wapic presentation november 2011 - esi-africa.com · 2019-09-02 · least cost –dispatch order....
TRANSCRIPT
WAPIC Presentation
November 2011
Ije IkokuIFC Infrastructure Cluster
Presentation Outline
2
IFC is a Member of the World Bank Group
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IDAInternational Development Association
Shared Mission: To Promote Economic Development and Reduce Poverty
IFC was awarded the 2010 Euromoney Project Finance Magazine “Multilateral of the
Year” award
IFC Financial Performance
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IFC FY11 HighlightsCredit Rating (S&P, Moody’s) AAAPortfolio $55.2 billionCommitted $12.2 billionMobilized $6.5 billion# of companies 1,737# of countries 102
Since 1967, IFC’s Power Group Has Committed $7.8 billion to 239 Projects in Emerging Markets
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Cumulative Commitments since 1967
Total Commitments = US$ 7.8 billion
Outstanding Portfolio, June 30 2011
Total Portfolio = US$ 4.7 billion
IFC’s Power Group is Active in All Regions…
Cumulative Commitments since 1967
Total Commitments = US$ 7.8 billion
Outstanding Portfolio, June 30 2011
Total Portfolio = US$ 4.7 billion
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Our Power Investments Span 57 Countries
Sub-Saharan Africa
# of investments
Senegal 4
Cameroon 2
Cote D’Ivore 2
Nigeria 1
Uganda 2
Djibouti 1
Kenya 1
Mali 1
Rwanda 1
Togo 1
South Asia # of investments
India 29
Sri Lanka 5
Nepal 3
Bangladesh 1
East Asia and Pacific
# of investments
Philippines 14
China 12
Indonesia 3
Thailand 3
Laos 1
Vietnam 1
Europe and Central Asia
# of investments
Czech Republic 3
Georgia 3
Tajikistan 2
Ukraine 2
Armenia 1
Hungary 1
Kazakhstan 1
Lithuania 1
Poland 1
Russia 1
L. America & Caribbean
# of investments
Chile 9
Brazil 8
Mexico 7
Jamaica 5
Colombia 4
D. Republic 4
Guatemala 4
Peru 4
Argentina 2
Bolivia 2
Nicaragua 2
Venezuela 2
Belize 1
Costa Rica 1
El Salvador 1
Haiti 1
Honduras 1
Panama 1
MENA & South Europe
# of investments
Turkey 11
Pakistan 9
Egypt 2
Moldova 2
Bulgaria 1
Jordan 1
Macedonia 1
Oman 1
Romania 1
IFC’s power committed portfolio as of June 30, 2011
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Presentation Outline
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Integrated UtilitySomewhat unbundled Single Buyer System
Generation Transmission DistributionGeneration Transmission Distribution
IPP IPPIPP
Transco Disco
IPP Customers
A bit more unbundled Single Buyer System
Customers
Customers
Customers
Transco
Unbundled
Disco
Market
High Volume CustomersIPP
System Operator
Electricity Market and its Participants
Contractual Framework
What Are You Trying to Achieve?
Why It’s Important
• Allocate the risk to the party who is best positioned to bear it
• Cash/Risk neutrality for Borrower/IPP, e.g. :
• delay liquidated damages (“LDs”)
• pass through of fuel take or pay
• back to back of Force Majeure (“FM”) provisions
• Pre-commissioning: no guarantee of being paid back (unless you have sponsor
support that covers the debt and a creditworthy sponsor – importance of EPC –
track record and contract);
• non–recourse financing (generally with the exception of sponsor support
during construction);
• PPA is often the only source of revenue.
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Why Does It Take so Long?
• Many parties with diverging interests are involved (off-taker, contractor, fuel
supplier, government, regulator, sponsors, other government agencies, groups
of lenders).
• Complex contract structure that at times has to substitute for the absence of
a bankable legal framework for private sector participation.
Contractual Framework – Typical Scheme
SponsorSupportAgreement
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General Risk Overview
� Construction Risk
� Completion on time/loss of PPA
� Completion on Budget
� Completion according to Specifications / reduction in capacity payments
� Operational Risks
� Default risk: project company/off-taker – loss of PPA - Plant
� Affecting Construction and Operational Phase
� Political risk: Government /government – owned Off-taker
� Natural disaster: insurance
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PPA Bankability Issues� Least Cost – Dispatch Order.
� Tenor of PPA vs debt.
� Off-taker Liquidity or Credit Support/ Government Guaranty —Acceptability of comfort letter as proposed substitute.
