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Filing of ARR & FPT for SLDC business for Third Control Period (FY 2014-15 to FY 2018-19)
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BEFORE THE HONOURABLE ANDHRA PRADESH ELECTRICITY REGULATORY COMMISSION
AT ITS OFFICE AT Vth FLOOR, SINGARENI BHAVAN, RED HILLS, HYDERABAD
FILING NO.______/2013
CASE NO. _______/2013
In the matter of:
Filing of the Aggregate Revenue Requirement (ARR), Filing for Proposed Tariff (FPT) for the Third
Control Period (FY 2014-15 to FY 2018-19) for its SLDC Activity under Section 26(5) of the Andhra
Pradesh Electricity Reform Act, 1998 (hereinafter referred to as ‘the Act’) and under Part VII (Section
61 to Section 64) of the Electricity Act, 2003 read with the relevant APERC Guidelines and
Regulations till date, by the Transmission Corporation of Andhra Pradesh Limited (‘APTransco’ or ‘the
Licensee’) as the Transmission Licensee and SLDC operator.
In the matter of:
TRANSMISSION CORPORATION OF ANDHRA PRADESH LIMITED
… Applicant
AFFIDAVIT OF APPLICANT VERIFYING THE APPLICATION ACCOMPANYING FILING OF AGGREGATE REVENUE REQUIREMENTS I, Suresh Chanda , S/o Ramgopal Singh, working for the gain at the Transmission Corporation of
Andhra Pradesh Limited do solemnly affirm and say as follows:
1. I am the Chairman and Managing Director of APTransco, the licensee company operating and
controlling the Transmission & SLDC business of electricity in Andhra Pradesh pursuant to the
license granted by the Hon’ble Commission and in terms of Government of Andhra Pradesh
(GoAP) orders vide G.O.Ms.No.8 dated 17-01-2004. I am competent and duly authorised by
APTransco to affirm, swear, execute and file this affidavit in the present proceedings.
2. I have read and understood the contents of the accompanying Filing of Aggregate Revenue
Requirement for SLDC Business. The statements made in the paragraph 9 of the accompanying
application now shown to me are true to my knowledge, derived from the official records made
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available to me and are based on information and advice received which I believe to be true and
correct.
DEPONENT
VERIFICATION:
I, the above named Deponent solemnly affirm at Hyderabad on this 30th November, 2013 that
the contents of the above affidavit are true to my knowledge, no part of it is false and nothing
material has been concealed there from.
DEPONENT
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BEFORE THE HONOURABLE ANDHRA PRADESH ELECTRICITY REGULATORY COMMISSION
AT ITS OFFICE AT Vth FLOOR, SINGARENI BHAVAN, RED HILLS, HYDERABAD
FILING NO.______/2013
CASE NO. ______/2013
In the matter of:
Filing of the Aggregate Revenue Requirement (ARR), Filing for Proposed Tariff (FPT) for the Third
Control Period (FY 2014-15 to FY 2018-19) for its SLDC Business under Section 26(5) of the Andhra
Pradesh Electricity Reform Act, 1998 (hereinafter referred to as ‘the Act’) and under Part VII (Section
61 to Section 64) of the Electricity Act, 2003 read with the relevant APERC Guidelines and
Regulations till date, by the Transmission Corporation of Andhra Pradesh Limited (‘APTransco’ or ‘the
Licensee’) as the Transmission Licensee and SLDC operator.
In the matter of:
TRANSMISSION CORPORATION OF ANDHRA PRADESH LIMITED
… Applicant
The Applicant respectfully submits as under: -
1. Pursuant to the applicable provisions of the Andhra Pradesh Electricity Reform Act, 1998, the
Government of Andhra Pradesh undertook the reform and restructuring of the erstwhile
Andhra Pradesh State Electricity Board (‘APSEB’). APTransco has been formed as a
successor entity of the erstwhile APSEB through the First statutory transfer scheme, which
was notified in the Official Gazette of the Government of Andhra Pradesh on February 1st
1999 to manage the Transmission and Distribution of erstwhile APSEB. Subsequently, the
State Government notified the Second Transfer Scheme on March 31st, 2000 wherein
APTRANSCO retained the Transmission, SLDC and Bulk Supply business of the State with
itself, while transferring the Distribution and Retail Supply of the State to the four Distribution
Companies formed in the State viz., (i) Eastern Power Distribution Company of Andhra
Pradesh Limited, (ii) Southern Power Distribution Company of Andhra Pradesh Limited, (iii)
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Central Power Distribution Company of Andhra Pradesh Limited, and (iv) Northern Power
Distribution Company of Andhra Pradesh Limited (collectively referred to as ‘Discoms’).
2. Pursuant to obtaining independent licenses by the Discoms in December 2000, APTransco
has relinquished its Distribution & Retail Supply License.
3. Subsequently on June 7, 2005, the State Government notified the Third Transfer Scheme in
its official gazette wherein the Bulk Supply business and undertaking of APTRANSCO is
vested to the DISCOMs with effect from June 9, 2005. As a result, APTRANSCO is presently
carrying out solely the Transmission & SLDC business as the State Transmission Utility (STU)
in the State.
4. This filing for Levy of Annual fee and Operating charges for SLDC business is in accordance
with the provisions of the Reform Act, the Electricity Act 2003, the License granted by the
Hon’ble Commission to APTransco on January 31, 2000 and the Guidelines and Regulation
No.1 of 2006, issued by the Honorable Commission.
5. Sub-section (1) of section 31 of the Electricity Act, 2003, provides that the State Government
shall establish a State Load Dispatch Center (SLDC). Sub-section (2) of the Section 31
provides that the said SLDC shall be operated by a Government
company/authority/corporation constituted by or under any State Act and that until such
company /authority /corporation is notified by the State Government, the State Transmission
Utility (STU) shall operate the SLDC. The Government of AP notified in G.O.Ms.No.8 dated
17-01-2004 that the existing SLDC shall continue as SLDC and be operated by the
Transmission Corporation of AP Ltd., being the STU, until the State Government establishes a
Government Company or any authority or Corporation.
6. While filing the present petition for Annual fee and Operating charges for SLDC Business,
APTransco has endeavored to comply with the various applicable legal and regulatory
directions and stipulations including the directions of the Hon’ble Commission in the Business
Rules of the Commission, the Guidelines, prior ARR and Tariff Orders and the recent
Regulations on Levy and Collection of Fees and Charges by State Load Dispatch Centre
(Regulation No. 1 of 2006) dated July 27, 2006.
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7. Based on the information available, the Applicant has made bonafide efforts to comply with
the directions of the Hon’ble Commission and discharge its obligations to the best of its
abilities. However, any further material become available in the near future, the Applicant
reserves the right to file such additional information and consequently amend /revise the
application.
8. The current petition for Annual fee and Operating charges for SLDC Business being filed has
been discussed and approved by the Board of Directors of APTransco and Sri. Suresh
Chanda, Chairman and Managing Director of APTransco has been authorized to execute and
file the said annual fee and operating charges Petition on behalf of APTransco. Accordingly,
the current petition for Annual fee and Operating Charges for SLDC Business is signed and
verified by, and backed by the affidavit of Sri. Suresh Chanda, Chairman and Managing
Director.
9. In the aforesaid facts and circumstances, the Applicant requests that the Hon’ble Commission:
a. Take the accompanying Annual fee and Operating charges for Petition of APTransco for
SLDC Business on record;
b. Grant suitable opportunity to APTransco within a reasonable time frame to file additional
material information if any;
c. Grant the waivers prayed for with respect to such filing requirements, as APTransco is
unable to comply with at this stage, as more specifically detailed and for the reasons set
out in the present Annual fee and Operating charges filing for SLDC Business.
d. Treat the filing as complete in view of substantial compliance as also the specific requests
for waivers with justification placed on record;
e. Consider and approve SLDC Annual fee and Operating charges including all requested
regulatory treatments in the filing;
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f. Pass such order, as the Hon’ble Commission may deem fit and proper in the facts and
circumstances of the case.
TRANSMISSION CORPORATION OF ANDHRA PRADESH LIMITED
(APPLICANT)
Through
Suresh Chanda
CHAIRMAN AND MANAGING DIRECTOR
Place: HYDERABAD
Dated: November 30th, 2013
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Contents Page No.
