has been developed based primarily on analysis of
historic data for the period FY 2009-10 to FY 2015-16. The ARR for the retail supply
business is being filed for the FY 2016-17. The Licensee submits the following forecasts of
energy sales (in million units) as part of the current application to the Hon’ble Commission.
For the FY 2014-15, the sales pertain to Anantapur & Kurnool districts are considered from
2nd June, 2014.
5.1.2
LT Cat-I: Domestic Supply
The consumption of power by the domestic category was 5946.78 MU in the year
2014-15 consisting of 2903.37 MU in the first half and 3043.72 MU in the second half of the
year.
APSPDCL
Page 60
The consumption of power by the domestic category in the first half of the 2015-16 is
3703.11 MU. For the year 2015-16, APSPDCL has estimated the power consumption by the
domestic category at 7099.72 MU, taking into account actual sales till September 2015. The
sales forecast for FY 2015-16 has been done for the months October to March 2016 by
projecting an appropriate growth rate over the sales (6 districts and Anantapur & Kurnool) of
the corresponding months of FY 2014-15 and adding the load relief quantum. The sales so
arrived shall reflect the unrestricted sales (sales projected such that there would be no load
shedding). The sales for second half of FY 2015-16 for this category will be 3396.62 MU.
For the year 2016-17, the licensee has projected sales using an appropriate growth
rate over 2015-16 projected sales (6 districts and Anantapur & Kurnool. The licensee has
projected the unrestricted sales for FY 2016-17, as it would like to plan no load restriction
measures for FY 2016-17. The unrestricted sales projected for FY 2016-17 for this category
is 7953.09MU. The growth rate of sales for 8 districts (6 districts and Anantapur & Kurnool)
for FY 2015-16 over FY 2014-15 is 15.76% and for FY 2016-17 over FY 2015-16 is
12.02%.
LT Cat-I
MUs
% Growth
5.1.3
2009-10
2010-11
3605.65
3861.84
7.11%
2011-12 2012-13
Actuals
4121.19
6.72%
4221.00
2.42%
2013-14
2014-15
4428.14
4.91%
5946.78
12.82%
2015-16 2016-17
Projections
7099.72
15.76%
7953.09
12.02%
LT Cat-II: Non-Domestic / Commercial Supply
The consumption of power by the non-domestic category was 1314.61 MU in the year
2014-15 consisting of 637.75 MU in the first half and 676.85 MU in the second half of the
year.
APSPDCL is experiencing an increase in the commercial activity thus necessitating
an increase in the release of new services as well as higher levels of specific consumption by
these commercial establishments. For 2015-16, the first half sales are 813.51 MU. The sales
forecast for FY 2015-16 has been done for the months October to March 2016 by projecting
an appropriate growth rate over the sales (6 districts and Anantapur & Kurnool) of the
APSPDCL
Page 61
corresponding months of FY 2014-15 and adding the load relief quantum. The sales so
arrived shall reflect the unrestricted sales. The sales for second half of FY 2014-15 for this
category are 771.66 MU. SPDCL has projected the sales for entire 2015-16 at 1585.17MU
For the year 2016-17, the licensee has added a moderate growth rate of 11.23 % has been
used to project the sales for FY 2016-17. The licensee has projected the unrestricted sales for
FY 2016-17, as it would like to plan considering no load-shedding for FY 2016-17. The sales
projected for FY 2016-17 for this category is 1763.12 MU. The growth rate of sales for 8
districts (6 districts and Anantapur & Kurnool) for FY 2015-16 over FY 2014-15 is 16.53%
and for FY 2016-17 over FY 2015-16 is 11.23%.
LT Cat-II
MUs
% Growth
5.1.4
2009-10
2010-11
850.52
901.31
5.97%
2011-12 2012-13
Actuals
986.59
9.46%
983.56
-0.31%
2013-14
2014-15
977.02
-0.67%
1314.61
11.38%
2015-16 2016-17
Projections
1585.17
16.53%
1763.12
11.23%
LT Cat-III: Industrial Supply
The consumption of power by the category is 643.04 MU in 2014-15 consisting of
737.19 MU in the first half and 1380.24 MU in the second half of the year.
During the year 2015-16, APSPDCL has achieved sales of 791 MU in the first half.
The sales forecast for FY 2015-16 has been done for the months October to March 2016 by
projecting an appropriate growth rate over the sales (6 districts and Anantapur & Kurnool) of
the corresponding months of FY 2014-15. Load relief quantities of corresponding months
are added to arrive unrestricted sales projections. The sales so arrived shall reflect the
unrestricted sales (sales projected such that there would be no load shedding). The sales for
second half of FY 2015-16 for this category is805.78 MU. The overall sales for 2015-16 are
likely to be around 1596.78 MU. For projecting sales of FY 2016-17, the Company has
added a growth rate of 13.57% over FY 2015-16 sales. No load reliefis expected in the FY
2016-17. The licensee has projected the sales for this category as 1813.53 MU.The growth
APSPDCL
Page 62
rate of sales for 8 districts (6 districts and Anantapur & Kurnool) for FY 2015-16 over FY
2014-15 is 11.85% and for FY 2016-17 over FY 2015-16 is 13.57%.
LT Cat-III
MUs
% Growth
5.1.5
2009-10
2010-11
740.82
796.76
7.55%
2011-12 2012-13
Actuals
989.83
24.23%
965.28
-2.48%
2013-14
2014-15
866.11
-10.27%
1380.24
27.67%
2015-16 2016-17
Projections
1596.78
11.85%
1813.53
13.57%
LT-IV - Cottage Industries &Dhobighats etc.,
The consumption of power by this category is 32.32 MU in 2014-15 consisting of
14.58 MU in the first half and 17.75 MU in the second half of the year.
The sales in this category during first half of 2015-16 is 18.56 MU. The sales forecast
for FY 2015-16 has been done for the months October to March 2016 by projecting an
appropriate growth rate over the sales (6 districts and Anantapur & Kurnool) of the
corresponding months of FY 2014-15. Load relief quantities of corresponding months are
added to arrive unrestricted sales projections. The sales so arrived shall reflect the
unrestricted sales (sales projected such that there would be no load shedding). The sales for
second half of FY 2015-16 for this category are 19.61 MU. For the year 2016-17, the
licensee has projected unrestricted sales using an appropriate growth rate over 2015-16
projected sales to arrive at 2016-17 unrestricted sales. Growth rate of 2015-16 unrestricted
sales over 2015-16 revised sales is 8.77%.The licensee has projected the unrestricted sales
for FY 2016-17 for this category is 41.52 MU.The growth rate of sales for 8 districts (6
districts and Anantapur & Kurnool) for FY 2015-16 over FY 2014-15 is 12.37% and for FY
2016-17 over FY 2015-16 is 8.77%.
LT Cat-IV
MUs
% Growth
APSPDCL
2009-10
2010-11
24.52
25.01
1.96%
2011-12 2012-13
Actuals
24.42
-2.33%
22.17
-9.24%
2013-14
2014-15
21.58
-2.62%
32.32
13.74%
2015-16 2016-17
Projections
38.17
12.37%
41.52
8.77%
Page 63
5.1.6
LT-V - Agriculture
a) The Licensed area of APSPDCL covers eight Districts after bifurcation of AP state.
Farmers in these eight Districts largely depend on lifting of ground water for their
irrigation needs. The Energy Demand has been growing consistently over the past
years. Usually, two crops are grown in a year and in some areas where plenty of water
is available, particularly in Krishna and Guntur districts & part of other districts, third
crop is also grown. Among all the crops, Paddy is the most preferred crop being
grown in all the eight Districts resulting in high Energy Demand on Irrigation. In
recent years, depth of water table is increased, resulting in increase in the Energy
demand.
b) Large no. of the pump sets under usage are of not as per standard specifications and
such pump sets draw more Energy. Also the farmers are replacing the old pump sets
with higher capacity pump sets whenever the depth of water table increases.
c) The Government of Andhra Pradesh declared a modified agriculture policy in
January 2005 aimed towards incentivizing Demand side management in the
agriculture sector. One of the key features of the policy is to install Capacitors for all
the existing pump sets. So far, 89.63%8of the existing pump sets as on 30.11.2015 are
provided with Capacitors by the consumers. The licensee is taking all necessary steps
to provide Capacitors for the balance pump sets also.
d) There are 8,20,732 Nos. agricultural services in the licensee’s area as on 31-03-2014.
Due to inclusion of Anantapur & Kurnool districts 3,17,152 Nos. agricultural services
are added on 02-06-2014. During FY 2014-15, 54,011 Nos. of new agricultural
connection are added, thus resulting in total no.of agricultural connections increased
to 11,91,895 Nos. as on 31-03-2015. During FY 2015-16, the licensee has planned to
release 87,600 Nos. agricultural connections, out of which 45,989 Nos. are released
upto November, 2015. By this addition of new connections, the total no.of
APSPDCL
Page 64
agricultural connections in the licensee area will be 12,79,495 Nos. at end of FY
2015-16. Further, the licensee projects 50,000 Nos. new agricultural connections
during FY 2016-17. The circle wise break up of no.of agricultural connections
existing, added and projections for FY 2014-15 to FY FY 2016-17 are furnished in
the table below:
S.No
Circle
Existing as
on
31-03-14
No.of agricultural services in APSPDCL
Added
Existing as
Added
Existing
during
on
during
as on
2015-16
31-03-16
2014-15
31-03-15
(Proj.)
(Proj.)
3905
88211
8500
94694
Added
during
2016-17
(Proj.)
4852
Existing as
on
31-03-17
(Proj.)
99546
1
Vijayawada
84306
2
3
4
5
Guntur
Ongole
Nellore
Tirupati
80614
127431
137086
260329
4457
9110
8311
5499
85071
136541
145397
265828
7500
15400
4900
4600
91323
146576
156083
285366
4281
8790
2797
2626
95604
155366
158880
287992
6
7
8
Kadapa
Anantapur
Kurnool
APSPDCL
130966
6821
205724
127336
371163
137787
205724
127336
1191895
5100
29600
12000
87600
147914
220844
136695
1279495
2911
16894
6849
50000
150825
237738
143544
1329495
820732
e) The majority of the agricultural connections are with bore wells. Hence, the average
capacity of the pump-sets are increasing at every year. The connected load details of
agricultural connections are furnished in the below table:
Connected load (HP) of agricultural services in APSPDCL
S.No
1
2
3
4
5
6
7
8
Circle
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
Anantapur
Kurnool
APSPDCL
Existing as
on
31-03-14
462495
382588
671975
636395
1471976
875405
4500834
Added
during
2014-15
21393
21123
47973
38529
31049
45530
973075
524952
1703622
Existing
as on
31-03-15
483887
403711
719948
674924
1503025
920935
973075
524952
6204456
Added
during
2015-16
(Proj.)
34000
30000
77000
19600
18400
20400
115154
48000
362554
Existing as
on
31-03-16
(Proj.)
517887
433711
796948
694524
1521425
941335
1088228
572952
6567009
Added
during
2016-17
(Proj.)
43865
34702
73056
35426
63597
49931
116992
47320
464889
Existing as
on
31-03-17
(Proj.)
561752
468413
870004
729950
1585022
991265
1205220
620272
7031898
f) Methods adopted for agricultural sales estimation :
 Sales estimation are being done following the agreed methodology. As per the
directions of the Honourable Commission, the licensee has implemented “ISI
APSPDCL
Page 65
methodology agricultural sales estimation”. The following are the details of
meters fixed in connection with the new methodology.
S.No
1
Meters fixed to DTRs
Circle
No.of meters fixed
Vijayawada
317
2
Guntur
3
Ongole
4
Nellore
5
Tirupati
6
Kadapa
7
Anantapur
8
Kurnool
314
451
395
1074
0
475
285
APSPDCL
3311
 For Anantapur & Kurnool circles, sales estimations are being done based on ISI
methodology from FY 2014-15.
 For Vijayawada, Guntur, Ongole, Nellore & Tirupati circles, the sales estimations
are being done based on ISI methodology from June, 2015.
 Fixing of meters in Kadapa circle is under progress and sales estimation using ISI
methodology will be done from next financial year.
g) And hence, the sales estimates furnished in this chapter is based on ISI methodology
for the areas provided with connected meters (from the date of fixing) and for
remaining periods the sales estimations are based on the earlier agreed methodology.
Hence, the licensee humbly requests the Honourable Commission to approve
agricultural sales estimations made hereunder.
h) Initiatives of the licensee to control agricultural sales in line with Tariff Order :
The licensee has took all possible measures to control agricultural sales within the
limits of Tariff Order. The following initiatives are taken in this regard.
 Strict implementation of 7 Hrs. supply-a-day.
 Anti pilferage measures.
 APSPDCL has taken Demand side management measures with publicity through
handouts, electronic media etc., to the farmers to install energy efficient pump
APSPDCL
Page 66
sets, required rating of capacitors, HDPE pipe lines at suction and delivery and
frictionless foot-valves to save energy and to avail subsidized tariff.
 Wide publicity is being given among the consumers on installation of capacitors
 With the initiatives of MNRE, Govt. of India, erection of solar pump sets project
has been under taken at a large scale. PFCGEL is acting as financial agency,
MNRE is giving 33% as subsidy, the consumer is contributing 11% and balance
56% is to be borne by the licensee. So far, 1032 Nos. (3HP : 13Nos and 5HP :
1019 Nos.) solar pump sets were commissioned at the end of November, 2015.
 Agreement entered with M/s EESL, New Delhi for conducting survey and
preparation of DPR at Hindupurmandal of Anantapur district for AgDSM project
(for replacement of existing old inefficient pump sets with ISI pump sets). Survey
work is under progress.
 HVDS :The APSPDCL has taken to convert existing LT network in to HVDS for
all agricultural connections. Majority of services in the districts of Vijayawada,
Guntur, Prakasam, Nellore, Tirupati& Kadapa are already provided supply with
HVDS. Schemes were prepared and are in process for completion balance works
in the above said six districts and also cover all the services in Anantapur &
Kurnool districts.
i) Factors for increased agricultural sales :
The following factors are expected for the increased agricultural sales in the licensee
area.
 Due to increase in depth of water table, some of the farmers replaced existing
pump sets resulting in increased energy demand.
 Many unauthorized additional loads are existing and pilferage cases are also
noticed in the agricultural sector. All necessary steps are being carried out to
regularize such cases or appropriate actions are being taken.
APSPDCL
Page 67
 Releasing of agricultural services at a large number due to increasing demand for
new services.
 Low rainfall in majority of the districts and low water levels in the projects.
j) Sales estimates with ISI methodology for Anantapur & Kurnool districts :
As stated above, sales estimates in respect of Anantapur & Kurnool circles are being
done with ISI methodology. The sales estimations for FY 2014-15, H1 of FY 2015-16
and projections for H2 of FY 2015-16 & FY 2016-17 are furnished below:
Details of DTRs existing and computation of sales per DTR :
S.No
Circle
1
2
Anantapur
Kurnool
Total
S.No
Circle
1
2
Anantapur
Kurnool
Total
APSPDCL
Apr-14
Apr15
39594
22798
62392
May14
May15
40139
22798
62937
DTRs Population for FY 2014-15
AugSepOctJul-14
14
14
14
32995
32995
33317
33442
33565
19085
19085
19566
19596
19619
52080
52080
52883
53038
53184
Jun-14
Jun15
40602
22798
63400
DTRs Population for FY 2015-16
JulAugSepOct15
15
15
15
41000
41403
41725
41993
22798
23266
23414
23540
63798
64669
65139
65533
Nov14
33790
19683
53473
Dec14
34084
19801
53885
Jan15
34461
20010
54471
Feb15
35054
20139
55193
Mar15
39125
22537
61662
Nov15
Dec15
Jan16
Feb16
Mar16
0
0
0
0
0
Page 68
k) Sales estimation for other six districts for FY 2014-15, FY 2015-16 & FY 2016-17
i)
For FY 2014-15 & FY 2015-16 (upto May’15, as estimation based on ISI
methodology started from the month of June, 2015), the Licensee has assessed the
agricultural consumption for six Districts i.eVijayawada, Guntur, Ongole,
Nellore, Chittoor and Kadapa based on readings of the meters provided on LV
side of the Distribution Transformers feeding agricultural loads exclusively. The
Licensee has done most of the representative sampling covering the existing 310
mandals of above six Districts. The sampled pump sets, under valid metered
DTRs, comprise about 1.61% of total existing pump set population in the 6 districts
of APSPDCL. 12 months common valid readings are available for 461 nos. DTRs.
ii) The following procedure is adopted for assessing agricultural consumption:
 Meter readings are collected every month from the field for the metered DTRs
feeding agricultural loads, exclusively, in the prescribed extended electronic
format T.F.2.10 that has 27 columns.
 The recorded kWh per month is computed by taking the difference of the present
meter reading and the previous meter reading. The net consumption (kWhNT) is
calculated by deducting the line loss from recorded kWh (kWhNT total /
Consumption).
 The kWhNT consumption of all the valid metered DTRs is summed up for each
of the mandals.
 Based on the HP capacity under each valid DTR in a mandal, the total valid HP in
each of the mandals is arrived at.
 The consumption per HP is computed for each of the mandal by dividing the total
kWhNT in a mandal with valid HP of the mandal.
 Based on the total number of pump sets and their capacity (which is available in
the master list for each of the mandal), the total mandal wise consumption
APSPDCL
Page 69
estimate is arrived at by multiplying the capacity with per HP consumption of that
mandal.
 By adding together the consumption estimates of the various mandals, the total
consumption for the district is arrived at. The summation of consumption figures
for all the districts leads to the company’s consumption estimate.
Such consumption estimates have been arrived based on the total valid
meter readings received from the field and employing connected load at
respective periods.
Since the fixing of meters in Kadapa circle is under progress, the sales
estimation for this circle for FY 2014-15 and H1 of 2015-16 are estimated
based on the above said procedure using valid DTR LV side meter readings.
iii)
Sales estimation based on ISI methodology :
Sales estimations are made based on ISI methodology from June, 2015 in
respect of Krishna, Guntur, Prakasam, Nellore & Chittoor districts.
iv)
For FY 2015-16 (H2) & FY 2016-17, sales projections are made based on the
historical sales, considering new services released / to be released and
anticipated seasonal changes.
v)
The actual sales estimated and projections made as discussed in the above
paras (i), (ii) & (iii) are furnished in the below tables.
APSPDCL
Page 70
Paying category services consumption
Paying category services consumption
Existing
services as on
01-4-14
Existing connected
load as on 01-04-14
30591
163458.16
consumption in
Mus during FY
2014-15
159.51
Consumption per HP in
units
Per Month
Per Year
81.32
975.86
The above sales are included in the sales estimation made in the earlier para.
The following issues were considered while projecting agricultural consumption for FY
2015-16 and for the next year 2016-17:
 The consumption of power by the category is 8006.78 MU in 2014-15 consisting of
3647.33 MU in the first half and 4359.45 MU in the second half of the year.
 While the consumption during 2014-15 H2 is higher than that of H1, the same trend is
expected to continue in second half of 2015-16. The Agricultural consumption during H2
of 2015-16 is expected to be higher than H1 and is estimated at 4679.85 MU.
 Growth in agriculture restricted sales are linked to the growth rate in agriculture
connections as mentioned above. The licensee is projecting 3.91% growth in sales for FY
2016-17 over the total sales for FY 2014-15. The licensee is confident that the growth-rate
APSPDCL
Page 71
projected would take care of the increase in specific consumption, consumption increase
because of new services to be released in 2016-17
LT Cat-V
MUs
% Growth
2009-10
2010-11
2011-12
2012-13
2013-14
2014-15
Actuals
4167.82
3664.49
-12.08%
4366.34
19.15%
4587.91
5.07%
5513.46
20.17%
8006.78
4.12%
2015-16
2016-17
2016-17
Projections (7Hrs.)
9 Hrs.
8392.70
0.63%
8720.67
3.91%
11,212.28
33.60%
The licensee has assumed 7 hours of supply to agricultural consumers, in its projections,
considering the present power supply situation in the state.
5.1.7
LT Category- VI: Local bodies, Street lighting and public waterworks
