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8/1/2019 HSBC Power Utilities
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abcGlobal Research
Equipment ordering for the 11th Plan
completed; focus turns to executionWe examine the status of current
projects; firms with operating experience
and financial stability emerge as winnersReiterate OW(V) on CESC and Tata
Power, N(V) on Lanco; downgrade NTPC
to UW(V) from N(V)Focus to shift on execution. Equipment ordering is now
complete for the 11th Plan, achieving a critical milestone in
project execution. Now, the focus will shift towards project
developers in terms of project completion. We have looked at
the status of projects under construction for stocks we cover.
We prefer developers with operating experience, financial
stability and projects that have achieved financial closure.
CESC: OW(V), TP = INR345. We like CESC primarily
because of its gradual capacity addition plan, which prevents
it from spreading itself too thin. We ascribe no value to the
real estate and retail businesses and retain our estimates,target price, and rating.
Tata Power: OW(V), TP = INR1,000. Its 5.6GW of capacity
addition is supported by fuel sourcing and funding strategy. We
reduce our FY10e profit estimates by 21% to incorporate lower
coal realisation; we lower our target price to INR1,000.
Lanco Infratech: N(V), TP = INR132. 3.9GW of power
projects are in advanced stages of execution, with 600MW to be
operational by FY10e. However, real estate and infrastructure
development continue to drag. We reduce our FY10e estimates
by 18% and lower the target price to INR132.
NTPC: UW(V), TP = INR142. NTPC enjoys the best
positioning in terms of access to funds and fuels, but the market
is ignoring delays in project execution (HSBC estimates
11.9GW vs companys guidance of 22GW). Maintain our
estimates and target, but downgade to UW(V).
Natural Resources & Energy
Indian Utilities
Indian UtilitiesFocus on project execution
14 January 2009
Sumeet Agrawal*
Analyst
HSBC Securities and Capital Markets (India) Private Limited
+91 22 2268 1243 [email protected]
Sumit Agarwal*
Associate
Bangalore
View HSBC Global Research at: http://www.research.hsbc.com*Employed by a non-US affiliate of HSBC Securities (USA) Inc,and is not registered/qualified pursuant to NYSE and/or NASDregulations
Issuer of report: HSBC Securities and Capital Markets (India)Private Limited
Disclaimer & DisclosuresThis report must be read with thedisclosures and the analyst certificationsin the Disclosure appendix, and with theDisclaimer, which forms part of it
Valuation summary (INR)
Name Curr.
price
Ticker New
rating
Sales
(bn)
EBITDA
(bn)
PAT
(bn)
New
TP
Old
TP
Potl
Return
CESC 242 CESC OW(V) 30.50 7.03 3.53 345 345 45%Lanco 111 LANCI N(V) 34.01 7.54 4.09 132 335 19%NTPC 171 NATP UW(V) 418.19 131.41 82.10 142 142 -15%Tata Power 727 TPWR OW(V) 146.19 38.52 20.97 1,000 1,244 41%
Source: HSBC estimates
http://www.research.hsbc.com/http://www.research.hsbc.com/http://www.research.hsbc.com/http://www.research.hsbc.com/8/1/2019 HSBC Power Utilities
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Focus turns to execution 3From orders to execution 3
Potential winners 3
BHEL to benefit from capacity addition 5
NTPC capacity addition plan 5
We prefer Tata Power among private-sector utilities 7
CESC Ltd (CESC) 12Key triggers 13
Valuation 14
Risks 14
Financials & valuation 15
Lanco Infratech (LANCI) 16De-risking the power portfolio 16
Valuation 18
Risks 19
Financials & valuation 20
NTPC Ltd (NATP) 21Strong project pipeline, but poor execution 21
Should continue to trade at a premium 22
Valuation 22
Risks 23
Financials & valuation 24
Tata Power (TPWR) 25Best-placed Indian utility 25
Fuel and funds well tied up 26
Valuation 27
Risks 28
Financials & valuation 29
Annexure 30Hectic equipment ordering in 2008 30
Why were targets not met? 30
Disclosure appendix 32
Disclaimer 36
Contents
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From orders to execution
The size of power equipment orders formed a
large part of news flow in 2008 for Indian utilities
equipment for power projects worth 15GW wasordered during the year. The Ministry of Power
pushed for power projects financial closure to
achieve the 11th Five-Year Plan (2007-2012)
target (c79GW power projects).
The order flow is over; it is now time to get down to
brass tacks and focus on execution. We contend that
this will be the big driver over the next three years.
We examine the order flows of utilities companies
under our coverage and maintain that the winners
will be those with operating experience, financial
stability, and projects that have achieved
financial closure.
Potential winners
Central utilities to dominate capacity
addition
We remain positive in terms of capacity addition
by central utilities. We expect central utilities to
dominate capacity addition with c21.7GW (45%
of total capacity). Central utilities like NTPC and
Damodar Valley Corporation should be front-
runners in terms of this capacity addition.
Private sector: who will win?
The exuberance in the power sector resulted in a
host of announcements by private players in terms
of capacity addition plan. c150GW of new
capacity addition, almost equivalent to Indias
current installed base, was announced by different
private-sector entities.
We remain cautious in terms of these capacities
finally coming on stream over the next decade.
We maintain that it is difficult for the entire
c150GW to be operational, given the funding
requirement as well as execution risk. After our
ground reality check, we believe only 17GW of
the expected 20GW of the 11th Plan private-
sector capacity addition has achieved financial
closure.
Key projects awaiting financial closure
600MW Reliance Power Rosa II
3960MW Reliance Power Sasan UMPP (2
units of 660MW each, expected for
commissioning in the 11th Plan)
540MW Goindwal Sahib by GVK Power(equipment order placed)
2400MW Sterlite Energy power project
Focus turns to execution
With the crucial milestone of equipment ordering for the 11th Plan
complete, the focus will now shift of project execution
Delays likely unavoidable due to on-the-ground issues, which will
result in demand outstripping supply
We expect central and state utilities to dominate capacity addition
as the private sector scales back its capacity addition
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Private power projects in the 11th Plan (MW)
Plant name State Agency Ultimatecapacity
Capacity in11th Plan
Coal linkagestatus
Equipment vendor Financialclosure
Expected dateof commission
Thermal coalAmarkantak Pathadi (Lanco) U2 Chattisgarh Lanco 300 300 Linkage Zelan, Malaysia Achieved 2009-10Amarkantak Pathadi (Lanco) U1 Chattisgarh Lanco 300 300 Linkage Zelan, Malaysia Achieved 2008-09Anpara C Uttar Pr Lanco 1,000 1,000 Linkage Dong Fang, China Achieved 2011-12Budge Budge Ext. West Bengal CESC 250 250 Block BHEL Achieved 2009-10Goindwal Sahib Punjab GVK 540 540 Block BHEL Not achieved 2011-12Jalipa/ Kapurdi-Lignite Rajasthan IPP 1,080 1,080 Shanghai Electric, China Achieved 2009-11JSW Ratnagiri Maharashtra JSW 1,200 1,200 Imported coal Shanghai Electric, China Achieved 2010-12Trombay TPS Maharashtra Tata Power 250 250 Imported coal BHEL Achieved 2008-09Sasan UMPP U1,2 Madhya Pr Reliance Energy 3,960 1,320 Block REL (main equipment by
Shanghai Electric, China)Not achieved 2011-12
Lanco-Nagarjuna Karnataka Lanco 1,015 1,015 Imported coal Dongfang, China Achieved 2010-11Maithan Jharkhand Tata Power 1,050 1,050 Linkage BHEL Achieved 2010-12Mundra TPP Adani Gujarat Adani 1,320 1,320 Imported coal Sepco III, China Achieved 2011-12Mundra TPP Adani Gujarat Adani 1,320 1,320 Imported coal SCMEC, China Achieved 2009-11Raigarh Chatt isgarh Jin. Power 750 750 Block BHEL Achieved 2007-08Raigarh Chatt isgarh Jin. Power 250 250 Block BHEL Achieved 2008-09Rosa St I Uttar Pr Reliance Power 600 600 Linkage Shanghai Electric, China Achieved 2010-11Rosa ST II Uttar Pradesh Reliance Power 600 600 Linkage Shanghai Electric, China Not achieved 2011-12Sterlite Energy Orissa Sterlite 2,400 600 SEPCO, China Not achieved 2009-10Mundra UMPP Gujarat IPP 4,000 1,600 Imported coal Doosan, Korea + Toshiba Achieved 2011-12Torangallu Karnataka JSW 600 600 Imported coal China Achieved 2008-10
Thermal Gas/LNGGautami Andhra Pr Gautami Power 464 464 Alstom Achieved 2008-09Konaseema Andhra Pr Oakwell 445 445 Larsen & Toubro Achieved 2008-09Kondapall i CCPP II Andhra Pr Lanco 366 366 Gas/LNG GE Achieved 2009-10Rithala CCPP Delhi NDPL 108 108 Gas/LNG China Not achieved 2009-10
Sugen Torrent Gujarat Torrent 1,128 1,128 Siemens Achieved 2008-10HydroAllain Duhangan Himachal Pr RSWML 192 192 BHEL Achieved 2009-10Budhi l Himachal Pr Lanco 70 70 Dongfang, China Achieved 2009-10Chujachen Sikkim Gati 99 99 Alstom Achieved 2009-10Karcham Wangtoo Himachal Pr JPKHCL 1,000 1,000 Voith Siemens Achieved 2011-12Maheshwar Madhya Pr IPP 400 400 BHEL Achieved 2011-12Malana II Himachal Pr Everest Power Co 100 100 Dongfang, Hong
Kong+Aviera IndiaAchieved 2009-10
Sorang Himachal Pr Sorand PowerCo
100 100 Voith Siemens Not achieved 2011-12
Srinagar Uttarakhand GVK 330 330 BHEL Achieved 2011-12Teesta III Sikkim Teesta Urja 1,200 1,200 Consortium including SEW
& ABIRAchieved 2011-12
Notes: SEW=SEW Infrastructure Limited; ABIR: ABIR I nfrastructure Private Limited; SEPCO=Shandong Electric Power Construction Corp.; RSWML=Rajasthan Spinning and Weaving Mills Limited; JPKHCL=Jaiprakash KarchamWangtoo Hydroelectric Project; NDPL=North Delhi Power Project Limited
TPP=thermal power projects; CCPP=combined cycle power projects; IPP=independent power producerSource: CEA, HSBC
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Impact of credit crisisGiven the current credit crisis, we expect debt
financing to private-sector projects based on
merchant or aggressive competitive tariff will be
difficult. Lending institutions have also been
reluctant to lend at 80:20 debt to equity. We
expect debt to equity to be 70:30.
