final arr 2015-16 and apr for 2014-15 petition 2015-16.pdfmmscmd million metric standard cubic meter...

PETITION FOR APPROVAL OF REVISED REVENUEREQUIREMENT AND DETERMINATION OF

GENERATION TARIFF FOR THE FINANCIALYEAR 2015-16

AND

TRUING-UP FOR FY 2013-14

AND

ANNUAL PERFORMANCE REVIEW FOR FY 2014-15,

Submission of Text and Affidavit

To

Assam Electricity Regulatory Commission

By

Assam Power Generation Corporation LimitedBijulee Bhawan, Paltanbazar

Guwahati-781 001

December, 2014

Petition for Approval for Revised ARR and Determination of Generation Tariff for the FY 2015-

16 and Truing-Up for FY 2013-14 and APR for FY 2014-15

Assam Power Generation Corporation Limited Page 1 of 226

BEFORE THE ASSAM STATE ELECTRICITY REGULATORYCOMMISSION, GUWAHATI.

Petition No. –

Case No.(to be filed by the Office)

IN THE MATTER OFFiling of Petition for Revised Revenue Requirement and Determination of Generation Tarifffor the Financial Year 2015-16, Annual Performance Review for FY 2014-15, and Truing-Upfor FY 2013-14

AND

Petition for Determination of TariffFor the year 2015-2016

AND

IN THE MATTER OFAssam Power Generation Corporation LimitedBijulee Bhawan, Paltanbazar,Guwahati-781 001. Petitioner

I,______________________________________ son of Shri _________________________aged _______ years residing at _________________________ do solemnly affirm and sayas follows:

I am the ___________________________ of Assam Power Generation Corporation Limited,the petitioner in the above matter and am duly authorized by the said Petitioner to make thisaffidavit for and on behalf of the Assam Power Generation Corporation Limited.

The Statement made in the Petition based on information received from official records and Ibelieve them to reflect truly and no material has been concealed from the statements somade or documents or supporting data etc. attached.

Solemnly affirm at Guwahati on ___________th day of __________ 2014 that the contents ofthis affidavit are true to my knowledge, no part of it is false or no material has beenconcealed therefore and misleading material included therein.

Place: Guwahati

Date _________

Deponent

By order of the Commission

Secretary of the Commission




TABLE OF CONTENTS

1. Legal and Regulatory Framework .........................................................................................092. Review of performance in FY 13-14 & FY 14-15 (Actual/Estimate) ....................................102.1. Status of APGCL Power station ...........................................................................................102.2. Investments (FY 14-15)........................................................................................................142.3. Highlights of the individual’s details of each expense for FY 13-14 & FY 14-15..........................162.3.1 Assumptions for 14-15………………………………………………………………………162.3.2 Employees Expenses ..............................................................................................................................172.3.3 Repair & Maintenance............................................................................................................................172.3.4 Administration and General Expenses ..................................................................................................182.3.5 Income from Other Sources...................................................................................................................182.3.6 Depreciation ............................................................................................................................................192.3.7 Repayment of Loan (Principal)..............................................................................................................192.3.8 Interest & financing charges...................................................................................................................192.3.9 Interest on Working Capital ...................................................................................................................202.3.10 Return on Equity………………………………………………………………………….202.3.11 Profit & Loss account ..........................................................................................................................202.3.12 Balance Sheet........................................................................................................................................213. Annual Revised Revenue Requirement (ARR) and Tariff Proposal for FY 15-16 ................223.1. Multi- year framework .........................................................................................................223.2. Assumptions .........................................................................................................................223.3. Projected Operating Performance Data for FY 15-16 ..........................................................373.4. Projected Financial Performance Data for FY 15-16 ...........................................................403.4.1 Employees Expenses ..........................................................................................................403.4.2 Repairs & Maintenance ......................................................................................................413.4.3 Administration and General Expenses ...............................................................................533.4.4 Return on Equity.................................................................................................................533.4.5 Income from Other Sources................................................................................................533.4.6 Depreciation........................................................................................................................543.4.7 Interest & financing charges...............................................................................................543.4.8 Interest on Working Capital ...............................................................................................543.4.9 Repayment of Loan (Principal) ................................................................................................553.4.10 Fuel Cost .................................................................................................................................554. Profit & Loss Account for FY 15-16 .....................................................................................555. Balance Sheet.............................................................................................................................566. Proposed ARR and Tariff Proposal for FY 15-16 ....................................................................577. Directives of AERC...................................................................................................................588. Investment Plan during FY 15-16 …........................................................................................649. Statements of proposed Monthly Generation, Fuel Prices & Cost of Fuel for FY 2015-16 .7810. Abstract of Technical Data for FY 2015-16 .............................................................................8411. Various data as per Specified formats of Hon’ble Commission ..............................................8612. Station wise information for claiming ARR and tariff for APGCL for FY 2015-16……..148

13. Appeal for Truing-up for FY 2013-14…............................................................................17014. Petition for Annual Performance Review of 2014-15……………………………………...17915. Statements of proposed Monthly Generation, Deviations comparing with Target of 2014-15

and Actual / Projected Cost of Fuel for FY 2014-15……………………………………...20316. Annual Statement of Accounts: 13-14..................................................................................20717. Annexure A, B, C, D, E, F, & G




List of TablesTable 1 (A): Generation Target & Achievements of 2013-14 ...................................................................10Table 1 (B): Generation Target & Achievements of 2014-15 (Actual/Estimate) .....................................11

Table 2: Comparison of Operating Performance of NTPS between FY 12-13, 13-14 and 15-16. .............12Table 3: Comparison of Operating Performance of LTPS between FY 12-13, 13-14 and 14-15...............12Table 4: Comparison of Operating Performance of KLHEP between FY 12-13, 13-14 and 14-15. ...................12Table 5: Comparison of Operating Performance of MSHEP between FY 12-13, 13-14 and 14-15. ..................12Table 6 (A): Investment of FY 14-15.........................................................................................................14Table 6 (B): Breakup of Renovation & Modernisation Scheme……………………………………………......15

Table 7: Assumptions for FY 2014-15…………………………………………………………………...16Table 8: Employees Expenses of FY 13-14& 14-15...................................................................................17Table 9: Repairs & Maintenance of FY 13-14 & 14-15 .............................................................................17Table 10: Administration and General Expenses of FY 13-14 & 14-15....................................................18Table 11: Income from Other Sources of FY 13-14 & 14-15 ....................................................................18Table 12: Depreciation of FY 13-14 & 14-15............................................................................................19

Table 13: Repayment of Loan (Principal) of FY 13-14 & 14-15 ...............................................................19Table 14: Interest and Financing Charges of FY 13-14 & 14-15 ................................................................19Table 15: Interest on Working Capital of FY 13-14 & 14-15 .....................................................................20Table 16: ROE for FY 13-14 & 14-15………………………………………………………………..……….20Table 17: Profit & Loss account of FY 13-14 & 14-15 ...............................................................................20Table 18: Balance Sheet of FY 13-14 & 14-15 ...........................................................................................21

Table 19: Assumptions for FY 2015-16 various heads I............................................................................34Table 20: Assumptions for FY 2015-16 various heads II ..........................................................................35Table 21: Generation Projection for FY 2015-16.......................................................................................38Table 22: Employees Expenses for FY 2015-16 ........................................................................................40Table 23: Repairs & Maintenance for FY 2015-16....................................................................................41Table 24: Administration and General Expenses for FY 2015-16..............................................................53

Table 25: Return on Equity for FY 2015-16 ..............................................................................................53Table 26: Income from Other Sources for FY 2015-16 .............................................................................53Table 27: Depreciation for FY 2015-16.....................................................................................................54Table 28: Interest & Financing charges for FY 2015-16............................................................................54

Table 29: Interest on Working Capital for FY 2015-16...............................................................................54

Table 30: Repayment of Loan (Principal) for FY 2015-16..........................................................................55Table 31: Fuel Cost for FY 2015-16...........................................................................................................55Table 32: Profit & Loss Account for FY 2015-16 ......................................................................................55Table 33: Balance Sheet for FY 2015-16....................................................................................................56Table 34: Proposed ARR and Tariff Proposal for FY 2015-16…………………………………………....57

Table 37: Investment 13-14........................................................................................................................180Table 38: Employees Expenses 12-14 ........................................................................................................181Table 39 Repairs & Maintenance for 12-14………………………………………………………………… 181Table40: Administration and General Expenses for FY 2012-14...............................................................182Table 41: Income from Other Sources for FY 2012-14 .............................................................................182

Table 42: Depreciation for FY 12-14.........................................................................................................182

Table 43: Repayment of Loan (Principal) for FY 2012-14..........................................................................185Table 44: Interest & Finance Charges for FY 12-14...................................................................................185Table 45: Interest on Working Capital for FY 2012-14 ..............................................................................185Table 46: Profit & Loss account of FY 12-14 .............................................................................................185Table 47: Balance Sheet of FY 12-14 .........................................................................................................187




List of Tables

Table 48: Assumptions for FY 2014-15 various heads I............................................................................188

Table 49: Assumptions for FY 2014-15 various heads II ..........................................................................189Table 50: Actaul Projected Operating Performance for FY 2014-15 .........................................................190Table 51: Employees Expenses for FY 2014-15 ........................................................................................192Table 52: Repairs & Maintenance for FY 2014-15....................................................................................192Table 53: Administration and General Expenses for FY 2014-15..............................................................196Table 54: Return on Equity for FY 2014-15 ..............................................................................................196

Table 55: Income from Other Sources for FY 2014-15 .............................................................................199Table 56: Depreciation for FY 2014-15.....................................................................................................199Table 57: Interest & Financing charges for FY 2014-15............................................................................199

Table 58: Interest on Working Capital for FY 2014-15...............................................................................200

Table 59: Repayment of Loan (Principal) for FY 2014-15..........................................................................200

Table 60: Fuel Cost for FY 2014-15...........................................................................................................200Table 61: Profit & Loss Account for FY 2014-15 ......................................................................................200Table 62: Balance Sheet for FY 2014-15....................................................................................................201Table on Revised ARR for FY 2014-15…………………………………………………………………...202




List of Annexure

Annexure I: Statements of proposed Monthly Generation, Fuel Prices & Cost of Fuel for

FY 2015-16...................................................................................................................................78

Annexure II: Abstract of Technical Data for FY 2015-16 .......................................................84

Annexure III: Status of Hon'ble Commission's Formats.........................................................86

Annexure IV: Systematic Station wise Information for claiming ARR and Tariff ...............148

Annexure V: Statements of proposed Monthly Generation, Fuel Prices & Cost of Fuel

for FY 2014-15.............................................................................................................................203

Annexure VI: Annual Statement of Accounts for FY 13-14....................................................207

Annexure A: Abstract of Quarterly Trial Balance

Annexure B: Sanction letters of Loans from GOA received up to FY 13-14

Annexure C: Interest rate considered for State Govt. Loan

Annexure D: Loan drawl from PFCL during FY 13-14

Annexure E: Interest and repayments made to PFCL during FY 13-14

Annexure F: TDS certificates on investments

Annexure G: Sanction Letters of Grant received by APGCL




Glossary

Acronym Full form

A&G Administrative and General

ABT Availability Based Tariff

ADB Asian Development BankAEGCL Assam Electricity Grid Corporation LimitedAERC Assam Electricity Regulatory Commission

APDRP Accelerated Power Development and Reforms Program

APGCL Assam Power Generation Corporation Limited

APDCL Assam Power Distribution Company Limited

ARR Annual Revenue RequirementASEB Assam State Electricity Board

CGM Chief General ManagerCT/PT Current Transformer/Potential TransformerEE Executive EngineerFAS Fuel Adjustment Surcharge

FY Financial YearGoA Government of AssamGoI Government of IndiaKV Kilo Volt

KVA Kilo Volt AmpereKW Kilo Watt

KWH Kilo Watt HourLRPP Lakwa Replacement Power Project

LTPS Lakwa Thermal Power Station

MIS Management Information Systems

MMSCMD Million Metric Standard Cubic Meter per dayMOU Memorandum of Understanding

MU Million UnitNERLDC North East Region Load Despatch Centre

NRPP Namrup Replacement Power Project

NTPS Namrup Thermal Power Station

O/H Over HeadsPGCIL Power Grid Corporation of India Limited

Ph PhasePLF Plant Load FactorR&M Repairs and Maintenance

Rs RupeesSEBs State Electricity BoardsST Scheduled TribeT&D Transmission and Distribution

T.C. Transportation CostKLHEP Karbi Langpi Hydro Electric Project




BEFORE THE HON'BLE ASSAM ELECTRICITY REGULATORY COMMISSION

FILINGNO.........................

CASENO ...........................

IN THE MATTER OF:

Petition for Revised Revenue Requirement and Determination ofGeneration Tariff for the for the period 1st April 2015 to 31st March2016 for the Assam Power Generation Corporation Limited(APGCL) and Truing-Up for FY 2013-14 and Annual PerformanceReview for FY 2014-15

AND IN THE MATTER OF:

Assam Power Generation Corporation Limited incorporated underthe provisions of the Companies Act, 1956 and having itsregistered office in the State of Assam

THE HUMBLE APPLICANT ABOVE NAMED MOST RESPECTFULLY SHEWETH:

1 That the Assam Power Generation Corporation Limited, hereinafter named as APGCL, is asuccessor corporate entity, formed in pursuant to the notification of the Government of Assam,notified under sub-sections (1), (2), (5), (6) and (7) of Section 131 and Section 133 of theElectricity Act 2003(Central Act 36 of 2003), for the purpose of transfer and vesting offunctions, properties, interests, rights, obligations and liabilities, along with the transfer ofPersonnel of the Board to the successor corporate entities.

2 That the Assam Power Generation Corporation Limited is a company incorporated with themain object of generation of electricity in the state of Assam.

3 That the Assam Power Generation Corporation Limited is a generating company under theprovisions laid down in Section 14 Proviso 5, read with Section 131 (2) of the Electricity Act2003.

4 That the licensee is now filing the Petition for Revised Revenue Requirement and Determination ofGeneration Tariff for the for FY 2015-16 for the Assam Power Generation Corporation Limited(APGCL)and Truing-Up for FY 2013-14 and Annual Performance Review for FY 2014-15.

(PETITIONER)




NOTES:

In this petition:

Previous Year is defined as the Financial Year (FY) 2013-2014

Current Year is defined as the Financial Year (FY) 2014-2015

Ensuing Year is defined as the Financial Years (FY) 2015-2016




1. Legal and Regulatory Framework1.1 Under the provisions of Electricity Act 2003 (hereinafter referred to as "Electricity Act") the Assam

Electricity Reforms First Transfer Scheme, 2004 (hereinafter referred to as "Transfer Scheme") wasnotified by Government of Assam on 10th December 2004. Under Section 5(2) of the transfer scheme the functions and undertakings as set out in Schedule-A of thetransfer scheme stands transferred to Assam Power Generation Corporation Limited(APGCL). The final transfer scheme was notified by Govt. of Assam vide notification No:PEL/151/2003/Pt.349 Dtd. 16th Aug’ 2005 w.e.f 1st April’05.

1.2 Section 131 (2) of the Electricity Act provides "...Any property, interest in property, rights andliabilities vested in the State Government under sub-section (1) shall be re-vested by the StateGovernment in a Government company or in a company or companies, in accordance with the transferscheme so published along with such other property, interest in property, rights and liabilities of theState Government as may be stipulated in such scheme, on such terms and conditions as may beagreed between the State Government and such company or companies being State TransmissionUtility or generating company or transmission licensee or distribution licensee,... ".

1.3 Section 62 of the Electricity Act 2003 requires the generating company to furnish details as maybe specified by the Commission for determination of tariff.

1.4 Section 5, 6 & 7 of A. E. R. C. (Terms and conditions for determination of Tariff) Regulations2006 lays down the following:

Periodicity of tariff determination (Sec.-5)

1.4.1(Sec.5.2) Subject to other provisions of these Regulations, the expenses allowed to be recouped forany financial year, shall be subject to adjustments in any tariff to be fixed for the subsequent period, ifthe Commission is satisfied, that such adjustments for the excess amount or shortfall in the amountactually realized or expenses incurred is necessary and the same is not on account of any reasonattributable to the licensee

1.4.2(Sec.5.3) In accordance with the principle of multi-year tariffs (MYT), the Commission approvedthree years control period i.e. 2010-11 to 2012-13and accordingly APGCL filed MYT petition forthe said control period to AERC on 08/02/2010.Against Tariff Petitions of APGCL, AERC issuedTariff order for FY 2010-11 and approved ARR for FY 2010-11, FY 2011-12 & FY 2012-13 on16thMay’2011. Latter APGCL filed Annual Performance Review of APGCL for FY 2011-12&Truing-up for FY 2009-10, FY 2010-11 on 4th June’12 and Revised Annual Revenue Requirementfor FY 2012-13 and determination of Generation Tariff for FY 2012-13 on dated 26th

Sept’12.Further, APGCL filed MYT petition for the control period of FY 2013-14 to 2015-16 on31.01.13.The Tariff for FY 2013-14 has been declared by AERC on 21.11.13 with effectuationdate from 1st Dec’13. Thereafter, APGCL submitted petition for Revised ARR and tariff proposalfor FY 2014-15 and True-up for FY 2012- to AERC 26/02/14. AERC declared tariff for FY 2014-15 on 21.11.14 with effectuation date from 1st Dec’14.

Petition for determination of MYT (Sec.-6)

1.4.3(Sec.-6.1) The licensee and generating company may file a tariff petition annually with theCommission to determine changes to the current tariff by not later than 1stDecember unless anextension is granted by the Commission upon application.

Petition for determination of tariff (Sec.-7)

1.4.4(Sec.-7.2) The licensee and generating company shall also submit financial information for theprevious year and forecasts for current year, ensuing year and the years up to the end of thecontrol period.

1.5 The petitioner has now prepared the revised ARR and Tariff proposal for FY 2015-16 and Truing-up for FY 13-14 and Annual Performance Review for FY 2014-15 for the area of operation ofAPGCL and to submit the same to AERC on or before 20th December’2014, as extended byAERC on our appeal.

1.6 The status of the various data formats and forms, as required by the Hon'ble Commission, arefurnished in Annexure III at Page No. 86

1.7 The Annual Accounts of APGCL for the year 2013-14 is enclosed in Annex. –VI at Page No.207




2. Review of performance in FY 13-14 & 14-15 (Actual/ Estimate)

2.1 Status of APGCL Power station:

APGCL’s 3 (three) operating power plants namely 119.5 MW (De-rated) Namrup Thermal PowerStation (NTPS), 157.2 MW Lakwa Thermal Power Station (LTPS), and 100 MW Karbi LangpiHydro-electric Power Station (KLHEP). 60 MW Chandrapur Thermal Power Station (CTPS) wasclosed since June’1999 due to exorbitant cost of generation for steep hikes of fuel oil. However theplant is being revived by using coal as an alternative fuel in JV on Public-Private- Partnership (PPP)mode on B-O-T basis.

FY 2013-14:

In the FY 2013-14, APGCL achieved gross generation of 1845.23MU as shown in Table 1(A).

Table 1(A)

Power Station Gross generation in MU % of achievements

Target Actual

NTPS 523.41 526.57 101%

LTPS + WHRU 855.30 896.15 105%KLHEP 390.00 422.51 108%

Myntriang St-II 17.69 0.00 0%

Total 1786.40 1845.23 103%

NTPS:

In the FY 2013-14 NTPS was able to achieve the normative PLF of 50% and it also surpassed itTarget Gross generation. Hence, its performance was satisfactory. Unit #2 of NTPS was under forcedshutdown since 03/07/13 due to high vibration problem. The unit was overhauled and put intooperation on 31/10/13.

LTPS:

Unit #1 of LTPS was under planned shutdown from 14/04/13 for Major Overhauling. This wasoriginally scheduled in 2012-13. However, due to deferment of the earlier scheduled shutdown, theMajor Overhauling of Unit #1 was postponed to 2013-14. The original scheduled shutdown was for25 days, but due to severe damage in internal parts, the overhauling work lasted for more than 4months and the unit was ultimately put into operation from 10/09/13. Even though the performance ofLTPS suffered a little bit due to this during this period, however, later the availability of LTPSimproved to 76%. As a result LTPS was able to surpass the target in Gross Generation.

KLHEP:

The generation from 100 MW KLHEP crossed the design generation i.e. 390 MU in the month ofJan’14. This was possible due to sufficient availability of water and because of keeping the generatingunits in smooth running condition by doing timely repair & maintenance works. Total generation ofKLHEP in the FY 2013-14 was 422.51 MU

Myntriang St-II:

Earlier Myntriang St-II SHEP project was expected to be completed in June’13. However due to delayin project work, the project started commercial operation from 08-08-14 only. Thus, there was nogeneration from Myntriang St-II SHEP in 2013-14.




FY 2014-15:

In the FY 2014-15, the actual and anticipated gross generation of APGCL is as shown in Table 1(B).

Table 1(B)

PowerStation

Target FY 14-15(Projected As on 1st Dec’14)

Actual/ Estimate % of achievement

NTPS 523.09 600.14 115%

LTPS +WHRU

842.47 897.36 107%

KLHEP 390.00 341.38 88%

MyntriangSHEP St-II

11.38 4.43 39%

Total 1766.94 1843.30 104%

NTPS:

Due to continuous efforts taken by APGCL, performance of NTPS has improved significantlycompared to previous years, which can be observed in its average higher PLF of 57% and availabilityfactor of 61% respectively during the period April-November of 2014-15. Due to such improvedperformance, it is expected that NTPS is going to surpass Target generation for the FY 2014-15.

LTPS:

From April to the end of November 2014, performance of LTPS was satisfactory. During the periodfrom April to November 2014 LTPS has achieved average PLF of 66% and availability of 72%. Dueto such satisfactory performance, even though LTPS is constantly facing shortage of gas supply, it isexpected that LTPS is going to surpass Target generation for the FY 2014-15.

KLHEP:

Due to shortfall in rain during the monsoon period of 2014-15, generation of KLHEP has sufferedsignificantly. Till November’14, generation of KLHEP was only 304 MU, even though the designenergy for this period is 353 MU. Including the actual generation and the design energy in the leanperiod from December to March 2014, KLHEP is expected to generate only 341.38 MU in 2014-15.

Myntriang SHEP St-II:

Commercial Operation Date of Myntriang SHEP St-II was declared on 08-08-14. But the project wasdamaged heavily in the devastating flood of 22-08-14. The machines were put into trial run on 20-10-14, however the machines were not stable. Both the units of Myntriang SHEP are not in operation atthe moment.

2.1.1. Plant wise Performance Data:

The following tables indicate the plant wise operating performance parameters of APGCL forFY 2012-13, FY 2013-14 and FY 14-15 (Actual/ Estimate) which reflects an improvement ofplants performance of APGCL.




Table 2

NTPS FY 12-13 FY 13-14 FY 14-15(Projected As on 1st

Dec’14)Gross Energy in MU 533.168 526.57 600.14Aux. Power Cons. (%) 5.6% 6.0% 5.7%Availability (%) 54% 54% 61%PLF (%) 51% 50% 57%Gross Station Heat Rate on GCV (Kcal/ Kwh) 4093 3976 4145Sp. Gas Consumption (SCM/Kwh) 0.4458 0.4290 0.4325

Table 3

LTPS + WHRU FY 12-13 FY 13-14 FY 14-15(Projected As on

1st Dec’14)Gross Energy in MU 888.08 896.15 897.36Aux. Power Cons. (%) 11.5% 8.8% 8.8%Availability (%) 73% 71% 71%PLF (%) 64% 65% 65%Gross Station Heat Rate on GCV (Kcal/ Kwh) 3066 3164 3084Sp. Gas Consumption (SCM/Kwh) 0.3219 0.3303 0.3117

Table 4

KLHEP FY 12-13 FY 13-14 FY 14-15(Projected As on 1st

Dec’14)Gross Energy in MU 344.02 422.51 341.38Aux. Power Cons. (%) 0.5% 0.5% 0.5%Capacity Index (%) 93% 95% 90%PLF (%) 39% 48% 39%

Table 5

Myntriang St-II FY 12-13 FY 13-14 FY 14-15(Projected As on 1st

Dec’14)Gross Energy in MU N/A N/A 4.43Aux. Power Cons. (%) N/A N/A 1.0%Capacity Index (%) N/A N/A 91%PLF (%) N/A N/A 17%

2.1.2. Brief Status of APGCL’s Running Power Stations

Namrup Thermal Power Stations: (119.5 MW)

At present Namrup Thermal Power Station is generating an average of 75-90 MW dependingon availability of gas. The details of units are as under:

Unit-1 (20 MW, GT): Unit is presently running at an average load of 19 MW. The unit isoverdue for major overhauling and is scheduled to be overhauled in June’15-July’15 for 60days. This was earlier scheduled in 2014-15.

Unit-2 (21 MW, GT): Unit is presently running at an average load of 20 MW

Unit-3 (21 MW, GT): Unit is presently running at an average load of 18 MW. The unit isoverdue for major overhauling and is scheduled to be overhauled in Nov’15-Dec’15 for 60




days.

Unit-4 (11 MW, GT): Unit presently runs at an average load of 9 MW. The unit was undershut down wef 09/09/14 for lube oil cooler fan damage and the unit was subsequently putunder scheduled major overhauling. The unit is expected to be resumed operation from25/12/14 after overhauling.

Steam Turbine Unit 5 (24 MW): The unit is presently running with an average load of 12MW due to technical constrain.

Waste Heat Unit 6 (22.5 MW): Unit is presently running with an average load of 12MW due to technical constraint. The unit is overdue for major overhauling and isscheduled to be overhauled in Aug’15-Sep’15 for 60 days. This was earlier scheduled in2014-15.

Lakwa Thermal Power Stations: (157.2 MW):

Lakwa Thermal Power Station is generating a daily average of 100 – 125 MW depending onavailability of gas. The details of the units are as under.

Unit-1 (15 MW, GT): The unit is presently running at full load capacity.

Unit-2 (15 MW, GT): The unit is presently running at full load capacity. The unit isoverdue for major overhauling and is scheduled to be overhauled in Apr’15-May’15 for 50days. This was earlier scheduled in 2014-15.

Unit-3 (15 MW, GT): The unit is presently running at full load capacity. The unit isoverdue for major overhauling and is scheduled to be overhauled in Jul’15-Aug’15 for 50days.

Unit-4 (15 MW, GT): The unit is presently running at full load capacity

Unit-5 (20 MW, GT): The unit is presently running at full load capacity

Unit-6 (20 MW, GT): The unit is presently running at full load capacity. The unit ispresently running at full load capacity. The unit is overdue for major overhauling and isscheduled to be overhauled in Jun’15 for 25 days.

Unit-7 (20 MW, GT): The unit is presently running at full load capacity. The unit wasunder shutdown for Major Inspection from 08-11-14 to 02-12-14.

Unit-8 (37.2 MW WHRU): The unit is presently running with an average load of 30 to 32MW.

Karbi Langpi Hydro Electric Project (100 MW):

Unit-1 (50 MW): The unit is presently in a healthy condition and running at full capacitydepending on availability of water.

Unit-2 (50 MW): The unit is presently in a healthy condition and running at full capacitydepending on availability of water.

Myntriang Small Hydro Electric Project St-II (3 MW):

Unit 1 (1.5 MW) & Unit 2 (1.5 MW): The plant got affected by heavy flood on 22-08-14. Allthe equipments needed servicing. At present both the units are under forced shutdown and itis expected that the units will start stable operation from January’15 after repairing.




2.2 InvestmentsTable 6 (A)

Revised Investment Proposal for the FY 2014-15Rs. in Crore

Sl.No.

Name of the Project

Approvedin theTariff

Order of2014-15

Revised investment Proposal for 2014-15

RemarksGovt

(Equity)GOA

(Loan)Grant(Govt)

FI(Loan)

Total

Thermal Wing

1R&M of NamrupTPS

6.85 8.67 8.67

Additional work of (i) Rs. 1.80Cr due to procurement of 25nos. of important mechanical,electrical & instrumentationspares required at NTPS forsmooth and trouble freeoperations of the old GT unitsand its auxiliaries, (ii) Rs. 0.02Cr due to revised estimate ofAnti Erosion Measures atDillighat intake from earlier Rs.0.30 Cr to 0.32 Cr

2

R&M of Lakwa TPS 23.20 20.19 20.19

Amount reduced as the R&Mproposal for 2014-15 by APGCLwas curtailed by GOA and workis now going to be executed onpriority basis.

R&M of Lakwa TPS(Major Overhaulingof Unit#2)

12.50 0.00Details of Overhauling Cost ofUnit #2 of LTPS is given atPage No. 193

3 R&M of KLHEP 5.82 1.56 1.56

Amount reduced as the work ofprocurement of 11/232/√3 kV, 21 MVA single phase generatortransformer has been deferreddue to fund constraint.

4100 MW NamrupRPP

165.00 100.00 100.00Amount is reduced due to delayin resuming of Project work

570 MW LakwaReplacement PowerProject

1.00 0.60 0.60As per approved amount in theAnnual Plan for construction ofboundary wall at site

6660 MW MargheritaThermal PowerProject

0.00 2.00 2.00As per approved amount in theAnnual Plan for construction ofboundary wall at site

Hydro Wing

79 MW MyntriangSHEP

0.00 7.00 7.00 Land Compensation

86 MW LungnitSHEP

22.00 0.00Due to litigations, bid finalizationprocess is at present undersuspension

9120 MW LowerKopilii HEP

0.00 84.00 7.00 91.00

Earlier Rs. 15/- Cr was includedin the Annual Plan Proposal forFY 2014-15 as govt. loan forpart payment of landcompensation. However, later itwas decided to include toinclude the whole amount ofland Compensation in the Govt.




Equity to be given by AIFA inthe meeting held on 05/08/14with GOA. The proposedamount in Annual plan has thusbeen reduced to Rs. 7/- Cr.under Govt. loan for projectdevelopment activities and theEquity of Rs. 84/- Cr is for landcompensation.

10Boundary Wall atJagiroad for KLHEPStore

0.33 0.36 0.36

Earlier estimate was as per the2011-12 APWD price schedule.Estimate has been revised asper the 2013-14 APWD priceschedule

Total ProposedInvestment

236.70 84.00 40.38 7.00 100.00 231.38

Breakup of R&M Scheme is given in the table below:Table 6 (B)

Sl No. Name of Schemes and Approved OutlayBudget

Proposal(Rs in Lakh)

Total(Rs. In Cr)

(A) R&M Works under Namrup Thermal Power Station (NTPS)

1. Procurement of 250 V,425 AH lead acid battery bank with suitablebattery charger at NTPS

0.60

8.67

2. Procurement of Flexible gear coupling of GT-1, 3 of NTPS 0.50

3. Procurement of Air Clutch Drum of GT-1,2,3 of NTPS 0.15

4. Procurement of 66kV SF-6 Breaker for NTPS Switch yard 0.30

5.Procurement of Mechanical, Electrical & Instrumentation spares forgenerating unit and auxiliaries & execution of important works atNTPS

1.80

6. Anti Erosion measure at Dillighat intake of NTPS 0.32

7. Boundary wall around the NTPS campus 5.00

(B) R&M works under Lakwa Thermal Power Station (LTPS)

8. Procurement of spares for Gas Compressor & air compressor of Ph-II at LTPS

0.60

20.19

9. Spares for major overhauling of GT #6 of LTPS Including workcomponent

15.00

10. Work expenditure for major overhauling of GT #6 of LTPS 0.70

11. Diesel generator set with Control panel/breaker and shed for WaterIntake pump house of WHRP

0.55

12.

New departmental quarters for officers of LTPS 0.00

i. 1 no. Type-II multi strayed building with 2 blocks 0.75

ii. 1 no. Type-III multi storied building with 4 blocks 0.90

13 Spares for WHRP including balance of plant(BOP) for LTPS 1.08

14 Spares of electrical and instrumentation parts of Ph-II power houseof LTPS

0.61

(C) R&M Works under Karbi Langpi Hydel Power Project

15 Supply of Spares/Accessories for revival & up-gradation ofinstrumentation installed in Dam of KLHEP with installation charges

0.36

1.5616 Procurement of Storage System for renovation of Electrical Stores at

KLHEP0.54

17 Communication Tower installation near surge shaft for onlinecommunication of data and information

0.66




2.3 The following tables highlight the individual’s details of each expense for 13-14&14-15 (Actual/Estimate).

2.3.1 Assumptions for FY 2014-15Table 7

2014-15

ST PLR - 14.75%

R & M Expenses 15.00%

Employee Expenses 8.42%

A & G Expenses escalation rates 8.42%

ROE 14.00%

Other Income@ 10%

escalation

Provision for Taxes

atapproved

by Hon'bleAERC

Provision for Bad and Doubtful Debts% of revenue 0.00

Current Assets - per Actual

O&M Expenses On annual Expenditure

Maintenance spares1% of GrossBlock

Receivable against sale of powerOn the total revenuedemand

Current Assets - per AERC

O&M Expenses & fuel On annual Expenditure



Power purchase Payable

Depreciation rate applicable for Thermal Hydel

Land & Rights 0.00 0.00

Buildings 1.80% 1.80%

Hydraulic 2.57% 2.57%

Other civil works 1.80% 1.80%

Plant & Machinery 6.00% 2.57%

Lines & Cable Network 2.57% 2.57%

Vehicles 18.00% 18.00%

Furniture & fixture 6.00% 6.00%

Office equipment 6.00% 6.00%

Roads on land Belonging to others 1.80% 1.80%

Capital spares at generating stations 4.75% 4.75%

Cap of Asset Value 90.00% 90.00%

Loan Rates - New Loan

Institution 11.40%

Existing Loans

Rates of interest

State Govt 10.50%




PFC

@differentagreementrates

Other 11.40%

Loan Repayment

Govt Loan 10.57

PFC 22.97

Others 0.00

Thermal

O & M for new stations on commercialstartup year subsequently @ inflation 5.72%

Interest rate for investment income

Hydel



2.3.2 Employees Expenses

Table 8Particulars 2013-14 2014-15

Salaries 33.81 36.65

Overtime 1.44 1.66

Dearness Allowance 27.12 29.85

Other Allowances 6.93 5.61

Bonus 0.03 0.03

Medical Allowances 0.18 0.09

Leave Travel Assistance 0.05 0.05

Earned Leave Encashment 0.27 0.29

Workmen Compensatory Payment 0.00 0.00

Other Staff Cost 0.01 0.01

Staff Welfare Expenses 0.13 0.14

Terminal Benefits 12.04 12.16

Subtotal 82.00 86.54

Less: Capitalisation 0.00 0.00

Total 82.00 86.54

Note: 1. Employee expenses for FY 14-15 are in actual up to 2nd quarter before any Head quarteradjustment. Regarding 3rd & 4th quarter of FY 14-15 expenses are assumed to be proportionateto the expenses of 1st & 2nd quarter.2. Escalation taken @ 8.42 % for Employees cost, as the escalation rate was approved by AERCin Tariff order 14-15

2.3.3 Repairs & Maintenance


A. Special Type Repair & Maintenance:-




Overhauling Works of Unit # 2 of LTPS underplant & Machinery 0.00 6.44

B. Regular Repair & Maintenance:-Plant & Machinery 20.60 14.74

Buildings 1.81 0.27

Other civil works 0.87 0.31

Hydraulic 0.89 1.10

Lines & Cable Network 0.03 0.09

Vehicles 0.06 0.26

Furniture & fixture 0.26 0.14

Office equipment 0.08 0.20

Lubricants & Consumable stores 1.23 1.41

Turbine Oil 0.20 0.23

Total: 26.03 25.19

Regular R&M cost for FY 14-15 is taken at par to that approved in Tariff order FY 14-15 and detailed

justifications on Special type Repair & Maintenance for Overhauling Works of Unit # 2 of LTPSunder plant & Machinery has been given in page No: 193 under APR for FY 2014-15

2.3.4 Administration and General Expenses


Rent, Rates & Taxes 0.35 0.35

Insurance 0.81 0.88

Telephone charges 0.12 0.05

Postage & Telegrarm 0.01 0.00

Legal charges 0.02 0.01

Audit fees 0.02 0.00

Consultancy charges 0.60 0.65

Technical fees 0.02 0.01

Other Professional fees 0.07 0.01

Conveyance & Travel charges 0.76 0.63

Freight 0.04 0.02

Other purchase related expenses 9.72 6.79

Energy bill raised by APDCL 0.00 0.00

Sub Total: 12.53 9.41

Less: Capitalised 0.00 0.00

Total: 12.53 9.41

Note: 1. A&G expenses for FY 14-15 are in actual up to 2nd quarter before any Head quarter adjustment.Regarding 3rd & 4th quarter of FY 14-15 expenses are assumed to be proportionate to the expensesof 1st & 2nd quarter.

2.3.5. Income from Other Sources


Interest on Staff Loans and advance 0.00 0.00

Income from Investment 8.85 8.85

Income from sale of scrap 0.06 0.06

Rebate for timely payment 0.79 0.79

Misc. receipts (except 62.901 & 62.908) 0.90 0.90

Rent from residential building 0.01 0.01

Total: 10.60 10.60




Note: Other income incurred in FY 2013-14 is considered at par for FY 2014-15

2.3.6. Depreciation

Table 12

Particulars 2013-14 2014-15


Buildings 0.72 0.72

Hydraulic 3.82 4.00


Plant & Machinery Thermal 11.93 12.57

Plant & Machinery Hydel 4.27 4.48


Vehicles 0.12 0.12

Furniture & fixtures 0.00 0.07


Roads on land belonging to others 0.00 0.00

Capital spares at generating stations 3.20 3.28

Total 27.35 29.40

(Less) : Depreciation on 90% of the Assets funded byGrants/subsidies -5.39 -6.13

Net Total 21.95 23.27

Depreciation has been calculated using the schedule as prescribed by the AERC. Analysis of the trialbalance under each function head has been carried out and the weighted average rate has beencalculated and used for calculation. Depreciation on assets commissioned in a year is charged at theaverage balance for the year (since they could be commissioned at different date).

2.3.7 Repayment of Loan (Principal)

Table 13


PFC Loan 22.97 22.97

State Govt Loan 0.00 10.57

Total 22.97 33.53

2.3.8. Interest & financing charges

Table 14:Particulars 2013-14 2014-15

Interest on loans 50.68 58.80

Other finance charges 0.05 5.81

Sub total 50.73 64.61

Less: Interest capitalised -19.46 -29.59

Total 31.27 35.02

Note: 1. Interest on loans & Other Finance Charges calculated for FY 13-14 @ 10.5% on loanoutstanding for Loan from Govt. of Assam, @ actual interest calculated by PFC for Loan fromPFCL. Interest on GPF is not claimed in true up 13-14 petition as the GPF trust not yetformed. But the same is expected to complete in FY 14-15 and hence claimed thereafter

2. Interest on loans & Other Finance Charges calculated for FY 14-15 @ 10.5% on loanoutstanding for Loan from Govt. of Assam, @ actual interest rates charged by PFC for Loan up




to Dec’14 from PFC and remaining on proportionate assumption. GPF trust is expected tocomplete in FY 14-15 and hence interest on GPF is claimed from FY 14-15

2.3.9 Interest on Working CapitalTable 15:


One month Fuel Cost 32.10 38.61

One month approved O&M Cost 9.79 9.83

Maintenance Spares 12.48 12.90

Two month Receivables 96.33 110.82

Total 150.70 172.16

Interest @ 14.75% 22.23 25.39

Note: Interest on working capital is computed @ an interest rate of 14.75%

2.3.10 Return on EquityTable 16


Namrup TPS 9.06 9.25

Lakwa TPS 10.07 10.67

Lakwa WHRP 9.93 9.93

Karbi Langpi HEP 9.54 9.54

Myntriang SHEP 0.79 1.72

Namrup RPP 0.00 0.00

Total 39.38 41.10

Note: ROE calculated as follows:

2.3.11 Profit & Loss Account


Power Generation

Energy generated (MU) 1845.23 1843.30

Sale of Power (MU) 1732.85 1728.62

Auxiliary Consumption, Loss % 6.09% 6.22%

INCOME

Revenue from tariff & Misc. charges 547.00 696.37

O&M expenses of CTPS 0.00 3.24

EXPENDITURE

Generation Cost 385.15 463.35

R&M Expenses 26.03 25.19

Employee Expenses 82.00 86.54

Particulars13-14 14-15 13-14 14-15 13-14 14-15 13-14 14-15 13-14 14-15 13-14 14-15 13-14 14-15

Opening Equity 64.62 64.74 70.72 73.19 68.11 68.11 70.92 70.92 0.00 0.00 0.00 11.27 274.37 288.22Closing Equity 64.74 67.34 73.19 79.24 68.11 68.11 70.92 70.92 0.00 0.00 11.27 13.37 288.22 298.98Average equity 64.68 66.04 71.95 76.22 68.11 68.11 70.92 70.92 0.00 0.00 5.63 12.32 281.30 293.60Rate 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14ROE 9.06 9.25 10.07 10.67 9.54 9.54 9.93 9.93 0.00 0.00 0.79 1.72 39.38 41.10

NTPS LTPS KLHEP NRPPLWHRP Myntriang Total




A&G Expenses 12.53 9.41

Depreciation 21.95 23.27

Interest & Finance Charges 50.73 64.61

Less: Interest & other expenses capitalised -19.46 -29.59

Interest on working Capital 22.23 25.39Other Debits (incl. Prov. for bad debts, int of W/Capital

etc.) 0.00 0.00

Extraordinary Items 0.00 0.00

Other (Misc.) - net prior period credit -10.07 0.00

Total 571.10 668.18

ROE 39.38 41.10

Other Income 10.60 10.60

Provision for taxes 0.45 0.93

Annual Revenue Requirement 600.33 699.61

Add: Incentive for generation for FY 2013-14 5.98

Add: Incentive for Secondary Energy generation forFY 2011-12 2.51

Surplus(+) / Shortfall(-) -61.82 0.00

2.3.12 Balance Sheet

Table 18:


Source of Fund

Share Capital 455.86 455.86

Reserve & Surplus 36.33 39.97

Loans from State Govt 135.78 167.96

Loans from others 405.49 505.49

Total 1033.47 1169.28Contributions, grants & subsidies towards cost of CapitalAsset 380.38 409.60

Grand Total 1413.85 1578.88

Application of Fund

Net Fixed Assets

(A) Gross Block 1325.74 1363.51

(B) Less : Accumulated Depreciation 626.38 649.44

(C) Net Fixed Assets 699.36 714.07

(D) Capital-works-in-progress 568.98 777.97

(E) Asset not in use

(F) Deferred Cost

(G) Intangible Asset

Total of (C) to (G) 1268.34 1492.04

Investements 0.00 0.00

Subsidy receivable from Govt

Net Current Assets

A. Current Assets, Loans & Advances

i) Inventories 68.25 75.08

ii) Receivables against Sale of Power 3.44 3.79

iii) Cash & Bank Balance 154.09 169.50




iv) Loans & Advances 57.40 63.14

v) Other current assets 76.23 83.86

Total of A 359.41 395.37

B. Current Liabilities and provisions

i) Borrowing for Working Capital

ii) Payment due on Capital Liabilities

iii) Other current liabilities 386.91 309.53

Total of B 386.91 309.53

Net Current Assets (A - B) -27.50 85.84

Profit/ Loss 173.01 1.00

Grand Total 1413.85 1578.88

3.0 Revised Annual Revenue Requirement (ARR) for 2015-16

3.1 Multi- year framework

In accordance with the principle of multi-year tariffs (MYT), the Commission approved three yearscontrol period i.e. 2010-11 to 2012-13 and accordingly APGCL filed MYT petition for the saidcontrol period to AERC on 08/02/2010.Against Tariff Petitions of APGCL, AERC issued Tariff orderfor FY 2010-11 and approved ARR for FY 2010-11, FY 2011-12 & FY 2012-13 on 16thMay’2011.Latter APGCL filed Annual Performance Review of APGCL for FY 2011-12& Truing-up for FY2009-10, FY 2010-11 on 4th June’12 and Revised Annual Revenue Requirement for FY 2012-13 anddetermination of Generation Tariff for FY 2012-13 on dated 26th Sept’12.Further, APGCL filed MYTpetition for the control period of FY 2013-14 to 2015-16 on 31.01.13.The Tariff for FY 2013-14 hasbeen declared by AERC on 21.11.13 with effectuation date from 1st Dec’13. Thereafter, APGCLsubmitted petition for Revised ARR and tariff proposal for FY 2014-15 and True-up for FY 2012- toAERC 26/02/14. AERC declared tariff for FY 2014-15 on 21.11.14 with effectuation date from 1st

Dec’14.