The consumption of power by the category is 489.42 MU in 2014-15 consisting of 232.77
MU in the first half and 256.65 MU in the second half of the year.
The Consumption of street light and public water works in the first half of 2015-16 is
264.43 MU. The sales forecast for FY 2015-16 has been done for the months October to
March 2016 by projecting an appropriate growth rate over the sales (6 districts and
Anantapur & Kurnool) of the corresponding months of FY 2014-15. Load relief quantities
of corresponding months are added to arrive unrestricted sales projections. The sales so
arrived shall reflect the unrestricted sales. The sales for second half of FY 2015-16 for this
category is 262.16MU. For the year 2016-17, the Licensee has added a moderate growth rate
of 2.06% to project the sales for FY 2016-17. The sales projected for FY 2016-17 for this
category is 537.42 MU.The growth rate of sales for 8 districts (6 districts and Anantapur &
Kurnool) for FY 2015-16 over FY 2014-15 is 1.84% and for FY 2016-17 over FY 2015-16 is
2.06%.
LT Cat-VI
MUs
% Growth
APSPDCL
2009-10
2010-11
533.87
419.62
-21.40%
2011-12 2012-13
Actuals
412.35
-1.73%
394.51
-4.33%
2013-14
2014-15
327.53
-16.98%
489.42
5.13%
2015-16 2016-17
Projections
526.59
1.84%
537.42
2.06%
Page 72
5.1.8
LT Category VII : General purpose
The consumption of power by the category was 77.14 MU in 2014-15 consisting of 34.49
MU in the first half and 42.65 MU in the second half of the year.
The Consumption of general purpose category in the first half of 2015-16 is 44.37 MU. The
sales forecast for FY 2015-16 has been done for the months October to March 2016 by
projecting an appropriate growth rate over the sales (6 districts and Anantapur & Kurnool) of
the corresponding months of FY 2014-15 and adding the load relief quantum. The sales so
arrived shall reflect the unrestricted sales (sales projected such that there would be no load
shedding). The sales for second half of FY 2015-16 for this category are45.15 MU. For the
year 2016-17, the licensee has projected sales using an appropriate growth rate over 2015-16
restricted sales. Growth rate of 2016-17 unrestricted sales over 2015-16 projected sales is
8.41%. The licensee has projected the unrestricted sales for FY 2016-17 for this category is
97.05 MU. The growth rate of sales for 8 districts (6 districts and Anantapur & Kurnool) for
FY 2015-16 over FY 2014-15 is 9.90% and for FY 2016-17 over FY 2015-16 is 8.41%.
LT Cat-VII
MUs
% Growth
2009-10
2010-11
43.69
46.87
7.28%
2011-12 2012-13
Actuals
49.02
4.59%
48.47
-1.12%
2013-14
2014-15
47.13
-2.77%
77.14
15.87%
2015-16 2016-17
Projections
89.52
9.90%
97.05
8.41%
HT sales forecast
Details of the trends envisaged for key categories are discussed in the following sections.
HT Cat-I – Industrial
5.1.9
The consumption of power by the HT-Industrial category is 6932.50 MU in 2014-15
consisting of 3282.95 MU in the first half and 3649.54 MU in the second half of the year.
APSPDCL
Page 73
The consumption of power by the HT-Industrial category in the first half of the 201516 is 3707.31 MU. The sales forecast for FY 2015-16 has been done for the months
October’15 to March 2016 by projecting an appropriate growth rate over the sales (6 districts
and Anantapur & Kurnool) of the corresponding months of FY 2014-15 and adding the load
relief units. The sales so arrived shall reflect the unrestricted sales. The sales for second half
of FY 2015-16 for this category is 4111.28 MU. For the year 2016-17, the licensee has
projected sales using an appropriate growth rate over 2015-16 projected. The licensee has
projected sales for this category is 8914.53 MU.The growth rate of sales for 8 districts (6
districts and Anantapur & Kurnool) for FY 2015-16 over FY 2014-15 is 8.21% and for FY
2016-17 over FY 2015-16 is 14.02%.
HT Cat-I
11 KV
33 KV
132 KV
Total Sales
% Growth
2009-10
2010-11
716.78
1236.78
646.72
2600.28
849.31
1769.39
912.04
3530.74
35.78%
2011-12 2012-13
Actuals
843.68
2020.60
1251.34
4115.62
16.57%
800.39
1909.48
1179.34
3889.21
-5.50%
2013-14
2014-15
1036.54
2056.20
1319.95
4412.70
13.46%
1415.43
3119.20
2397.88
6932.50
18.10%
2015-16 2016-17
Projections
1562.58
3572.32
2683.69
7818.59
8.21%
1804.40
4059.34
3050.79
8914.53
14.02%
5.1.10 HT Cat-II: Non-Industrial (Others)
The consumption of power by the HT Non-Industrial category was 553.31 MU in the
year 2014-15 consisting of 280.53 MU in the first half and 272.79 MU in the second half of
the year.
The consumption for the category is 347.51 MU in the first half of the 2015-16. The sales
forecast for FY 2015-16 has been done for the months October’15 to March 2016 by
projecting an appropriate growth rate over the sales (6 districts and Anantapur & Kurnool)
of the corresponding months of FY 2014-15 and adding the load relief units. The sales so
arrived shall reflect the unrestricted sales. The sales for second half of FY 2015-16 for this
category is 307.68 MU. For the year 2016-17, the licensee has projected sales using an
APSPDCL
Page 74
appropriate growth rate over 2015-16 projected. Growth rate of 2016-17 unrestricted sales
over 2015-16 revised sales is 15.12%. The licensee has projected the unrestricted sales for
FY 2016-17, considering no load restriction measures for FY 2016-17. The sales projected
for FY 2016-17 for this category is 754.27 MU.The growth rate of sales for 8 districts (6
districts and Anantapur & Kurnool) for FY 2015-16 over FY 2014-15 is 16.67% and for FY
2016-17 over FY 2015-16 is 15.12%.
2009-10
2010-11
11 KV
33 KV
132 KV
292.89
35.54
0.00
311.54
40.91
0.00
335.93
43.67
0.00
Total Sales
328.43
352.45
7.31%
HT Cat-II
% Growth
2011-12 2012-13
Actuals
2013-14
2014-15
2015-16 2016-17
Projections
348.18
70.73
3.96
362.91
73.46
10.43
455.62
80.94
16.75
539.67
93.43
22.09
621.30
107.57
25.40
379.60
422.86
446.79
553.31
655.19
754.27
7.70%
11.40%
5.66%
12.13%
16.67%
15.12%
5.1.11 HT III: Airports, Bus Stations and Railway Stations:
The sales projections for this category of consumers are given below for FY 2015-16
and FY 2016-17.
Aviation
11 KV
% Growth
2009-10
2010-11
0.00
0.00
2011-12 2012-13
Actuals
0.00
1.28
2013-14
2014-15
8.56
567.27%
17.87
78.33%
2015-16 2016-17
Projections
21.57
10.22%
23.69
9.81%
5.1.12 HT Cat-IV: Irrigation & Agriculture
The consumption of power by the HT Irrigation & Agriculture category was 528.35
MU in 2014-15 consisting of 59.56 MU in the first half and 468.79 MU in the second half of
the year.
The consumption for the category is 64.23 MU in the first half of the 2015-16.
APSPDCL projects 470.13 MU in the second half for the 2015-16. The Licensee has collected
the likely commissioning dates of the upcoming lift irrigation schemes in consultation with
irrigation department and projected the sales for FY2016-17. In APSPDCL, the following are
major State Government Lift Irrigation Schemes are expected to be operational.
APSPDCL
Page 75
Accordingly, APSPDCL is projecting a sale of 1973.91 MU during 2016-17. The growth rate
of sales for 8 districts (6 districts and Anantapur & Kurnool) for FY 2015-16 over FY 201415 is -5.42% and for FY 2016-17 over FY 2015-16 is 269.39%.
2009-10
2010-11
11 KV
33 KV
132 KV
22.76
6.61
0.00
20.19
7.26
0.00
50.89
10.42
0.00
Total Sales
29.37
27.45
-6.52%
HT Cat-IV
% Growth
2011-12 2012-13
Actuals
2013-14
2014-15
2015-16 2016-17
Projections
29.73
6.54
0.00
43.31
5.38
0.00
137.08
63.15
328.13
143.90
81.18
309.28
151.95
84.78
1737.17
61.31
36.27
48.69
528.35
534.36
1973.91
123.33%
-40.84%
34.25%
58.47%
-5.42%
269.39%
5.1.13 HT Cat-V: Railway traction
The consumption of power by this category was 747.84 MU in FY 2014-15 consisting
of 370.21 MU in the first half and 377.63 MU in the second half of the year.
For 2015-16, the consumption for the first half is 354.99 MU and APSPDCL has
projected consumption of 413.80 MU for the second half. The overall consumption for the
2015-16 is 768.79MU.
The projected consumption for the 2016-17 is 830.88 MU. The growth rate of sales for
8 districts (6 districts and Anantapur & Kurnool) for FY 2015-16 over FY 2014-15 is 2.28%
and for FY 2016-17 over FY 2015-16 is 8.08%.
HT Cat-V
132 KV
% Growth
APSPDCL
2009-10
2010-11
522.15
521.40
-0.14%
2011-12 2012-13
Actuals
569.54
9.23%
609.65
7.04%
2013-14
2014-15
646.15
5.99%
747.84
15.31%
2015-16 2016-17
Projections
768.79
2.28%
830.88
8.08%
Page 76
5.1.14 HT Cat-VI: Townships and Residential Colonies
The consumption of power by this category was 34.48 MU in the 2014-15 consisting of
16.48 MU in the first half and 18.00 MU in the second half of the year.
For 2015-16, the consumption for the first half is 21.26 MU and APSPDCL has
projected a consumption of 18.52 MU for the second half as the consumption of this
category. APSPDCL is projecting an expected growth rate of 5.03 % for FY 2016-17
resulting in 41.77MU(unrestricted sales).The growth rate of sales for 8 districts (6 districts
and Anantapur & Kurnool) for FY 2015-16 over FY 2014-15 is 5.71% and for FY 2016-17
over FY 2015-16 is 5.03%.
HT Cat-VI
11 KV
33 KV
132 KV
Total Sales
% Growth
2009-10
2010-11
47.55
1.05
0.00
48.60
51.03
0.00
0.00
51.03
5.01%
2011-12 2012-13
Actuals
33.99
1.48
0.00
35.47
-30.51%
26.53
0.82
0.00
27.35
-22.89%
2013-14
2014-15
21.39
0.77
0.00
22.16
-18.97%
33.04
1.44
0.00
34.48
2015-16 2016-17
Projections
37.80
1.97
0.00
39.77
5.71%
-9.45%
39.60
2.17
0.00
41.77
5.03%
5.1.15 HT Cat-VIII : RESCOs
The consumption of power by this category was 284.31 MU in 2014-15 consisting of
137.23 MU in the first half and 147.07 MU in the second half of the year.
For the year 2015-16, APSPDCL has projected increase in consumption to 301.96 MU, out
of which the first half sales accounts for 139.51 MU. The projected consumption for 2016-17
is 328.40 MU. The growth rate of sales for 8 districts (6 districts and Anantapur & Kurnool)
for FY 2015-16 over FY 2014-15 is 6.21% and for FY 2016-17 over FY 2015-16 is 8.76%.
Resco
11 KV
% Growth
2009-10
2010-11
199.44
241.74
21.21%
2011-12 2012-13
Actuals
275.53
13.98%
234.74
-14.80%
2013-14
2014-15
257.40
9.65%
284.31
10.45%
2015-16 2016-17
Projections
301.96
6.21%
328.40
8.76%
Sales Forecast category wise and Voltage level wise (Form – 3) Sales in MU
APSPDCL
Page 77
2009-10
2010-11
2011-12
2012-13
2013-14
2015-16
2016-17
(Proj.)
(Proj.)
2014-15
Category
Actuals
LT Category
9968.21
9716.43
10951.15
11223.49
12181.94
17262.87
19344.29
20942.05
Domestic
3605.65
3861.84
4121.19
4221.00
4428.14
5946.78
7099.72
7953.09
Non-domestic/Commercial
850.52
901.31
986.59
983.56
977.02
1314.61
1585.17
1763.12
Industrial
740.82
796.76
989.83
965.28
866.11
1380.24
1596.78
1813.53
24.52
25.01
24.42
22.17
21.58
32.32
38.17
41.52
4167.82
3664.49
4366.34
4587.91
5513.46
8006.78
8392.70
8720.67
533.87
419.62
412.35
394.51
327.53
489.42
526.59
537.42
43.69
46.87
49.02
48.47
47.13
77.14
89.52
97.05
1.31
0.55
1.40
0.59
0.96
15.57
15.65
15.65
1280.22
1473.82
1540.02
1440.86
1730.18
2343.35
2606.44
2968.30
695.90
727.84
702.16
690.10
875.16
1146.52
1251.79
1448.03
17.04
20.58
8.02
1.67
1.89
31.67
39.76
45.36
Industrial Colonies
1.16
1.56
1.76
2.33
1.40
2.50
2.61
2.89
Seasonal Industries
0.00
23.12
24.45
36.06
40.95
59.05
65.03
72.83
Time of Day Tariffs (6 PM to 10 PM)
0.00
76.21
107.29
70.24
117.14
175.69
203.40
235.28
HT I (B): Ferro Alloy Units
2.68
0.00
0.00
0.00
0.00
0.00
0.00
0.00
292.89
311.54
335.93
292.28
304.15
377.31
447.77
514.95
Time of Day Tariffs (6 PM to 10 PM)
0.00
0.00
0.00
55.89
58.75
78.31
91.90
106.35
HT III: Aviation & Stations
0.00
0.00
0.00
1.28
7.22
14.59
17.32
19.05
Time of Day Tariffs (6 PM to 10 PM)
0.00
0.00
0.00
0.00
1.33
3.28
3.21
3.60
22.76
17.26
40.41
19.32
27.09
88.38
86.60
86.65
HT IV Agriculture
0.00
0.54
9.79
0.31
0.00
23.95
17.55
17.90
HT IV CPWS
0.00
2.39
0.69
10.10
16.23
24.75
39.75
47.41
47.55
51.03
33.99
26.53
21.39
33.04
37.80
39.60
HT VII: Green Power
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
HT VIII: Temporary
0.80
0.00
0.00
0.00
0.08
0.00
0.00
0.00
Cottage Industries, Dhobighats& Others
Irrig& Agriculture
Local Bodies, St. Lighting & PWS
General Purpose
Temporary Supply
HT Category at 11 kv
HT I (A): General
Lights and Fans
HT II: Others
HT IV Government LIS
HT VI: Townships & Residential Colonies
APSPDCL
Page 78
Category
2009-10
2010-11
2011-12
2012-13
2013-14
2015-16
2016-17
(Proj.)
(Proj.)
2014-15
199.44
241.74
275.53
234.74
257.40
284.31
301.96
328.40
HT Category at 33 kv
1279.98
1817.55
2076.16
1987.56
2135.81
3264.72
3749.95
4254.90
HT I (A): General
1179.48
1482.15
1625.99
1652.33
1728.35
2405.91
2766.85
3154.29
Lights and Fans
5.65
6.21
3.01
0.60
0.48
32.09
40.59
46.27
Industrial Colonies
2.29
4.59
7.07
9.34
7.26
11.20
11.44
13.05
Seasonal Industries
0.00
33.28
27.73
34.88
33.83
45.39
47.13
53.73
Time of Day Tariffs (6 PM to 10 PM)
0.00
159.51
251.28
156.71
220.51
393.86
486.18
554.26
HT I (B): Ferro Alloy Units
49.36
83.66
105.52
55.63
65.77
230.75
220.14
237.75
HT II: Others
35.54
40.91
43.67
60.83
62.18
67.62
77.72
89.48
Time of Day Tariffs (6 PM to 10 PM)
0.00
0.00
0.00
9.90
11.28
13.32
15.71
18.08
HT III: Aviation & Stations
0.00
0.00
0.00
0.00
0.00
0.00
0.99
0.99
Time of Day Tariffs (6 PM to 10 PM)
0.00
0.00
0.00
0.00
0.00
0.00
0.06
0.06
HT IV Government LIS
6.61
6.53
10.16
5.58
5.38
37.70
39.35
39.38
HT IV Agriculture
0.00
0.00
0.26
0.00
0.00
10.20
9.81
10.00
HT IV CPWS
0.00
0.72
0.00
0.95
0.00
15.25
32.02
35.40
HT VI: Townships & Residential Colonies
1.05
0.00
1.48
0.82
0.77
1.44
1.97
2.17
HT VII: Green Power
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
HT VIII: Temporary
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Category: RESCOs
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
1168.87
1433.44
1820.88
1792.94
1976.53
3490.59
3783.85
5644.24
640.23
825.77
1109.07
1036.33
1107.02
1914.08
2112.03
2407.78
Lights and Fans
0.82
2.13
0.58
0.81
0.50
15.41
24.78
28.25
Industrial Colonies
5.66
5.36
5.96
10.01
5.81
12.38
13.92
15.87
Seasonal Industries
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Time of Day Tariffs (6 PM to 10 PM)
0.00
78.78
135.73
87.44
119.84
317.23
388.01
442.34
HT I (B): Ferro Alloy Units
0.00
0.00
0.00
44.74
86.78
138.77
144.95
156.55
HT II: Others
0.00
0.00
0.00
3.42
8.85
14.25
18.78
21.60
Category: RESCOs
HT Category at 132 kv
HT I (A): General
APSPDCL
Page 79
Category
2009-10
2010-11
2011-12
2012-13
2013-14
2015-16
2016-17
(Proj.)
(Proj.)
2014-15
Time of Day Tariffs (6 PM to 10 PM)
0.00
0.00
0.00
0.54
1.58
2.50
3.30
3.80
HT III: Aviation & Stations
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Time of Day Tariffs (6 PM to 10 PM)
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
HT IV Government LIS
0.00
0.00
0.00
0.00
0.00
328.13
309.28
1737.17
HT IV Agriculture
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
HT IV CPWS
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
522.15
521.40
569.54
609.65
646.15
747.84
768.79
830.88
HT VI: Townships & Residential Colonies
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
HT VII: Green Power
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
HT VIII: Temporary
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Category: RESCOs
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
13697.27
14441.24
16388.21
16444.85
18024.46
26361.53
29484.53
33809.49
HT V: Railway Traction
Total (LT + HT)
5.2
Revenue from Current Tariffs
APSPDCL
Page 80
The computation of revenue at current tariff for FY 2015-16 and FY 2016-17 for each
customer category is carried out as follows:
Revenue from Tariffs =
Energy Estimate * Approved Energy Charges … ……………………..……….. (a)
+ Demand Estimate * Approved Demand Charges …….……………………..... (b)
+ Incremental Revenue on account of Monthly Minimum Charges (‘MMC’) … (c)
+ Customer Charges (d)
+ Other Charges ----- (e)
Energy charges:
For customer categories having telescopic energy tariffs, the energy estimates have been
apportioned into the slabs and then have been multiplied with the corresponding slab tariff.
The apportionment has been based on the historical break up of telescopic consumption into
the various slabs as captured in the billing information database. The energy charges are
calculated as per the billing parameters i.e., KWH and KVAH for the category and the
existing tariff rates of that category
Demand/Fixed Charges: The estimate of demand has been made in “HP” or in “MVA” as
the case maybe. Billing demand has been assumed to grow in proportion to the growth of
sales in FY 2016-17. Additional demand due to additional load has been added to arrive at
final demand for the year FY 2016-17.
Monthly Minimum charges (MMC): The ‘incremental’ revenue due to MMC for each
category is the difference between cost of units recorded and computed units billed at the
relevant tariff in respect of HT categories. In respect of LT categories, it is the difference
between the cost of units recorded and monthly minimum charges notified in the tariff order.
Customer Charges: Customer charges are as approved in tariff Order for each of the
category of consumers. As per the revised regulatory formats income from customer charges
is considered as part of revenue from tariffs.
Other Charges: These are the charges other than the above charges. There are no “other
charges” proposed for FY 2016-17.
Based on the above approach, the gross revenue (excl. NTI) for FY 2015-16 is expected
to be Rs 12117.14 Cr, while that for FY 2016-17 is expected to be Rs 14493.43 Cr. The NTI
APSPDCL
Page 81
for FY 2015-16 is Rs. 76.34 Crs., while for FY 2016-17 NTI isRs. 79.33 crores. The table
below provides the category-wise revenue for FY 2015-16 and FY 2016-17:
Category-wise revenue (Excl NTI) (Form-5)
Category
LT Category
Domestic
Non-domestic/Commercial
Industrial
Cottage Industries, Dhobighats& Others
Irrig& Agriculture
Local Bodies, St. Lighting & PWS
General Purpose
Temporary Supply
HT Category at 11 kv
HT I (A): General
Lights and Fans
Industrial Colonies
Seasonal Industries
Time of Day Tariffs (6 PM to 10 PM)
HT I (B): Ferro Alloy Units
HT II: Others
Time of Day Tariffs (6 PM to 10 PM)
HT III: Airports, Bus Stations and Railway Stations
Time of Day Tariffs (6 PM to 10 PM)
HT IV Government LIS
HT IV Agriculture
HT IV CPWS
HT VI: Townships & Residential Colonies
HT VII: Green Power
HT VIII: Temporary
Category: RESCOs
HT Category at 33 kv
HT I (A): General
Lights and Fans
Industrial Colonies
Seasonal Industries
Time of Day Tariffs (6 PM to 10 PM)
APSPDCL
(Rs. Crores)
2015-16
5487.86
2537.19
1465.43
1043.78
15.54
59.10
289.88
61.45
15.50
1835.32
1004.12
23.94
1.56
47.14
143.80
0.00
413.67
76.28
14.31
2.56
49.33
9.90
18.39
23.09
0.00
0.00
7.25
2434.81
1811.41
22.61
6.82
31.06
321.85
2016-17
6185.36
2925.69
1622.52
1180.39
16.42
62.82
295.57
66.44
15.50
2106.73
1162.46
27.31
1.72
52.80
166.34
0.00
475.54
88.27
15.57
2.86
49.31
10.10
22.37
24.18
0.00
0.00
7.88
2765.26
2065.01
25.77
7.78
35.40
366.92
Page 82
Category
HT I (B): Ferro Alloy Units
HT II: Others
Time of Day Tariffs (6 PM to 10 PM)
HT III: Airports, Bus Stations and Railway Stations
Time of Day Tariffs (6 PM to 10 PM)
HT IV Government LIS
HT IV Agriculture
HT IV CPWS
HT VI: Townships & Residential Colonies
HT VII: Green Power
HT VIII: Temporary
Category: RESCOs
HT Category at 132 kv
HT I (A): General
Lights and Fans
Industrial Colonies
Seasonal Industries
Time of Day Tariffs (6 PM to 10 PM)
HT I (B): Ferro Alloy Units
HT II: Others
Time of Day Tariffs (6 PM to 10 PM)
HT III: Airports, Bus Stations and Railway Stations
Time of Day Tariffs (6 PM to 10 PM)
HT IV Government LIS
HT IV Agriculture
HT IV CPWS
HT V: Railway Traction
HT VI: Townships & Residential Colonies
HT VII: Green Power
HT VIII: Temporary
Category: RESCOs
Total (LT + HT)
2015-16
115.14
69.30
12.00
0.80
0.04
22.25
5.53
14.77
1.23
0.00
0.00
0.00
2359.14
1323.30
12.76
8.30
0.00
240.56
69.72
14.00
2.44
0.00
0.00
174.46
0.00
0.00
513.60
0.00
0.00
0.00
0.00
12117.14
2016-17
124.36
79.78
13.82
0.80
0.04
22.25
5.64
16.34
1.35
0.00
0.00
0.00
3436.09
1508.76
14.55
9.46
0.00
274.25
75.31
16.09
2.80
0.00
0.00
979.79
0.00
0.00
555.08
0.00
0.00
0.00
0.00
14493.43
5.3 Detailed category wise Revenue computation
The detailed category wise computation of revenue is as follows.
APSPDCL
Page 83
5.3.1
Low Tension Categories
5.3.1.1 LT I: Domestic Category
At present, domestic consumers are billed on the basis of monthly consumption only. The
licensee submits that the existing tariff structure has the following drawbacks:

Tariff shock observed by consumers on the verge of moving from one slab to another:
Consumption in Units
Category
Bill in Rs / month
100
Category I (B)
233
101
Category I (C)
300
200
Category I (C)
667
201
Category I (D)
877
Additional Charge for
extra unit in Rs
66
210

Tariff is dynamic based on consumption during the month. Consumers can not be
designated with any sub-cateogry of Domestic due to non-static consumption of a
consumption.

Tariffs are independent of affordability / income level of consumers: Under the existing
tariff regime, high-income consumers are likely to enjoy concessional tariffs intended
for low-income consumers, in case their consumption during any month is reduced. Exif a consumer having an average consumption of 200 units/month consumes 30
units/month will be charged at 1.45 / unit.

Non requirement of sub-category LT I(A) in presence of LT (B).
Considering above, the licensee would like to propose simplied tariff structure of Domestic
category by grouping consumers, with no tariff change, based on certain conditions as shown
below:

Group A: Domestic consumers with annual consumption upto 600 Units ( upto 50
units/ month)

Group B: Domestic consumers with annual consumption greater than 600 Units
and upto 2,400 Units

Group C: Domestic consumers with annual consumption more than 2,400 Units
and all three-phase consumers
Grouping of domestic consumers will be done based on annual consumption of FY
2015-16 during the start of FY 2016-17 and will continue to be in the same group till
the annual threshold limits stipulated above.
In case of a new consumer, the following rules will be applicable