We believe the recent credit crisis will be
beneficial to the private sector in long term. Non-
availability of funds has forced the private sectorto bid for projects at a more reasonable tariff. In
recent bidding invited by the Punjab State
Electricity Board, a sole private developer quoted
a levelised tariff of cINR3.38 per unit. This is
somewhat higher than bids of less than cINR2.0
per unit for earlier thermal power projects. Thus,
aggressive bidding by the private sector has taken
a back seat, and projects are bid for at prices that
make economic sense.
We believe this financial crunch will help
companies with strong balance sheets and the
ability to raise funds emerge as the clear winners.
We prefer such companies.
Developers with projects in advanced
stages of development
We maintain a positive view on projects that have
achieved financial closure and significant progress
in terms of execution.
In this scenario, private utilities will be a mixed
bag; developers like Tata Power and CESC should
be better placed in term of achieving their
capacity addition target.
BHEL to benefit from capacityaddition
BHEL was a major beneficiary of this rush toward
equipment order placement. Quality concerns of
imported equipment as well as currencymovement helped BHEL to secure c60% market
share for projects awarded for 11th Plan.
BHELs success in term of maintaining its
leadership position has put to rest concerns of
global competition. In the recent past, BHEL has
been able to gain some of its lost ground in
private-sector utilities. It has been able to secure
equipment orders from developers like Jindal
Power (2,400MW, INR50bn) and Jaiprakash
Power (500MW, INR11.75bn).
Equipment vendors for thermal based power projects (MW)
FY08a FY09e FY10e FY11e FY12e TotalCentral BHEL 1,250 1,750 1,990 5,765 5,501 16,256Central Others 740 0 1,320 1,260 1,920 5,240State BHEL 2,680 870 4,192 5,202 5,291 18,235State Others 1,200 392 374 1,200 600 3,766Private BHEL 750 500 250 0 540 2,040Private Others 0 2,261 3,520 3,145 6,440 15,366Total BHEL 4,680 3,120 6,432 10,967 11,332 36,531
Others 1,940 2,653 5,214 5,605 8,960 24,372Total Overall 6,620 5,773 11,646 16,572 20,292 60,903
Source: CEA, HSBC estimates
NTPC capacity addition plan
NTPC has targeted for 22GW of capacity additionplan. However, some projects are facing
significant delays. Central Electricity Authority
(CEA), in its recent report, has indicated
c15.4GW of capacity addition by NTPC in the
11th Plan.
NTPCs capacity addition status
Status MW
Capacity commissioned 2,740Under implementation 15,930
Yet to be awarded 3,760Source: Company, HSBC estimates
We do not think there is concern regarding
funding at NTPC, which has cINR170bn in cash
on its balance sheet and a cINR150bn line of
credit. Its debt-to-equity ratio of c0.5:1 provides
scope for future domestic bond issuances, or even
raising ECBs after a few months, once the global
credit scenario improves.
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Key reason for delays
c3.76 GW of capacity from 11th Plan projects
yet to be awarded to equipment vendors
Ongoing negotiation between its international
vendor, Technoprom Exports (TPE) and
Power Machines of Russia for increase in
project cost for 1320MW Bahr project
Delay in deployment of EPC contractors by
BHEL and other equipment manufacturers
Hydro power project affected due to non-
availability of regulatory clearance
To mitigate any delays/lapses in capacity addition,
NTPC has identified c3GW of brown field
capacity addition and is looking at awarding these
projects by FY09-10e.
NTPC additional capacity addition plan
Project/Location Capacity
Vindhyachal 1,000Rihand 1,000Vallur 500Muzaffarpur 500
Source: Company, HSBC
Despite all these efforts, we expect NTPCscapacity addition to fall short of the plan. We
expect NTPCs capacity addition to lag behind its
NTPCs generation capacity addition plans
Plant Name Ultimatecapacity
Capacity to beoperational in 11thPlan
Ordered to Expected date ofcommissioning
Status
Thermal ProjectsBarh-I 1,980 1,320 Technoprom,
Russia2011-12 Various units likely to be commissioned by June 11, Dec 11 and March
12. Civil and structural work for main plant in progressVallur Ennore JV 1,000 1,000 BHEL 2011-12 Scheduled for commissioning in November 2010Bhilai JV 500 BHEL 2008-09 U 1 commissioned. U 2 synchronisation of turbine expected,
synchronisation on designated fuel due in Jan 09. Coal handling plantcompleted & ash handling plant to be ready by Jan 09
Bongaigaon 750 750 BHEL 2010-12 Units expected to go on steam in October 2010 and November 2010.Boiler piling is in progress
Dadri Ext. 980 980 BHEL 2009-11 U 5 scheduled for commissioning in Sep 09. Turbine generator (TG)erection under way. TG deck testing for U 6 also done. Hydro testcompleted in Nov 08. Unit 6 boiler erection in progress
Farakka Stage-III 500 500 BHEL 2010-11 Commissioning likely August 2010. Work on the steam generator (SG) inprogress; Boiler erection in progress
Kahalgaon II Units (U) 6 & 7 1,000 1,000 BHEL 2007-09 Expected to slip to the 4Q09 vs 3Q09 earlier. Coal firing already complete;delay as coal bunker to be ready only by Jan 09
Indira Gandhi TPP (Jhajjar)JV
1,500 1,500 BHEL 2010-11
Korba III 500 500 BHEL 2010-11 Anticipated date of commissioning Feb 10. Unit hydro test likely in Feb09; TG deck casting complete
Nabinagar 1,000 750 BHEL 2011-12Ratnagiri (Dhobol) JV 740 740 GE 2007-08Simhadri-Ext. U 3 & 4 1,000 1,000 BHEL 2011-12 U 3 scheduled for commissioning in Nov 10. SG work in progressSipat I 1,980 1,980 Doosan,
Korea+PowerMachines,
Russia
2009-11 Under implementation. Anticipated dates of commissioning the two units:Sep 09 and Mar 10 slipped to FY10, against its original target of 3Q09
Sipat II U 4 & 5 1,000 1,000 BHEL 2007-09 Original target 1Q09; now scheduled for 3Q09Hydro ProjectsKol Dam 800 800 BHEL 2009-10 Various units anticipated to be commissioned in Dec 10, Jan 11, Feb 11
and Mar 11. Dam filling work in progressLohari Nagpala 600 600 2011-12 3x150MW units targeted for commissioning in 2012-13. Work on head
race tunnel (HRT), barrage, desilting chambers and power house underway
Tapovan Vishnugarh 520 520 2011-12 All 4 units targeted for commissioning during 2011-12. Work related toHRT, barrage, desilting chambers and power house in progress
Source: Industry, HSBC
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plan and expect it to add c11.9GW of new
capacity between FY08 and FY13e. We have
extended the project execution timeline for c10
GW projects and expect these to be operational
during the 12th Plan.
We believe there is a significant risk in terms of
NTPC achieving its capacity target, given the fact
that 63% of expected capacity is scheduled for
commissioning in FY11-12.
We prefer Tata Power amongprivate-sector utilities
We expect Tata Power to be well placed with its
5.6GW capacity under construction on track.
Funding tie-up
Tata Power has completed financing for two of its
largest power plants under construction i.e., the
1050MW Maithon project, for which the debt
component of cINR30bn is being funded by a
consortium led by the State Bank of India. For its
Mundra project, the company has tied up to raise
USD1.8bn in foreign exchange loans and
USD1.4bn in INR loans with several multilateral
and domestic financial institutions. With these
two big projects, most of the groups funding for
plants under construction has been tied up.
Funding for remaining smaller projects, such as
captive projects at Jojbera and Jamshedpur, is at
advanced stages of reaching financial closure. Of
the total funding requirement of INR240bn during
the next four years, Tata Power proposes to raise
the amount through its own contribution and debt
(INR180bn), a large portion of which is already
tied up (INR60bn).
Equity funding of INR66bnTata Power requires INR60bn of equity funds for
its projects under construction. Sources to meet its
own funding requirement have been identified as
INR29bn from internal accruals, with INR12bn to
be obtained through sales of investments in
various group companies. Any shortfall should be
met through short-term borrowing in the interim.
We expect that given the weak equity market
scenario, fund raising through sales ofinvestments and warrants will be a challenge. The
warrant conversion price was cINR1,357 per
share, which was above the prevailing market
price. Hence, Tata Powers management had not
subscribed to the warrant.
We expect Tata Power to raise short-term debt to
fund balance equity. However, we do not expect
this to affect its capacity addition. It has already
invested cINR20bn of its equity contribution in
projects. We expect that, given the credit rating
and developer support, raising short-term debt
will not be an issue, and that Tata Power can raise
sufficient funds for its expansion plan. Hence, we
maintain that there is no significant risk to its
5.6GW of projects under construction.
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However, we expect the projects in the pipeline to
be delayed, given the equity fund constraints.
Hence, we believe this will put projects under
pipeline at risk. Hence, there can be uncertainty
around 5.7GW of power capacity addition plan.
The NPV of these five projects (Dehrand, Naraj
IPP, Naraj CPP, Tubed IPP, Jharkhand CPP)
based on Tata Powers ownership is cINR15.6bn,translating into INR71 per share. We assign no
value to these projects, as against 50% earlier.
CESC: Gradual capacity addition a
positive
What we like about CESC is its gradual
generation capacity addition plan, which prevents
it from spreading itself too thin.