1 INTRODUCTION 9
2 TRUE UP - ANALYSIS OF PERFORMANCE FROM FY 2008-09 TO FY 2012-13 10
2.1 OPERATING EXPENSES TRUE UP: 10
2.2 CAPITAL COST TRUE UP: 12
2.3 REVENUE TRUE UP: 13
2.4 SURPLUS/ (DEFICIT) DURING THE PERIOD FY 2008-09 TO FY 2012-13 14
3 DETERMINATION OF SLDC ANNUAL FEE FOR 3RD
CONTROL PERIOD 15
3.1 CAPITAL INVESTMENTS 15
3.2 CAPITAL COST PROJECTION 23
3.3 TOTAL GENERATION CAPACITY: 23
3.4 ANNUAL FEE FOR THE THIRD CONTROL PERIOD AND REVISED CAPITAL COST FOR FY 2013-14 24
4 DETERMINATION OF SLDC OPERATING FEE FOR THE 3RD
CONTROL PERIOD 25
4.1 EMPLOYEE COST: 25
4.2 ADMINISTRATION AND GENERAL CHARGES: 26
4.3 REPAIRS AND MAINTENANCE COSTS: 26
4.4 SURPLUS CLAWED BACK 27
4.5 OPERATING CHARGES FOR THIRD CONTROL PERIOD: 28
5 SUMMARY – SLDC CHARGES 29
6 ANNEXURE-A 30
7 ANNEXURE-B 32
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LIST OF TABLES PAGE NO.
TABLE 1: OPERATION AND MAINTENANCE EXPENSES - APERC 10
TABLE 2: OPERATION AND MAINTENANCE EXPENSES - ACTUAL 11
TABLE 3: TRUE UP: OPERATION AND MAINTENANCE EXPENSES - VARIANCE 11
TABLE 1 : TRUE UP: INVESTMENT AND CAPITAL COST - VARIANCE 13
TABLE 5: TRUE UP: ACTUAL REVENUE 13
TABLE 6: TRUE UP: SURPLUS/(DEFICIT) FOR THE PERIOD FY 2008-09 TO FY 2012-13 14
TABLE 7: PROPOSED CAPITAL INVESTMENT FOR THE 3RD
CONTROL PERIOD 16
TABLE 8: CAPITAL COST FOR THE 3RD
CONTROL PERIOD 23
TABLE 9: ESTIMATED GENERATION CAPACITIES (MW) 24
TABLE 10: SLDC ANNUAL FEE FOR THE 3RD
CONTROL PERIOD 24
TABLE 11: PROJECION – OPERATION AND MAINTENANCE EXPENSES 245
TABLE 12: SLDC OPERATING FEE – 3RD
CONTROL PERIOD 28
TABLE 13: SUMMARY – FILING FOR SLDC FOR THE 3RD
CONTROL PERIOD 29
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1 Introduction
Pursuant to the applicable provisions of the Electricity Act, 2003 the State Government shall
establish a State Load Dispatch Center (SLDC). Section 31 (2) of the Act, provides that the said
SLDC shall be operated by a Government Company / Authority / Corporation constituted by or
under any State Act and that until such Company / Authority / Corporation is notified by the State
Government, the State Transmission Utility (STU) shall operate the SLDC. The Government of
AP notified in G.O.Ms.No. 8, dated 17-01-2004 that the existing SLDC shall continue as SLDC
and be operated by the APTransco being the STU, until the State Government establishes a
Government Company / Authority / Corporation. As a result APTransco is presently carrying out
solely, the Transmission & SLDC business as the State Transmission Utility (STU) in the state.
The purpose of this filing is to propose for levy and collection of annual fee and operating
charges of SLDC business. Section 32 (3) of the Electricity Act, 2003 provides for levy and
collection of such fees and charges from the generating companies and licensees engaged in the
intra-state transmission of electricity as may be specified by the State Commission.
As per the clause 6 of Regulation (Regulation No. 1 of 2006 dated July 27, 2006), on levy and
collection of fees and charges by State Load Dispatch, APTransco has to file with the
Commission, an application / petition for the second control period with statements containing
details of the Fee and Charges under its currently – approved levels of fee and charges along
with the proposals for the Third Control Period of 5 years for FY 2014-15 to FY 18-19.
In compliance with the APERC Regulations and Guidelines, APTransco, the State Transmission
Utility & Transmission licensee managing the SLDC business (as per G.O.Ms.No. 8 dated
17.01.2004) herein submits the following in this Petition:
i. Analysis of Performance of FY 2008-09 and Second Control period from
FY2009-10 to FY2012-13.
ii. Revised Estimates for FY2013-14
iii. Annual Fee for the Third Control Period (FY 2014-15 to FY 2018-19)
iv. Operating Charges for the Third Control Period (FY 2014-15 to FY 2018-19)
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2 True Up - Analysis of Performance from FY 2008-09 to FY 2012-13
APTRANSCO had filed for determination of ARR for SLDC for the 2nd control period (FY 2009-10
– FY 2013-14) and the Hon’ble commission had determined the ARR and charges based on
principles laid out in Regulation 1 of 2006.
The actual costs and revenue vary with the cost and revenue approved by APERC for the
2nd control period. Following is the variation w.r.t costs and revenue for the years FY 2008-09 to
FY 2012-13.
2.1 Operating Expenses True Up:
Operating Expenses consist of the following expenses:
Employee Expenses
Administration and General Expenses
Repair & Maintenance Expenses
Other Miscellaneous expenses
There is a significant variance in the actual employee expenses as compared to the expenses
approved by the Hon’ble commission. The salaries of employees of SLDC were revised in FY
2010-11. This contributed in an increase of employee expenses.
The details of the O&M expenses approved by the commission, actual O&M Expenses and
variation in expenses are as given below: in
Table 1: Operation and Maintenance Expenses - APERC
O&M Expenses - SLDC Tariff Order
Parameter Unit 2008-09 2009-10 2010-11 2011-12 2012-13 Total
Employee Cost INR Crs 19.19 19.36 21 22.85 24.85 107.25
Administration and
General Expenses INR Crs 2.77 2.89 3.14 3.42 3.71 15.93
Repair and
Maintenance
Expenses
INR Crs 2.92 3.66 3.96 4.24 4.46 19.24
Other Expenses INR Crs 0.04 - - - - 0.04
Cost Clawed back INR Crs - -1.58 - - - -1.58
Total Operating
Expenses INR Crs 24.92 24.33 28.10 30.51 33.02 140.88
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Table 2: Operation and Maintenance Expenses - Actual
O&M Expenses - Actual
Parameter Unit 2008-09 2009-10 2010-11 2011-12 2012-13 Total
Employee Cost INR Crs 16.67 19.29 31.2 34.53 38.63 140.32
Administration and
General Expenses INR Crs 2.40 2.73 3.41 4.07 4.60 17.21
Repair and
Maintenance
Expenses
INR Crs 5.35 4.92 5.12 4.56 4.79 24.74
Other Expenses INR Crs (0.06) - - - - (0.06)
Cost Clawed back INR Crs
-
Total Operating
Expenses INR Crs 24.36 26.94 39.73 43.16 48.02 182.21
Table 3: True Up: Operation and Maintenance Expenses - Variance
Deviation Deviation Deviation Deviation Deviation APERC Actual Deviation
Employee Cost INR Crs (2.52) (0.07) 10.20 11.68 13.78 107.25 140.32 33.07
Administration and General
ExpensesINR Crs
(0.37) (0.16) 0.27 0.65 0.89 15.93 17.21 1.28
Repair and Maintenance
ExpensesINR Crs
2.43 1.26 1.16 0.32 0.33 19.24 24.74 5.50
Other Expenses INR Crs (0.10) - - - - 0.04 (0.06) (0.10)
Cost Clawed back INR Crs - 1.58 - - - (1.58) - 1.58
Total Operating Expenses INR Crs (0.56) 2.61 11.63 12.65 15.00 140.88 182.21 41.33
O&M Expenses - APERC vis-à-vis Actual
Parameter Unit2008-09 2009-10 2010-11 2011-12 2012-13 Total
As could be seen from the above table, from year FY 2008-09 to FY 2012-13, Rs.41.33 Crs
excess expenditure was incurred than the approved expenditure. The employee expenditure
increased by Rs.33.07Crs, A&G expenditure increased by Rs.1.28Crs and Repairs &
Maintenance expenditure increased by Rs.5.5 Crs than the approved expenditure in the Tariff
Orders.
Almost 85% of the variance in O&M expenses is due to an increase in the Employee Expenses
during the 2nd control period. The employee expenses increased only after FY 2010-11 due to
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revision in pay for the employees of SLDC. This was already mentioned by APTRANSCO during
the filing of MYT for 2nd Control Period for SLDC activity.
The increase in repairs and maintenance cost is due to the AMC of EMS/ SCADA system as long
term service agreement has been entered with M/s Power Grid for AMC of EMS/ SCADA system
for three years from 01-01-07 to 31-12-09 with a provision for extension of the LTSA for a further
period of 2 years at the same prices, terms and conditions. The LTSA from 01-01-07 to 31-12-09
had offshore component which varied as per dollar exchange rate and hence, the charges for the
period varied. After completion of 01-01-07 to 31-12-09 period, Karnataka opted out of the LTSA
and as the supplier insisted on fixed amount for the southern region, Karnataka amount was
shared among rest of constituents and hence AMC charges increased. The LTSA payments are
made as per the MoU entered
Hence, the R&M expenses have increased during the control period. We would humbly request
the Hon’ble commission to consider the increase in expenses.
