plan petrobras londres
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Jos Sergio Gabrielli
CEO
August, 2011
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This presentation may contain forward-lookingstatements. Such statements reflect only theexpectations of the Company's managementregarding the future conditions of the economy,
the industry, the performance and financialresults of the Company, among other factors.Such terms as "anticipate", "believe", "expect","forecast", "intend", "plan", "project", "seek","should", along with similar expressions, areused to identify such statements. Thesepredictions evidently involve risks and
uncertainties, whether foreseen or not by theCompany. Consequently, these statements donot represent assurance of future results of theCompany. Therefore, the Company's futureresults of operations may differ from currentexpectations, and readers must not base theirexpectations solely on the information presented
herein. The Company is not obliged to updatethe presentation and forward-looking statementsin light of new information or futuredevelopments. Amounts informed for the year2011 and upcoming years are either estimatesor targets.
The United States Securities and Exchange
Commission permits oil and gas companies,in their filings with the SEC, to discloseproved reserves that a company hasdemonstrated by actual production orconclusive formation tests to be economicallyand legally viable under existing economicand operating conditions. We use certainterms in this presentation, such as
discoveries, that the SECs guidelines strictlyprohibit us from including in filings with theSEC.
Cautionary statement for U.S. investors:
DISCLAIMER
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62%38%
Brasil
Outros
New Discoveries 2005-2010
(33,989 million bbl) Deep-Water
Discoveries
Source: PFC Energy
BRAZIL LEADERSHIP IN RECENT DISCOVERIESDeep-water discoveries in Brazil represent 1/3 of the worldwide discoveries in the last 5 years
In the last 5 years, more than 50% of the new discoveries (worldwide) were made in deep waters
The development of these reserves will demand additional capacity from the supply chain
Expansion of the oil and gas chain in Brazil is in line with this perspective
Petrobras expects to double its proved reserves until 2020, keeping the discovery cost around US$2/boe
Other Discoveries Deep-Waters
Brazil
Other
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INCREASE IN SALES VOLUMES
Sales Volume (thousand boe/day)
652 718731 899
706699 586
231312 320
480
542593 634125
136 147
290
401
1,078
1,3151,2041,097
1,4531,739
997
2,317
436
738
906
9494 97
106
141
1717 17
38
79
3,4643,773 3,848
4,958
7,142
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
2009 2010 2011 2015 2020
Fertilizers
Electric Energy
Biofuels
International Sales(*)
Natural Gas
Exports
Other Di stribui tors
Sales to BR
BP 2011-15 - Petrobras Total Sales Volume
6.6% p.y.
5.6% p.y.
(*) international area sales and offshore trading operations free from eliminations
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Investment Program
2011-15
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2010-14 Business Plan
53%
33%
2% 1%1% 2%
8%
2,9
E&P RTC
Gs,Energia & Gs Qumica Petroqumica
Distribuio Biocombustveis
Corporativo
5% of investments will be made overseas, 87%
of which in E&P
HSEE (US$ 4.2 bi), IT (US$ 2.7 bi), Technology (US$ 4.6bi), Logistics (US$ 17.4 bi), Maintenance & Infrastructure
(US$ 20.6 bi)
2011-15 Business Plan
US$224.7 billionUS$224 billion
65,5
14,7
4,1
3,24,2
2,3
65,5
14,7
4,1
3,24,2
2,4
2011-2015 INVESTMENTS
Stable investments, greater focus on E&P
57%31%
6%2%
1%1% 2%
(*) US$22.8 billion in Exploration
(*)
Biofuels
Gas, Energy & Gas Chemicals
Distribution
Corporate
E&P
Petrochemicals
RTM
118.8
73.6
17.8
5.1
2.43.5