APSPDCL
Group A - if a consumer is Domestic consumers
Page 84
.The existing tariff structure is as under:
Existing Category / Slab Structure
(Units)
Energy charge (Rs./Unit)
LT I (A): Upto 50 Units/Month
1.45
LT I (B): Above 50 Units/Month and Up to 100 Units/Month
<50
1.45
51-100
2.60
LT I (C): Above 100 Units/Month and Up to 200 Units/Month
<50
2.60
51-100
2.60
101-150
3.60
151-200
3.60
<50
2.60
51-100
3.25
101-150
4.88
151-200
5.63
201-250
6.70
251-300
7.22
301-400
7.75
401-500
8.27
>500
8.80
LT I (D): Above 200 Units/Month
The licensee proposes a simplified tariff structure with grouping, with no change in in tariff,
as under:
Proposed Category / Slab Structure
(Units)
Energy charge
(Rs./Unit)
Group A: Domestic consumers with annual consumption < = 600
Units
0-50
1.45
51-100
2.60
101-200
3.60
APSPDCL
Page 85
Above 200#
6.90
Group B: Domestic consumers with consumption ( < =2400 and >
600 units)
0-50
2.60
51-100
2.60
101-200
3.60
201-300
6.90
Above 300
7.75
Group C: Domestic consumers with annual consumption >2400
units
0-50
2.60
51-100
3.25
101-200
5.26
201-300
6.90
301-400
7.75
401-500
8.27
Above 500 units
8.80
# computed average existing tariff for a consumer whose consumption is > 200 but < 300
units
Estimated revenue for FY 2015-16 & FY 2016-17 are submitted below:
Year
2015-16
2016-17
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs
crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue
from Tariff
(Rs
crores)
2231.56
2600.28
0.00
0.00
66.84
68.18
238.79
257.23
0.00
0.00
2537.19
2925.69
Based on the above the total revenue estimate for the category is Rs.2537.19 Crores for
2015-16 and Rs.2925.69 Crores for 2016-17.
5.3.1.2 LT II: Non-Domestic & Commercial Category
Slab-wise Breakup of Revenue
APSPDCL
Page 86
The incremental revenue due to the impact of the monthly minimum charges over and
above the revenue from stated tariff rates in shown below.
Revenue from Tariffs
Year
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue
from Tariff
(Rs crores)
2015-16
2016-17
1356.20
1509.94
69.07
71.20
13.23
13.62
26.94
27.76
0.00
0.00
1465.43
1622.52
Based on the above the total revenue estimate for the category is Rs.1465.43 Crores
for 2015-16 and Rs.1622.52 Crores for 2016-17.
5.3.1.3 LT III : Industrial (Normal & Optional) Category
Due to very different tariff structures between Pisciculture/ Prawn culture and nonpisciculture units, the revenue computation has been done separately for the two subcategories and is shown below:
APSPDCL
Page 87
Energy
Charges
(Rs crores)
Sub-Cat
Industries
Seasonal Industries (off season)
2015-16
Demand
Minimum
/Fixed
Charges
charges
(Rs crores)
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs
crores)
Gross
Revenue
from Tariff
(Rs crores)
892.90
54.23
0.00
3.45
0.00
950.58
0.00
0.00
0.00
0.00
0.00
0.00
1.15
0.01
0.00
0.00
0.00
55.39
2016-17
55.86
0.00
1.19
0.01
0.00
0.00
0.00
57.05
0.00
0.00
0.00
0.00
0.00
0.00
0.71
0.00
0.00
0.00
0.00
4.16
0.00
0.00
0.00
0.00
0.00
0.00
92.95
0.24
0.00
0.00
0.00
1043.78
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
3.56
0.00
0.71
0.00
0.00
0.00
0.00
4.28
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
1078.02
0.00
102.11
0.27
0.00
0.00
0.00
1180.39
Pisciculture/Prawn culture
Sugarcane crushing
Poultry farms
Mushroom and Rabbit farms
Floriculture in Green House
Total
91.09
0.23
0.00
0.00
0.00
984.23
Industries
Seasonal Industries (off season)
Pisciculture/Prawn culture
Sugarcane crushing
Poultry farms
Mushroom and Rabbit farms
Floriculture in Green House
Total
1018.60
0.00
100.21
0.26
0.00
0.00
0.00
1119.06
The total revenue estimate for the category is Rs 1043.78 Crores for 2015-16 and Rs.1180.39
Crores for 2016-17.
5.3.1.4 LT IV: Cottage Industries &Dhobighat Category
Year
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue
from Tariff
(Rs crores)
2015-16
2016-17
14.31
15.57
0.83
0.46
0.00
0.00
0.39
0.40
0.00
0.00
15.54
16.42
The total revenue estimate for the category is Rs 15.54 Crores for 2015-16 and
Rs.16.42 Crores for 2016-17.
5.3.1.5 LT V: Agriculture Category
The revenue from agricultural category has been computed with reference to each
subcategory. Agricultural consumers following DSM measures with less than or equal to
APSPDCL
Page 88
three service connections or agricultural consumers having agricultural land less than or
equal to 2.5 acres are eligible for free power. The other subcategories come under paying
category. The revenue computation from the category is given below:
Energy Charges
(Rs. Crs.)
Category V - Irrigation and Agriculture
Category V (A) - Agriculture (DSM)
Corporate Farmers & IT Assesses
Wet Land Farmers (Holdings >2.5 acre)
Dry Land Farmers (Connections > 3 nos.)
Wet Land Farmers (Holdings <= 2.5 acre)
Dry Land Farmers (Connections <= 3 nos.)
Category V (B) - Agriculture (Non-DSM)
Corporate Farmers & IT Assesses
Wet Land Farmers (Holdings >2.5 acre)
Dry Land Farmers (Connections > 3 nos.)
Wet Land Farmers (Holdings <= 2.5 acre)
Dry Land Farmers (Connections <= 3 nos.)
Category - V (C) - Others
Category V(A)(i) Salt Farmers
Category V(A)(ii) Rural Horticulture Nurseries
Total
2015-16
2016-17
57.93
7.41
5.23
1.90
6.51
36.88
1.17
0.39
0.68
0.08
0.01
0.01
0.00
0.00
0.00
59.10
61.63
7.70
5.42
1.98
6.98
39.56
1.19
0.40
0.69
0.08
0.01
0.01
0.00
0.00
0.00
62.82
Based on the above computations the gross revenue from agricultural category is
Rs.59.10 Crores for FY 2015-16 and Rs.62.82 Crores for FY 2016-17.
5.3.1.6 LT VI: Street Lighting & PWS Category
2015-16
Sub-Cat
Street Lighting
PWS Scheme
NTR SujalaPadhakam
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue
from Tariff
(Rs crores)
108.78
169.03
0.26
2.36
6.54
0.00
0.00
0.00
0.00
1.66
1.25
0.00
0.00
0.00
0.00
112.80
176.82
0.26
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue
from Tariff
(Rs crores)
2016-17
Sub-Cat
APSPDCL
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Page 89
Street Lighting
PWS Scheme
NTR SujalaPadhakam
110.96
172.41
0.39
2.67
6.60
0.00
0.00
0.00
0.00
1.67
1.26
0.00
0.00
0.00
0.00
115.30
180.27
0.39
The total revenue estimate for the category is Rs.289.88 Crores for 2015-16 and
Rs.295.96 Crores for 2016-17.
5.3.1.7 LT VII: General Purpose Category
Year
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue from
Tariff
(Rs crores)
2015-16
2016-17
59.79
64.88
0.13
0.16
1.15
1.18
0.39
0.23
0.00
0.00
61.45
66.44
The total revenue estimate for the category is Rs.61.45 Crores for 2015-16 and
Rs.66.44 Crores for 2016-17
5.3.1.8 LT VIII: Temporary supply Category
Year
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue from
Tariff
(Rs crores)
2015-16
2016-17
15.50
15.50
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
15.50
15.50
The total revenue estimate for the category is Rs.15.50 Crores for 2015-16 and
Rs.15.50 Crores for 2016-17.
5.3.2
High Tension Categories
5.3.2.1 HT Cat-I: Industrial
2015-16
APSPDCL
Page 90
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Total
970.01
2038.60
1419.04
4427.65
232.40
266.67
232.90
731.97
11 KV
33 KV
132 KV
Total
1119.89
2317.15
1613.57
5050.61
268.82
304.00
265.51
838.33
Voltage
11 KV
33 KV
132 KV
Minimum
Charges
(Rs crores)
14.21
3.20
2.59
20.00
2016-17
17.86
3.66
3.14
24.66
3.94
0.42
0.11
4.47
0.00
0.00
0.00
0.00
Gross
Revenue
from Tariff
(Rs crores)
1220.56
2308.89
1654.64
5184.09
4.06
0.43
0.11
4.60
0.00
0.00
0.00
0.00
1410.64
2625.24
1882.33
5918.21
Customer
Charges
(Rs crores)
Others
(Rs crores)
Based on the above the total revenue estimate for the category is Rs.5184.09 Crores for
2015-16 and Rs.59188.21 Crores for 2016-17.
5.3.2.2 HT Cat-II: Others
2015-16
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
11 KV
33 KV
132 KV
Total
400.91
63.22
14.33
478.46
85.04
18.01
2.08
105.13
11 KV
33 KV
132 KV
Total
461.61
72.78
16.48
550.87
97.79
20.73
2.39
120.92
Voltage
Minimum
Charges
(Rs crores)
2.26
0.02
0.00
2.28
2016-17
2.58
0.02
0.00
2.60
1.75
0.06
0.02
1.83
0.00
0.00
0.00
0.00
Gross
Revenue
from Tariff
(Rs crores)
489.95
81.30
16.44
587.69
1.83
0.06
0.02
1.91
0.00
0.00
0.00
0.00
563.81
93.60
18.90
676.31
Customer
Charges
(Rs crores)
Others
(Rs crores)
Based on the above consumption the total revenue estimate for the category is
Rs.587.69 Crores for 2015-16 and Rs.676.31 Crores for 2016-17.
5.3.2.3 HT Cat-III : Aviation activity at Airports
APSPDCL
Page 91
Year
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue
from Tariff
(Rs crores)
2015-16
2016-17
15.19
16.69
2.47
2.54
0.00
0.00
0.05
0.05
0.00
0.00
17.71
19.28
Based on the above consumption the total revenue estimate for the category is Rs.17.71
Crores for 2015-16 and Rs.19.28 Crores for 2016-17.
5.3.2.4 HT Cat- IV: Irrigation & Agriculture
2015-16
Voltage
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
11 KV
33 KV
132 KV
Total
77.07
42.49
174.43
293.99
0.00
0.00
0.00
0.00
11 KV
33 KV
132 KV
Total
80.82
44.17
979.77
1104.75
0.00
0.00
0.00
0.00
Minimum
Charges
(Rs crores)
0.55
0.06
0.02
0.63
0.00
0.00
0.00
0.00
Gross
Revenue
from Tariff
(Rs crores)
77.61
42.55
174.46
294.62
0.57
0.06
0.02
0.65
0.00
0.00
0.00
0.00
81.39
44.23
979.79
1105.41
Customer
Charges
(Rs crores)
0.00
0.00
0.00
0.00
2016-17
0.00
0.00
0.00
0.00
Others
(Rs crores)
The total revenue estimate for the category is Rs.294.62 Crores for 2015-16 and
Rs.1105.41 Crores for 2016-17.
5.3.2.5 HT Cat-V: Railway Traction
Year
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue
from Tariff
(Rs crores)
2015-16
2016-17
513.55
555.02
0.00
0.00
0.00
0.00
0.05
0.05
0.00
0.00
513.60
555.08
The total revenue estimate for the category is Rs 513.60 Crores for 2015-16 and
Rs.555.08 Crores for 2016-17.
5.3.2.6 HT Cat -VI: Township & Residential Colonies
2015-16
APSPDCL
Page 92
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
11 KV
33 KV
132 KV
Total
22.53
1.18
0.00
23.70
0.51
0.04
0.00
0.55
0.05
0.01
0.00
0.06
0.00
0.00
0.00
0.00
23.09
1.23
0.00
24.32
11 KV
33 KV
132 KV
Total
23.60
1.29
0.00
24.90
0.52
0.04
0.00
0.56
0.00
0.01
0.00
0.01
2016-17
0.00
0.01
0.00
0.01
0.05
0.01
0.00
0.06
0.00
0.00
0.00
0.00
24.18
1.35
0.00
25.52
Voltage
Gross Revenue
from Tariff
(Rs crores)
Others
(Rs crores)
The total revenue estimate for the category is Rs 24.32 Crores for 2015-16 and
Rs.25.52 Crores for 2016-17.
5.3.2.7 HT Cat-VII : Green Power
There in no existing services
5.3.2.8 HT Cat-VIII : RESCOs
Year
Energy
Charges
(Rs crores)
Demand /Fixed
charges
(Rs crores)
Minimum
Charges
(Rs crores)
Customer
Charges
(Rs crores)
Others
(Rs crores)
Gross
Revenue
from Tariff
(Rs crores)
2015-16
2016-17
7.25
7.88
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
7.25
7.88
The total revenue estimate for the category is Rs 7.25 Crores for 2015-16 and Rs.7.88 Crores
for 2016-17.
The estimated revenue gap for the licensee for FY 2016-17 is as follows:
Form-9
Particulars
Aggregate Revenue Requirement (Rs. Crs.)
Total Revenue
Revenue Deficit (-) / Surplus (+) at Current Tariffs (Rs. Crs.)
Revenue Changed through Proposed Tariff
Government Subsidy Envisaged
Net Deficit/Surplus (Rs. Crs.)
6
FY 2016-17
18920.15
14572.76
-4347.39
488.35
3859.04
0.00
Performance Parameters
APSPDCL
Page 93
The details as required by the APERC as per the fresh directive (1) in the Retail supply Tariff
order 2009-10 are given below:
6.1.1
Compensation paid by the licensee to consumers for deficiency of service as per
the Regulations of the Commission
S.N
o
1
CG No. & Date
Compensation awarded for FY 2014-15 (Apr'14 to Mar'15)
compensatio
Date of
Circle
n awarded in
Orders
Rs.
1/2014-15, 01-04-14
Nellore
25-06-14
Brief Remaks
Rs. 1700 /-
Delay of 17 days in releasing of
additional load of 2HP to ASC No.83 of
DavaraVamuru Section, Gudur Section
2
30/2014-15, 23-05-14
Ongole
30-08-14
Rs. 4500 /-
Delay of 45 days in resolving the low
voltage problem inrespect of Sri
P.RaheemBasha, Indira Colony, Kanigiri
division
3
43/2014-15, 23-05-14
Ongole
26-06-14
Rs. 11700 /-
Delay of 117 days in releasing of new
domestic service to Sri G. Manohar
Reddy, Kanigiri division
4
46/2014-15, 31-05-14
Ongole
26-06-14
Rs. 100 /-
Delay of 2 days in revision of bill
inrespect of Smt. V. Sreelakshmi, Ongole
5
50/2014-15, 06-06-14
Vijayawada
30-08-14
Rs. 10800 /-
Delay of 108 days in releasing of new
non domestic service to Sri V.P.V. Rama
Krishna, M.G.Road, Vijayawada
6
64/2014-15, 18-07-14
Kurnool
01-09-14
Rs. 6000 /-
Delay of 60 days in releasing of new
service to Sri M. Vishnu Vardhan Reddy
of Kurnool
Compensation awarded for FY 2015-16 (Apr'15 to Sep'15)
1
196/2014-15, 12-02-15
Guntur
06-05-14
Rs. 7500 /-
Abnormal delay of 120 days in resolving
the billing complaint against Sc.No.1155
of Chilakaluripet, Guntur
2
202/2014-15, 23-02-15
Nellore
21-08-15
Rs. 17500 /-
70 days delay in resolving low voltage
problem for 5 consumers at the rate of
Rs.50/- per day
3
133/2015-16, 11-06-15
Guntur
31-08-15
Rs. 12800 /-
128 days delay in releasing the industrial
service (Aqua culture) at the rate of
Rs.100/- per day
APSPDCL
Page 94
6.1.2
Details of electrical accidents and ex-gratia paid during FY 2014-15 and FY 201516Accidents :
2014-15 (Non-Departmental)
S.No
Circle
1
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
Anantapur
Kurnool
Total
2
3
4
5
6
7
8
Human
NonFatal
fatal
27
11
15
6
12
9
90
58
228
4
0
6
2
2
2
12
5
33
Animal
NonFatal
fatal
18
23
9
5
2
6
13
25
101
0
0
0
0
0
0
0
0
0
2015-16 (upto Sep'15)
(Non-Departmental)
Human
Animal
NonNonFatal
Fatal
fatal
fatal
20
6
9
5
5
16
45
56
162
5
0
0
5
3
2
6
14
35
28
24
8
3
3
4
11
79
160
0
1
0
1
0
0
0
0
2
Ex-gratia Paid
2014-15
2015-2016 (upto Sep, 2015)
Animal
(Nos.)
Amount
(Rs.)
Human
(Nos.)
Amount
(Rs.)
Animal
(Nos.)
Amount
(Rs.)
Human
(Nos.)
Amount
(Rs.)
Anantapur
Kurnool
8
11
11
20
1
0
2
0
1,83,000
212000
340000
400000
20000
0
40000
0
13
5
21
1
3
1
11
1
28,50,000
900000
200000
200000
600000
200000
2200000
200,000
7
5
9
21
1
0
0
0
3,47,000
100000
346000
446000
200000
0
0
0
10
2
11
23
0
5
3
0
22,00,000
400000
200000
600000
0
1000000
600000
0
SPDCL
53
1012000
56
4500000
43
1092000
54
2800000
Circle
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
6.1.3
APSPDCL
Replacement of burnt transformers, installation of additional transformers.
Page 95
2014-15
S.No.
1
2
3
4
5
6
7
8
Circle
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
Anantapur
Kurnool
Total
6.1.4
2015-16 (upto Sep'15)
Total
No. of
DTRs
Failed
Replacement
of failed
transformers
Installation of
additional
transformers
Total
No. of
DTRs
Failed
Replacement
of failed
transformers
Installation of
additional
transformers
2099
2719
4843
4367
7251
5378
6712
4859
38228
2099
2719
4843
4367
7251
5378
6712
4859
38228
3418
3557
18637
5469
2216
2279
3650
2200
41426
1495
1767
2634
2469
4033
3335
4633
2561
22927
1495
1767
2634
2469
4033
3335
4633
2561
22927
1782
2002
1934
1384
943
6528
2224
1295
18092
Number of burnt-out, non-functioning or faulty meters (Circle-wise).
Circle
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
Anantapur
Kurnool
Total
Circle
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
Anantapur
Kurnool
Total
Burnt meters for FY 2014-15
Defective as on
Defective during
Replaced during
Defective as on 3103-2015
1/4/2014
2014-2015
2014-2015
1 Ph 3 Ph
Total
1 Ph 3 Ph
Total
1 Ph 3 Ph
Total 1 Ph 3Ph Total
15
6
4126 1899
4130 1900
11
5
21
6025
6030
16
49
9
93
16
58 17581 2161
19742 17537 2154
19691
109
1735
42
5005
391
3544
296
1777
5396
3840 3196 137
3333
84
58
262
6045
6165
142
186
76
4231 1814
4333 1832
0
0
2405
673
2405
673
0
0
0
3078
3078
0
137
0
5264
262
5130
262
271
0
137
5526
5392
271
39
0
2970
748
2900
745
109
3
39
3718
3645
112
117
50
2905 1058
2961 1097
61
11
167
3963
4058
72
2278
183
2461 44487 9006
53493 42940 8959
51899 3825 230
4055
Burnt meters for FY 2015-2016 (upto Sep, 2015)
Defective as on
Defective during
Replaced during
Defective as on 302015-2016 (upto
2015-2016 (upto
09-2015
1/4/2015
September 2015)
September 2015)
3
3
1 Ph
Total
1 Ph 3 Ph Total
1 Ph 3 Ph Total 1 Ph
Total
Ph
Ph
11
5
2162 1042
2160 1040
13
7
16
3204
3200
20
93
16
8692
382
8584
362
201
36
109
9074
8946
237
3196 137
1303
88
3784
126
715
99
3333
1391
3910
814
255
62
97
2131
1911
317
60
37
1416
715
1221
690
0
0
1218
257
1218
257
0
0
0
1475
1475
0
271
0
2991
59
3262
59
0
0
271
3050
3321
0
109
3
3150
433
3235
431
24
5
112
3583
3666
29
61
11
1360
496
1336
502
85
5
72
1856
1838
90
3801 209
4010 22292 3472
25764 24800 3467
28267 1293 214
1507
Stuck-up meters for FY 2014-15
APSPDCL
Page 96
Defective as on
Circle
1/4/2014
3 Ph
Total
1 Ph
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
Anantapur
Kurnool
Total
14
130
6219
3810
0
298
70
1644
12185
16
25
39
320
0
0
1
98
499
1 Ph
30
155
6258
4130
0
298
71
1742
12684
55578
117010
42856
44827
36506
42475
33043
29522
401817
Replaced during
2014-2015
3 Ph
Total
7340
7720
1160
4338
1648
598
1696
2152
26652
62918
124730
44016
49165
38154
43073
34739
31674
428469
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
Anantapur
Kurnool
Total
1 Ph
21
164
5984
3Ph
9
30
173
1761
0
368
280
623
9201
296
0
0
20
22
550
Total
30
194
6157
2057
0
368
300
645
9751
1 Ph
27342
63101
18309
3 Ph
3426
836
444
21933
15074
20950
23031
11721
201461
2465
990
225
921
1057
10364
Total
30768
63937
18753
24398
16064
21175
23952
12778
211825
Defective as on 31-032015
2014-2015
3 Ph
Total
1 Ph
55571
116976
43091
43984
36506
42405
32833
30543
401909
7347
7715
1026
4179
1648
598
1677
2228
26418
1 Ph
27352
62911
23655
3 Ph
3425
821
443
22682
15074
21297
23291
11487
207749
2511
990
225
938
1057
10410
1 Ph
21
164
5984
4653
0
368
280
623
12093
62918
124691
44117
48163
38154
43003
34510
32771
428327
Stuck-up meters for FY 2015-2016 (upto Sep, 2015)
Defective as on
Defective during
Replaced during
2015-2016 (upto
2015-2016 (upto
1/4/2015
September 2015)
September 2015)
Circle
6.1.5
Defective during
Total
30777
63732
24098
25193
16064
21522
24229
12544
218159
3 Ph
Total
9
30
173
479
0
0
20
22
733
30
194
6157
5132
0
368
300
645
12826
Defective as on
30-09-2015
1 Ph
11
354
638
1012
0
21
20
857
2913
3Ph
10
45
174
250
0
0
3
22
504
Total
21
399
812
1262
0
21
23
879
3417
Performance with regard to attending fuse-off calls.
1
Performance with regard to attending fuse-off calls
2014-15
2015-2016 (upto Sep, 2015)
Circle
With in the
With in the
Received
Received
stipulated time
stipulated time
Vijayawada
18598
18550
8654
8654
2
Guntur
12149
11698
6194
6085
3
Ongole
11826
11778
6942
6935
4
Nellore
21355
21328
11332
11332
5
Tirupati
11902
11635
3075
3001
6
Kadapa
14366
14301
6949
6949
7
Anantapur
58602
58475
56062
56021
56136
55702
45022
45022
204934
203467
144230
143999
S.No.
8
APSPDCL
Kurnool
APSPDCL
Page 97
6.1.6
Breakdowns and interruptions in power supply to urban and rural consumers
(Circle-wise) and time taken for restoration.
Break Downs : 2014-15
33KV
Circle
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
Anantapur