APGCL is now to submit revised ARR and Tariff petition for FY 2015-16 and APR for FY 2014-15by considering the detailed assumptions on technical and financial data as mentioned below forGeneration functions.

3.2 Assumptions

Based on the current position of machine and gas availability of the existing Thermal Plants fromvarious gas sources, M/c age factor, gas pricing, inflation trend etc., the fuel charges and fixedcharges for LTPS & NTPS are projected and listed below.

The CERC norm could not be followed in case of ageing NTPS, LTPS for indifferent mode ofoperation & frame sizes of the power stations. For KLHEP also CERC norms was found to be notapplicable as the power project was commissioned after an inordinate delay of 25 years for whichits project cost was not at par comparing with the norms of a Hydro Project’s having normalgestation period & commissioned in 2007.

For NRPP, O&M cost have been considered as per DPR of the Power Projects.

For all other APGCL Power Stations, Employees Cost and A&G Cost has been projected as perapproved escalation rate of AERC in the Tariff Order of 2014-15. For Repair & Maintenance work15% escalation rate has been considered.

Note on Projected Auxiliary Power Consumption (APC) and Station Heat Rate (SHR)considered in the FY 2015-16

(a) Auxiliary Power Consumption (APC):




Years FY 12-13 FY 13-14 FY 2014-15(Actual/Estimate)

Average Projected forFY 2015-16

Namrup TPSAux. Power Cons. (%) 5.6% 6.0% 5.7% 5.8% 5.5%Normative Aux. Power Cons.(%)

4.5% 4.5% 4.5% 4.5% 4.5%

Lakwa TPS with WHPAux. Power Cons. (%) 11.5% 8.8% 8.8% 9.7% 7.5%Normative Aux. Power Cons.(%)

5.5% 5.5% 5.5% 5.5% 5.5%

From the above table, it may be observed that the average actual Auxiliary Power Consumption (APC)for the last 3 years of both LTPS/NTPS found to be in higher side than the normative targets fixed byAERC.

However, APGCL is constantly trying for reduction of APC to the extent possible. Following are thesteps so far taken by APGCL as per recommendation of Energy Audit Report of NPC (NationalProductivity Council)

ACTION TAKEN ON ENERGY AUDIT REPORT

Lakwa Thermal Power Station (LTPS):

The action taken against the recommendations of the Energy Audit Report of NPC along with otheradditional measures including the measures being taken for handing over the transformer feeders toAEGCL and APDCL at LTPS has been detailed below.

Sl.No.

NPC recommendation Action Taken

1. 0.5% reduction in Instrument Aircompressor(Cut off pressure is lowered to6.2 kg/cm2 from 6.6kg/cm2)

Action has been taken

2. Temperature inside the PH-I control roomraised by 1°C


3. Temperature inside the PH-II controlroom raised by1°C


4. Indicating bulbs (2w) in the control panel( Switch Yard replaced by 100 nos 0.5wLED bulbs


5. In PH-I control room:I) total 25 nos of FTLs (2x40W)

replaced by 15 nos TS (62W) Bulbs

II) Gas Turbine Floor: 48 nos SodiumVapour Lamp (250W) replaced by33 nos energy efficient Metal Halide(250W) bulbs

III) Gas Compressor Station: 20 nos200W GLS Lamps replaced by 15nos energy efficient Metal Halide150W bulbs having more Lumens

IV) Power House surrounding area: 30





nos (150W) Sodium Vapour Lampsreplaced by 25 nos Metal Halide(150W) Lamps having moreLumens.

6. PH-II Power House:i) 4 nos conventional (200W) bulbsreplaced by CFL (20W) bulbs in machinecompartments

ii) 13 nos conventional (200W) bulbsreplaced by CFL (20W) bulbs in GasCompressor Station,

iii) 4 nos conventional (200W) bulbsreplaced by CFL (20W) bulbs in GasIntake and Metering Station.


7. i) Colony Lighting: total 100 nos FTLs(40w) replaced by T5 (0.28W) bulbs,

ii) Colony Lighting: total 6 nos 48WLED bulbs installed replacing 250WHPSV lamps,


8. Auxiliary consumption reduced by atleast 0.2% by optimizing GasCompressor running and diverting 0.4to 0.6 MMSCMD gas to PH-I GTsfrom PH-Il Gas Compressors. (by notstarting a gas compressor of rating:525kw, 107A, 3.3KV, 0.85 pf forapprox.10 days in a month.)


9. Skin Loss of GT#3 is minimized.Complete and new insulation will bedone at the time of Major Overhaulingwhich is already due.


ADDITIONAL ENERGY SAVING MEASURES TAKEN AT LTPS

1

Modification of cooling water line ofPh-II Gas Turbines for the followingmultifold benefits.

I. Reduction of auxiliary powerconsumption:- Both the fans and therunning pump of each module arewithdrawn after changeover to thenew system resulting reduction ofpower consumption by the systemconsiderably

II. Availability of Gas and SteamTurbines: LTPS had to take shutdown of GTs on failure of bearingsof motors or fans, motor windings orpumps resulting in reduction ofgeneration. During the period ofOctober’12 to October’13 total





cumulative period of outage ofmachine due to cooling watermodule problem was 139 hours.

III. Capacity generation duringsummer season:-The machine loadshad to reduce during high ambienttemperature in summer season forrestriction of high lube oiltemperature. This reduction of GT’sload had cascading effect on STGloading.

IV. Reduction of O&M cost: TheO&M cost of age old cooling watermodule will be reducedsubstantially as the system will beremain as standby only.

Others: Procurement of normative test checking equipment at LTPS

1 IRISYS Multipurpose Thermal ImagerModel: IRI 4030

Used for non-contact temperature detection.

2 Pressure calibratorMake : FLUKE, USAModel :718300GRange : - 12 to 300 psi

Used for calibration of static and differentialpressure transmitters.

3 Digital Photo Tachometer(Laser Type)Model : DT2234C

Used for non-contact speed detection

4 BoroscopeKARL STORZ EndoskopeMake: KARL STORZ Gmbh& Co. KG,78532 Puttlingen, Germany.

Used for viewing of Gas turbine or machineinternals which are otherwise cannot be seen fromoutside.

Measures to Control Transformer Loss

1 Handing over of 33 kV transformerfeeders to APDCL:

APGCL at present is operating and maintainingtwo nos. of 33 kV feeders at the LTPS switchyard.APGCL is working on to handover these feeders toAPDCL. In this connection, in the meeting held on05/09/2012 at the Office Chamber of theChairman, ASEB in presence of the officials fromAPGCL, AEGCL & APDCL, it was decided totake necessary action for handing over of 33 kVfeeders to APDCL. The process of handing overthese feeders to APDCL is in progress.

The GM, LTPS vide his letter No.LTPS/GM/2014/T-93/2771 dated 09/12/14 haswritten to the GM, APDCL, Jorhat requesting himfor a discussion on the mechanism for transfer ofthe 33 kV feeders from APGCL to APDCL. It isexpected that, a meeting between APDCL andAPGCL on the issue will be held very soon.




Namrup Thermal Power Station (NTPS)

As the major Auxiliary Consumption loss in case of NTPS is observed in the switchyard, dueimportance has been given in handing over the relevant transformer feeders to AEGCL and APDCL.Along with this, other measures as per the comments/recommendations of the Energy Audit Report ofNPC are also being taken for reducing APC loss. All this has been detailed below:

Sl.No.

Measures to Control APC Action Taken

Measures to Control Transformer Loss1 Handing over of 6 nos. of 33 kV

transformer feeders to APDCLi. A meeting was held on 05/09/2012 at the

Office Chamber of the Chairman, ASEB inpresence of the officials from APGCL,AEGCL & APDCL where it was decided totake necessary action for handing over of the220 kV, 132 kV, 66 kV and 33 kV feeders toAEGCL and APDCL respectively.

ii. In another follow up meeting held betweenAPDCL & APGCL on 02/02/2013 to discussthe modalities for the handover of the 33 kVsystem from APGCL to APDCL, it wasinformed by the APDCL authority that they areplanning to construct a 33 kV substation atNTPS and the takeover of 33 kV feeders willbe possible only after completion of theconstruction of the substation.

iii. For this, in a separate communication, APDCLrequested APGCL to provide land at NTPS forthe construction of the said substation. Therequired land has been provided to APDCL andthe same was informed to the CGM (D) videletter no. APGCLCGM (G)/NTPS/APGCL-AEGCL-APDCL/55/23 dated 24/07/2013.

iv. In the meantime, six nos. of 33 kV breakerswith terminal equipment were taken over byAPDCL from 01/04/2013.

v. In a meeting held on 16-08-2013 between theSenior Officers of the three CompaniesAPGCL, APDCL and AEGCL, it wasdiscussed that the tendering process for theshifting of the existing 33 kV system wasgoing on and that the construction work wassupposed to be completed by March’14.However, the work is not yet completed.

vi. Construction of 132/33 kV APDCL substationis going on at NTPS and is expected to becompleted by March’15 as understood fromAPDCL. Transfer of the 6 nos. of 33 kVfeeders to APDCL will be done after thecommissioning of this substation.




2 Handing over of 1 no. of 220 kV, 3 nos.of 132 kV and 6 nos. 66 kV transformerfeeders to AEGCL

i. A meeting was held on 02/08/2013 betweenAPGCL and AEGCL, where the modalitiesfor the handover were discussed.

ii. The matter was also discussed in the meetingheld on 16-08-2013 between the SeniorOfficers of the three Companies APGCL,APDCL and AEGCL, where it was decidedthat a detailed transfer scheme will becompleted soon.

iii. Further, APGCL has again requested AEGCLto complete the work at the earliest vide letterno. APGCL/CGM (G)/NTPS/APGCL-AEGCL-APDCL/60/20 dated 31/03/2014 andvide letter dated 27/08/2014.

iv. On 25/09/14 the followingfeeders/equipment along with the ControlRoom for operation of thesefeeders/equipment were handed over toAEGCL:

a. 3 nos. of 66/132 kV auto transformersb. 1 no. of 132 kV Dibrugarh feederc. 2 nos. of 132 kV Lakwa I & II feedersd. 2 nos. of 220 kV Tinsukia feeders

along with 2 nos. of 220/132 kVtransformers

Action taken as per comments/recommendations of the Energy Audit Report by NPC

1 Minimization of the auxiliaryconsumption and improvement of powergeneration by modifying the illuminationsystem by replacing the existing Filamentbulbs, HPMV Lamps and fluorescenttubes with CFL/LED bulbs in phase-wisemanner.


2 Constant and strict monitoring of highcurrent drawing auxiliaries such as,Cooling Water Pumps, Cooling Towerfans, Boiler Feed Pumps, BoilerCirculating Water Pumps etc.

Continuous monitoring is being done

3 Regular checking of Boiler startup andTurbine Rolling timing up tosynchronization to avoid unnecessarydelay as far as practicable.

Continuous checking is being done

4 Replacement age old motors of differentpumps and Primary Oil Pumps with latesthigh efficiency energy saving motors.

Action being taken

5 Action to solve the problem of differencein temperature between the settemperature and actual temperature of the

Action being taken




Control Room AC as observed by NPC.

By taking above measures APGCL expect to reduce APC for NTPS from Current 5.8% [FY 2014-15(Actual/Estimate)] to 5.5% and accordingly projected in the proposed tariff petition for FY 15-16.

For LTPS basically the higher APC is due to consumption in the gas compressors. As the LTPSmachines having heat rate almost double than the modern generating machines, it implies that therequirement of gas is also double in LTPS compared to similar generating capacity with the latestmachines. Hence the capacity of gas compressor requirement is also enhanced to double attributing thehigher APC. Also, as the pressure of gas supplied to LTPS is often lower than the agreed pressure bythe supplier due to various reasons, the power consumed by the gas compressors also becomes higherdue to extra work that has to be done by the compressors to increase the pressure to the rated pressure.This also contributes to higher APC of LTPS. By implementing the above measures APGCL expect toreduce APC for LTPS with WHU from Current 8.8% [FY 2014-15 (Actual/Estimate)] to 7.5% andaccordingly projected in the proposed tariff petition for FY 15-16.

Further, APGCL also put forwarded its comment in petition form on AERC’s draft notification onamendment on auxiliary consumption norms of NTPS and LTPS vide letter No: AERC/ CGM(G)/AERC/2013-14/115/Pt.-IX/19 Dtd. 21.08.14 appealing APC norms of 5.5% for NTPS and 7.5%for LTPS with WHU, which has been reproduced below.




In view of the above, the projections of APC for the FY 2015-16 have been summarized below:

For Existing Power Project:

1. Namrup TPS: APC of 5.5% has been considered based on the Petition of APGCL for review ofthe normative APC of NTPS & LTPS.

2. Lakwa TPS: APC of 7% for Open Cycle and 9.4% for WHU has been proposed as per DPR.Open Cycle APC of 7% has been considered for LTPS based on the Petition of APGCL forreview of the normative APC of NTPS & LTPS. The overall APC for LTPS with WHU hasbeen projected as 7.5%.

3. 63 MW NRPP: APC of 4.6% has been proposed for the GT by eliminating WHRU auxiliariesfrom the APC of 6.3% for NRPP taken from the approved DPR.

4. Karbi Langpi HEP: APC of 0.5% has been proposed as approved in Tariff Order for FY 2014-15.

5. Myntriang SHEP: APC of 1.0% has been proposed as approved in Tariff Order for FY 2014-15.

(b) Station Heat Rate (SHR):

APGCL has made all out efforts to operate its existing power plant to obtain optimum performancelevel to meet the operating norms fixed by AERC. However, due to fluctuation in supply of gas andintermittent under loading & outage of units due to technical reasons at times lead to higher GSHR inthe past years for both LTPS & NTPS.

To resolve the persistent higher heat rate issues of APGCL’s thermal power stations Hon’blecommission suggested that an institution like IIT / AEC may be approached for studyingactual position of the generating stations the State Advisory Committee held on Dec’ 2012and the report may be submitted to the Commission for review. Accordingly APGCLengaged IIT, Guwahati for the purpose and the report was submitted to AERC in Nov’13.

Accordingly, Hon’ble Commission Notified Draft Amendment of Station Heat Rate of NTPSand LTPS on 31.07.14 as stated below:

Station Approved (Previous) GSHR

(Kcal/kWh)Amended GSHR

(Kcal/kWh)

NTPS (Open Cycle) - 4740

NTPS (Closed Cycle) 3266 4170

LTPS(Open Cycle) 3658 4010

LTPS (Closed Cycle) - 3200




Accordingly, APGCL considered Gross Station Heat Rate for NTPS with WHU as 4170Kcal/Kwh and the Gross Station Heat Rate (open cycle) of 4010 kcal/kWh for LTPS as perAERC’s above draft notification. Gross Heat Rate for combined cycle operation has beenderived with the projected generation of 171.12 MU for WHU as 3213 kcal/kWh as per thecalculation given below:

Gross Open Cycle Heat Rate of LTPS = 4010 kcal/kWhProjected WHRU Generation of LTPS = 171.12 MUProjected Total Generation of LTPS = 861 MUGross Combined Cycle Heat Rate of LTPS = 4010 X [1-(171.12/861)] kcal/kWh

= 3213 kcal/kWh

Basis of projection of Generation of Waste Heat Recovery Unit # 8 of LTPS

The average generation pattern of WHRU from FY2012-13 to September 2014-15 is 43% of thegeneration of Ph.-II Units # 5, 6 & 7. Accordingly for the FY 2015-16 the generation of WHRU hasbeen projected considering above trend of 43% in respect to projected Ph.-II units’ generation ofLTPS.

Gas supply matters:

The Gas Linkage for the existing Gas Plants of APGCL (LTPS & NTPS) is shown as under:

1. LTPS → APM

→ Non-APM

0.40 MMSCMD from GAIL

0.5 MMSCMD from OIL

2. NTPS→ APM 0.66 MMSCMD from OIL.

Gas supply Position:

Gas received during the FY 2013-14 are as under:

LTPS = 296.00 MMSCM.NTPS = 225.90 MMSCM.

The estimated Gas supply for the FY 2014-15 are as under:

LTPS = 279.75 MMSCM.NTPS = 259.56 MMSCM.

Projected Gas availability in the FY 2015-16

BCPL is expected to be commissioned in 2015-16. Earlier after commissioning of BCPL, APGCLwas expected to get lean gas with lower CV. However, after assurance from the gas suppliers ofAPGCL for keeping the same CV of the supplied gas even after commissioning of BCPL, the avg.GCV of gas from 2011-12 to September 2014 has been considered for Generation Projection for2015-16. The details of the gas availability for 2015-16 are given in the table below:

Station PeriodGas

Source

Avg GCVfrom 2011-12to Sep’14 in

kcal/scm

ContractedQuantity

(MMSCMD)

Availability(MMSCMD)

Remarks

NTPS 2015-16OIL

APM9300 0.66 0.66

LTPS 2015-16GAILAPM

9793 0.40 0.40




Apr-Oct OILNon-APM

9300 0.50

0.35Gas availabilityfrom OIL to LTPShas been consideredas per siteexperience

Nov-Mar 0.45

Assumptions for various Heads – I

Table 19:2015-16

ST PLR - 14.75%




ROE 14.00%

Other Income@ 10%escalation

Provision for Taxes

atapprovedby Hon'bleAERC

Provision for Bad and Doubtful Debts% of revenue 0.00%



Mainranence spares1% of GrossBlock














Vehicles 18.00% 18.00%

Furniture & fixture 6.00% 6.00%









Institution 11.40%

Existing Loans

Rates of interest

State Govt 10.50%

PFC


Other 11.40%

Loan Repayment

Govt Loan 15.20

PFC 22.97

Others 0.00

Thermal



Hydel



Table 20

Assumptions for various heads – II

INVESTMENTPROPOSED FOR

2015-16SOURCE

PROPOSED(RS. IN CR)

NTPS

State Govt. equity

State Govt. Loan 3.80

State Govt. Grant

PFC Loan

Others

LTPS

State Govt. equity


State Govt. Grant

PFC Loan

Others

KLHEP

State Govt. equity


State Govt. Grant 2.42

PFC Loan

Others

Construction of a newwater intake pumphouse at Dilli river forconsumptive water

State Govt. equity


State Govt. Grant




requirement of existingplant and NamrupReplacement Project.

PFC Loan

Others

NRPP

State Govt. equity

State Govt. Loan

State Govt. Grant

PFC Loan 160.00

Others

LRPP

State Govt. Equity 54.90

State Govt. Loan

State Govt. Grant

PFC Loan

Others 78.60

CACHARDISTRIBUTEDGENERATIONSYSTEM BY GAS ICENGINE


State Govt. Loan


PFC Loan

Others 16.86

EPC contrct for 2.0 MWSolar Power Project atNTPS

State Govt. Equity


State Govt. Grant

PFC Loan

Others

EPC contrct for 2.0 MWSolar Power Project atLTPS

State Govt. Equity


State Govt. Grant

PFC Loan

Others

Procurement/Acquisitionof land for Titabor GasBased Power Project

State Govt. Equity

State Govt. Loan


PFC Loan

Others

MYNTRIANG


State Govt. Loan


PFC Loan

Others

LOWER KOPILI



State Govt. Grant

PFC Loan

Others

21 MW Karbi LangpiMiddle Stage-I

State Govt. Equity


State Govt. Grant

PFC Loan

Others

24 MW Karbi LangpiMiddle Stage-II

State Govt. Equity


State Govt. Grant

PFC Loan

Others




12 MW KLHEP BarrageToe Project

State Govt. Equity


State Govt. Grant

PFC Loan

Others

60 MW Karbi LangpiUpper Stage

State Govt. Equity


State Govt. Grant

PFC Loan

Others

Installation of deep tubewell with submersiblepump set for watersupply at BKVInvestigation DivisionColony, Jagiroad

State Govt. Equity


State Govt. Grant

PFC Loan

Others

TOTAL PROPOSEDINVESTMENT

State Govt.Equity

249.82



PFC Loan 160.00

Others 95.46

Total 621.36

3.3. Projected Operating Performance Data for FY15-16.

It is expected to continue the current rising trend of generation due to improvement in gas supplyposition of NTPS and LTPS and machines heath conditions of NTPS the station wise operatingperformance data are projected as shown in the following table. For KLHEP we have assumed thedesigned energy as generation target for this FY.

Assumptions considered for projecting Operating Performance for 2015-16 are:

a) Availability: Availability for Thermal Generation has been computed on the basis grossgeneration & projected Aux. cons. as per the formula below:

For Hydro stations, availability has been considered as per design data.

b) Planned Outages: Details of Planned and Forced Outages Considered:

i. For NTPS and LTPS, Planned outage has been considered as per the Maintenance Schedulesfor the year 2015-16 of the respective Power Stations.

ii. In KLHEP, maintenance is carried out during the lean period and thus, it does not affect thegeneration of KLHEP. Hence, for projecting generation of KLHEP, design generation datahas been considered.

c) PLF: Plant Load Factor has been computed on the basis of gross generation as per the formulabelow:

Table 18

Availability = Projected Gross Generation in MW / {total hours in a year X Installed Capacity inMW X (1-Projected Auxiliary Power Consumption in %)} %

PLF = Projected Gross Generation in MW / (total hours in a year X Installed Capacity in MW) %




d) Gross Energy: Gross energy generation has been projected after considering PlannedMaintenance of units, Unit Load factors and as per the Gas availability mentioned above at PageNo. 33.

Further, in case of NRPP, the PLF as mentioned in the DPR is 72%. However, this was calculatedby considering lean gas availability after commissioning of BCPL. As the gas suppliers of APGCLhas assured that they are going to maintain the present CV of gas even after commissioning ofBCPL, the Gross energy from NRPP has been projected at 80% PLF as per the AERC norms fornew thermal power projects.

For calculating the Gross energy of NTPS old units after commissioning of 63 MW NRPP GT inAug’15, 2 nos. of GT units from the old power station and the Waste Heat Unit No. 6 with acombined capacity of 63.5 MW (20 MW Unit #1 + 21 MW Unit #2 + 22.5 MW Unit #6) has beenconsidered to be run with the daily average available gas of 0.29 MMSCMD left after using dailyaverage gas of 0.37 MMSCMD by the GT unit of NRPP at a yearly PLF of 80%.

For Hydro generating station, Gross Energy Generation has been considered as per design energy.

e) Auxiliary Consumption: As mentioned in the Section 3.2 (a) above at Page No. 22 to 32.

f) Gross Station Heat Rate: Gross Station Heat Rates for LTPS & NTPS have been considered asper the draft amendment of the AERC (terms and Conditions for Determination of Tariff)Regulations 2006, which are 4010 kcal/kWh for LTPS Open Cycle operation and 4170 kcal/kWhfor NTPS combined cycle operation respectively.

Table 21Generation Projection for FY 2015-16

NTPS from Apr'15-July'15 FY 15-16

Gross Energy in MU 179.17

Aux. Power Cons. (%) 5.5%

Net Generation in MU 169.36

Availability (%) 54%

PLF (%) 51%

Gross Station Heat Rate on GCV (Kcal/ Kwh) 4170

Sp. Gas Consumption (SCM/Kwh) 0.4484

NTPS with units 1,2 & 6 from Aug'15 toMar'16

FY 15-16





PLF (%) 44%



Total NTPS for 2015-16 FY 15-16





PLF (%) 48%



NRPP 63 MW GT from Aug'15 FY 15-16








PLF (%) 80%



LTPS with WHRU FY 15-16





PLF (%) 63%



KLHEP FY 15-16





PLF (%) 45%

Myntriang SHEP St-II FY 14-15





PLF (%) 81%

Myntriang SHEP St-I FY 14-15





PLF (%) 81%

APGCL FY 15-16

APGCL Total Gross Generation (MU) 1930.71

APGCL APC (%) 5.13%

APGCL Total Net Generation (MU) 1831.57


PLF (%) 59%

Comparison of Approved Generation for 2015-16 in the MYT Order for 2013-14 to2015-16 and Revised Generation Projection for 2015-16

Total Generation Approved in the MYT Order for 2015-16 was 2200.35 MU. New projects consideredwere:

1. 100 MW NRPP: The Project was earlier expected to be commissioned in 2013-14. Annualenergy approved for 2015-16 in the MYT from NRPP was 622.32 MU. However, due to delayin project work, now the 63 MW GT unit of the project is expected to be commissioned inAugust'15.

2. 70 MW LRPP: The project was earlier expected to be commissioned in 2015-16. Annualenergy approved for the project in the MYT for 2015-16 was 415.80 MU. However, due todelay in the completion of the bidding process, the project is now expected to becommissioned after 2015-16.




3. 6 MW Lungnit PP: The St-I of the project was earlier expected to be commissioned in 2014-15 and the St-II in 2015-16. Annual energy approved for the project in the MYT for 2015-16was 26.74 MU. However, due to cancellation of the agreement with the EPC contractor forslow progress of work and litigations arising thereafter, now the project is not expected to becommissioned in 2015-16.

4. Myntriang SHEP St-I: The project was earlier expected to be commissioned in 2014-15.Annual energy approved for the project in the MYT for 2015-16 was 45.77 MU. However, dueto delay in project work, the project is now expected to be commissioned in December'15 withgeneration of 19 MU of energy. This includes 3.5 MU from 3 MW enhancement of the St-Iproject.

Because of the above, the Generation Projection for the FY 2015-16 has to be revised from theapproved energy of 2200.35 MU to 1930.71 MU

3.4. Projected Financial Performance Data for FY 15-16

3.4.1 Employees ExpensesTable 22

Particulars 2015-16

Salaries 48.21

Overtime 2.07

Dearness Allowance 39.33

Other Allowances 7.38

Bonus 0.04

Medical Allowances 0.13

Leave Travel Assistance 0.07

Earned Leave Encashment 0.36

Workmen Compensatory Payment 0.00

Other Staff Cost 0.00

Staff Welfare Expenses 0.19

Terminal Benefits 14.41

Subtotal 112.19

Less: Capitalisation 6.92

Total 105.27

Note: The Hon’ble Commission approved an amount of Rs. 91.42 Crore towards employees cost inthe MYT Order 13-16, however the Employee expenses for FY 14-15 in actual up to 2nd quarter andproportionate for 3rd and 4th quarter comes to Rs. 86.54 Crore. On escalating the same with anescalation factor @ 8.42% the total employees cost comes to Rs (86.54*108.42%=) 93.83 Crore. Inaddition to this Myntriang SHEP is expected to operate at full capacity considering enhanced capacityof 4.5 MW from Dec’15 which increases the employees cost proportionately by Rs. 2.35 Crore.

Further the NRPP is proposed to be commissioned in the FY 15-16 (from August’15). The existingNamrup TPS is proposed to be operated simultaneously along with the NRPP with the left over gasutilizing units, 1, 2 & Waste Heat Unit 6. The balance units 3, 4 & 5 will be kept as standby to run atthe event of excess gas availability and unscheduled outage of NRPP. Hence, the existing manpowerof NTPS cannot be disturbed and cannot be spared for NRPP. New recruitment will be made forNRPP by creation of required post which is projected at Rs. 16.01 Crore (figure calculated as perDPR), thereby totaling the Employees cost at Rs (93.83+2.35+16.01)=Rs. 112.19 Crore. Aftercapitalizing the figures comes to Rs.105.27 Crore.




3.4.2 Repairs & Maintenance

Table 23Particulars 2015-16

A. Regular Repair & Maintenance:-Plant & Machinery 16.95

B. Special Type Repair & Maintenance:-Overhauling Works under plant &Machinery (details as follows) 32.00

Total Plant & machinery (A+B) 48.95

Buildings 0.31

Other civil works 0.35

Hydraulic 1.26

Lines & Cable Network 0.11

Vehicles 0.30

Furniture & fixture 0.16

Office equipment 0.23

Lubricants & Consumable stores 1.62

Turbine Oil 0.26

Total: 53.55

Note:

1. In the above consolidated projection of Repair & Maintenance (R&M) of APGCL, the NTPScomponent of R&M works amounting to Rs. 2.65 Cr. has been computed on the followingmodalities:

Rs. in Cr.

All units NTPS (119.5 MW) running till July'15 tillcommissioning of NRPP

0.88

Unit 1 & 2 & 6 (63.5 MW) running from Aug'15 to March'16with the left over gas after consumption in NRPP

0.94

Standby unit 3, 4 & 5 (56 MW) from Aug'15 to March’16 forrunning in case of excess gas availability & unscheduledoutage of NRPP.

0.83

Total 2.65

2. APGCL feels that an escalation @ 8.42 % for Repair & maintenance expenses is on a lowerside, taking an account of requirement of APGCL and old age of power stations, an escalationtaken @ 15% on R&M projected for FY 15-16 is considered on Regular R&M works

3. Special Type Repair & Maintenance: To keep the generating machines in healthy andrunning conditions, we have to carry out the Major Overhauling (O/H), as per the OEM’s(Original Equipment Manufacturer) Operation Manual.

4. The details units of NTPS and LTPS which are proposed to be overhauled in FY 2015-16 asper OEMs recommendation are stated below:

Station Unit DescriptionAmount (Rs.

in Cr)

NTPS 1

Procurement of capital spares for asTurbine unit-1 of NTPS

6.00

Work Component for Major Overhauling 0.00




Total 6.00

3

Procurement of capital spares for GasTurbine unit-3 of NTPS

6.00


Total 6.00

6

Procurement of capital spares for GasTurbine unit-6 of NTPS

2.00


Total 2.00

Total NTPS 14.00

LTPS3

Procurement of capital spares for GasTurbine unit-3 of phase I of LTPS.

17.50

Major Inspection/ Overhauling of GasTurbine unit No. 3 of LTPS

0.50

Total 18.00

Total LTPS 18.00

Grand Total 32.00

APGCL proposed this Special type of above Repair & Maintenance cost amounting to Rs.32.00 Cr. for consideration under Operation & maintenance (O&M) as a special case to keepthese machines smooth running condition to enable to contribute power to the state of Assamto mitigate shortfall of power to the extent feasible.

The details of unit wise running hours, since from the last overhauled, which justifies theOEM’s recommendation are furnished below:

The Running hours since last overhauling of the units of LTPS and NTPS are:

STATION UNIT

LAST MAJOR

INSPECTION

(DATE/HR)

RUNNING HOURS SINCE

LAST MAJOR

OVERHAULING AS

ON 30/11/14

MAJOR OVERHAULING

REQUIRED AT RUNNING

HOURS AS PER OEM

MANUAL

LTPS

#1DATE- 10.09.13 /

HR-1486167530 28000

#2DATE- 14.07.07 /

HR-12849648965

28000

Major Overhauling Originally

proposed in 2014-15. Now,

scheduled in 2015-16. Amount

already approved in the Review

Order of 2013-14 and also in the

Tariff Order of 2014-15. Action

has already been initiated. LC

opened and materials in transit.

Materials likely to be reached at

site by March’15 and overhauling

will be done in the period Apr’15-




May’15

#3DATE-29.11.04/

HR-1,02,83548957

28000Major Overhauling proposed in

2015-16

#4DATE-25.08.10/

HR-55,35728057 28000

#5DATE-24.02.2014/

HR-804146690

32000 hrs to 48000 hrsdepending on hot gas path

inspection intervals

#6DATE-31.03.2008/

HR-7288644945



Major Overhauling is scheduledin 2015-16. Amount already

approved in the Annual Plan of2014-15. Also included in the

R&M DPR of 2013-14 to 2014-15 submitted to AERC

#7Completed on

03/12/14RH-84886

Major Overhauling completedin 2014-15



NTPS

#1DATE-10.10.2009/

HR-28066639185

28000

Major Overhauling proposed in

2015-16

#2DATE-26.06.13/

HR-2602869349 28000

#3DATE-20.08.10/

HR-29466728750

28000


2015-16

#4DATE-09.09.14/

HR-133220

Major Overhauling completed

in 2014-1528000

#5

DATE-17.06.10

(Forced shutdown due

to Stator Problem)/

HR-209439

15647 75000

#6DATE-May-01/

HR-16403995924

75000


2015-16

From the above table it can be seen that the following overhauling has been proposed in theFY 2015-16:

LTPS Unit-3: The last Major Overhauling of Unit 3 of LTPS was done on 29/11/04. Sincethen the unit has been in operation for 48957 hours till 30/11/14. As per the OEM’s guidelinefor WCL model W191 i.e. for Unit # 3, the overhauling hours may be extended up to 35,000against the recommended 28,000.




Details of LTPS’ GT Units # 3 running hrs from the last overhauling justifying the need ofMajor overhauling as per OEM’s recommendations.

GT UNIT

LAST

MAJOR INSPECTION

(DATE/HR)

RUNNING HOURS SINCE LAST

MAJOR OVERHAULING AS

ON 30/11/14

LTPS #3DATE-29.11.04/

HR-1,02,835

48,957

(Major O/H is overdue)

Hence major overhauling is overdue for Unit # 3 to ensure smooth operation of thegenerating Unit and it is proposed in Jul’15-Aug’15 for 50 days. The cost-benefit analysis ofthis overhauling has been calculated and given is below:

Petition for Approval for Revised ARR and Determination of Generation Tariff for the FY 2015-16 and Truing-Up for FY 2013-14 and APR for FY 2014-15


PROJECT: Major overhauling of LTPS Unit-3

PROJECT COST: 18.00

Loan 18.00

Interest rate for short term loan 15.00%

Rate (WACC) 10.14%

Project Life 4

Escalation of Annual O & M - 8.42%

Depreciation : 22.50%

(Rs. in Cr)

1.NPV Evaluation

No. of

yearsFY

ACQUISITI

ON COSTFuel Cost

ANNUAL

O&M

DEPRECIA

TION

TOTAL

EXPENSES

ANTICIPAT

ED

REVENUE

EARNINGS

BEFORE

TAXES

PROVISIO

N FOR

TAXES

PROFIT

AFTER TAX

OPERATIN

G CASH

FLOW

NPV OF

OP. CASH

FLOW

1 2 3 4 5 6 7=3+4+5+6 8 9=8-7 10 11=9-10 12=11+6 151 2015-16 18.00 37.00 0.45 4.05 59.50 44.35 (15.15) 0.00 (15.15) (11.10) (11.10)

2 2016-17 37.01 0.49 4.05 41.55 45.52 3.97 0.00 3.97 8.02 7.28

3 2017-18 37.02 0.53 4.05 41.60 45.29 3.69 0.00 3.69 7.74 6.38

4 2018-19 37.03 0.57 4.05 41.66 45.06 3.40 0.00 3.40 7.45 5.58

4 2018-19 1.80 1.80

-

Scrap value

18.00 148.07 2.04 18.00 186.11 180.22 (4.10) - (4.10) 12.10 8.13

Since NPV > 0, the major overhauling is accepted.

2. IRR: Year

n

1 (11.10) (11.10)2 7.28 8.02

3 6.38 7.74

4 5.58 7.4549.11%

FW OF CASH

FLOW

Cost Benefit Analysis for Major Overhauling of Unit #3 of LTPS:




NTPS Unit-1: The last Major Overhauling of Unit 1 of NTPS was done on 10.10.2009. Sincethen the unit has been in operation for 39185 hours till 30/11/14. As per the OEM’s guidelinefor Unit # 1, the overhauling hours is 24000 hrs.

Details of NTPS’ GT Units # 1 running hrs from the last overhauling justifying the need ofMajor overhauling as per OEM’s recommendations.

GT UNITLAST MAJOR NSPECTION

(DATE/HR)

RUNNING HOURS SINCE LAST MAJOR

OVERHAULING AS ON 30/11/14

NTPS #1DATE-10.10.2009/

HR-28066639185


Hence major overhauling is overdue for Unit # 1 to ensure smooth operation of thegenerating Unit and it is proposed in Jun’15-Jul’15 for 60 days. The cost-benefit analysis ofthis overhauling has been calculated and is given below:

SOP determination from Major overhauling of LTPS Unit-3Project cost 18.00

Loan 18.00

Equity 0.00

1 2 3 4Annual O&M 0.45 0.49 0.53 0.57

Interest and finance Charges 1.35 2.43 2.16 1.89

depreciation 4.05 4.05 4.05 4.05A Fixed charges 5.85 6.97 6.74 6.51B Interest on working capital 1.55 1.58 1.57 1.57C return on equity 0.00 0.00 0.00 0.00D Fuel Cost 37.00 37.01 37.02 37.03E Sale of Power (A+B+C) 44.35 45.52 45.29 45.06

Note:1 Depreciation @ 22.50% has been taken for evaluation purpose i.e 90%/4

2 Interest on short term loan 15%

3 Annual O&M for the initial year of operation is taken at 2.5% of the project cost.

4 O&M Escalation @ 8.42%

5 Tax @ 32.4%

6 Discounting factor (WACC) 10.14 %

WACC=Rd*(1-t)*D/V+ Re*E/V

where; Rd- cost of debt

Re- cost of equity

E/V- percentage of financing that is equity

D/V- percentage of financing that is debt

t- tax rate

7 Repayment of loan considered to be paid during the life of the project.

8 Estimated actual fuel cost computed is considered for revenue/ SOP determination



Cost Benefit Analysis for Major Overhauling of Unit #1 of NTPS:

PROJECT: Major overhauling of NTPS Unit-1PROJECT COST: 6.00Loan 6.00


Rate (WACC) 10.14%Project Life 4Escalation of Annual O & M - 8.42%Depreciation : 22.50%

(Rs. in Cr)

1.NPV Evaluation

No. ofyears

FYACQUISITION COST

Fuel CostANNUAL O&M

DEPRECIATION

TOTALEXPENSES

ANTICIPATED

REVENUE

EARNINGS

BEFORETAXES

PROVISION FORTAXES

PROFITAFTER

TAX

OPERATING CASH

FLOW

NPV OFOP.

CASHFLOW

1 2 3 4 5 6 7=3+4+5+6 8 9=8-7 10 11=9-10 12=11+6 151 2015-16 6.00 62.04 0.15 1.35 69.54 66.36 (3.19) 0.00 (3.19) (1.84) (1.84)2 2016-17 62.07 0.16 1.35 63.58 66.77 3.18 0.59 2.59 3.94 3.583 2017-18 62.10 0.18 1.35 63.62 66.72 3.09 0.56 2.53 3.88 3.204 2018-19 62.12 0.19 1.35 63.66 66.67 3.00 0.53 2.47 3.82 2.864 2018-19 0.60 0.60

Scrap value6.00 248.34 0.68 6.00 261.02 266.51 6.09 1.69 4.40 9.80 7.79


2. IRR: Year FW OFCASHFLOWn

1 (1.84) (1.84)2 3.58 3.943 3.20 3.884 2.86 3.82

205.78%




SOP determination from Major overhauling of NTPS Unit-1

Project cost 6.00

Loan 6.00

Equity 0.00

1 2 3 4

Annual O&M 0.15 0.16 0.18 0.19


depreciation 1.35 1.35 1.35 1.35

A Fixed charges 1.95 2.32 2.25 2.17

B Interest on working capital 2.36 2.37 2.37 2.37

C return on equity 0.00 0.00 0.00 0.00

D Fuel Cost 62.04 62.07 62.10 62.12

E Sale of Power (A+B+C) 66.36 66.77 66.72 66.67

Note:

1 Depreciation @ 22.50% has been taken for evaluation purpose i.e 90%/4




5 Tax @ 32.4%




Re- cost of equity



t- tax rate



NTPS Unit-3: The last Major Overhauling of Unit 3 of NTPS was done on 20.08.10. Sincethen the unit has been in operation for 28750 hours till 30/11/14. As per the OEM’s guidelinefor Unit # 3, the overhauling hours is 24000 hrs.