� Award of PPA and licenses— Transparency scrutiny
� Unusual Force Majeure/Termination Provisions —mismatch among project contracts.
� No Direct Agreement.
� Short term Fuel Supply Agreements – Market disruption on the fuel.
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PPA Bankability Issues
� Stranded asset in the event of loss of PPA - Lack of market – direct sales to high volume customers – sales to neighboring countries.
� Currency mismatch –between costs in FX (ROE, debt, fuel, O&M) and revenue in local ccy.
� Tariffs do not permit reasonable return on equity (what is “reasonable” ?)
� No Inflation Adjustment: Tariff not adjusted to cover components of fixed and variable expenses which rise over time.
� Change of Law/Political Force Majeure: Tariff not adjustable to cover increased costs due to Political Force Majeure (including Change of Law).
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FSA - Certain Key Bankability Issues
� In comparing terms of different contracts (e.g., FSA, PPA and O&M) must consider
start date of term to ensure timely start of delivery obligations.
� Is supply based on an exhaustible reserve? Are reserves dedicated to the Project
Company? Alternate sources?
� Transportation?
� Security over reserves and/or transportation?
� Need for parent guarantee and/or other credit support if Fuel Supplier or Buyer not
sufficiently creditworthy.
� Price/foreign exchange rate risk and hedging/mismatch of PPA.
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FSA - Certain Key Bankability Issues
� Conformity of fuel specifications with equipment manufacturers’
requirements, ash storage capacity, etc.
� Relationship of PPA energy charge calculations with pricing of fuel under FSA
– pass-through? Take or pays? (Sometimes comfort through market studies
in deregulated markets).
� FMs back to back with PPA
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� Mismatch with PPA: technical specifications, completion deadlines,
penalties/damages
� Mismatch with projected Project economics (plant capacity; levels
of delay or performance LDs)
� Owners scope and other work outside scope of EPC Contractor: force
majeure claims, change order claims, price adjustment claims
� “Force Majeure” definition and related risk allocations
� Interfaces between contractors/suppliers
� Change orders
� Environmental requirements
� Other
EPC – Certain key bankability issues & recurring themes
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Presentation Outline
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1997: IFC Advisory signs mandate with Cameroon for the privatization of the countries national utility (Sonel)
1997: IFC Advisory signs mandate with Cameroon for the privatization of the countries national utility (Sonel)
2001 2004 20051997 - 1998
1998: Cameroon passes new electricity law; setting up regulator, and paving the way for PPP in the power sector.
1998: Cameroon passes new electricity law; setting up regulator, and paving the way for PPP in the power sector.
2006 - 20082001 - 2003
2001: Sonel is privatized with AES Corp buying 56% of the 58 year old national utility. The new entity is called AES Sonel
2001: Sonel is privatized with AES Corp buying 56% of the 58 year old national utility. The new entity is called AES Sonel
2012
Key milestonesKey milestones
2010 - 2011
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2012: IFC expected to lead a syndicate of 6 DFIs in securing Eur193.5 Million debt package to support Kribi (Cameroon's 2nd
IPP). This will be a joint WorldBank/IFCproject, with IDA providing a guarantee to unlock local bank financing
2012: IFC expected to lead a syndicate of 6 DFIs in securing Eur193.5 Million debt package to support Kribi (Cameroon's 2nd
IPP). This will be a joint WorldBank/IFCproject, with IDA providing a guarantee to unlock local bank financing
2011: IFC leads a syndicate of 3 DFIs to close US$88 mill for Dibamba, Cameroon’s 1st IPP
2011: IFC leads a syndicate of 3 DFIs to close US$88 mill for Dibamba, Cameroon’s 1st IPP
IFC/IDA ENGAGEMENT IN CAMEROON’S ENERGY SECTOR (~15 YEARS)
2008: World Bank ESDP aims to increase access to energy, improve the planning & management of sector resources, assist with LPHP (unlock hydro potential)
2008: World Bank ESDP aims to increase access to energy, improve the planning & management of sector resources, assist with LPHP (unlock hydro potential)
2006: IFC leads a syndicate of 8 DFIs to raise Eu260 million to support AES-Sonel’s Eu380 million 5 year investment program
2006: IFC leads a syndicate of 8 DFIs to raise Eu260 million to support AES-Sonel’s Eu380 million 5 year investment program
2003: The Kribi gas power project is the trigger for the GOC to develop a comprehensive Gas Masterplan in 2003,
2003: The Kribi gas power project is the trigger for the GOC to develop a comprehensive Gas Masterplan in 2003,
2005: World Bank commences support to strengthen public sector capacity
2005: World Bank commences support to strengthen public sector capacity
IFCIFC
World BankWorld Bank
Cameroon – Country HighlightsEconomy Facts (2005)
• Population: 16 million
• GDP Per Capita (2005): US$ 800 (proj. growth ~5%)
• Currency: CFA Francs (XAF)
• Key Sectors: agriculture (20%), industry (31%), services (49%)
• Oil/gas sector: Cameroon produces about 32 million barrels per year of crude oil; extractive industries account for only 8-10% of Cameroon’s GDP.