It has an installed capacity base of 975MW,
including the 100MW New Cossipore Generating
Station, which is to be decommissioned in the
next two years. The company expects to add
Tata Powers generation capacity addition plans
Project Capacity(MW)
Projectcost(INRbn)
Debttoequity
Debt(INRbn)
Equity(INRbn)
Developerstake (%)
Developerequity (INRbn)
Status of fundingclosure
Fuel type Fuel source
UnderconstructionMundra 4,000 170.00 75:25 127.5 42.5 100% 42.5 Done, with USD1.8bn
forex loan andUSD1.4bn rupee loan
Imported coal 10mtpa offtake agreement withKPC*/Arutmin, pricing part fixedand part linked to CERC Index
Maithon (74%stake)
1,050 44.50 70:30 31.2 13.4 74% 9.9 Done; funded byState Bank of India
Domestic coal Fuel linkage from Bharat CokingCoal mines
Jamshedpur andJojobera
240 11.10 70:30 7.8 3.3 74% 2.5 In advanced stage ofcompletion
Tollingarrangement
Coke oven gases of Tata Steel,and linkage from West Bokaroand Mahanadi coal fields
Trombay Expansion 250 10.66 70:30 7.5 3.2 100% 3.2 In advanced stage ofcompletion
Imported coal Imported coal, cost pass-through
Haldia 120 6.05 70:30 4.2 1.8 100% 1.8 In advanced stage ofcompletion
Tollingarrangement
Hot flue gases from HooglyMetcoke
Sub-total 5,660 242 178 64 60In the pipelineCoastalMaharashtra
2,400 101 70:30 75.6 25.2 100% 25.2 Imported Coal Coal from Bumi Resourcesofftake
Naraj MarthapurIPP
1,000 42.0 70:30 29.4 12.6 100% 12.6 Domestic coal Mandakini Coal Block
Naraj MarthapurCPP
1,270 53.3 70:30 37.3 16.0 74% 11.8 Tollingarrangement
Supply by procurers
Tubed IPP 500 21.0 70:30 14.7 6.3 100% 6.3 Domestic coal Captive coal blockJharkhand CPP 500 21.0 70:30 14.7 6.3 74% 4.7 Tolling
arrangementSupply by Tata Steel
Sub-total 5,670 238 172 66.4 60.6Total 11,330 480 350 131 120
* KPC= Kaltim Prima CoalSource: Company, HSBC estimates
CESCs generation capacity addition plans
Location Businessmodel
Size Cost (INRbn) COD Remarks
Budge Budge Regulated 250 12 2009-10 Under implementation, commissioning in September 2009Haldia I Regulated 600 26 2010-11 70% land acquired, long-term coal linkage obtained, evacuation and railways
feasibility study completed, no-objection certificate obtained for water drawalDhumka, Jharkhand Merchant 1,000 40 2012-13 110m tonnes coal block allocated, memorandum of understanding (MoU) signed
with Jharkhand Govt., land acquisition process initiated
Dhenkanal, Orissa Merchant 1,000 40 2013-14 MoU signed, land acquisition process initiated, coal allocation being pursued
Thermal/hydel power plantsin West Bengal/other states
Merchant 1,300-1,500MW 60 2013-14 Cabinet approval received for 1800 MW power plant at Pirpainti, Bihar
Source: Company, HSBC estimates
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c1.85GW capacity by FY12-13e and an additional
2.3GW by FY14-15e, thus increasing its existing
capacity by 5x. It has already secured fuel for the
new 1.8GW power generation capacity and has
achieved financial closure for 50% of the new
projects, thus providing good visibility and
reducing execution risk. However, we have not
factored into our valuation the 2.3GW of capacity
to come by FY14-15e, as not much action has
been taken yet.
The status of the 1.85GW capacity under
development is as follows:
250MW Budge Budge expansion under
construction; to be operational by FY10
600MW Haldia phase I: Land acquisition in
progress. Received coal linkage from
Mahanadi coal mine, looking at awarding the
equipment contract; project cost cINR26bn
1000MW Dumka, Jharkhand to be a merchant
power plant. Received coal linkage from
Mahugadi coal block; land acquisition in
progress
We have extended project execution timelines for
CESCs Haldia and Dumka projects. We expect
Haldia to be commissioned in FY13. We have not
considered Dumka for valuation purposes.
Lanco InfratechLanco has undertaken an aggressive capacity
addition plan. It has a pipeline of c4GW of
capacity under construction and another c4GW in
the pipeline.
Financial closure has been achieved for projects
under construction, and execution activity started.
It has incurred INR50bn capex on these projects
so far, including INR22bn equity contribution.
We expect 600MW of Amarkantak I and II
thermal power plants to be operational by
1HFY10. In terms of other capacity, 1015MW
Nagarjuna Power project and Anpara C are major
contributors and we expect them to be operational
by April 2012 and January 2012 respectively.
Hence, we believe the risk to these capacity
additions is not significant.
However, we expect delay in capacity addition of
3.9GW projects in the pipeline (2.64GW Babandhand 1.3GW Amarkantak). We expect them to be
extended beyond FY12e and hence have not
factored in these in our estimates.
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Lancos generation capacity addition plans
Projects Location Fuel Capacity(MW)
Est. projectcost (USDm)
Holding(%)
PPA(years)
Powerofftaker
Capexspent so
far (INRm)
Est.COD
Status
Projects under executionAmarkantak I Chhattisgarh Coal 300 284 76% 25 PTC India 20,118 Feb-09 Boiler hydro test completed Dec 07, switchyard
charged, switchyard connected to gridAmarkantak I I Chhat tisgarh Coal 300 296 76% 25 PTC India Sep-09 Boi ler drum l if ting completed Dec07, hydro testing
completed, turbine generator (TG) erectedVamshiHydro
HimachalPradesh
Hydro 10 12 91% 35 PunjabSEB
1,234 Dec-09 Under commissioning
VamshiIndustrial
HimachalPradesh
Hydro 10 12 91% 35 PunjabSEB
Dec-09
Lanco Green HimachalPradesh
Hydro 70 92 90% 35 PTC India 1,992 Apr-11 River divers ion completed in Oct 07, river bedexcavation of dam completed. Commissioningexpected in Dec 09 by company
Kondpalli-II AndhraPradesh
Gas 400 300 59% Merchant NA 904 Apr-10 Piling completed, erection of columns in ECB started
Udupi(Nagarjuna)
Karnataka Imported Coal
1,015 955 74% 25 KarnatakaSEB
14,534 Apr-12 Boiler drum lifting, TG casting done. TG erection tostart soon. For U 2, boiler erection completed
Lanco Energy Sikkim Hydro 500 660 74% 35 PTC Ind ia 5,704 Jul-12 Civ il work for tunnel in progressLancoUttaranchal
Uttarakhand Hydro 152 220 90% Merchant NA 577 Apr-12 Techno-economic clearance received, infrastructuredevelopment under way
Anpara C U ttar Pradesh Coal 1,200 1,100 100% 29 UttarPradesh
SEB
5,411 Jan-12 U 1: Boiler foundation done, boiler erection to begin.U 2: construction of boiler foundation in progress
Total 3,957 3,931 50,474
Power projects under developmentBabandh Orissa Coal
(partly
owned)
2,640 2,970 100% 25 yearsand
Merchant
MP, Orissaand
HaryanaSEBs
Apr-14 Captive mine allocated, land acquisition initiated,PPAs secured. Financial closure in process
AmarkantakIII & IV
Chatt isgarh Coal 1,320 1,300 76% Merchant NA Apr-13 Financial c losure process under way
Total 3,960 4,270
Source: Company, HSBC
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Company profiles CESC Lanco Infratech
NTPC
Tata Power
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CESC is an integrated utility player under the
flagship of RPG Enterprises. With installed
capacity of 975MW and a customer base of 2m, the
company accounts for c13% of installed generation
in the state of West Bengal and c90% share of
installed capacity by the private sector in the state.
Gradual capacity addition plans
What we like about CESC is its gradual generation
capacity addition plan, which prevents it from
spreading itself too thin. It has an installed capacity
base of 975MW, including the 100MW New
Cossipore Generating Station, which is to be
decommissioned in the next two years. The
company expects to add c1.85GW capacity by
FY12-13e and an additional 2.3GW plant by FY14-
15e, thus increasing its existing capacity by 5x. It
has already secured fuel for the new 1.8GW and has
achieved financial closure for 50% of the new
projects, thus providing good visibility and reducing
execution risk. However, we have not factored into
our valuation the 2.3GW of capacity to come by
FY14-15e, as not much action has been taken yet.
Excellent operating performance at
existing generation plants
During the year ended March 2008 (FY08), all
three power plant stations achieved a combined
PLF of c97%, the highest levels ever recorded by
those stations. These projects also featured in the
list of top generating stations with highest
capacity utilisation factors in the country.
CESC Ltd (CESC)
Integrated utilities player with gradual capacity addition plans
Current market cap 1.36x of regulated equity base, indicating little
value ascribed by the market for upcoming projects, retail and real
estate businesses
Reiterate Overweight (V) and INR345 target. Catalysts include
turnaround of retail business and financial closure on some projects
CESCs generation capacity addition plans
Location Purpose Size Cost(INRbn)
COD Remark
Budge Budge Regulated 250 12 2009-10 Under implementation, commissioning in September 2009
Haldia I Regulated 600 26 2010-11 70% land acquired, long-term coal linkage obtained, evacuation & railways feasibility studycompleted, no-objection certificate obtained for water drawal
Dhumka, Jharkhand Merchant 1000 40 2012-13 110m tonnes coal block allocated, memorandum of understanding (MoU) signed withJharkhand Govt., land acquisition process initiated
Dhenkanal, Orissa Merchant 1000 40 2013-14 MoU signed, land acquisition process initiated, coal allocation being pursued
Thermal/hydel power plantin West Bengal/other states
Merchant 1300-1500MW 60 2013-14 Cabinet approval received for 1800 MW power plant at Pirpainti, Bihar
Source: Company, HSBC estimates
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The Budge Budge plant, with a PLF of 100.4%, had
the second highest thermal power plant PLF in India
during FY08. It has also received INR115m of
carbon credit this year, for the last four years
performance. The steady performance of all the
generation units helped the company achieve a
combined PLF of 93.4% for FY08, which was
better than the national average of 78.6% and the
private-sector average of 90.8%.
In the T&D division, it has considerably reducedlosses through reduction of pilferage and better
collection efficiency.