(DATE/HR)



NTPS #3DATE-20.08.10/

HR-29466728750


Hence major overhauling is overdue for Unit # 3 to ensure smooth operation of thegenerating Unit and it is proposed in Nov’15-Dec’15 for 60 days. The cost-benefit analysisof this overhauling has been calculated and is given below:




PROJECT: Major overhauling of NTPS Unit-3PROJECT COST: 6.00Loan 6.00


Rate (WACC) 10.14%Project Life 4

Escalation of Annual O & M - 8.42%Depreciation : 22.50%

1.NPV Evaluation Rs Cr

No. ofyears

FYACQUISITION COST

FuelCost

ANNUAL O&M

DEPRECIATION

TOTALEXPENSE

S

ANTICIPATED REVENUE

EARNINGS

BEFORETAXES

PROVISION FORTAXES

PROFITAFTER

TAX

OPERATING CASHFLOW

NPV OFOP.

CASHFLOW

1 2 3 4 5 6 7=3+4+5+6 8 9=8-7 10 11=9-10 12=11+6 151 2015-16 6.00 40.72 0.15 1.35 48.22 44.24 (3.98) 0.00 (3.98) (2.63) (2.63)2 2016-17 40.73 0.16 1.35 42.25 44.64 2.39 0.34 2.05 3.40 3.093 2017-18 40.75 0.18 1.35 2.28 44.58 2.30 0.31 1.99 3.34 2.764 2018-19 40.77 0.19 1.35 2.31 44.52 2.21 0.28 1.93 3.28 2.464 2018-19 0.60 .60

Scrap value6.00 162.97 0.68 6.00 175.65 177.98 2.92 0.92 2.00 7.40 5.67


2. IRR: YearFW OFCASHFLOWn

1 (2.63) (2.63)2 3.09 3.403 2.76 3.344 2.46 3.28

115.46%





Project cost 6.00

Loan 6.00

Equity 0.00

1 2 3 4

Annual O&M 0.15 0.16 0.18 0.19


depreciation 1.35 1.35 1.35 1.35

A Fixed charges 1.95 2.32 2.25 2.17



D Fuel Cost 40.72 40.73 40.75 40.77


Note:





5 Tax @ 32.4%




Re- cost of equity



t- tax rate



NTPS Unit-6: The last Major Overhauling of Unit 6 of NTPS was done on May-01. Sincethen the unit has been in operation for 95924 hours till 30/11/14. As per the OEM’s guidelinefor Unit # 6, the overhauling hours is 75000.



(DATE/HR)



NTPS #6DATE-May-01/

HR-16403995924


Hence major overhauling is overdue for Unit # 6 to ensure smooth operation of thegenerating Unit and it is proposed in Aug’15-Sep’15 for 60 days. The cost-benefit analysisof this overhauling has been calculated and is given below:




PROJECT: Major overhauling of NTPS Unit-6

PROJECT COST: 2.00

Loan 2.00


Rate (WACC) 10.14%

Project Life 4Escalation of Annual O & M - 8.42%

Depreciation : 22.50%

1.NPV Evaluation (Rs. in Cr)

No. ofyears

FYACQUISI

TIONCOST

FuelCost

ANNUAL O&M

DEPRECIATION

TOTALEXPENSE

S

ANTICIPATED

REVENUE

EARNINGS

BEFORETAXES

PROVISION FORTAXES

PROFITAFTER

TAX

OPERATING CASH

FLOW

NPV OFOP. CASH

FLOW

1 2 3 4 5 6 7=3+4+5+6 8 9=8-7 10 11=9-10 12=11+6 15

1 2015-16 2.00 - 0.05 0.45 2.50 0.67 (1.83) 0.00 (1.83) (1.38) (1.38)

2 2016-17 - 0.05 0.45 0.50 0.80 0.29 0.00 0.29 0.74 0.67

3 2017-18 - 0.06 0.45 0.51 0.77 0.26 0.00 0.26 0.71 0.59

4 2018-19 - 0.06 0.45 0.51 0.75 0.23 0.00 0.23 0.68 0.51

4 2018-19 0.20 0.20Scrap value

2.00 - 0.23 2.00 4.23 2.98 (1.04) - (1.04) 0.76 0.39

Since NPV> 0, the major overhauling is accepted.

2. IRR: Year FW OFCASH FLOWn

1 (1.38) (1.38)

2 0.67 0.74

3 0.59 0.714 0.51 0.68

25.93%





Project cost 2.00

Loan 2.00

Equity 0.00

1 2 3 4

Annual O&M 0.05 0.05 0.06 0.06


depreciation 0.45 0.45 0.45 0.45

A Fixed charges 0.65 0.77 0.75 0.72



D Fuel Cost 0.00 0.00 0.00 0.00


Note:





5 Tax @ 32.4%




Re- cost of equity



t- tax rate








Rent, Rates & Taxes 0.39

Insurance 0.94

Telephone charges 0.06

Postage & Telegram 0.00

Legal charges 0.01

Audit fees 0.00

Consultancy charges 0.71

Technical fees 0.00

Other Professional fees 0.00

Conveyance & Travel charges 0.78

Freight 0.02

Other purchase related expenses 7.64

Energy bill raised by APDCL 0.00

Sub Total: 10.56

Less: Capitalised 0.70

Total: 9.85

Note: Escalation taken @ 8.42% for A&G expenses

3.4.4 Return on Equity


Namrup TPS 9.86

Lakwa TPS 11.50

Lakwa WHRP 9.93

Karbi Langpi HEP 9.54

Myntriang SHEP 3.27

Namrup RPP 14.57

Total 58.66

ROE calculated as follows:Particulars NTPS LTPS KLHEP LWHRP NRPP Myntriang Total

15-16 15-16 15-16 15-16 15-16 15-16 15-16

Opening Equity 67.34 79.24 68.11 70.92 0.00 13.37 298.98

Closing Equity 73.58 84.98 68.11 70.92 208.12 33.34 539.04

Average equity 70.46 82.11 68.11 70.92 104.06 23.35 419.01

Rate 0.14 0.14 0.14 0.14 0.14 0.14 0.14

ROE 9.86 11.50 9.54 9.93 14.57 3.27 58.66

3.4.5 Income from Other Sources


Interest on Staff Loans and advance 0.00

Income from Investment 8.85

Income from sale of scrap 0.06

Rebate for timely payment 0.79

Misc. receipts (except 62.901 & 62.908) 0.90

Rent from residential building 0.01

Total: 10.60




Note: Other income incurred in FY 2013-14 is considered at par for FY 2015-16

3.4.6. Depreciation


Land & Rights 0.00

Buildings 0.74

Hydraulic 4.23


Plant & Machinery Thermal 31.23

Plant & Machinery Hydel 5.10


Vehicles 0.12

Furniture & fixtures 0.23


Roads on land belonging to others 0.00

Capital spares at generating stations 3.69

Total 50.04

(Less) : Depreciation on 90% of theAssets funded by Grants/subsidies -10.16

Net Total 39.88


3.4.7 Interest & financing charges


Interest on loans 82.62

Other finance charges 6.43

Sub total 89.05

Less: Interest capitalised -24.21

Total 64.84Note: Interest on loans & Other Finance Charges calculated for FY 14-15 @ 10.5% on loanoutstanding for Loan from Govt. of Assam, @ previous interest rates charged by PFC for Loanfrom PFC. GPF trust is expected to complete in FY 14-15 and hence interest on GPF isclaimed from FY 15-16

3.4.8 Interest on Working Capital

Table 29

Particulars 2015-16

One month Fuel Cost 43.49

One month approved O&M Cost 13.77

Maintenance Spares 13.28

Two month Receivables 137.07

Total 207.61

Interest @ 14.75% 30.62




Note: Interest on working capital is computed @ an interest rate of 14.75% as per AERC

3.4.9 Repayment of Loan (Principal)Table 30

Particulars 2015-16

PFC Loan 22.97

State Govt Loan 15.20

Total 38.16

3.4.10. Fuel CostTable 31

Particulars 2015-16Namrup TPS 127.25NRPP 75.41Lakwa TPS 319.26Total 521.92

4. Profit & Loss AccountTable 32

Particulars 2015-16

Power Generation

Energy generated (MU) 1930.71

Sale of Power (MU) 1831.57

Auxiliary Consumption, Loss % 5.13%

INCOME

Revenue from tariff & Misc. charges 871.42

O&M expenses of CTPS 3.50

EXPENDITURE

Generation Cost 521.92

R&M Expenses 53.55

Employee Expenses 105.27

A&G Expenses 9.85

Depreciation 39.88

Interest & Finance Charges 89.05

Less: Interest & other expenses capitalised -24.21

Interest on working Capital 30.62

Other Debits (incl. Prov. for bad debts, int of W/Capital etc.) 0.00

Extraordinary Items 0.00

Other (Misc.) - net prior period credit 0.00

Total 825.93

ROE 58.66

Other Income 10.60

Provision for taxes 0.93

Annual Revenue Requirement 874.92

Surplus(+) / Shortfall(-)




5. Balance SheetTable 33

Particulars 2015-16

Source of Fund

Share Capital 455.86

Reserve & Surplus 43.96

Loans from State Govt 224.62

Loans from others 760.95

Total 1485.39

Contributions, grants & subsidies towards cost of Capital Asset 434.77

Grand Total 1920.16

Application of Fund

Net Fixed Assets

(A) Gross Block 2236.49

(B) Less : Accumulated Depreciation 689.53

(C) Net Fixed Assets 1546.96

(D) Capital-works-in-progress 183.91


(F) Deferred Cost


Total of (C) to (G) 1730.87

Investments 0.00


Net Current Assets


i) Inventories 82.59

ii) Receivables against Sale of Power 4.17

iii) Cash & Bank Balance 186.45

iv) Loans & Advances 69.45

v) Other current assets 92.25

Total of A 434.91



ii) Payment due on Capital Liabilities

iii) Other current liabilities 247.62

Total of B 247.62

Net Current Assets (A - B) 187.29

Profit/ Loss 2.00

Grand Total 1920.16

Station wise information for claiming ARR and Tariff for FY 2015-16 is depicted inAnnexure-IV (Page No. 148)


Assam Power Generation Corporation LimitedPage57 of 227

6. Proposed ARR for FY 2015-16:

Table 34: (Station wise, FY 15-16)(Rs in crore)

Particulars 2015-16NTPS LWHRP LTPS (LTPS +

LWHRP)CTPS KLHEP Myntriang NRPP Total

Gross Generation (MU) 342.98 171.12 689.87 861.00 0.00 390.00 41.59 295.14 1930.71

Aux. Power Consumption (MU) 18.82 16.09 48.29 64.38 0.00 1.95 0.42 13.58 99.14

Net Generation (MU) 324.16 155.04 641.58 796.62 0.00 388.05 41.17 281.57 1831.57

Fixed Charges

Operation & Maintenance

Employee Cost 35.02 9.51 30.55 40.06 3.45 14.59 1.47 10.67 105.27

Repairs & Maintenance 16.65 0.83 28.35 29.18 0.00 7.69 0.03 0.00 53.55

Administrative & General Expenses 1.54 0.47 3.74 4.21 0.01 2.97 0.24 0.89 9.85

Interest & Finance Charge 4.77 12.44 6.84 19.28 0.04 11.19 0.47 29.09 64.84

Interest on working Capital 7.32 1.44 15.13 16.57 0.00 2.22 0.13 4.39 30.62

Taxes on income 0.31 0.00 0.31 0.31 0.00 0.31 0.00 0.00 0.93

Depreciation 1.33 10.93 4.81 15.74 0.00 8.75 -0.73 14.78 39.88

Provision for Bad & Doubtful Debts 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Return on Equity 9.86 9.93 11.50 21.42 0.00 9.54 3.27 14.57 58.66

Less: Other Income -3.68 0.00 -3.69 -3.69 0.00 -3.23 0.00 0.00 -10.60

(A. 1) Total Fixed Charges 73.12 45.54 97.55 143.09 3.50 54.02 4.87 74.40 353.00(A. 2) R&M Expenses approved vide letter No.AERC 442/2014/15 "Order on Review Petition onTariff Order for FY 13-14" dated 08.07.2014 26.73

(A) Total Fixed Cost 379.73

(B) Fuel Cost 127.25 0.00 319.26 319.26 0.00 0.00 0.00 75.41 521.92

ARR (A) + (B) 200.37 45.54 416.81 462.35 3.50 54.02 4.87 149.81 901.65

Fixed Cost Paise / Kwh (sent out) 225.55 293.76 152.04 179.62 139.22 118.31 264.23 207.33

Fuel Cost Paise/ Kwh (sent out) 392.56 0.00 497.61 400.77 0.00 0.00 267.81 284.96

Tariff Paise/ Kwh (sent out) 618.12 293.76 649.65 580.39 139.22 118.31 532.04 492.28

Note: The Secondary Energy Charges will be computed as per the lowest variable charge bearing Central Sector Generating Station as per CERC Tariff Orderfor FY 2014-19



7. Directives of AERC

Directives of the Commission in its Tariff Order for FY 2013-14 to 2015-16

Updated report up to the 2nd quarter of 2014-15 on the Compliance of old Directives and new Directives issued by the Commission in the Tariff Order for FY 2013-14 to 2015-16 has already been furnished to AERC vide letter No. APGCL /CGM (G) / AERC / 2014-15 / T&C / 6 Dtd. 30/10/2014 and the abstract of the same is given below:

Old Directives issued in Tariff Order dated 16 th May, 2011

DirectiveNo:

AERC’s Directive Comments of the Commission on21.05.2014

Latest Status

1 Directive4: Auxiliary Consumption

The auxiliary consumption of both the thermal stations (NTPSand LTPS) is on high side. APGCL was directed to carry out energyaudit of both the thermal stations and take steps to reduce theauxiliary consumption to the required levels and compliancesubmitted to Commission.

Noted. The efforts should becontinue and the status on PAT besubmitted every quarter.

Both LTPS and NTPS placed orders to anAccredited Energy Auditor, M/S A2ZMaintenance & Engineering Services Ltd.Gurgaon for verification of Form-1, 2& 3and for submission of Form-A as per the PATnorms.Forms 1, 2 &3 have been verified by theEnergy Auditor and submitted to BEE for theyears 2012-13 and 2013-14. Forms for theyear 2014-15 along with form A as performat for the 3 years 1st cycle period of PATmechanism will be submitted aftercompletion of the financial year 2014-15.

2 Directive3: Employee’s Provident Fund

APGCL is utilizing the provident fund amount recovered from theemployees and no such account is maintained. APGCL wasdirected to maintain separate accounts for the amountsrecovered from the employees towards provident fund and itsutilization duly audited by Statutory Auditors.

As requested, a letter is beingforwarded to the State Governmentfrom the Commission on 24.06.2014

Noted. APGCL further sent another letter tothe Commissioner & Secretary, Power(Elect.) Dept., GOA on the issue inAugust’14.

3 Directive-5: Procurement of Gas



DirectiveNo:


Latest Status

APGCL is not getting the committed quantity of gas from the gassuppliers due to which generation of energy is getting reducedcorrespondingly. APGCL shall make all the efforts to get the gassupply as per commitment and also to get allotment of additionalgas supply to overcome the problem of inadequate availability ofpower in the State.

The Company is required to pursuethe matter urgently with the StateGovernment for adequate gassupply to power stations to improvepressure of the supplied gas. The gassupply Agreement should bereviewed.

A statement of drawing of gaseous fuel byNTPS &LTPS in Jul’14 and Sep’14 is givenbelow:

Month Received/ Allotted Qty (MMSCM)

NTPS (OIL) LTPS(OIL)

LTPS(GAIL)

Jul’14 22.13/20.46

(108%)

10.00/15.50(65%)

12.40/12.40

(100%)

Aug’14 21.73/20.46

(106%)

8.88/15.50(57%)

13.20/12.40

(106%)

Sep’14 21.05/19.80

(106%)

9.73/15.00(65%)

11.16/12.00(93%)



DirectiveNo:


Latest Status

During this period, natural gas supplied byOIL to LTPS was erratic. APGCL is making allout efforts to get the gas supply as percommitment and also to get allotment ofadditional gas supply to overcome theserious setback of poor generation of powerin the state. In this connection APGCL haswritten a letter to AGCL with penalty bill fortransporting gas through the existing LowPressure pipeline only to LTPS for whichAPGCL is not getting the contracted quantityof gas from OIL, whereas, as per theagreement with AGCL, they are supposed totransport the gas through high pressure/lowpressure pipeline to maintain adequateparameters at APGCL end.

Also, To improve the situation, APGCL wroteto the Chairman and Managing Director, OILand Natural gas corporation Ltd and to theSecretary to Govt. of India, Ministry ofPetroleum and Natural gas to allocate 0.15MMSCMD of gas available at ONGC gasfields near Golaghat District.

The draft renewal agreement between OILand APGCL for supply of gas to LTPS is underscrutiny and will be finalized shortly



DirectiveNo:


Latest Status

4 Directive-6: Performance Parameters

The Performance Parameters of the gas-based power stations(NTPS, LTPS) are far below the national standards. APGCL shallendeavor for R&M assistance from the Government of Indiaschemes and implement such steps so that the performances ofthe plants are brought to the national average level.

Noted. Detailed R&M schemessubmitted for NTPS, LTPS and KLHEPfor 2013-15 for in-principle approvalof the Commission is under process.APGCL should ensure timelycompletion of the projects.

Performance parameters of APGCL PowerStations are regularly submitted to AERC

5 Directive-7: Monitoring of Progress of New Power Projects

The detailed progress report on new and ongoing R&Mandgeneration projects is to be submitted by the Utility quarterlybefore the Commission without fail, for review.

APGCL should expedite the ongoingR&M and generation projects andensure that the projects arecompleted on time. Any delay in theprojects need to be brought to thenotice of the commissionimmediately with authentic reasons,for approval.

Progress Report on implementation of NewProjects (Thermal) & ongoing R&M projectsof APGCL are being regularly submitted toAERC.

6 Directive-9: Performance of Petitioner’s Plants

A lot of concern had been expressed by the stakeholders on theneed for improvement in the performance of NTPS and LTPSwhere most of the Units are more than 25 years old. There is ascope for improvement in generation from these plants byincreasing their existing capacities to at least their original designvalues, which have been stated to have reduced due to wear andtear during past many years. The more important issue is that ofensuring generation availability from these plants for longerduration of time as most of these plants have already outlivedtheir originally envisaged useful life. Accordingly, the Commissionwas of the view that these plants urgently need Renovation,Modernization and Up gradation (RMU) for both improvement ingeneration capacity and life extension.

The matter is under process Noted.



DirectiveNo:


Latest Status

The Commission therefore, directed the Petitioner to submit thefinal DPR with cost benefit analysis indicating life extensionperiod shall be submitted for approval of the Commission asearly as possible.

7 Directive-10: Need for Augmenting Own Generating Capacity

APGCL shall make all out efforts to complete the ongoing projectswithin stipulated time to avoid time and cost overruns.

Noted, APGCL shall make all-outeffort s to complete the on-goingprojects within stipulated to avoidtime and cost overruns. Any delay inthe projects need to be brought tothe notice of the Commissionimmediately stating the reasons fordelay and percentage of workscompleted till date, for approval.

Noted. All out efforts are being made byAPGCL for timely completion of its ongoingprojects. Latest status of ongoing and newprojects as on 30/11/14 has been given inSection-8.1 at Page No. 70



Fresh Directives of AERC issued in the Tariff order for FY 2013-14Directive

No:AERC’s Directive Comments of the

Commission on21.05.2014

Latest Status

1. Submission of DPR for Renovation & Modernisation Schemes:

The Commission observed that that most of the expenses submittedby APGCL under Repair & Maintenance expenses are of CapitalExpenditure nature such as - major overhauling of LTPS station isrequired to be undertaken for Unit-6 and Unit-7 during the ControlPeriod, and procurement of spares. Accordingly, the Commissiondirects APGCL to include the major overhauling in the scope of work ofRenovation and Modernisation and submit the Detailed Project Reportwith cost benefit analysis for approval of the Commission.

Noted. DPR for NTPS, LTPS & KLHEP for proposed Renovation &Modernisation Works furnished Vide Letter No:APGCL/CGM(G)/AERC/2013-14/115/Pt-IX/33dtd 20/12/2014

2. Capital Cost of Small Hvdro Projects:

The Commission observed that Capital Cost of new hydroelectricproject Myntriang SHEP and Lungnit SHEP has increased significantlyon account of cost and time over run. In this regard, the Commissiondirects APGCL to submit the Petition with detailed break-up of theCapital Cost for approval of the Commission.

Noted Reply in response to AERC’s letter No. AERC.447/2014/6dated 16.05.2014 has been furnished vide our letter No.APGCL/CGM (G)/MYT/13-16/232/Part/Myntriang Tariff/6dtd 28/10/14 on the in principle approval of capital costof 9 MW Myntriang SHEP. However, reply regarding 6MW Lungnit SHEP and enhanced capacity of 4.5 MW ofMyntriang SHEP is being prepared and will be furnishedshortly.

3. Creation of Tariff Regulatory Cell:

APGCL shall create/constitute a Tariff Regulatory Cell (under an Officerof status/rank not below that of General Manager or equivalent)within one month from the date of issue of this Order. The Cell soconstituted/created shall be provided with necessary authority andresources so as to look after all the tariff regulatory matters primarilyto provide correct and timely information to the Commission as well asstakeholders, and should be the primary source of all data andsubmissions being filed before the Commission, so as to ensureconsistency and timeliness of the data submitted and proper co-ordination with the Commission in the tariff determination process.

Noted Directive already implemented




8. Investment Plan for FY 2015-16

The projected demand of power of Assam by end of 12th Plan (12-13 to 16-17) is 2293 MWas per CEA’s 17th EPS. To meet this energy demand to the extent feasible, APGCL, at theinitiative of Govt. of Assam, has emphasized on development of large capacity thermalpower projects based on coal & natural gas available in this region. This would in a wayminimize over dependency on hydro power particularly during lean hydro generation periodand to balance a suitable Thermal & Hydel generation ratio. Further, to harness renewablesource of energy as per policy of GOA for development of SHP, APGCL has identified 37Nos. of locations in Assam. Process has been initiated for engaging nationally/internationallyreputed professional consultancy to prepare Techno Economic Studies including preparationof DPRs.

In order to meet the ever growing demand of electricity in the state, APGCL has earmarkedon large investment plan for development of power projects. This will also help in the growth& profitability of the company.

The additional capacity envisaged after development & implementation of proposed thermaland hydro-electric power projects in 2015-16 along with proposed investment are shown inthe Tables I & II below.

On implementation of the proposed projects, APGCL will be in a position to mitigateconsiderably the shortfall of power in the state of Assam.

Investment Plan Table-1

Name of Power Station12-13

InstalledMW

13-14Installed

MW

14-15Installed

MW

15-16Installed

MWNamrup TPS 119.5 119.5 119.5 63.5Lakwa TPS with WHU 157.2 157.2 157.2 157.2Karbi Langpi HE Project 100.0 100.0 100.0 100.0Myntriang SHE Project 0.0 0.0 3.0 13.5Namrup RPP 0.0 0.0 0.0 63.0Lungnit SHE Project Commissioning beyond 2015-16Lakwa RPP Commissioning beyond 2015-16

Gas IC Engine based Cachar PP Commissioning beyond 2015-16Gas IC Engine based Titabor PP Commissioning beyond 2015-16Margherita TPS Commissioning beyond 2015-16Solar PV Project at LTPS Commissioning beyond 2015-16Solar PV Project at NTPS Commissioning beyond 2015-16Lower Kopili HEP Commissioning beyond 2015-16TOTAL 376.7 376.7 379.7 397.2



Investment Plan Table-IIInvestment Proposal for the FY 2015-16

Sl. No. Name of the Project

Approvedin the MYTOrder for2015-16

Revised Investment for 2015-16

RemarksCommercial Date of Operation if

Commissioned in 2015-16Govt(Equity)

GOA(Loan)

Grant(Govt)

FI(Loan)

TotalProposed

investmentThermal Wing

1 R&M of Namrup TPS 0.00 3.80 3.80 The DPR for NTPS, LTPS & KLHEPfor proposed Renovation &Modernisation Works in the FY 15-16 has been furnished Vide LetterNo: APGCL/CGM(G)/AERC/2013-14/115/Pt-IX/33dtd 20/12/2014 as directed by theHon’ble Commission in its TariffOrder for 2014-15.

2 R&M of Lakwa TPS 0.00 20.62 20.62

3 R&M of KLHEP 0.00 5.38 2.42 7.80

4

Construction of a new water intakepump house at Dilli river forconsumptive water requirement ofexisting plant and NamrupReplacement Project.

0.00 17.00 17.00 New proposal.

5 100 MW Namrup RPP 0.00 160.00 160.00

Earlier NRPP was expected to becommissioned in 2013-14.However, due to slow progress ofwork by the EPC contractor BHEL,the GT unit of the project is nowexpected to be commissioned inAugust’15

63 MW GT expected to becommissioned in August'15

670 MW Lakwa Replacement PowerProject

277.76 54.90 78.60 133.50

Earlier LRPP was expected to becommissioned in 2015-16.However, due to delay incompletion of the bidding processfor various reasons, the projectwork is now expected to start in2015-16

Commissioning beyond 2015-16



730 MW Cachar Distributed GenerationSystem by Gas IC Engine

0.00 3.80 0.83 16.86 21.49

Due to non establishment of gaslinkage, project work has not beenstarted. Project work now isexpected to be started in 2015-16.Grant of Rs. 0.83 Cr is forprocurement/acquisition of land forthe project.


8EPC contract for 2.0 MW Solar PowerProject at NTPS

0.00 17.00 17.00 New Project Commissioning beyond 2015-16

9EPC contract for 2.0 MW Solar PowerProject at LTPS

0.00 17.00 17.00 New Project Commissioning beyond 2015-16

10Procurement/Acquisition of land forTitabor Gas Based Power Project

0.00 0.49 0.49 New proposal. Commissioning beyond 2015-16

Hydro Wing

11 13.5 MW Myntriang SHEP 0.00 8.12 23.50 31.62

Due to delay in project execution,the St-I of the project is yet to becompleted. Further, the project hasbeen enhanced by another 4.5 MW

2X3 MW St-I along with 1X3 MWenhancement and 1X1.5 MWenhancement in St-II is expected tobe commissioned in December'15

12 6 MW Lungnit SHEP 21.00 0.00

Project work is at the moment athalt due to litigations related tocancellation of Work Order withearlier EPC Contractor due to slowprogress of work


13 120 MW Lower Kopili HEP 0.00 183.00 7.00 190.00

Project work has not started yetdue to delay in obtaining variousclearances. Project work isexpected to be started in the FY2015-16 with the finance from theGOA. equity first.


14 21 MW Karbi Langpi Middle Stage-I 0.00 0.25 0.25

Projects are in DPR preparationstage

Commissioning beyond 2015-1615 24 MW Karbi Langpi Middle Stage-II 0.00 0.25 0.2516 12 MW KLHEP Barrage Toe Project 0.00 0.25 0.2517 60 MW Karbi Langpi Upper Stage 0.00 0.25 0.25

18

Installation of deep tube well withsubmersible pump set for water supplyat BKV Investigation Division Colony,Jagiroad

0.00 0.05 0.05 New proposal.

Total Proposed Investment 298.76 249.82 88.85 27.23 255.46 621.36




Breakup of R&M Plan for FY 15-16 is given in the table below:

SlNo.

Name of Schemes and Approved Outlay

BudgetProposal

(Rs inCr.)

Total(Rs. In Cr)

(A) R&M Works under Namrup Thermal Power Station (NTPS)-Govt. Loan:

1Replacement of existing 11 KV PILC single core copper cable fromgenerator terminal to 11KV Unit Transformer of Gas Turbine Unit-3 with XLPE cable along with terminal joints.

0.65

3.80

2Replacement of existing BHEL make AVR at GT Unit-3 withmicroprocessor based AVR.

0.60

3Replacement of existing Analog AVR for Diesel Generator unit-1 &2 of Diesel Power House by new microprocessor based digital AVR.

0.30

4Procurement & renovation of cooling tower of Steam Turbine unit-5

1.00

5Procurement & renovation of cooling tower of Steam Turbine unit-6

1.00

6Procurement of 66 kV, 800 A, double break triple pole gangoperated rotating centre pole isolating switch.

0.25

(B) R&M Works under Lakwa Thermal Power Station (LTPS) - Govt. Loan:

7Procurement and up gradation of one number Speedtronic Mark-IVControl System to Mark- VIe Control System at GT Unit-5 .

7.00

20.62

8Procurement of Plan security measures with CC camera andaccessories.

0.20

9Repairing of one HT spare motor for gas compressor of Phase-IIPower House.

0.35

10Procurement of Phase-I 132 kV main bus sectionalizing systemwith breaker, isolator & electrical panels.

0.33

11Procurement of Isolators of Phase-1 switchyard is required forreplacement of the existing old isolators.

0.50

12Procurement of relay of protection systems: i) Numerical relay for3.3 kV system ii) Numerical relay for 33 kV system iii) Numericalrelay for 132kV system.

0.34

13Up-gradation of the existing damaged Hydrant fire fighting systemof the Power Plant.

0.75

14 Procurement of Air Filter for Gas Turbine of Phase-II. 0.20

15 Procurement of three (3) numbers motor operated steam valves. 0.15

16Procurement of one (1) no. new pump motor set for water Intakealong with pipes, valves, cables etc.

0.65

17 Procurement of some major spares of WHRP. 1.50

18 Fire tender with foam and water facility at LTPS . 0.45

19Procurement of spares for Gas Compressor & air compre4ssor ofPhase-II at LTPS.

0.80

20Procurement of one no. 300AH, 120 V Battery bank for GT unit- 1of LTPS

0.15

21Procurement of spares for GT Starting Diesel Engine of unit#1, #3,#5 & #6 .

0.20

22Development of existing colony water supply and WHRP supplysystem. 2.75

23

Construction of new departmental quarters for employee:

1.80(a) One Type-V multistoried building with eight (8) blocks.

(b) One Type-VI multistoried building with eight (8) blocks.

24 Repairing of a part of road inside colony at LTPS 1.20

25 Development of the backyard of the new compressor building withPCC and road 0.60




26 Repairing of Burge at river Suffry at LTPS 0.10

27 Construction of Master Drain at LTPS 0.60

(C) R&M Works under Karbi Langpi Hydro Electric Project: Govt. Loan

28Procurement of one no. 220/33 kV, 25.0 MVA Station ReserveTransformer with one set of C.T. (220 kV) for KLHPP

4.50

5.38

29 Procurement & replacement of Shaft Seal KLHEP Hydro turbine. 0.20

30Procurement for renovation of 33 kV 8(Eight) units indoor Control/Relay panel having 2 nos. Incomer & 6 nos. outgoing panel.

0.50

31Procurement for renovation of Firefighting (Hydrant) system withEcofriendly system and renewed positioning of piping system.

0.18

(D) R&M Works under Karbi Langpi Hydro Electric Project: Govt. Grant

32 Repairing of Amtereng Hatidubi Road 1.17

2.4233 Boulder pitching at upstream side of right bank and left bank and

downstream side of right bank at Hatidubi Dam includingconstruction of stone masonry drain near Hatidubi Dam 0.50

34Slope stabilization works at the Right Bank (downstream side) andprotection works at the top of landslide zone of Dam site atHatidubi Dam, KLHEP 0.75




8.1. The brief Status of proposed on-going & new schemes of APGCL includingR&M and joint venture projects are depicted below:

8.1.1. Renovation & Modernisation (R&M):In continuation of successful execution of R&M, PH-I, PH-II & PH-III schemes, it has beenproposed for implementation of a comprehensive R&M schemes Phase-IV for LTPS, NTPS& KLHEP covering the period 2013-14 to 2015-16. The Ph.-IV R&M schemes have beennecessitated in order to ensure maximum reliability and availability of the existing old unitsof both LTPS, NTPS & KLHEP to maximize generation. The R&M of power stations hasbeen considered to be the most attractive economic option for the Company. R&M schemesare aimed at reducing auxiliary power consumption, and improving PLFs of generating unitsby sustaining an efficient and smooth operation of plants.

Hence, keeping in view of the above, a comprehensive R&M Ph.-IV scheme has beenformulated for LTPS, NTPS & KLHEP for implementation during the period of 2013-14 to2015-16.

The expenditures proposed to be incurred in the FY 15-16 as a part execution of the R&MPh.-IV scheme & scope of works in general are mentioned below.

R&M of Lakwa Thermal Power Station (For FY 2015-16):The R&M scheme has been proposed for the FY 2015-16 at an estimated cost of Rs 20.62 Croreunder the Annual Plan of 2015-16. The scheme comprises of procurement and up gradation of

1. one number Speedtronic Mark-IV Control System to Mark- VIe Control System at GTUnit-5,

2. procurement of CC cameras and accessories for plant security,3. Repairing of one HT spare motor for gas compressor of Phase-II Power House,4. procurement of 132 kV Bus Isolator,5. Procurement of Isolators of Phase-1 switchyard for replacement of the existing old

isolators,6. Procurement of relay of protection systems,7. Up-gradation of the existing damaged Hydrant fire fighting system,8. Procurement of Air Filter for Gas Turbine of Phase-II,9. Procurement of three (3) numbers motor operated steam valves,10. Procurement of one (1) no. new pump motor set for water Intake along with pipes, valves,

cables etc.,11. Procurement of some major spares of WHRP,12. Fire tender with foam and water facility at LTPS .13. Procurement of spares for Gas Compressor & air compre4ssor of Phase-II at LTPS.14. Procurement of one no. 300AH, 120 V Battery bank for GT unit- 1 of LTPS15. Procurement of spares for GT Starting Diesel Engine of unit#1, #3, #5 & #6 .16. Development of existing colony water supply and WHRP supply system,17. Construction of new departmental quarters for employee,18. Repairing of a part of road inside colony,19. Development of the backyard of the new compressor building with PCC and road,20. Repairing of Burge at river Suffry at LTPS.21. Construction of Master Drain at LTPS

R&M of Namrup Thermal Power Station (For FY 2015-16):The R&M scheme has been proposed for the FY 2015-16 at an estimated cost of Rs 3.80 Croreunder the Annual Plan of 2015-16. The scheme comprises of

1. Replacement of existing 11 KV PILC single core copper cable from generator terminal to




11KV Unit Transformer of Gas Turbine Unit- 3 with XLPE cable along with terminaljoints,

2. Replacement of existing BHEL make AVR at GT Unit-3 with microprocessor basedAVR,

3. Replacement of existing Analog AVR for Diesel Generator unit-1 & 2 of Diesel PowerHouse by new microprocessor based digital AVR,

4. Procurement & renovation of cooling tower of Steam Turbine unit-5,5. Procurement & renovation of cooling tower of Steam Turbine unit-6,6. Procurement of 66 kV, 800 A, double break triple pole gang operated rotating centre pole

isolating switch.

R&M of Karbi Langpi Hydro Electric Project (For FY 2015-16):The R&M scheme has been proposed for the financial year 2015-16 at an estimated cost of Rs.7.80 Crore under the Annual Plan of 2015-16. The scheme comprises of

1. Procurement of one no. 220/33 kV, 25.0 MVA Station Reserve Transformer with one setof C.T. (220 kV),

2. Procurement & replacement of Shaft Seal KLHEP Hydro turbine,3. Procurement for renovation of 33 kV 8(Eight) units indoor Control/ Relay panel having 2

nos. incomer & 6 nos. outgoing panel,4. Procurement for renovation of Firefighting (Hydrant) system with Ecofriendly system and

renewed positioning of piping system,5. Repairing of Amtereng Hatidubi Road,6. Boulder pitching at upstream side of right bank and left bank and downstream side of

right bank at Hatidubi Dam including construction of stone masonry drain near HatidubiDam.

7. Slope stabilization works at the Right Bank (downstream side) and protection worksat the top of landslide zone of Dam site at Hatidubi Dam, KLHEP

Status of On-going & New Projects of APGCL as on 30/11/2014

Ongoing Projects

A. Thermal Projects

I. 1x100MW Namrup Replacement Power Project (Ph-I):

Present Status:

After engagement of new Civil agency, M/s Power Mech Projects Ltd., Hyderabad forbalance civil and structural works by BHEL 13-03-14, work has resumed at site and isin progress. MEI sub contractor under M/s NBPPL is to start mobilizing the site veryshortly.

BHEL has been constantly impressed upon to improve progress of civil works. In thisregard, a High level meeting was held on 20-08-14 in New Delhi with the Director(Power), BHEL. CEA also held meeting with BHEL and APGCL on 16-09-14 toreview progress of works of the project.

Expected date of Commissioning of the GT unit is 01/08/2015 based on progress ofwork.

Financial Progress:




a) Total fund received : Rs. 348.0 crore (equity: 208cr & PFCL: 140cr)b) Total fund released to theImplementing Agencies so far

: Rs. 283.83 crore to BHELRs. 45.27 crore to other agencies

c) Funds utilized so far : Rs. 329.10 crore

B. Hydro Projects

I. Myntriang SHP (3x3 MW St-I & 3x1.5 MW St-II = 13.5MW):

Stage II (2 x 1.5 MW) of Myntriang Small Hydro Electric Project was synchronised on 3rd

March, 2014 and Commercial Operation was declared on 08-08-2014.

The overall progress of works in Stage-I (2X3 MW) is 45 %.

The project will be enhanced by another 4.5 MW (1X 1.5 in St-II and 1X 3 in St-I) throughthe existing EPC Contractor increasing the total capacity to 13.5 MW from 9 MW.Additional civil & hydro mechanical works are already being executed through the existingEPC Contractor as per supplementary agreement.

The balance work of St-I along with the enhancement work is expected to be completed byDecember 2015.

STATUS REPORT OF MYNTRIANG SHEP(STAGE I : 2 x 3.00 MW=6MW)

SL No. Description of Item Stage Percentage of progress1 Infrastructure I 95%

2 Concrete weir I 86% (Excavation)28% (Concreting)

3 Power Channel I 82% (Excavation)36% (Concreting)

4 Forebay I 90% (Excavation)60% (Concreting)

5 Cross drainage work I 50%

6 Saddles & anchor I NIL

7 Power House and tail race I 7.5% (P.H Area)

8 Supply of hydro mechanicalequipment

I NIL

9 Supply & Erection of Electromechanical equipment

I 50%

10 Penstock fabrication I 10%

11 Additional Civil and HydroMechanical works as persupplementary agreement forenhancement of power from

I 12.5%




9MW (Stage-I: 2x 3.0MW &Stage-II: 2x1.5MW) to 13.50MW (Stage-I: 3x3.0MW &Stage-II: 3x1.5MW).

II 99%

II. Lungnit SHP (2x3 MW = 6 MW):

After termination of the EPC contract with M/s P. Das & Co. and M/s Jyoti Ltd for slowprogress of work, APGCL initiated necessary action for bidding process for completion ofthe Balance Works of the Project by inviting bids on 04/03/2014 with the date of submissionof tender on 22/04/2014. In response, total 3 (three) nos. of bidders submitted their bids(Technical). Technical evaluation of the bids has been completed and approval of price bid isunder consideration. However, selection of new EPC contractor is getting delayed due tolitigations. The resumption of Project Work at the earliest is under active consideration byAPGCL.

St-II of Lungnit SHEP is expected to be completed within 20 months and St-I is expected tobe completed within 30 months after the construction is resumed by the new EPC contractor.

New Projects

A. Thermal Projects

I. 70 MW Lakwa Replacement Gas IC Engine Project:

The first four units (15MWX4) of Lakwa Thermal power project have, on average, run forover twenty five years till date. Being of simple cycle, the heat rates of these units are twiceas much as that of the modern combined cycle plant. It was decided to replace the first fourunits with a modern plant with better heat rate.

Present Status

1. Investment Approval from Public Investment Board (PIB), GOA obtained. AIFA Inprinciple sanctioned equity amount of Rs. 79.2 Crores. for equity support.

2. EIA clearance of 70MW LRPP from MOE&F obtained Vide letter no J13012/21/2012.IA.II (T) dated 14/10/2013.

3. DPR placed before AERC for approval. AERC in principle approved the DPR on30/03/2013.

4. For Power Purchased Agreement (PPA) proposal placed before APDCL

5. Aviation Clearance obtained from AAI vide Letter no NER/ATM/2014/ 49E.0000-NOCS-RCER 2604-06 dated 10/06/2014.

6. APGCL incorporated LRPP under Assam power sector enhancement investmentproject-II of Asian Development Bank (ADB) for arranging fund (Term Loan).




7. Bid documents for Selection of EPC contractor Prepared in consultation with ADB’sConsultant and “Invitation for Bids (IFB)” sent to ADB on 31/12/2013 for publicationin the ADB business opportunities Websites as advance procurement action. ADBpublished the IFB on their business opportunities Websites on 23/01/2014. APGCLuploaded the IFB and the BID Documents at website www.apgcl.org on 24/01/14 andpublished the IFB in local News Paper and National News paper on 25.01.2014. It isto be mentioned that the last date was extended twice for insufficient participation.Last date of submission of bid documents and opening of bid documents was on 16th

May, 2014.

8. The technical bid was opened on 16-05-14. Only one party “Consortium of WartsilaIndia Ltd and Wartsila Finland OY” participated. Price bid will be opened afterevaluation of the Technical Bid.

9. The bid evaluation report was placed before TPC meeting 14-07-14. The TPC videres. no 1 dtd 14-07-14 approved the bid evaluation report and sending evaluationreport to ADB for approval through the Director , PMU, APDCL is under process.

10. Technical Bid evaluation report sent to ADB through The Director, PMU vide Emaildated 02/08/2014. ADB sought some clarifications on Technical Bid evolution report,APGCL’s replies to the clarifications on Technical bid evaluation report send to ADBthrough The Director PMU vide Email dated 04/09/2014.

11. ADB Letter dt 16.10.14 from Mr.Yongping Zhai, Director, Energy Division, SouthAsia, Asian Development Bank, Manila, addressed to Director, PMU asked APGCLto go for Rebidding with Approval of Fresh Bid Documents from ADB. Preparationof Fresh Bid Documents is under Process in consultation with ADB.