2.2 Capital Cost True Up:
Capital Cost approved in the Tarff Order would cover the repayment of principal and payment of
interest on investment in a year, plus any residual capital cost of past investment.
But, the actual Capital Cost varies from the Capital Cost approved by the Commission mainly
due to the following reasons:
The year on year actual investments made by SLDC do not match the investments envisaged by
the commission.
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The details of the capital cost incurred vis-à-vis the Hon’ble Commissions approved capital cost
is shown below table:
Table 4: True Up: Investment and Capital Cost - Variance
Capital Cost as per–Tariff Order
Parameter Unit 2008-09 2009-10 2010-11 2011-12 2012-13 Total
Residual/Annual
Investment INR Crs 26.37 9.16 9.76 9.69 4.83 59.81
Total Capital Cost INR Crs 4.11 5.54 7.06 8.57 9.32 34.59
Capital Cost as per – Actuals
Residual/Annual
Investment INR Crs 16.59 1.19 0.55 1.66 0.43 20.42
Total Capital Cost INR Crs 2.59 1.88 2.26 2.08 1.92 10.73
Difference in
Capital Cost INR Crs (1.52) (3.66) (4.80) (6.49) (7.40) (23.86)
The actual residual value at the begging of FY 2008-09 was INR 16.59 Crs Vis-à-vis INR 26.37
Crs estimated by the commission. The actual investments made during 2nd Control period are
less than the approved investments in the Tariff Order.
2.3 Revenue True Up:
Table 5: True Up: Actual Revenue
Revenue
Parameter Unit 2008-09 2009-10 2010-11 2011-12 2012-13 Total
Tariff Order INR Crs 29.03 29.87 35.16 39.08 42.34 175.47
Actual INR Crs 31.24 31.15 35.66 40.79 54.78 193.62
Difference INR Crs 2.21 1.28 0.5 1.71 12.44 18.15
The revenue has increased by around 10%. This is mainly due to increase in the number of
Open Access consumers in FY 2012-13.
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2.4 Surplus/ (Deficit) during the period FY 2008-09 to FY 2012-13
Table 6: True Up: Surplus/(Deficit) for the period FY 2008-09 to FY 2012-13
Surplus/(Deficit)
Parameter Unit 2008-09 2009-10 2010-11 2011-12 2012-13 Total
Actual Cost INR Crs
26.95
28.82
41.99
45.24
49.94
192.94
Actual Revenue INR Crs 31.24 31.15 35.66 40.79 54.78 193.62
Surplus/(Deficit) INR Crs 4.29 2.33 -6.33 -4.45 4.84 0.68
The total surplus estimated for the period FY 2008-09 to FY 2012-13 is INR 0.68 Crs. The
surplus would be passed on to consumers in the 3rd control period.
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3 Determination of SLDC Annual Fee for 3rd Control Period
The Hon’ble Commission has notified the Regulation No.1 on “Levy and collection of Fees and
Charges by SLDC” (Regulation No. 1 of 2006) dated July 27th 2006. As per the above regulation,
the APTRANSCO has to file an application for Annual Fee and Operating Charges for the Third
Control period of 5 years from FY 2014-15 to FY 2018-19.
Filing for Annual Fee
In compliance with Clause of Regulation 1 of 2006, APTRANSCO has to determine the Capital
cost for the period FY 2014-15 to FY 2018-19 based on the methodology suggested by the
Hon’ble commission and then compute the Annual SLDC charges. The Capital Cost covers the
repayment of principal and payment of interest on the investments made in a year
Annual SLDC Fee (Rs /MW/Annum) = (Capital Cost (CC) (in Rs) / Total Generation Capacity
(MW) )
APTRANSCO has computed the Annual SLDC charges based on the following methodology:
Estimation of Year on Year Investments for the period FY 2014-15 to FY 2018-19
Computation of Capital Cost based on methodology suggested by the Hon’ble
Commission
Determination of Year on Year Generation Capacity
Computation of SLDC Annual Charges
3.1 Capital Investments
The plan of Capital Assets to be added for SLDC Activity for the Five Year of 3rd Control Period
(FY 2014-15 to FY 2018-19) and Revised Estimates for FY2013-14 is shown in Table 7.
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Table 7: Proposed Capital Investment for the 3rd Control Period
Name of the
Wing
2013-14
(R.E) 2014-15 2015-16 2016-17 2017-138 2018-19
Grid Operation 12.03 0.89 0.77 0.73 0.78 0.69
Commercial/EBC - 0.16 0.23 0.12 0.13 0.15
Telecom 3.84 40.97 14.29 14.18 12.89 -
Power Systems - 0.01 0.34 0.21 1.34 0.05
Total 15.87 42.04 15.63 15.24 15.15 0.88
The new CapitalI Assets proposed to be added during the Third control period and the need for
such capital assets for SLDC business in each of the wings viz., Grid Operation,
Telecommunication, Power System and Commercial/Energy Billing Centre wings is detailed
below.
A. Grid Operation wing:
In the above investment plan, Grid Operation wing is proposed to upgrading the existing ULDC
SCADA system
The present ULDC SCADA system is over 10 years old and the hardware and software systems
are now getting obsolete. Hence, APSLDC is upgrading the existing ULDC SCADA system with
state of the art technology in consultation with Power Grid Corporation of India Limited along with
the other Southern Region constituents viz., Kerala, Pondicherry and SRLDC.
The project execution has commenced and it is scheduled to be commissioned by ending of FY
2013-14. Hence, the large capital investment proposed in FY 2013-14.
As per present security standards for critical infrastructure, redundancy of Control Centre is
essential. Hence, the Up gradation scheme seeks to implement a remotely located (in a different
seismic zone) fully functional replica Control Center, to which all the field locations report the
real-time data parallel, on a redundant communication path. The communication protocol is being
upgraded from the present serial communication link based IEC 60870-5-101 to the Ethernet
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based IEC 60870-5-104 for enhancing the data rate. For this purpose, the APTRANSCO
communication system is also being augmented.
The new system has a provision for the acquisition of data from over 1500 field locations by
means of newer communication protocols and hardware, as compared to the 140 field stations
now being monitored. Data Concentrator Cum Protocol Converters (DCPCs) will be located at 16
identified broadband locations for collecting data from the existing and new RTU stations, which
will report to the DCPC over IEC 60870-5-101 protocol. The DCPCs will in turn report to both the
main and backup SLDC over redundant communication routes, over IEC 60870-5-104 protocol.
The planned lifetime of the new project is 7 years as per the CERC regulations.
The new system provides the operators with new tools such as Complex Event Processing
(CEP) engines for enormous data storage and it’s near instantaneous retrieval; common
information model (CIM) based modeling and data exchange, Dispatcher Training Simulator
(DTS) for training, tools for better visualization of the SCADA Displays, to aid them in better Grid
Control and Visualization.
The Control Center will have a 6x3 Unit video projection system with each unit of size 70”
diagonal. This provides the operator with an excellent visualization for the large grid network.
This is in addition to the individual two monitor workstation provided to each operator.
A new DTS is also envisaged for training the operators on the new system. It will also aid the
new operators in getting trained before being posted on the job.
In view of the requirement of having SLDC data on the Internet, a dedicated APSLDC website
with real-time and historical data is being developed. The upgraded SCADA system also will
integrate seamlessly to this website with recommended cyber security systems and email
systems in tow.
The cyber security systems will have dedicated firewalls for internal and external networks apart
from IPS and IDS apart from online automated patch management solutions, antivirus solutions,
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file sharing mechanisms, and single point user authentication systems. A Network Management
System is also envisaged.
Historical Data of up to seven years will be available online in the new system. The backup of the
system software and data will also be automatically taken periodically at both local and remote
location on different media. The AMC of the new system will be done by the supplier for a period
of 6 Years after the mandatory 1 year warranty, post commissioning of the system. The AMC is
also part of the Project Tender itself.
In addition to that grid operation wing, also proposed to add the assets like computers, printers,
LCD Display units, up gradation of software for various PCs in the 3rd Control Period.
B. Telecom wing:
For strengthening and Modernization of Telecom equipment the following schemes are proposed
during the second control period.
a) Communication to Back up SLDC at Tirupathi :
The provision of communication system in Transmission network for Back up SLDC, at
Tirupathi is proposed in view of the Up-gradation of existing SCADA EMS system with
Main SLDC at Vidyut Soudha, Hyderabad and Back up SLDC, at Tirupathi.
The main thrust and emphasis is laid on:
i. Providing reliable real time data (of all 220KV and 400KV SS and Generators) to Grid
operators of SLDC.
ii. Providing of data connectivity to Back up SLDC which is a fully functional replica of
Main SLDC and which shall take over operation in case of any emergency.
iii. Providing high speed secured data route with redundancy for all RTU locations.