• Governance: key impediment to growth/investment; Corruption is prevalent at all levels of society
• Commodity dependent economy: ~34% of GDP (of which oil is less than 5%).
• Major exports: crude oil, cocoa, coffee, cotton, timber
• Surface Area: 475,000 km2
• Vision 2035: GoC aims to reduce poverty, spur growth & create jobs through increased industrialization, improved competitiveness & better governance
• Commercial Center/City: Douala
• Political & Administrative capital – Yaounde
Economy Facts (2005)
• Population: 16 million
• GDP Per Capita (2005): US$ 800 (proj. growth ~5%)
• Currency: CFA Francs (XAF)
• Key Sectors: agriculture (20%), industry (31%), services (49%)
• Oil/gas sector: Cameroon produces about 32 million barrels per year of crude oil; extractive industries account for only 8-10% of Cameroon’s GDP.
• Governance: key impediment to growth/investment; Corruption is prevalent at all levels of society
• Commodity dependent economy: ~34% of GDP (of which oil is less than 5%).
• Major exports: crude oil, cocoa, coffee, cotton, timber
• Surface Area: 475,000 km2
• Vision 2035: GoC aims to reduce poverty, spur growth & create jobs through increased industrialization, improved competitiveness & better governance
• Commercial Center/City: Douala
• Political & Administrative capital – Yaounde
20
Key Project Highlights
• AES Sonel is the privatized integrated national
power utility of Cameroon:
� Privatized in 2001 with advice from IFC advisory
� Acquired by The AES Corp. of the US (56%); Republic of Cameroon retained shareholding of 44%
� Operates under a 20-year concession terminating in 2021
� Holds generation, transmission, & distribution assets in northern & southern grids of Cameroon;
21
• In 2006, IFC led the coordination of EUR 260 million financing of the EUR 380 million five year
Investment Plan being implemented by the Company to renew and refurbish their
generation/transmission/distribution assets in order to improve the quality of service & increase
electrification rates. Syndicate of 8 DFI lenders included IFC, AfDB, EIB, Proparco, FMO, DEG,
EAiF, BDEAC.
Cameroon – Electricity Market Highlights (2005)
22
• Electrification Rates: 31% of urban households & 11% of rural
• Hydro Potential/Dependence: 2nd highest hydro potential in the region(after DRC);
• Installed Capacity: 933 MW with 77% based on hydro, specifically from the Sanaga basin, which is seasonal
• Population Dispersion: highly dispersed population (31% in large towns, and 31% in small towns) makes it expensive to serve the entire population
• Alucam: More than 40% is consumed by a single customer – Alucam – the country’s aluminum smelter
• Tariff Classes/Levels: LV/MV – retail clients with tariffs of EUR 0.9 c/kWh and EUR 9.3 c/kWh respectively; HV – Industrial clients (Alucam) with tariffs of EUR 1.1 c/kWh
• Electrification Rates: 31% of urban households & 11% of rural
• Hydro Potential/Dependence: 2nd highest hydro potential in the region(after DRC);
• Installed Capacity: 933 MW with 77% based on hydro, specifically from the Sanaga basin, which is seasonal
• Population Dispersion: highly dispersed population (31% in large towns, and 31% in small towns) makes it expensive to serve the entire population
• Alucam: More than 40% is consumed by a single customer – Alucam – the country’s aluminum smelter