II. 660 MW Margherita Coal Based Power Project:

Assam Power Generation Corporation Ltd proposes to set up a Coal Based Power Project atvillage Saliki NC under Makum Mauza of Margherita Sub-Division, Margherita, DistrictTinsukia, Assam. The Project site is situated in the vicinity of coal mines of North EasternCoal Fields of Coal India Ltd and considered it as a pit head project.Present Status

Project capacity has been increased to 660 MW from earlier 500 MW.

Water drawl permission @3300 cum per hour for 660 MW obtained from the WaterResources Dept., GOA vide letter No. WR (ED) Tech/5110/05/140 dated 20/09/2014.

The project is proposed to be implemented through JV with NEEPCO. DraftMemorandum of Understanding has already been approved by APGCL Board ofDirectors. Approval by NEEPCO Board of Directors is awaited.

Amended Terms of Reference (TOR) was granted for 1X660 MW project in themeeting with MOEF on 30/10/14. However, the MOM of 30/10/14 is not yetuploaded in the MOEF website.

Consultancy has been awarded for the preparation of DPR for Supercritical 1X660MW configuration to M/s Fichtner India, Chennai and work is in progress.




III. 42 MW Distributed IC Engine for Generation from Gas of OIL/ ONGCL atdifferent locations of Golaghat & Silchar area:

The pre-feasibility report (PFR) for Golaghat Project has been prepared. Allotment of Gasallocation is awaited. Meanwhile, ONGCL floated open NIT for gas fields at Golaghat.APGCL participated in the bidding process with deviation clauses as per the approval by theAPGCL Board. Tender opening date was 25.10.12. APGCL submitted its bid for two gasfields of Golaghat district with deviations from terms and conditions laid down by ONGC.ONGC requested APGCL to withdraw the deviations, which it was unable to do so for thesake of project viability. After which ONGCL cancelled the Tender. There has been nofurther progress on the matter since then.

Meanwhile, APGCL wrote to the Chairman and Managing Director, ONGC and to theSecretary to Govt. of India, Ministry of Petroleum and Natural gas for additional gas videletter No. MD / APGCL /PS / Misc / 2014 / 17 dated 25th July 2014 and MD /APGCL /PS/Misc /2014/30 dated 12th Sept, 2014 respectively to allocate 0.15 MMSCMD of gasavailable at ONGC gas fields near Golaghat District to APGCL.

Because of non-establishment of gas linkage till now, the implementation of theGolaghat Power Project has been differed indefinitely.

ONGCL retendered for its Bhubandar and Banskadi Gas fields in December’13 in a two bidsystem. APGCL took part in the bidding which was closed on 05/05/14. Technical bids wereopened on the same day and APGCL was the sole bidder for Bhubandar gas field and inBanskandi Gas field other than APGCL only AGCL took part in the bidding. Price Bid forBhubandar Gas Field was opened on 07/10/14 and that for Banskandi Field was opened on07/11/14. APGCL is awaiting further correspondence from ONGC.

Implementation of Cachar Power Project is strictly dependent on the successful biddingof the Gas by APGCL from ONGCL.

IV. 60 MW Revival of Chandrapur TPS on coal under JV mode:

Regarding revival of CTPS on coal as alternative fuel through PPP, APGCL, land measuringapprox. 67 acres and 6 cusec of water are to be transferred to JV Company i.e. M/s. IAPL onlease as per the joint venture agreement dtd. 02.02.2010.

Present Status:

1. M/s IAPL applied to Ministry of Coal for sanction of 0.2 Million Tonnes Coallinkage.

2. APGCL Board (resolution No. 4 dtd. 31/03/12) approved transfer of 67 acres of landalong with existing water rights to the JV Company M/s IAPL.

3. The draft Lease Deed Agreement for transfer of Land & Buildings of CTPS hasalready been finalized with the consent of M/s IAPL and APGCL Board approvedthe same.

4. Fuel Supply Agreement (FSA) between M/s World Trade Raw Materials Inc, USA(having selling rights of coal from Indonesia) and M/s IAPL to import coal fromIndonesia has been signed on 8th July'13. Coal from Indonesia will be used till coallinkage from GOI is obtained.

5. MOU has been signed between M/s IAPL and APDCL on 21 st August’2013 for




sale of power.6. In pursuance of Board’s resolution dtd. 14/08/13, process has been initiated for

disposal of the boiler and auxiliaries of CTPS.7. Ministry of Environment & Forest, GOI has transferred the CTPS revival

proposal to State Level Environment Impact Assessment Authority (SEIAA),GOA as the revival of CTPS project is a Category-B project and State LevelEnvironment Impact Assessment Authority, Assam has now been constituted.

8. APGCL/ Commissioner & Secretary, Power, GOA requested State LevelEnvironment Impact Assessment Authority (SEIAA), GOA for issue ofnecessary Environmental & Forest Clearance to the JV Company forimplementation of the project without further delay. Environmental & ForestClearance is likely to be received soon.

9. Process has been initiated to remove existing Boiler & Auxiliaries of 2x30 MW CTPSunits to make room for new Boilers to be installed by M/s Imperial APGCL PowerLimited. The award of contract for Disposal of Boiler & Auxiliaries of 2x30 MWCTPS units has been awarded to Yashaswi Ispat Pvt. Ltd., Guwahati-8. Lifting ofscrap materials by the firm is under progress.

B. Solar PV Projects:

The Government of India had launched Jawaharlal Nehru National Solar Mission(JNNSM) topromote ecologically sustainable growth while addressing India’s energy security challengeand focus on setting up an enabling environment for solar technology penetration in thecountry.

Under this Mission; Ministry of New and Renewable Energy (MNRE) is providing subsidyfor promoting off-grid systems and Decentralised Solar Application scheme:”OperationalGuidelines for Grid Connected roof top and small solar Power plant program”.

APGCL intends to set up Solar Power Projects at NTPS, LTPS and Amguri and DPRpreparation for the projects are under process. The proposed installed capacity for solarpower projects are as follows:

1. Namrup Solar PV Power Project- 2 MW (nominal)2. Lakwa Solar PV Power Project- 2 MW (nominal)3. Amguri Solar PV Power Project- 60 MW (nominal).

C. Hydro Projects

I. 120 MW Lower Kopili HEP:

1. Revised DPR was submitted to CEA after compliance of observations for Techno-Economic Clearance in March 2013. After examining the DPR, statutory authoritiese.g., Central Electricity Authority (CEA), Central Water Commission (CWC),Geological Survey of India (GSI), Central Soil & Materials Research Station(CSMRS) raised certain observations regarding incorporation of some information inthe DPR and advised for some additional Geo-Technical explorations, which arebeing done by APGCL and expected to be completed by Dec’14.

2. Environment Impact Assessment (EIA) studies are being carried out by Water andPower Consultancy Services (WAPCOS) as consultant. Terms of Reference (TOR)




for EIA have been received. Additional studies as stipulated in the TOR are going on.Draft EIA report is targeted for completion by June’15.

3. As suggested by the Forest Deptt, GOA, the revised forest clearance application hasbeen uploaded in the website of MOEF.

4. Hydrology, Power potential for (2X55+1X5+2X2.5)=120 MW, Power Evacuationarrangement, Instrumentation aspects, Geology aspects have been approved by theconcerned Directorates of CWC/CEA and GSI. Clearances received from Ministry ofHome Affairs (MOHA), Ministry of Defense (MOD).

5. Proposal for site specific seismic coefficients has been placed to FESA Directorate ofCWC for approval of the coefficients by National Committee on Seismic DesignParameter.

II. 21 MW Karbi Langpi Intermediate Stage-I, 24 MW Karbi Langpi IntermediateStage-II HEP & 12 MW Karbi Langpi Barrage Toe H.E. Projects :

DPR is being prepared through M/s. Lahmeyer International India (LII) for(i) Karbi Langpi Intermediate stage-I (21MW),(ii) Karbi Langpi Intermediate stage-II (24MW) and(iii) Karbi Langpi Barrage Toe H.E Project (12MW).

Draft DPR for Karbi Langpi Intermediate St-II has been submitted by LII which is underscrutiny by APGCL.

III. Projects Under Investigation:

APGCL is doing survey and investigation at the following locations:1) Sunani (Karbi Anglong)2) Maine (Karbi Anglong)3) Silbheta (Karbi Anglong)4) Bonda (Kamrup)5) Killing (Karbi Anglong)




Directive issued in Tariff Order for FY 14-15, reply to be furnished along with tariffPetition for FY 15-16 & APR for FY 14-15

1. Justification of under generation of Lakwa WHRU leading to higher Gross Station HeatRate of LTPS (Combined Cycle)

APGCL collected the details justification regarding under generation of WHRU from LTPSwhich has been stated below:

The WHRP was commissioned on 17th January'12 with its 3 (three) HRSG in operation. Inthe initial period of STG operation, the sustainable load achieved was around 35-36 MW butthe load started to decrease since May'12 end. On 8th October'12, the performance guarantee(PG) test was performed by BHEL. During performance guarantee test, the actual loadachieved was 33.52 MW (after voltage & PF correction) which was submitted by BHEL asper their report number PEMC¬03692. The STG power output after GT exhaust flow andtemperature correction was 35.2 MW. The correction factor of condenser was not acceptedby APGCL.

Considering the above PG test report and as per actual sustainable generation achieved duringone year from commissioning, the most possible STG generation may be taken as 33.5 MW.It is expected that the present low output of 30.0 MW can be resolved by BHEL afterimproving the condenser low vacuum problem. The STG generation has reduced to average30.0 MW gradually due to drop of condenser vacuum. BHEL technical team has alreadyvisited twice to LTPS to study particularly on the low generation caused by the drop ofcondenser vacuum. In view of the above, the decreasing trend of generation of WHRP asraised by AERC can be improved to the extent of PG test performance of 33.5 MW and notto that of the design output of 37.2 MW which includes the GT exhaust correction factor. Asper contractual agreement, BHEL is to prove the design output as per approved PG testprocedure which is still to be achieved.

Comments: The design annual generation of WHRU as per approved DPR is 223 MU.Considering the current performance of WHRU @ 30 MW for the above stated constrain, theoutput has been reduced to 180 MU, which is at per with the actual generation of WHRU forFY 12-13, 13-14 and FY 2014-15 (up to Nov’14). However, it is expected to improve outputof WHRU to the extent of 33.5 MW i.e. annual generation up to 200 MU after taking abovecorrective measures as recommended by BHEL. In this connection this may be mentionedhere that as the auxiliary equipment’s consumption remain the same, the reduced output ofthe WHRU also attributed to higher APC LTPS (Combined Cycle). Further, for abovereasons the lower output of the WHRU, the Gross Station Heat Rate (GSHR) of LTPS(Combined Cycle) is also increases as commented by the Hon’ble Commission in the TariffOrder for FY 2014-15.

2. Furnishing of DPR for Renovation & Modernisation for NTPS. LTPS & KLHEP alongwith APR for FY 15-16

DPR for NTPS, LTPS & KLHEP for proposed Renovation & Modernisation Worksfurnished Vide Letter No: APGCL/CGM(G)/AERC/2013-14/115/Pt-IX/33dtd 20/12/2014




Annexure I

9. Statements of proposed Monthly Generation, Fuel Prices&Cost of Fuel for FY 2015-16.



Proposed Monthly Generation for FY 2015-16

STATION Apr-15 May-15 Jun-15 Jul-15 Aug-15 Sep-15 Oct-15 Nov-15 Dec-15 Jan-16 Feb-16 Mar-16 TotalFuel Cost(Rs. In Cr.)

Namrup TPS 119.5 MW from Apr'15 to Dec'15

Gross Gen. (MU) 44.16 45.63 43.91 45.48 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 179.17

67.45APC @5.5% 2.42 2.50 2.40 2.49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9.81

Net Gen. (MU) 41.74 43.13 41.50 42.99 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 169.36

Namrup TPS 63.5 MW with Unit 1, 2 & 6 from Jan'16 to Mar'16 after commissioning of NRPP

Gross Gen. (MU) 0.00 0.00 0.00 0.00 17.37 16.80 21.96 21.25 21.96 21.96 20.54 21.96 163.81

59.80APC @5.5%

0.00 0.00 0.00 0.00 0.96 0.92 1.21 1.17 1.21 1.21 1.13 1.21 9.01

Net Gen. (MU) 0.00 0.00 0.00 0.00 16.41 15.88 20.75 20.08 20.75 20.75 19.41 20.75 154.80

Total of Namrup TPS for 2015-16

Gross Gen. (MU) 44.16 45.63 43.91 45.48 17.37 16.80 21.96 21.25 21.96 21.96 20.54 21.96 342.98

127.25APC @5.5%

2.42 2.50 2.40 2.49 0.96 0.92 1.21 1.17 1.21 1.21 1.13 1.21 18.82

Net Gen. (MU) 41.74 43.13 41.50 42.99 16.41 15.88 20.75 20.08 20.75 20.75 19.41 20.75 324.16

NRPP 63 MW GT

Gross Gen. (MU) 0.00 0.00 0.00 0.00 37.50 36.29 37.50 36.29 37.50 37.50 35.08 37.50 295.14

75.41APC @4.6% 0.00 0.00 0.00 0.00 1.72 1.67 1.72 1.67 1.72 1.72 1.61 1.72 13.58

Net Gen. (MU) 0.00 0.00 0.00 0.00 35.77 34.62 35.77 34.62 35.77 35.77 33.46 35.77 281.57

157.2 MW Lakwa TPS

LTPS GT Gross Gen.(MU)

53.66 55.45 53.66 55.45 55.45 53.66 55.45 60.62 62.64 62.64 58.59 62.64 689.87

319.26

LTPS GT APC @7.0%(MU)

3.76 3.88 3.76 3.88 3.88 3.76 3.88 4.24 4.38 4.38 4.10 4.38 48.29

WHRU Gross Gen. (MU) 14.94 13.64 10.79 15.43 15.43 14.94 13.77 13.44 15.10 13.77 14.44 15.43 171.12

WHRU APC @9.4% (MU) 1.40 1.28 1.01 1.45 1.45 1.40 1.29 1.26 1.42 1.29 1.36 1.45 16.09

LTPS Gross Gen. (MU)with WHRU

68.59 69.09 64.44 70.88 70.88 68.59 69.22 74.06 77.74 76.41 73.03 78.07 861.00

Total APC @7.5%with WHRU

5.16 5.16 4.77 5.33 5.33 5.16 5.18 5.51 5.80 5.68 5.46 5.84 64.38



LTPS Net Gen. (MU) withWHRU

63.43 63.92 59.67 65.55 65.55 63.43 64.04 68.55 71.93 70.73 67.57 72.23 796.62

100 MW Karbi Langpi HEP

Gross Gen. (MU) 9.00 19.00 45.00 68.00 74.00 72.00 45.00 21.00 15.00 11.00 5.00 6.00 390.00

0.00APC @ 0.5 % 0.05 0.10 0.23 0.34 0.37 0.36 0.23 0.11 0.08 0.06 0.03 0.03 1.95

Net Gen. (MU) 8.96 18.91 44.78 67.66 73.63 71.64 44.78 20.90 14.93 10.95 4.98 5.97 388.05

Myntriang Small HEP - Stage II (3 MW + 1.5 MW Enhancement from December'15)

Gross Gen. (MU) 1.59 1.94 1.94 1.94 1.94 1.94 1.94 1.94 2.22 2.12 1.68 1.46 22.68

0.00APC @ 1% 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.01 0.23

Net Gen. (MU) 1.58 1.92 1.92 1.92 1.92 1.92 1.92 1.92 2.20 2.10 1.66 1.44 22.45

Myntriang Small HEP - Stage I (6 MW + 3 MW Enhancement - both from December'15)

Gross Gen. (MU) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.46 5.43 4.29 3.73 18.91

0.00APC @ 1% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.05 0.05 0.04 0.04 0.19

Net Gen. (MU) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.40 5.38 4.25 3.69 18.72

APGCL

Gross Gen. (MU) 123.34 135.66 155.29 186.31 201.69 195.63 175.62 154.54 159.87 154.42 139.62 148.71 1930.71

521.92APC @5.1% 7.64 7.78 7.42 8.18 8.40 8.13 8.35 8.47 8.89 8.74 8.29 8.85 99.14

Net Gen. (MU) 115.70 127.88 147.88 178.12 193.28 187.50 167.27 146.07 150.99 145.68 131.33 139.87 1831.57

Note: Earlier NRPP GT was expected to be commissioned by March'15 and the WHRU by September'15 as per BHEL's target date. However, based on the presentwork in progress, the GT unit is now expected to be commissioned in Aug'15 and the Waste Heat Recovery Unit in April'16.




Projected Gas Price for NTPS/ LTPS 2015-16 Remarks

Namrup Thermal Power Station

A. Gas supplied by OIL, Duliajan (APM)

1.00 Basic Price (for G.C.V. 10000)/ 1000 SCM 7399.45

As per new gas priceimplemented from Nov'2014

2.00 Basic Price after adjustment (for G.C.V. 9300 Average) 6881.33

3.00 Marketing Margin (for NCV 10000) /1000 SCM 200.00

4.00 Marketing Margin after adjustment (for N.C.V. 8378/1000 SCM) 167.56

Total 7048.90

5.00 VAT @ 12 % on above 845.87

Total (A) 7894.77

B. T.C. for Transportation of the OIL Gas by AGCL

1.00 T.C./ 1000 SCM 417.69 Yearly escalation 3% onTC as per agreement.2.00 Fuel surcharge/ 1000 SCM 31.76

Total 449.45

3.00 Service Tax @ 12.36% on TC 51.63

Total (B) 501.08

Landed price of gas supplied to NTPS (A+B)/ 1000SCM

8395.84

Lakwa Thermal Power Station

A. Gas supply by GAIL (APM)



2.00 10% Royalty /1000 SCM Included

Total 7399.45

3.00Basic Price after adjustment (for G.C.V. 9793 Average)/1000 SCM

7246.48



6.00 VAT @ 12 % on above 890.75

Total (A) 8313.69

B. Fixed Monthly Service charge(Rs./ 1000 SCM) 20.66

Landed price of gas supply to LTPS by GAIL (A+B)/1000 SCM

8334.35

C. Gas supplied by OIL Duliajan (Non APM)



2.00 Basic Price after adjustment (for GCV 9300 /1000 SCM) 11468.89



Total 11636.45

5.00 VAT @ 12 % on above 1396.37

Total (C) 13032.83




D. T.C for Transportation of OIL gas by AGCL

T.C./ 1000 SCM 651.14 Yearly escalation 3% onTC as per agreement.Service Tax @ 12.36% on TC 80.48

Total 731.62

Landed price of gas supply to LTPS by OIL (C+D)/1000 SCM

13764.45

APGCL’s Projected Fuel cost for FY 2015-16Cost of Fuel (NTPS) 2015-16

All units of Namrup TPS (From Apr'15Jul'15)

Generation by APM Gas

Gross Generation by APM Gas (MU) 179.17

Net Generation by APM Gas (MU) 169.36

Gross Heat Rate on GCV basis Kcal/Kwh 4170.00Rate of Gas (for GCV 9300 Kcal/CUM) Rs./1000 CUM 7894.77

Cost of APM Gas (NTPS) in Rs. 634276028.77

Average Gross Calorific of Gas Kcal/CUM 9300Gas Quantity MMSCM 80.34

Transportation Charge of Gas

TC Rate of Gas Rs. /1000 CUM 501.08

Total TC in Rs. 40257155.64

Total cost of Fuel including TC 674533184.41

Say Rs. In Cr. 67.45 Cr.

Namrup TPS with Units 1, 2 & 6 after Commissioning of NRPPGT (From Aug'15-Mar'16)


Gross Generation by APM Gas (MU) 163.81

Net Generation by APM Gas (MU) 154.80

Gross Heat Rate on GCV basis Kcal/Kwh 4044Rate of Gas (for GCV 9300 Kcal/CUM) Rs./1000 CUM 7894.77

Cost of APM Gas (NTPS) in Rs. 562311019.38

Average Gross Calorific of Gas Kcal/CUM 9300Gas Quantity MMSCM 71.23





Say Rs. In Cr. 59.80 Cr.

Total Cost of Gas 127.25 Cr.

Total Gross NTPS Generation in 2015-16 (MU) 342.98

Total Net NTPS Generation in 2015-16 (MU) 324.16

Average Fuel Cost Rs./Kwh 3.71

Average Fuel Cost Rs./Kwh Sentout 3.93

NRPP (63 MW GT from Jan'16)





Gross GT Generation by APM Gas (MU) 295.14

Net GT Generation by APM Gas (MU) 281.57

Gross GT Heat Rate on GCV basis Kcal/Kwh 2830Rate of Gas (for GCV 9300 Kcal/CUM) Rs./1000 CUM 7894.77

Cost of APM Gas (NRPP) in Rs. 709062012.33

Average Gross Calorific of Gas Kcal/CUM 9299.79Gas Quantity MMSCM 89.81





Say Rs. In Cr. 75.41

NRPP Fuel Cost Rs./Kwh 2.55

NRPP Fuel Cost Rs./Kwh Sentout 2.68

Cost of Fuel (LTPS) 2015-16

LTPS Fuel Cost Rs./Kwh

Lakwa TPS with Waste Heat Unit

Gross GT Generation by GAIL Gas (MU) 357.54

Net GT Generation by GAIL Gas (MU) 332.51

Gross GT Heat Rate on GCV basis Kcal/Kwh 4010.00

Average GCV of GAIL Gas Kcal/CUM 9793

GAIL Gas Quantity MMSCM 146.40Rate of Gas of GAIL Rs./1000 CUM 8313.69Rate of GAIL Service Charge of transportatrion of Gas Rs./1000CUM 20.66Total Rate of Gas of GAIL Rs./1000 CUM 8334.35

Cost of APM Gas (GAIL) in Rs. (A) 1220148728.01

(B) Generation by Non-APM Gas from OIL

Gross GT Generation by OIL Gas (MU) 332.33

Net GT Generation by OIL Gas (MU) 309.07

Gross GT Heat Rate on GCV basis Kcal/Kwh 4010.00

Average GCV of OIL Gas Kcal/CUM 9300

OIL Gas Quantity MMSCM 143.30Rate of Gas of OIL Rs./1000 CUM 13032.83

Cost of Non-APM Gas (OIL) in Rs. 1867604279.30

TC Rate of Gas of OIL Rs. /1000 CUM 731.62

Total TC in Rs. 104841013.18

Total Fuel Cost for OIL Gas (B) 1972445292.49

Total Fuel Cost of LTPS (A) + (B) 3192594020.50

Say Rs. In Cr. 319.26

Waste Heat Unit 8 Gross Generation (MU) 171.12

Waste Heat Unit 8 Net Generation (MU) 155.04

Total Gross Generation LTPS (MU) 861.00Total Net Generation LTPS (MU) 796.62Average LTPS Fuel Cost Rs./Kwh 3.71Average LTPS Fuel Cost Rs./Kwh Sentout 4.01




Annexure II

10. Abstract of Technical Data for FY 2015-16



Name of the Power StationCapacity

(MW)

Availability

Factor (%)PLF%

Gas

Source

Gross

(MU)%APC APC(MU) Net (MU)

GCVof

Gas Kcal/

SCM

Gas

Availability

(mscmd)

Total Gas

Cons.

(mscm)

Sp. Gas

(SCM/

Kwh)

StationHeat

Rate onGCV

Basis

(Kcal/ Kwh)

Fuel cost (Rs.) TC(Rs.)Total Fuel cost

(Rs.)

Cost of

fuel

(Rs./

Kwh)

Cost of

fuel

(Sent out)

(Rs./ Kwh)

Namrup TPS

(From Apr'15 to Jul'15) 119.50 54.2% 51.2%OIL

APM179.17 5.5% 9.81 169.36 9300 0.66 80.34 0.4484 4170 634276029 40257156 674533184 3.76 3.98

Namrup TPS (U1, 2 &6)

(From Aug'15 to Mar'16) 63.50 46.6% 44.1%OIL

APM163.81 5.5% 9.01 154.80 9300 0.29 71.23 0.4348 4044 562311019 35689576 598000595 3.65 3.86

NTPS Total 105.50 50.6% 47.8% 342.98 5.5% 18.82 324.16 9300 0.57 151.57 0.4419 4110 1196587048 75946731 1272533779 3.71 3.93

NRPP 63 MWGT (From Aug'15 to

Mar'16)63.00 83.9% 80.0%

OIL

APM295.14 4.60% 13.58 281.57 9300 0.37 89.81 0.3043 2830 709062012 45003781 754065794 2.55 2.68

Lakwa WHRP 37.20 57.8% 52.4% 171.12 9.40% 16.09 155.04

GAIL

APM357.54 9793 0.40 146.40 0.4095 4010 1220148728 0 1220148728

OIL

Non-332.33 9300 0.39 143.30 0.4312 4010 1867604279 104841013 1972445292

Total LTPS with WHRP 157.20 67.9% 62.8% 861.00 7.48% 64.38 796.62 9549 0.79 289.70 0.3365 3213 3087753007 104841013 3192594020

Karbi Langpi HEP 100.00 90% 44.5% N/A 390.00 0.50% 1.95 388.05

Myntriang SHEP

Stage-II4.50 91% 80.9% N/A 22.68 1.00% 0.23 22.45

Myntriang SHEP

Stage-I 9.00 91% 80.7% N/A 18.91 1.00% 0.19 18.72

Total APGCL 397.20 72.3% 59.5% 1930.71 5.13% 99.14 1831.57 9436 2.11 531.08 0.4105 3873 4993402068 225791526 5219193594 2.70 2.85

120.00 70.4% 65.4% 48.29

Abstract of TechnicalDataPertainingtoAPGCL(2015-16)

3.71 4.01Lakwa TPS (GT) 7.00% 641.58




Annex-III

11. Various data as per Specified formats of Hon’ble Commission.

List of formats for which data has/ has not been furnished in this Petition

Formats for which datahave been submitted

F-1,F-2,F-3, F-5, F-6, F-7, F-11, F-12, F-14, F-15, F-16, F-17

Formats which are found not to berelevant

F-4, F-8, F-9, F-10, F-13




FORM-1

SUMMARY SHEET

Name of the Company Assam Power Generation Corporation Limited

Name of the Power Station

State District

Assam

Tariff Period From 01-04-2013 To 31-03-2016

2013-14 2014-15 2015-16

S.No. Particulars

(1) (2) (3) (4) (5)1. Calculation of FixedCharges (Rs. Crs)

1.10 Depreciation [FROM-11 ] 21.95 23.27 39.88

1.20 Interest on Loan [FROM-12 ] 31.22 29.21 58.41

1.30 Return on Equity 39.38 41.10 58.66

1.40 Taxes on income 0.45 0.93 0.93

1.50 Interest on Working Capital [FROM-14 ] 22.23 25.39 30.62

1.60 O & M Expenses [FROM-15 ] 120.56 121.14 168.67

1.70 Other Finance Charges 0.05 5.81 6.43

1.80 Less other Income -10.60 -10.60 -10.60

1.90 Prior Period Items -10.07

1.91R&M Expenses approved vide letter No. AERC442/2014/15 "Order on Review Petition on TariffOrder for FY 13-14" dated 08.07.2014

26.73

Total 215.18 236.26 379.73

2. Calculation of Rate of Energy Charge(Rs./kWh)1

DuringStabilization

AfterStabilizati

on

2.10 Rate of Energy Charge from Primary Fuel (REC)p2

2.22 2.68 2.85

2.20 Rate of Energy Charge from Secondary Fuel (REC) 0.00 0.00 0.00

2.30 Rate of Energy Charge ex-bus (REC)3A,3B,3C

2.22 2.68 2.85

### Details of calculations to be furnished. If accounts of the company formore than one year i.e previous year, have not been audited, informationas per this format may be furnished for such year(s) separately.

### If multi-fuel is used simultaneously; five 2.1 is respect of every fuelindividually.

3A The rate of energy charge shall be computed for open cycle operationand combined cycle operation separately in case of gas/liquid fuel firedplants

3B The total energy charge shall be worked out based on ex-bus energyschedule to be sent out in case of plants covered by ABT, and ex-busenergy delivered sent out in case of plants not covered by ABT, as thecase may be.

3C Any escalation in fuel cost to be considered for subsequent years or FPAto take care of the escalation.

PETITIONER




FORM-2

Plant Characteristics

Name of the Company Assam Power Generation Corporation Ltd

Name of the Pow er Station Namrup Thermal Power Station

Basic characteristics of the plant 1 (I) 4 Gas Turbines

(II) 1 Gas Fired Steam Turbine

(III)1 Waste Heat Recovery Unit

Fuel type 2 Natural Gas

Details

Rated Capacity (MW)

Date of synchronization

Capacity at the date of synchronization

Date of entry into commercial operation

Date of stabilisation

Capacity at the date of stabilisation

Derated Capacity (MW)

Has any performance test been performed

If yes,capacity at test

Type of cooling systen for condenser 3

Type of Boiler Feed pump4

Type of cooling system for electric generator 5

Any other special feature6

If yes, furnish full details

PETITIONER

24 22.520 21 21 11

4 Motor driven, Steam turbine deriven etc.5 Air cooled, w ater cooled, hydrogen cooled etc.6 Any special feature such as merry-go-round, scrubbers etc.Specify all such features.

Has the station received any notice or shut dow n the pow er station of penalty

imposed for violation of any environmental standard by the Central/State Statutory

Authorities

1 Describe the basic characteristics of the plant e.g. in the case of a coal based plant w hether it is a

conventional steam generator or circulating fluidized bed combustion generator or sub-critical once through

steam generator etc.2 Coal or natural gas or naphta or lignite etc.3 Closed circuit cooling, once through cooling,sea cooling etc.

No

Unit 1

Module number of Unit number

Unit 6Unit 5Unit 4Unit 3Unit 2

3023 23 12.5 22.5

Apr - 65 Apr - 65 Apr - 65 Sep - 75 Apr - 76 Mar - 85

23

23 23 23 12.5

Apr - 65 Apr - 65 Apr - 65 Sep - 75

Apr - 76 Apr - 90

24 15

3011.25

(Single Boiler)

Apr - 76 Apr - 90

23 12.5

Apr - 65 Sep - 75Apr - 65 Apr - 65

23 23

NOT APPLICABLE

No NoNo No No No

- - - -

- -- -

BF-20

WEIR

Water

BF-20 WEIR

Make

Could

not be

loaded

upto

rated

Could not be

loaded upto

rated capacity

Air Air

Water

Hydrogen Air

- -- -

HydrogenHydrogen




FORM-3

Normative Parameters

Name of the Company : Assam Power Generation Corp. Ltd.

Name of the Power Station : Namrup Thermal Power Station

ParticularsFY 2012-13 Last Audited

Year2013-14

Current Year2014-15

Ensuing Year2015-16

Target Availability (Gross Generation inMU)

533.17 526.58 600.14 342.98

Target Availability (%) 54% 54% 61% 51%

Normative PLF (%) 51% 50% 57% 48%

Auxilary consumption(%) 5.6% 6.0% 5.7% 5.5%

Gross Station Heat Rate on GCVk.Cal/kWh

4093 3976 4145 4562

Hours of operation at Target Availability 4773 4730 5344 4429

Hours of operation at Target PLF 4459 4362 4993 4186

Sp. Gas consumption (SCM/kWh) 0.4458 0.4290 0.4325 0.4419

O& M Charges (% of CC for plants lessthan 5 years old)

(Based on actuals for plants more than 5years

Coal stock expense in months for workingcapital (WC)

Oil stock in months for WC

Spares stock for WC as % of O&M

Receivables in Months for WC

Rate of Return on Equity (%)

PETITIONER






Name of the Power Station Lakwa Thermal Power Station

Basic characteristics of the plant 1 Gas Turbine

Fuel type 2 Natural Gas

Details

Rated Capacity (MW)








Type of cooling systen for condenser 3


Type of cooling system for electric generator



PETITIONER

Scrubbers

Yes

15 15

- -

- -

20

26-07-94

20

-

Scrubbers

Yes Yes

15 15

Scrubbers

- -

AirAir Air Air Air Air Air

Scrubbers

Kirloskar (325 KW,

53 CUM/Hr)/Sulzer

(9.5 KW, 13.5

CUM/Hr)

- Water

Scrubbers Scrubbers

- -

-

-

15

05-08-81 01-12-86 29-07-94

15 2020

06-01-94

Yes Yes

20 20 -

YesYes

03-01-94 17-01-1226-07-94

33

17.01.1202-08-83 29-04-81

15 15

30-07-83 26-04-81 02-08-81 28-11-86

15 15 15 1511

(w ith 1 HRSG)

37.2

30-07-83 26-04-81 02-08-81 28-11-86 03-01-94 17.08.11

15

20

Unit 8Unit 5Unit 4Unit 3Unit 2

2015 15 15

Unit 6

FORM-2

4 Motor driven, Steam turbine deriven etc.5 Air cooled, w ater cooled, hydrogen cooled etc.6 Any special feature such as merry-go-round, scrubbers etc.Specify all such features.

Has the station received any notice or shut dow n the pow er station of penalty

imposed for violation of any environmental standard by the Central/State Statutory

Authorities

1 Describe the basic characteristics of the plant e.g. in the case of a coal based plant w hether it is a conventional steam generator or

circulating fluidized bed combustion generator or sub-critical once through steam generator etc.2 Coal or natural gas or naphta or lignite etc.3 Closed circuit cooling, once through cooling,sea cooling etc.

Unit 1


Unit 7

20

24-05-99

20

24-05-99

No

Air

Scrubbers

27-05-99

20

Yes

20

-

-




FORM-3



Name of the Power Station : Lakwa Thermal Power Station with WHRU

Particulars

FY 2012-13

LastAudited

Year2013-14

CurrentYear

2014-15

Ensuing Year2015-16


888.00 896.15 897.36 861.00


Normative PLF (%) 64% 65% 65% 63%



3066 3164 3084 3213



Sp. Gas consumption (SCM/kWh) 0.3219 0.3303 0.3117 0.3365

O& M Charges (% of CC for plants lessthan 5 years old)(Based on actuals for plants more than 5years

Coal stock expense in months for workingcapital (WC)

Oil stock in months for WC




PETITIONER






Name of the Power Station Karbi Langpi HEP

Basic characteristics of the plant1 (I) 2 WaterTurbines

Fuel type2 NIL

Details

Rated Capacity (MW)








Type of cooling systen for condenser3


Type of cooling system for electric generator5



PETITIONER

6 Any special feature such as merry-go-round, scrubbers etc.Specify all such features.

Has the station received any notice or shut down the power station of penalty imposed for

violation of any environmental standard by the Central/State Statutory Authorities

1 Describe the basic characteristics of the plant e.g. in the case of a coal based plant whether

it is a conventional steam generator or circulating fluidized bed combustion generator or sub-2 Coal or natural gas or naphta or lignite etc.3 Closed circuit cooling, once through cooling,sea cooling etc.4 Motor driven, Steam turbine deriven etc.5 Air cooled, water cooled, hydrogen cooled etc.

Unit 1


Unit 2

50

31-01-07 20-03-07

50

50 50

06-04-07 06-04-07

Not applicable Not applicable

06-04-07 06-04-07

50 50

50 50

Yes

FORM-2

- -

Not applicable Not applicable

Air Air

Yes




FORM-3



Name of the Power Station : Karbi Langpi HEP

Particulars

FY 2012-13

LastAudited

Year2013-14

Current Year2014-15

EnsuingYear

2015-16


344.02 422.51 341.38 390.00


Normative PLF (%) 39% 48% 39% 45%



N/A N/A N/A N/A



Sp. Gas consumption (SCM/kWh)

O& M Charges (% of CC for plants lessthan 5 years old)

(Based on actuals for plants more than 5years

Coal stock expense in months for workingcapital (WC)Oil stock in months for WC




PETITIONER




FORM-5

Statement of Project Cost Upto (COD)

Name of the CompanyAssam Power Generation CorporationLimited

Name of the Power Station Lower Kopili HEP

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3As per

OriginalApproved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)

1.0Cost of Land, Works,

Plant &Equipment, service

1.1Land & PreliminaryInvestigation

1.2 Site Development

1.3 Steam Generator Island

1.4 Tribune Generator Island

1.5 BOP Mechanical

1.6 BOP Electrical & C & I

1.7External water supplysystem

1.8External coal transportationsystem

1.9Rolling stock andlocomotives

1.10Ash disposal Plant &Equipment

1.11 Initial spares

1.12 Civil Woks

1.13Ash disposal areadevelopment

1.14 Township & Colony

1.15Temp. construction &enabling works

1.16Erection Testing andcommissioning

1.17Procurement &Management fee

1.18 Installation & Engineering

1.19Estab./Constructionsupervision

1.20 Training

1.21 Construction Insurance

1.22 Tools & Plants

1.23 Acess and diversion Road

1.24 Operators training

1.25 Start up fuel

1.26 Shared Facilities costs

2.0 Taxes and Duties




2.10 Custom Duty

2.20 Other Taxes & Duties

3.0 Overheads

3.1 Development expenses

3.2 Legal fee etc.

3.3 Eastablishment

3.4 Owners Engg.Expenses

3.5 Pre-operative expences

3.6 Audit & Accounts

3.7 Contingency

4.0Project cost without IDC& FC

1275.00

5.0 IDC & FC4

195.00

6.0Project cost includingIDC & FC

1470.00

7.0 Working Capital Margin

Name of the Power Station 13.5 Myntriang SHEP

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3

As perOriginal

Approved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)







1.5 BOP Mechanical






1.11 Initial spares

1.12 Civil Woks











1.20 Training


1.22 Tools & Plants



1.25 Start up fuel



2.10 Custom Duty


3.0 Overheads


3.2 Legal fee etc.

3.3 Eastablishment




3.7 Contingency


127.87

5.0 IDC & FC4

2.11


129.98


Note:

Details of FunctionalAssets Created onCapitalization

Land & Rights 11.12

Buildings 1.63

Hydraulic 35.16


Plant & Machinery 66.72


Vehicles 0.00


Office equipment 0.00Capital spares atgenerating stations

0.00

Total: 129.98

Name of the Power Station Lungnit SHEP

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3

As perOriginal

Approved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)










1.5 BOP Mechanical






1.11 Initial spares

1.12 Civil Woks








1.20 Training


1.22 Tools & Plants



1.25 Start up fuel



2.10 Custom Duty


3.0 Overheads


3.2 Legal fee etc.

3.3 Eastablishment




3.7 Contingency


50.81

5.0 IDC & FC4

4.80


55.61


Note:





Land & Rights 1.48

Buildings 1.35

Hydraulic 20.33




Vehicles 0.00



0.00

Total: 55.61

Name of the Power Station KLHEP (Intermediate Stage-I)

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3

As perOriginal

Approved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)







1.5 BOP Mechanical






1.11 Initial spares

1.12 Civil Woks








1.20 Training


1.22 Tools & Plants






1.25 Start up fuel



2.10 Custom Duty


3.0 Overheads


3.2 Legal fee etc.

3.3 Eastablishment




3.7 Contingency


191.62

5.0 IDC & FC4

18.38


210.00


Name of the Power Station KLHEP (Intermediate Stage-II)

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3

As perOriginal

Approved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)







1.5 BOP Mechanical






1.11 Initial spares

1.12 Civil Woks





1.17 Procurement &




Management fee



1.20 Training


1.22 Tools & Plants



1.25 Start up fuel



2.10 Custom Duty


3.0 Overheads


3.2 Legal fee etc.

3.3 Eastablishment




3.7 Contingency


228.12

5.0 IDC & FC4

21.88


250.00


Name of the Power Station KLHEP Barrage Toe Project

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3

As perOriginal

Approved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)







1.5 BOP Mechanical






1.11 Initial spares

1.12 Civil Woks











1.20 Training


1.22 Tools & Plants



1.25 Start up fuel



2.10 Custom Duty


3.0 Overheads


3.2 Legal fee etc.

3.3 Eastablishment




3.7 Contingency


173.37

5.0 IDC & FC4

16.63


190.00


Name of the Power Station Namrup Replacement Power Project

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3

As perOriginal

Approved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)







1.5 BOP Mechanical









1.11 Initial spares

1.12 Civil Woks








1.20 Training


1.22 Tools & Plants



1.25 Start up fuel



2.10 Custom Duty


3.0 Overheads


3.2 Legal fee etc.

3.3 Eastablishment




3.7 Contingency


614.73

5.0 IDC & FC4

79.00


693.73


Note:


Land & Rights 0.00

Buildings 0.00

Hydraulic 0.00







Vehicles 0.00



11.19

Total: 693.73

Name of the Power Station Lakwa Replacement Power Project

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3

As perOriginal

Approved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)







1.5 BOP Mechanical






1.11 Initial spares

1.12 Civil Woks








1.20 Training


1.22 Tools & Plants



1.25 Start up fuel



2.10 Custom Duty


3.0 Overheads





3.2 Legal fee etc.

3.3 Eastablishment




3.7 Contingency


282.65

5.0 IDC & FC4

55.59

6.0Project cost includingIDC & FC 338.24


Note:

Details of Functional Assets Created onCapitalization

Civil works 16.50


Contingency 7.68Env. ManagementPlanning 2.20

Overhead Charges 2.39

IDC & FC 55.59

Total: 338.24

Name of the Power Station Margherita Thermal Power Project

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3

As perOriginal

Approved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)







1.5 BOP Mechanical






1.11 Initial spares

1.12 Civil Woks











1.20 Training


1.22 Tools & Plants



1.25 Start up fuel



2.10 Custom Duty


3.0 Overheads


3.2 Legal fee etc.

3.3 Eastablishment




3.7 Contingency


3072.70

5.0 IDC & FC4

493.30


3566.00


Name of the Power StationCachar Distributed Generation System byGas IC Engine

Sl.No.