Fuel tied up, financial closures
awaited
Capex plan for future projects
Project Capacity(MW)
Projectcost
(INRbn)
Debt/equity
Debt(INRbn)
Equity(INRbn)
Haldia I 600 26 70:30 18.2 7.8Dumka Jharkhand 1,000 40 70:30 32 12
Sub-total 1,600 66 46.2 19.8
Capex in T&D (fornext three years)
13.5 70:30 9.45 4.05
Fund for SpencersRetail (till FY10e)
4.5 70:30 3.15 1.35
Sub-total 84 58.8 25.2
Dhenkanal Orissa 1,000 40 70:30 28 12Haldia II 1,800 60 70:30 42 18Total 184 129 55.2
Source: Company, HSBC estimates
CESC has already tied up the fuel requirement for
these projects. It has achieved financial closure for
the 250MW Budge Budge expansion and is
looking at financial closure for its projects at
Haldia (West Bengal) and Dumka (Jharkhand). We
expect financial closure for Haldia soon because (a)
land acquisition is at an advanced stage, (b) fuel
supply has been assured, and (c) Haldia is based on
a regulated model, thus ensuring its ROE.
We expect CESC to fund the equity contribution
(cINR21.2bn) through (a) INR10bn cash and cash
equivalents, including INR5.8bn in qualifiedinstitutional placement (QIP) money, and (b)
internal accrual of INR10bn. We expect CESC to
be able to fund its Haldia project once required
land acquisition and approval is received.
However, it will require an additional INR30bn
for projects in the pipeline. Funding will be an
issue for these projects (2.8GW) which are at an
initial stage of development e.g., Dhenkanal and
others. We havent considered any of these
projects into our valuation, given uncertainty
attached to these projects.
Current market cap vs regulatedequity base attractive valuation
The current market cap of INR29.3bn is at only
36% premium to the approved regulated equity
base of INR21.5bn for FY10e after incorporating
the Budge Budge capacity expansion, of 250 MW.
Based on regulated return of 14% RoE, and an
allowed depreciation charge of INR1.68bn and
INR2.04bn for FY09 and FY10 respectively, we
expect that the company generates minimum cashprofits of INR4bn and INR4.8bn in the next two
years. This profit does not assume any incentives
and rental income that CESC has been historically
receiving due to its efficient operation. Hence,
even considering minimum cash profit level, it is
trading at only 6x FY10e cash profit.
Efficient operations achieved by its operating
plants help CESC generate higher RoE over the
assured 14%. As CESC exports power at a higher
rate and is allowed to keep 40% of profit from
export sales, it adds to the profitability over and
above the prescribed return.
All of the above indicates that the market is ascribing
little value to the companys capacities under
construction, and its retail and real estate businesses.
Key triggers
Financial closure of power projects
600MW Haldia power project. This is at an
advanced stage; CESC expects it to be completed
soon, and has acquired c75% of the land and
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obtained coal linkage. It has received
environmental and water consumption clearance.
1000 MW Dhenkanal Power Project. CESC
expects to achieve financial closure for this
project by the end of this year. However, we have
not considered this in our projection.
Turnaround of the retail business
CESC has moderated its retail business rollout plan
with 1.7msq ft of retail space by FY09e. This
amounts to only a 0.55m sq ft addition, down from
1m sq ft planned previously. It is focusing on large
formats for growth, as well as closing unviable and
unprofitable outlets. Management expects the
business to see turnaround by FY10-11.
Value unlocking in the Spencers
Retail business
Spencers Retail, 95% owned by CESC, is using
cash generated from the CESC power business.
However, if CESC is able to unlock value from
Spencers by getting a strategic investor, this
would add a valuation benchmark. We assign no
value to Spencers Retail.
HSBC vs consensus
HSBC vs consensus (INRbn)
____Sales___ ____ PAT ___ EPS ( INR/share) _INRbn FY09e FY10e FY09e FY10e FY09e FY10e
HSBCestimates
30.50 32.39 3.53 3.77 28.1 30.0
Consensusestimates
30.46 33.43 3.63 4.08 29.0 32.5
% difference 0% -3% -3% -7% -3% -8%
Source: HSBC, Reuters
Valuation
We maintain our CESC estimates and our 12-
month target price to INR345, an average of the
following three methods.
Discounted cash flow
Discounting the future cash flows of the company
assuming WACC at 12.8% and a terminal growth
of 3%, we value the company at INR234 per
share.
Sum of the parts
We value the present capacity installed at the
replacement cost multiple of 46.5x and value the
investments of the company to its book value. We
assign no value to the retail business because it is
unprofitable, and there has been significant
correction in the retail peer valuation. We value it
at INR375 per share on SOTP basis.
Price to book
We have valued CESC at INR426.5, using a
multiple of 0.97x book value for FY10e.
Based on the average of all the three methods, we
derive a target price of INR345, and retain our
estimates.
Target price derivation
INR per shareSOTP 375DCF 234PB 426.5Target price 345
Source: HSBC estimates
Under our research model, for stocks with a
volatility indicator, the Neutral band is 10
percentage points above and below the hurdle rate
for Indian stocks of 11%. For CESC, this
translates into a Neutral band of 1-21% around the
current share price. Our target price of INR345 for
CESC shares implies a total return (including
dividend yield) of 44.7%, which is above the
Neutral band; thus, we have an Overweight (V)
rating on CESC stock.
Risks
Downside risks, we believe, include deeper-than-
expected losses in the retail business and cost
overruns from delayed execution.
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Financials & valuation: CESC Ltd Overweight (V)Financial statements
Year to 03/2008a 03/2009e 03/2010e 03/2011e
Profit & loss summary (INRm)
Revenue 35,428 30,498 32,392 34,383EBITDA 3,977 7,028 7,780 8,489Depreciation & amortisation -1,962 -2,913 -3,141 -3,688Operating profit/EBIT 2,015 4,114 4,639 4,801Net interest -1,480 -2,068 -2,315 -2,539PBT 2,496 4,008 4,287 4,224HSBC PBT 2,496 4,008 4,287 4,224Taxation 131 -481 -514 -507Net profit 2,674 3,527 3,772 3,717HSBC net profit 2,674 3,527 3,772 3,717
Cash flow summary (INRm)
Cash flow from operations 6,356 4,328 7,105 7,777Capex -8,937 -16,218 -14,900 -12,300Cash flow from investment -8,937 -16,218 -14,900 -12,300Dividends -343 -743 -794 -783Change in net debt -155 12,633 8,590 5,306FCF equity -4,544 -13,852 -9,757 -6,485
Balance sheet summary (INRm)
Intangible fixed assets 0 0 0 0Tangible fixed assets 62,371 75,676 87,435 96,047Current assets 21,168 19,704 20,024 20,227Cash & others 10,170 10,170 10,170 10,170
Total assets 89,546 101,386 113,466 122,280Operating liabilities 23,490 19,914 20,425 21,000Gross debt 20,683 33,316 41,906 47,211Net debt 10,513 23,146 31,736 37,041Shareholders funds 45,362 52,204 55,182 58,117Invested capital 49,879 65,296 76,864 85,104
Ratio, growth and per share analysis
Year to 03/2008a 03/2009e 03/2010e 03/2011e
Y-o-y % change
Revenue 42.6 -13.9 6.2 6.1EBITDA -31.2 76.7 10.7 9.1Operating profit -52.0 104.2 12.8 3.5
PBT -26.7 60.5 7.0 -1.5HSBC EPS -37.5 24.2 7.0 -1.5
Ratios (%)
Revenue/IC (x) 0.7 0.5 0.5 0.4ROIC 4.4 6.3 5.7 5.2ROE 6.4 7.2 7.0 6.6ROA 5.1 5.6 5.4 5.0EBITDA margin 11.2 23.0 24.0 24.7Operating profit margin 5.7 13.5 14.3 14.0EBITDA/net interest (x) 2.7 3.4 3.4 3.3Net debt/equity 23.2 44.3 57.5 63.7Net debt/EBITDA (x) 2.6 3.3 4.1 4.4CF from operations/net debt 60.5 18.7 22.4 21.0
Per share data (INR)
EPS Rep (diluted) 22.62 28.08 30.04 29.60HSBC EPS (diluted) 22.62 28.08 30.04 29.60DPS 4.00 5.05 5.41 5.33Book value 383.62 415.67 439.38 462.74
Valuation data
Year to 03/2008a 03/2009e 03/2010e 03/2011e
EV/sales 1.0 1.6 1.7 1.8EV/EBITDA 8.9 6.8 7.3 7.3EV/IC 0.7 0.7 0.7 0.7PE* 10.7 8.6 8.1 8.2Price to book value 0.6 0.6 0.6 0.5FCF yield (%) -18.2 -55.5 -39.1 -26.0Dividend yield (%) 1.7 2.1 2.2 2.2
Note: * = B ased on HSBC EPS (diluted)
Issuer information
Share price (INR) 242.00 Target price (INR) 345.00 Potentl tot rtn (%) 44.7
Reuters (Equity) CESC.BO Bloomberg (Equity) CESC INMarket cap (USDm) 619 Market cap (INRm) 30,243Free float (%) 84 Enterprise value (INRm) 48,090Country India Sector Electric UtilitiesAnalyst Sumeet Agrawal Contact 91 22 2268 1243
Price relative
108
208
308
408
508
608
708
2007 2008 2009 2010
108
208
308
408
508
608
708
Cesc Ltd Rel to BOMBAY SE SENSITIVE INDEX
Source: HSBC
Note: price at close of 12 Jan 2009
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3.9GW of projects in advancedstages of execution
Lancos aggressive capacity expansion is
supported by the financial closure of c3.9GW of
projects. The projects are to be funded through a
mix of debt and equity. The financial closure of
some of these projects provides us with comfort in
terms of their execution.
These projects are in advanced stages of execution
with the first 300MW of Amarkantak to be
operational by end-FY09. The other 300MW of
Amarkantak II is likely to be commissioned by
September 2009. Other projects are in advanced
stages of execution. We expect c620GW of
capacity to be operational by FY10e, almost 2x
the current installed base.
Lanco has already spent cINR50.5bn in the above
projects and requires an additional cINR124bn.
We believe the capacity addition of 3.9GW over
the next five years is not at risk.
However, we believe the equity contribution
should be a big challenge on the existing balance
sheet. Lanco is already leveraged at 2.7x with net
debt of cINR11bn. The equity contribution of
INR61bn, including INR35bn of equity
investment for projects in its pipeline, is an issue.