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The backup SLDC shall be a functional replica of Main SLDC so that it can function as a
full-fledged SLDC in case of any disaster. In this scheme, the full functionality of the
backup SLDC as far as the infrastructure is concerned shall be similar to the Main SLDC.
As per new SCADA EMS Up-gradation scheme proposal, all the existing and upcoming
RTUs would report to both the control centers i.e., Main SLDC & Back up SLDC preferable
over IEC 60870-5-104 protocol. RTUs coming through 101 protocol will be converted to
104 protocol through protocol convertor. Both the control centers Main and Back up will be
integrated with Distribution companies control centers as well as SRLDC, Bangalore on
ICCP links.
To meet the high speed multi data channel requirement, Optic Fibre based broadband
communication system is proposed in certain areas and Digital PLCC based
communication is proposed in certain links where execution of OFC works is difficult and
to have redundant data paths also.
Investment approval was accorded for the above scheme vide CRN:APT/TS/ULDC-up
gradation of communication/F-INVST-26/2012 by Hon’ble APERC.
b) ULDC Project commissioned during the year 2000-2002.
Power Grid and all constituents in Southern Region have implemented the Unified Load Dispatch
and Communication project for a sophisticated, reliable and secured load dispatch operations
with ALDCs, SLDCs and RLDC at Bangalore during the year 2000-2002 for transfer of real time
data from RTU location to ALDCs, SLDC and RLDC in Southern Region.
As a part of the ULDC project, the following systems are proposed:
Fibre Optic Transmission system (FOT) consisting of Optical line terminal equipment
(OLTEs)
Digital Microwave and MUX communication system with Network Management system
(NMS).
Laying of ADSS cable
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c) Up gradation of existing Marconi make OLTEs commissioned under ULDC:
M/s. Marconi make OLTEs were commissioned in ULDC project in Southern Region during 2000-
2002. The following difficulties were experienced during the maintenance of the equipment.
Up gradation / modification & rectification of software corruption to be carried out by OEM
only as the software is proprietary in nature.
There is no repairing facility in India, the faulty cards of these OLTEs shall be sent to M/s.
Marconi, Italy for repairs which involves customs duty assessment etc.
In view of the above, APTRANSCO has accorded approval for AMC of OLTEs with M/s.
Ericsson along with all other constituents of Southern Region up to 31-03-2009.
Due to change in technology, M/s. Ericsson had withdrawn the support of further
maintenance w.e.f. 01-04-2009 and advised for network modification or up-gradation with
new hardware and software.
In view of the above, PGCIL have conducted several meetings to arrive a solution and reached to
a conclusion along with all constituents and APTRANSCO opined to deliberate issue at SRPC.
CEA suggested for adoption of latest technology which will support to the PMU (Phasor
Measurement units) which would be a part of smart grid in near future. Hence along with other
constituents in Southern Region, APTRANSCO also agreed for up-gradation of existing SDH
fibre optic equipment (OLTE) commissioned under ULDC project for transfer of real time data
from RTU locations to 4 ALDCs, SLDC and thereon to RLDC.
Hence APTRANSCO proposed up gradation of OLTEs.
d) Up-gradation of existing MUX commissioned under ULDC:
Alcatel make MUX equipment and NMS installed in ULDC project in Southern Region were
maintained by the original OEM M/s. Alstom Transmission & Distribution system with separate
charges for repair/replacement of faulty cards with increase in the AMC charges @ 10% of
amount year by year up to 31.12.2012.
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During the year 2013, M/s. Alstom have increased the AMC by 15% on the existing AMC charges
due to change of technology and non-availability of spares and PGCIL also imposed the
overhead charges @ 15% over and above the contract price of AMC charges and M/s. Alstom
have not covered the rectification of faulty modules. APTRANSCO did not accept for increase in
AMC and PGCIL overhead charged and withdrawn from AMC and are presently being
maintained by APTRANSCO engineers with the available spare prints.
The present MUX equipment served more than 10years and also due to vast technology change
in communication system, it is necessary to upgrade the existing system. Hence we propose this
up gradation.
e) Replacement of existing ADSS cable laid under ULDC scheme by OPGW:
As per CERC Regulation of Grid code (IEGC) clause no. 4.6.2 reliable and efficient speech and
data communication system shall be provided to facilitate necessary communication and data
exchange and supervision/control of grid.
Subsequent to the commissioning of ULDC, volume of data and no. of substations/generating
stations have increased considerably. Number of hops for data transmission is increasing with
expansion of network. In addition to the requirement of communication system for SCADA
system, Special Protection schemes (SPS) are to be implemented and installation of PMUs and
Grid Security Expert System (GSES) are also envisaged. Each PMU requires minimum 64kbps
bandwidth. SPS requires transfer of signals over no. of hops. These additional requirements of
communication for the existing and upcoming substations can’t be met unless provided with
OPGW based communication link.
The ADSS cable laid under ULDC project have served more than 10years life period and giving
frequent problems. Due to change in technology and introduction of OPGW cable (Optical fibre
with ground wire), it is proposed to lay OPGW cable in place of ADSS cable because of dual
functionality of grounding and communication and most preferred aerial cable considering fibre
security and long life for transfer of real time data from RTU locations to 4 ALDCs, SLDC and
thereon to RLDC.
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C. Energy Billing Center wing:
EBC wing of SLDC, is receiving Boundary meters (Generation to Transmission and Transmission
to Discoms) MRI data, manual readings from the field and on processing the above data through
various Billing applications could able to generate Transco-Discom Energy certificate, Discom-
Discom Energy & cost settlements reports and also generating Transmission Losses data for
various purposes. EBC has also developed software for Open Access users within state as per
APERC Regulation No. 2 of 2005 & Regulation No. 2 of 2006 which is web based application. All
the Open Access users as per Regulation 2 of 2006 may have to send or receive the relevant
data through this application. Further Open Access users can also view /download various
settlement data through this application.
EBC proposes to procure new Furniture, H.P Proline server (2Nos) to replace existing old
servers ,Printers for HP Color Laser Jet and also proposed provide dedicated leased line
Internet Service to its center in the 3rd Control Period for smooth functioning of Energy Billing
Center. Presently limited open access users are existing the same is expected to increase in due
course of time, for which necessary software with applicable licenses are needed to improve the
accessibility of web application to open access users. As such the propose infrastructure shown
in the investment plan is very essential
D. Power Systems:
Proposed to upgrade the outdated software currently in use for System Software, Generation
Planning Software, Transmission Planning Software and Load Forecast software.
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3.2 Capital Cost Projection
Based on the capital investments shown above and 12% interest rate, the capital cost computed
as per APERC methodology is shown below:
Table 8: Capital Cost for the 3rd Control Period
Parameter Unit 2014-15 2015-16 2016-17 2017-18 2018-19 Total
Capital Cost on new
investmentINR Crs 7.44 2.73 2.66 2.64 0.16 15.63
Capital Cost on Residual
investmentINR Crs 6.05 13.49 16.22 18.88 21.52 76.16
Total Capital Cost INR Crs 13.49 16.22 18.88 21.52 21.68 91.79
Capital Cost - 3rd Control Period
The capital cost based on the residual value of asset at the end of FY 2012-13 and the
investments made during FY 2013-14 is INR 5.3 Crs Vis-à-vis INR 10.09 Crs approved by the
commission.
The residual value of assets at the end of 2013-14 has been considered to be INR 34.2 Crs. The
asset value at the beginning of FY 2013-14 was INR 18.33 Crs and the investments expected to
be made during FY 2013-14 is INR 15.87 Crs
The capital cost of this residual value and the annual capital investments is INR 91.79 Crs over
the 3rd Control Period.
3.3 Total Generation Capacity:
The total generation capacity estimated, including the capacity related to Open Access
consumers over the next five years is as shown below:
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Table 9: Estimated Generation Capacities (MW)
S.No Source of Power 2014-15 2015-16 2016-17 2017-18 2018-19
I APGENCO 11330 11449 11449 12050 12790
A Thermal 7252 7252 7252 7853 8593
B Hydro 4078 4197 4197 4197 4197
II Central Generating
Stations 3669 3669 4372 4477 4477
III Joint Setor 57 57 57 57 57
IV IPPS 2426 2426 2426 2426 2426
V Others (NCE, M PP’s
etc, wind, Mini Hydel) 3606 5859 6576 6993 7361
Total 21088 23460 24881 26003 27110
VI Open Acess Generators 672 672 672 672 672
Grand Total 21761 24132 25553 26675 27782
Note:- Generating Station-wise details are shown in Annexures –B 1 to 5
3.4 Annual Fee for the Third Control Period and Revised Capital Cost for FY 2013-14
Table 10: SLDC Annual Fee for the 3rd Control Period
Parameter 2014-15 2015-16 2016-17 2017-138 2018-19
Capital Cost (INR Crs) 13.49 16.22 18.88 21.52 21.68
Generation
Capacity(MW) 21761 24132 25553 26675 27782
SLDC Annual Fee
(INR/MW/Annum) 6199 6721 7389 8069 7804
The Annual fee for the Third control period has been calculated based on the total capital cost
for the Third control period on total generation capacity as per SLDC regulation.