Break Down1

Cost in Rs. Crore2

VariationReasons

forVariation

AdmittedCost3

As perOriginal

Approved

CompletedCost as on

COD

(1) (2) (3) (4) (5) (6) (7)







1.5 BOP Mechanical



1.8 External coal transportation




system



1.11 Initial spares

1.12 Civil Woks








1.20 Training


1.22 Tools & Plants



1.25 Start up fuel



2.10 Custom Duty


3.0 Overheads


3.2 Legal fee etc.

3.3 Eastablishment




3.7 Contingency


146.14

5.0 IDC & FC4

16.82


162.96


1The break down shown here is only illustrative for a Coal/lignite based project.In case of Gas/Liquid fuel

based projects,

break down in similar manner in the relevant heads applicable for such plants may be furnished. Thepetitioners may vary the

break down incase of need.As far as possible the breakdown given here are to be adhered to.2

If there are any iteams,which need to be shown in Indian Rupee and foreign currency(ies), the same shouldbe shown

separatly alongwith the currency, the exchange rate and the date e.g. Rs.80 Cr+US$50m=Rs.280Cr atUS$=Rs.40 as on say 4.1.1999.




3In case the project has been completed and any tariff notification(s) has already been issued in the past by

AERC, fill

column 7 giving the cost as admitted by-(name of the authority) for the purpose of tariff notification alreadyissued (enclose copy of tariff order).4

If IDC has not been maintained separately and forms part of column 4, give a foot note accordingly.

PETITIONER

FORM-6

Final Package upto COD/ Transfer Scheme


Name of the Power Station Lower Kopili HEP

Project Cost as on COD1

or as per transfer scheme 1470.00

Date of Commercial Operation2

Debt: Equity Ratio as per transferscheme

Financial Package asApproved

Financial as on COD As Admitted on COD

Currency andAmount

3 Currency and Amount3

Currency and Amount3

(1) (2) (3) (4) (5) (6) (7)

State Govt.Loan

PFC Loan

Public Bond

Others 1020.00

MNRE

NABARD

New Loan

Total Loans 1020.00

Grants

Equity

ForeignDomestic

(Govt.)450.00

Total Equity 450.00





Name of the Power Station 13.5 MW Myntriang SHEP







Currency andAmount



(1) (2) (3) (4) (5) (6) (7)

State Govt.Loan 10.00

PFC Loan

Public Bond

Total Loans 10.00

Grants

NABARD 46.14

State Govt. 40.50

Total Grants 86.64

Equity 33.34

Foreign

Domestic

Total Equity


Name of the Power Station Lungnit SHEP Stage I & Stage II




Debt: Equity Ratio as per transfer




scheme



Currency andAmount



(1) (2) (3) (4) (5) (6) (7)


PFC Loan

Public Bond

Others 30.50

Total Loans 32.50

Grants

NEC 4.50

MNRE 18.00

Total Grants 22.50

Equity

Foreign

Domestic

Total Equity


Name of the Power Station Namrup Replacement Power Project







Currency andAmount



(1) (2) (3) (4) (5) (6) (7)


PFC Loan 486.00

NEC

MNES

NABARD

Public Bond

Total Loans 499.98




Grants 193.75

Equity

Foreign

Domestic

Total Equity


Name of the Power Station KLHEP (Intermediate Stage-I)







Currency andAmount



(1) (2) (3) (4) (5) (6) (7)

State Govt.Loan

PFC Loan

NEC

MNES

NABARD

New Loans 147.00

Total Loans 147.00

Grants

Equity

Foreign

Domestic(Govt.) 63.00

Total Equity 63.00


Name of the Power Station KLHEP (Intermediate Stage-II)










Currency andAmount



(1) (2) (3) (4) (5) (6) (7)

State Govt.Loan

PFC Loan

NEC

MNES

NABARD

New Loans 175.00

Total Loans 175.00

Grants

Equity

Foreign

Domestic(Govt.) 75.00

Total Equity 75.00


Name of the Power Station KLHEP Barrage Toe project







Currency andAmount



(1) (2) (3) (4) (5) (6) (7)

State Govt.Loan

PFC Loan

NEC

MNES




NABARD

New Loans 133.00

Total Loans 133.00

Grants

Equity

Foreign

Domestic(Govt) 57.00

Total Equity 57.00


Name of the Power Station Cachar Distributed Generating System







Currency andAmount



(1) (2) (3) (4) (5) (6) (7)

State Govt.Loan

PFC Loan

NEC

MNES

NABARD

New Loans 114.07

Total Loans 114.07

Grants

Equity

Foreign

Domestic (Govt) 48.89

Total Equity 48.89





Name of the Power Station Lakwa Replacement power project







Currency andAmount



(1) (2) (3) (4) (5) (6) (7)

State Govt.Loan

PFC Loan

NEC

MNES

NABARD

New Loans 265.10

Total Loans 265.10

Grants

Equity

ForeignDomestic

(Govt.)73.14

Total Equity 73.14


Name of the Power Station Margherita TPP










Currency andAmount



(1) (2) (3) (4) (5) (6) (7)

State Govt.Loan

PFC Loan

NEC

MNES

NABARD

New Loans 2496.20

Total Loans 2496.20

Grants

Equity

ForeignDomestic

(Govt.)1069.80

Total Equity 1069.80

1Say US $ 200m+ Rs.400 Cr or Rs. 1200 Cr including US $200m at an exchange rate of 1US $=Rs.40/-

2Date of Commercial Operation means Commercial Operation of the last unit

3For example : US $, 200m etc.

PETITIONER

FORM-7

Statement Giving Details of Project Specific Loans(As on COD

1/as per Transfer Scheme)

Name of theCompany

Assam PowerGeneration CorporationLimited

Name of thePower Station




Particulars Package1 Package2Package3

Package4

Package5

Package6

(1) (2) (3) (4) (5) (6) (7)

Source of Loan2

State Govt., PFCPublic Bond andothers

Currency3

Amount of Loan

See Details belowInterest Type4

Fixed InterestRate, if applicableBase Rate, ifFloating Interest

5

Margin, if FloatingInterest

6

Are there anyCaps/Floor

7 Yes/No Yes/NoYes/No

Yes/No

Yes/No

Yes/No

MoratoriumPeriod

8

Moratoriumeffective fromRepaymentPeriod

9

RepaymentFrequency

10

Base ExchangeRate

11

Date of BaseExchange Rate

1 In case the project has been completed and any tariff notification(s) has already been issued in thepast by AERC, the details in this form would pertains to loan package as on COD/ or as per transferschme.

2Source of loan means the agency from whom the loan has been taken such as WB, ADB, OECF,

KWF, SBI, ICICI, IFC, PFC ETC.3

Currency refers to currency of loan such as US $, DM, Yen, Indian Rupee etc.4

Interest type means whether the interest is fixed or floating5

Base rate means the base as PLR, LIBOR, etc. over which the margin is to be added.6

Margin means the points over and above the floating rate.7

At times caps/floor are put at which the floating rates are frozen. If such a condition exists, specifythe limits.8

Moratorium period refers to the period during which loan servicing liability is not required.9

Repayment period means the repayment of loan such as 7 years, 10 years, 25 years etc.10

Repayment frequency means the interval at which the debt servicing is to be done such as monthly,quarterly, half yearly, annual, etc.11

Base exchange rate means the exchange rate prevailing as on the date of COD.

PETITIONER

Station SourceRepayment Period

2013-14

2014-15

2015-16

KLHEPPFC

-8.34 -8.34 -8.34

ST. NTPS -1.27 -1.27 -1.27




R&M - II - LTPS -1.22 -1.22 -1.22

LWHRP -12.13 -12.13 -12.13

NRPP 0.00 0.00 0.00

Total PFC loanrepayment

-22.97 -22.97 -22.97

LTPS

Govt. of Assam

0.00 -2.20 -4.22

NTPS 0.00 -1.30 -2.67

KLHEP 0.00 -5.86 -6.06

Myntriang 0.00 -1.00 -1.00

NRPP 0.00 0.00 -1.01

Others 0.00 -0.20 -0.24

Total State Govt.Loan Repayment

0.00 -10.57 -15.20

Grand total -22.97 -33.53 -38.16




FORM-11



Amount of

Additional

Capitalisat

ion

Depreciati

on Amount

Amount of

FERV on

which

depreciati

on

charged

Depreciation amount

(1) (2) (3) (4) (5) (6)

Note: Details of calculations to be furnished.

PETITIONER

See Details below

Statement of Depreciation

Depreciati

on on

Capital

Cost as on

COD

Financial

Year

(Starting

from COD)

Detail of FERVDepreciation on

Additional

Capitalisation



APGCL ConsolidatedPrevious year 2013-14 Current year 2014-15 Ensuing year 2015-16

Sl.No

Depreciation of Assets Balance ofaccumulate

ddepreciation at the endof the year

Depreciationfor the year

Withdrawl of

depreciation

Balance ofaccumulate

ddepreciatio

n at theend of the

year

Depreciation for the

year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year

1 Land & Rights 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2 Building 16.02 0.72 0.00 16.74 0.72 0.00 17.46 0.74 0.00 18.20

3 Hydraulic 24.35 3.82 0.00 28.81 4.00 0.00 32.81 4.23 0.00 37.04

4 Other Civil Works 15.61 3.02 0.00 19.26 3.12 0.00 22.38 3.58 0.00 25.96

5 Plant & Machinery Thermal 236.64 11.93 -0.49 266.15 12.57 0.00 278.71 31.23 0.00 309.94

6 Plant & Machinery Hydel 43.31 4.27 0.00 28.24 4.48 0.00 32.72 5.10 0.00 37.81

7 Lines & Cable Network 8.01 0.21 0.00 8.51 0.98 0.00 9.50 1.06 0.00 10.56

8 Vehicles 1.22 0.12 0.00 1.05 0.12 0.00 1.17 0.12 0.00 1.29

9 Furniture & Fixtures 3.65 0.00 0.00 3.65 0.07 0.00 3.73 0.23 0.00 3.95

10 Office Equipemnt 0.50 0.05 0.00 0.55 0.06 0.00 0.61 0.06 0.00 0.68

11Roads on land belonging toother

0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.01

12 Capital spares atGenerating Stations

151.58 3.20 0.00 154.78 3.28 0.00 158.06 3.69 0.00 161.75

13 TOTAL 500.89 27.35 -0.49 527.75 29.40 0.00 557.15 50.04 0.00 607.19

14Depreciation on 90% of theAssets funded byGrants/subsidies

0.00 -5.39 0.00 -5.39 -6.13 0.00 -11.53 -10.16 0.00 -21.68

15 Net Depreciation 500.89 21.95 -0.49 522.35 23.27 0.00 545.62 39.88 0.00 585.50



Station : NTPSPrevious year 2013-14 Current year 2014-15 Ensuing year 2015-16

Sl.No




Withdrawl of

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year

1 Land & Rights 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2 Building 8.71 0.17 0.00 8.88 0.17 0.00 9.04 0.17 0.00 9.21

3 Hydraulic 3.66 0.11 0.00 3.77 0.11 0.00 3.89 0.11 0.00 4.00


5 Plant & Machinery Thermal 121.36 0.08 0.00 121.44 0.19 0.00 121.62 0.76 0.00 122.38



8 Vehicles 0.48 0.12 0.00 0.60 0.12 0.00 0.72 0.12 0.00 0.84




0.000.00 0.00

0.000.00 0.00

0.000.00 0.00 0.00

12Capital spares atGenerating Stations

46.110.22 0.00

46.330.26 0.00

46.590.30 0.00 46.89

13 TOTAL 186.29 0.84 0.00 187.12 1.10 0.00 188.22 1.77 0.00 189.99

14Depreciation on 90% of theAssets funded byGrants/subsidies -0.43

-0.43 -0.43 -0.86 -0.43 -1.29

15 Net Total 186.29 0.41 0.00 186.69 0.67 0.00 187.36 1.33 0.00 188.69



Station : LTPSPrevious year 2013-14 Current year 2014-15 Ensuing year 2015-16

Sl.No




Withdrawl of

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year

1 Land & Rights 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2 Building 4.34 0.08 0.00 4.43 0.08 0.00 4.51 0.08 0.00 4.59

3 Hydraulic 0.23 0.01 0.00 0.24 0.01 0.00 0.25 0.01 0.00 0.27





8 Vehicles 0.40 0.00 0.00 0.40 0.00 0.00 0.40 0.00 0.00 0.40




0.000.00 0.00

0.000.00 0.00

0.000.00 0.00 0.00

12 Capital spares atGenerating Stations

104.872.98 0.00

107.853.01 0.00

110.863.10 0.00 113.96

13 TOTAL 200.61 3.35 0.00 203.96 4.07 0.00 208.03 4.94 0.00 212.98


-0.13 -0.13 -0.13 -0.26 -0.13 -0.39

15 Net Total 200.61 3.22 0.00 203.83 3.94 0.00 207.77 4.81 0.00 212.58



Station : CTPSPrevious year 2013-14 Current year 2014-15 Ensuing year 2015-16

Sl.No




Withdrawl of

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year

1 Land & Rights 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2 Building 0.02 0.00 0.00 0.02 0.00 0.00 0.02 0.00 0.00 0.02

3 Hydraulic 0.06 0.00 0.00 0.06 0.00 0.00 0.06 0.00 0.00 0.06





8 Vehicles 0.05 0.00 0.00 0.05 0.00 0.00 0.05 0.00 0.00 0.05




0.000.00 0.00

0.000.00 0.00

0.000.00 0.00

0.00


0.590.00 0.00

0.590.00 0.00

0.590.00 0.00

0.59

13 TOTAL 28.11 0.00 0.00 28.11 0.00 0.00 28.11 0.00 0.00 28.11


15 Net Total 28.11 0.00 0.00 28.11 0.00 0.00 28.11 0.00 0.00 28.11



Station : KLHEP

Previous year 2013-14 Current year 2014-15 Ensuing year 2015-16Sl.No




Withdrawl of

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year

1 Land & Rights 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2 Building 2.94 0.47 0.00 3.41 0.47 0.00 3.88 0.47 0.00 4.35

3 Hydraulic 20.41 3.11 0.00 23.52 3.11 0.00 26.64 3.11 0.00 29.75





8 Vehicles 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00



11Roads on land belonging toother 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.01

12 Capital spares atGenerating Stations 0.00 0.00 0.00 0.00 0.01 0.00 0.01 0.03 0.00 0.03

13 TOTAL 64.35 9.67 0.00 74.02 10.47 0.00 84.49 10.58 0.00 95.07


-2.11 -2.11 -1.80 -3.90 -1.82 -5.73

15 Net Total 64.35 7.56 0.00 71.91 8.67 0.00 80.59 8.75 0.00 89.34



Station : LWHRP





Withdrawl of

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year

1 Land & Rights 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2 Building 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.01

3 Hydraulic 0.00 0.40 0.00 1.03 0.40 0.00 1.43 0.40 0.00 1.83


5 Plant & Machinery Thermal 1.27 11.64 -0.49 30.48 11.49 0.00 41.97 11.49 0.00 53.46



8 Vehicles 0.29 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00



11Roads on land belonging toother 0.00

0.000.00 0.00 0.00 0.00

0.000.00 0.00 0.00

12 Capital spares atGenerating Stations 0.00

0.000.00 0.00 0.00 0.00

0.000.03 0.00 0.03

13 TOTAL 21.53 13.07 -0.49 34.11 12.92 0.00 47.02 12.95 0.00 59.98


-2.02 -2.02 -2.02 -4.04 -2.02 -6.06

15 Net Total 21.53 11.05 -0.49 32.09 10.90 0.00 42.98 10.93 0.00 53.92



Station : Myntriang SHEP





Withdrawl of

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year


year

Withdrawlof

depreciation


ddepreciatio

n at theend of the

year

1 Land & Rights 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2 Building 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.01

3 Hydraulic 0.00 0.18 0.00 0.18 0.37 0.00 0.55 0.59 0.00 1.14





8 Vehicles 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00



11Roads on land belonging toother 0.00 0.00 0.00 0.00 0.00 0.00

0.000.00 0.00 0.00

12 Capital spares atGenerating Stations 0.00 0.00 0.00 0.00 0.00 0.00

0.000.00 0.00 0.00

13 TOTAL 0.00 0.42 0.00 0.42 0.84 0.00 1.27 1.75 0.00 3.02


-0.70 -0.70 -1.75 -2.46 -2.48 -4.94

15 Net Total 0.00 -0.28 0.00 -0.28 -0.91 0.00 -1.19 -0.73 0.00 -1.92



Station: NRPP


Depreciation of Assets Balance ofaccumulateddepreciationat the end of

the year


Withdrawlof

depreciation

Balance ofaccumulateddepreciationat the end of

the year


Withdrawl ofdepreciation


the year


Withdrawl ofdepreciation


the year

1 Land & Rights 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

2 Building 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

3 Hydraulic 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00





8 Vehicles 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00




0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00


0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.24 0.00 0.24

0.00 0.00 0.00 0.00 0.00 0.00 0.00 18.05 0.00 18.05


0.00 0.00 -3.26 -3.26

15 Net Total 0.00 0.00 0.00 0.00 0.00 0.00 0.00 14.78 0.00 14.78




Loan Consolidated APGCL

Existing Loans 12-13 13-14 14-15 15-16PFC

O/Balance 239.45 306.48 333.51 410.55

Additions 90.00 50.00 100.00 160.00

Repayments 22.97 -22.97 -22.97 -22.97

C/Balance 306.48 333.51 410.55 547.58

Total Interest 27.53 37.46 45.05 59.97

Interest capitalised 4.01 -15.34 -25.34 -14.23

FORM-12



Openin

g

Balanc

e

Repay

ment

Closing

Balanc

e

Interest

due

Openin

g

Balanc

e

Repay

ment

Closing

Balanc

e

Interest

due

(1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11) (12)

Original Currency

Rs.

Original Currency

Rs.

Original Currency

Rs.

Original Currency

Rs.

Original Currency

Rs.

Original Currency

Rs.

PETITIONER

See Details below

Statement showing Computation of Interest on Various Loans

Particulars

Loan-2 and so onLoan-1Total

Interest

due

Total

Repay

ment

Year...

Total

Year 1

Year 2

Year 3

Year...




Interest charged to P&L A/c 23.52 22.13 19.71 45.74

State Govt. Loan

O/Balance 108.22 117.58 136.15 167.96

Additions 9.37 18.57 42.38 71.85

Repayments 0.00 0.00 -10.57 -15.20

C/Balance 117.58 136.15 167.96 224.62

Interest 16.89 13.21 13.75 17.21

Interest to be capitalised 2.83 -4.12 -4.25 -4.54Interest to be charged toP&L 14.06 9.09 9.51 12.67

Other

O/Balance 0.00 0.00 0.00 0.00

Additions 0.00 0.00 0.00 95.46

Repayments 0.00 0.00 0.00 0.00

C/Balance 0.00 0.00 0.00 95.46

Interest 0.00 0.00 0.00 5.44

Interest to be capitalised 0.00 0.00 0.00 -5.44Interest to be charged toP&L 0.00 0.00 0.00 0.00

Station Govt Of Assam PFC Other FI Loan Total

LT

PS

LT

PS

LT

PS

LT

PS

LT

PS

LT

PS

LT

PS

RuralElectrification 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.10 0.10 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.10 0.09

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 -0.01 -0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.01 -0.01

C/Balance 0.10 0.09 0.08 0.00 0.00 0.00 0.00 0.00 0.00 0.10 0.09 0.08

Total Interest 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.01

Interest capitalised 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Interest charged toP&L A/c 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.01

LWHRP 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 7.23 7.23 6.51124.3

4112.2

1100.0

8 0.00 0.00 0.00131.5

7119.4

4106.5

9

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 -0.72 -0.72 -12.13 -12.13 -12.13 0.00 0.00 0.00 -12.13 -12.85 -12.85

C/Balance 7.23 6.51 5.79112.2

1100.0

8 87.95 0.00 0.00 0.00119.4

4106.5

9 93.73

Total Interest 0.76 0.68 0.61 14.88 13.36 11.83 0.00 0.00 0.00 15.64 14.04 12.44


R&M LTPS 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16




O/Balance 12.10 13.60 32.43 0.00 0.00 0.00 0.00 0.00 0.00 12.10 13.60 32.43

Additions 1.50 20.19 20.62 0.00 0.00 0.00 0.00 0.00 0.00 1.50 20.19 20.62

Repayments 0.00 -1.36 -3.38 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -1.36 -3.38

C/Balance 13.60 32.43 49.67 0.00 0.00 0.00 0.00 0.00 0.00 13.60 32.43 49.67

Total Interest 1.28 1.47 3.23 0.00 0.00 0.00 0.00 0.00 0.00 1.28 1.47 3.23


LTPS Ph-II 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.70 0.70 0.63 13.41 12.19 10.97 0.00 0.00 0.00 14.11 12.89 11.60

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 -0.07 -0.07 -1.22 -1.22 -1.22 0.00 0.00 0.00 -1.22 -1.29 -1.29

C/Balance 0.70 0.63 0.56 12.19 10.97 9.75 0.00 0.00 0.00 12.89 11.60 10.31

Total Interest 0.07 0.07 0.06 1.53 1.39 1.24 0.00 0.00 0.00 1.60 1.45 1.30


EAP ConsultingServices 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.37 0.37 0.34 0.00 0.00 0.00 0.00 0.00 0.00 0.37 0.37 0.34

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 -0.04 -0.04 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.04 -0.04

C/Balance 0.37 0.34 0.30 0.00 0.00 0.00 0.00 0.00 0.00 0.37 0.34 0.30

Total Interest 0.04 0.04 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.04 0.03


NT

PS

R&M NTPS 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 11.00 11.00 20.36 5.74 4.46 3.19 0.00 0.00 0.00 16.73 15.46 23.55

Additions 0.00 10.67 3.80 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10.67 3.80

Repayments 0.00 -1.30 -2.67 -1.27 -1.27 -1.27 0.00 0.00 0.00 -1.27 -2.57 -3.94

C/Balance 11.00 20.36 21.50 4.46 3.19 1.91 0.00 0.00 0.00 15.46 23.55 23.41

Total Interest 1.14 1.30 2.42 0.42 0.32 0.21 0.00 0.00 0.00 1.57 1.62 2.63


KL

HE

PK

LH

EP

KL

HE

PK

LH

EP

KLHEP 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 51.39 56.78 52.9173.00

64.66 56.31 0.00 0.00 0.00124.3

9121.4

4109.2

3

Additions 5.39 1.92 5.43 0.00 0.00 0.00 0.00 0.00 0.00 5.39 1.92 5.43

Repayments 0.00 -5.79 -5.99 -8.34 -8.34 -8.34 0.00 0.00 0.00 -8.34 -14.14 -14.33

C/Balance 56.78 52.91 52.3664.66 56.31 47.97

0.00 0.00 0.00121.4

4109.2

3100.3

3

Total Interest 5.48 5.37 4.98 5.29 4.65 4.01 0.00 0.00 0.00 10.77 10.02 8.98


Survey &investigation ofHEP 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.70 0.70 0.63 0.00 0.00 0.00 0.00 0.00 0.00 0.70 0.70 0.63

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00




Repayments 0.00 -0.07 -0.07 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.07 -0.07

C/Balance 0.70 0.63 0.56 0.00 0.00 0.00 0.00 0.00 0.00 0.70 0.63 0.56

Total Interest 0.07 0.07 0.06 0.00 0.00 0.00 0.00 0.00 0.00 0.07 0.07 0.06


MS

HE

P

Myntriang SHEP 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 2.00 10.00 9.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 10.00 9.00

Additions 8.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8.00 0.00 0.00

Repayments 0.00 -1.00 -1.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -1.00 -1.00

C/Balance 10.00 9.00 8.00 0.00 0.00 0.00 0.00 0.00 0.00 10.00 9.00 8.00

Total Interest 0.28 0.95 0.84 0.00 0.00 0.00 0.00 0.00 0.00 0.28 0.95 0.84

Interest capitalised -0.26 -0.63 -0.37 0.00 0.00 0.00 0.00 0.00 0.00 -0.26 -0.63 -0.37Interest charged toP&L A/c 0.02 0.32 0.47 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.32 0.47

Am

gu

ri

Development ofAmguri 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.50 0.50 0.45 0.00 0.00 0.00 0.00 0.00 0.00 0.50 0.50 0.45

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 -0.05 -0.05 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.05 -0.05

C/Balance 0.50 0.45 0.40 0.00 0.00 0.00 0.00 0.00 0.00 0.50 0.45 0.40

Total Interest 0.05 0.05 0.04 0.00 0.00 0.00 0.00 0.00 0.00 0.05 0.05 0.04


DH

EP

Dhansiri HEP 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 1.04 1.04 0.94 0.00 0.00 0.00 0.00 0.00 0.00 1.04 1.04 0.94

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 -0.10 -0.10 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.10 -0.10

C/Balance 1.04 0.94 0.83 0.00 0.00 0.00 0.00 0.00 0.00 1.04 0.94 0.83

Total Interest 0.11 0.10 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.11 0.10 0.09


CT

PS

CTPS 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.50 0.50 0.45 0.00 0.00 0.00 0.00 0.00 0.00 0.50 0.50 0.45

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 -0.05 -0.05 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.05 -0.05

C/Balance 0.50 0.45 0.40 0.00 0.00 0.00 0.00 0.00 0.00 0.50 0.45 0.40

Total Interest 0.05 0.05 0.04 0.00 0.00 0.00 0.00 0.00 0.00 0.05 0.05 0.04


NR

PP

NRPP Ph- I 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 10.13 10.13 10.13 90.00140.0

0240.0

0 0.00 0.00 0.00100.1

3150.1

3250.1

3

Additions 0.00 0.00 0.00 50.00100.0

0160.0

0 0.00 0.00 0.00 50.00100.0

0160.0

0

Repayments 0.00 0.00 -1.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -1.01

C/Balance 10.13 10.13 9.11140.0

0240.0

0400.0

0 0.00 0.00 0.00150.1

3250.1

3409.1

1

Total Interest 1.69 1.06 0.96 15.34 25.34 42.68 0.00 0.00 0.00 17.02 26.40 43.64




Interest capitalised -1.69 -1.06 -0.32 -15.34 -25.34 -14.23 0.00 0.00 0.00 -17.02 -26.40 -14.55Interest charged toP&L A/c 0.00 0.00 0.64 0.00 0.00 28.45 0.00 0.00 0.00 0.00 0.00 29.09

Oth

er

pro

jec

tsn

ot

ye

tc

om

ms

sio

ned

Lower Kopili 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 12.75 12.75 19.75 0.00 0.00 0.00 0.00 0.00 0.00 12.75 12.75 19.75

Additions 0.00 7.00 7.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 7.00 7.00

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 12.75 19.75 26.75 0.00 0.00 0.00 0.00 0.00 0.00 12.75 19.75 26.75

Total Interest 1.33 1.40 2.14 0.00 0.00 0.00 0.00 0.00 0.00 1.33 1.40 2.14


Lakwa RPP 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.00 0.98 1.58 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.98 1.58

Additions 0.98 0.60 0.000.00 0.00 0.00

0.00 0.0078.6

0 0.98 0.60 78.60

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 0.98 1.58 1.580.00 0.00 0.00

0.00 0.0078.6

0 0.98 1.58 80.18

Total Interest 0.07 0.11 0.17 0.00 0.00 0.00 0.00 0.00 4.48 0.07 0.11 4.65

Interest capitalised -0.07 -0.11 -0.17 0.00 0.00 0.00 0.00 0.00 -4.48 -0.07 -0.11 -4.65Interest charged toP&L A/c 0.00 0.00 0.00

0.00 0.00 0.000.00 0.00 0.00 0.00 0.00 0.00

Lungnit SHEP 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 3.00

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 3.00

Total Interest 0.31 0.32 0.32 0.00 0.00 0.00 0.00 0.00 0.00 0.31 0.32 0.32


Development ofSHEP 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 1.00 1.00 1.00 0.00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 1.00

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 1.00 1.00 1.00 0.00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 1.00

Total Interest 0.11 0.11 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.11 0.11 0.11


Non ConventionalSources of Energy 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.40 0.40 0.40 0.00 0.00 0.00 0.00 0.00 0.00 0.40 0.40 0.40

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 0.40 0.40 0.40 0.00 0.00 0.00 0.00 0.00 0.00 0.40 0.40 0.40

Total Interest 0.04 0.04 0.04 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.04 0.04





KLHEP (Upper) 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.40 1.30 1.30 0.00 0.00 0.00 0.00 0.00 0.00 0.40 1.30 1.30

Additions 0.90 0.00 0.25 0.00 0.00 0.00 0.00 0.00 0.00 0.90 0.00 0.25

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 1.30 1.30 1.55 0.00 0.00 0.00 0.00 0.00 0.00 1.30 1.30 1.55

Total Interest 0.06 0.14 0.14 0.00 0.00 0.00 0.00 0.00 0.00 0.06 0.14 0.14


KLHEP(Intermediate) 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.40 1.00 1.00 0.00 0.00 0.00 0.00 0.00 0.00 0.40 1.00 1.00

Additions 0.60 0.00 0.50 0.00 0.00 0.00 0.00 0.00 0.00 0.60 0.00 0.50

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 1.00 1.00 1.50 0.00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 1.50

Total Interest 0.05 0.11 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.05 0.11 0.11


Setting up of a200 MW (CCGT) 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.15 0.15 0.15 0.00 0.00 0.00 0.00 0.00 0.00 0.15 0.15 0.15

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 0.15 0.15 0.15 0.00 0.00 0.00 0.00 0.00 0.00 0.15 0.15 0.15

Total Interest 0.02 0.02 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.02 0.02


Margherita/Borgolai 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 1.35 2.25 4.25 0.00 0.00 0.00 0.00 0.00 0.00 1.35 2.25 4.25

Additions 0.90 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.90 2.00 0.00

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 2.25 4.25 4.25 0.00 0.00 0.00 0.00 0.00 0.00 2.25 4.25 4.25

Total Interest 0.16 0.25 0.45 0.00 0.00 0.00 0.00 0.00 0.00 0.16 0.25 0.45


Golaghat 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.37 0.37 0.37 0.00 0.00 0.00 0.00 0.00 0.00 0.37 0.37 0.37

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 0.00 -0.04 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.04

C/Balance 0.37 0.37 0.33 0.00 0.00 0.00 0.00 0.00 0.00 0.37 0.37 0.33

Total Interest 0.04 0.04 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.04 0.03


Amring 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16 13-14 14-15 15-16

O/Balance 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00




Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total Interest 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00


Solar PP at NTPS13-14 14-15 15-16 13-14 14-15 15-16

13-14

14-15

15-16

13-14 14-15 15-16

O/Balance 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Additions 0.00 0.00 17.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 17.00

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 0.00 0.00 17.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 17.00

Total Interest 0.00 0.00 0.15 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.15

Interest capitalised 0.00 0.00 -0.15 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.15Interest charged toP&L A/c 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Solar PP at LTPS13-14 14-15 15-16 13-14 14-15 15-16

13-14

14-15

15-16

13-14 14-15 15-16

O/Balance 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Additions 0.00 0.00 17.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 17.00

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 0.00 0.00 17.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 17.00

Total Interest 0.00 0.00 0.15 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.15

Interest capitalised 0.00 0.00 -0.15 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.15Interest charged toP&L A/c 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

KLHEP BarrageToe Project 13-14 14-15 15-16 13-14 14-15 15-16

13-14

14-15

15-16

13-14 14-15 15-16

O/Balance 0.00 0.30 0.30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.30

Additions 0.30 0.00 0.25 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.00 0.25

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 0.30 0.30 0.55 0.00 0.00 0.00 0.00 0.00 0.00 0.30 0.30 0.55

Total Interest 0.00 0.03 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.03

Interest capitalised 0.00 -0.03 -0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.03 -0.03Interest charged toP&L A/c 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Cachar distributedGenerationsystem by Gas ICEngine

13-14 14-15 15-16 13-14 14-15 15-1613-14

14-15

15-16

13-14 14-15 15-16

O/Balance 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Additions 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0016.8

6 0.00 0.00 16.86

Repayments 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C/Balance 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0016.8

6 0.00 0.00 16.86

Total Interest 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.96 0.00 0.00 0.96

Interest capitalised 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.96 0.00 0.00 -0.96Interest charged toP&L A/c 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00




FORM-14



2013-14 2014-15 2015-16

(1) (2) (3) (4) (5)

INTEREST ON WORKING CAPITAL

Fuel Cost - 1 month

Fuel stock - 1 or 1/2 month

Oil stock - 2 months

O & M expenses - 1 month

Spares 1 year = 40% of O & M Less 1/5th

of initial capitalised spares for first 5 years

Receivables - 2 months

Total Working Capital (Rs. cr)

Working Capital Loan allowed

Weighted Average Interest Rate

INTEREST ON WORKING CAPITAL (Rs cr)

AMOUNTRATE OF

INTEREST

(Rs. in Crs)(Cash Credit)

(%)

(1) (2) (3) (4)

a

b

c

d

e

TOTAL

Weighted Average Rate of Interest

Period

2013-14 2014-15 2015-16

22.23 25.39 30.62

Interest on Working Capital as per AERC

PETITIONER

Statement of Calculation of Averge Rate of Interest (CC) on Working Capital Loans

Year ending March

Source of Loan for Working CapitalSL.

NO.

See Details below




FORM-15



2013-14 2014-15 2015-16

(1) (2) (3) (4)

O&M data projection for 2013-14 to 2015-16

A) Total O & M Expenses 120.56 121.14 152.57

B) Abnormal O&M expenses1

- On account of water charges

- On account of other factors

C) Calculation of Base O&M (A-B) 120.56 121.14 152.57Notes:

PETITIONER

1 Abnormal O&M expenses such as on account of sharp increase in water charges etc. which are abnormal innature andfor which the utility shall file a separate petition.

Calculation of Operation and Maintenance Expenses




FORM-16



2013-14 2014-15 2015-16

(1) (2) (3) (4) (5)(A) Breakup of O& M expenses

1 Employee cost & terminal benefit provisions

2 Repair and Maintenance3 Stores consumed4 Power Charges5 Water Charges6 Communication expenses7 Travelling expenses8 Insurance

- Plant & Machinery- Other

9 Rent10 Security expenses11 Professional expenses12 Printing and Stationery13 Corporate office expenses allocation14 Other Expenses like employees past period liabilities15 Total (1 to 4)

LESS: RECOVERED (IF ANY)Net Expenses

Notes:1. The process of allocation of corporate expenses to generating stations should be specified.2. An annual increase in O&M expenses under a given head ( in excess of 20 percent shouldbe explained)3. The data should be certified by statutory auditors.

(B) Corporate office expenses(aggregate)- Direct employee expense- Repair and maintaenance- Training and Recruitment- Commmunication- Travelling- Security- Rent- Others

PETITIONER

Details of Operation and Maintenance Expenses

See Details below




APGCL Consolidated

Employee Expenses

Particulars 2013-14 2014-15 2015-16

Salaries 33.81 36.65 48.21

Overtime 1.44 1.66 2.07

Dearness Allowance 27.12 29.85 39.33

Other Allowances 6.93 5.61 7.38

Bonus 0.03 0.03 0.04

Medical Allowances 0.18 0.09 0.13

Leave Travel Assistance 0.05 0.05 0.07

Earned Leave Encashment 0.27 0.29 0.36

Workmen Compensatory Payment 0.00 0.00 0.00

Other Staff Cost 0.01 0.01 0.00

Staff Welfare Expenses 0.13 0.14 0.19

Terminal Benefits 12.04 12.16 14.41

Subtotal 82.00 86.54 112.19

Less: Capitalisation 0.00 0.00 6.92

Total 82.00 86.54 105.27

Administration and General Expenses

Particulars 2013-14 2014-15 2015-16

Rent, Rates & Taxes 0.35 0.35 0.39

Insurance 0.81 0.88 0.94

Telephone charges 0.12 0.05 0.06

Postage & Telegrarm 0.01 0.00 0.00

Legal charges 0.02 0.01 0.01

Audit fees 0.02 0.00 0.00

Consultancy charges 0.60 0.65 0.71

Technical fees 0.02 0.01 0.00

Other Professional fees 0.07 0.01 0.00

Conveyance & Travel charges 0.76 0.63 0.78

Freight 0.04 0.02 0.02

Other purchase related expenses 9.72 6.79 7.64

Energy bill raised by APDCL 0.00 0.00 0.00

Sub Total: 12.53 9.41 10.56

Less: Capitalised 0.00 0.00 0.70

Total: 12.53 9.41 9.85

Repairs & Maintenance

Particulars 2013-14 2014-15 2015-16


Overhauling Works 0.00 6.44 32.00

B. Regular Repair & Maintenance:-Plant & Machinery 20.60 14.74 16.95

Buildings 1.81 0.27 0.31

Other civil works 0.87 0.31 0.35

Hydraulic 0.89 1.10 1.26




Lines & Cable Network 0.03 0.09 0.11

Vehicles 0.06 0.26 0.30

Furniture & fixture 0.26 0.14 0.16

Office equipment 0.08 0.20 0.23

Lubricants & Consumable stores 1.23 1.41 1.62

Turbine Oil 0.20 0.23 0.26

Total: 26.03 25.19 53.55

NTPSEmployee Expenses

Particulars2013-

142014-

152015-

16

Salaries 13.59 14.74 15.98

Overtime 0.41 0.54 0.59



Bonus 0.01 0.01 0.01








Subtotal 30.03 32.30 35.02


Total 30.03 32.30 35.02


Particulars2013-

142014-

152015-

16


Insurance 0.00 0.00 0.00




Audit fees 0.01 0.00 0.00





Freight 0.01 0.00 0.00


Sub Total: 3.75 2.65 1.54


Total: 3.75 2.65 1.54





Particulars2013-

142014-

152015-

16

A. Special Type Repair &Maintenance:-



Buildings 0.78 0.17 0.20


Hydraulic 0.00 0.52 0.60


Vehicles 0.00 0.00 0.00




Turbine Oil 0.01 0.01 0.01

Total: 5.23 2.30 16.65

NRPPEmployee Expenses

Particulars2013-

142014-

152015-

16

Salaries 0.00 0.00 7.30

Overtime 0.00 0.00 0.27



Bonus 0.00 0.00 0.01








Subtotal 0.00 0.00 16.01


Total 0.00 0.00 10.67


Particulars2013-

142014-

152015-

16


Insurance 0.00 0.00 0.00




Audit fees 0.00 0.00 0.00








Freight 0.00 0.00 0.00


Sub Total: 0.00 0.00 1.33


Total: 0.00 0.00 0.89


Particulars2013-14

2014-15

2015-16




Buildings 0.00 0.00 0.00


Hydraulic 0.00 0.00 0.00


Vehicles 0.00 0.00 0.00




Turbine Oil 0.00 0.00 0.00

Total: 0.00 0.00 0.00

LTPSEmployee Expenses

Particulars2013-

142014-

152015-

16

Salaries 10.23 11.09 12.03

Overtime 0.79 0.85 0.92



Bonus 0.01 0.01 0.01








Subtotal 26.85 28.19 30.55


Total 26.85 28.19 30.55





Particulars2013-

142014-

152015-

16


Insurance 0.58 0.63 0.68




Audit fees 0.01 0.00 0.00





Freight 0.01 0.00 0.00


Sub Total: 3.32 3.46 3.74


Total: 3.32 3.46 3.74


Particulars2013-

142014-

152015-

16




Buildings 0.58 0.03 0.03


Hydraulic 0.00 0.29 0.33


Vehicles 0.01 0.13 0.15




Turbine Oil 0.00 0.00 0.00

Total: 6.95 15.45 28.35

CTPSEmployee Expenses

Particulars2013-

142014-

152015-

16

Salaries 1.64 1.78 1.93

Overtime 0.00 0.00 0.00



Bonus 0.00 0.00 0.00











Subtotal 3.02 3.18 3.45


Total 3.02 3.18 3.45


Particulars2013-

142014-

152015-

16


Insurance 0.00 0.00 0.00




Audit fees 0.00 0.00 0.00





Freight 0.00 0.00 0.00


Sub Total: 0.06 0.02 0.01


Total: 0.06 0.02 0.01


Particulars2013-

142014-

152015-

16




Buildings 0.00 0.00 0.00


Hydraulic 0.00 0.00 0.00


Vehicles 0.00 0.00 0.00




Turbine Oil 0.00 0.00 0.00

Total: 0.03 0.00 0.00

KLHEP




Employee Expenses

Particulars2013-

142014-

15 2015-16

Salaries 4.89 5.30 5.75

Overtime 0.00 0.00 0.00



Bonus 0.01 0.01 0.01








Subtotal 13.17 13.46 14.59


Total 13.17 13.46 14.59


Particulars2013-

142014-

15 2015-16


Insurance 0.05 0.05 0.05




Audit fees 0.01 0.00 0.00





Freight 0.01 0.01 0.02


Sub Total: 4.28 2.75 2.97


Total: 4.28 2.75 2.97


Particulars2013-

142014-

15 2015-16




Buildings 0.27 0.03 0.03





Hydraulic 0.89 0.29 0.33


Vehicles 0.04 0.13 0.15




Turbine Oil 0.19 0.22 0.25

Total: 12.03 6.69 7.69

LWHRPEmployee Expenses

Particulars2013-

142014-

152015-

16

Salaries 3.17 3.44 3.73

Overtime 0.24 0.26 0.29



Bonus 0.00 0.00 0.00








Subtotal 8.32 8.78 9.51


Total 8.32 8.78 9.51


Particulars2013-

142014-

152015-

16


Insurance 0.18 0.20 0.21




Audit fees 0.00 0.00 0.00





Freight 0.00 0.00 0.00


Sub Total: 1.03 0.44 0.47


Total: 1.03 0.44 0.47





Particulars2013-

142014-

152015-

16




Buildings 0.18 0.04 0.05


Hydraulic 0.00 0.00 0.00


Vehicles 0.00 0.00 0.00




Turbine Oil 0.00 0.00 0.00

Total: 1.77 0.72 0.83

MyntriangEmployee Expenses

Particulars 2013-14 2014-15 2015-16

Salaries 0.28 0.30 1.49

Overtime 0.00 0.00 0.00



Bonus 0.00 0.00 0.00








Subtotal 0.60 0.63 3.06


Total 0.60 0.63 1.47

Particulars 2013-14 2014-15 2015-16


Insurance 0.00 0.00 0.00




Audit fees 0.00 0.00 0.00





Freight 0.00 0.00 0.00





Sub Total: 0.10 0.09 0.50


Total: 0.10 0.09 0.24


Particulars 2013-14 2014-15 2015-16




Buildings 0.00 0.00 0.00


Hydraulic 0.00 0.00 0.00


Vehicles 0.00 0.00 0.00




Turbine Oil 0.00 0.00 0.00

Total: 0.03 0.03 0.03



FORM-17

Details/Information to be Submitted in respect of Fuel for Computation of Energy

Name of the Company APGCL

Name of the Power Station Namrup Thermal Power Station

GAS

Months

For preceding 3rdMonth

For preceding 2ndMonth

For preceding 1stMonth (October'14)

APM Non-APM

APM Non-APM

APM Non-APM

Quantity of Gas (1000 SCM) 20113.75 1613.22 19497.22 1550.14 20115.33 1028.59

Amount charged by the Gas Co. (Rs.)