2.9
127.570.6
13.2
3.8
3.14.1
2.4
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Maintained
New
US$ billion
Excluded
192,6213,2
10,8
(R$ 419.7 billion)
BP 2011-15BP 2010-14
82,9
37%
141,1
63%
90,6
40%
134,1
60%
Total in Foreign Currency
Total in Local Currency
32,1
INVESTMENTS BP 2011-15 VS. BP 2010-14
Increase from new E&P projects and FX rate offset by downstream deferrals
0,3%
-9,7%
(R$ 388.9 billion)
Maintained
US$ 224 billion US$ 224.7 billion
Changes in:
FX rate 8.6
Budget 1.5
Schedule (23.7)
Business model (0.6)Scope (6.4)
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Exploration & Production
+ US$8.7 billion
New Projects
Transfer of Rights
New Pre-Salt Units (Lula)
Infrastructure
New Discoveries and R&D
Excluded, Revised and/or
Postponed Projects
Projects discontinued afterunsuccessful exploratory phase
Revision of Development Projects
KEY CHANGES IN PORTFOLIO
Reassignment of E&P investments
Gas & Energy
- US$4.6 billion
Supply(includes Petrochemicals)
- US$4.3 billion
New Projects TPP Barra do Rocha I TPP Bahia II
Projects concluded in 2010
Gas pipelines: Gasene, Pilar-
Ipojuca, Gasduc III and Gasbel II
Excluded, Revised and/or
Postponed Projects
Postponement of projects: UFN IV,
UFN V, GTL Paraffins and Gas FSO
Exclusion of Catu-camaari gaspipeline and Ecomp Itajupe
Exclusion of TPP projects (from
2010 auctions)
New Projects
New Comperj units
Oil Logistics
Projects concluded in 2010
Braskem capital contribution
Fuels quality investment
Excluded, Revised and/or
Postponed Projects
Postponement of Premium IRefinery
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75,7
224,751,0
41,4
33,5
5,4 4,113,5
0
50
100
150
200
250
Aprovados
at 2009
2010 2011 2012 2013 2014 Ps 2014 Total
275 projetos
95 projetos
104 projetos
112 projetos39 projetos
22 projetos 41 projetos
34%
23%
18%
15%6% 2% 2%
US$ billion
INVESTMENTS AND PROJECT APPROVAL TIMELINE
2011-15 Period
US$224.7 billion
688 projects
Approved
until 2009
After 2014
95 projects
104 projects
112 projects39 projects
22 projects 41 projects
275 projects
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ROCE
-5%
0%
5%
10%
15%
20%
25%
30%
35%
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
Companhias Integradas Companhias de E&P Companhias de Refino
E&P Investments (57% of total) ensure production growth and high IRR
Other investments (43% of total) add value to the chain, generating returns equal or higher than the cost of
capital
Investments in quality are a legal requirement
Total investments (BP 2011-2015) with attractive IRR Petrobras is an integrated company ready to speed up production growth
Reduced cost due to a higher business integration and a leading position in a large and growing market
CONSOLIDATED RETURNS
E&P drives results
Source: selected company data
Integrated companies
deliver better returns
Integrated Companies Downstream CompaniesE&P Companies
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Funding Needs
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Based on 2011-2012 forecasts: Banks (Source: Bloomberg)
Based on 2013-2015 forecasts: PIRA, DOE, CERA, WoodMackenzie, IEA
0
25
50
75
100
125
150
175
200
225
250
2010 2011 2012 2013 2014 2015
PetrobrasScenarios
95
80
US$/bbl
OIL PRICE
Oil price assumptions within market's expectations
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Oil price
Foreign Exchange Rate
Brazilian Market Growth
Average Realization Price (ARP) Brazil
International Parity
International margins per product
Oil and oil products exports and imports
Investment Program
Divestments and business restructuring
Third-party funding
AssumptionsNo Equity Issue in the period
Investment grade maintenance
Key variables for Cash Generation and Investment Level
VARIABLES
Key variables that impact the cash flow and funding needs