The Annual fee for the year FY 2014-15 is Rs.6199 MW/p.a, for the FY 2015-16 is
Rs.6121MW/p.a, for the FY 2016-17 is Rs.7389 MW/p.a, for the year FY 2017-18 is
Rs.8069MW/p.a, for the year FY 2018-19 is Rs.7804 MW/p.a.
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4 Determination of SLDC Operating Fee for the 3rd Control Period
As per the guidelines given by the Commission vide para 4.5 of the regulation (Regulation
No.1/2006) the basis for determination of the Operating Charges are based on the Employee
cost, Administration and General Charges, Repairs and Maintenance expenses and other
relevant costs.
The details of the Annual Operating charges i.e. Employee cost, Administration and General
charges, Repairs and Maintenance charges and other charges are shown in the table below:
Table 11: Projection – Operation and Maintenance Expenses
Parameter Unit Base Year/
2013-14(R.E) 2014-15 2015-16 2016-17 2017-18 2018-19
Employee Cost INR Crs 47.66
58.81
72.55
89.52
110.45 136.27
Administration and
General Expenses INR Crs 5.41
6.37
7.49
8.82
10.37 12.21
Repair and
Maintenance
Expenses
INR Crs 5.05 8.17 4.71 5.39 5.62 5.37
Other Expenses INR Crs - - -
- - -
Surplus in 2nd
Control
Period – Clawed back INR Crs -
(0.68)
Total Operating Expenses
INR Crs 58.12 72.66 84.76 103.73 126.44 153.85
4.1 Employee Cost:
The employee cost for the base year FY 2013-14 has been projected based on the actual growth
rate observed in the employee expenses observed during the period FY 2008-09 to FY 2012-13.
Employee Expenses for 13-14 = (Employee Expenses for 12-13) * (CAGR (Emp exp 12-13/ Emp
exp 08-09))
The same growth rate has also been considered for projecting the employee expenses for the
3rd control period.
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The employee cost, other than the salaries of the personnel, also contain the following
components:
Surrender leave
Various medical allowances
Other Allowances and pension contribution
Next wage revision is due with effect from 1st April 20104. The financial commitment of wage
revision will be claimed based on actuals
4.2 Administration and General Charges:
The Administration and General(A&G) cost for the base year FY 2013-14 has been projected
based on the actual growth rate observed in the A&G expenses observed during the period FY
2008-09 to FY 2012-13.
A&G Expenses for 13-14 = (A&G Expenses for 12-13) * (CAGR (A&G exp 12-13/ A&G exp 08-
09))
The same growth rate has also been considered for projecting the A&G expenses for the 3rd
control period.
4.3 Repairs and Maintenance Costs:
As per the clause No. 7 of Regulation 2/2006, the Energy Billing Center is also considered as the
SLDC Business. Therefore the assets of SLDC Business are mainly in Grid Operation unit,
Energy Billing Center and Telecom units. At present the Telecom unit assets are shared by the
Transmission business as well as SLDC business.
However for the purposes of calculation of operating charges certain amount of Repairs and
Maintenance expenses have been considered in the SLDC business.
These costs are primarily for the RTU’s and the SCADA system. The repairs & Maintenance
expenditure is projected based on the requirements of each wing.
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A. EBC:
For smooth operations of Open Access and data collection system the following are essentially
required for AMC viz: Servers, Workstations, HUBs, Switches and procurement of consumables
like Printer cartridges and data cartridges to take the database backup and other computer
consumables for use in EBC wing is included in R&M cost.
B. Grid Operation:
The R&M expenditure projections cover for Annual Maintenance Charges for the following
equipment available in Grid Operation wing.
AMC of EMS/SCADA system till the up gradation of EMS/SCADA system gets completed,
AMC of new EMS/SCADA .
AMC of UPS systems at SLDC, ALDCs and Backup SLDC.
AMC of Air Conditioning Units at SLDC, ALDCs and Backup SLDC.
AMC of DG sets at SLDC, ALDCs.
AMC of HP Servers, PCs and printers at SLDC & ALDCs.
AMC of networking equipment at SLDC, ALDCs and Backup SLDC.
Further for regular maintenance the consumables are required for computer systems, printers
and other equipment
C. Telecom:
The repairs and maintenance cost of Telecom wing is projected due to AMC contracts of OLTEs
and MUXS with different vendors and regular maintenance of Micro wave links.
4.4 Surplus clawed back
There was a surplus of INR 0.68 Crs during the 2nd control period. We propose to pass on this
surplus to the consumers in FY 2014-15.
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4.5 Operating Charges for Third Control Period: As per the regulation no .1 of 2006 the Operating charges are calculated by following formula
prescribed in the regulation.
Operating Charges (Rs / MW /pm) =( Annual Operating charges/ Total Generating Capacity
(MW) * 12)
The details of the Operating charges as shown in Table 9
Table 22: SLDC Operating Charges – 3rd Control Period
Parameter 2014-15 2015-16 2016-17 2017-138 2018-19
Operating Expenses
(INR Crs) 72.66 84.76 103.73 126.44 153.85
Generation
Capacity(MW) 21761 24132 25553 26675 27782
SLDC Operating
Charges
(INR/MW/Month)
2783 2927 3383 3950 4615
The Monthly Operating Charges for the year 2014-15 is Rs. 2783 / MW / month, for the year
2015-16 is Rs. 2,927 /MW/month, for the year 2016-17 is Rs3,383 /MW/month, for the year 2017-
18 is Rs. 3950/ MW /month and for the year 2018-19 is Rs. 4615/MW/month.
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5 Summary – SLDC Charges The summary of SLDC Annual Fee and SLDC Operating Charges computed:
Table 33: Summary – Filing for SLDC for the 3rd Control Period
Summary - SLDC MYT Filing
Parameter Unit 14-15 15-16 16-17 17-18 18-19 Total
Capital Cost INR Crs 13 16 19 22 22 92
Employee Expenses INR Crs 59 73 90 110 136 468
A&G Expenses INR Crs 6 7 9 10 12 45
R&M Expenses INR Crs 8 5 5 6 5 29
Other Expenses INR Crs (0.68) - - - - (1)
O&M Expenses INR Crs 73 85 104 126 154 541
Total Cost INR Crs 86 101 123 148 176 633
Generation Capacity MW 21760 24132 25553 26675 27782
Annual Fee INR/MW/Annum 6199 6721 7389 8069 7804
Operating Charge INR/MW/Month 2783 2927 3383 3950 4615
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6 ANNEXURE-A
LIST OF DIRECTIVES FOR SECOND CONTROL PERIOD
Dir. No.
Description of Directive
Status
1 APTRANSCO shall segregate the SLDC accounts in full shape within
a year, i.e. by 31st March 2010 and also immediately start maintaining
separate asset registers on prospective basis. These asset registers
will be inspected by the Commission Staff, from time to time.
(Paragraph 28)
The directive is complied with
2 APTRANSCO shall file the details of completed capital works
pertaining to SLDC operations along with Project Completion
Certificate (PCC) and Financial Completion Certificate (FCC) as is
being done for transmission projects. APTRANSCO shall also file a
monthly report with the Commission on progress in capital works
pertaining to SLDC operations by 25th of every month for the previous
month.
(Paragraph 29)
The directive is complied with
3 APTRANSCO shall file with the Commission an approach paper on its
OFC network duly indicating a) existing capacities, b) planned future
capacities c) expected surplus capacity available and d) possible
ways and means to utilize the surplus capacity by November 30,
2009.
(Paragraph 30)
The directive is complied with
4. APTRANSCO to collect variable cost information including backing
down limitation from each generating station on daily basis along with
generation schedule for a complete period of three months. Using this
information, it should analyze the perceived merit order benefits on
expost basis for the three months period and make a presentation on
this issue to the Commission by December 31, 2009.
(Paragraph 35)
The directive is complied with
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5. APTRANSCO shall file the actual costs and revenues by 25th of every
month for the previous month in the format prescribed for this purpose
by the Commission. APTRANSCO may also state its own
observations on cost, revenues and capacities along with the monthly
report.
(Paragraph 48)
The directive is complied with
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7 ANNEXURE-B
Generating Capacities FY 2014-15
Source of Power Plant Capacity A.P.share A.P.share
A.P. share Excl. Aux. Consm.