Transportation Charge (Rs.)

Weighted average GCV Gas kCal/CUM 8817.00 8817.00 8607.00 8607.00 8615.00 8615.00

Unit price ofGas chargedby the Gas Co.

Base price for CV (Rs/1000SCM) 5295.49 8825.82 5241.66 8736.11 5243.09 8738.48

Marketing Margin (Rs/1000SCM) 176.34 176.34 172.14 172.14 172.30 172.30

Cess or duty (Rs/1000SCM)

Sales Tax (VAT)12%

(Rs/1000SCM) 656.62 1080.26 649.66 1068.99 649.85 1069.29

Transportation (Rs/1000SCM)

Total (Rs/1000SCM) 6128.45 10082.42 6063.46 9977.23 6065.24 9980.07

Transportationbyrail/ship/road(Pipe Line)

Distance (Km)

Rate (Rs/1000SCM) 469.92 470.16 482.41

Amount 10209841.00 9895564.00 10199940.00

Note:

1. Furnish copies of relevant coal/lignite price notifications or the fuel supply agreement, tariff rates of Railwaysor other transport authorities as

applicable.2. Similar details to be furnished for natural gas/liquid fuel for CCGT station and secondary fuel oil for coal/lignite

based thermal.

PETITIONER



FORM-17

Details/Information to be Submitted in respect of Fuel for Computation of Energy

Name of the Company APGCL

Name of the Power Station Lakwa Thermal Power Station

GASMonths For preceding 3rd Month For preceding 2nd Month For preceding 1st Month (Oct'14)

Name of the Gas Supplier GAIL OIL CANORO GAIL OIL CANORO GAIL OIL CANORO

Quantity of Gas (1000 SCM) 13197.5 8880.3 908.9 11160.5 9726.6 865.7 14725.4 9913.7 907.1

Amount charged by the GasCo.

(Rs.)

Transportation Charge (Rs.)

Weighted average GCV Gas kCal/CUM 9179 8817 9623 9305 8607 9603 9870 8615 9609

Unit price ofGas chargedby the GasCo.

Base price forCV

(Rs/1000SCM) 5513 8826 5056 5667 8736 5106 6007 8738 5109

Any othercharge

(Rs/1000SCM)

MarketingMargin

(Rs/1000SCM) 183.6 176.3 192.5 186.1 172.1 192.1 197.4 172.3 192.2

Royalty (Rs/1000SCM) 505.6 510.6 510.9

Sales Tax(VAT) 12%

(Rs/1000SCM) 683.6 1080.3 690.5 702.3 1069.0 697.0 744.5 1069.3 697.4

Transportation (Rs/1000SCM) 20.1 20.1 20.1

Total (Rs/1000SCM) 6400.1 10082.4 6445 6575.2 9977.2 6505.1 6968.8 9980.1 6508.9

Transportationby Pipe Line

Distance (Km)

Rate (Rs/1000SCM) 736.7 736.7 736.7

Amount 7211769.0 7803358.0 7971835.0

Note:1. Furnish copies of relevant coal/lignite price notifications or the fuel supply agreement, tariff rates of Railways or other transport authorities asapplicable.2. Similar details to be furnished for natural gas/liquid fuel for CCGT station and secondary fuel oil for coal/lignite based thermal.

PETITIONER




Annex-IV

12. STATIONWISE INFORMATION FOR CLAIMING

ARR AND TARIFF FOR ASSAM POWER GENERATION

CORPORATION LIMITED FOR FY 2015-16




Table of Contents

1. Namrup Thermal Power Station

1.1 FY 12-13 to 15-16 data ………………………... 150

2. Lakwa Thermal Power Station

2.1. FY 12-13 to 15-16 data ………………………... 152

3. Karbi Langpi Hydro Electric Project

3.1. FY 12-13 to 15-16 data ………………………... 155

4. Lakwa Waste Heat Recovery Power Project

4.1 FY 12-13 to 15-16 data ………………………... 158

5. Namrup Replacement Power Project

5.1 FY 12-13 to 15-16 data ………………………... 161

6. Myntriang Small Hydro Electric Project

6.1 FY 12-13 to 15-16 data ………………………... 163

7.. Chandrapur Thermal Power Station

7.1 FY 12-13 to 15-16 data ………………………... 166




1. Namrup Thermal Power Station

1.1. FY 12-13 to 15-16 Data

NTPSEmployee Expenses

Particulars2012-13

2013-14

2014-15

2015-16

Salaries 12.82 13.59 14.74 15.98

Overtime 0.12 0.41 0.54 0.59

Dearness Allowance 8.64 11.07 12.19 13.21

Other Allowances 2.47 2.64 2.08 2.25

Bonus 0.01 0.01 0.01 0.01

Medical Allowances 0.09 0.10 0.05 0.06

Leave Travel Assistance 0.02 0.04 0.04 0.05

Earned Leave Encashment 0.00 0.09 0.10 0.11

Workmen Compensatory Payment 0.00 0.00 0.00 0.00

Other Staff Cost 0.01 0.00 0.00 0.00

Staff Welfare Expenses 0.04 0.06 0.09 0.09

Terminal Benefits 4.64 2.01 2.46 2.67

Subtotal 28.85 30.03 32.30 35.02

Less: Capitalisation 0.00 0.00 0.00 0.00

Total 28.85 30.03 32.30 35.02


Particulars2012-13

2013-14

2014-15

2015-16

Rent, Rates & Taxes 0.11 0.18 0.12 0.07

Insurance 0.24 0.00 0.00 0.00

Telephone charges 0.05 0.05 0.02 0.01

Postage & Telegrarm 0.00 0.01 0.00 0.00

Legal charges 0.16 0.01 0.01 0.01

Audit fees 0.01 0.01 0.00 0.00

Consultancy charges 0.00 0.03 0.03 0.02

Technical fees 0.00 0.01 0.00 0.00

Other Professional fees 0.02 0.00 0.00 0.00

Conveyance & Travel charges 0.24 0.24 0.22 0.13

Freight 0.02 0.01 0.00 0.00

Other purchase related expenses 1.47 3.22 2.24 1.30

Sub Total: 2.31 3.75 2.65 1.54

Less: Capitalised 0.00 0.00 0.00 0.00

Total: 2.31 3.75 2.65 1.54

Other Income

Particulars2012-13

2013-14

2014-15

2015-16

Interest on Staff Loans and advance 0.00 0.00 0.00 0.00

Income from Investment 2.40 2.95 2.95 2.95




Income from sale of scrap 0.01 0.01 0.01 0.01

Rebate for timely payment 0.22 0.26 0.26 0.26

Misc. receipts (except 62.901 & 62.908) 0.10 0.46 0.46 0.46

Rent from residential building 0.00 0.00 0.00 0.00

Total: 2.72 3.68 3.68 3.68


Particulars2012-13

2013-14

2014-15

2015-16



B. Regular Repair & Maintenance:-Plant & Machinery 6.47 4.42 1.45 1.67

Buildings 0.83 0.78 0.17 0.20

Other civil works 0.04 0.00 0.08 0.09

Hydraulic 0.00 0.00 0.52 0.60

Lines & Cable Network 0.00 0.00 0.00 0.00

Vehicles 0.01 0.00 0.00 0.00

Furniture & fixture 0.00 0.00 0.00 0.00

Office equipment 0.02 0.02 0.07 0.08

Lubricants & Consumable stores 0.00 0.00 0.00 0.00

Turbine Oil 0.00 0.01 0.01 0.01

Total: 7.37 5.23 2.30 16.65

Depreciation

Particulars2012-13

2013-14

2014-15

2015-16

Land & Rights 0.00 0.00 0.00 0.00

Buildings 0.00 0.17 0.17 0.17

Hydraulic 0.01 0.11 0.11 0.11


Plant & Machinery Thermal 1.29 0.08 0.19 0.76

Plant & Machinery Hydel 0.00 0.00 0.00 0.00


Vehicles 0.00 0.12 0.12 0.12

Furniture & fixtures 0.00 0.00 0.06 0.06


Roads on land belonging to others 0.00 0.00 0.00 0.00

Capital spares at generating stations 0.00 0.22 0.26 0.30

Total: 1.37 0.84 1.10 1.77

Depreciation on 90% of the Assets funded by Grants/subsidies -0.43 -0.43 -0.43

Net Total 1.37 0.41 0.67 1.33

Interest & financing charges

Particulars2012-13

2013-14

2014-15

2015-16

Interest on loans 1.83 1.57 1.62 2.63




Other finance charges 1.97 0.02 1.94 2.14

Sub total 3.80 1.58 3.55 4.77

Less: Interest capitalised 0.00 0.00 0.00 0.00

Total 3.80 1.58 3.55 4.77

Interest on working Capital

Particulars2012-13

2013-14

2014-15

2015-16

IWC 6.52 7.39 9.40 7.32

Profit & Loss Account

Particulars2012-13

2013-14

2014-15

2015-16

Power Generation

Energy generated (MU) 533.17 526.57 600.14 342.98

Sale of Power (MU) 503.14 494.98 565.91 324.16

Auxiliary Consumption, Loss % 0.06 0.06 0.06 0.05

INCOME

Revenue from tariff & Misc. charges 167.53 191.59 256.80 200.37

EXPENDITURE

Generation Cost 140.23 146.57 200.05 127.25

R&M Expenses 7.37 5.23 2.30 16.65

Employee Expenses 28.85 30.03 32.30 35.02

A&G Expenses 2.31 3.75 2.65 1.54

Depreciation 1.37 0.41 0.67 1.33

Interest & Finance Charges 3.80 1.58 3.55 4.77

Less: Interest & other expenses capitalised 0.00 0.00 0.00 0.00

Interest on working Capital 6.52 7.39 9.40 7.32Other Debits (incl. Prov. for bad debts, int of W/Capital

etc.) 0.00 0.00 0.00

Extraordinary Items 0.00 0.00 0.00

Other (Misc.) - net prior period credit -10.32 -3.36 0.00 0.00

Total 180.13 191.61 250.92 193.88

ROE 8.86 9.06 9.25 9.86

Other Income 2.72 3.68 3.68 3.68

Provision for taxes 0.35 0.15 0.31 0.31

Annual Revenue Requirement 197.69 197.13 256.80 200.37

Surplus(+) / Shortfall(-) -30.16 -5.54 0.00 0.00

2. Lakwa Thermal Power Station

2.1. FY 12-13 to 15-16 Data

Employee Expenses

Particulars2012-13

2013-14

2014-15

2015-16




Salaries 9.92 10.23 11.09 12.03

Overtime 0.39 0.79 0.85 0.92



Bonus 0.01 0.01 0.01 0.01





Other Staff Cost 0.01 0.00 0.00 0.00



Subtotal 22.46 26.85 28.19 30.55


Total 22.46 26.85 28.19 30.55


Particulars2012-13

2013-14

2014-15

2015-16

Rent, Rates & Taxes 0.08 0.13 0.12 0.13

Insurance 0.11 0.58 0.63 0.68



Legal charges 0.07 0.00 0.00 0.00

Audit fees 0.00 0.01 0.00 0.00


Technical fees 0.01 0.01 0.00 0.00



Freight 0.03 0.01 0.00 0.00


Sub Total: 1.00 3.32 3.46 3.74


Total: 1.00 3.32 3.46 3.74

Other Income

Particulars2012-13

2013-14

2014-15

2015-16







Total: 0.82 3.69 3.69 3.69





Particulars2012-13

2013-14

2014-15

2015-16




Buildings 0.44 0.58 0.03 0.03


Hydraulic 0.18 0.00 0.29 0.33


Vehicles 0.01 0.01 0.13 0.15




Turbine Oil 0.00 0.00 0.00 0.00

Total: 3.15 6.95 15.45 28.35

Depreciation

Particulars2012-13

2013-14

2014-15

2015-16

Land & Rights 0.00 0.00 0.00 0.00

Buildings 0.00 0.08 0.08 0.08

Hydraulic 0.02 0.01 0.01 0.01





Vehicles 0.13 0.00 0.00 0.00





Total: 2.13 3.35 4.07 4.94


Net Total 2.13 3.22 3.94 4.81


Particulars2012-13

2013-14

2014-15

2015-16



Sub total 5.64 3.11 5.04 6.84


Total 5.64 3.11 5.04 6.84


Particulars 2012- 2013- 2014- 2015-




13 14 15 16

IWC 5.12 10.94 12.33 15.13


Particulars2012-13

2013-14

2014-15

2015-16

Power Generation


Sale of Power (MU) 611.18 642.97 640.24 641.58


INCOME


EXPENDITURE

Generation Cost 225.16 238.58 263.30 319.26

R&M Expenses 3.15 6.95 15.45 28.35


A&G Expenses 1.00 3.32 3.46 3.74

Depreciation 2.13 3.22 3.94 4.81




etc.) 0.00 0.00 0.00



Total 254.34 289.62 331.71 408.69

ROE 9.66 10.07 10.67 11.50

Other Income 0.82 3.69 3.69 3.69



Surplus(+) / Shortfall(-) -89.00 -33.38 0.00 0.00

3. Karbi Langpi Hydro-Electric Power Station

3.1. FY 12-13 to 15-16 Data

Employee Expenses

Particulars2012-13

2013-14

2014-15

2015-16

Salaries 4.74 4.89 5.30 5.75

Overtime 0.00 0.00 0.00 0.00



Bonus 0.00 0.01 0.01 0.01





Other Staff Cost 0.00 0.00 0.00 0.00






Subtotal 10.83 13.17 13.46 14.59


Total 10.83 13.17 13.46 14.59


Particulars2012-13

2013-14

2014-15

2015-16

Rent, Rates & Taxes 0.02 0.01 0.12 0.13

Insurance 0.87 0.05 0.05 0.05



Legal charges 0.18 0.01 0.00 0.00

Audit fees 0.01 0.01 0.00 0.00


Technical fees 0.00 0.00 0.00 0.00



Freight 0.00 0.01 0.01 0.02


Sub Total: 2.61 4.28 2.75 2.97


Total: 2.61 4.28 2.75 2.97

Other Income

Particulars2012-13

2013-14

2014-15

2015-16







Total: 2.65 3.23 3.23 3.23


Particulars2012-13

2013-14

2014-15

2015-16




Buildings 0.17 0.27 0.03 0.03


Hydraulic 0.32 0.89 0.29 0.33





Vehicles 0.07 0.04 0.13 0.15




Turbine Oil 0.00 0.19 0.22 0.25

Total: 8.02 12.03 6.69 7.69

Depreciation

Particulars2012-13

2013-14

2014-15

2015-16

Land & Rights 0.00 0.00 0.00 0.00

Buildings 0.74 0.47 0.47 0.47

Hydraulic 4.96 3.11 3.11 3.11





Vehicles 0.00 0.00 0.00 0.00





Total: 13.33 9.67 10.47 10.58


Net Total 13.33 7.56 8.67 8.75


Particulars2012-13

2013-14

2014-15

2015-16



Sub total 16.24 10.86 12.02 11.19


Total 16.24 10.86 12.02 11.19


Particulars2012-13

2013-14

2014-15

2015-16

IWC 2.40 2.34 2.15 2.22


Particulars2012-13

2013-14

2014-15

2015-16

Power Generation


Sale of Power (MU) 342.30 420.40 339.67 388.05





INCOME


EXPENDITURE

Generation Cost 0.12 0.00 0.00 0.00

R&M Expenses 8.02 12.03 6.69 7.69


A&G Expenses 2.61 4.28 2.75 2.97

Depreciation 13.35 7.56 8.67 8.75




etc.) 0.00 0.00 0.00 0.00

Extraordinary Items 0.00 0.00 0.00 0.00


Total 9.18 46.88 45.74 47.41

ROE 9.54 9.54 9.54 9.54

Other Income 2.65 3.23 3.23 3.23



Surplus(+) / Shortfall(-) 40.81 22.06 0.00 0.00

4. Lakwa Waste Heat Recovery Project

4.1. FY 12-13 to 15-16 Data

Employee Expenses

Particulars 2012-13 2013-14 2014-15 2015-16

Salaries 3.08 3.17 3.44 3.73

Overtime 0.12 0.24 0.26 0.29



Bonus 0.00 0.00 0.00 0.00





Other Staff Cost 0.00 0.00 0.00 0.00



Subtotal 6.96 8.32 8.78 9.51


Total 6.96 8.32 8.78 9.51


Particulars 2012-13 2013-14 2014-15 2015-16




Rent, Rates & Taxes 0.02 0.04 0.00 0.00

Insurance 0.03 0.18 0.20 0.21



Legal charges 0.02 0.00 0.00 0.00

Audit fees 0.00 0.00 0.00 0.00


Technical fees 0.00 0.00 0.00 0.00



Freight 0.01 0.00 0.00 0.00


Sub Total: 0.31 1.03 0.44 0.47


Total: 0.31 1.03 0.44 0.47

Other Income

Particulars 2012-13 2013-14 2014-15 2015-16







Total: 1.98 0.00 0.00 0.00


Particulars 2012-13 2013-14 2014-15 2015-16




Buildings 0.14 0.18 0.04 0.05


Hydraulic 0.05 0.00 0.00 0.00


Vehicles 0.00 0.00 0.00 0.00




Turbine Oil 0.00 0.00 0.00 0.00

Total: 0.98 1.77 0.72 0.83

Depreciation

Particulars 2012-13 2013-14 2014-15 2015-16

Land & Rights 0.00 0.00 0.00 0.00




Buildings 0.00 0.00 0.00 0.00

Hydraulic 0.56 0.40 0.40 0.40





Vehicles 0.00 0.00 0.00 0.00





Total: 14.80 13.07 12.92 12.95


Net Total 14.80 11.05 10.90 10.93


Particulars 2012-13 2013-14 2014-15 2015-16



Sub total 16.76 15.64 14.04 12.44


Total 16.76 15.64 14.04 12.44


Particulars 2012-13 2013-14 2014-15 2015-16

IWC 1.79 1.54 1.44 1.44


Particulars 2012-13 2013-14 2014-15 2015-16

Power Generation


Sale of Power (MU) 174.99 174.49 178.42 155.04


INCOME


EXPENDITURE


R&M Expenses 0.98 1.77 0.72 0.83


A&G Expenses 0.31 1.03 0.44 0.47

Depreciation 14.80 11.05 10.90 10.93




etc.) 0.00 0.00 0.00





Other (Misc.) - net prior period credit 0.00 0.00 0.00

Total 41.61 39.35 36.32 35.62

ROE 9.93 9.93 9.93 9.93

Other Income 1.98 0.00 0.00 0.00



Surplus(+) / Shortfall(-) 1.71 -32.04 0.00 0.00

5. Namrup Replacement Power Project5.1. FY 12-13 to 15-16 Data

Employee Expenses

Particulars2012-13

2013-14

2014-15

2015-16

Salaries 0.00 0.00 0.00 7.30

Overtime 0.00 0.00 0.00 0.27



Bonus 0.00 0.00 0.00 0.01





Other Staff Cost 0.00 0.00 0.00 0.00



Subtotal 0.00 0.00 0.00 16.01


Total 0.00 0.00 0.00 10.67


Particulars2012-13

2013-14

2014-15

2015-16

Rent, Rates & Taxes 0.00 0.00 0.00 0.06

Insurance 0.00 0.00 0.00 0.00



Legal charges 0.00 0.00 0.00 0.01

Audit fees 0.00 0.00 0.00 0.00


Technical fees 0.00 0.00 0.00 0.00



Freight 0.00 0.00 0.00 0.00


Sub Total: 0.00 0.00 0.00 1.33





Total: 0.00 0.00 0.00 0.89

Other Income

Particulars2012-13

2013-14

2014-15

2015-16







Total: 0.00 0.00 0.00 0.00


Particulars2012-13

2013-14

2014-15

2015-16


Overhauling Works 0.00 0.00 0.00 0.00


Buildings 0.00 0.00 0.00 0.00


Hydraulic 0.00 0.00 0.00 0.00


Vehicles 0.00 0.00 0.00 0.00




Turbine Oil 0.00 0.00 0.00 0.00

Total: 0.00 0.00 0.00 0.00

Depreciation

Particulars2012-13

2013-14

2014-15

2015-16

Land & Rights 0.00 0.00 0.00 0.00

Buildings 0.00 0.00 0.00 0.00

Hydraulic 0.00 0.00 0.00 0.00





Vehicles 0.00 0.00 0.00 0.00





Total: 0.00 0.00 0.00 18.05

Depreciation on 90% of the Assets funded byGrants/subsidies 0.00 0.00 0.00 -3.26




Net Total 0.00 0.00 0.00 14.78


Particulars2012-13

2013-14

2014-15

2015-16




Sub total 5.07 17.02 26.40 43.64

Less: Interest capitalised -5.07 -17.02 -26.40 -14.55

Total 0.00 0.00 0.00 29.09

Particulars2012-13

2013-14

2014-15

2015-16

Interest on working capital per AERC 0.00 0.00 0.00 4.39


Particulars2012-13

2013-14

2014-15

2015-16

Power Generation


Sale of Power (MU) 0.00 0.00 0.00 281.57


INCOME


EXPENDITURE

Generation Cost 0.00 0.00 0.00 75.41

R&M Expenses 0.00 0.00 0.00 0.00


A&G Expenses 0.00 0.00 0.00 0.89

Depreciation 0.00 0.00 0.00 14.78

Interest & Finance Charges 5.07 17.02 26.40 43.64Less: Interest & other expenses

capitalised -5.07 -17.02 -26.40 -14.55

Interest on working Capital 0.00 0.00 0.00 4.39Other Debits (incl. Prov. for bad debts,

int of W/Capital etc.)0.00

0.00 0.00 0.00


Other (Misc.) - net prior period credit 0.00 0.00 0.00 0.00

Total 0.00 0.00 0.00 135.24

ROE 0.00 0.00 0.00 14.57

Other Income 0.00 0.00 0.00 0.00



Surplus(+) / Shortfall(-) 0.00 0.00 0.00 0.00

6. Myntriang SHEP

6.1. FY 12-13 to 15-16 Data




Employee Expenses

Particulars 2012-13 2013-14 2014-15 2015-16

Salaries 0.30 0.28 0.30 1.49

Overtime 0.00 0.00 0.00



Bonus 0.00 0.00 0.00








Subtotal 0.56 0.60 0.63 3.06


Total 0.00 0.60 0.63 1.47


Particulars 2012-13 2013-14 2014-15 2015-16


Insurance 0.00 0.00 0.00




Audit fees 0.00 0.00 0.00





Freight 0.10 0.00 0.00 0.00


Sub Total: 0.12 0.10 0.09 0.50


Total: 0.00 0.10 0.09 0.24

Other Income

Particulars 2012-13 2013-14 2014-15 2015-16







Total: 0.00 0.00 0.00 0.00





Particulars 2012-13 2013-14 2014-15 2015-16


Overhauling Works 0.00 0.00 0.00 0.00


Buildings 0.00 0.00 0.00 0.00


Hydraulic 0.00 0.00 0.00 0.00


Vehicles 0.00 0.00 0.00 0.00




Turbine Oil 0.00 0.00 0.00 0.00

Total: 0.00 0.03 0.03 0.03

Depreciation

Particulars 2012-13 2013-14 2014-15 2015-16

Land & Rights 0.00 0.00 0.00 0.00

Buildings 0.00 0.00 0.00 0.01

Hydraulic 0.00 0.18 0.37 0.59





Vehicles 0.00 0.00 0.00 0.00





Total: 0.00 0.42 0.84 1.75

Depreciation on 90% of the Assets funded byGrants/subsidies

0.00-0.70 -1.75 -2.48

Net Total 0.00 -0.28 -0.91 -0.73


Particulars 2012-13 2013-14 2014-15 2015-16



Sub total 0.00 0.28 0.95 0.84

Less: Interest capitalised 0.00 -0.26 -0.63 -0.37

Total 0.00 0.02 0.32 0.47


Particulars 2012-13 2013-14 2014-15 2015-16




IWC 0.00 0.02 0.07 0.13


Particulars 2012-13 2013-14 2014-15 2015-16

Power Generation

Energy generated (MU) 0.00 4.43 41.59

Sale of Power (MU) 0.00 4.39 41.17

Auxiliary Consumption, Loss % 0.00 0.01 0.01

INCOME

Revenue from tariff & Misc. charges 0.00 1.96 4.87

EXPENDITURE

Generation Cost 0.00 0.00 0.00

R&M Expenses 0.03 0.03 0.03

Employee Expenses 0.60 0.63 1.47

A&G Expenses 0.10 0.09 0.24

Depreciation -0.28 -0.91 -0.73

Interest & Finance Charges 0.28 0.95 0.84Less: Interest & other expenses

capitalised -0.26 -0.63 -0.37

Interest on working Capital 0.02 0.07 0.13Other Debits (incl. Prov. for bad debts,

int of W/Capital etc.) 0.00 0.00 0.00


Other (Misc.) - net prior period credit 0.00 0.00 0.00

Total 0.49 0.23 1.60

ROE 0.79 1.72 3.27

Other Income 0.00 0.00 0.00

Provision for taxes 0.00 0.00 0.00

Annual Revenue Requirement 1.27 1.96 4.87

Surplus(+) / Shortfall(-) -1.27 0.00 0.00

7. Chandrapur Thermal Power Station

7.1. FY 12-13 to 15-16 Data

Employee Expenses

Particulars2012-13

2013-14

2014-15

2015-16

Salaries 1.79 1.64 1.78 1.93

Overtime 0.00 0.00 0.00 0.00



Bonus 0.00 0.00 0.00 0.00





Other Staff Cost 0.00 0.00 0.00 0.00






Subtotal 3.01 3.02 3.18 3.45


Total 3.01 3.02 3.18 3.45

Particulars2012-13

2013-14

2014-15

2015-16

Rent, Rates & Taxes 0.00 0.00 0.00 0.00

Insurance 0.00 0.00 0.00 0.00



Legal charges 0.00 0.00 0.00 0.00

Audit fees 0.00 0.00 0.00 0.00


Technical fees 0.00 0.00 0.00 0.00



Freight 0.00 0.00 0.00 0.00


Sub Total: 0.15 0.06 0.02 0.01


Total: 0.15 0.06 0.02 0.01

Other Income

Particulars2012-13

2013-14

2014-15

2015-16







Total: 0.00 0.00 0.00 0.00


Particulars2012-13

2013-14

2014-15

2015-16




Buildings 0.00 0.00 0.00 0.00


Hydraulic 0.00 0.00 0.00 0.00





Vehicles 0.00 0.00 0.00 0.00




Turbine Oil 0.00 0.00 0.00 0.00

Total: 0.00 0.03 0.00 0.00

Depreciation

Particulars2012-13

2013-14

2014-15

2015-16

Land & Rights 0.00 0.00 0.00 0.00

Buildings 0.00 0.00 0.00 0.00

Hydraulic 0.00 0.00 0.00 0.00





Vehicles 0.00 0.00 0.00 0.00





Total: 0.00 0.00 0.00 0.00Depreciation on 90% of the Assets funded by Grants/subsidies 0.00 0.00 0.00

Net Total 0.00 0.00 0.00 0.00


Particulars2012-13

2013-14

2014-15

2015-16



Sub total 0.09 0.05 0.05 0.04


Total 0.09 0.05 0.05 0.04


Particulars2012-13

2013-14

2014-15

2015-16

IWC 0.00 0.00 0.00 0.00


Particulars2012-13

2013-14

2014-15

2015-16

Power Generation


Sale of Power (MU) 0.00 0.00 0.00 0.00


INCOME






EXPENDITURE


R&M Expenses 0.11 0.03 0.00 0.00


A&G Expenses 0.15 0.06 0.02 0.01

Depreciation 0.00 0.00 0.00 0.00




etc.) 0.00 0.00 0.00 0.00


Other (Misc.) - net prior period credit 0.00 0.00 0.00 0.00

Total 3.35 3.16 3.24 3.50

ROE 0.00 0.00 0.00 0.00

Other Income 0.00 0.00 0.00 0.00


Annual Revenue Requirement 3.35 3.16 3.24 3.50Surplus(+) / Shortfall(-) -3.35 -3.16 0.00 0.00




APPEAL FOR TRUE-UP FOR THE FINANCIAL YEAR2013-14

To


By


Guwahati-781 001




13.0. APPEAL FOR TRUING UP FOR FY 2013-14

Table 36:

Particulars

ApprovedTariff

Order 13-14

Amountappearedin AnnualAccounts

13-14

Amountclaimedfor True-

Up

Remarks

Energy generated (MU) 1786.40 1845.228 1845.23

Sale of Power (MU) 1713.76 1732.847 1732.85

Auxiliary Consumption, Loss % 4.07% 6.09% 6.09%

INCOME

Revenue from tariff & Misc. charges 483.95 547.05 544.49Revenue from Secondary Energy Charges ofKLHEP 2.51

Total revenue from Sale of Power 547.00 ***

Other Income 10.99 10.55 10.60 ^^^Total revenue income 494.94 557.60 557.60

EXPENDITURE

Cost of fuel 289.45 385.36 385.15 @@

Employee Expenses 78.12 82.00 82.00


26.03 $$Lubricants & Consumable stores 1.23

Total R& M Expenses 14.91 25.83

A&G Expenses 5.93 12.53 12.53 ++

Depreciation 16.35 28.68 21.95 ##

Interest & Finance Charges 30.90 43.96 31.27 %%

Provision for taxes 0.93 0.45 0.45 !!

Prior period items 84.15 -10.07 &&

ROE 37.99 39.38

Interest on working Capital 18.25 22.23

Total Revenue Requirement 494.94 688.79 610.93


Add: Incentive for Secondary Energy generationfor FY 2013-14 2.51

Gross Expenditure 494.94 688.79 619.42

Surplus(+) / Shortfall(-) 0 -131.19 -61.82

Note:

I Auxiliary Consumption: Actual APC of LTPS and NTPS for 2013-14 againstnormative APC is as given below:

Power StationNormative

APCActual APCfor 2013-14

APC as per APGCL’sPetition for Review of

Normative APCLTPS 5.5% 8.78% 7.50%NTPS 4.5% 6.00%. 5.50%

KLHEP 0.50% 0.50% 0.50%APGCL Total 4.07% 6.09% 5.33%




The Actual APC of APGCL is higher than the normative APC. Reason for thishas already been explained in details in the Section 3.2 at Page No. 22 to 32above. The actual APC of APGCL for 2013-14 is 6.09%. However, it comesdown to 5.33% if the APC of LTPS and NTPS are considered as per APGCL’sPetition for review of normative APC of LTPS and NTPS. In view of this, APGCLappeals to AERC to consider APC of APGCL as 5.33%.for the True-up of 2013-14.

II Station Heat Rate: Actual Station Heat Rate of LTPS & NTPS against the HeatRate given by AERC in the Draft amendment of AERC (Terms and Conditionsfor Determination of Tariff) Regulations 2006 is as given below:

Station Actual Gross Heat Rateon GCV basis in 2013-

14 (kcal/kWh)

Heat Rate as perAERC’s Draft Amended

Regulation(kcal/kWh)

LTPS with WHRU 3164 3200NTPS 3976 4170

Actual Station Heat Rates of LTPS and NTPS are more or less similar with thatof the Draft Amended Regulation of AERC. In view of this, APGCL appeals toconsider the actual Heat Rates of LTPS and NTPS in the True-up of 2013-14.

III *** Note 21 of Annual Accounts 13-14 includes as follows:-

a. Sale of Power (ASEB) 547.00

b. Sale of scrap 0.06

Total Revenue from operation appeared in Profit & Loss Account 13-14547.05

(less):- Sale of Scrap 0.06

Total Revenue from tariff and Misc Charges claimed for true up547.00

A statement of Month wise bill from Sale of Power is provided below:



Fixed Charge

AMOUNT NTPS LTPS Total NTPS (AMOUNT) LTPS (AMOUNT) Total

April'13 18,76,50,000.00 3,73,84,019.40 8,73,34,048.62 12,47,18,068.02 - 5,21,25,807.31 7,17,88,209.73 12,39,14,017.04 43,62,82,085

May'13 18,76,50,000.00 4,05,47,033.80 8,96,91,153.30 13,02,38,187.10 - 6,01,32,094.92 7,43,66,873.28 13,44,98,968.20 45,23,87,155

June'13 18,76,50,000.00 3,34,25,319.20 7,55,96,672.34 10,90,21,991.54 - 4,62,10,236.27 6,85,22,499.32 11,47,32,735.59 41,14,04,727

July'13 18,76,50,000.00 3,49,35,482.40 7,66,44,203.58 11,15,79,685.98 - 5,27,57,623.46 7,97,59,202.84 13,25,16,826.30 43,17,46,512

August'13 18,76,50,000.00 3,45,57,377.40 7,14,11,749.92 10,59,69,127.32 - 5,39,72,526.02 7,63,31,518.53 13,03,04,044.55 42,39,23,172

September'13 18,76,50,000.00 3,17,85,117.00 7,29,91,560.60 10,47,76,677.60 - 5,37,01,302.01 8,47,94,029.58 13,84,95,331.59 43,09,22,009

October'13 18,76,50,000.00 3,74,96,113.20 8,64,63,228.60 12,39,59,341.80 - 6,48,68,137.86 10,07,67,633.94 16,56,35,771.80 47,72,45,114

November'13 18,76,50,000.00 3,57,91,228.20 9,64,15,023.60 13,22,06,251.80 - 6,06,15,545.96 9,81,20,705.79 15,87,36,251.75 47,85,92,504

December'13 17,12,41,666.67 9,97,85,268.00 17,46,47,322.30 27,44,32,590.30 - 1,32,61,841.36 2,15,61,364.98 3,48,23,206.34 48,04,97,463

January'14 17,12,41,666.67 10,14,66,068.00 17,96,52,905.04 28,11,18,973.04 - 1,17,41,064.85 3,06,83,701.67 4,24,24,766.52 49,47,85,406

January'14 - 52,18,526.25 52,18,526

February'14 17,12,41,666.67 10,72,87,928.00 13,48,28,634.18 24,21,16,562.18 84,26,180.39 1,96,65,524.84 2,26,69,054.04 4,23,34,578.88 46,41,18,988

March'14 17,12,41,666.67 8,91,87,252.00 16,88,68,211.64 25,80,55,463.64 79,59,218.93 1,45,03,819.70 2,75,44,637.82 4,20,48,457.52 47,93,04,807

Additional for FY 13-14 - 35,30,043.09 35,30,043

TOTAL 2,18,61,66,666.68 68,36,48,206.60 1,31,45,44,713.72 1,99,81,92,920.32 2,51,33,968.66 50,35,55,524.56 75,69,09,431.52 1,26,04,64,956.08 5,46,99,58,512

MONTHWISE BILL FOR SALE OF POWER

For The Year 2013-14

MONTHVariable Charge

Secondary ChargeFPA Bill

Total SOP




IV ^^^ Other Income appeared in Profit and Loss A/c 13-14 10.55

Add:- Sale of Scrap appeared in Note 21 of Annual Accounts 13-14 0.06

Total Other Income claimed 10.60

V @ Cost of fuel detailed in Note 24 of Annual Accounts is as follows:

a. Gas 29.86

b. Gas/Oil (Internal Combustion) 355.50

Total 385.36

The Gas/Oil (internal combustion) includes Rs. 0.20 Crore towards Oil (Internal Combustion) which is nowclaimed in Repair & Maintenance. An abstract from Quarterly Trial Balance is Annexed at Annexure-A

VI $$ 1. Repair & Maintenance claimed in true up as follows:-

Note 27 of Annual Accounts 13-14 24.60

(+) Lubricants and consumable stores (Note 24 of Annual Accounts) 1.23

(+)Oil (Internal Combustion) ( Refer Note V) 0.20

Total R& M Expenses Claimed 26.032.

During FY 13-14 there was an expenditure for the Overhauling of Karbi LangpiHEP Unit #2 of Rs. 9.03 Cr. the Overhauling work was approved by theCommission in the following breakup:In the Tariff Order for 13-14: Rs. 4.10 Cr.In the Review Order of 13-14: Rs. 12.73 Cr.Total Overhauling amount: Rs. 16.83 Cr.Further there was an expenditure of Rs. 5.77 Cr for LTPS for procurement ofPlant & Machinery spares.Moreover while approving R&M for FY 13-14 @ Rs. 14.91 does not includeLubricants & consumables and Turbine Oil expenses, which is now in additionto normal R&M expenses claimed in the true up.

VII ++ The Hon’ble Commission has approved an amount of Rs. 5.93 for FY 13-14.However, during FY 13-14 an amount of Rs. 5.78 Cr has been further provided forElectricity Bill of Different Offices of APGCL to be paid to APDCL in addition tonormal A&G expenses in the annual accounts, which resulted in increase in A&Gexpenses compared to previous year and than that approved by the Commission.

VIII ## Depreciation Calculated at norms specified by Hon'ble AERC.

IX %%

1. Sanction letters of Loans from GOA received up to FY 13-14 is provided atAnnexure-B

2. Interest rate considered for State Govt. Loan is provided at Annexure-C3. Loan drawl from PFCL during FY 13-14 is provided at Annexure-D4. Interest and repayments made to PFCL during FY 13-14 and for FY 14-15

(up to Dec’14) is provided at Annexure-E5. Moreover as the GPF trust is not formed till FY 13-14, no interest on GPF

claimed for that FY in true up.

X !! APGCL incurred Taxes on account of TDS on investments. Relevant TDS certificatesare Annexed at F

XI && Prior Period items appeared in Annual Accounts and claimed in True-up for FY 2013-14 is detailed below:



Appeared in

Annual

Accounts

Claimed in

True up Remarks(a) Prior period income includes:-

207846329 0.00 The said amount was not considered in earlier tariff orders by theHonble Commission in earlier tariff orders , hence not claimed.

40429489 0.00 The withdrawal of excess provision of bond repayment is a capital itemand does not form part of any component of ARR , hence not takeninto consideration

17363728 0.00 The Hon'ble Commission allowed provision for taxes on submission ofpayment challans for taxes and did not considered provision madeagainst "Assam Building & Other Constuction workers welfare cess in

earlier tariff orders and hence the said amount is not claimed.

15837047 0.00 The adjustment relates to oil stock which does not form of anycomponent of ARR, hence not claimed in Prior period income:

100484453 100484453

953971 0.00 The said amount was not considered in earlier tariff orders by theHonble Commission in earlier tariff orders , hence not claimed.

1315 1315

1030296 1030296

383946628 101516064

759224 759224

55711893 0.00 The amount of LD recovered from BHEL is adjusted with Asset anddoes not form part of any component of ARR , hence not claimed in

prior period expense. However the effect of same is considered whilecomputing Depreciation.

1168900000 0.00 Revenue surplus of Rs.96.38 crore for 09-10 and Rs.20.51 crore for 10-11 arrived by AERC while truing up adjusted as per comment C&AGNo.C.1

93547 93547

1225464664 852771Net Prior Period 841518036 -100663293

Details of Prior Period Items

vii) Interest income for prior period

(iiI) Revenue surplus of Rs.96.38 crore for 09-10 and Rs.20.51 crore for 10-11 arrived by AERC while truing up

adjusted as per commnent C&AG No.C.1

Subtotal (a)

(i) withdrawl of excess provision of interest on public bond as per C&AG's comment No.A.1 by Rs. 20,78,46,329/-

for periods 2005-06 to 2009-10

(ii) withdrawl of excess provision of bond repayment issued via warrant by Rs. 4,04,29,489/-.

Subtotal (b)

iv) Other charges relating to Prior Period

(iii) withdrawl of provision made against "Assam Building & other Construction Workers Welfare Cess" in prior

period as per C&AG commnent No.A.04 by Rs.1,73,63,728/-.

(iv) withdrawl of adjustment Jv. No.21 of FY 2012-13 as per POS-11 of C&AG audit by Rs.1,58,37,047/-.

(v) withdrawl of excess provision of ROP arrear for FY 09-10

(vi) withdrawl of ADB loan interest accounted in prior period

(ii) LD recovered from BHEL against LWHRP booked as other income now rectified & adjusted with asset as per

commnent C&AG No.A.03 by Rs.5,57,11,893/-

i) Operating expenses for Prior Period (KLHEP)(b) Prior period expense includes:-

viii) Other income relating to prior period



ENERGY CHARGE OF APGCL: 2013-14

STATION Apr/13 May/13 Jun/13 Jul/13 Aug/13 Sep/13 Oct/13 Nov/13 Dec/13 Jan/14 Feb/14 Mar/14 TotalEnergyCharge

(Rs./kWh)

Lakwa TPS + WHRP

Fuel Quantity (MMSCM) 26.41 26.64 23.40 21.92 21.99 23.11 23.45 25.21 26.70 27.76 24.10 25.32 296.00

2.92Fuel Cost Rs. in Cr. 18.84 19.05 17.47 17.99 17.96 19.71 19.96 20.89 22.30 23.09 20.19 21.10 238.56

Energy Sent Out (MU) 69.31 71.18 60.00 60.83 56.68 57.93 68.62 76.52 78.67 80.93 60.73 76.07 817.47

Namrup TPS

Fuel Quantity (MMSCM) 20.18 20.69 17.60 17.43 17.82 17.59 17.52 16.36 20.04 20.91 21.98 17.77 225.90

2.96Fuel Cost Rs. in Cr. 11.75 12.54 10.24 11.21 11.33 11.68 11.81 10.84 13.36 13.78 15.67 12.38 146.57

Energy Sent Out (MU) 41.08 44.56 36.73 38.39 37.98 34.93 41.20 39.33 45.36 46.12 48.77 40.54 494.98



Incentive computation for thermal stations for FY 2013-14

SI.