• Tariff Classes/Levels: LV/MV – retail clients with tariffs of EUR 0.9 c/kWh and EUR 9.3 c/kWh respectively; HV – Industrial clients (Alucam) with tariffs of EUR 1.1 c/kWh
GENERATION ASSETS AND STORAGE DAMS
Lagdo 72 MW
4.5 bn m3
Mbakaou 2.2 bn m3
Mapé 3.6 bn m3
Bamendjin 1.8 bn m3
Total 7.7 bn m3
Song Loulou 384 MW
Edéa 265 MW
Total - Hydro 721 MW 77%
Thermal GRID
HFO 122 MW 13%
Diesel 66 MW 7%
Isolated 24 MW 3%
Total - Generation 932.7 MW 100%
Sanaga River Water Flow Fluctuation
Generation – Strong Hydro Dependence
23
Makary
GoulféFo tokol
A fade
KousseriMaltam
Logone B irni
D jilbe
Ndiguina
W aza
Ko lo fata
M ora
Tokom béré
MeriM okolo
M arouaM indif
M outouroua
Kaélé
Guider
Figuil
LagdoNgong
Bidzar
Pitoa
G aroua
Poli
Tcholliré
Rey Bouba
Touboro
N gaoundéré
LEGENGE
Poste THT/HT 225/90 KV
Poste THT/HT 110/90 KV
Poste HT/M T 90/30/15 KV
Centrale Hydroélectrique
Centrale Thermique
Barrage de retenue
Ligne TH T 225 KV ou 110 KV
Lignes H T 90 KV
C entres AES-SONEL
ENSEM BLE DES INFRASTRUCTURES PERTINENTES AES-SONEL
Lignes M T 30 KV
Yagoua
Réseau Cam rail
Routes nationales
Power infrastructure in CameroonRegional Demand Breakdown
• South grid 850 km 90 kV and 480 km 225 kV T-lines
• 2 components : Alucam and Public Sector
• North grid (9%) - 350 km 110 kV and 200 km 90 kV T-
lines
• Isolated centers (1%) - 30 isolated localities supplied
by LFO small gensets
Regional Demand Breakdown
• South grid 850 km 90 kV and 480 km 225 kV T-lines
• 2 components : Alucam and Public Sector
• North grid (9%) - 350 km 110 kV and 200 km 90 kV T-
lines
• Isolated centers (1%) - 30 isolated localities supplied
by LFO small gensets
Cameroon – Electricity Market Highlights (2005)
• Northern Region - 8.5% of revenues, 4.6% of energy delivery
• Western Region – 12.1% of revenues, 8.3% of energy delivery
• Coastal / Littoral Region –53.7% of revenues, 68.3% of energy delivery
• Center Region – 25.7% of revenues, 18.8% of energy delivery
Cameroon’s Electricity Market
24
Historically, retail demand growth in line with GDP..
0
100,000
200,000
300,000
400,000
500,000
600,000
700,000
800,000
900,000
1977
1979
1981
1983
1985
1987
1989
1991
1993
1995
1997
1999
2001
2003
MW
h/yr
-
500
1,000
1,500
2,000
2,500
3,000
Bn
FC
FA
(co
nsta
nt)
MT BT GDP WB
-
1,000,000
2,000,000
3,000,000
4,000,000
5,000,000
6,000,000
7,000,000
8,000,000
2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021
MW
h
LV sales (MWh) MV sales (MWh) Total energy requirements (MWh) LV+MV sales (MWh)
..and projections illustrate healthy demand growth…
0
200
400
600
800
1000
1200
1400
1600
1800
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
MW
Kribi
Existing capacity
Alucam load
MV/LV load
But also a looming supply deficit
• Significant investment for additional
generation capacity will be needed to
avoid load shedding; This is expected
to come from IPPs – such as Kribi
Cameroon’s Electricity Market
25
Client Base
• Public sector: including low-voltage (domestic, professional and street-lighting), medium
voltage (small businesses, other retail) accounts for 54% of sales & nearly 90% of the
total revenue
• Industrial clients: mainly Alucam and four other large customers, accounts for 44% of
sales & 10% of revenue
Regulatory Framework
• Since 1998, the GoC has initiated a series of policy & structural reforms to improve
efficiency & governance in the power sector and increase private sector participation.
• Electricity law introduced in 1998 sets out basis for a competitive market.