(MW) (%) (MW) (MW)
I APGENCO
VTPS I 420 100.00% 420.00 383.25
VTPS II 420 100.00% 420.00 383.25
VTPS III 420 100.00% 420.00 383.25
VTPS IV 500 100.00% 500.00 462.50
RTPP I 420 100.00% 420.00 382.20
RTPP-II 420 100.00% 420.00 382.20
RTPP-III 210 100.00% 210.00 191.63
KTPS A 240 100.00% 240.00 216.72
KTPS B 240 100.00% 240.00 216.72
KTPS C 240 100.00% 240.00 216.72
KTPS D 500 100.00% 500.00 455.00
KTPS VI 500 100.00% 500.00 462.50
RTS B 62.5 100.00% 62.50 56.88
Kakatiya TPS Stage 1 500 100.00% 500.00 462.50
Kakatiya TPS Stage II 600 100.00% 600.00 555.00
Damodaram Sanjeevaiah Thermal Power Plant-I 800 100.00% 800.00 748.00
Damodaram Sanjeevaiah Thermal Power Plant-II 800 100.00% 800.00 748.00
RTPP-IV 600 100.00% 600.00 546.00
TOTAL THERMAL 7892.5
7892.5 7252.31
MACHKUND PH AP Share 120 70.00% 84.00 83.16
TUNGBHADRA PH AP Share 72 80.00% 57.60 57.02
USL 240 100.00% 240.00 237.60
LSR 460 100.00% 460.00 455.40
DONKARAYI 25 100.00% 25.00 24.75
SSLM 770 100.00% 770.00 762.30
SSLM LCPH 900 100.00% 900.00 891.00
NSPH 815.6 100.00% 815.60 807.44
NSRCPH 90 100.00% 90.00 89.10
NSLCPH 60 100.00% 60.00 59.40
POCHAMPAD PH 27 100.00% 27.00 26.73
NIZAMSAGAR PH 10 100.00% 10.00 9.90
PABM 20 100.00% 20.00 19.80
SINGUR 15 100.00% 15.00 14.85
MINI HYDRO&OTHERS 12.16 100.00% 12.16 12.04
Priyadarshini JURALA HES 234 100.00% 234.00 231.66
POCHAMPAD Stg II 9 100.00% 9.00 8.91
Nagarjuna Sagar Tail Pond 50 100.00% 50.00 49.50
Lower Jurala Hydro Electric (New Project) 240 100.00% 240.00 237.60
TOTAL HYDRO 4169.76
4119.36 4078.17
Total A.P. Genco 12062.26
12011.86 11330.48
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II Central Generating Stations (CGS)
NTPC(SR) Ramagundam- U1-U6 2100 32.32% 678.72 629.78
NTPC (SR) Ramagundam -U7 500 33.92% 169.60 158.58
NLC TS-II Stage-I 630 18.33% 115.48 103.93
NLC TS-II Stage-II 840 24.33% 204.37 183.93
NPC-MAPS 440 9.90% 43.56 38.99
Talcher Stage 2 2000 20.00% 400.00 374.00
NTPC- Simhadri Stage I 1000 100.00% 1000.00 940.00
NTPC- Simhadri Stage II 1000 46.01% 460.10 432.49
Kaiga Nuclear power Plant I&II 440 30.82% 135.61 121.37
Kaiga Nuclear power Plant III&IV 440 32.64% 143.62 128.54
Vallur Thermal Power Plant 1500 14.75% 221.25 206.87
Kalpakkam 500 26.40% 132.00 116.16
Tutricorn 1000 25.46% 254.60 234.23
Total Central Sector 12390
3958.91 3668.87
III Joint sector
APGPCL-I 100 16.00% 16.00 15.60
APGPCL-I 172 24.88% 42.79 41.72
Total Joint Sector 272
58.79 57.32
IV IPPs
GVK 216 100.00% 216.00 209.52
Spectrum 205 100.00% 205.00 198.85
Kondapalli 361.92 100.00% 361.92 351.06
BSES 220 100.00% 220.00 213.40
GVK Extension 220 100.00% 220.00 213.40
Vemagiri 370 100.00% 370.00 358.90
Gowthami 464 100.00% 464.00 450.08
Konaseema 444.08 100.00% 444.08 430.76
Total IPPS 2501
2501.00 2425.97
V Non Conventional Sources
Total Non conventional sources 2114.33 100.00% 2114.33 2114.33
VI Mini Power Projects
1 Sri Vatsa power Projects Limited 17.2 100.00% 17.20 16.51
2 M/s LVS Power Limited 36.8 100.00% 36.80 35.33
Total MPPS 54
54 51.84
VII OTHERS
Hinduja 1040
1040.00 1040.00
KSK Mahanadi 400
400.00 400.00
Total Others 1440
1440 1440
VIII Open Access Generators
Total Open Access Generators 671.8
671.8 671.8
Grand Total 31505.39
22810.69 21760.61
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2015-16
Source of Power Plant
Capacity A.P.share A.P.share
A.P. share Excl. Aux. Consm.
(MW) (%) (MW) (MW)
I APGENCO
VTPS I 420 100.00% 420.00 383.25
VTPS II 420 100.00% 420.00 383.25
VTPS III 420 100.00% 420.00 383.25
VTPS IV 500 100.00% 500.00 462.50
RTPP I 420 100.00% 420.00 382.20
RTPP-II 420 100.00% 420.00 382.20
RTPP-III 210 100.00% 210.00 191.63
KTPS A 240 100.00% 240.00 216.72
KTPS B 240 100.00% 240.00 216.72
KTPS C 240 100.00% 240.00 216.72
KTPS D 500 100.00% 500.00 455.00
KTPS VI 500 100.00% 500.00 462.50
RTS B 62.5 100.00% 62.50 56.88
Kakatiya TPS Stage 1 500 100.00% 500.00 462.50
Kakatiya TPS Stage II 600 100.00% 600.00 555.00
Damodaram Sanjeevaiah Thermal Power Plant-I 800 100.00% 800.00 748.00
Damodaram Sanjeevaiah Thermal Power Plant-II 800 100.00% 800.00 748.00
RTPP-IV 600 100.00% 600.00 546.00
TOTAL THERMAL 7892.5
7892.5 7252.31
MACHKUND PH AP Share 120 70.00% 84.00 83.16
TUNGBHADRA PH AP Share 72 80.00% 57.60 57.02
USL 240 100.00% 240.00 237.60
LSR 460 100.00% 460.00 455.40
DONKARAYI 25 100.00% 25.00 24.75
SSLM 770 100.00% 770.00 762.30
SSLM LCPH 900 100.00% 900.00 891.00
NSPH 815.6 100.00% 815.60 807.44
NSRCPH 90 100.00% 90.00 89.10
NSLCPH 60 100.00% 60.00 59.40
POCHAMPAD PH 27 100.00% 27.00 26.73
NIZAMSAGAR PH 10 100.00% 10.00 9.90
PABM 20 100.00% 20.00 19.80
SINGUR 15 100.00% 15.00 14.85
MINI HYDRO&OTHERS 12.16 100.00% 12.16 12.04
Priyadarshini JURALA HES 234 100.00% 234.00 231.66
POCHAMPAD Stg II 9 100.00% 9.00 8.91
Nagarjuna Sagar Tail Pond 50 100.00% 50.00 49.50
Lower Jurala Hydro Electric (New Project) 240 100.00% 240.00 237.60
Pulichintala 120 100.00% 120.00 118.80
TOTAL HYDRO 4289.76
4239.36 4196.97
Total A.P. Genco 12182.26
12131.86 11449.28
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II Central Generating Stations (CGS) NTPC(SR) Ramagundam- U1-U6 2100 32.32% 678.72 629.78
NTPC (SR) Ramagundam -U7 500 33.92% 169.60 158.58
NLC TS-II Stage-I 630 18.33% 115.48 103.93
NLC TS-II Stage-II 840 24.33% 204.37 183.93
NPC-MAPS 440 9.90% 43.56 38.99
Talcher Stage 2 2000 20.00% 400.00 374.00
NTPC- Simhadri Stage I 1000 100.00% 1000.00 940.00
NTPC- Simhadri Stage II 1000 46.01% 460.10 432.49
Kaiga Nuclear power Plant I&II 440 30.82% 135.61 121.37
Kaiga Nuclear power Plant III&IV 440 32.64% 143.62 128.54
Vallur Thermal Power Plant 1500 14.75% 221.25 206.87
Kalpakkam 500 26.40% 132.00 116.16
Tutricorn 1000 25.46% 254.60 234.23
Total Central Sector 12390
3958.91 3668.87
III Joint sector APGPCL-I 100 16.00% 16.00 15.60
APGPCL-I 172 24.88% 42.79 41.72
Total Joint Sector 272
58.79 57.32
IV IPPs GVK 216 100.00% 216.00 209.52
Spectrum 205 100.00% 205.00 198.85
Kondapalli 361.92 100.00% 361.92 351.06
BSES 220 100.00% 220.00 213.40
GVK Extension 220 100.00% 220.00 213.40
Vemagiri 370 100.00% 370.00 358.90
Gowthami 464 100.00% 464.00 450.08
Konaseema 444.08 100.00% 444.08 430.76
Total IPPS 2501
2501 2425.97
V Non Conventional Sources Total Non conventional sources 2817.33 100.00% 2817.33 2817.33
VI Mini Power Projects 1 Sri Vatsa power Projects Limited 17.2 100.00% 17.20 16.51
2 M/s LVS Power Limited 36.8 100.00% 36.80 35.33
Total MPPS 54
54 51.84
VII OTHERS Hinduja 1040
1040.00 1040.00
KSK Mahanadi 400
400.00 400.00
Singareni 1050
1050.00 1050.00
Thermal Power Tech 500
500.00 500.00
Total Others 2990
2990.00 2990.00
VIII Open Access Generators Total Open Access Generators 671.8
671.8 671.8
Grand Total 36196.59
25183.69 24132.41
Filing of ARR & FPT of SLDC business for the Third Control Period (FY2014-15 to FY2018 –19)
36
2016-17
Source of Power Plant Capacity A.P.share A.P.share
A.P. share Excl. Aux.