No.

Sta

tion

Inst

alle

dCapaci

ty(M

W)

Targ

et

PLF

for

allo

win

g

ince

ntive

(%)

Gro

ssG

enera

tion

with

targ

et

PLF

(MU

)

Appro

ved

aux.

consu

mption(%

)

Net

genera

tion

with

targ

et

PLF

(MU

)

Act

ualPLF

Gro

ssG

enera

tion(A

ctual)

(MU

)

Act

ualaux.

consu

mption(%

)

Net

Genera

tion

(Act

ual)

(MU

)

Ex-

bus

energ

yelig

ible

for

ince

ntive

Ince

ntive

Rs

Cro

re

1 2 3 4 5 6 6 8 9 10=(9-5) 11=25paise x

10

1 NTPS 119.5 50% 523.41 4.50% 499.857 50.30% 526.568 6.00% 494.985 -4.872 0.00

2 LTPS 157.2 50% 688.54 5.50% 650.667 65.08% 896.150 8.78% 817.465 166.799 4.17

Total 1150.523 1422.718 1312.450 4.17

Note: For NTPS the incentive is negative, hence it set to zero

Incentive computation for Hydro station for FY 2013-14

SI.

No.

Sta

tion

Capaci

tyof

KLH

EP

Targ

et

Capaci

tyIn

dex

Act

ualCapaci

tyIn

dex

Capaci

tyof

APG

CL

(MW

)

AnnualFix

ed

Charg

es

of

APG

CL

(Rs

Cro

re)

AnnualFix

ed

Charg

es

of

KLH

EP

(Rs

Cro

re)

Ince

ntive

in(R

sCro

re)

1 2 3 4 5 6 7=(2x6)/5 8= 0.65 x(4-3) x 7

1 KLHEP 100 90% 95.10% 376.7 205.48 54.55 1.81




Certificate for Energy Generation of APGCL for FY 2013-14 from SLDC




PETITION FOR APPROVAL FOR ANNUALPERFORMANCE REVIEW FOR THE FINANCIAL

YEAR 2014-15

To


By


Guwahati-781 001




14 APPEAL FOR ANNUAL PERFORMANCE REVIEW OF 2014-15

14.1 InvestmentsTable 37

Investment (13-14)

(Rs. in Crore)Investment SOURCE 2013-14

LTPS State Govt. equity


State Govt. Grant

PFC Loan

OthersKLHEP State Govt. equity


State Govt. Grant

PFC Loan

OthersNRPP State Govt. equity

State Govt. Loan

State Govt. Grant

PFC Loan 50.00

OthersMARGHERITA TPP State Govt . Equity


State Govt. Grant

PFC Loan

OthersMYNTRIANG State Govt . Equity


State Govt. Grant

PFC Loan

OthersKLHEP (Upper Stage) State Govt . Equity


State Govt. Grant

PFC Loan

OthersKLHEP (Inter.Stage-I) State Govt . Equity


State Govt. Grant

PFC Loan

OthersKLHEP (Inter.Stage-II) State Govt . Equity


State Govt. Grant

PFC Loan

OthersKLHEP Barrage ToeProject

State Govt . Equity


State Govt. Grant




PFC Loan

Others70 MW LRPP State Govt . Equity


State Govt. Grant

PFC Loan

Others

Others

TOTAL




PFC Loan 50.00

Others 0.00

68.57

14.2 The following tables highlight the individual’s details of each expense for FY 12-13 &13-14.

14.2.1 Employees Expenses for FY 12-13 & 13-14

Table 38


Salaries 33.06 33.81

Overtime 0.63 1.44

Dearness Allowance 21.96 27.12

Other Allowances 6.37 6.93

Bonus 0.02 0.03

Medical Allowances 0.19 0.18

Leave Travel Assistance 0.04 0.05

Earned Leave Encashment 0.18 0.27

Workmen Compensatory Payment 0.00 0.00

Other Staff Cost 0.02 0.01


Terminal Benefits 11.11 12.04

Subtotal 73.80 82.00

Less: Capitalisation 1.67 0.00

Total 72.11 82.00

14.2.2 Repairs & Maintenance for FY 12-13 & 13-14

Table 39



Overhauling Works 0.00 0.00

B. Regular Repair & Maintenance:-Plant & Machinery 16.12 20.60

Buildings 1.57 1.81


Hydraulic 0.55 0.89





Vehicles 0.09 0.06

Furniture & fixture 0.22 0.26


Lubricants & Consumable stores 0.00 1.23

Turbine Oil 0.00 0.20

Total: 19.62 26.03

14.2.3 Administration and General Expenses for FY 12-13 & 13-14


Rent, Rates & Taxes 0.23 0.35

Insurance 1.25 0.81

Telephone charges 0.13 0.12

Postage & Telegrarm 0.00 0.01

Legal charges 0.43 0.02

Audit fees 0.02 0.02

Consultancy charges 0.04 0.60

Technical fees 0.01 0.02

Other Professional fees 0.05 0.07

Conveyance & Travel charges 0.70 0.76

Freight 0.15 0.04

Other purchase related expenses 3.48 9.72

Energy bill raised by APDCL 0.00 0.00

Sub Total: 6.50 12.53

Less: Capitalised 0.12 0.00

Total: 6.38 12.53

14.2.4. Income from Other Sources for FY 12-13 & 13-14

Table 41


Interest on Staff Loans and advance 0.00 0.00

Income from Investment 5.96 8.85

Income from sale of scrap 0.03 0.06

Rebate for timely payment 0.69 0.79

Misc. receipts (except 62.901 & 62.908) 1.50 0.90

Rent from residential building 0.01 0.01

Total: 8.17 10.60

14.2.5. Depreciation for FY 12-13 & 13-14



Buildings 0.74 0.72

Hydraulic 5.55 3.82


Plant & Machinery Thermal 15.75 11.93

Plant & Machinery Hydel 4.50 4.27


Vehicles 0.13 0.12

Furniture & fixtures 0.04 0.00





Roads on land belonging to others 0.00 0.00

Capital spares at generating stations 0.55 3.20

Total 31.66 27.35

(Less) : Depreciation on 90% of the Assets funded byGrants/subsidies -5.39

Net Total 31.66 21.95

Note: Sanction Letters of Grant received by APGCL are annexed at G.Statement of Grant received by APGCL is provided below:

Sl.No. FY Project for Type of grant Amount Remarks

1.00 2004-05 Lungnit SHEP MNRE 18000000.00 Work in progress2.00 2005-06 LWHRP State Govt. grant 450000000.00 Capital asset

3.00 2006-07 Myntriang SHEP NABARD 92289000.00 Work in progress4.00 2006-07 KLHEP State Govt. grant 100000000.00 Capital asset

5.00 2006-07 KLHEP & LWHRP State Govt. grant LWHRP 165000000.00 Capital asset

6.00 KLHEP 416570000.006.00 2008-09 Namrup RPP State Govt. grant 300000000.00 Work in progress7.00 2009-10 Myntriang SHEP NABARD 150000000.00 Work in progress8.00 2009-10 Lungnit SHEP MNRE 18000000.00 Work in progress

9.00 2009-10 Lungnit SHEP MNRE 18000000.00 Work in progress

10.00 2009-10 Namrup RPP State Govt. grant 122500000.00 Work in progress11.00 2009-10 LTPS State Govt. grant 40000000.00 Capital asset

12.00 2009-10 NTPS State Govt. grant 10000000.00 Capital asset

13.00 2009-10 KLHEP State Govt. grant 30000000.00 Capital asset14.00 2009-10 Lungnit SHEP NEC 15000000.00 Work in progress

15.00 2009-10 Amring SHEP NEC 4000000.00 Work in progress

16.00 2010-11 Namrup RPP State Govt. grant 270000000.00 Work in progress17.00 2010-11 Myntriang SHEP NABARD 36153000.00 Work in progress

18.00 2011-12 Namrup RPP State Govt. grant 609750000.00 Work in progress19.00 2011-12 Lower Kopili HEP State Govt. grant 50000000.00 Work in progress20.00 2012-13 Namrup RPP State Govt. grant 616950000.00 Work in progress

21.00 2012-13 Myntriang SHEP NABARD 150000000.00 Work in progress22.00 2012-13 KLHEP State Govt. grant 190000000.00 Capital assetTotal 3872212000.00

11839991.00108447500.00

3992499491.00

LWHRP 615000000.00KLHEP 736570000.00NTPS 130287491.00LTPS 40000000.00

Grants & Subsidies on Work in progress as on 01.04.13 2470642000.00

2012-13

Add : ADB grantAdd: Donated Capital Assets

Total Capital Reserve as on 31.03.13

581570000.00

1521857491.00

Grants & Subsidies on Capital Assets

as on 01.04.13




Cummulative grant received by APGCL as on 01.04.13 3992499491.00Less : Transfer of capital grant to revenue grant as per commnent C&AG No.A.02) -190000000.00 Capital asset

Add: ADB loan to ADB grant as per order No.PEL.112/2005/54 dtd. 29/03/08) 1315554.00 Capital asset

Cummulative grant received by APGCL as on 01.04.14 3803815045.00

LWHRP 615000000.00KLHEP 546570000.00NTPS 131603045.00LTPS 40000000.00Myntriang

SHEP 428442000.00

Grants & Subsidies on Work in progress as on 01.04.14 2042200000.00Cummulative grant received by APGCL as on 01.04.14 3803815045.00

Sl.No. FY Project for Type of grant Amount Remarks

Cummulative grant received by APGCL as on 01.04.14 3803815045.001.00 2013-14 Namrup RPP State Govt. grant 68550000.00 Work in progress

2.00 2013-14 Myntriang SHEP State Govt. grant 100000000.00 Capital asset

3.00 2013-14 Myntriang SHEP State Govt. grant 33000000.00 Capital asset

4.00 2014-15Myntriang Small Hydro

Electric Project State Govt. grant 70000000.00 Capital asset

5.00 2014-15

SD for slope stabilisation

of Hatidubi KLHEP Dam

damaged due to flood State Govt. grant 7475000.00 Capital asset

6.00 2014-15

SD for procurement/

acquisition of Land for

Cachar distributed

generation system by Gas State Govt. grant 8250000.00 Work in progress

7.00 2014-15

SD for procurement/

acquisition of Land for

Titabor Power project State Govt. grant 4870000.00 Work in progress



MyntriangSHEP 638917000.00


Sl.No. FY Project for Type of grant Amount RemarksCummulative grant received by APGCL as on 01.04.15 4095960045.00

1.00 2015-16Myntriang Small Hydro

Electric Project State Govt. grant 235000000.002.00 2015-16 Karbi Langpi Hydel Electric Project 16700000.00



Myntriang SHEP873917000.00NRPP 1987750000.00


1972090045.00Grants & Subsidies on Capital Assets

as on 01.04.15

2014-15

2013-14

4211540045.00

NRPP commissioned in

FY 2015-16. WIP Grants

converted to Capital grantGrants & Subsidies on Capital Assets

as on 01.04.16

2015-16

Grants & Subsidies on Capital Assets

as on 01.04.141761615045.00

Myntriang SHEP

commissioned in FY 2013-

14. WIP Grants converted

to Capital grant




14.2.6 Repayment of Loan (Principal) for FY 12-13 & 13-14


PFC Loan 22.97 22.97

State Govt Loan 0.00 0.00

Total 22.97 22.97

14.2.7. Interest & financing charges


Interest on loans 44.30 50.68

Other finance charges 4.96 0.05

Sub total 49.26 50.73

Less: Interest capitalised -6.73 -19.46

Total 42.53 31.27

14.2.8 Interest on Working CapitalTable 45:

Particulars 2012-13 2013-14One month Fuel Cost 26.14 32.10One month approved O&M Cost 7.69 9.79Maintenance Spares 12.13 12.48Two month Receivables 104.37 96.33Total 150.33 150.70Interest @ 14.00 % for 12-13 & 14.75% for 13-14 21.05 22.23

Note: Interest on Normative working capital as per AERC

14.2.9. Profit & Loss account for 2012-13 & 2013-14


Power Generation

Energy generated (MU) 1765.26 1845.23

Sale of Power (MU) 1631.60 1732.85

Auxiliary Consumption, Loss % 7.57% 6.09%

INCOME

Revenue from tariff & Misc. charges 459.66 547.00


EXPENDITURE

Generation Cost 365.50 385.15


Employee Expenses 72.11 82.00

A&G Expenses 6.38 12.53

Depreciation 31.66 21.95

Interest & Finance Charges 49.26 50.73

Less: Interest & other expenses capitalised -6.73 -19.46

Interest on working Capital 15.83 22.23




Other Debits (incl. Prov. for bad debts, int of W/Capitaletc.) 0.00 0.00

Extraordinary Items 0.00 0.00

Other (Misc.) - net prior period credit -65.02 -10.07

Total 488.61 571.10

ROE 37.99 39.38

Other Income 8.17 10.60

Provision for taxes 0.50 0.45

Annual Revenue Requirement 539.65 600.33


Add: Incentive for Secondary Energy generation forFY 2011-12 2.51

Surplus(+) / Shortfall(-) -79.99 -61.82




14.2.10 Balance Sheet for FY 12-13 & 13-14

Table 47:


Source of Fund

Share Capital 455.86 455.86

Reserve & Surplus 30.45 36.33

Loans from State Govt 117.21 135.78

Loans from others 374.39 405.49

Total 977.91 1033.47

Contributions, grants & subsidies towards cost of Capital Asset 399.25 380.38

Grand Total 1377.16 1413.85

Application of Fund

Net Fixed Assets

(A) Gross Block 1284.44 1325.74

(B) Less : Accumulated Depreciation 597.70 626.38

(C) Net Fixed Assets 686.74 699.36

(D) Capital-works-in-progress 565.93 568.98


(F) Deferred Cost

(G) Intengible Asset

Total of (C) to (G) 1252.67 1268.34

Investements 0.00 0.00


Net Current Assets


i) Inventories 58.23 68.25

ii) Receivables against Sale of Power 94.86 3.44

iii) Cash & Bank Balance 117.64 154.09

iv) Loans & Advances 56.51 57.40

v) Other current assets 66.38 76.23

Total of A 393.62 359.41



ii) Payment due on Capital Libilities

iii) Other current liabilities 355.77 386.91

Total of B 355.77 386.91

Net Current Assets (A - B) 37.85 -27.50

Profit/ Loss 86.64 173.01

Grand Total 1377.16 1413.85




15. Revised Annual Revenue Requirement (ARR) for 2014-15

15.1

Table 48:

Assumptions for various Heads – I

2014-15

ST PLR - 14.75%




ROE 14.00%

Other Income@ 10%

escalation

Provision for Taxes

atapproved

by Hon'bleAERC

Provision for Bad and Doubtful Debts% of revenue 0.00



Mainranence spares1% of GrossBlock














Vehicles 18.00% 18.00%

Furniture & fixtures 6.00% 6.00%






Institution 11.40%




Existing Loans

Rates of interst

State Govt 10.50%

PFC


Other 11.40%

Loan Repayment

Govt Loan 10.57

PFC 22.97

Others 0.00

Thermal



Hydel



15.2

Table 49Assumptions for various heads – II

Rs. In CroresInvestment SOURCE 2014-15

Fund fromAnnual

Plan 13-14.

Investment(14-15)

NTPS State Govt. equity

State Govt. Loan 2.00 8.67

State Govt. Grant

PFC Loan

OthersLTPS State Govt. equity


State Govt. Grant

PFC Loan

OthersKLHEP State Govt. equity


State Govt. Grant

PFC Loan

OthersNRPP State Govt. equity



PFC Loan 100.00

OthersMARGHERITA TPP State Govt . Equity





State Govt. Grant

PFC Loan

OthersMYNTRIANG State Govt . Equity

State Govt. Loan

State Govt. Grant 13.30 7.00

PFC Loan

Others120 MW Lower kopili State Govt . Equity 84.00


State Govt. Grant

PFC Loan

OthersBoundary wall at jagiroadfor KLHEP Store

State Govt . Equity


State Govt. Grant

PFC Loan

OthersKLHEP (Upper Stage) State Govt . Equity

State Govt. Loan

State Govt. Grant

PFC Loan

Others70 MW LRPP State Govt . Equity


State Govt. Grant

PFC Loan

Others

TOTAL

State Govt. Equity 0.00 84.00

State Govt. Loan 7.00 40.38

State Govt. Grant 20.16 7.00

PFC Loan 0.00 100.00

Others 0.00 0.00

27.16 231.38

258.54

15.3. Actual/ Projected Operating Performance Data for FY 2014-15

Table 50

NTPS FY 14-15





PLF (%) 57%

Gross Station Heat Rate on NCV(Kcal/ Kwh) 4145


LTPS with WHRU FY 14-15








PLF (%) 65%

Gross Station Heat Rate on NCV(Kcal/ Kwh) 3084


KLHEP FY 14-15





PLF (%) 39%

Myntriang SHEP St-II FY 14-15





PLF (%) 17%

APGCL FY 14-15

APGCL Total Gross Generation (MU) 1843.30

APGCL APC (%) 6.22%

APGCL Total Net Generation (MU) 1728.62


PLF (%) 58%

Variation of Actual/ Projected Heat Rate and Aux. Consumption with the NormativeParameters in FY 2014-15:

Heat Rate:

Power Station

Actual/ Projected GrossSHR on GCV

basis(kcal/kWh) in FY2014-15

Heat Rate as perAERC’s Draft

Amended Regulation of2006 (kcal/kWh)

NTPS 4145 4170

LTPS WithWHRU

3084 3200

From the above table it is observed that the actual Gross SHR (Actual + Projection) of LTPS andNTPS in the FY 14-15 is more or less similar with that of the Draft Amended Regulation of AERC. Inview of this, the projected Station Heat Rates of LTPS and NTPS have been considered in the AnnualPerformance Review of 2014-15.

Aux. Power Cons. (APC):

PowerStation

Normative Aux.Cons.

Actual/ ProjectedAux. Cons. in FY

2014-15

APC as perAPGCL’s Petition

for Review ofNormative APC

NTPS 4.5% 5.7% 5.5%LTPS 5.5% 8.8% 7.5%KLHEP 0.5% 0.5% 0.5%Myntriang 1.0% 1.0% 1.0%




APGCL 4.2% 6.2% 5.5%

From the above it is seen that the Actual/Projected APC of APGCL for 2014-15 is higher than thenormative APC. Reason for this has already been explained in details in the Section 3.2 at Page No.22 to 32 above. The actual/Projected APC of APGCL for 2014-15 is 6.2% if the APC of LTPS andNTPS are considered as per APGCL’s Petition for review of normative APC of LTPS and NTPS. Inview of this, APGCL appeals to AERC to consider APC of APGCL as 5.5%.for the AnnualPerformance Review of 2014-15.

15.4. Actual/ Projected Financial Performance Data for FY 2014-15

15.4.1 Employees ExpensesTable 51

Particulars 2014-15

Salaries 36.65

Overtime 1.66

Dearness Allowance 29.85

Other Allowances 5.61

Bonus 0.03

Medical Allowances 0.09

Leave Travel Assistance 0.05

Earned Leave Encashment 0.29

Workmen Compensatory Payment 0.00

Other Staff Cost 0.01

Staff Welfare Expenses 0.14

Terminal Benefits 12.16

Subtotal 86.54

Less: Capitalisation 0.00

Total 86.54

Note: 1. Employee expenses for FY 14-15 are in actual upto 2nd quarter before any Head quarteradjustment. Regarding 3rd & 4th quarter of FY 14-15 expenses are assumed to be proportionate to theexpenses of 1st & 2nd quarter.

15.4.2. (A) Regular Repairs & Maintenance



Overhauling Works 0.00

Buildings 0.27


Hydraulic 1.10


Vehicles 0.26




Turbine Oil 0.23

Total: 18.75

Note: Regular R&M cost for FY 14-15 is taken at par to that approved in Tariff order FY 14-15. Inaddition, Lubricants & Consumable Stores & Turbine oil is also considered.




15.4.2. (B) Special Type Repair & Maintenance Works

Particulars 2014-15

Plant & Machinery (Overhauling of Unit # 2 of LTPS) 6.44

Total: 6.44

Note: Originally the estimated approved amount of this overhauling works was Rs. 8.5 Cr., out of

which Rs 2.0 Cr. was approved in Tariff Order for FY 2013-14 and Rs. 6.5 Cr. was booked inthe revised ARR for FY 2015-16 against Repair Maintenance of the Unit in the "Order onReview Petition on Tariff Order of FY 2013-14" vide letter No. AERC 442/2014/15 dated08.07.2014. However, the expenditure of Rs. 2.0 Cr., allowed in Tariff order for FY 2013-14,was not incurred in that FY.

The present estimated overhauling cost involvement of LTPS Unit # 2 is around Rs.12.94 Cr.The variation in the estimated cost is due to additional works.

The work order for supply of the capital spares have been already issued to the OEM at anamount of Rs 12.29 Cr and LC for an amount of Rs. 12.29 Cr had been already been openedfor procurement of these capital spares. The LC amount is likely to be encashed by the partyin FY 14-15. In addition to the amount of Rs. 12.29 Cr for spares, another amount of Rs. 0.60Cr for work component and Rs. 0.05 Cr for other miscellaneous expenses is estimated to incurfor the overhauling of Unit#2 of LTPS totaling the whole amount to Rs. 12.94 Cr. The BoardResolution and Agenda for the procurement of spares is given below:




However, as per Hon'ble Commission's order dated.08.07.14, an amount of Rs. 6.5 Cr. isbooked in the revised ARR for FY 2015-16 against Repair Maintenance of the Unit. Thebalance amount of Rs. 6.44 Cr. is shown in Revised ARR for FY 2014-15 under AnnualPerformance Review of the FY. It is appealed before Hon’ble Commission to approve thebalance amount of Rs. 6.44 Cr for the above mentioned reasons.

15.4.2. Total Repairs & Maintenance [15.4.2. (A) + 15.4.2. (B)]

Particulars 2014-15


Overhauling Works 0.00

Buildings 0.27


Hydraulic 1.10


Vehicles 0.26




Turbine Oil 0.23

Total: 25.19






Rent, Rates & Taxes 0.35

Insurance 0.88

Telephone charges 0.05

Postage & Telegrarm 0.00

Legal charges 0.01

Audit fees 0.00

Consultancy charges 0.65

Technical fees 0.01

Other Professional fees 0.01

Conveyance & Travel charges 0.63

Freight 0.02

Other purchase related expenses 6.79

Energy bill raised by APDCL 0.00

Sub Total: 9.41

Less: Capitalised 0.00

Total: 9.41

Note: A&G expenses for FY 14-15 are in actual up to 2nd quarter before any Head quarter adjustment.Regarding 3rd & 4th quarter of FY 14-15 expenses are assumed to be proportionate to the expenses of 1st& 2nd quarter.

15.4.4 Return on Equity

Table 54

Particulars 2014-15

Namrup TPS 9.25

Lakwa TPS 10.67

Lakwa WHRP 9.93

Karbi Langpi HEP 9.54

Myntriang SHEP 1.72

Namrup RPP 0.00

Total 41.10

Return on equity calculated as follows:-

Particulars NTPS LTPS KLHEP LWHRP NRPP Myntriang Total

14-15 14-15 14-15 14-15 14-15 14-15 14-15

Opening Equity 64.74 73.19 68.11 70.92 0.00 11.27 288.22

Closing Equity 67.34 79.24 68.11 70.92 0.00 13.37 298.98

Average equity 66.04 76.22 68.11 70.92 0.00 12.32 293.60

Rate 0.14 0.14 0.14 0.14 0.14 0.14 0.14

ROE 9.25 10.67 9.54 9.93 0.00 1.72 41.10Equity Base calculated is provided below:




CALCULATION OF COST OF CAPITAL 2009-10 , 2010-11, 2011-12, 2012-13,2013-14,2014-15 & 2015-16

NTPS LTPS BTPS CTPS KLHEP Lakwa

WHRP

Myntria

ng

SHEP

NRPP Total

Gross Fixed Assets Cost on 01-04-2009 as Audited

Accounts 2009-10212.35 214.68 91.49 34.46 517.11 0.00 0.00 0.00 1070.08

Gross Approved Fixed Asset as on 01-04-2009212.35 214.68 91.49 34.46 517.11 0.00 0.00 0.00 1070.08

Gross Fixed Assets Cost on 01-04-2010 as per

Audited Accounts

Additions during the F.Y. 2009-10 1.43 24.02 0.02 0.00 0.00 0.00 25.48Deductions during the FY 2009-10 -117.36 -117.36Adjustment as on 01.04.2010 appeared in Annual

accounts25.85 25.85

Approved Gross Capital Cost as on 01-04-2010

213.78 238.71 0.00 34.46 517.11 0.00 0.00 0.00 1004.05Gross Fixed Assets Cost on 01-04-2011 as per

Audited AccountsAdditions during the F.Y. 2010-11

0.96 5.98 0.00 1.53 0.17 0.00 8.63Adjustment as on 01.04.2011 appeared in Annual

accounts0.00

Approved Gross Capital Cost as on 01-04-2011214.74 244.68 0.00 35.98 517.28 0.00 0.00 0.00 1012.69

Gross Fixed Assets Cost on 01-04-2012 as per

Audited Accounts

Additions during the F.Y. 2011-120.44 -17.20 0.00 0.00 0.67 295.98 279.90

Adjustment as on 01.04.2012 appeared in Annual

accounts 0.00Approved Gross Capital Cost as on 01-04-2012


Audited Accounts

Additions during the F.Y. 2012-130.23 8.24 0.00 0.00 13.44 0.00 21.90

Deductions during the FY 2012-13-30.05 -30.05

Adjustment as on 01.04.2013 appeared in Annual

accounts 0.00Approved Gross Capital Cost as on 01-04-2013


Audited Accounts

Additions during the F.Y. 2013-14 0.38 8.24 0.00 0.00 0.45 0.24 37.56 46.87Deductions during the FY 2013-14 -5.57 -5.57Approved Gross Capital Cost as on 01-04-2014

215.79 243.96 0.00 35.98 501.79 290.64 37.56 0.00 1325.73Gross Fixed Assets Cost on 01-04-2015

Additions during the F.Y. 2014-15 8.67 20.19 0.00 0.00 1.92 0.00 7.00 37.78Deductions during the FY 2014-15 0.00Approved Gross Capital Cost as on 01-04-2015

224.45 264.15 0.00 35.98 503.72 290.64 44.56 0.00 1363.51Gross Fixed Assets Cost on 01-04-2015

Additions during the F.Y. 2015-1620.80 19.12 0.00 0.00 7.85 1.50 85.42 693.73 828.42

deductions during the F.Y. 2015-160.00

Adjustment as on 01.04.20160.00

Approved Gross Capital Cost as on 01-04-2016245.25 283.26 0.00 35.98 511.57 292.14 129.98 693.73 2191.93

2011-12

2012-13

2013-14

2014-15

2015-16

2009-10

PartIcula

rsAPGCL STATIONS

2010-11

2016-17




CALCULATION OF APPROVED EQUITY CAPITAL

NTPS LTPS BTPS CTPS KLHEP Lakwa

WHRP

Myntriang

SHEP

Namrup

RPPOther

projects

Total

1 Approved Capital Cost as on 01-04-2009 212.35 214.68 91.49 34.46 517.11 0.00 0.00 0.00 0.00 1070.08

2 30% of Appvd. Capital cost 63.70 64.41 27.45 10.34 155.13 0.00 0.00 0.00 0.00 321.02

3 Actual Equity Capital apportioned as on 01-04-2008 vide

letter CGM (F & A) dtd 05/12/08 128.54 136.53 81.15 20.49 68.11 0.00 0.00 0.00 21.03 455.86

4 Revised Equity Capital Cost as on 01-04-2009.

63.70 64.41 27.45 10.34 68.11 0.00 0.00 0.00 0.00 234.00


2 30% of Appvd. Capital cost64.14 71.61 0.00 10.34 155.13 0.00 0.00 0.00 0.00 301.22

3 Actual Equity Capital

128.54 136.53 0.00 20.49 68.11 0.00 0.00 0.00 102.18 455.86

4 Equity Capital as on 01-04-2010.

64.14 71.61 0.00 10.34 68.11 0.00 0.00 0.00 0.00 214.19




128.54 136.53 0.00 20.49 68.11 0.00 0.00 0.00 102.18 455.86

4 Approved Equity Capital as on 01-04-2011.64.42 73.40 0.00 10.80 68.11 0.00 0.00 0.00 0.00 216.73




128.54 136.53 0.00 20.49 68.11 70.92 0.00 0.00 31.26 455.86

4 Equity Capital as on 01-04-2012.64.56 68.24 0.00 10.80 68.11 70.92 0.00 0.00 0.00 282.63




128.54 136.53 0.00 20.49 68.11 70.92 0.00 0.00 31.26 455.86




3 Actual Equity Capital128.54 136.53 0.00 20.49 68.11 70.92 19.56 0.00 11.70 455.86





4 Estimated Equity Capital as on 01-04-2015.

67.34 79.24 0.00 10.80 68.11 70.92 13.37 0.00 0.00 309.77


2 30% of Appvd. Capital cost 73.58 84.98 0.00 10.80 153.47 87.64 39.00 208.12 0.00 657.58


4 Estimated Equity Capital as on 01-04-2016.

73.58 84.98 0.00 10.80 68.11 70.92 33.34 208.12 0.00 549.84

NOTE: (1) Approved Equity Capital as on 01-04-2013 is the actual equity capital as on 01-04-2013 subject to aceiling of 30% of the Approved Capital cost.

Sl. No.

PartIcu

l

ars

APGCL STATIONS




15.4.5 Income from Other Sources


Interest on Staff Loans and advance 0.00

Income from Investment 8.85

Income from sale of scrap 0.06

Rebate for timely payment 0.79

Misc. receipts (except 62.901 & 62.908) 0.90

Rent from residential building 0.01

Total: 10.60

15.4.6. Depreciation


Land & Rights 0.00

Buildings 0.72

Hydraulic 4.00


Plant & Machinery Thermal 12.57

Plant & Machinery Hydel 4.48


Vehicles 0.12



Roads on land belonging to others 0.00

Capital spares at generating stations 3.28

Total 29.40

(Less) : Depreciation on 90% of the Assets fundedby Grants/subsidies -6.13

Net Total 23.27


15.4.7 Interest & financing charges


Interest on loans 58.80

Other finance charges 5.81

Sub total 64.61

Less: Interest capitalised -29.59

Total 35.02

Note:1. Interest on loans & Other Finance Charges calculated for FY 14-15 @ 10.5% on loan outstanding for

Loan from Govt. of Assam, @ actual interest rates charged by PFC for Loan up to Dec’14 from PFCand remaining on proportionate assumption. GPF trust is expected to complete in FY 14-15 andhence interest on GPF is claimed from FY 14-15




15.4.8 Interest on Working Capital

Table 58

Particulars 2014-15

One month Fuel Cost 38.61

One month approved O&M Cost 9.83

Maintenance Spares 12.90

Two month Receivables 110.82

Total 172.16

Interest @ 14.75% 25.39

Note: Interest on Normative working capital worked out as per AERC norms

15.4.9 Repayment of Loan (Principal)Table 59

Particulars 2014-15

PFC Loan 22.97

State Govt Loan 10.57

Total 33.53

15.4.10. Fuel CostTable 60Rs. In Cr.

Particulars 2014-15

Namrup TPS 200.06

Lakwa TPS 263.30

Total 463.36

16. Profit & Loss Account


Power Generation

Energy generated (MU) 1843.30

Sale of Power (MU) 1728.62

Auxiliary Consumption, Loss % 6.22%

INCOME

Revenue from tariff & Misc. charges 696.37

O&M expenses of CTPS 3.24

EXPENDITURE

Generation Cost 463.35

R&M Expenses 25.19

Employee Expenses 86.54

A&G Expenses 9.41

Depreciation 23.27

Interest & Finance Charges 64.61

Less: Interest & other expenses capitalised -29.59

Interest on working Capital 25.39

Other Debits (incl. Prov. for bad debts, int of W/Capital etc.) 0.00

Extraordinary Items 0.00




Other (Misc.) - net prior period credit 0.00

Total 668.18

ROE 41.10

Other Income 10.60

Provision for taxes 0.93

Annual Revenue Requirement 699.61

Surplus(+) / Shortfall(-)

17. Balance SheetTable 62

Particulars 2014-15

Source of Fund

Share Capital 455.86

Reserve & Surplus 39.97

Loans from State Govt 167.96

Loans from others 505.49

Total 1169.28

Contributions, grants & subsidies towards cost of Capital Asset 409.60

Grand Total 1578.88

Application of Fund

Net Fixed Assets

(A) Gross Block 1363.51

(B) Less : Accumulated Depreciation 649.44

(C) Net Fixed Assets 714.07

(D) Capital-works-in-progress 777.97


(F) Deferred Cost


Total of (C) to (G) 1492.04

Investments 0.00


Net Current Assets


i) Inventories 75.08

ii) Receivables against Sale of Power 3.79

iii) Cash & Bank Balance 169.50

iv) Loans & Advances 63.14

v) Other current assets 83.86

Total of A 395.37



ii) Payment due on Capital Libilities

iii) Other current liabilities 309.53

Total of B 309.53

Net Current Assets (A - B) 85.84

Profit/ Loss 1.00

Grand Total 1578.88

Station wise information for claiming Revised ARR for 2014-15 are depicted inAnnexure-IV (Page No. 148)



18. Proposed Revised ARR for 2014-15:

(Rs in crore)

Particulars 2014-15NTPS LWHRP LTPS (LTPS +

LWHRP)CTPS KLHEP Myntriang Total

Gross Generation (MU) 600.14 197.40 699.96 897.36 0.00 341.38 4.43 1843.30Aux. Power Consumption (MU) 34.23 18.99 59.72 78.71 0.00 1.71 0.04 114.69Net Generation (MU) 565.91 178.42 640.24 818.65 0.00 339.67 4.39 1728.62Fixed ChargesOperation & Maintenance

Employee Cost 32.30 8.78 28.19 36.97 3.18 13.46 0.63 86.54Repairs & Maintenance 2.30 0.72 15.45 16.17 0.00 6.69 0.03 25.19Administrative & General Expenses 2.65 0.44 3.46 3.90 0.02 2.75 0.09 9.41

Interest & Finance Charge 3.55 14.04 5.04 19.08 0.05 12.02 0.32 35.02Interest on working Capital 9.40 1.44 12.33 13.77 0.00 2.15 0.07 25.39Taxes on income 0.31 0.00 0.31 0.31 0.00 0.31 0.00 0.93Depreciation 0.67 10.90 3.94 14.84 0.00 8.67 -0.91 23.27Provision for Bad & Doubtful Debts 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00Return on Equity 9.25 9.93 10.67 20.60 0.00 9.54 1.72 41.10Less: Other Income -3.68 0.00 -3.69 -3.69 0.00 -3.23 0.00 -10.60(A) Total Fixed Charges 56.75 46.25 75.71 121.96 3.24 52.36 1.96 236.26(B) Fuel Cost 200.05 0.00 263.30 263.30 0.00 0.00 0.00 463.35ARR (A) + (B) 256.80 46.25 339.01 385.26 3.24 52.36 1.96 699.61Fixed Cost Paise / Kwh (sent out) 100.27 259.25 118.25 148.98 154.14 445.84 136.68Fuel Cost Paise/ Kwh (sent out) 353.50 0.00 411.25 321.63 0.00 0.00 268.05

Tariff Paise/ Kwh (sent out) 453.78 259.25 529.50 470.61 154.14 445.84 404.72

Note: The Secondary Energy Charges will be computed as per the variable charge of AGBPP, NEEPCO as per CERC Tariff Order 2009-14 which is the lowestin the NE region




Annexure V

Statements of proposed Monthly Generation, Deviations comparingwith Target of 2014-15 and Actual / Projected Cost of Fuel

for FY 2014-15



LATEST REVISED GENERATION TARGET OF APGCL: 2014-15

STATION

Actual Projection

Total

FuelCost

(Rs. InCr.)

Apr-14

May-14

Jun-14

Jul-14

Aug-14

Sep-14

Oct-14

Nov-14

Dec-14

Jan-15

Feb-15

Mar-15

119.5 MW Namrup TPS

Gross Gen. (MU) 50.66 50.19 48.96 49.65 53.00 50.75 50.98 45.57 51.34 51.34 46.37 51.34 600.14200.05Aux. Cons. @5.70% 2.75 2.79 2.56 2.88 2.93 2.96 3.20 2.73 2.93 2.93 2.64 2.93 34.23

Net Gen. (MU) 47.91 47.40 46.40 46.78 50.07 47.79 47.78 42.83 48.41 48.41 43.72 48.41 565.91

157.2 MW Lakwa TPS

LTPS GT Gross Gen. (MU) 56.26 63.01 55.63 57.88 57.16 54.36 64.40 55.65 57.37 61.99 55.94 60.31 699.96

263.30

LTPS GT APC @8.53% (MU) 4.97 5.81 4.83 4.69 5.13 4.80 5.08 4.24 4.91 5.31 4.79 5.17 59.72LTPS GT Net Gen. (MU) 51.29 57.20 50.80 53.19 52.02 49.56 59.32 51.41 52.46 56.69 51.16 55.14 640.24WHRU Gross Gen. (MU) 19.43 19.50 16.58 12.83 18.33 16.42 20.73 15.46 13.94 15.62 14.11 14.45 197.40WHRU Aux. Cons. @9.62% (MU) 1.70 1.80 1.66 1.41 1.73 1.67 1.83 1.59 1.34 1.50 1.36 1.39 18.99WHRU Net Gen. (MU) 17.72 17.70 14.92 11.42 16.60 14.74 18.90 13.87 12.60 14.12 12.75 13.06 178.42

LTPS Gross Gen. (MU) with WHRU 75.69 82.51 72.21 70.70 75.49 70.78 85.13 71.11 71.32 77.62 70.06 74.76 897.36

Total Aux. Cons. @8.77% withWHRU

6.68 7.61 6.49 6.10 6.86 6.47 6.91 5.83 6.26 6.81 6.14 6.56 78.71

LTPS Net Gen. (MU) with WHRU 69.01 74.90 65.72 64.60 68.63 64.30 78.22 65.28 65.06 70.81 63.91 68.20 818.65100 MW Karbi Langpi HEPGross Gen. (MU) 7.64 18.97 27.76 39.78 50.85 63.49 63.83 32.06 15.00 11.00 5.00 6.00 341.38

0.00Aux. Cons. @ 0.5 % 0.04 0.09 0.14 0.20 0.25 0.32 0.32 0.16 0.08 0.06 0.03 0.03 1.71Net Gen. (MU) 7.60 18.87 27.62 39.58 50.60 63.18 63.51 31.90 14.93 10.95 4.98 5.97 339.67Myntriang Small HEP - Stage II (3 MW)*\Gross Gen. (MU) 0.00 0.00 0.00 0.00 0.37 0.00 0.21 0.04 0.00 1.46 1.17 1.18 4.43

0.00Aux. Cons. @ 1% 0.00 0.00 0.00 0.00 0.003 0.00 0.002 0.00 0.00 0.01 0.01 0.01 0.04Net Gen. (MU) 0.00 0.00 0.00 0.00 0.37 0.00 0.21 0.04 0.00 1.45 1.16 1.17 4.39

APGCL

Gross Gen. (MU) 133.99 151.67 148.93 160.13 179.71 185.02 200.15 148.78 137.65 141.41 122.59 133.27 1843.30

463.35Aux. Cons. @6.22% 9.47 10.49 9.19 9.17 10.05 9.75 10.43 8.72 9.26 9.81 8.83 9.53 114.69

Net Gen. (MU) 124.52 141.17 139.74 150.96 169.66 175.27 189.73 140.05 128.39 131.61 113.77 123.75 1728.62

Note: Myntriang St-II generation has been considered from the COD of 08-8-14



Deviations comparing with Target of 2014-15 and Actual / Projected Generation for FY 2014-15

Power Station ItemApr/

14May/

14Jun/14

Jul/14

Aug/14

Sep/14

Oct/14

Nov/14

TotalFrom

Apr'14 toNov'14

Dec/14

Jan/15

Feb/15

Mar/15

ProjectedTotal fromDec'14 to

Mar'15

GrandTotal

2014-15

NTPS

Target of 14-15 43.48 44.93 43.32 44.93 44.93 37.70 44.93 43.48 347.71 44.93 44.93 40.58 44.93 175.38 523.09

Actual/Projected Generationfor 14-15

Actual Projected

50.66 50.19 48.96 49.65 53.00 50.75 50.98 45.57 399.76 51.34 51.34 46.37 51.34 200.38 600.14

Surplus (+)/Deviation (-)

7.18 5.26 5.64 4.72 8.07 13.05 6.05 2.09 52.05 6.40 6.40 5.79 6.40 25.00 77.05

LTPS withWHU

Target of 14-15 67.11 64.64 67.11 69.34 69.34 66.79 69.34 73.96 547.63 76.11 76.42 69.03 73.29 294.84 842.47


Actual Projected

75.69 82.51 72.21 70.70 75.49 70.78 85.13 71.11 603.61 71.32 77.62 70.06 74.76 293.75 897.36


8.59 17.86 5.10 1.36 6.15 3.98 15.79 -2.85 55.98 -4.79 1.19 1.03 1.47 -1.10 54.89

KLHEP

Target of 14-15 9.00 19.00 45.00 68.00 74.00 72.00 45.00 21.00 353.00 15.00 11.00 5.00 6.00 37.00 390.00


Actual Projected

7.64 18.97 27.76 39.78 50.85 63.49 63.83 32.06 304.38 15.00 11.00 5.00 6.00 37.00 341.38


-1.36 -0.03 -17.24-

28.22-23.15 -8.51 18.83 11.06 -48.62 0.00 0.00 0.00 0.00 0.00 -48.62

MyntriangSHEP, St-II

Target of 14-15 0.00 0.00 0.00 0.00 0.37 1.30 2.01 1.94 5.62 1.95 1.46 1.17 1.18 5.76 11.38


Actual Projected

0.00 0.00 0.00 0.00 0.37 0.00 0.21 0.04 0.62 0.00 1.46 1.17 1.18 3.81 4.43


0.00 0.00 0.00 0.00 0.00 -1.30 -1.79 -1.91 -5.00 -1.95 0.00 0.00 0.00 -1.95 -6.95

APGCL

Target of 14-15119.5

9128.57

155.43

182.27

188.64177.7

9161.2

8140.38 1253.96

137.99

133.82

115.78

125.40 512.98 1766.94


Actual Projected

133.99

151.67148.9

3160.1

3179.71

185.02

200.15

148.78 1308.37137.6

5141.4

1122.5

9133.27 534.94 1843.30


14.40 23.09 -6.50-

22.14-8.93 7.23 38.87 8.39 54.41 -0.34 7.60 6.82 7.88 21.95 76.37

Note: Myntriang St-II SHEP generation reduced as the plant got affected by heavy flood on 22-08-14. All the equipments needed servicing. At present both theunits are under forced shutdown and it is expected that the units will start stable operation from January’15 after repairing.