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125,0
148,9
224,7 224,7
91,4
67,0
31,4 30,9
26,1 26,1
13,6 13,6
Scenario A Scenario B
US$ 256.1 US$ 255.6US$ 256.1 US$ 255.6 Key assumptions
Scenario A Scenario B
Exchange rate
(R$/US$)1.73 1,73
Brent (US$/bbl)
2011 110 2011 110
2012 80 2012 95
2013 80 2013 952014 80 2014 95
2015 80 2015 95
Leverage (Average) 29% 26%
Net Debt/EBITDA
(Average) 1.9 1.5
ARP (R$/bbl) 158 177Debt Amortization
Investments
Divestment and Restructuring
Cash
Third-Party Resources (Debt)
Operating Cash Flow (After Dividends)
Sources Use Sources Use
CASH GENERATION AND INVESTMENTS
Divestment and traditional funding sources adequate for Plan needs
40% of capex in dollar in comparison to 37% in the
previous Plan
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Exploration & Production
US$127.5 billion
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Increase oil and gas reserves and production, in a sustainable manner, and be
recognized for its excellence in E&P operations, placing the Company among the worlds
five largest oil producers
2011-15 Business Plan Highlights:
65% of Capex allocated to production development
19 large projects, adding capacity of 2.3 million bpd
Drilling of more than 1,000 offshore wells, of these 40% is exploratory and 60% is production
development
In 2020, the pre-salt production will correspond to 40.5% of the oil production in Brazil
STRATEGY
Sustainable development of hydrocarbon reserves
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Annual investments of more than US$ 4 billion in exploration Investments of US$ 12.4 billion related to the transfer of
rights areas in 2011-15
In the BP 2010-2014, the forecasted investment for the Pre-Salt was of US$33 billion
Pre-Salt
US$ 53.4 billion
Post-Salt
US$ 64.3 billion
17%
65%
ProductionDevelopment
18%
Exploration
Infrastructure68%
Other areasTransfer of
Rights
26%
Pre-salt
6%
Exploration
Production Development
Pre-salt
37%
Transfer of Rights
Other areas
48%
15%
E&P investments in Brazil: US$117.7 bn
E&P INVESTMENTS IN BRAZIL 2011-15 BUSINESS PLAN
Note: Pre-salt includes Basins in Santos, Campos and Esprito Santo
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18Note: Does not include Non-Consolidated International Production.
Pre-salt and Transfer of Rights will represent 69% of
the additional capacity up to 2020
Pre-Salt participation in the total production will
enhance from the current 2% to 18% in 2015 and
40.5% in 2020
PRODUCTION
Petrobras can more than double production in the next decade
1.855 1.971 2.004
321 317334
435
618
1.120
111 132144
141
180
246
2.100
99 9693 96
125
142
2008 2009 2010 2011 2015 2020
Oil Production- Brazil Natural Gas Production - Brazil Oil Production - International Natural Gas Production - International
2,386 2,516
6,418
3,993
1,148543
Pre-Salt000boe/day
2,772
845
Transfer of Rights13
+10 Post-Salt Projects
+8 Pre-Salt Projects
+1 Transfer of Rights
+ 35 Systems
Added Capacity
Oil: 2,300,000 bpd
2,575
3,070
4,910
3,907
2.004
2.980
144
176
623
334
128
93
2010 2014
+ 9 Post-Salt Projects
+ 5 Pre-Salt Projects
Business Plan 2010-14
2,575
Added Capacity
Oil: 1,800,000 bpd
Business Plan 2011-15
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112 211230 21475
400 292189
749
1,601
42
0
400
800
1200
1600
2000
1980 1990 2000 2010
Deep water
Shallow water
Onshore
187
2,004
1,271
653
10%10% p.yp.y over the last 30 yearsover the last 30 years
ThousThous. bpd. bpd
123 offshore units (45 floating and 78 fixed)
25 new units installed over the last 5 years
P-56P-57
PRODUCTION
Long history of implementing offshore projects in Brazil
Onshore Shallow Water Deep WaterDeep & Ultra-Deep Water
Pre-Salt
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3.070
2.1002.004
0
500
1000
1500
2000
2500
3000
2010 2011 2012 2013 2014 2015
Thous.