Consm.
(MW) (%) (MW) (MW)
I APGENCO
VTPS I 420 100.00% 420.00 383.25
VTPS II 420 100.00% 420.00 383.25
VTPS III 420 100.00% 420.00 383.25
VTPS IV 500 100.00% 500.00 462.50
RTPP I 420 100.00% 420.00 382.20
RTPP-II 420 100.00% 420.00 382.20
RTPP-III 210 100.00% 210.00 191.63
KTPS A 240 100.00% 240.00 216.72
KTPS B 240 100.00% 240.00 216.72
KTPS C 240 100.00% 240.00 216.72
KTPS D 500 100.00% 500.00 455.00
KTPS VI 500 100.00% 500.00 462.50
RTS B 62.5 100.00% 62.50 56.88
Kakatiya TPS Stage 1 500 100.00% 500.00 462.50
Kakatiya TPS Stage II 600 100.00% 600.00 555.00
Damodaram Sanjeevaiah Thermal Power Plant-I 800 100.00% 800.00 748.00
Damodaram Sanjeevaiah Thermal Power Plant-II 800 100.00% 800.00 748.00
RTPP-IV 600 100.00% 600.00 546.00
TOTAL THERMAL 7892.5
7892.5 7252.31
MACHKUND PH AP Share 120 70.00% 84.00 83.16
TUNGBHADRA PH AP Share 72 80.00% 57.60 57.02
USL 240 100.00% 240.00 237.60
LSR 460 100.00% 460.00 455.40
DONKARAYI 25 100.00% 25.00 24.75
SSLM 770 100.00% 770.00 762.30
SSLM LCPH 900 100.00% 900.00 891.00
NSPH 815.6 100.00% 815.60 807.44
NSRCPH 90 100.00% 90.00 89.10
NSLCPH 60 100.00% 60.00 59.40
POCHAMPAD PH 27 100.00% 27.00 26.73
NIZAMSAGAR PH 10 100.00% 10.00 9.90
PABM 20 100.00% 20.00 19.80
SINGUR 15 100.00% 15.00 14.85
MINI HYDRO&OTHERS 12.16 100.00% 12.16 12.04
Priyadarshini JURALA HES 234 100.00% 234.00 231.66
POCHAMPAD Stg II 9 100.00% 9.00 8.91
Nagarjuna Sagar Tail Pond 50 100.00% 50.00 49.50
Lower Jurala Hydro Electric (New Project) 240 100.00% 240.00 237.60
Pulichintala 120 100.00% 120.00 118.80
TOTAL HYDRO 4289.76
4239.36 4196.97
Total A.P. Genco 12182.26
12131.86 11449.28
Filing of ARR & FPT of SLDC business for the Third Control Period (FY2014-15 to FY2018 –19)
37
II Central Generating Stations (CGS) NTPC(SR) Ramagundam- U1-U6 2100 32.32% 678.72 629.78
NTPC (SR) Ramagundam -U7 500 33.92% 169.60 158.58
NLC TS-II Stage-I 630 18.33% 115.48 103.93
NLC TS-II Stage-II 840 24.33% 204.37 183.93
NPC-MAPS 440 9.90% 43.56 38.99
Talcher Stage 2 2000 20.00% 400.00 374.00
NTPC- Simhadri Stage I 1000 100.00% 1000.00 940.00
NTPC- Simhadri Stage II 1000 46.01% 460.10 432.49
Kaiga Nuclear power Plant I&II 440 30.82% 135.61 121.37
Kaiga Nuclear power Plant III&IV 440 32.64% 143.62 128.54
Vallur Thermal Power Plant 1500 14.75% 221.25 206.87
Kalpakkam 500 26.40% 132.00 116.16
Tutricorn 1000 25.46% 254.60 234.23
Kudigi I & II 4000 18.70% 748.00 703.12
Total Central Sector 16390
4706.91 4371.99
III Joint sector APGPCL-I 100 16.00% 16.00 15.60
APGPCL-I 172 24.88% 42.79 41.72
Total Joint Sector 272
58.79 57.32
IV IPPs GVK 216 100.00% 216.00 209.52
Spectrum 205 100.00% 205.00 198.85
Kondapalli 361.92 100.00% 361.92 351.06
BSES 220 100.00% 220.00 213.40
GVK Extension 220 100.00% 220.00 213.40
Vemagiri 370 100.00% 370.00 358.90
Gowthami 464 100.00% 464.00 450.08
Konaseema 444.08 100.00% 444.08 430.76
Total IPPS 2501
2501 2425.97
V Non Conventional Sources Total Non conventional sources 3534.33 100.00% 3534.33 3534.33
VI Mini Power Projects 1 Sri Vatsa power Projects Limited 17.2 100.00% 17.20 16.51
2 M/s LVS Power Limited 36.8 100.00% 36.80 35.33
Total MPPS 54
54 51.84
VII OTHERS Hinduja 1040
1040.00 1040.00
KSK Mahanadi 400
400.00 400.00
Singareni 1050
1050.00 1050.00
Thermal Power Tech 500
500.00 500.00
Total Others 2990
2990 2990
VIII Open Access Generators Total Open Access Generators 671.8
671.8 671.8
Grand Total 38595.39
26648.69 25552.53
Filing of ARR & FPT of SLDC business for the Third Control Period (FY2014-15 to FY2018 –19)
38
2017-18
Source of Power Plant Capacity A.P.share A.P.share A.P. share Excl. Aux Consm.