ACUAL/PROJECTED FUEL COST OF APGCL: 2014-15

Actual Projected

Fuel Cost for FY 2014-15 (LTPS)

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 Total

GAIL

Qty (MMSCM) 10.54 12.47 11.41 12.40 13.20 11.16 14.73 11.21 11.24 12.23 11.04 11.78 143.40

Amount (Rs. in Cr) 6.51 7.75 6.90 7.70 8.45 7.34 10.27 9.48 9.51 10.35 9.34 9.97 103.56

AGCL

Qty (MMSCM) 13.04 13.49 11.39 10.92 9.79 10.59 10.82 10.97 11.01 11.98 10.81 11.54 136.34

Amount (Rs. in Cr) 13.78 13.73 11.55 11.56 10.28 11.07 11.31 14.90 14.94 16.26 14.68 15.67 159.74

Total Fuel Cost LTPS(Rs. in Cr)

20.29 21.47 18.45 19.26 18.73 18.41 21.59 24.38 24.45 26.61 24.02 25.63 263.30

Fuel Cost for FY 2014-15 (MMSCM) (NTPS)

Qty (MMSCM) 22.49 23.33 21.31 22.13 21.73 21.05 21.14 19.71 22.20 22.20 20.05 22.20 259.56

Total Fuel Cost NTPS(Rs. in Cr)

15.64 16.01 14.11 15.61 14.97 14.36 14.44 17.58 19.81 19.81 17.89 19.81 200.05

Total APGCL (Rs. in Cr) 35.93 37.49 32.56 34.87 33.71 32.77 36.02 41.97 44.26 46.42 41.91 45.44 463.35


Annex- VI

`

UN AUDITED ANNUAL ACCOUNTS

FOR FY 2013-14

ASSAM POWER GENERATION

CORPORATION LIMITED


Particulars NoteRupees in

lakh

As on 31st

March 2014

As on 31st

March 2013

I.EQUITY & LIABILITES(A) Shareholder's Funds(a) Share Capital 1 45,585.98 45,585.98(c) Reserves and Surplus 2 20,737.33 31,260.51(B) Share Application Money 3 - -

(Pending Allotment) - -C. Non Current Liabilites - -(a) Long Term Borrowings 4 53,387.87 48,419.89(b) Differed Tax Liabilites (Net) - -(c) Other Long Term Liabilites 5 739.37 739.37(d) Long Term Provisions 6 3,633.47 3,045.20D. Current Liabilites - -(a) Short Term Borrowings 7 - -(b) Trade Payables 8 16,748.92 12,790.75(c) Other Current Liabilites 9 15,147.11 15,229.39(d) Short Term Provisions 10 6,795.39 7,556.88

- -Total :: 162,775.44 164,627.97

II. ASSETS(A) Non-Current Assets(a)Fixed Assets 11(i) Tangible Assets 69,935.92 68,673.47(ii) Intangible Assets - -(iii) Capital Work-In-Progress 56,898.33 56,593.29(iv) Intangible Assets Under Development - -(b) Non Current Investment 12 - -(c) Differed Tax Assets (Net) - -(d) Long Term Loans & Advances 13 - -(e) Others Non Current Assets 14 - -(B) Current Assets(a) Current Investment 15 - -(b) Inventories 16 6,825.08 5,822.61(c) Trade Receivable 17 344.10 9,485.66(d) Cash & Cash Equivalents 18 15,408.79 11,763.97(e) Short Term Loans & Advances 19 5,739.80 5,651.37(f) Others Current Assets 20 7,623.42 6,637.60

Total :: 162,775.44 164,627.97

Notes forming part of the Consolidated Financial

Statements1 - 41

ASSAM POWER GENERATION CORPORATION LIMITED

BALANCE SHEET AS AT 31st MARCH, 2014


Particulars Notes

As on 31st

March

2014

(Rupees in lakh)

As on 31st

March

2013

(Rupees in lakh)

I.INCOME(a) Revenue From Operations 21 54,705.14 45,967.81(b) Other Income 22 1,054.59 1,373.70(c) Other Receipts 23 1,900.00 -

Total Revenue :: 57,659.73 47,341.51

II.EXPENDITURE(a) A. Cost of Materials Consumed 24 38,535.78 36,454.49(a) B. Cost of Materials Consumed (Lubricant) 122.90 96.17(b) Employee Benifites Expenses 25 8,199.64 7,211.53Losses relating to fixed assets - -(c) Finance Costs 26 4,396.27 4,252.22(d) Depriciation and Amortization Expenses 2,867.72 3,786.82(e) (i) Other Expenses 27 (i) 3,713.43 2,600.94

(ii) Other Expenses - Prior period items 27 (ii) 8,415.18 (6,502.12)

Total Expenses :: 66,250.92 47,900.05Profit(Loss) Before Tax (I-II) (8,591.19) (558.54)Exceptional Item - -Profit(Loss) Before Extra ordinary item and Tax (8,591.19) (558.54)III.TAX EXPENSES(a) Current Tax (i) Income Tax 45.14 -

(ii) MAT - -(iii) Building & other construction workers welfare cess - 49.87

(b) Deferred Tax - -45.14 49.87

Profit (Loss) For the Period (8,636.33) (608.41)

IV. Earnings per share:(a) Basic 28 (18.95) (1.33)(b) Diluted

Notes forming part of the Consolidated Financial

Statements1 - 41

ASSAM POWER GENERATION CORPORATION LIMITEDSTATEMENT OF PROFIT & LOSS ACCOUNT FOR THE YEAR ENDED 31.3.2014


As on 31st March

2014

(Rupees in lakh)

As on 31st March

2013

(Rupees in lakh)

A. CASH FLOW FROM OPERATING ACTIVITIES:

Net Profit before Taxation (8,591.19) (558.54)Adjusted for: - -

Tax Provision - -Deferred Tax Provision - -Profit/Loss on Sale of Assets - -Profit/Loss on Sale of Fixed Assets(Net) - -Profit/Loss on Sale of Current Investments-others - -Provision for Diminution in Current Investment - -Depreciation 2,867.72 3,477.93Lease Equalisation - -Transferred from general Reserve - -Income from Investment - -Interest /Other Income - (720.57)Lease Rent written off - -Capial Work in Progress written off - -Preliminary Expenses written off - 0.30Prior Period Expenses - -Interest Expenses 4,396.27 4,252.22

7,263.99 7,009.88

Operating profit before working capital changes (1,327.20) 6,451.34

Adjusted for :

Increase in Current Assets 7,064.82 (2,699.46)Decrease in Current Liabilities 3,114.42 (1,280.25)Decrease in Loans & Advances - 0.14

10,179.24 (3,979.57)Cash generated from operations 8,852.04 2,471.77

Tax expenses 45.14 49.87- -

Net Cash from Operating Activities 8,806.90 2,421.90

B. CASH FLOW FROM INVESTMENT ACTIVITIES :

Purchases of Fixed Assets (4,130.17) 814.78Sale of Fixed Assets - -Purchase of Investments - -Sale of Investments - -Capital Work in Progress (305.04) (15,236.96)Income from Investment - -Interest/Other Income - 720.57

- -Net Cash Used in Investment Activities (4,435.21) (13,701.61)

ASSAM POWER GENERATION CORPORATION LTD.

CASH FLOW STATEMENT FOR THE YEAR ENDED 31st

MARCH, 2014


NOTES FORMING PART OF THE CONSOLIDATED FINANCIAL STATEMENTS

SIGNIFICANT ACCOUNTING POLICIES: -1. Basis of Preparation:The financial Statements have been prepared under the historical cost convention, based onaccrual basis of accounting and in accordance with the generally accepted accounting principlesand the provision of the Companies Act, 1956.2. Use of Estimate:The preparation of financial statement in conformity with generally accepted accounting principlesrequires the management to make estimates and assumptions that affect the reported balancesof assets and liabilities as of the date of the financial statement and reported amounts of income& expenses during the reporting period. Management believes that the estimates used in thepreparation of financial statement are prudent and reasonable. Difference between the actualresult and estimates are recognized in the period in which result are known/ materialized.3. Inventories:Stock Accounts of the Company maintained for construction project has been treated as “CapitalStores” and that of O& M purpose treated as “Operational Stores”. Materials are issued to worksat standard price.Issue of Standard Items is at Standard rates on FIFO basis. For Non-Standard Items receiptaccounting is based on Basic Price+E/Duty+Sales Tax. Issue of Non-Standard Items is based onweighted average rate of previous month’s closing balance. If there is no closing stock in theprevious month, valuation of issue is based on the first receipt rate of the current month.

Shortages found on physical verification of stocks are booked under “Material Shortages pendinginvestigation (Account code 22.8). These shortages are recovered from persons responsible orwritten off, as the case may be, on completion of investigation.4. Capital –Work –in-progress:All expenses incurred for acquiring, erecting and commissioning of fixed assets including intereston long term loans utilized for meeting capital expenditure. Capital work in progress includes costof material purchased, excise duty and other management overheads and are allocated to thefixed assets on the completion of the projects.5. Operational Performance:The operational performance of the company is detailed in Annexure-A. The gross powergeneration of the company was 1845.228 MU. The Auxiliary consumption was 112.380 MU. Net

power available for sale was 1732.847 MU and the power was sold for an amount of 547.00crore to APDCL (ASEB).6.Fixed Assets and Depreciation:

a) The Fixed Assets are stated at cost, less accumulated depreciation/ amortization. Costsinclude all expenses incurred to bring the assets to its present location and condition.

b) Depreciation for the period in respect of assets has been provided on straight line methodas per Schedule-XIV of Companies Act, 1956. Depreciation on addition of assets has beencalculated on pro-rata basis.

C. CASH FLOW FROM FINANCING ACTIVITIES :

Proceeds from Share capital - -Proceeds from Long Term Borrowings 4,967.96 8,577.20Repayment of Finance Lease Liabilities 588.28 -Dividend Paid - -Interest paid (4,396.27) (4,252.22)Reserve & Surplus (1,886.84) 9,836.08

Net Cash Used in Financing Activities (726.87) 14,161.06

Net Increase/Decrease in Cash and Cash Equivalents (A+B+C) 3,644.82 2,881.35

Opening Balance of Cash and Cash Equivalents 11,763.97 8,882.62

Closing Balance of Cash and Cash Equivalents 15,408.79 11,763.97


ASSET Rate of Dep METHOD

Building (Residence) 1.63% SLMBuilding (Factory) 3.34% SLMHydrulic 4.75% SLMOther Civil Works 1.63% SLMPlant & Machinary 5.28% SLMLines & Cable Network 5.28% SLMVehicles - truck, bus 11.31% SLMVehicles - others 9.50% SLMFurniture & Fixtures 6.33% SLMOffice Equipment 4.75% SLM

c) The Fixed Assets are depreciated up to 95% of the original cost after taking 5% as theresidual value.

d) Company’s assets are not subject to any lien.

e) The expenditure on capital work-in-progress is transferred to appropriate asset oncommissioning of the asset/when first put to use.

f) As per the accounting policy followed by the Company, Consumers’ contribution, subsidiesand grants towards cost of capital assets have not been reduced from the cost of assetsbut have been treated as ‘Reserves and Surplus’. However, the depreciation pertaining tofixed assets constructed out of consumer’s contribution, subsidies and grants towards costof capital assets is charged.

7. Segment Reporting:The company has single business segment namely, “Generation of Electricity”. As regardsgeographical segment the area that falls under the company is similar in respect of economic andpolitical condition etc. and therefore is not subject to different risk and return. Therefore, thecompany business doesn’t fall under the different segments as defined in AS 17 of ICAI.8. Revenue Recognition:Sale of energy is accounted for based Tariff rates approved by AERC.9. Accounting for Government Grants:Government grants received for capital works are treated as Capital Reserve. Govt. Grantstowards cost of capital assets are contribution of the owner (i.e. State Govt.) towards capital of theCompany. Fund brought in by the ‘owner’ cannot be construed as meeting a portion of the cost.Hence, in terms of AS-12 Govt. Grants has been treated as capital receipt and taken to CapitalReserve.Grants from ADB, though shown separately in the accounts are grants from the Govt. of Assam,which receives the fund from Central govt., the borrower in terms of the loan agreement withADB.10. Accounting for Investments:Investments are carried at cost. All the investment in UTI mutual fund has been redeemed.Investment in fixed deposits represents unutilized capital funds to be deployed for capitalexpenditure and shown as bank balance.11. Retirement benefits:Pursuant to the Transfer Scheme, the GoA vide Notification No.PEL.190/2004/69 dtd.4

th

February, 2005 notified the plan for meeting the terminal benefit obligations of personneltransferred from ASEB to successor entities. As per Clause 1.5 of the said notification “TerminalBenefit” means the ASEB’s employee related liabilities including payments of pension, gratuity,leave encashment and General Provident Fund and any other retirement benefits and applicablebenefits including right to appropriate revisions in the above benefits consistent with the practicethat were prevalent in ASEB:(A) Funding for past unfunded terminal liabilities is on the basis of actuarial valuation done as at30

thSeptember, 2012. The cash outflows towards past unfunded liabilities of existing employees,

existing pensioners and existing family pensioners funded pattern will be guided by the aforesaidGovt. notification.(B) Funding for future services-Terminal Benefits:The company has made a provision for terminal liability for future service of its existing employees


@23.31% of Basic plus DA as per AERC guidelines and in the line with the GoA’s Notificationmentioned above.

(C) Leave Encashment Benefit (LEB) of employees:

Leave encashment benefit of the old employees are accounted on cash basis. LEB admissible tothe employees are being paid by the Company and claim for recovery of the appropriate share ofsuch fund (i.e. share of past liability) relating to period prior to 9.12.2004 is forwarded to thePension Trust Authority as per GoA Notification mentioned here-in-above.

(D) GPF deductions/payments of employees:

Payments on account of GPF (Final Withdrawal and Non-refundable advance) to the existingemployees are being made from the GPF Account of the Company. Claim for recovery ofappropriate share of such fund (i.e. share of past unfunded liability) is forwarded to the PensionTrust authority as per GoA Notification mentioned above.

Provision for interest on GPF is on the basis of average rate of 8.70 % applied on the averagesubscription of the employee.

(E) Terminal benefit for new (appointed on or after 1.1.2004) employees:

New Pension Scheme is being implemented for the new employees of the Company as perGovernment of India Notification No.5/7/2003-ECB & PR dated. 22.12.2003. The Companycontributed the equal amount deducted from its employees, fall under New Pension Scheme.12. Accounting for Borrowing Costs:Borrowing costs attributable to acquisition/construction or production of qualifying assets arecapitalized as part of cost of such assets. A qualifying asset is an asset that necessarily takes asubstantial period of time to get ready for its intended use or sale. Other borrowing costs arerecognized as an expense in the period in which they are incurred.13. Provision for Taxation:Provision for current tax is measured at the amount expected to be paid to the tax authorities,using the applicable rate and tax laws.14. Repayment of Loans:No amount is being reserved for repayment of loan. However, repayments of loan, redemption ofbonds and interest has been paid duly, except the GoA Loan.

15. Impairment of Assets:As per AS-28, an asset is treated as impaired when the carrying cost of assets exceeds itsrecoverable value. An Impairment Loss is charged to Profit & Loss A/c in the year in which theasset is identified as impaired. The Impairment Loss recognized in prior accounting periods isreversed if there has been a change in the estimate of recoverable amount.

16. Contingent Liabilities:Contingent liabilities are disclosed in respect of present possible obligation that arise from pastevents but their existence is confirmed by the occurrence or non-occurrence of one or moreuncertain future events not wholly within the control of the Company.

17. Disclosures vide notification No.GSR 719(E) of Ministry of Corporate Affairs dated 16-11-07:

Outstanding amount to fuel suppliers of APGCL as on 31-03-14 in rupees crore is as tabulatedbelow –

Supplier Outstanding principal Outstanding interest Total (in Rupees)

OIL 139.33 0.87 140.20GAIL 12.37 0.29 12.66AGCL 14.65 14.65

There are no suppliers in APGCL who fall under Micro, Small & Medium Enterprises DevelopmentAct, 2006.

18. Miscellaneous:i.Expenses incurred in raising of finance are being charged to revenue in the year in whichthese are incurred.


ii.Interest on loans and advances to staff is recovered on completion of recovery of principalamount.


Notes forming part of the Consolidated Financial Statements

The Previous Year Figures have been regrouped/ reclassified,wherever necessary to conform to the current year presentation.

1. SHARE CAPITAL

ParticularsAccountcodes

As on 31-03-2014(Rupees in lakh)


Authorised Shares Capital100000000 equity share of 100 each 100,000.00 100,000.00

Issued, Subscribed and paid up

(i) 45585975 equity share of Rs 100/- each fully paid up 59.101 45,585.98 45,585.98

(Previous Year 5008 equity share of Rs 100/- each fully paid up)

Total 45,585.98 45,585.981.1 45585975 ( 5008) Shares out of the issued , subscrided and paid up Shares Capital were allotted as fullypaid uppursuant to transfer scheme without payment being received in cash.

Name of the Shareholder As on 31-03-2014 As on 31-03-2013

No of Shares % Held No of Shares % Held

Governor of Assam 45585967 99.99998 99.99998One number of share of Rs.100/- each by Shri S.Das, Shri S.Abbasi,Shri S.K.Handique, Shri S.Kar, Smti.K.Baruah, Shri A.C.Baruah, ShriS.K.Saha, Shri K.Patowali 8 0.00002 0.00002

1.3 The Reconcillation of the number of shares outstanding is set out below :

ParticularsAccountcodes As on 31-03-2014 As on 31-03-2013

Equtity Shares at the beginning of the year 45585975 45585975Add: Shares Issued During the Year 0 0Equity Shares At the End of the Year 45585975 45585975

2. RESERVES AND SURPLUS

ParticularsAccountcodes



General Reserves

Capital Reserves 55.300 38,038.15 39,924.99


Profit (Loss) as per last Balance Sheet (8,664.48) (8,056.07)Profit (Loss) for the year (8,636.33) (608.41)

(17,300.82) (8,664.48)Total 20,737.33 31,260.51

2.1 Capital reserve includes:-As on 31-03-2014

(in Rs)As on 31-03-2013

(in Rs)(a) Grant towards cost of Capital Assets (for WIP) 3,253,770,000 3,575,770,000(b) Donated Capital Assets 108,447,500 108,447,500(c) ADB Grant (for WIP) 13,155,545 11,839,991(d) GoA Grant (from NABARD for CWIP of Myntriang SHEP) 428,442,000 428,442,000

1.2 the Details of Shareholders holding more than 5% Shares


3. Shares Application Money Pending Allotment

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Capital of Assam State Electricity Board apportioned to the company as

per notification of the Government of Assam which is pending allotment

59.102

0.00 0.00Total 0.00 0.00

4. Long Term Borrowings

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

SECUREDLoans from PFC 52.111 33,351.33 30,648.00

Total 33,351.33 30,648.00

UNSECUREDLoans from ADB 52.112 0.00 13.16

State Govt. Loan 54.100 13,578.01 11,720.97

GPF 57.120 6,408.40 5,975.22

Staff Pension Fund (DCP) 50.13 62.54

Total 20,036.54 17,771.894.1 Loan from PFC is secured against the assets created out of it.4.2 Loan from State Govt. includes Rs.65,64,99,696/- as repayment due.4.3 During the year Rs.50.00 crore loan was drawn from PFC against NRPP project.

5. OTHER LONG TERM LIABILITES

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)Trade payable

Liabilities to railways for Coal receipt 40.100 739.37 739.37

Total 739.37 739.375.1 Reconciliation with railways for settlement of dues is under progress & the process may take few more time.

6.LONG TERM PROVISION

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)Provision For Employees Benefits

Provision For Employees Benefits 3,633.47 3,045.20

Others

Provision for doubtful loans and advances 46.922 0.00 0.00

Total 3,633.47 3,045.20

7.SHORT TERM BORROWINGS

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

SECURED

0.00 0.00

UNSECURED

0.00 0.00

Total 0.00 0.00


8.TRADE PAYABLE

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Micro Small And Medium Enterprises

OthersLiabilities for Supply of Gas 40.500 16,748.92 12,790.75

Total 16,748.92 12,790.75

9.OTHERS CURRENT LIABILITES

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Interest accrued but not due on Borrowings 51.203 0.00 9.54

Interest accrued and due on Borrowings 51.204 8,980.78 9,089.35

Other Payables

Liabilities for capital supplies /works 42.1-42.6 3,283.10 2,919.24

Liabilities for supplies/works(O&M) 43.1-43.6 697.76 730.49

Other Liabilities 46.900 2,187.26 2,482.56

Advance (to) /from AEGCL 45.704 (1.79) (1.79)

Total 15,147.11 15,229.399.1 Interest accrued and due on borrowings includes (a) State Govt Loan Rs.82,45,50,341/-

(b) PFC Loan Rs.7,35,28,009/-

10.SHORT TERM PROVISION

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)Provision For Employes Benefits

Salaries, wages, bonous 44.300 807.67 704.65

Employees' contribution & recoveries 44.400 150.52 132.85

958.19 837.50

Others

Deposits and retention from suppliers and contractors 46.100 5,089.37 4,789.22

Provision for Liability for Expenses 46.400 654.68 1,713.01

Liability for Pension 46.500 90.30 41.11

Provision of Audit Fees 46.805 2.40 2.40

Provision for Building & other Construction workers welfare cess 46.803 0.46 173.64

Provision for Minimum Alternate Tax 46.802 0.00 0.00

5,837.21 6,719.38Total 6,795.40 7,556.88


A/c

Code Description

As at

1.4.2013

Adjustment

as at

1.4.2013

Additions

during the

year

Deductions

during the

year

As at

31.3.2014

As at

1.4.2013

Adjustment

as at

1.4.2013

Depreciation

for the year

Deduction

during the

year

As at

31.3.2014

As at

31.3.2014

As at

31.3.2013

TANGIBLE ASSETS

OWN ASSETS

10.1 Land & Rights 2,079.19 - - - 2,079.19 - - - - - 2,079.19 2,079.19

10.2 Building 4,445.63 - 31.27 - 4,476.90 2,196.65 - 86.74 - 2,283.39 2,193.51 2,248.98

10.3 Hydraulic 15,742.50 - 1,578.36 - 17,320.86 4,383.07 - 753.52 - 5,136.59 12,184.27 11,359.43

10.4 Other Civil Works 18,463.06 - 392.59 - 18,855.65 1,768.51 3,847.00 201.39 - 5,816.90 13,038.75 16,694.55

10.5 Plant & Machinery 65,354.14 281.77 2,635.99 557.12 67,714.78 32,260.06 324.84 1,637.63 - 34,222.53 33,492.25 33,094.08

10.6 Lines & Cable Network 4,414.57 - 32.98 - 4,447.55 1,574.98 1,163.01 21.30 - 2,759.29 1,688.26 2,839.59

10.7 Vehicles 124.17 - - - 124.17 115.03 (35.69) 6.55 - 85.89 38.28 9.14

10.8 Furniture & Fixtures 412.65 (281.77) 5.32 - 136.20 369.88 (281.80) 3.40 - 91.48 44.72 42.77

10.9 Office Equipemnt 97.07 - 10.78 - 107.85 67.82 (8.42) 8.70 - 68.10 39.75 29.25

11.1Roads on landbelonging to others

28.24 - - -28.24

0.25 - 0.25 -0.50 27.74 27.99

11.3Capital spares atGenerating Stations

17,282.56 - - -17,282.56

17,034.06 (5,008.94) 148.25 -12,173.37

5,109.19 248.50

Total 128,443.78 - 4,687.29 557.12 132,573.95 59,770.31 - 2,867.73 - 62,638.04 69,935.91 68,673.47

Previous Year 129,258.56 - 2,190.31 3,005.09 128,443.78 56,292.38 - 3,786.82 308.89 59,770.31 68,673.47 72,966.18

CAPITAL WORK IN

PROGRESS56,898.33 56,593.29

ASSET Rate of Dep METHOD

Building (Residence) 1.63% SLMBuilding (Factory) 3.34% SLMHydrulic 4.75% SLMOther Civil Works 1.63% SLMPlant & Machinary 5.28% SLMLines & Cable Network 5.28% SLMVehicles - truck, bus 11.31% SLM

Vehicles - others 9.50% SLMFurniture & Fixtures 6.33% SLMOffice Equipemnt 4.75% SLM

Note:- (i) In the absence of shift log book for Plant & Machinary, depreciation on Plant & Machinary has been charged on continued process plant basis.

(ii) On fixed assets accuired during the year depreciation is charged on 'Put to Use' basis.


11.FIXED ASSETS

GROSS BLOCK DEPRECIATION NET BLOCK


12. NON CURRENT INVESTMENT

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)Trade Investment 0.00 0.00Others Investment 0.00 0.00Total 0.00 0.00

13.LONG TERM LOANS & ADVANCES

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Others Loans & Advances

Security Deposits from consumers 48.100 & 48.200 0.00 0.00

Total 0.00 0.00

14.OTHERS NON CURRENT ASSETS

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

OthersPrelimenary Expenses 17.300 0.00 0.00Total 0.00 0.00

15. CURRENT INVESTMENT

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Investment in Equity Instruments 0.00 0.00Total 0.00 0.00

16. INVENTORIES

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

1. Capital Stores and Spares

Fuel Stock 21.101/125 10.71 7.41

Capital Materials Stock A/c 22.601 6,862.72 7,393.76

2. O&M Materials Stock A/c 22.602 2,766.51 1,318.22

3. Materials Stock Adjustments (Capital) 22.501 0.00 0.00

Other Material Account 22.700 358.10 276.17

Material stock-Excess/Shortage pending investigation - Capital 22.800 30.10 30.10

Less Provision against Stock 46.920 (3,203.05) (3,203.05)

Net Total 6,825.09 5,822.61

17. TRADE RECEIVABLES

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Receivables against sale of power - APDCL 23.101 344.10 9,485.66

Total 344.10 9,485.66


18. CASH & CASH EQUIVALENTS

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Balances With Bank 696.87 1,110.10

Cash In Hand 61.13 65.34

Fixed Deposits with Banks 14,650.79 10,588.53

Total 15,408.79 11,763.9718.1 Balances with bank includes closing bank balance of HQ as well as of all field units along with the fund in transit.18.2 Fixed Deposits with Banks includes closing balance of fixed deposit at various banks.

19. SHORT TERM LOANS & ADVANCES

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

(Unsecured & Considered Good)

Advances for O&M supplies/works 26.1 to 26.8 5,778.85 5,647.36

Loans and advances to staff 27.1 & 27.2 (39.05) 4.01

Advance Tax/Income Tax deducted at source 27.400 0.00 0.00

Total 5,739.80 5,651.37

20. OTHER CURRENT ASSETS

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Interest Accrued on InvestmentAdvance to suppliers (Capital )

Interest bearing 25.100 0.00 0.00

Interest free 25.500 1,345.78 1,454.48

Advance to contractors (Capital )

Advance to Capital Contractors - Interest Free 25.600 6.12 6.12

Contractors materials control Account (capital) 25.700 0.00 0.00

Income Accrued but not Due 28.300 752.94 442.12

Fuel Related Receivables & Claims { Railway claims for Coal} 28.500 747.91 747.91

Other Receivables 28.800 4,753.21 3,902.26

Prepaid expenses 0.00 77.46

Deposits(except (28.907) 28.900 0.55 0.55

Inter Unit A/c - Capital Expenditure & Fixed Assets 32.000 0.00 (1.92)

Inter Unit A/c - Remittance to HQ 33.000 15.80 7.50

Inter Unit A/c - Opening Balance 36.802 1.11 1.11

Total 7,623.42 6,637.59

20.1 Other recivable includes proportion of unfunded liabilities to be received from the Pension Trust on account of GPF & LEB

payment.


21. REVENUE FROM OPERATIONS

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Sale of Power (ASEB) 61.101 54,699.58 45,965.83

Sale of scrap 5.56 1.98

Total 54,705.14 45,967.81

22. OTHER INCOME

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

InterestInterest on House Building Advances to Staff 62.211 0.03 0.03

Interest on Investment (Fixed Deposit) 62.221 880.57 605.81

DividendDividend gain on investment in UTI mutual fund 62.222 0.00 114.76

Other Non Operating IncomeInterest from Banks (other than interest on fixed deposits) 4.26 0.00

Rebate received for timely payment of dues of loans, interest, etc. 62.273 78.91 58.62

Rebate for timely payment 62.361 0.00 9.63

Misc.receipts (except 62.901 &62.908) 62.900 89.56 583.71

Rentals from staff quarters 62.901 1.26 1.14Total 1,054.59 1,373.70

* Interest on FD is calculated as closing balance of FD.

23. OTHER RECEIPTS

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Revenue grant received 1,900.00 0.00Total 1,900.00 0.00

24.COST OF MATERIALS CONSUMED

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

IndigenousGas 71.130 2,985.80 382.17

Gas/Oil (Internal Combustion) 71.140 to 35,549.98 36,072.32

Lubricants and cunsumable stores 71.600 122.90 96.17Total 38,658.68 36,550.66

25. EMPLOYEE BENEFITS EXPENSES

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Salaries and Wages

Salaries 75.100 3,380.68 3,349.31

Overtime 75.200 143.72 63.01

Dearness Allowance 75.300 2,712.21 2,195.02



Bonus 75.500 2.88 2.22

Sub Total 6,932.19 6,246.38

Less:-Employees cost capitalised 75.900 0.00 211.79

Salaries and Wages 6,932.19 6,034.59

Contribution to Provident and Other Funds 75.800 1,204.34 1,112.05

Medical expenses reimbursement 75.611 17.42 18.47

Leave travel concession (L.T.C) 75.612 4.51 4.20

Earned leave encashment. 75.617 27.57 18.81

Other Staff Cost 75.630 to 75.649 0.65 2.08

Staff Welfare 75.700 12.96 21.33


TOTAL: 8,199.64 7,211.53

26. FINANCE COSTS

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Interest Expenses

Interest on State Govt. Loan 78.100 1,657.16 1,404.75

Interest on PFC Loan 78.300 3,746.36 2,752.95

Interest on ADB Loan 78.400 0.00 1.38

Interest on GPF 78.852 520.08 475.49

Less:Interest Capitalised 78.900 1,532.04 401.40

Interest Expenses 4,391.56 4,233.17

Bank charges 4.71 19.05

Total 4,396.27 4,252.22

26.1 Under 'Interest Expenses', an amount of Rs.15,32,04,111/- has been capitalised against NRPP.26.2

(a) Interest on State Govt. Loan 165,716,474

(b) Interest on OD A/c 0

(c) Interest on PFC Loan 374,635,766

(d) Interest on GPF 52,008,041

25.2 Under 'Contribution to Provident and Other Funds', 23.31% of Pay and DA of employees who joined in service prior to 01-01-

2004 and 10% of Pay and DA of employees who joined in service after 01-01-2004.


29. The balance amount of Preference Share Capital (Paid up) of Rs.31/- which was remained asit is after transferring of Preference Share Capital (Paid up) to Share Capital during 2011-12 hasbeen withdrawal during the year after taking due approval from the Board of APGCL vide MinutesNo.7(B) of Board Meeting No.53 dtd.07-02-14.

27. OTHER EXPENSES

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Manufacturing ExpensesRepair and Maintenance of Plant and Machinery 74.100 2,060.00 1,612.44

Repair and Maintenance of Building 74.200 181.23 156.54

Repair and Maintenance of Civil Works 74.300 88.84 55.43

Repair and Maintenance of Hydraulic Works 74.400 86.65 101.84

Repair and Maintenance of Lines, Cable Net Works etc 74.500 3.36 0.15

TOTAL 2,420.08 1,926.40Establishment Expenses

Rent Rates and Taxes 76.101-76.102 35.22 22.82

Insurance 76.103-76.106 80.96 125.56

Telephone Charges, 76.107 11.50 12.67

Postage.Telegram& Tele Charges 76.108-76.109 1.15 0.54

Tax Audit Fees 76.130 0.10 0.10

Legal charges 76.110 1.94 43.63

Audit Fee 76.111 2.09 1.90


Technical Fee 76.113 1.80 0.77

Other Professional Charges 76.114 6.66 5.02

Conveyance and Travel 76.115-76.119 117.44 69.52

Other administrative expenses (except 76.130) 76.120-76.190 968.57 353.08

Freight 76.210-76.220 3.28 5.45

Other Purchase related expenses 76.230-76.299 0.45 0.02

Other misc. expenses 76.501 3.42 5.40

Repair and Maintenance of Vehicles 74.600 6.03 9.10

Repair and Maintenance of Furniture and Fixures 74.700 25.91 22.19

Repair and Maintenance of Office Equipment 74.800 7.94 4.72

Less:-Administration and General Expenses capitalised 76.900 0.00 (11.97)

Total 1,293.35 674.54

Prior period items 8,415.19 (6,502.13)

Net Total 12,128.62 (3,901.19)

(a) Prior period income includes:-

(i) withdrawl of excess provision of interest on public bond as per C&AG's comment No.A.1 by Rs. 20,78,46,329/-(ii) withdrawl of excess provision of bond repayment issued via warrant by Rs. 4,04,29,489/-.

(iv) withdrawl of adjustment Jv. No.21 of FY 2012-13 as per POS-11 of C&AG audit by Rs.1,58,37,047/-.(v) withdrawl of excess provision of ROP arrear for FY 09-10 after adjusting actual payment by Rs.10,46,19,575/-.

(vi) withdrawl of ADB loan interest accounted in prior period by Rs.9,53,971/-.

(b) Prior period expense includes:-

28. EARNING PER SHARE (EPS)

Particulars

Account

codes

As on 31-03-2014

(Rupees in lakh)

As on 31-03-2013

(Rupees in lakh)

Net profit After Tax As per Statement of Profit & Loss (8,636.33) (608.41)

Number of Equity Shares 45585975 45585975

Earning Per Share (18.95) (1.33)

Face Value per Equity share 100 100

(iii) withdrawl of provision made against "Assam Building & other Construction Workers Welfare Cess" in prior period as per

C&AG commnent No.A.04 by Rs.1,73,63,728/-.

(i) LD recovered from BHEL against LWHRP booked as other income now rectified & adjusted with asset as per commnent C&AG

No.A.03 by Rs.5,57,11,893/-(ii) Revenue surplus of Rs.96.38 crore for 09-10 and Rs.20.51 crore for 10-11 arrived by AERC while truing up adjusted as per

commnent C&AG No.C.1


30. Against Revision of Pay Rules, 2O1O, APGCL provided a lump-sum provision of Rs.31.75crore for the period w.e.f. 01-01-06 to 31-03-09 in its Annual Accounts for FY 2008-09 andRs.11.49 crore for FY 2009-10 in its Annual Accounts for payment of the arrear to its employees.But the arrear amount was declared to pay from 01-04-09 onwards only vide the said rules. Theprovision made in the annual accounts for FY 2008-09 of Rs.31.75 crore has already beenwithdrawn during the last year. The balance of excess provision of ROP arrear of Rs.10.46 crorehas been withdrawn during the financial year after adjustment with the actual payment.31. The 2x1.5 MW, stage-II of Myntriang Small Hydro Electric Project, Myntriang, Karbi AnglongDistrict, was commissioned on 03-03-2014. The value of asset of stage-II is Rs.37.56 crore.Construction work for stage-I (2x3 MW) and capacity enhancement of both the stages are alsogoing on.32. AERC had issued revenue surplus of Rs.96.38 crore and Rs.20.51 crore for FY 2009-10 andFY 2010-11 while truing up and the same had been adjusted with the tariff order issued toAPDCL. It was commented by C&AG while auditing the annual accounts of APGCL for FY 2012-13 vide comment No.C.1. So, the total amount of Rs.116.89 crore has been provided as priorperiod loss and has been adjusted with receivable against sale of power during FY 2013-14.33. The Fixed Asset Register of APGCL was derived from the opening trial balance of APGCL ason 01-04-05 received on bifurcation of erstwhile ASEB. Over the past years since 2005-06,depreciation was calculated on the basis of this Fixed Asset Register. But during FY 2013-14, amassive physical verification of the fixed assets of APGCL was conducted by the technical wing.Thus, a new Fixed Asset Register alongwith physical verification of the assets was derived fromthe report and depreciation for the year has been calculated on the basis of this Fixed AssetRegister. But due to time differences and calculation of depreciation on the detailed fixed assets,there occurred noticeable difference in various asset groups of fixed asset and depreciation.These differences are shown as adjustments as on 01-04-2013 to both assets and depreciationsin Note-11 of the Annual Accounts. These adjustments neither affect the total fixed asset nor thetotal depreciation, but affect individual asset groups.34. In absence of any specific information available with the Company in respect of any supplierattracting provisions of the Macro, Small and Medium Enterprises Development Act, 2006, nodisclosure/ treatment has been considered necessary in this regard.35. Remuneration to Managing Director: During Financial Year 2013-14, an amount of11,37,233/- was paid as remuneration to the Managing Director.36. Value of imports calculated on C.I.F. basis:Value of imports calculated on C.I.F. basis incurred during the year 2013-14 on import of Capital

goods is 8,18,00,530/-.37. Expenditure in foreign currency (on cash basis):The Expenditure in foreign currency (on cash basis) incurred during the year 2013-14 on import of

capital goods is 8,18,00,530/-.38. Number of employees who are in receipt of emoluments aggregating to 24,00,000/- per

annum or 2,00,000/- per month as per Companies (Particulars of Employees) Rules, 1975 isnil.39. An amount of 3,00,00,000/- was sanctioned as overdraft by pledging fixed deposit of3,00,00,000/- with State Bank of India, New Guwahati Branch.40. The Company prepares Bank Reconciliation Statement regularly.41. Details of remuneration to Auditors:

Particulars Amount ( )

Statutory Audit Fee 1,50,000.00Cost Audit Fee 40,000.00For Tax Audit 10,000.00Total 2,00,000.00


Sl. No. Particulars Previous Year

2012-13

This Year

2013-14

(1) (2) (3) (4)

1 Installed Capacity (MW)

(a) Thermal 60 60

(b) Hydel 102 105

(c) Gas 276.7 276.7

Total 438.7 441.7

2 Power Generated (MU)

(a) Thermal --- ---

(b) Hydel 344.017 422.510

(c) Gas 1421.247 1422.718

Total 1765.264 1845.228

3 Less: Auxiliary Consumption (MU) 133.661 112.381

6 Total power available for sale (MU) 1631.603 1732.847

7 Power sold (MU) 1631.603 1732.847

8 Units generated per MW of installed capacity (in Lakh unit) 40.2 42.1

9 Plant Load Factor (%)

(a) Thermal 0% 0%

(b) Hydel 38.50% 47.29%

(c) Gas 58.63% 58.70%

10 Percentage of generation to installed capacity 53.49% 55.92%


OPERATIONAL PERFORMANCE

ANNEXURE - A


Sl. No. Particulars Previous Year

2012-13

This Year

2013-14

(1) (2) (3) (4)

1 Installed Generation capacity (in MW) at the year end.

(a) Thermal 60 60

(b) Hydel 102 105

(c) Gas 276.7 276.7

Total 438.7 441.7

2 Plant Load Factor (%) 53.49% 55.92%

3 Power Generated (MU)

(a) Thermal --- ---

(b) Hydel 344.017 422.510

(c) Gas 1421.247 1422.718

Total 1765.264 1845.228

4 Auxiliary Consumption (MU) 133.661 112.381

5 Fuel

a) Gas Consumption (MMSCM) 523.50 521.89

b) Average calorific value of Gas (Kcal/SCM) 8442 8509

c) Gas Consumption per unit of generation (in SCM/Kwh) 0.3683 0.3668


ANNEXURE - B

OPERATIONAL PERFORMANCE


I. Registration Details

Registration No. 02-07239 State Code No.: 02

Balance Sheet Date 31-03-2014

II. Capital raised during the year (Amount in Rs. Lakh)

Public Issue: NIL Rights Issue NIL

Bonus Issue: NIL Private Placement: NIL

III. Position of Mobilisation and Deployment of Funds (Amount in Rs. Lakh)

Total Liabilities: Total Assets: 38,691

Source of Funds:

Paid up Capital: Reserves & Surplus: 20,737

Share Deposit

Secured Loans: 33,351 Unsecured Loans: 20,037

Application of Funds:

Net Fixed Assets: 69,936 Investments: 0

Net Current Assets: 35,941 Misc. Expenditure: 0

Accumulated Losses: 17,301 Capital work in progress: 56,898

IV. Performance of Company (Amount in Rs.Lakh)

Turnover: Total Expenditure: 0

Profit/ Loss (-) before Tax: (8,591) Profit/ Loss (-) after Tax: (8,636)

Earning per share in Rs.: (18.95) Dividend rate % NIL

V. Generic Names of Three Principal Products/Services of Company (as per monetary terms)

Item Code No. NIL

Product description Generation of Electricity


BALANCE SHEET ABSTRACT AND COMPANY'S GENERAL BUSINESS PROFILE

Statutory information pursuant to Part IV of Schedule VI to the Companies Act, 1956

ANNEXURE-C

38,691

0

45,586

57,660