bpd
Lula Pilot
FPSO BW Cidade
Angra dos Reis
100.000 bpd
Cachalote and
Baleia Franca
FPSO Capixaba
100.000 bpd
Marlim Sul
module 3
SS P-56
100.000 bpd
Jubarte
FPSO P-57
180.000 bpd
Baleia Azul
FPSO Cidade de
Anchieta
100.000 bpd
(FPSO Espadarte
reallocation)
Roncador
module 4
FPSO P-62
180.000 bpd
Roncador
module 3
SS P-55
180.000 bpd
Papa-Terra
TLWP P-61 &
FPSO P-63
150.000 bpd
Guar (North)FPSO
150.000 bpd
Parque dasBaleias
FPSO P-58
180.000 bpd
Tiro/SidonFPSO Cidade de
Itaja
80.000 bpd
Tiro Pilot
SS-11
Atlantic Zephir
30.000 bpd
Mexilho
Jaqueta
HG
EWT Guar
FPSO Dynamic
Producer
30.000 bpd
ESP/Marimb
FPSO
40.000 bpd
Urugu
FPSO Cidade de
Santos
35.000 bpd
AruanFPSO
100.000 bpd
Guar Pilot 2
FPSO Cidade de
So Paulo
120.000 bpd
Lula NE
FPSO Cidade de
Paraty
120.000 bpd
Maromba
FPSO
100.000 bpdSiri
Jaqueta eFPSO
50.000 bpd
Cernambi
South
FPSO
150.000 bpd
FPSO P-67
Replicant 2
150.000 bpd
BMS-9 our11
4 EWTs
Pre-salt
FPSO P-66
Replicant 1
150.000 bpd
BMS-9 or 11
Baleia Azul
FPSO
60.000 bpd
Juru NG
Tamba
FPSO Cidade
de Santos
NG
EWTs
EWTs Lula NE
e Cernambi
FPSO BW
Cidade So
Vicente30.000 bpd
EWT Carioca
FPSO Dynamic
Producer
30.000 bpd
Franco 1
Transfer of
Rights
FPSO
150.000 bpd
3 EWTs
Pre-salt
5 EWTs
Pre-salt5 EWTs
Pre-salt
NEW PROJECTS
Large projects drive the increase in production Pre-Salt and Transfer ofRights Projects
NG Projects
Post-Salt ProjectsDocumento
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0
4
8
12
16
20
P-43 P-48 P-50 P-52 P-54 P-53 P-51 FPSO
CAPIXABA
P-57
Para atingir 50% capacidade
Para atingir 75% capacidade
Months
2004 20062005 2007 2007 2008 2009 2010
Water Depth 2006 2008 2010
Up to 1,000 meters 6 11 111,000 to 2,000 meters 19 19 21
Over 2,000 meters 2 3 15
From 2007 to 2012 Petrobras will double its fleet of contracted drilling rigs, focusing on modern, recently built drilling rigs
with capacity to operate in the Pre-salt layer
2011 2012 2013
+2 +1 +1
+10 +13 +1
2010
Forecast
NEW PROJECTS
Higher number of drilling rigs will enable a faster ramp-up of the new platforms
P-56: 1 producing well and 1 injection well at the start-up (3Q11). 4 connected wells by end of 2011
To reach 50% capacity
To reach 75% capacity
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34
3
5 5
41
4
1
2011 2012 2013 2014 2015
TLD - Pr-Sal e Cesso Onerosa TLD - Outras reas
Stable production
Restriction due to flaring limitation
Good reservoirs behavior
Good lateral communication
No oil flow issues
Results obtained during EWTs
PRE-SALT RESULTS
EWT results and learning curve from drilling show improving economics
Average drilling time of wells completed during the year
(versus combined average time for 2006/7)
5 wells
4 wells
5 wells
6 wells
EWT Schedule
EWT Pre-Salt and Transfer of
Rights
EWT Other areas
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COST-BENEFIT ANALYSIS
Capital investments required by Plansal 45% lower, increasing NPV
Investment
Ne
tPresentValue
ConcessionAreas
ConcessionAreas
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Key Assumptions:
150,000 bpd FPSO
Production of 500,000 BOE
Ramp-up in line with industry Historic decline rate
Oil value = 95% Brent
Does not include exploration andacquisition costs
The graph illustrates the cost-benefit ratio of a standard production development in Brazil, using assumptions
based on previous experiences
Case 3 US$12/boe Capex / US$5/boe Opex without Special Participation (such as Transfer of Rights)
Case 1 US$12/boe Capex / US$5/boe Opex
Case 2 US$15/boe Capex / US$7/boe Opex
(expected scenario)
PROFITABILITY
New E&P projects generate attractive returns
US$/ bbl
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E&P PROFITABILITY IN BRAZIL
E&P profitability strongly correlated to oil price
Production in Brazil: 86% oil and 14% gas
Higher net profit per barrel yields better returnthan its peers
Stable regulatory environment allows for
capturing the benefits of the increase in oil prices
Peers: BP, CVX, XOM,RDS, TOT
E&P ROCE
E&P Net Income ($/boe)Brent vs. Net income per Barrel
Profitability of oil Production in Brazil fully exposed to oil prices
Petrobras
Peers
Petrobras
Peers
Brent (Average in dollars)
Netincomepe
rBarrel(US$)
Source: PFC Energy
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VARREDURA PROJECT
Technological development and exploratory optimization
Additional recoverable volume from discoveries:
Post-salt: Marimb, Marlim Sul and Pampo:
1,105 MM boe
Pre-salt: Barracuda, Caratinga, Marlim, Marlim
Leste, Albacora and Albacora Leste: 1,130 MM
boe*
Well productivity exceeds 20,000 bpd
Between 2011 and 2015 67 exploratory wells will be drilled in current production
areas in Campos basin
Varredura Project
*No volumes have been announced regarding the Marlim Leste and Albacora Leste discoveries.