Kurnool
TOTAL
Interruption : 2014-15
11KV
LC
Nos
Duration
Nos
Duration
Nos
Duration
Nos
Duration
410
228
194
218
117
199
173
115
1570:17
1110:12
1246:15
1119:18
558:22
813:41
866:21
578:16
2769
2843
567
488
937
2590
716
416
9257:07
1110:12
1502:40
1119:18
3276:44
12646:36
2328:28
2327:42
310
286
99
165
6
173
77
837:05
688:23
200:02
446:45
10:59
303:40
111:36
3115
3476
3101
2542
2009
2462
960
1696
486:17
692:10
564:11
466:27
384:37
465:08
276:08
352:29
1654
7862:42
11326
33568:47
1116
2598:30
19361
3687:27
Break Downs : 2015-16
33KV
Circle
Vijayawada
Guntur
Ongole
Nellore
Tirupati
Kadapa
Anantapur
Kurnool
TOTAL
6.1.7
Interruption: 2015-16
11KV
Trippings
Nos
Duration
Nos
Duration
Nos
Duration
370
242
204
312
240
286
275
187
2116
1364:02
1276:20
1200:02
2639:50
1458:17
2137:02
2053:48
834:42
12964:03
2812
1717
364
160
1947
1854
1192
663
10709
5679:12
5147:36
1334:20
990:06
4316:30
11166:46
5831:56
4079:07
38545:33
2335
2475
2505
2231
1504
2127
1423
2028
16628
521:33
715:49
570:12
547:18
366:17
514:43
430:28
436:29
4102:49
Frequency and voltage at various levels of interface over the period.
Average
Hz.
49.94
49.97
49.92
49.93
49.92
49.95
49.96
50.00
49.98
50.00
50.00
49.99
49.96
Hz.
50.53
50.56
50.65
50.36
50.34
50.37
50.49
50.42
50.58
50.56
50.55
50.54
Date
20.4.14
30.05.14
12.06.14
23.07.14
26.08.14
01.09.14
02.10.14
16.11.14
15.12.14
01.01.15
17.02.15
01.03.15
Hz.
49.49
49.41
49.32
49.42
49.36
49.35
49.53
49.58
49.54
49.55
49.58
49.52
Date
26.04.14
20.05.14
27.06.14
25.07.14
01.08.14
09.09.14
07.10.14
27.11.14
30.12.14
15.01.15
17.02.15
03.03.15
Apr-15
49.99
50.55
25.04.15
49.50
07.04.15
May-15
Jun-15
Jul-15
Aug-15
Sep-15
Average 2015-16
49.98
50.01
49.99
49.97
49.94
49.98
50.55
50.53
50.33
50.27
50.33
19.05.15
13.06.15
26.07.14
12.08.15
20.09.15
49.19
49.56
49.56
49.55
49.36
24.05.15
26.06.15
28.07.15
03.08.15
04.09.15
Month
Apr-14
May-14
Jun-14
Jul-14
Aug-14
Sep-14
Oct-14
Nov-14
Dec-14
Jan-15
Feb-15
Mar-15
Average 2014-15
APSPDCL
Trippings
Max.
Min.
Page 98
6.1.8
Pending applications and connections released to different categories of
consumers
Category wise LT pending Applications in SPDCL During the year 2015-16 (upto 31.10.15)
Category
I
II
III
IV
V
VI(a)
VI(b)
VII
VIII
Total
Pending at the
beginning of the month
12384
2805
1268
97
89018
272
1535
153
103
107635
Received during the
month
150368
18462
1441
351
40585
545
1217
561
293
213823
2127
485
317
22
9340
87
347
31
69
12825
152926
18872
1473
297
38260
444
945
522
61
213800
4913
849
765
18
34052
149
714
104
2
94833
Deleted during the
month
Services released during
the month
Pending at the end of
the month
6.1.9
Arrears of consumers over Rs.50, 000 pending for over six months and details of
bad debts written off
Defaulters list of individual consumers (circle wise) whose arrears are more than
Rs.50,000/- as on 30-09-2015isdisplayed in APSPDCL website (www.apspdcl.in)
APSPDCL
Page 99
6.1.10 Court cases involving the Licensee
S.No
Petition No.
Name of the
Petitioner
Subject
Remarks
NCE Project–list of Court cases filed at APERC
1
R.P. No. 1 of 2009
in
O.P. No. 5 of 2009
M/s RPP Ltd
2
R.P. No. 2 of 2009
in
O.P. No. 5 of 2009
Small Hydro Power
Developers Association
3
R.P. No. 3 of 2009
in
O.P. No. 5 of 2009
4
R.P. No. 4 of 2009
in
O.P. No. 5 of 2009
5
R.P. No. 5 of 2009
in
O.P. No. 5 of 2009
6
R.P. No. 6 of 2009
in
O.P. No. 5 of 2009
R.P.No. 7 of 2009
in
O.P. No. 5 of 2009
7
8
O.P. 18 of 2013
9
O.P. No. 31 of
2013
M/s Sardar Power Ltd
M. Venu Gopal Rao
M/s Velagapudi Power
Generation Company Ltd,
Hyderabad
Punna Rao
1) SISMA
2) M/s Empee Power
Company (India) Ltd
3) M/s GSR Sugars Ltd
4) M/s KCP Sugar
Industrial Corporation Ltd
5) M/s Nizam Deccan
Sugar Ltd
M/s Matrix Power Private
Limited
M/s Hetero Wind power
Limited
M/s SLS Power Limited
10
O.P No. 27 of 2012
APSPDCL
Against orders passed by APERC
Dt. 31.3.2009in O.P. No. 5 of 2009
determining the tariff for NCE
Projects
Against orders passed by APERC
Dt. 31.3.2009in O.P. No. 5 of 2009
determining the tariff for NCE
Projects
Against orders passed by APERC
Dt. 31.3.2009in O.P. No. 5 of 2009
determining the tariff for NCE
Projects
Against orders passed by APERC
Dt. 31.3.2009in O.P. No. 5 of 2009
determining the tariff for NCE
Projects
Against orders passed by APERC
Dt. 31.3.2009in O.P. No. 5 of 2009
determining the tariff for NCE
Projects
Against orders passed by APERC
Dt. 31.3.2009in O.P. No. 5 of 2009
determining the tariff for NCE
Projects
APERC dismissed
review petition on
27.7.2013
Against orders passed by APERC
Dt. 31.3.2009in O.P. No. 5 of 2009
determining the tariff for NCE
Projects
APERC dismissed
review petition on
27.7.2013
Petition for determining of the
tariff to take effect on completion
of 10 years from the date of
commissioning of the project
Regarding evacuation policy,
wheeling charges and banking of
power generated by captive power
producers
Petition for determining of the
tariff to take effect on completion
of 10 years from the date of
commissioning of the project
APERC dismissed
review petition on
27.7.2013
APERC dismissed
review petition on
27.7.2013
APERC dismissed
review petition on
27.7.2013
APERC dismissed
review petition on
27.7.2013
APERC dismissed
review petition on
27.7.2013
Hearing on
9.11.2013
Hearing on
9.11.2013
Hearing on
9.11.2013
Page 100
S.No
1
2
3
4
1
2
Petition No.
Name of the
Petitioner
Remarks
NCE Project – list of Court cases filed at High court of AP
Against Ld Single Judge orders in
Writ Appeal Nos:
APTRANSCO &
W.P. No. 17344/2007 and batch
1255, 1285,1291,
DISCOMS
regarding provisions banking of
1293 of 2008
energy facility to NCE Developers
(APERC Regulation 2 of 2006)
To wheel the petitioners energy,
which was generated / banked or
remaining un-utilized/ un allocated
M/s Tirumala hydel power
Writ Petition No:
as at the end of December 2006 and
projects limited,
18553 of 2009
as at the end of December 2007 and
Chilakaluripet
as the end of December ‘2008 (
APERC Regulation 2 of 2006)
High court passed
interim order
directing into to
wheel power to
scheduled
consumers from
unutilized energy
from January 2010
High court passed
To wheel the petitioners energy,
interim order
which was generated / banked or
directing into to
remaining un-utilized/ un allocated
Writ Petition No:
M/s Akshay profiles ltd,
wheel power to
as at the end of December 2006 and
18554 of 2009
Chilakaluripet
scheduled
as at the end of December 2007 and
consumers from
as the end of December ‘2008
unutilized energy
(APERC Regulation 2 of 2006)
from January 2010
High court passed
To wheel the petitioners energy,
interim order
which was generated / banked or
directing into to
remaining un-utilized/ un allocated
Writ Petition No:
Trident Power Systems
wheel power to
as at the end of December 2006 and
18555 of 2009
Ltd, Hyderabad
scheduled
as at the end of December 2007 and
consumers from
as the end of December ‘2008
unutilized energy
(APERC Regulation 2 of 2006)
from January 2010
NCE Project – list of Court cases filed at Appellate Tribunal for Electricity, New Delhi
NIL
NCE Project – list of Court cases filed at Supreme Court of India
Against the Appellate Tribunal for
Civil Appeals Nos
Electricity, New Delhi orders date
M/s Jocil Ltd
3891-3892 of 2009
19.12.2008 in Appeal No. 92 & 38
of 2007
Civil
Appeal N0.
M/s Sitapuram Power
Against orders passed by Appellate
837 of 2011
Limited
Tribunal Appeal No. 8 of 2010
3
Civil Appeal Nos
5159 of 2005 &
5157 of 2005
M/s Sagar Sugars &
Allied Products Limited
4
Civil Appeal No.
1376 – 1385 of
2013
M/s SLS & others
APSPDCL
Subject
To consider COD of the plant from
the date of synchronization of the
plant without establishing the sugar
plant
Against Appellate Tribunal Order
dated 20.12.2012 with regards NCE
tariff cases in APERC order dated
20.3.2004
Still pending at
Supreme court
Still pending at
Supreme court
Still pending at
Supreme court
Still pending at
Supreme court
Page 101
6.1.11 Number of cases filed in respect of pilferage of power in various categories giving
comparative picture with respect to FY 2013-14& 2014-15 (upto Sep’14)
APSPDCL
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7 Retail Supply Business True-up for FY 2014-15& FY 2015-16
7.1
Filing for True-up by the Distribution Licensee
This filing is made by the Distribution Licensee, SOUTHERN POWER DISTRIBUTION
COMPANY OF ANDHRA PRADESH LIMITED (APSPDCL) under Clause 19, Pg 11
of the Andhra Pradesh Electricity Regulatory Commission ‘(Terms and Conditions for
Determination Of Tariff For Wheeling and Retail Sale of Electricity)’ Regulation No. 4
of 2005 and Clause 2, Pg 2 of the Andhra Pradesh Electricity Regulatory Commission
‘First Amendment to (Terms and Conditions for Determination of Tariff for Wheeling
and Retail Sale of Electricity) Regulation No. 1 of 2014, for corrections for
“uncontrollable” and “controllable” items and as well as sharing of gains/losses for FY
2013-14.
As per Andhra Pradesh Electricity Regulatory Commission (APERC) Regulation No. 4
of 2005, ‘Terms and Conditions for Determination of Tariff for Wheeling and Retail
Sale of Electricity’ –
“4. Controllable and Uncontrollable items of ARR:- The expenditure of the
Distribution Licensee considered as “controllable” and “uncontrollable” shall be as
follows:
ARR Item
Operation & Maintenance expenses
Distribution Business
“Controllable”/”Uncontrollable”
Controllable
Return on Capital Employed
Depreciation
Taxes on Income
Controllable
Controllable
Uncontrollable
Non-tariff income
Controllable
In addition to the above items the retail supply business shall include the following:
Retail Business
ARR Item
Cost of power purchase
APSPDCL
“Controllable”/”Uncontrollable”
Uncontrollable
Page 103
5. Pass-through of gains and losses on variations in “uncontrollable” items of ARR:The Distribution Licensee shall be eligible to claim variations in “uncontrollable”
items in the ARR for the year succeeding the relevant year of the Control Period
depending on the availability of data as per actuals with respect to effect of
uncontrollable items:
Provided that the Commission shall allow the financing cost on account of the time
gap between the time when the true-up becomes due and when it is actually allowed
and the corrections shall not be normally revisited.
6. Sharing of gains and losses on variations in “controllable” items of ARR:- The
Distribution Licensee in its annual filings during the Control Period shall present
gains and losses for each controllable item of the Aggregate Revenue Requirement.
A statement of gain and loss against each controllable item will be presented after
adjusting for any variations on account of uncontrollable factors.
7. For the purpose of sharing gains and losses with the consumers, only aggregate
gains or losses for the Control Period as a whole will be considered. The
Commission will review the gains and losses for each item of the ARR and make
appropriate adjustments wherever required:
Provided that for the first Control Period, insofar as the gains and losses from the
Retail Supply Business of the Distribution Licensee are concerned, these will be
shared with the consumers on yearly basis.”
“MAIN ITEMS OF ARR
The Aggregate Revenue Requirement of the Distribution Licensee, for each year of
the Control Period, shall contain the following items:
1. Cost of power for (Retail Supply Business alone)
2.Transmission charges (for Retail Supply Business alone)
3.Load dispatch charges;
4.Operation and maintenance expenses;
5.Return on capital employed;
6.Depreciation;
7.Taxes on Income;
8.Corrections for “uncontrollable” items and “controllable” items (indexed to
external parameters);
9.Any other relevant expenditure”
“4. The Distribution Licensee shall be entitled to recover or shall refund, as the case
may be, the charges on account of Fuel Surcharge Adjustment as approved by the
APSPDCL
Page 104
Commission from time to time, suo-motu or based on the filing made by the
Distribution Licensee, as the Commission may deem fit.”
“1. The Distribution Licensee shall be allowed to recover transmission and load
despatch charges payable to the Transmission Licensees (Central Transmission
Utility, State Transmission Utility etc.) and System Operators (Regional Load
Despatch Centre, State Load Despatch Centre etc.) for access to and use of the interstate transmission system, intra-state transmission system and availing load dispatch
services on long-term basis in accordance with the tariffs approved from time to time
by CERC and this Commission, as the case may be.
2. The Distribution Licensee shall also be allowed to recover the expenses, at the
approved level, pertaining to (a) use of transmission and load dispatch facilities
under short-term procurement of power for the Retail Supply Business; and (b)
wheeling charges for use of the distribution system of other Distribution Licensee for
procurement of power for the Retail Supply Business.”
As per Andhra Pradesh Electricity Regulatory Commission (APERC) Regulation No.
1 of 2014, ‘First Amendment to (Terms and Conditions for Determination of Tariff
for Wheeling and Retail Sale of Electricity)Regulation No. 4 of 2005’ –
“12.5 True-up for Retail Supply Business
a. The Distribution Licensee shall include the power purchase cost variation
over the previous year Power Purchase cost in the Tariff Order as expense
(in the event of incurring excess cost)/rebate (in case of cost saving) in the
ARR as special item with relevant details. To arrive the power purchase
cost variation, the least of the following power purchase quantity is to be
considered:
i)
Actual power purchase quantity procured by the Discoms for its
consumers.
ii) Power purchase quantity computed based on actual sales except LT
Agriculture sales. LT Agriculture sales will be limited to Tariff Order
quantity. These aggregated sales will be grossed up with approved
losses for the relevant year in the MYT orders.
b. Since the complete information of cost actually incurred relating to
previous year will not be available at the time of filing of ARR for a
particular tariff year, the Licensee may include provisional cost variation
for the previous year in ARR filings which will be subject to final correction
by the Commission as and when final accounts for that year become
available.
APSPDCL
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c. The Licensees shall also include in the ARR the amounts to be collected on
final basis being the difference between the cost incurred based on audited
annual accounts report and costs provisionally approved by the
Commission in the Tariff Order for the year immediately preceding the
previous year.”
The Amendment Regulation mentions about power purchase cost
variation. However, deviation in actual and approved ARR and revenue
arises because of variation in approved and actual agriculture sales, losses
and average realization besides variation in power purchase cost. If this is
not accounted for, it will result in the requirement of another Financial
Restructuring Plan on account of accumulation of losses.
Hence, this write-up explains the total truing up gap arising out of the deviations in
Aggregate Revenue Requirement components and revenue for the Retail Supply
Business for FY 2014-15.
7.2
True-up of Aggregate Revenue Requirements components & Gap from Retail
Business for FY 2014-15& FY 2015-16
2015-16
Particulars
2014-15
Approved
Revised
Estimate
Deviation
Transmission Cost
SLDC Cost
Distribution Cost
PGCIL Expenses
ULDC Expenses
Network and SLDC Cost
Power Purchase/Procurement Cost
478.70
19.86
1,481.60
217.12
6.89
2,204.17
12,217.29
654.10
21.05
2,153.24
211.10
9.71
3,049.20
654.10
21.05
2,153.24
211.10
9.71
3,049.20
12,672.00
13,468.63
0.00
0.00
-0.00
0.00
0.00
0.00
796.63
Interest on Consumer Security Deposits
Supply Margin
Other Cost
Supply Cost
Gross ARR
Revenue
Subsidy
Total Revenue (incl. Subsidy)
122.83
12.12
0.00
12,352.24
14,556.41
10,320.98
2,169.03
12,490.01
147.09
13.13
565.53
13,397.75
16,446.95
14,128.50
2,318.45
16,446.95
142.12
13.13
38.12
13,662.00
16,711.20
12,193.48
2,318.45
14,511.93
-4.97
-0.00
-527.41
264.25
264.25
-1,935.02
0.00
-1,935.02
Total Gap from Retail Business
-2,066.40
0.00
-2,199.27
-2,199.27
As shown in the table above, the total gap for Retail Supply Business is Rs -2066.40Crs for
FY 2014-15& Rs. -2199.27 Crs. for FY 2015-16.
APSPDCL
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7.3
Prayer
The Petitioner (Distribution Licensee) prays that the Hon’ble Commission may:
The Petitioner (Distribution Licensee) submits that as per the APERC Regulation 1 of
2014,APDISCOMS have to file for power purchase cost deviation of last two years. The
licensee has computed the revenue gap for FY14-15 and FY 15-16, but it has not added this
revenue deficit to the ARR for FY16-17 because the GoAP has given in principle approval to
UDAY scheme floated by GoI. As per UDAY scheme, GoAP will take over 75% of
DISCOM debt as on 30 September 2015 over two years - 50% of DISCOM debt will be
taken over in 2015-16 and 25% in 2016-17.DISCOM debt not taken over by GoAP will be
converted by the Banks / FIs into loans or bonds with interest rate notmore than the bank’s
base rate plus 0.1%. Alternately, this debt may be fully or partly issued by the DISCOM as
GoAP guaranteed DISCOM bonds at the prevailing market rates which shall be equal to or
less than bank base rate plus 0.1%. In view of the above, the licensee requests not to consider
the above trueup amounts (for FY 2014-15 & FY 2015-16) while determining the ARR /
revenue deficit for FY 2016-17.
APSPDCL
Page 107
8) Detailed Tariff Proposal for Retail Supply Business for FY 2016-17
Average Cost to Serve (CoS) for the FY 2015-16 as approved by the Hon’ble Commission for
the State was Rs 5.38/Unit. Whereas, revised average Cost to Serve (CoS) for the current year is
Rs 5.92/Unit. The Licensee estimates the Discom level CoS for the ensuing year i.e. FY 2016-17
is estimated to be at Rs. 5.60/Unit. This implies an increase of Rs. 0.22/ Unit (4.05 % increase)
when compared to approved average CoS for the previous year.
The Aggregate Revenue Requirement for both the Discoms combined for FY16-17 is projected
to be Rs.28,423 Crs. and the projected revenue at current tariffs including non-tariff income is
Rs.23,725 Crs. which results in a gap of Rs.5,148 Crs. Also, the average CPI inflation in India
was 5.41% year-on-year in November 2015. The licensee would like to propose a nominal
increase in the tariffs to meet the increased costs which is detailed below.
Gist of Tariff rationalization, Tariff Proposals and Revenue Impact:
Summary of tariff proposals are shown below.
I.
No tariff increase proposed for the following categories:

LT I Domestic

Group A consumers (all Domestic consumers with annual consumption less than or
equal to 600 units during last year)

Group B consumers (all Domestic consumers with annual consumption greater than
600 Units and less than 2,400 Units during last year)

LT IV (B) Agro Based Activity

LT V Agriculture

LT VI (C) NTR Sujala Padhakam

HT I (B) Energy Intensive Industries: With a view to enable rapid industrialization in the
State, the licensee would like to propose to extend concessional tariffs under HT I (B) to
other energy intensive industries in addition to Ferro-alloy units. The licensee would like to
propose to rename the category HT-I (B) Ferro Alloys to Energy Intensive Industries.
APSPDCL
Page 108
The following energy intensive industries shall be eligible for the concessional tariffs
offered under this renamed category:
II.

Ferro Alloy Units

PV Ingots & Cell Manufacturing

Poly-silicon industry

Aluminum industry
Tariff reduction proposed for following categories

Poultry farms*: As per G.O.Ms.No.49, dated 09.12.2013 it was suggested that the tariff
offered to poultry farms be equivalent to the average pooled power purchase cost. Further,
the licensee has received representations from poultry farmers for similar concessions.
In addition, all HT services which are being billed at HT I Industrial tariff shall be billed
at the same concessional tariff as LT services with the creation of a new sub category HT
I (C) Aquaculture and Animal Husbandry.
The licensee would like to propose the following tariffs:
Tariff Component
Existing
Proposed
5.63
3.75
53
21
Energy Charges (Rs. / Unit)
Demand Charges (Rs. / kW / month)
The revenue impact is Rs. 3.78 Cr for APSPDCL.

LT III Pisciculture & Prawn culture*: Associations from the Pisciculture and prawn
culture industry have submitted their request for concessional tariff at Rs. 3.75 / Unit to
Government of Andhra Pradesh with a view to keep these industries in AP competitive.
The Government has then directed APDISCOMs to consider providing concessional tariff
to these industries.
APSPDCL
Page 109
In addition, all HT services which are being billed at HT I Industrial tariff shall be billed
at the same concessional tariff as LT services with the creation of a new sub category HT
- I (C) Aqua-culture and Animal Husbandry.
The licensee would like to propose the following tariffs:
Tariff Component
Energy Charges (Rs. / Unit)
Demand Charges (Rs. / kW / month)
Existing
Proposed
4.63
3.75
21
21
The revenue impact is Rs. 38.74 Cr for APSPDCL.
* Keeping in view that the licensee is proposing same tariffs for LT III sub categories
Pisciculture/Prawn culture and Poultry farms, the licensee would like to propose a single
sub category for Pisciculture/Prawn culture and Poultry farms and the sub category may
be named as Aquaculture & Animal Husbandry.

Further, HT services for Poultry Farms, Pisciculture, Prawn culture and Dairy Farms shall
be billed under a new category HT I (C) Aquaculture & Animal Husbandry with the same
tariffs as proposed for LT services.

Tourism Infrastructure Projects: As per the Andhra Pradesh Tourism Policy 2015, all new
and existing Tourism Infrastructure Projects eligible as per the Policy including 3 star &
above Hotels shall be billed under HT III category. The licensee thus would like to propose
renaming of HT III category to HT III Public Infrastructure & Tourism which shall be
limited to Airports, Bus Stations, Railway Stations and eligible Tourism Infrastructure
Projects as per the Andhra Pradesh Tourism Policy 2015
III.
Tariff for HT IV (A) Govt. Lift Irrigation & Agriculture to be equal to Cost of Service (CoS).
IV.
Tariff increase for all other categories:

4% increase in Demand Charges, Energy Charges, Time of Day tariff

2.5% increase in Energy Charges for Domestic Group-C consumers

No change in other components of tariff – customer charges and minimum charges
APSPDCL
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V.
Billing demand for HT services: The licensee would like to propose that the billing demand
shall be the maximum demand recorded during the month or 90% of the contracted demand,
whichever is higher, except HT-VI Townships & Residential Colonies category. The licensee
does not propose any change in billing demand for HT-VI category.
VI.
New HT sub-categories: The licensee would like to propose the following new HT
categories:

HT I (C) Aquaculture & Animal Husbandry: At present, HT services for Poultry Farms,
Pisciculture, Prawn culture and Dairy Farms are being billed under HT I. The licensee
would like to propose to create a new sub category called HT - I (C) Aqua-culture and
Animal Husbandry applicable for Poultry Farms, Pisciculture, Prawn culture and Dairy
Farms. These would be charged the same concessional tariff as per the corresponding sub
category in LT III.

HT II (B) Religious Places: At present, HT services for Religious Places are being billed
under HT II Others tariff. The licensee proposed to create a new sub category called HT II
(B) Religious Places applicable for religious places currently being billed under HT-II.
These would be charged the same tariff as that of LT-VII (B).
VII.
Interruption Free Supply: It is the endeavor of the licensees to provide high reliable /
interruption free power to all consumers in the state. The licensees intend to roll out this
initiative with HT consumers at 33 kV and above in 6 cities / areas from April 2016.
The licensee intends to roll out this initiative of providing high reliable / uninterrupted power
supply to HT consumers at 33 kV and above in the following cities / areas from April
2016:
•
Visakhapatnam
•
Kakinada
•
Rajahmundry
•
Sri City
•
Krishnapatnam
•
Tirupati
APSPDCL
Page 111
The licensee would like to propose Rs. 0.25 / Unit as reliability charge in addition to the
applicable HT tariff w.e.f. 01 October 2016 for all HT consumers at 33 kV and above in the
above areas.
VIII.
Monthly billing of all LT I Domestic services: The licensee would like to propose to
implement monthly billing of all rural domestic consumers who are currently being billed on a
bi-monthly basis. It is the licensee’s view that this would improve cash flow, enable a better
control on commercial aspects and also improve its finances due to (a) higher collection of
minimum charges; and (b) reduction in receivable-days.
Category-wise Tariff Proposals
The following section lists in detail the proposed rationalized tariff structure and modifications in
the tariff categories for different consumer categories.

The definition of any consumer category is proposed to remain the same unless and
otherwise mentioned in this section.