• GoC is a member of the Central African Power Pool (CAPP), which aspires to connect the
electricity grids of all members of the Central Africa Economic Community (CEEAC); GoC
wants to position itself as a key power supplier in the CAPP
Key Stakeholders include:
26
WORST POWER OUTAGES IN CAMEROON’S HISTORY
WORST POWER OUTAGES IN CAMEROON’S HISTORY
MINIMAL PERFORMANCE IMPROVEMENTS
MINIMAL PERFORMANCE IMPROVEMENTS
• Downturn in global infrastructure market immediately following privatization led to inability to fund post privatization program
• AES Corp narrowly escapes bankruptcy due to rapid expansion, crash in energy prices & distress in Latin America where it had significant exposure
• Downturn in global infrastructure market immediately following privatization led to inability to fund post privatization program
• AES Corp narrowly escapes bankruptcy due to rapid expansion, crash in energy prices & distress in Latin America where it had significant exposure
INABILITY TO ATTRACT FDI
INABILITY TO ATTRACT FDI
• …. Leading to strained relationship between AES Sonel & Govt. of Cameroon
• Perceived lack of sensitivity to local culture
• …. Leading to strained relationship between AES Sonel & Govt. of Cameroon
• Perceived lack of sensitivity to local culture
STRAINED RELATIONSHIP
STRAINED RELATIONSHIP
• Cameroon experiences its 4th driest year in 60 years; • 90% of installed capacity is hydro • Severe drought coupled with an uptick in economic growth • Situation exacerbated by poor communication by AES Sonel to its customers• Alucam arbitration against AES Sonel due to inappropriate rationing of power & poor management of the situation
• Cameroon experiences its 4th driest year in 60 years; • 90% of installed capacity is hydro • Severe drought coupled with an uptick in economic growth • Situation exacerbated by poor communication by AES Sonel to its customers• Alucam arbitration against AES Sonel due to inappropriate rationing of power & poor management of the situation
• Electricity losses remained high; collection levels low; E&S standards lacking –
reflecting deferral of significant investments in the sector since 1992
• Substantially below concession targets, particularly new connections, many concession objectives set with unrealistic expectations & were unattainable
• Management & technical team, unable to deal with crisis
• Electricity losses remained high; collection levels low; E&S standards lacking –
reflecting deferral of significant investments in the sector since 1992
• Substantially below concession targets, particularly new connections, many concession objectives set with unrealistic expectations & were unattainable
• Management & technical team, unable to deal with crisis
27
AES Sonel – In crisis in years following privatization…
ADDRESSING SUPLY DEFICIT &
CUSTOMER RELATIONS
ADDRESSING SUPLY DEFICIT &
CUSTOMER RELATIONS
NEW AES SONEL MANAGEMENT
TEAM
NEW AES SONEL MANAGEMENT
TEAM
• Increase in distribution & transmission efficiencies
• Improvement of business processes & organizational structure
• Increase in distribution & transmission efficiencies
• Improvement of business processes & organizational structureSIGNS OF
OPERATIONAL/ FINANCIAL
IMPROVEMENT
SIGNS OF OPERATIONAL/ FINANCIAL
IMPROVEMENT
• All resulting in a more constructive dialogue between AES Sonel & RoC
• Allowing for the re-negotiation of the concession with more realistic targets
• All resulting in a more constructive dialogue between AES Sonel & RoC
• Allowing for the re-negotiation of the concession with more realistic targets
RELATIONSHIP ON THE MEND
RELATIONSHIP ON THE MEND
• Construction of new thermal capacity & good hydrology• 85MW HFO plant at Limbe in 2004, plus another 48MW of thermal capacity• Settlement with Alucam, leading to AES Sonel providing free energy credits
• Construction of new thermal capacity & good hydrology• 85MW HFO plant at Limbe in 2004, plus another 48MW of thermal capacity• Settlement with Alucam, leading to AES Sonel providing free energy credits
• After two rounds of management changes, Jean David Bile was hired as DG,
• Able to take steps to re-build relationship with RoC & demonstrate better
performance through hiring of qualified staff
• After two rounds of management changes, Jean David Bile was hired as DG,
• Able to take steps to re-build relationship with RoC & demonstrate better
performance through hiring of qualified staff
28
…signs of tide turning at time of IFC’s investment
• In parallel, sector institutional capacity strengthened particularly in the Ministry of
Energy with the help of the WB
• Better long term planning in place evidenced by development of a country-wide least cost generation expansion plan
• In parallel, sector institutional capacity strengthened particularly in the Ministry of
Energy with the help of the WB
• Better long term planning in place evidenced by development of a country-wide least cost generation expansion plan
CAPACITY STRENGTHENED WITHIN THE
GOVT
CAPACITY STRENGTHENED WITHIN THE
GOVT
Key Project Strengths – Why we did it
Macro Considerations
Experienced, Capable Sponsor
Strong World Bank Engagement
• Cameroon has enjoyed economic growth and political stability; economic situation
had improved considerably. The growth rate of GDP had risen to a steady 5% per
year; inflation remained low, and the current account deficit turned slightly positive
in 2005
• Strong Sponsor with technical capabilities, global track record in emerging markets
power; After a some problems in 2002, AES Corp had regained its position as a
global power player
29
Government Support
• Although many aspects remain to be developed, the GoC had lent its support to on-
going reform of the sector and privatization of Sonel, authorized tariff increases.