Descobertas do Pr -salna Bacia de Campos2009/10 (VARREDURA)
Discoveries in Pre-salt
Campos Basin 2009/10
(Varredura)
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NEW TECHNOLOGIES
Applications enhance recovery, slow decline rates and increase production
VASPS
Technological Solution Technology Status
Subsea Pumping
Systems
Subsea BCS In Operation
Subsea Pumping Model In Operation (Jubarte e Golfinho)
Skid BCS Prototype in TLD ESP 23 (Oct/11)
Subsea Multiphase Pump BMSHA Prototype in Barracuda (Dec/11)
Gas/Liquid Subsea
SeparationVASPS Prototype Tested in P-08 (2011)
Oil/Water Subsea
SeparationSSAO Prototype in Marlim (End of 2011)
Raw water injectionSRWI Prototype in Albacora (End of 2011)
Subsea electric
transmission and
distribution
Under qualification Prototype scheduled to 2015
Underwater Electric
Pump in SkidRaw water injection Oil/Water Subsea
Separation
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NEW VESSELS AND EQUIPMENTS
Resources required for production growth
39 rigs contracted, 28 more to be built by 2020:39 rigs contracted, 28 more to be built by 2020:
o Until 2013: 16 rigs contracted before 2008 and 2 rigs relocated from international operations; +15 newrigs contracted in 2008, +1 in 2009, +1 in 2010 and +4 in 2011 through international bidding
o 2015-2020: From the 28 rigs to be built in Brazil, EAS won the bid for the first package - constructionand chartering of seven drilling rigs to be built in Brazil. A new bid was open for the remaining 21
Critical Resources Current Situation(Dec/10)
Delivery Plan (to be contracted)
Accumulated Value
By 2013 By 2015 By 2020
Drilling Rigs Water Depth Above 2.000 m 15 39 37 (1) 65 (2)
Supply and Special Vessel 287 423 479 568
Production Platforms SS e FPSO 44 54 61 94
Others (Jacket and TLWP) 78 80 81 83
Production
Platform (FPSO)Drilling RigsSupply Vessel
(1) Two rigs reallocated from international operations, expire in 2015, so it is not considered in the 2020 accumulated value
(2) The demand for long-term will be adjusted as new demand assessments are made.