(MW) (%) (MW) (MW)
I APGENCO
VTPS I 420 100.00% 420.00 383.25
VTPS II 420 100.00% 420.00 383.25
VTPS III 420 100.00% 420.00 383.25
VTPS IV 500 100.00% 500.00 462.50
RTPP I 420 100.00% 420.00 382.20
RTPP-II 420 100.00% 420.00 382.20
RTPP-III 210 100.00% 210.00 191.63
KTPS A 240 100.00% 240.00 216.72
KTPS B 240 100.00% 240.00 216.72
KTPS C 240 100.00% 240.00 216.72
KTPS D 500 100.00% 500.00 455.00
KTPS VI 500 100.00% 500.00 462.50
RTS B 62.5 100.00% 62.50 56.88
Kakatiya TPS Stage 1 500 100.00% 500.00 462.50
Kakatiya TPS Stage II 600 100.00% 600.00 555.00
Damodaram Sanjeevaiah Thermal Power Plant-I 800 100.00% 800.00 748.00
Damodaram Sanjeevaiah Thermal Power Plant-II 800 100.00% 800.00 748.00
RTTP-IV 600 100.00% 600.00 546.00
Ramagundam-C 660 100.00% 660.00 600.60
TOTAL THERMAL 8552.5 8552.50 7852.91
MACHKUND PH AP Share 120 70.00% 84.00 83.16
TUNGBHADRA PH AP Share 72 80.00% 57.60 57.02
USL 240 100.00% 240.00 237.60
LSR 460 100.00% 460.00 455.40
DONKARAYI 25 100.00% 25.00 24.75
SSLM 770 100.00% 770.00 762.30
SSLM LCPH 900 100.00% 900.00 891.00
NSPH 815.6 100.00% 815.60 807.44
NSRCPH 90 100.00% 90.00 89.10
NSLCPH 60 100.00% 60.00 59.40
POCHAMPAD PH 27 100.00% 27.00 26.73
NIZAMSAGAR PH 10 100.00% 10.00 9.90
PABM 20 100.00% 20.00 19.80
SINGUR 15 100.00% 15.00 14.85
MINI HYDRO&OTHERS 12.16 100.00% 12.16 12.04
Priyadarshini JURALA HES 234 100.00% 234.00 231.66
POCHAMPAD Stg II 9 100.00% 9.00 8.91
Nagarjuna Sagar Tail Pond 50 100.00% 50.00 49.50
Lower Jurala Hydro Electric (New Project) 240 100.00% 240.00 237.60
Pulichintala 120 100.00% 120.00 118.80
TOTAL HYDRO 4289.76 4239.36 4196.97
Total A.P. Genco 12842.26 12791.86 12049.88
Filing of ARR & FPT of SLDC business for the Third Control Period (FY2014-15 to FY2018 –19)
39
II Central Generating Stations (CGS)
NTPC(SR) Ramagundam- U1-U6 2100 32.32% 678.72 629.78
NTPC (SR) Ramagundam -U7 500 33.92% 169.60 158.58
NLC TS-II Stage-I 630 18.33% 115.48 103.93
NLC TS-II Stage-II 840 24.33% 204.37 183.93
NPC-MAPS 440 9.90% 43.56 38.99
Talcher Stage 2 2000 20.00% 400.00 374.00
NTPC- Simhadri Stage I 1000 100.00% 1000.00 940.00
NTPC- Simhadri Stage II 1000 46.01% 460.10 432.49
Kaiga Nuclear power Plant I&II 440 30.82% 135.61 121.37
Kaiga Nuclear power Plant III&IV 440 32.64% 143.62 128.54
Vallur Thermal Power Plant 1500 14.75% 221.25 206.87
Kalpakkam 500 26.40% 132.00 116.16
Tutricorn 1000 25.46% 254.60 234.23
Kudigi I & II 4000 18.70% 748.00 703.12
Neyveli 1000 11.37% 113.70 104.60
Total Central Sector 17390 4820.61 4476.60
III Joint sector
APGPCL-I 100 16.00% 16.00 15.60
APGPCL-I 172 24.88% 42.79 41.72
Total Joint Sector 272 58.79 57.32
IV IPPs
GVK 216 100.00% 216.00 209.52
Spectrum 205 100.00% 205.00 198.85
Kondapalli 361.92 100.00% 361.92 351.06
BSES 220 100.00% 220.00 213.40
GVK Extension 220 100.00% 220.00 213.40
Vemagiri 370 100.00% 370.00 358.90
Gowthami 464 100.00% 464.00 450.08
Konaseema 444.08 100.00% 444.08 430.76
Total IPPS 2501 2501 2425.97
V Non Conventional Sources
Total Non conventional sources 3951.33 100.00% 3951.33 3951.33
VI Mini Power Projects
1 Sri Vatsa power Projects Limited 17.2 100.00% 17.20 16.51
2 M/s LVS Power Limited 36.8 100.00% 36.80 35.33
Total MPPS 54 54 51.84
VII OTHERS
Hinduja 1040 1040.00 1040.00
KSK Mahanadi 400 400.00 400.00
Singareni 1050 1050.00 1050.00
Thermal Power Tech 500 500.00 500.00
Total Others 2990 2990 2990
VIII Open Access Generators
Total Open Access Generators 671.8 671.8 671.8
Grand Total 40672.39 27839.39 26674.74
Filing of ARR & FPT of SLDC business for the Third Control Period (FY2014-15 to FY2018 –19)
40
2018-19
Source of Power Plant Capacity A.P.share A.P.share A.P. share Excl.
Aux Consm.
(MW) (%) (MW) (MW)
I APGENCO
VTPS I 420 100.00% 420.00 383.25
VTPS II 420 100.00% 420.00 383.25
VTPS III 420 100.00% 420.00 383.25
VTPS IV 500 100.00% 500.00 462.50
RTPP I 420 100.00% 420.00 382.20
RTPP-II 420 100.00% 420.00 382.20
RTPP-III 210 100.00% 210.00 191.63
KTPS A 240 100.00% 240.00 216.72
KTPS B 240 100.00% 240.00 216.72
KTPS C 240 100.00% 240.00 216.72
KTPS D 500 100.00% 500.00 455.00
KTPS VI 500 100.00% 500.00 462.50
RTS B 62.5 100.00% 62.50 56.88
Kakatiya TPS Stage 1 500 100.00% 500.00 462.50
Kakatiya TPS Stage II 600 100.00% 600.00 555.00
Damodaram Sanjeevaiah Thermal Power Plant-I 800 100.00% 800.00 748.00
Damodaram Sanjeevaiah Thermal Power Plant-II 800 100.00% 800.00 748.00
RTTP-IV 600 100.00% 600.00 546.00
Ramagundam-C 660 100.00% 660.00 600.60
Kakatiya TPS Stage III 800 100.00% 800.00 740.00
TOTAL THERMAL 9352.5 9352.50 8592.91
MACHKUND PH AP Share 120 70.00% 84.00 83.16
TUNGBHADRA PH AP Share 72 80.00% 57.60 57.02
USL 240 100.00% 240.00 237.60
LSR 460 100.00% 460.00 455.40
DONKARAYI 25 100.00% 25.00 24.75
SSLM 770 100.00% 770.00 762.30
SSLM LCPH 900 100.00% 900.00 891.00
NSPH 815.6 100.00% 815.60 807.44
NSRCPH 90 100.00% 90.00 89.10
NSLCPH 60 100.00% 60.00 59.40
POCHAMPAD PH 27 100.00% 27.00 26.73
NIZAMSAGAR PH 10 100.00% 10.00 9.90
PABM 20 100.00% 20.00 19.80
SINGUR 15 100.00% 15.00 14.85
MINI HYDRO&OTHERS 12.16 100.00% 12.16 12.04
Priyadarshini JURALA HES 234 100.00% 234.00 231.66
POCHAMPAD Stg II 9 100.00% 9.00 8.91
Nagarjuna Sagar Tail Pond 50 100.00% 50.00 49.50
Lower Jurala Hydro Electric (New Project) 240 100.00% 240.00 237.60
Pulichintala 120 100.00% 120.00 118.80
TOTAL HYDRO 4289.76 4239.36 4196.97
Total A.P. Genco 13642.26 13591.86 12789.88
II Central Generating Stations (CGS)
NTPC(SR) Ramagundam- U1-U6 2100 32.32% 678.72 629.78
NTPC (SR) Ramagundam -U7 500 33.92% 169.60 158.58
Filing of ARR & FPT of SLDC business for the Third Control Period (FY2014-15 to FY2018 –19)
41
NLC TS-II Stage-I 630 18.33% 115.48 103.93
NLC TS-II Stage-II 840 24.33% 204.37 183.93
NPC-MAPS 440 9.90% 43.56 38.99
Talcher Stage 2 2000 20.00% 400.00 374.00
NTPC- Simhadri Stage I 1000 100.00% 1000.00 940.00
NTPC- Simhadri Stage II 1000 46.01% 460.10 432.49
Kaiga Nuclear power Plant I&II 440 30.82% 135.61 121.37
Kaiga Nuclear power Plant III&IV 440 32.64% 143.62 128.54
Vallur Thermal Power Plant 1500 14.75% 221.25 206.87
Kalpakkam 500 26.40% 132.00 116.16
Tutricorn 1000 25.46% 254.60 234.23
Kudigi I & II 4000 18.70% 748.00 703.12
Neyveli 1000 11.37% 113.70 104.60
Total Central Sector 17390 3958.91 4476.60
III Joint sector
APGPCL-I 100 16.00% 16.00 15.60
APGPCL-I 172 24.88% 42.79 41.72
Total Joint Sector 272 58.79 57.32
IV IPPs
GVK 216 100.00% 216.00 209.52
Spectrum 205 100.00% 205.00 198.85
Kondapalli 361.92 100.00% 361.92 351.06
BSES 220 100.00% 220.00 213.40
GVK Extension 220 100.00% 220.00 213.40
Vemagiri 370 100.00% 370.00 358.90
Gowthami 464 100.00% 464.00 450.08
Konaseema 444.08 100.00% 444.08 430.76
Total IPPS 2501 2501 2425.97
V Non Conventional Sources
Total Non conventional sources 4318.33 100.00% 4318.33 4318.33
VI Mini Power Projects
1 Sri Vatsa power Projects Limited 17.2 100.00% 17.20 16.51
2 M/s LVS Power Limited 36.8 100.00% 36.80 35.33
Total MPPS 54 54 51.84
VII OTHERS
Hinduja 1040 1040.00 1040.00
KSK Mahanadi 400 400.00 400.00
Singareni 1050 1050.00 1050.00
Thermal Power Tech 500 500.00 500.00
Total Others 2990 2990 2990
VIII Open Access Generators
Total Open Access Generators 671.8 671.8 671.8
Grand Total 41839.39 28144.69 27781.74
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