However, we do not expect any significant issue
in terms of equity investment of INR26.4bn for
projects under execution. Internal accruals over
the next five years should address the shortfall.
We have not factored in any capacity addition
from project under development (Babanth and
Amarkantak III and IV).
Fuel supply for projects
Lanco has already met most of its coal requirements
through coal linkages, which reduces fuel risk. For
the Nagarjuna Power project, though, it has entered
into a long-term (12-year) fuel supply agreement.
As the project is based on a regulatory model, the
fuel cost is passed through to the end user, so Lanco
is not exposed to the fuel cost risk.
Status of Lancos projects under execution
Projects Location Fuel Capacity(MW)
Est. projectcost
(INRm)
Holding(%)
Capexspentso far
(INRm)
HSBCest.
COD
Status
Amarkantak I Chhattisgarh Coal 300 12,900 76% 20,118 Feb-09 Boiler hydro test completed in Dec 07, switchyard charged, switchyard
connected to gridAmarkantak II Chhattisgarh Coal 300 13,400 76% Sep-09 Boiler drum lifting completed in Dec07, hydro testing completed, turbine
generator erected
Vamshi Hydro HimachalPradesh
Hydro 10 1,490 91% 1,234 Dec-09 Under commissioning
VamshiIndustrial
HimachalPradesh
Hydro 10 91% Dec-09
Lanco Green HimachalPradesh
Hydro 70 4,200 90% 1,992 Apr-11 River diversion completed in Oct 07, River bed excavation of dam completed.commissioning expected in Dec 09 by company
Kondpalli-II AndhraPradesh
Gas 400 11,880 59% 904 Apr-10 Piling completed, erection of columns in ECB started
Udupi(Nagarjuna)
Karnataka ImportedCoal
1,015 43,400 74% 14,534 Apr-12 Boiler drum lifting and TG casting done; TG erection to start soon. For U 2,boiler erection completed
Lanco Energy Sikkim Hydro 500 30,000 74% 5,704 Jul-12 Civil work for tunnel in progressLancoUttaranchal
Uttarakhand Hydro 152 9,500 90% 577 Apr-12 Techno-economic clearance received, infrastructure development under way
Anpara C Uttar Pradesh Coal 1,200 48,000 100% 5,411 Jan-12 U 1: boiler foundation done, boiler erection to get started; U 2 : construction ofboiler foundation in progress
Total 3,957 74,770 50,474
Source: Company, HSBC
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Taking care of fuel requirement
Project Fuel type Status of fuel source
Under constructionKondapalli II AP Gas From KG BasinAmarkantak I Chattisgarh Domestic Coal Coal linkages (SECL)Amarkantak II Chattisgarh Domestic Coal Coal linkages(SECL)Nagarjuna Karnataka Imported Coal Long term FSA from
Indonesia (12 years)Anpara C UP Domestic Coal Coal linkages (NCL)Lanco Green HP Hydro HydroVamshi Industrial HP Hydro HydroVamshi Hydro HP Hydro HydroLanco Energy TeestaSikkim
Hydro Hydro
Lanco Hydro Uttarakhand Hydro HydroUnder pipelineBabanth I Orissa Domestic Coal 1000 MW Captive
balance from Coallinkages
Babanth II Orissa Domestic Coal Coal linkagesAmarkantak III & IV Chattisgarh
Domestic Coal In process
*SECL: South Eastern Coalfields Limited, 100% subsidiary of Coal India LtdSource: Company, HSBC
Change in forecasts
We have factored in delays in few of its project
under construction. We now expect Amarkantak I
to be operational in 4QFY09e and Amarkantak II
in 2QFY10e, as against earlier target of 3QFY09e
and company guidance of FY09e. We have also
extended project completion for Anpara C to
4QFY12e vs company guidance of FY11e.
Apart from power execution delays, we have also
changed our estimates for the EPC business by
forecasting a 10% and 4% decline for FY09 and
FY10 respectively. We have also reduced EBITDA
margin estimates to 18% from 20% for FY09e.
Summary of forecast changes
____New____ ____ Old______ __Change (%) __INRbnFY09e FY10e FY09e FY10e FY09e FY10e
Sales 34.01 50.27 37.50 52.00 -9% -3%PAT 4.09 6.73 5.00 7.20 -18% -6%EPS (INR) 18.38 30.29 22.44 32.46 -18% -7%
Source: HSBC estimates
HSBC vs consensusHSBC vs consensus (INRbn)
___ Sales __ ___ PAT ___ _ EPS (INR/share) _INRbn FY09e FY10e FY09e FY10e FY09e FY10e
HSBCestimates
34.01 50.27 4.09 6.73 18.4 30.3
Consensusestimates
56.97 81.76 4.32 6.13 19.5 27.7
% difference -40% -39% -5% 10% -6% 10%
Source: HSBC, Reuters
Valuation
Based on this, we have reduced our FY09e profit
estimates by 6%, driven by 3% decline in revenue
and lower EPC margin. We have also extended
execution time frame for EPC business, given the
delays in power projects.
Real estate valuation
We have value the real estate separately and used
a discount rate of 15%. We have assumed the
entire Hyderabad real estate to be developed in
the next eight years. Based on this, we derive an
NAV of INR10.3bn. However, we have also
removed the value of real estate (INR37 per share
earlier) from our valuation, given the current
slowdown in the real estate sector. We expect that
any upturn in the real estate business to provide an
upside to the stock.
Discounted cash flow
We have used the discounted cash flow method to
value generation, and other businesses. We haveused a discount rate of 13.1% (12.8% earlier) to
incorporate higher cost of debt (14% vs 12%
earlier). Based on this, we derive a fair value of
INR140 per share (INR297 per share earlier).
Price to book value
We have used a price-to-book multiple of 1.2x (2x
earlier), a 33% discount to NTPCs target PB.
Based on this, we derive a fair value of INR149
per share (INR312 earlier).
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Financials & valuation: Lanco Infratech Neutral (V)Financial statements
Year to 03/2008a 03/2009e 03/2010e 03/2011e
Profit & loss summary (INRm)
Revenue 32,413 34,015 50,274 77,368EBITDA 6,905 7,538 12,600 20,128Depreciation & amortisation -776 -1,235 -2,361 -3,715Operating profit/EBIT 6,129 6,302 10,238 16,413Net interest -832 -1,160 -1,578 -2,064PBT 6,175 6,191 9,813 15,617HSBC PBT 6,175 6,191 9,813 15,617Taxation -1,405 -1,391 -2,205 -3,509Net profit 3,542 4,088 6,735 10,989HSBC net profit 3,542 4,088 6,735 10,989
Cash flow summary (INRm)
Cash flow from operations 9,419 6,407 13,745 22,113Capex -8,520 -16,589 -15,391 -38,731Cash flow from investment -8,520 -16,589 -15,391 -38,731Dividends 0 0 0 0Change in net debt -899 9,264 462 15,236FCF equity -54 -11,230 -2,800 -17,886
Balance sheet summary (INRm)
Intangible fixed assets 0 0 0 0Tangible fixed assets 32,134 47,487 60,517 95,533Current assets 24,807 25,566 33,263 46,090Cash & others 5,050 5,050 5,050 5,050
Total assets 62,970 79,082 99,810 147,652Operating liabilities 22,870 24,001 35,473 54,591Gross debt 16,200 25,464 25,926 41,162Net debt 11,150 20,413 20,875 36,112Shareholders funds 18,722 22,809 29,544 40,533Invested capital 29,021 44,002 53,257 81,982
Ratio, growth and per share analysis
Year to 03/2008a 03/2009e 03/2010e 03/2011e
Y-o-y % change
Revenue 101.9 4.9 47.8 53.9EBITDA 64.5 9.2 67.2 59.7Operating profit 73.0 2.8 62.5 60.3
PBT 96.7 0.3 58.5 59.1HSBC EPS 61.6 15.4 64.7 63.2
Ratios (%)
Revenue/IC (x) 1.2 0.9 1.0 1.1ROIC 17.5 13.4 16.3 18.8ROE 20.9 19.7 25.7 31.4ROA 9.8 8.0 9.9 11.1EBITDA margin 21.3 22.2 25.1 26.0Operating profit margin 18.9 18.5 20.4 21.2EBITDA/net interest (x) 8.3 6.5 8.0 9.8Net debt/equity 47.0 69.4 54.6 69.8Net debt/EBITDA (x) 1.6 2.7 1.7 1.8CF from operations/net debt 84.5 31.4 65.8 61.2
Per share data (INR)
EPS Rep (diluted) 15.93 18.38 30.29 49.42HSBC EPS (diluted) 15.93 18.38 30.29 49.42DPS 0.00 0.00 0.00 0.00Book value 84.20 102.58 132.87 182.30
Valuation data
Year to 03/2008a 03/2009e 03/2010e 03/2011e
EV/sales 1.1 1.3 1.0 0.9EV/EBITDA 5.0 6.1 3.8 3.3EV/IC 1.2 1.0 0.9 0.8PE* 7.0 6.0 3.7 2.2Price to book value 1.3 1.1 0.8 0.6FCF yield (%) -0.2 -44.5 -10.3 -60.0Dividend yield (%) 0.0 0.0 0.0 0.0
Note: * = Based on HSBC EPS (diluted)
Issuer information
Share price (INR) 110.85 Target price (INR) 132.00 Potentl tot rtn (%) 19.1
Reuters (Equity) LAIN.BO Bloomberg (Equity) LANCI INMarket cap (USDm) 505 Market cap (INRm) 24,649Free float (%) 21 Enterprise value (INRm) 45,654Country India Sector Electric UtilitiesAnalyst Sumeet Agrawal Contact 91 22 2268 1243
Price relative
0
100
200
300
400500
600
700
800
900
2007 2008 2009 2010
0
100
200
300
400500
600
700
800
900
Lanco Infratech Rel to BOMBAY SE SENSITIVE INDEX
Source: HSBC
Note: price at close of 12 Jan 2009
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Strong project pipeline, butpoor execution
NTPC has a strong project pipeline with capacity
addition target of 22GW by 2012e to increase itsinstalled base to 50GW.