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Development
Duration: 4 yearsExtendable for 2 more years
Variable, according toDevelopment Plan
Total Duration: 40 years, extendable for 5 more years according to specific criteria
TRANSFER OF RIGHTS
Development of the areas fully under way
Declaration of Commerciality
Exploration Production
Area 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020
Franco
lara surroundings
Florim
NE of Tupi
South of Guar
South of Tupi
Resources already
available for:
7 Exploratory wells
1 contingent Exploratory
well
1 EWT
2 contingent EWTs
3D Seismic
First 4
production
units
undergoing
contracting
(*)
New technologies
and definition ofresource allocation
* Conversion at the Inhama shipyard
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THE TRANSFER OF RIGHTS
Mechanisms for the revision allow for fair valuation
The revision will be completed after the declaration of commerciality (4 years period)
Revision based on technical reports and on assumptions provided in the contract
Assumptions for price revision:
Changes in oil price
Production curve
Cost assumptions update
No changes in the discount rate and same appraisal base-date
Higher Lower Petrobras pays the difference to the Federal
Government
(or) Petrobras requests a reduction involumes corresponding to the difference
Federal Government pays the differenceto Petrobras
Finalvalue
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BENEFITS FROM THE DEVELOPMENT OF THE LOCAL INDUSTRY
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Suppliers investing in Brazil
Flexible pipes - Wellstream and Prysmian
Pumping Units Weatherford
Valves Cameron
Turbine generators Rolls-Royce
2 FPSOs fully built in Brazil
6 Platforms under construction in Brazil
Construction of 8 hulls for replicant FPSOs (65% Local
Content)
Contracting of 7 drilling rigs at competitive cost and
21 being leased (55%-65% Local Content)
BENEFITS FROM THE DEVELOPMENT OF THE LOCAL INDUSTRY
Source: Sinaval
Platforms built in Brazil with competitive cost
30 x
Jobs Positions at Navy IndustryDocumento
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Refining, Transportation &
Marketing (RTM),
Including Petrochemicals
US$74.4 billion
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DOWNSTREAM INVESTMENTS
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US$70.6 billion
Refining Capacity Expansion: Abreu e Lima
Refinery, Premium I and II, and Comperj
Quality & Conversion: Modernization,
conversion, and hydrodesulphurization projects
Operational improvement: maintenance &
optimization, HSE, and R&D
Fleet Expansion
Logistics for Oil: oil supply to refineries and oil
exports infrastructure
1.1%
4.5%
26.4%
0.8%15.2%
Logistics for Oil
International
Fleet Expansion
Quality and Conversion
Refining Capacity Expansion
Operational improvement
1.0%
23.9%
13.9%
4.9%
Petrochemical Investments amount to US$3.8 billion
DOWNSTREAM INVESTMENTS
New refineries, fuel quality and modernization account for 74% of RTM investments
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DOWNSTREAM EXPANSION
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DOWNSTREAM EXPANSION
Reduced dependence on imports of oil products
* Source: IEA 2010 World Energy Statistics** Without considering Capacity Expansion
2006 2007 2008 2011E2009 2010
Brazil (2020)**
IndonesiaMexico
Spain
JapanChina
Germany
France
Brazil (2010)USA
Net Imports as a percentage of total demand (%)*
000 bpd
Increase in import levels will lead to higherlogistical costs...
... and to high levels of exposure tointernational supply
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PRODUCTION DOWNSTREAM AND DEMAND IN BRAZIL
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Oil and NGL Production Brazil Total crude oil processed Brazil Oil Products Market (2 scenarios)
PRODUCTION, DOWNSTREAM AND DEMAND IN BRAZIL
Construction of new refineries to meet the demands of the local market
1,8
11
2,2
05
3,2
17
1,9
71
2,0
04
2,1
00 3
,070
4,9
10
1,7
92
1,7
98
1,9
33
2,1
47
2,2
08
0
1,000
2,000
3,000
4,000
5,000
2009 2010 2011 2015 2020
,000 bpd
Abreu e Lima
Refinery (RNE)230,000 bpd
(2012)
COMPERJ
(1st phase)
165,000 bpd
(2013)
PREMIUM I
(1st phase)300,000 bpd(2016)
PREMIUM I(2nd phase)300,000 bpd
(2019)
PREMIUM II300,000 bpd
(2017)
COMPERJ(2nd phase)165,000 bpd