• A least cost generation expansion plan was being developed with all relevant parties
in the sector.
• GoC and AES Corp appointed senior management members/officials to the Board as
a sign of their commitment.
• The World Bank had played a key role in Cameroon by engaging all stakeholders in a
constructive policy dialogue, clearing the way for revision of the Concession and
development of the least cost generation expansion program.
• The Bank also provided capacity building of sector entities;
Strong Earnings Potential
• In spite of recent challenges, revenues had doubled & EBITDA had quadrupled since
privatization; the Company was projected to generate an EBITDA of US$173 million
and net income of US$54 million by the end of the 5 year investment program in
2009; This would have been adequate to service a substantial debt levels
Tariffs
Collections
Reducing network losses
• Accurate & timely billing; timely disconnection of customers for non-payment
• Develop a culture of paying for power – political support important
• Keeping tariffs at reasonable levels helps in maintaining good collection rates
• Aggressively tackling non-technical losses (theft) with effective programs –
understanding of local context & consistent approach are key
• Targeted investments in network to reduce technical losses
30
… so how does AES Sonel make money?
Demand growth & new connections
• New connections an important concession target. However, increasing access
is not always a high payback investment for AES Sonel, particularly in remote
areas. Least cost supply additions needed to keep up with demand growth.
• Good track record of implementing mostly cost reflective tariffs with appropriate
& timely pass-through of costs [& any tariff subsidy];
• Meet concession targets – to avoid incurring penalties
• Tax schemes & tax rates impact tariff levels which can impact tariff affordability
Planning & Investment
• Continuous system planning & productive (high NPV) investments which
improve efficiency & are approved in the regulated asset base
• Concession is structured to bring efficiency & competition into the power sector
• Tariff (& its regulation) is designed to promote efficiency & investment while providing a fair return for
investors & reasonable cost of power for end-users
KEY DRIVERS
Key terms of the AES Sonel Concession (1)
31
Exclusivity: • AES Sonel has exclusive right to provide transmission services & distribute and sell electricity to MV, LV & HV customers fro 20 years. After 1st 5 years: • AES Sonel is to set up a subsidiary to manage the transmission network
Regulated monopoly on distribution , steps towards complete unbundling
Generation cap to promote competition
Improving access a key priority for RoC
Main obligations of AES Sonel *:• Connect 51,000 new customers on average every year during the concession;• Meet performance standards incl. specific targets for un-served energy, • Pay an annual fee to the Regulator of 1% of revenue;• Submit to ARSEL for approval, a 5-year program and financial plan;• Respect principles of equality of treatment, non-discrimination &continuity of power supply;• Link, upon request, any new IPP to the transmission network.
Maximum installed generation capacity: AES Sonel has the exclusive right to install generation capacity in the country up to a cap of 1000 MW
AES Sonel – Tariff Structure
32
• Correct the lack of tariff increases in the years preceding privatization despite the currency devaluation and higher levels of inflation;
• Mitigate external risks to AES Sonel (inflation, hydrology, fuel costs, etc.);
• Provide an incentive to AES Sonel & any other power sector participant to become more efficient in their operations;
• Provide for a sustainable revenue stream, which includes a reasonable rate of return on investment, given efficient, operating and maintenance practices;
• Create an environment which fosters an efficient level of investment within the sector;
• Correct the lack of tariff increases in the years preceding privatization despite the currency devaluation and higher levels of inflation;
• Mitigate external risks to AES Sonel (inflation, hydrology, fuel costs, etc.);
• Provide an incentive to AES Sonel & any other power sector participant to become more efficient in their operations;
• Provide for a sustainable revenue stream, which includes a reasonable rate of return on investment, given efficient, operating and maintenance practices;
• Create an environment which fosters an efficient level of investment within the sector;
• Tariff methodology:
• Different tariff evaluation phases split over 20 year period with a 3 yr grace period for all penalties for unmet obligations
• Price Cap: (1st 10 years) specific formula for average tariffs with pre-agreed increases in tariff levels
• Revenue Cap: (2nd 10 year period) (i) a cap on AES Sonel’s revenues; & (ii) a guaranteed rate of return on AES Sonel’s regulated asset base (requires regulator approval)
• Tariff methodology:
• Different tariff evaluation phases split over 20 year period with a 3 yr grace period for all penalties for unmet obligations
• Price Cap: (1st 10 years) specific formula for average tariffs with pre-agreed increases in tariff levels
• Revenue Cap: (2nd 10 year period) (i) a cap on AES Sonel’s revenues; & (ii) a guaranteed rate of return on AES Sonel’s regulated asset base (requires regulator approval)
What Happened? - AES Sonel Performance vs Projections
33
• Catching up on connections targets,
which have been historically low,
still falls short of cumulative target
• Maintains strong collections rates…
• unserved energy has improved, but
still falls short of targets
• total system losses have historically been &
are still high at 24.9%, in part due to a high
prevalence of fraud.