We expect NTPC to miss its capacity addition
target despite strong project execution capabilities
and fund availability. NTPC saw execution delays
due in the past too, from delay in land acquisition,
regulatory approvals, and by equipment vendors.
The Central Electricity Authority has also taken
cognisance of delays in execution, and expects
NTPC to commission only 15.4GW in the 11thPlan. We are more conservative, and expect it to
commission 11.9GW of capacity by 2012.
Capacity addition plan
NTPC plans to add 20GW by FY12 to its current
installed base of 29GW. We expect the projects
under tendering (3.8GW) will not come on stream
by FY12, leading to an overall shortfall of 10GW
against planned capacity by the end of the 11th
Plan period.
Delay in coal mining a concern
NTPC has huge coal requirement annually. In
2008, it consumed c124mt, 2.6mt of which was
imported. Globally, there is a shortage of coal,
and coal prices are on the rise. Coal India Limited
is the principal supplier of coal to NTPC.
To meet its coal requirements on an ongoing basis,
NTPC is developing seven coal mines, which have
total reserves of 3.6bn tonnes, with an annual
estimated capacity of 56m tonnes per annum
(mtpa). Of the total approved advance expenditure
of INR5.4bn to develop these mines, INR0.8bn was
already spent as at end of the last financial year.
NTPCs coal reserves
Project Est.reserves
(m tonnes)
Mine life(in years)
Est.capacity
(mtpa)
Projectdevmt
yearexpected
Pakri Barwadih 1,436 50 15 FY10Chatti Bariatu 243 30 7 FY11Chatti Bariatu II 354 30 5 FY11Kerandari 229 25 6 FY12Dulanga 260 30 5 FY11Talaipalli 965 30 15 FY13Chhatrasal 150 30 3Total Own 3,637 56JV with Coal India Limited
Brahminni 1,900 25 25Chichro Patsimal 356 NA 5Total 5,893 86
Source: Company, HSBC
NTPC Ltd (NATP)
NTPC enjoys the best positioning in terms of access to funds and
fuel, but market ignoring delays in project execution
NTPC continues to trade at a premium valuation, defying risk of
delays and reduction in RoE in FY09e
Downgrade to Underweight (V) from Neutral (V) on valuation
trading (1.78x FY10e PB); retain our target of INR142
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Discounted cash flowBased on our DCF approach, we derive a value of
INR123.
Sum of the parts
We have valued NTPC on SOTP value of
INR165. We have valued the existing generation
business at an EV/MW of INR46.5m, based on
expected replacement cost and a premium for the
existing business. We have not valued the captive
coal mining business, as the mine development
operator has yet to be appointed and there is not
much clarity on the transfer pricing between the
mine and the generating station. In addition, we
have valued NTPCs investment in various JVs
(other than power generating JVs) at 1.5x the
book value of the investments, since they are at
very early stages of development.
Price to book
We have valued NTPC using a multiple of 1.8xFY10e book value. Based on this, we derive a fair
value of INR138 per share.
NTPCs SOTP
Business Unit Capacity Multiple Value INR pershare
Generation MW 30,807 46.50x 1,432,523 174Investments Premium to
book101,883 50.0% 152,825 19
Total 1,585,347 192Less Net debt 221,950 27Equity value 1,363,397 165
Source: HSBC
Based on the average of these three values, we
derive a target price of INR142, suggesting
17% downside.
Target price derivation
INR per share
SOTP 165DCF 123PB 138Target price 142
Source: HSBC estimates
Under our research model, for stocks with a
volatility indicator, the Neutral band is 10
percentage points above and below the hurdle rate
for Indian stocks of 11%. For NTPC, this
translates into a Neutral band of 1-21% around the
current share price. Our target price of INR142 for
NTPC shares implies a total return (including
dividend yield) of -14.6%, which is below the
Neutral band; thus, we have an Underweight (V)
rating on the NTPC stock.
Risks
Business risks includes fuel supply concerns,
delays in project execution, and an impact from
higher costs on merchant power. Also, regulatory
risks include a reduction in RoE due to higher
efficiency norms to be set by the regulator. Upside
risks to our rating include faster execution, higher
efficiency norms, and the ability to raise funds at
lower cost and to address the fuel issue.
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Financials & valuation: NTPC Underweight (V)Financial statements
Year to 03/2008a 03/2009e 03/2010e 03/2011e
Profit & loss summary (INRm)
Revenue 386,823 418,192 467,204 518,285EBITDA 117,352 131,412 144,773 156,979Depreciation & amortisation -22,060 -21,213 -23,306 -25,735Operating profit/EBIT 95,292 110,199 121,468 131,244Net interest -18,581 -20,910 -23,998 -26,860PBT 103,510 112,502 119,941 126,154HSBC PBT 103,510 112,502 119,941 126,154Taxation -28,811 -30,404 -33,057 -35,342Net profit 74,699 82,098 86,884 90,812HSBC net profit 74,699 82,098 86,884 90,812
Cash flow summary (INRm)
Cash flow from operations 97,822 99,202 119,943 137,619Capex -99,442 -82,556 -127,945 -206,790Cash flow from investment -82,505 -66,041 -111,430 -190,275Dividends -28,932 -29,605 -33,581 -35,221Change in net debt 16,328 1,027 30,105 93,161FCF equity -46,404 -8,414 -31,898 -92,411
Balance sheet summary (INRm)
Intangible fixed assets 6 6 6 6Tangible fixed assets 537,900 599,243 703,882 884,937Current assets 263,157 304,766 313,315 280,150Cash & others 153,605 190,961 186,356 139,688
Total assets 935,533 1,021,970 1,118,644 1,250,018Operating liabilities 77,030 85,788 107,959 141,737Gross debt 303,147 341,530 367,031 413,523Net debt 149,542 150,569 180,674 273,836Shareholders funds 528,629 573,647 621,290 671,087Invested capital 570,428 627,266 722,888 883,668
Ratio, growth and per share analysis
Year to 03/2008a 03/2009e 03/2010e 03/2011e
Y-o-y % change
Revenue 14.2 8.1 11.7 10.9EBITDA 15.4 12.0 10.2 8.4Operating profit 18.1 15.6 10.2 8.0
PBT 15.5 8.7 6.6 5.2HSBC EPS 8.3 9.9 5.8 4.5
Ratios (%)
Revenue/IC (x) 0.7 0.7 0.7 0.6ROIC 13.0 13.4 13.0 11.8ROE 14.7 14.9 14.5 14.1ROA 9.9 9.9 9.7 9.3EBITDA margin 30.3 31.4 31.0 30.3Operating profit margin 24.6 26.4 26.0 25.3EBITDA/net interest (x) 6.3 6.3 6.0 5.8Net debt/equity 28.2 26.2 29.0 40.7Net debt/EBITDA (x) 1.3 1.1 1.2 1.7CF from operations/net debt 65.4 65.9 66.4 50.3
Per share data (INR)
EPS Rep (diluted) 9.06 9.96 10.54 11.01HSBC EPS (diluted) 9.06 9.96 10.54 11.01DPS 3.51 3.91 4.14 4.33Book value 64.11 69.57 75.35 81.39
Valuation data
Year to 03/2008a 03/2009e 03/2010e 03/2011e
EV/sales 3.7 3.4 3.2 3.1EV/EBITDA 12.1 11.0 10.3 10.2EV/IC 2.5 2.3 2.1 1.8PE* 18.9 17.2 16.2 15.5Price to book value 2.7 2.5 2.3 2.1FCF yield (%) -3.6 -0.7 -2.4 -7.0Dividend yield (%) 2.1 2.3 2.4 2.5
Note: * = Based on HSBC EPS (diluted)
Issuer information
Share price (INR) 170.90 Target price (INR) 142.00 Potentl tot rtn (%) -14.6
Reuters (Equity) NTPC.BO Bloomberg (Equity) NATP INMarket cap (USDm) 28,849 Market cap (INRm) 1,409,150Free float (%) 11 Enterprise value (INRm) 1,441,764Country India Sector Electric UtilitiesAnalyst Sumeet Agrawal Contact 91 22 2268 1243
Price relative
105125145165185205
225245265285305
2007 2008 2009 2010
105125145165185205
225245265285305
NTPC Rel to BOMBAY SE SENSITIVE INDEX
Source: HSBC
Note: price at close of 12 Jan 2009
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Best-placed Indian utility
Building on existing experience and
presence
Tata Power has established itself as a credible
player in the Indian power sector by leveraging its
experience of operating the largest installed base
within the private sector and operating
distribution circles in Mumbai and Delhi. It is the
first private player to set up and operate a high-
voltage transmission line in a JV with PGCIL,
which completed its first year of operations in
March 2008. It is now expanding its fleet of
power plants across India; these are at various
stages of construction and development. The
success of the company is shown by its ability to
achieve financial closure and source fuel linkages
for most of its projects both through captive mine
allocation and acquiring coal mines in Indonesia.
Well-diversified generating portfolio
Tata Power has a well-diversified generating
portfolio in terms of both fuel mix and selling
arrangements i.e., regulated versus tariff based,
captive and merchant based power plant. It has a
well-defined capacity addition plan, with
2,400MW already under operation, 5,660MW
under construction, and c5,670MW in the
pipeline. Its generation portfolio consists of a
diverse fuel mix, with thermal, hydro and
alternative fuels accounting for 75%, 20%, and
3% respectively.
Tata Power (TPWR)
Building a well-diversified generation portfolio supported by fuel
sourcing and funding strategy
Acquisition of overseas coal blocks proving to be a well-crafted
strategy for security fuel; lower FY10 profit estimates 21% to
incorporate lower coal realisation
Reiterate Overweight (V), lower target to INR1,000 from INR1,244
Tata Power generation portfolio
Regulated Tariff based Captive power / IPP Merchant Renewable
Developed1330MW Trombay thermal 428MW Jojobera 79MW Wind447MW Hydro power Station 81MW BelgaumUnder construction250MW Trombay extension 4000MW Mundra UMPP 120MW Jamshedpur 124MW Wind Power1050MW Maithon thermal 120MW Jojobera thermal 3MW Solar PV120MW Haldia thermalUnder pipeline
1000MW Naraj Marthapur IPP 2400MW Coastal Maharashtra1270MW Naraj Marthapur CPP500MW Tubed IPP
500MW Jharkhand (Tata Steel)
Source: Company, HSBC
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Within alternative energy sources, Tata Power
plans to expand its wind capacity from 78MW
now to 200MW over the next year. It has plans to
further explore opportunities in the wind energy
space, which we believe will help the company to
manage its obligation under the renewable energy
target imposed on distributors in Maharashtra.