(2018)
2,536
3,0952,643
3,327
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REFINERY EXPANSION 2011-15
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Capacity: 230,000 bpd
Stage: Implementation
Startup: 2012
REPRE I
Comperj
Abreu e Lima Refinery
Capacity: 330,000 bpd
Stage: Implementation
Startup: 2013 and 2018
Capacity: 300,000 bpd
Stage: Preliminary License issued
Startup: 2017
REPRE II
RNE
Comperj
Capacity: 600,000 bpd
Stage: Earthworks
Startup: 2016 and 2019
Premium I Refinery Premium II Refinery
60s50s 70s 80s 90s 00s
RL
AM
RE
CAP
RP
BC
RE
MAN
RE
DUC
RE
GAP
RE
FAP
RE
PLAN
RE
PAR
RE
VAP
RN
EST
CO
MPERJ
10s
32 years
Petrobras Refineries
Learning curve from Abreu e Lima and Comperj will reduce Premium refineries CAPEX
REFINERY EXPANSION 2011 15
First construction of greenfield refineries in 32 years
PR
EMIUM
I
PR
EMIUM
II
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PRODUCT DEMAND
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Market in 2015Market in 2010
Product deficits in the northeast determine location of new refineries
Increased demand in Central-West, Northeast, and North regions explains the investments in the Northeast
Tax incentives and environmental restrictions (in other regions) contribute to these investments assignments
552
Deficit
-416
Demand
968
Capacity
1.652
Deficit
-23
Demand
1.675
Capacity
299
-464
763
82
1.466
1.384
DeficitDemandCapacity
SurplusDemandCapacity
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PRODUCTS
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21%
4%
7%
10%
Light
36%
6%
9%
21%
Medium Distillated
43%
5%
38%
Others
Fuel OilSpecialNaphtha
LPGGasoline
Jet FuelDiesel
Intermediary
4%
15%
19%
4%11%
15%
65%
15%
50%
Existing refineries output 2020
LightMedium Distillated Others
New refineries output 2020
Higher global demand for medium-distillates products tends to lead to an increase in these prices
New refineries will produce higher value-added oil products
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PREMIUM REFINERIES
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Design competition project based on the lowest cost
Hiring of UOP - international company with wide experience
Unique design integrating both on-site and off-site
Designer involved from conceptual design to technicalassistance when the start up
Economy of Scale (Train: 300kbpd modules)
Standardization of equipments
Age (years)
Scale (000 bpd)
Positive returns based on scale, standardization and design
Current downstream cost
(US$ / bbl in 2010)
Lower refining cost due to designquality and scale
Economies of scale and new implementationstrategies to reduce Capex, including:
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INVESTMENT LEVEL
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US$ 16 billion
1.01.0
3.2
4.9
5.9
7.0
4.5
2.3
1.1
0.20.1
15141312111098765
-15%p.y.
Decreasing investments in quality after the segments modernization stage
US$16 billion in 2011-15 Reduction in sulfur content
Avg. Sulfur content Diesel (ppm)
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MARKET IN BRAZIL
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Free market follows international prices in the long term
20
40
60
80
100
120
140
160
2011201020092008200720062005200420032002
US$/bbl2002-2011
ARP Brazil
ARP USA
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Natural Gas, Electric Energy
and Fertilizers
US$13.2 billion
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GAS, ENERGY, AND GAS-CHEMICALS; 2011-2015
US$ 13 2 billion in gas pipelines LNG regasification power and fertilizers
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US$ 13,2 billion in gas pipelines, LNG regasification, power and fertilizers
2011-15 Investments
US$13.2 billion
Investment cycle in the expansion of the
transportation network to be completed by
2011
New city gates and negotiation with distribution
companies aiming to increase the sales and
establish different contract types
Investment in thermal power generation
Investment in LNG for the pre-salt gas
production transportation and to supply the
thermal power market
investment in natural gas conversion into urea,
ammonia, methanol and other gas-chemicalsproducts
3,4
5,9
0,30,8 26%
21%
45%
2%6%
3,4
2,8
5,9
0,30,8
3,4
2,8
Network Electric Energy