Operational Performance has been mediocre, falling short of most of the concession targets
34
• Poor operational performance relative to targets has had an impact on the bottom line
• They continue to meet their revenue targets, but underperform on earnings & net income
What Happened? - AES Sonel Performance vs Projections
So, was the privatization successful?
• Cameroon’s electrification
rate of 49% is almost twice
the SSA average & up from
31% at time of IFC
investment
• Cameroon’s end-user tariff of
US$16.5 cents / kWh
consumers are in line with SSA
tariffs
• Although cost reflective, end
user tariffs are relatively high
considering hydro potential
• High system losses & more
expensive thermal capacity
have had pressure on tariff
levels.
35
So, was the privatization successful?
• Despite its ongoing challenges, AES Sonel has succeeded in tripling revenue, growing EBITDA by
6X since privatization & transforming the former govt entity from a loss making utility (with
negative net margin of Euro35 million) to an income generating asset today.
• AES Sonel continues to attract the most capital out of the four privately operated electricity
concessionaires in Sub-Saharan Africa, and represents one of the strongest credits among
power companies in region.
• Private capital flowing to Cameroon’s power sector continues with market opening up to IPP
models, initially Dibamba followed shortly by Kribi.
AES SONEL today generates and distributes power to over 712,000 customers in Cameroon.
36
Designing concession targets / Practical financing covenants
• Need to set realistic & attainable targets at the outset… also important when
managing expectations with government & general population
• Need to ensure that contract is structured with sufficient incentive for appropriate
levels of investment throughout life of concession;
• Revision of priorities should be expected in a financing of a large utility
First Impressions Die Hard
• Being able to show tangible results early on is critical
• AES Sonel was slow to show improvements in performance…due in part to high
management turn-over & poor understanding of local operating / political
environment; The lost credibility has been difficult to regain
The Elusive Loss Reduction …
• Loss reduction can be challenging to achieve & sustainable improvements require a
long-term commitment from a qualified management team; There are few
examples where this has been done successfully
• Proper planning for medium/long term investments is required
• Large investments at early stage of sector reform require intensive supervision
• Broad DFI support, as well as coordinated sector engagement across WBG & DFI
community, is key for managing an effective dialogue with government & the
Sponsor, especially when faced with difficult issues.
Stakeholder Engagement is Not Optional
• Proactive management of stakeholders including government, employees, and
customers is critical; AES could have better managed customers during load
shedding period to avoid arbitration/brand erosion
• Perceived lack of sensitivity to cultural/language differences made relations with
stakeholders more contentious
LOOKING BACK – LESSONS LEARNED
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Building a sustainable energy sector program is a long-term commitment
Presentation Outline
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Kribi Power Development Corporation (KPDC)
� Kribi Project: 216MW gas-fired power plant & 100km transmission line
� Technology:
• Wartsila engines: 13 x 18V50DF- gas reciprocating engines of 16.6MW gross capacity each
• Siemens-KEC JV: 100km 225kV double circuit transmission line; step-up 11/225kV sub-station
� Fuel type: gas to be provided from off-shore Sanaga Gas field
� Location: near coastal city of Kribi, in the South Province of Cameroon
� Target COD: early 2013, in time for dry season
� Off-taker: AES Sonel, integrated power utility for Cameroon
� KPDC is owned by The AES Corporation (56%); Republic of Cameroon (44%)
IPP using PPP Framework
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Kribi: Project Highlights
Kribi confirmed as the next least cost investment in the power sector
The Kribi Project will:� significantly expand the country’s energy generation capacity
� help bridge the period before further hydropower developments
� provides much needed low-carbon thermal complement to hydro-based system
� catalyze the first commercical development of Cameroon's gas reserves
� benefit 163,000 households (equivalent)
As second IPP in Cameroon & one of few IPPs in Africa, the Project: � serves to demonstrate a replicable IPP model
� successful example of a Public Private Partnership in the power sector