We believe Tata Powers ability to create a well-
diversified power plant portfolio, i.e., selling in
both the regulated and the free markets will
enable it to mitigate fuel and offtake risks.
Fuel and funds well tied up
Visible success in acquiring fuel to
power its plants
Tata Power is well positioned to meet its fuel
obligations, in our view, as it has made significantarrangements for most of its plants under
construction either by way of captive mine
allocation or through fuel offtake agreement for
coal supply from Indonesia. For example, it has
been allocated two coal mines for its projects. It
received allocation of the 189mt coal block in
Jharkhand in JV with Hindalco and the 290mt
Mandakini coal block in Orissa along with Jindal
Photo and Monnet Ispat. It has picked up a 30%
stake in KPC and Arutmin from PT BumiResources in Indonesia, which allows it to draw
10mt of coal supplies over the long term, which is
capable of fuelling almost the entire Mundra
plant. For Maithon projects, Tata Power has tied
up fuel from Bharat Coking Coal mines, which
reflects its ability to obtain fuel linkages for large
projects.
Successful in achieving financial
closure for large projects
Tata Power has completed financing for two of its
largest power plants under construction i.e., the
Tata Powers generation capacity addition plans
Project Capacity(MW)
Projectcost
(INRbn)
Debtto
equity
Debt(INRbn)
Equity(INRbn)
Developerstake (%)
Developerequity
(INRbn)
Status of fundingclosure
Fuel type Fuel source
UnderconstructionMundra 4,000 170.00 75:25 127.5 42.5 100% 42.5 Done, with USD1.8bn
forex loan and USD1.4bnrupee loan
Imported coal 10mtpa offtake agreement withKPC*/Arutmin, pricing part fixedand part linked to CERC Index
Maithon (74%stake)
1,050 44.50 70:30 31.2 13.4 74% 9.9 Done; funded by StateBank of India
Domestic coal Fuel linkage from Bharat CokingCoal mines
Jamshedpur andJojobera
240 11.10 70:30 7.8 3.3 74% 2.5 In advanced stage ofcompletion
Tollingarrangement
Coke oven gases of Tata Steel,and linkage from West Bokaroand Mahanadi coal fields
Trombay Expansion 250 10.66 70:30 7.5 3.2 100% 3.2 In advanced s tage ofcompletion
Imported coal Imported coal, cost pass-through
Haldia 120 6.05 70:30 4.2 1.8 100% 1.8 In advanced stage ofcompletion
Tollingarrangement
Hot flue gases from HooglyMetcoke
Sub-total 5,660 242 178 64 60
In the pipelineCoastalMaharashtra
2,400 101 70:30 75.6 25.2 100% 25.2 Imported Coal Coal f rom Bumi Resourcesofftake
Naraj MarthapurIPP
1,000 42.0 70:30 29.4 12.6 100% 12.6 Domestic coal Mandakin i Coal Block
Naraj MarthapurCPP
1,270 53.3 70:30 37.3 16.0 74% 11.8 Tollingarrangement
Supply by procurers
Tubed IPP 500 21.0 70:30 14.7 6.3 100% 6.3 Domest ic coal Capt ive coal blockJharkhand CPP 500 21.0 70:30 14.7 6.3 74% 4.7 Tolling
arrangementSupply by Tata Steel
Sub-total 5,670 238 172 66.4 60.6Total 11,330 480 350 131 120
* KPC=Kaltim Prima CoalSource: Company, HSBC estimates
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1050MW Maithon project, for which the debt
component of cINR30bn is being funded by a
consortium led by State Bank of India. For its
Mundra project, the company has tied up to raise
USD1.8bn in foreign exchange loans and
USD1.4bn in INR loans with several multilateral
and domestic financial institutions. With these
two big projects, most of the groups funding for
plants under construction has been tied up.
Funding for remaining smaller projects, such as
captive projects at Jojobera and Jamshedpur, are
at advanced stages of reaching financial closure.
Tata Power proposes to raise the total funding
requirement of INR240bn during the next four
years through its own contribution (INR60bn) and
through debt (INR180bn), a large portion of
which is already tied up.
Change in forecasts
We have reduced our contribution from the coal
mine business, given the declining coal prices. Weexpect average realisation of coal to fall to
cUSD48 per tonne, a decrease of 30% from the
previous year in contrast to our earlier estimate of
10% decline. Also we have decreased the coal
production forecast now to 4% annual increase
from earlier estimates of 7% for FY09 and 5%
thereafter. Also in our estimates, we now provide
for 20% provision for taxation from earlier
estimates of 12.4%.
Summary of changes in forecasts
_____ New ___ ____ Old______ __Change (%)__(INRbn)FY09e FY10e FY09e FY10e FY09e FY10e
Sales 146.19 142.82 149.11 151.99 -2% -6%PAT 20.97 24.11 21.29 30.42 -1% -21%EPS (INR) 95.05 109.26 96.49 137.82 -1% -21%
Source: HSBC estimates
HSBC vs consensusHSBC vs consensus (INRbn)
___ Sales _ ___ ___ PAT ____ _ EPS (INR) __INRbn FY09e FY10e FY09e FY10e FY09e FY10e
HSBCestimates
146.2 142.8 20.9 24.1 95.0 109.3
Consensusestimates
150.4 169.7 18.9 26.7 84.4 116.1
% difference -3% -16% 11% -10% 13% -6%
Source: HSBC, DataStream
Valuation
Combination of valuation approaches
We value Tata Power using the methods below
and derive a target price of INR1,000.
Discounted cash flow
We use the discounted cash flow method to value
the entire generation as well as other business. We
used a discount rate of 12% (13.5% cost of equity
and 6.6% cost of debt). Based on this, we derive a
fair value of INR1,243 per share.
Price to book value
We value Tata Power at PB multiple of 2.0x (a
slight premium of 15% to global utilities),
deriving a value of INR986 per share.
Sum of the parts
We value the existing generation business at an
EV/MW of INR46.5m, based on expected
replacement cost. We value NDPL based on 2x
price-to-book, given that it is able to generate a
16% ROE and is growing at c15% CAGR over
FY08-10e. We have not considered the value
derived from projects under development. Based
on the SOTP approach, we value the company at
INR770 per share.
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Target price derivation
INR per share
SOTP 770DCF 1243PB 986Target price 1,000
Source: HSBC estimates
Under our research model, for stocks with avolatility indicator, the Neutral band is 10
percentage points above and below the hurdle rate
for Indian stocks of 11%. For Tata Power, this
translates into a Neutral band of 1-21% around the
current share price. Our target price of INR1,000
for Tata Power shares implies a total return
(including dividend yield) of 40.7%, which is
above the Neutral band; thus, we have an
Overweight (V) rating on the Tata Power stock.
RisksBusiness risks include equity funding for the
5.6GW under pipeline, delays in project
execution, interest rate risk, and regulatory risk.
Tata Powers SOTP
Business Unit Particulars Multiple Value (INRm) INR per share
Generation MW 3,019 46.50x 140,373 636.1NDPL Equity investment 2,009 2.00x 4,019 18.2Transmission lines Book Value 2,380 2.00x 2,428 11.0License area distribution assets Book Value 5,033 2.00x 10,067 45.6Tata BP Solar 8xFY08 EV/Sales 8,500 1.76x 14,946 67.7Mundra Power Project NPV to Equity 7,802 35.430% stake in Bumi Resources NPV to Equity 38,768 175.7Value of projects under construction NPV to Equity 9,492 1.00x 9,492 43.0Investments Premium to book 26,398 50% 39,597 179.4Value of projects in pipeline 0% 0 0.0Total 267,490 1212Less Net debt -97,488 -442Equity value 170,002 770No. of shares 220.68
Source: HSBC
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Financials & valuation: Tata Power Overweight (V)Financial statements
Year to 03/2008a 03/2009e 03/2010e 03/2011e
Profit & loss summary (INRm)
Revenue 108,891 146,189 142,816 178,753EBITDA 21,203 38,517 43,359 46,493Depreciation & amortisation -5,593 -7,109 -8,230 -9,085Operating profit/EBIT 15,611 31,407 35,129 37,408Net interest -4,881 -6,841 -6,937 -7,735PBT 15,485 29,611 33,489 35,234HSBC PBT 15,485 29,611 33,489 35,234Taxation -3,765 -8,302 -8,835 -8,898Net profit 9,965 20,975 24,112 24,848HSBC net profit 9,965 20,975 24,112 24,848
Cash flow summary (INRm)
Cash flow from operations 13,152 23,268 23,688 42,559Capex -25,527 -17,827 -25,447 -36,717Cash flow from investment -69,956 -17,827 -25,447 -36,717Dividends -2,365 -5,944 -6,833 -7,042Change in net debt 47,753 1,198 9,981 2,241FCF equity -17,073 397 -7,056 281
Balance sheet summary (INRm)
Intangible fixed assets 0 0 0 0Tangible fixed assets 140,901 151,619 168,835 196,466Current assets 50,049 59,796 60,671 57,468Cash & others 5,623 5,623 5,623 5,623
Total assets 222,228 242,693 260,784 285,212Operating liabilities 33,151 37,749 29,427 33,362Gross debt 91,136 92,334 102,315 104,556Net debt 85,513 86,711 96,692 98,933Shareholders funds 75,920 90,950 108,229 126,035Invested capital 152,176 168,044 194,456 214,949
Ratio, growth and per share analysis
Year to 03/2008a 03/2009e 03/2010e 03/2011e
Y-o-y % change
Revenue 68.1 34.3 -2.3 25.2EBITDA 94.3 81.7 12.6 7.2Operating profit 130.8 101.2 11.8 6.5
PBT 127.9 91.2 13.1 5.2HSBC EPS 21.3 110.5 15.0 3.1
Ratios (%)
Revenue/IC (x) 1.0 0.9 0.8 0.9ROIC 10.6 14.1 14.3 13.7ROE 15.3 25.1 24.2 21.2ROA 8.6 11.3 11.8 11.8EBITDA margin 19.5 26.3 30.4 26.0Operating profit margin 14.3 21.5 24.6 20.9EBITDA/net interest (x) 4.3 5.6 6.3 6.0Net debt/equity 101.8 87.9 84.0 74.2Net debt/EBITDA (x) 4.0 2.3 2.2 2.1CF from operations/net debt 15.4 26.8 24.5 43.0
Per share data (INR)
EPS Rep (diluted) 45.15 95.05 109.26 112.60HSBC EPS (diluted) 45.15 95.05 109.26 112.60DPS 10.94 23.02 26.47 27.27Book value 344.03 412.14 490.43 571.12
Valuation data
Year to 03/2008a 03/2009e 03/2010e 03/2011e
EV/sales 2.1 1.5 1.6 1.3EV/EBITDA 10.5 5.8 5.4 5.1EV/IC 1.5 1.3 1.2 1.1PE* 16.1 7.7 6.7 6.5Price to book value 2.1 1.8 1.5 1.3FCF yield (%) -12.4 0.3 -5.2 0.2Dividend yield (%) 1.5 3.2 3.6 3.8
Note: * = Based on HSBC EPS (diluted)
Issuer information
Share price (INR) 727.25 Target price (INR) 1000.00 Potentl tot rtn (%) 40.7
Reuters (Equity) TTPW.BO Bloomberg (Equity) TPWR INMarket cap (USDm) 3,296 Market cap (INRm) 161,004Free float (%) 67 Enterprise value (INRm) 224,164Country India Sector Electric UtilitiesAnalyst Sumeet Agrawal Contact 91 22 2268 1243
Price relative
350
550
750
9501150
1350
1550
1750
2007 2008 2009 2010
350
550
750
9501150
1350
1550
1750
Tata Power Rel to BOMBAY SE SENSITIVE INDEX
Source: HSBC
Note: price at close of 12 Jan 2009
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Hectic equipment ordering in2008
2008 was a momentous year, with 15GW ordered
for various equipment manufacturers this was
because of the push towards achieving 78GW of
the governments capacity addition target. The
Ministry of Power pushed to achieve financial
closure, and equipment ordering led to significant
news flow in 2008.