Gas-chemicals plants(Nitrogenized)
International
LNG
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2ND INVESTMENT CYCLE: MONETIZATION OF THE PRE-SALT RESERVES
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UFN III (Sep/14)
Regs Bahia
(Jan/14)
New NG TPPs
Urucu-Manaus
Gasbel II
Gasduc III
Gastau
Gasene
Gaspal II
Gasan II
Pilar-Ipojuca
Atalaia-Itaporanga
Cacimbas-Vitria
Catu-Pilar
Japeri-Reduc
Gascav
Gascar
LNGPecm
LNGBGUA
TPP Biofuel Conversion
Termoau
Cubato
Ammonia Sulfate (May/13)
ARLA 32 (out/11)
NG Comps + City gates + Network Maintenance
UFN IV (Jun/17)
Acquisition TPPs
UPGN Cabinas
2nd Route Pre-Salt(Aug/14)
Adjustment of the Gas Pipeline Network (US$ 3.34 bi)
New NG TPPs (US$ 1.82 bi)
LNG regasification (US$ 0.74 bi)
Chemical Transformation of NG (US$ 5.85 bi)
TPP Commitments (US$ 0.94 bi)
Renewable Energy: Wind Power and Biomass (US$ 0.02 bi)
Natural Gas Liquefaction (US$ 0.10 bi)
%o
ftotalinvestment
UFN V (Sep/15)
1st Investment Cycle
COMPLETED
2nd Investment Cycle2nd Investment Cycle
20112011--2015 BP2015 BP
45
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INCREASING DEMAND
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Generation CapacityFertilizer Production
420420
581
6,6946,098
8,894
34
30
44
-1,000
1,000
3,000
5,000
7,000
9,000
11,000
2011 2015 2020
MW
0
10
20
30
40
50
60
70
UTE Renewable Natural Gas Consumption
Millioncm/d
7,114
9,475
6,518
Millioncm/day
New units to consume higher natural gas production
UFN III (Sep/2014)
UFN IV (Jun/2017)
UFN V (Sep/2015)
Brazil currently imports 53% of its total ammonia consumption and will be self-sufficient in 2015
Brazil currently import 53% of the total urea consumed. This amount will reduce to 28% in 2015, 16% in 2017 and
22% in 2020
813813
291
2,936
2,271
1,109
13
3
6
0
1.000
2.000
3.000
4.000
2011 2015 2020
Thous.
ton
/year
-
5
10
15
20
25
30
Ammonia Urea Natural Gas Consumption
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SUPPLY & DEMAND (MILLION M3/D)
Increasing supply of associated domestic gas and flexible demand
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TotalDemand
Thermal Power Plants Demand: Petrobras + Third parties
Increasing supply of associated domestic gas and flexible demand
Firm
Flexible30
24
30
24
30
24
202020152011
TotalSupply
173149106 20015196
Downstream
UPGN
Fertilizers61
32
16
39
25
17
Petrobras Demand: Downstream + Fertilizers
Non-thermal power
LDC Demand
202020152011
2011 2015 2020
2011 2015 2020
2011 2015 2020
Guanabara Bay
Pecm
Bahia41
20
1441
20
1421
14
Bolivian Supply
Domestic NG Supply
Supply via LNG Regasification Terminals
Inflexible
Flexible40
13
3725
2011 2015 2020
To be contracted (5.5 GW
76
(15.1 GW)59
(10.7 GW)38
(6.7 GW)
DEMANDPCS 9.400 kcal/m
4969
936
9
9 North Region
Other Regions
55
78
102
SUPPLY
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Biofuels
Distribution
International
US$18.2 billion
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BIOFUEL INVESTMENTSPriority for ethanol in partnership with private companies
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Priority for ethanol in partnership with private companiesINVESTMENTS
US$ 4.1 billion
Ethanol
Ethanol Logistics
Biodiesel
R&D
273%
1.5
Pbio + Partners
5.6
16%
735
855
Pbio + Partners
Market Share Pbio+Partners:
2011: 28%
2015: 26%
Biodiesel supply (000 m)
2011 2015
Ethanol supply (million m)
2011 2015
Market-share Pbio+Partners:
2011: 5.3%
2015: 12%
47%
7%
32%
14%
1.9
1.3
0.6
0.3
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Final Considerations
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TECHNOLOGY MANAGEMENT
Complete integration with suppliers research institutions and other oil companies
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Other operatorsOther operators
International Research
Centers
International Research
Centers
SuppliersSuppliers
Brazilian Universitiesand Research CentersBrazilian UniversitiesBrazilian Universitiesand Research Centersand Research Centers
Four R&D centers of Petrobras suppliers under construction
In order to meet local content requirements, several companies will develop technological centers
in Brazil
Expenditures: US$1.3 billion / year
Complete integration with suppliers, research institutions and other oil companies
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