Broad and diverse lender group� Prospective DFI lenders include IFC, African Development Bank (AfDB), European Development Bank (EIB), FMO, Proparco, BDEAC
� Standard Chartered Bank led local bank syndicate backed by WB partial risk guarantee
� First private long-term local currency project finance for an infrastructure project
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KPDC: Contractual Structure
� EPC Procurement: Fixed price EPCs Wärtsilä& Siemens T&D /KEC International (KEC) -selected on a competitive basis
� Power Purchase Agreement / Connection Installation Agreement: 20-year off-take with AES-Sonel for 100% of the power;
� Licenses: 20-year sales & generation licenses issued by Minister of Energy upon recommendation of ARSEL;
� Gas Supply Agreement: With SNH (National Petroleum Agency), with Perenco as the upstream operator;
� Government Commitment Agreement:Agreement through which RoC commits its support to the Project
TSA
GSA 2
LICENCES
DIRECT AGREEMENT
AES (56%) GoC (44%)
Power Plant EPC
Kribi Power
Development
Company
(KPDC)
T-Line/CI EPCs
SHA
AES (56%) GoC (44%)
AES SONEL
AES ENGINEERING
SNH
MINEE/ARSEL
LENDERS
Wärtsilä Siemens/KEC T&D
GCA
Loan CTA
PPA
CIA
ASA
GSA 1
WITH: GoC, SNH, [Perenco], AES Sonel, AES Engineering, EPC
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Kribi: Key Project Risks & Mitigants
Sector-related: new electricity law, capacity� Government commitment to reform� WBG active sector dialogue; WB partial risk guarantee (PRG)� Broad DFI support through financing of bankable projects
Timely construction of power plant, transmission line, gas supply facilities� Choice of proven technology & relatively standard design� Competitively bid fixed price contracts with reputable companies� Contractual alignment of construction schedules� Appropriately sized penalties for contractor under-performance
Balanced contractual structure� In line with good industry practice� RoC had international advisors for project structuring & negotiations� Regulator reviewed & provides its non-objection on contracts
Off-taker credit-worthiness� One of the strongest credits among power companies in SSA; � AES Sonel is profitable with EBITDA of US$100M in 2010� End user tariffs are cost recovery with respect to costs of IPPs
There are risks but with appropriate allocation among stakeholders they can be adequately mitigated
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Role & Risk Allocation for Project Sponsor: AES Corporation
� Shareholder / Equity contribution• Strong financial capacity
� Project Development• Experienced Sponsor with track record in emerging markets power
� Arranging financial close• Experience in structuring bankable project documents for project finance lending
• Global relationships with DFI & commercial lenders
� Over-seeing construction & operation of the Project• Technical capability to develop the Project
• Active in Cameroon’s electricity sector since 2001:
• 56% owner of AES Sonel (national integrated utility) – concession awarded in 2001
• 56% owner of Dibamba Power Plant (88MW HFO plant) - COD achieved 2009
• Able to leverage existing in-country platform & expertise of local staff working at AES affiliate companies
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Role & Risk Allocation for Government: Republic of Cameroon
Role
� Shareholder /Equity contribution
� Back-stops bulk of payments in
connection with early termination
of power purchase agreement (PPA)
or gas supply agreement (GSA)
� Maturity enhancement of local
tranche
� Guarantee support for bridge loans
Key Risks
• Sizable contingent obligations vis-à-vis the Project
• Obligations not unusual given early stage of development of country’s energy sector
• Most RoC undertakings are covering risks which are within RoC’s control
• ROC assisted by international advisors
• Commitment to sustainable sector reform
• Non-performance of private participant• Selection of strong & experienced operator
• Performance based incentives / penalties
• Close monitoring by regulator
• Striking right balance between constructive engagement and negative interference
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Key Success Factors for IPPs
• Political commitment to implement IPPs & government support for its
obligations
• Meets a need competitively and efficiently
• Adequate tariffs, good adjustments, payment discipline
• Regulatory framework independent & transparent
• Contractual arrangements balanced & fair
• Good legal documentation: this is contract-based financing
• An appropriate financial structure
• Strong and creditworthy participants
• Government and Private participants advised by experienced firms
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THANK YOU FOR YOUR ATTENTION
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