11th Plan: capacity addition plan (MW)
Central State Pr ivate Total %
Thermal 21,496 22,001 17,406 60,903 76%Hydro 8,654 3,362 3,491 15,507 19%Nuc lear 3,380 0 0 3,380 4%Total 33,530 25,363 20,897 79,790% 42% 32% 26%
Source: CEA, HSBC estimates
Why were targets not met?
India has a poor record in achieving its power
capacity addition targets. The 10th Plan achieved
only 52% of the proposed installed base. Failure to
achieve financial closure and delays from
equipment vendors and regulators were key reasons
why capacity addition targets were not met.
Why 10th Five-Year Plan capacity addition targets were not met
Major reasons for slippage Total
Delay in supplies/erection by suppliers/ contractors 24%Delay in tie-up super critical technology 14%Non-availability of gas 11%Delay in award of works, mainly in state sector/NLC 9%Projects not taken up/escrow cover not given/financialclosure not achieved/funds not tied up
19%
Delay in clearance/investment decisions (hydro projects) 8%Hydro projects: delay in environmental clearance,geological surprises, natural calamities, relocation andrehabilitation issues, delay in signing of MoU, court cases
11%
Law & order problems 2%Nuclear projects included on best effort basis (otherwise
scheduled for 11th Plan)
4%
Adjustments due to change of size -3%
Source: CEA
Capacity addition: actual vs planned over five-year plans
-
10,000
20,000
30,000
40,000
50,000
I IV VII IX
30%40%
50%
60%
70%
80%
90%
100%
Capacity planned Capacity added %
Source: CEA
To mitigate the delays due to equipment shortage,
developers have already placed equipment orders
on vendors, providing sufficient time for project
execution this time around.
With equipment now ordered, we expect focus to
shift towards execution, over the next three years.
Annexure
2008 saw hectic equipment ordering
We analyse reasons why earlier plans were not achieved
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However, we still expect delays to hamper the
capacity addition plan and expect c48GW of
capacity addition over 2007-12e.
Generation capacity addition analysis (MW)
FY08 FY09e FY10e FY11e FY12e Total
Breakdown by technologyThermal 6620 5047 7795.2 6948 11901 38311Hydro 2423 232 499 1281 2211 6646Nuclear 220 440 220 1500 1000 3380Total 9263 5719 8514.2 9729 15112 48337
Breakdown by sectorCentra l 3240 2440 2250 4692 9051 21673State 5273 1494 3126.2 4028 3201 17122Private 750 1785 3138 1009 2860 9542Total 9263 5719 8514.2 9729 15112 48337
Source: CEA, HSBC estimates
We expect the major reasons for slippage in capacity
addition will be delays from equipment vendors,
failure to receive regulatory clearances for hydro
projects, and the fact that most capacity addition is
back-ended (36% capacity to be commissioned in
FY12, as per recent CEA publications).
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Disclosure appendix
Analyst certification
The following analyst(s), who is(are) primarily responsible for this report, certifies(y) that the opinion(s) on the subject
security(ies) or issuer(s) and any other views or forecasts expressed herein accurately reflect their personal view(s) and that no
part of their compensation was, is or will be directly or indirectly related to the specific recommendation(s) or views contained
in this research report: Sumeet Agrawal
Important disclosuresStock ratings and basis for financial analysis
HSBC believes that investors utilise various disciplines and investment horizons when making investment decisions, which
depend largely on individual circumstances such as the investors existing holdings, risk tolerance and other considerations.
Given these differences, HSBC has two principal aims in its equity research: (1) to identify long-term investment opportunities
based on particular themes or ideas that may affect the future earnings or cash flows of companies on a 12 month time horizon;
and (2) from time to time to identify short-term investment opportunities that are derived from fundamental, quantitative,
technical or event-driven techniques on a 0-3 month time horizon and which may differ from our long-term investment rating.
HSBC has assigned ratings for its long-term investment opportunities as described below.
This report addresses only the long-term investment opportunities of the companies referred to in the report. As and when
HSBC publishes a short-term trading idea the stocks to which these relate are identified on the website at
www.hsbcnet.com/research. Details of these short-term investment opportunities can be found under the Reports section of thiswebsite.
HSBC believes an investors decision to buy or sell a stock should depend on individual circumstances such as the investors
existing holdings and other considerations. Different securities firms use a variety of ratings terms as well as different rating
systems to describe their recommendations. Investors should carefully read the definitions of the ratings used in each research
report. In addition, because research reports contain more complete information concerning the analysts views, investors
should carefully read the entire research report and should not infer its contents from the rating. In any case, ratings should not
be used or relied on in isolation as investment advice.
Rating definitions for long-term investment opportunities
Stock ratings
HSBC assigns ratings to its stocks in this sector on the following basis:
For each stock we set a required rate of return calculated from the risk free rate for that stocks domestic, or as appropriate,
regional market and the relevant equity risk premium established by our strategy team. The price target for a stock represents
the value the analyst expects the stock to reach over our performance horizon. The performance horizon is 12 months. For a
stock to be classified as Overweight, the implied return must exceed the required return by at least 5 percentage points over the
next 12 months (or 10 percentage points for a stock classified as Volatile*). For a stock to be classified as Underweight, the
stock must be expected to underperform its required return by at least 5 percentage points over the next 12 months (or 10
percentage points for a stock classified as Volatile*). Stocks between these bands are classified as Neutral.
Our ratings are re-calibrated against these bands at the time of any material change (initiation of coverage, change of
volatility status or change in price target). Notwithstanding this, and although ratings are subject to ongoing management
review, expected returns will be permitted to move outside the bands as a result of normal share price fluctuations without
necessarily triggering a rating change.
*A stock will be classified as volatile if its historical volatility has exceeded 40%, if the stock has been listed for less than 12
months (unless it is in an industry or sector where volatility is low) or if the analyst expects significant volatility. However,
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stocks which we do not consider volatile may in fact also behave in such a way. Historical volatility is defined as the pastmonths average of the daily 365-day moving average volatilities. In order to avoid misleadingly frequent changes in rating,
however, volatility has to move 2.5 percentage points past the 40% benchmark in either direction for a stocks status to change.
Prior to this, from 7 June 2005 HSBC applied a ratings structure which ranked the stocks according to their notional target
price vs current market price and then categorised (approximately) the top 40% as Overweight, the next 40% as Neutral and
the last 20% as Underweight. The performance horizon is 2 years. The notional target price was defined as the mid-point of the
analysts valuation for a stock.
From 15 November 2004 to 7 June 2005, HSBC carried no ratings and concentrated on long-term thematic reports which
identified themes and trends in industries, but did not make a conclusion as to the investment action that potential investors
should take.
Prior to 15 November 2004, HSBCs ratings system was based upon a two-stage recommendation structure: a combination ofthe analysts view on the stock relative to its sector and the sector call relative to the market, together giving a view on the
stock relative to the market. The sector call was the responsibility of the strategy team, set in co-operation with the analysts.
For other companies, HSBC showed a recommendation relative to the market. The performance horizon was 6-12 months. The
target price was the level the stock should have traded at if the market accepted the analysts view of the stock.
Rating distribution for long-term investment opportunities
As of 13 January 2009, the distribution of all ratings published is as follows:
Overweight (Buy) 43% (31% of these provided with Investment Banking Services)
Neutral (Hold) 37% (33% of these provided with Investment Banking Services)
Underweight (Sell) 20% (21% of these provided with Investment Banking Services)
Share price and rating changes for long-term investment opportunities
Tata Power (TTPW.BO) share price performance INR vs HSBC rating history
Source: HSBC
Recommendation & price target history
From To Date
N/A Overweight 28 July 2006Overweight Underweight 07 November 2007Underweight Underweight (V) 17 March 2008Underweight (V) Overweight (V) 29 August 2008
Target Price Value Date
Price 1 679.10 28 July 2006Price 2 724.00 30 January 2007Price 3 714.00 20 April 2007Price 4 732.00 23 May 2007Price 5 843.00 26 July 2007Price 6 1198.