The definition of categories or sub categories which have been merged or moved has to
be modified accordingly to reflect the new consumer mix.
Low Tension Category
LT I Domestic
The licensee has proposed grouping of domestic consumers based on consumption in the section
on revenue at current tariffs. The licensee would like to propose no change in tariff for Group A
and B consumers (all Domestic consumers with annual consumption less than 2,400 Units during
last year). The licensee would like to propose a 2.5% increase in energy charges only for Group
C consumers (all Domestic consumers with annual consumption more than 2,400 Units during
last year).
APSPDCL
Page 112
The proposed tariff for LT I Domestic category is as under:
Proposed Category / Slab Structure
Existing
Proposed
(Units kWh)
Tariff
Tariff
(Rs./Unit)
Group A: All Domestic consumers with annual consumption
< = 600 Units during last year
0-50
1.45
1.45
51-100
2.60
2.60
101-200
3.60
3.60
Above 200 #
6.90
6.90
Group B: All Domestic consumers with annual consumption
< =2400 and > 600 units during last year
0-50
2.60
2.60
51-100
2.60
2.60
101-200
3.60
3.60
201-300 #
6.90
6.90
Above 300
7.75
7.75
Group C: All Domestic consumers with annual consumption
>2400 units
0-50
2.67
2.60
51-100
3.33
3.25
101-200##
5.39
5.26
201-300#
7.07
6.90
301-400
7.94
7.75
401-500
8.48
8.27
Above 500 units
8.80
9.02
# computed average existing tariff for a consumer whose consumption is > 200 but < 300 units
##computed average existing tariff for a consumer whose consumption is > 100 but < 200 units
LT-II Non Domestic/Commercial
The licensee would like to propose an increase in the Demand charges by 4% and an increase in
Energy charges by 4% on existing tariff FY 2015-16 for all the sub categories in LT-II.
Sub Category/ Slab Structure
Proposed Energy charge
Proposed Fixed charge
(Rs/kW/month)
(Units kVAh / kWh)
(Rs. /Unit)
LT II (A) Upto 50 Units/Month
55
5.62
LT II (B) Above 50 Units/Month
0-50
55
6.90
51-100
55
7.68
101-300
55
8.88
301-500
55
9.42
>500
55
9.97
LT II (C) Advertisement Hoardings
55
12.04
APSPDCL
Page 113
LT III Industry
The licensee would like to propose an increase in the Demand charges by 4% and an increase in
Energy charges by 4% on existing tariff FY 2015-16 for all the sub categories in LT III except
Pisciculture / Prawn culture and Poultry farms, for which the licensee would like to propose
concessional tariffs.
Sub- Category
Proposed Demand
charge
(Rs/kVA/month)
LT III Industry
Industries
Seasonal Industries (off season)
Aquaculture & Animal
Husbandry *
Sugarcane crushing
Mushroom and Rabbit farms
Floriculture in Green House
Proposed Energy charge
(Rs. /Unit)
55
55
6.64
7.37
21
3.75
22
55
55
4.82
5.86
5.86
* Keeping in view that the licensee is proposing same tariffs for LT III sub categories
Pisciculture/Prawn culture and Poultry farms, the licensee would like to propose a single sub
category for Pisciculture/Prawn culture and Poultry farms and the sub category may be named as
Aquaculture & Animal Husbandry.
LT IV Cottage Industries
The licensee would like to propose no change in tariff for sub category LT IV (B) Agro based
activities and increase in the Energy and Demand charges by 4% for sub category LT IV (A)
Cottage Industries.
Sub-Category
Cottage Industries
Agro based activities
Proposed Demand
charge
(Rs/kVA/month)
21
20
Proposed Energy charge
(Rs. /Unit)
3.90
3.75
LT V Agriculture
The licensee would like to propose to continue with existing tariff for all the sub categories in LT
V. The proposed tariff is same as the existing tariff for all the sub categories in LT V.
APSPDCL
Page 114
Sub- Category
LT V(A) Agriculture with DSM Measures
Corporate Farmers & IT Assesses
Wet Land Farmers (Holdings >2.5 acre)
Dry Land Farmers (Connections > 3 nos.)
Wet Land Farmers (Holdings <= 2.5 acre)
Dry Land Farmers (Connections <= 3 nos.)
LT V (B) Agriculture without DSM
Measures
Corporate Farmers & IT Assesses
Wet Land Farmers (Holdings >2.5 acre)
Dry Land Farmers (Connections > 3 nos.)
Wet Land Farmers (Holdings <= 2.5 acre)
Dry Land Farmers (Connections <= 3 nos.)
LT V (C) Others
Salt farming units with CL upto 15HP
Rural Horticulture Nurseries
* Equivalent flat rate tariff
Demand charge
(Rs/HP/Year)
Energy charge
(Rs. /Unit)
0
525.00*
525.00*
0
0
2.50
0.50
0.50
0
0
0
1050.00*
1050.00*
525.00*
525.00*
3.50
1.00
1.00
0.50
0.50
240.00
240.00
3.70
3.70
LT VI Street Lighting & PWS
The licensee would like to propose an increase in the Demand charges by 4% and an increase in
Energy charges by 4% on existing tariff FY 2015-16 for the sub categories in LT VI (A) and
(B). The licensee would like to propose to continue with existing tariff for sub category LT VI
(C) NTR Sujala Padhakam.
Sub Category
LT VI (A) Street Lighting
Panchayats
Municipalities
Municipal Corporations
LT VI (B) PWS Schemes
Panchayats
Municipalities
Municipal Corporations
LT-VI (C) NTR Sujala Padhakam
APSPDCL
Proposed Demand
charge
(Rs/kW/month)
33
33
33
(Rs/HP/month)
33
33
33
Rs.10/HP/month
Proposed Energy charge
(Rs. /Unit)
5.87
6.41
6.96
4.77
5.87
6.41
4.00
Page 115
LT VII General Purpose
The licensee would like to propose an increase in the Demand charges by 4% and an increase in
Energy charges by 4% on existing tariff FY 2015-16 for all the sub categories in LT VII:
Category
LT VII (A) General Purpose
LT VII (B) Religious Places
Proposed Demand charge
(Rs/kW/month)
22
21
Proposed Energy charge
(Rs. /Unit)
7.13
4.89
LT VIII Temporary Supply
The licensee would like to propose an increase in the Demand charges by 4% and an increase in
Energy charges by 4% on existing tariff FY 2015-16 for category LT VIII
Category
LT VIII Temporary
Proposed Demand charge
(Rs/kW/month)
22
Proposed Energy charge
(Rs. /Unit)
10.30
High Tension Category
HT I (A) Industry
The licensee would like to propose an increase in the Demand charges by 4% and an increase in
Energy charges by 4% on existing tariff FY 2015-16 for all the sub categories in HT I (A) and
HT I (A) ToD for all voltage levels (11 kV, 33 kV, 132 kV).
Voltage
Level
HT I (A)
11 KV
33 KV
APSPDCL
Sub-Category
Proposed Demand
charge
(Rs/kVA/month)
Proposed Energy
charge
(Rs. /Unit)
General
Lights and Fans
Industrial Colonies
Seasonal Industries
Time of Day Tariffs (6 PM to
10 PM)
386
386
6.26
6.26
6.20
7.54
-
7.35
General
386
5.79
Page 116
Voltage
Level
132 KV
Sub-Category
Proposed Demand
charge
(Rs/kVA/month)
Proposed Energy
charge
(Rs. /Unit)
Lights and Fans
Industrial Colonies
Seasonal Industries
Time of Day Tariffs (6 PM to
10 PM)
General
Lights and Fans
Industrial Colonies
Seasonal Industries
Time of Day Tariffs (6 PM to
10 PM)
386
5.79
6.20
6.85
-
6.88
386
386
5.36
5.36
6.20
6.58
-
6.45
HT I (B) Energy Intensive Industries (presently termed as HT I (B) Ferro Alloys)
With a view to enable rapid industrialization in the State, the licensee would like to propose to
extend concessional tariffs under HT I (B) to other energy intensive industries in addition to
Ferro-alloy units. The licensee would like to propose to rename the category HT I (B) to HT I
(B) Energy Intensive Industries. The following industries shall be eligible for the concessional
tariffs offered under this renamed category:

Ferro Alloy Units

PV Ingots & Cell Manufacturing

Poly-silicon industry

Aluminum industry
The licensee would like to propose no increase on existing tariff of FY 2015-16 for category HT
I (B) for all the voltage levels (11 kV, 33 kV, 132 kV).
Voltage Level
HT I (B)
11 KV
33 KV
132 KV
APSPDCL
Proposed Energy charge
(Rs. /Unit)
5.68
5.23
4.81
Page 117
HT I (C) Aquaculture & Animal Husbandry (New Category)
At present, HT services for Poultry Farms, Pisciculture and Prawn culture are being billed under
HT I. The licensee would like to propose to create a new sub category called HT I (C) Aquaculture and Animal Husbandry applicable for Pisciculture, Prawn Culture, Dairy Farms and
Poultry Farms. These would be charged the same concessional tariff as per the corresponding
sub category in LT III.
Category
Proposed Demand charge (Rs/kVA/month)
HT I (C)
Rs. 21 / kVA
HT II Others
Proposed Energy charge
(Rs. /Unit)
3.75
The licensee would like to propose an increase in the Demand charges by 4% and an increase in
Energy charges by 4% on existing tariff FY 2015-16 for category HT II Others & HT II Others
–ToD.
Voltage Level
HT II Others
11 KV
11 KV - ToD
33 KV
33 KV - ToD
132 KV
132 KV - ToD
Proposed Demand charge
Proposed Energy charge
(Rs/kVA/month)
(Rs. /Unit)
386
386
386
-
7.54
8.63
6.85
7.95
6.58
7.68
HT II (B) Religious Places: At present, HT services for Religious Places are being billed under
HT II Others tariff. The licensee proposes to create a new sub category called HT II (B)
Religious Places applicable for religious places currently being billed under HT II. These would
be charged the same tariff as that of LT VII (B):
Category
HT II (B) Religious Places
APSPDCL
Proposed Demand charge
(Rs/kVA/month)
Proposed Energy charge
(Rs. /Unit)
Rs. 21 / kVA
4.89
Page 118
HT III Public Infrastructure & Tourism (presently termed as HT III Airports, Bus
Stations and Railway Stations)
Presently, all tourism infrastructure projects are being billed under HT II Others category. The
Andhra Pradesh Tourism Policy 2015 states that such consumers shall be billed as per HT III
category. Accordingly, the licensee would like to propose to rename the category HT III to HT
III Public Infrastructure & Tourism which shall be restricted to Airports, Bus Stations, Railway
Stations and eligible Tourism Infrastructure Projects as per the policy. As per the policy, the
following projects shall be eligible for the said incentive:
“
i. Hotels (Three-Star or above
category hotels as per
guidelines of Ministry of
Tourism, Government of
India)
iv. Amusement Parks
vii. Botanical gardens
x. Wayside amenities
”
ii. Resorts, including beach
resorts, jungle resorts, hill
resorts etc. (Three-Star or
above category hotels as per
guidelines of Ministry of
Tourism, Government of
India)
v. MICE Centers
viii. Urban/Rural Haats
xi. Spiritual/Wellness Centers
iii. Heritage Hotels (Heritage
Basic, Heritage Classic,
Heritage Grand as per
guidelines of Ministry of
Tourism, Government of
India)
vi. Golf Courses
ix. Tourism & Hospitality
Training Institutes
xii. Museums
Tourism projects which are eligible as per the Andhra Pradesh Tourism Policy shall be billed
under this category.
The licensee would like to propose to increase in the Demand charges by 4% and an increase in
Energy charges by 4% on existing tariff FY 2015-16 for category HT III and HT III ToD.
Proposed Demand charge
(Rs/kVA/month)
HT III Public Infrastructure & Tourism
11 KV
386
11 KV - ToD
33 KV
386
33 KV - ToD
Voltage Level
132 kV
132 KV - ToD
APSPDCL
386
Proposed Energy charge (Rs/ /
Unit)
7.19
8.28
6.56
7.65
6.25
7.34
Page 119
HT IV Irrigation, Agriculture and CPWS
The licensee would like to propose the Energy charges equivalent to Cost of Service (CoS) for
FY 2016-17, i.e., Rs. 5.60 / Unit for sub categories HT IV (A) Government LIS and HT IV (A)
Private Irrigation and Agriculture for all the voltage levels (11 kV, 33 kV, 132 kV).
The licensee would like to propose an increase in Energy charges by 4% on existing tariff FY
2015-16 for category HT IV (B) Composite Water Supply Schemes for all the voltage levels (11
kV, 33 kV, and 132 kV).
Category
Proposed Energy charge
(Rs. /Unit)
HT IV Irrigation, Agriculture and CPWS
Government LIS
5.60
Agriculture
5.60
CPWS
4.79
HT V Railway Traction
The licensee would like to propose an increase in Energy charges by 4% on existing tariff FY
2015-16 for category HT V.
Category
Proposed Energy charge
(Rs. /Unit)
HT V Railway Traction
6.95
HT VI Townships and Residential Colonies
The licensee would like to propose an increase in the Demand charges by 4% and an increase in
Energy charges by 4% on existing tariff FY 2015-16 for category HT VI for all the voltage
levels (11 kV, 33 kV, 132 kV).
Category
HT VI Townships & Residential
Colonies
APSPDCL
Proposed Demand
charge (Rs/kVA/month)
55
Proposed Energy
charge
(Rs. /Unit)
6.20
Page 120
HT VII Green Power
The licensee would like to propose no increase on existing tariff of FY 2015-16 for category HT
VII for all the voltage levels (11 kV, 33 kV, 132 kV).
Category
Proposed Energy charge
(Rs. /Unit)
HT VII Green Power
11.32
HT VIII Temporary
The licensee would like to propose the continuation of the current tariff structure i.e. 1.5 times of
the corresponding HT category
HT – RESCOs (11 KV)
The licensees would like to propose the following tariffs for the RESCOs:



Anakapalle : Rs. 1.53/unit
Chipurpalle : Rs. 0.26/unit
Kuppam : Rs. 0.41/unit
Billing demand for HT services
The licensee would like to propose that the billing demand shall be the maximum demand
recorded during the month or 90% of the contracted demand, whichever is higher, except HT-VI
Townships & Residential Colonies category. The licensee does not propose any change in billing
demand for HT-VI category.
Madhya Pradesh and Tamil Nadu currently levy demand charges on 90% of contract demand or
maximum demand, whichever is higher.
Interruption Free Supply
AP has been one of the pioneering states in India in implementing reforms in the Power Sector.
Government of Andhra Pradesh has successfully achieved zero load restrictions from past one
year giving the most required boost to the industrial sector. Now the government envisages to go
a step further and make the state interruption free. AP currently has an interruption of 6000
minutes per customer per year (as per CEA report) compared to 100 – 200 minutes
internationally:
APSPDCL
Page 121
Country
Average frequency of
Average interruption duration per
interruption per consumer for an
consumer (Minutes)
year (No.)
Singapore
0.47
0.015
UK
34
1–2
US
100
~1
Australia
200
1.8
Interruption free power is viewed as one of the most important drivers for industrial growth:

Xi'an LONGi, Foxconn and other major global industrial players have expressed their desire
for interruption free power to invest in the State

Many industries have invested in setting up dedicated captive power plants to ensure
uninterrupted supply
It is the endeavor of the licensee to achieve high reliability and become the most reliable power
distributor in India. A diagnostic study has been carried out both APDISCOMs to baseline the
current level of interruptions, analyze reasons & root causes leading to interruptions, and develop
a strategy to substantially reduce the current level of interruptions. Based on real-time
interruption data using modem communication for all 11 kV feeders, following is the current
level of interruptions in APSPDCL:

SAIDI (System Average Interruption Duration Index) – 2,019 mins / year

SAIFI (System Average Interruption Frequency Index) – 99.04 interruptions / year
The above is in line with the CEA data.
Daily interruption data can be monitored on the website www.apspdcl.in
The licensee intends to roll out this initiative of providing high reliable / uninterrupted
power supply to HT consumers at 33 kV and above in the following cities / areas from
April 2016:

Visakhapatnam

Kakinada

Rajahmundry
APSPDCL
Page 122

Krishnapatnam

Sri City

Tirupati
The licensee would like to propose Rs. 0.25 / Unit as reliability charge in addition to the
applicable HT tariff w.e.f. October 2016 for all HT consumers at 33 kV and above in the
above areas.
The licensee shall form a baseline on present level of interruptions using SAIDI and SAIFI as
KPIs for each of the above cities / areas by April 2016. The detailed analysis, design,
implementation and review for the initiative shall require 6 – 9 months.
The licensee is targeting to bring down the SAIDI by 40% by March 2017 as compared to April
2016. In case the licensee fails to meet its target, the license shall refund the reliability charge as
under:
Target met (% reduction in SAIDI)
> 0% and <= 10%
> 10% and <=20%
> 20% and <= 30%
> 30% and <= 40%
>= 40%
Refund of Reliability Charge to consumer
by the licensee at the end of the Financial
Year
20 paise / Unit
15 paise / Unit
10 paise / Unit
5 paise / Unit
No refund
Going forward, it is the intent of the licensee to ensure negligible interruptions to all HT
consumers in the state – with a view to position AP as the most desirable destination for
investment.
The funds collected shall be utilized toward building of infrastructure for interruption free supply
with a view to cater to (n – 1) contingency. Also, providing highly reliable power to the
industries would boost investments especially in the high growth clusters.
The licensee submits that at present it is unable to compute the revenue impact due to collection
of reliability surcharge and building of additional infrastructure to achieve interruption-free
supply in these areas.
APSPDCL
Page 123
Other Tariff Proposals

Cross subsidy surcharge determination for FY 2016-17:
Provisions under the National Tariff Policy – 2006
Cross subsidy and additional surcharge for open access
When open access is allowed the surcharge for the purpose of sections 38, 39, 40 and subsection 2 of section 42 would be computed as the difference between
(i) The tariff applicable to the relevant category of consumers and
(ii) The cost of the distribution licensee to supply electricity to the consumers of the
applicable class
In case of a consumer opting for open access, the distribution licensee could be in a
position to discontinue purchase of power at the margin in the merit order. Accordingly,
the cost of supply to the consumer for this purpose may be computed as the aggregate of
(a) The weighted average of power purchase costs (inclusive of fixed and variable charges) of
top 5% power at the margin, excluding liquid fuel based generation, in the merit order approved
by the SERC adjusted for average loss compensation of the relevant voltage level and
(b) The distribution charges determined on the principles as laid down for intra-state
transmission charges.
Surcharge formula:
S = T–[C/ (1-L) +D]
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
APSPDCL
Page 124
L is the system losses for the applicable voltage level, expressed as a percentage
The Hon’ble commission, in 2015-16 determined the Cross Subsidy Surcharge for various
categories of consumers based on the embedded cost methodology. The Commission is of the
opinion that Embedded Cost Approach is the most appropriate approach since the embedded
accounting costs are actually used to allocate costs to various consumer categories and to
determine the current level of cross-subsidy.
As per National Tariff Policy, the Cross Subsidy Surcharge has to be determined based on
avoided cost methodology. In view of this, the licensee would like to file a proposal for
determination of cross-subsidy surcharge for Open Access transactions along with this ARR
filing for FY 2016-17. It may be noted that the licensee has adopted the methodology stated in
the National Tariff Policy for determination of the cross-subsidy surcharge. The Cross Subsidy
as computed by the licensee for each category is as shown below:
SPDCL
Categories
HIGH TENSION
HT Category at 11 kV
HT-I Indl Segregated
HT-II - Industrial Non Segregated
HT - III Aviation
HT -IV A Govt Lift Irrigation
HT-VI -Colony Supply
HT- VII Green Power
Rural co-operatives
Temporary
HT Category at 33 kV
HT-I Indl Segregated
HT-II - Industrial Non Segregated
HT - III Aviation
HT -IV A Govt Lift Irrigation
HT-VI -Colony Supply
HT- VII Green Power
Rural co-operatives
Temporary
APSPDCL
Cross
Average
Marginal Wheeling
Applicable Subsidy
Realization
PP
Charges
Loss%
Surcharge
(Rs./unit) (Rs./unit) (Rs./unit)
(Rs./unit)
8.01
9.35
8.06
5.41
6.37
0.43
-
5.36
5.36
5.36
5.36
5.36
5.36
5.36
5.36
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
10.23%
10.23%
10.23%
10.23%
10.23%
10.23%
10.23%
10.23%
1.46
2.80
1.50
0.00
0.00
0.00
0.00
0.00
6.74
9.07
8.43
5.29
6.47
-
5.36
5.36
5.36
5.36
5.36
5.36
5.36
5.36
0.19
0.19
0.19
0.19
0.19
0.19
0.19
0.19
6.83%
6.83%
6.83%
6.83%
6.83%
6.83%
6.83%
6.83%
0.80
3.13
2.49
0.00
0.53
0.00
0.00
0.00
Page 125
Categories
HT Category at 132 kV
HT-I Indl Segregated
HT-II - Industrial Non Segregated
HT - III Aviation
HT -IV A Govt Lift Irrigation
HT-V –Railway Traction
HT-VI -Colony Supply
HT- VII Green Power
Rural co-operatives
Temporary
Cross
Average
Marginal Wheeling
Applicable Subsidy
Realization
PP
Charges
Loss%
Surcharge
(Rs./unit) (Rs./unit) (Rs./unit)
(Rs./unit)
6.43
7.76
5.62
6.97
-
5.36
5.36
5.36
5.36
5.36
5.36
5.36
5.36
5.36
0.16
0.16
0.16
0.16
0.16
0.16
0.16
0.16
0.16
3.34%
3.34%
3.34%
3.34%
3.34%
3.34%
3.34%
3.34%
3.34%
0.72
2.05
0.00
0.00
1.27
0.00
0.00
0.00
0.00
Revenue Impact
SPDCL: The total revenue impact due to above tariff proposals is Rs. 488.35 Cr.
APSPDCL
Page 126
Tariff Table for All Consumer Categories
The present and proposed tariffs for all consumer categories are as shown below:
Category
Units
Rates for FY 2015-16
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
Rates for FY 2016-17
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
LT Category I
Domestic
Group A: All Domestic
consumers with annual
consumption < = 600
kWh
First 50 units
kWh
1.45
1.45
51-100 units
kWh
2.60
2.60
101 - 200 units
kWh
3.60
Above 200 units
kWh
3.60
6.70 8.80
Group B: All Domestic
consumers with
consumption ( < =2400
and > 600 units)
First 50 units
kWh
2.60
2.60
51-100 units
kWh
2.60
2.60
101 - 200 units
kWh
3.60
201 - 300 units
kWh
Above 300 units
kWh
3.60
6.70 7.22
7.75 8.80
Group C: All Domestic
consumers with annual
consumption >2400
units
First 50 units
kWh
2.60
2.67
51-100 units
kWh
3.33
101 - 200 units
kWh
201 - 300 units
kWh
301 - 400 units
kWh
3.25
4.88 5.63
6.70 7.22
7.75
401 – 500 units
Above 500 units
kWh
8.27
8.48
kWh
8.80
9.02
APSPDCL
6.90
6.90
7.75
5.39
7.07
7.94
Page 127
Category
LT Category II Nondomestic/Commercial
LT II (A) Upto 50
Units/Month
LT II (B) Above 50
Units/Month
0-50 units
Units
Rates for FY 2015-16
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
Rates for FY 2016-17
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
kWh/kVAh
53/kW
5.40
55/kW
5.62
kWh/kVAh
53/kW
6.63
55/kW
6.90
51-100 units
kWh/kVAh
53/kW
7.38
55/kW
7.68
101-300 units
kWh/kVAh
53/kW
8.54
55/kW
8.88
301-500 units
kWh/kVAh
53/kW
9.06
55/kW
9.42
Above 500 Units
LT-II(C) Advertising
Hoardings
LT Category III
Industry
Industries
Seasonal Industries (Off
Season)
Aquaculture & Animal
Husbandry
Sugarcane crushing
Mushroom & Rabbit
Farms
Floriculture in Green
House
LT Category IV
Cottage Industries
Cottage Industries upto
10 HP@
Agro based activity upto
10 HP@
LT Category V
Agriculture
LT V (A) Agriculture
with DSM Measures
Corporate Farmers & IT
Assesses
Wet Land Farmers
(Holdings >2.5 acre)
Dry Land Farmers
(Connections > 3 nos.)
kWh/kVAh
53/kW
9.59
55/kW
9.97
kWh/kVAh
53/kW
11.58
55/kW
12.04
kWh/kVAh
53/kW
6.38
55/kW
6.64
kWh/kVAh
53/kW
7.09
55/kW
7.37
kWh/kVAh
21/kW
4.63
21/kW
3.75
kWh/KVAh
21/kW
4.63
22/kW
4.82
kWh/kVAh
53/kW
5.63
55/kW
5.86
kWh/kVAh
53/kW
5.63
55/kW
5.86
kWh
20/kW
3.75
21/kW
3.90
kWh
20/kW
3.75
20/kW
3.75
kWh
0
2.50
0
2.50
kWh
* 525/HP/Year
0.50
* 525/HP/Year
0.50
kWh
* 525/HP/Year
0.50
* 525/HP/Year
0.50
APSPDCL
Page 128
Category
Wet Land Farmers
(Holdings <= 2.5 acre)
Dry Land Farmers
(Connections <= 3 nos.)
LT V (B) Agriculture
without DSM
Measures
Corporate Farmers & IT
Assesses
Wet Land Farmers
(Holdings >2.5 acre)
Dry Land Farmers
(Connections > 3 nos.)
Wet Land Farmers
(Holdings <= 2.5 acre)
Dry Land Farmers
(Connections <= 3 nos.)
Category LT V(C)
Others
Salt farming units with
CL up to 15HP $
Rural Horticulture
Nurseries upto 15HP $
LT Category VI Street
Lighting & PWS
LT VI (A)-Street
Lighting
Panchayats
Units
Rates for FY 2015-16
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
Rates for FY 2016-17
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
kWh
0
0
0
0
kWh
0
0
0
0
kWh
0
3.50
0
3.50
kWh
* 1050/HP/Year
1.00
* 1050/HP/Year
1.00
kWh
* 1050/HP/Year
1.00
* 1050/HP/Year
1.00
kWh
* 525/HP/Year
0.50
* 525/HP/Year
0.50
kWh
* 525/HP/Year
0.50
* 525/HP/Year
0.50
kWh
20/HP
3.70
20/HP
3.70
kWh
20/HP
3.70
20/HP
3.70
kWh
32/kW
5.64
33/kW
5.87
Municipalities
kWh
32/kW
6.16
33/kW
6.41
Municipal Corporations
LT VI (B) PWS
Schemes
Panchayats
kWh
32/kW
6.69
33/kW
6.96
kWh/kVAh
32/HP
4.59
33/HP
4.77
Municipalities
kWh/kVAh
32/HP
5.64
33/HP
5.87
Municipal Corporations
LT - VI(C) NTR Sujala
Padhakam
LT Category VII
General
kWh/kVAh
32/HP
6.16
33/HP
6.41
kWh/kVAh
10/HP
4.00
10/HP
4.00
kWh/kVAh
21/KW
6.86
22/KW
7.13
LT VII (A) - General
Purpose
APSPDCL
Page 129
Category
LT VII (B) – Religious
Places
Units
Rates for FY 2015-16
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
Rates for FY 2016-17
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
kWh
20/KW
4.70
21/KW
4.89
kWh/kVAh
21/KW
9.90
22/KW
10.30
HT I (A) General
132 KV and above
kVAh
5.15
kVAh
11 KV
kVAh
Rs.
386/KVA/Month
of maximum
demand recorded
or 90% of CMD
whichever is
higher
5.36
33 KV
Rs.
371/KVA/Month
of maximum
demand recorded
or 80% of CMD
whichever is
higher
Lights & Fans
132 KV and above
kVAh
5.15
5.36
33 KV
kVAh
5.57
5.79
11 KV
kVAh
6.02
6.26
132 KV and above
kVAh
5.96
6.20
33 KV
kVAh
5.96
6.20
11 KV
kVAh
5.96
6.20
Seasonal Industries
132 KV and above
kVAh
33 KV
kVAh
11 KV
kVAh
Time-of-Day Tariff (6
PM to 10 PM)
132 KV and above
kVAh
6.20
6.45
kVAh
6.62
6.88
kVAh
7.07
7.35
LT Category VIII
Temporary Supply
HT-I Industry
5.57
6.02
5.79
6.26
Industrial Colonies
33 KV
11 KV
Rs.
371/KVA/Month
of maximum
demand recorded
or 80% of CMD
whichever is
higher
6.33
6.59
7.25
Rs.
386/KVA/Month
of maximum
demand recorded
or 90% of CMD
whichever is
higher
6.58
6.85
7.54
HT I (B) Energy
APSPDCL
Page 130
Category
Units
Rates for FY 2015-16
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
Rates for FY 2016-17
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
Intensive Industries
132 KV and above
kVAh
4.81
4.81
33 KV
kVAh
5.23
5.23
11 KV
HT I (C) Aquaculture
& Animal Husbandry
11 KV
kVAh
5.68
5.68
kVAh
New category
Rs. 21/kVA
3.75
Rs.
386/KVA/Month
of maximum
demand recorded
or 90% of CMD
whichever is
higher
6.58
HT II (A) Others
Rs.
371/KVA/Month
of maximum
demand recorded
or 80% of CMD
whichever is
higher
132 KV and above
kVAh
33 KV
kVAh
11 KV
kVAh
Time-of-Day Tariff (6
PM to 10 PM)
132 KV and above
kVAh
7.38
7.68
33 KV
kVAh
7.64
7.95
11 KV
HT II (B) Religious
Places
kVAh
8.30
8.63
11 kV
kVAh
HT III Public
Infrastructure &
Tourism
132 KV and above
kVAh
33 KV
kVAh
11 KV
kVAh
Time-of-Day Tariff (6
PM to 10 PM)
132 KV and above
kVAh
7.06
7.34
kVAh
7.36
7.65
kVAh
7.96
8.28
33 KV
11 KV
APSPDCL
6.33
6.59
7.25
New category
Rs.
371/KVA/Month
of maximum
demand recorded
or 80% of CMD
whichever is
higher
6.01
6.31
6.91
6.85
7.54
Rs. 21 / kVA
4.89
Rs.
386/KVA/Month
of maximum
demand recorded
or 90% of CMD
whichever is
higher
6.25
6.56
7.19
Page 131
Category
HT IV Irrigation,
Agriculture & CPWS
Lift Irrigation &
Agriculture
CP Water Supply
Schemes
HT V Railway Traction
132 KV
HT VI Townships &
Residential Colonies
Units
Rates for FY 2015-16
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
Rates for FY 2016-17
Fixed/Demand
Energy
Charges in Rs/ Charges
Month
Rs/Unit
kVAh
5.64
5.60
kVAh
4.61
4.79
kVAh
KVAh
6.68
Rs.
53/KVA/Month
of Billing
demand
5.96
6.95
Rs.
55/KVA/Month
of Billing
demand
6.20
RESCOs
Kuppam
HT VII Green Power
HT VII Temporary
kWh
kVAh
0.24
0.41
11.32
1.5 times of the Tariff of
corresponding HT
category
11.32
1.5 times of the Tariff of
corresponding HT
category
@ - Units which exceed 10 HP connected load shall be billed at tariff specified for LT-III
Industrial category
* -Equivalent flat rate of tariff
$ - Units with connected load more than 15 HP shall be billed under LT –III Industrial Normal
tariff
Note: All other conditions are as per in the Chapter -XII of the Retail supply Tariff Schedule for
FY 2015-16.
The total revenue increase from the tariff proposals for both licensees is Rs. 783.05 Crs.
APSPDCL
Page 132