press release business plan 2011-2015 presentation
TRANSCRIPT
2
This presentation may contain forward-looking statements. Such statements reflect only the expectations of the Company's management regarding the future conditions of the economy, the industry, the performance and financial results of the Company, among other factors. Such terms as "anticipate", "believe", "expect", "forecast", "intend", "plan", "project", "seek", "should", along with similar expressions, are used to identify such statements. These predictions evidently involve risks and uncertainties, whether foreseen or not by the Company. Consequently, these statements do not represent assurance of future results of the Company. Therefore, the Company's future results of operations may differ from current expectations, and readers must not base their expectations solely on the information presented herein. The Company is not obliged to update the presentation and forward-looking statements in light of new information or future developments. Amounts informed for the year 2011 and upcoming years are either estimates or targets.
The United States Securities and Exchange Commission permits oil and gas companies, in their filings with the SEC, to disclose proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally viable under existing economic and operating conditions. We use certain terms in this presentation, such as discoveries, that the SEC’s guidelines strictly prohibit us from including in filings with the SEC.
Cautionary statement for U.S. investors:
DISCLAIMER
4
INVESTMENT REQUIREMENT DUE TO GROWING WORLDWIDE OIL DEMAND
• Additional capacity required in 2020: 38 MM bpd
• Incorporation of new discoveries
• Alternative energy sources
• Increased energy efficiency
Source: WoodMackenzie
20
30
40
50
60
70
80
90
100
110
2000 2005 2010 2015 2020
20
30
40
50
60
70
80
90
100
110
2000 2005 2010 2015 2020
(Global Liquids Demand in MM bpd)LIQUIDS DEMAND SCENARIO
Probable and developing projects
Non-OPEC
OPEC Projected Decline
Projected Decline Non-OPEC
OPEC
Probable and developing projects, and new discoveries*
5Source: BP Statistical Review 2011
OECD oil consumption decreases 0,04% p.y.
5
BRAZIL IS THE SEVENTH LARGEST WORLD OIL CONSUMER
Brazil oil consumption grows 2.1% p.y.;
1.61.71.82.02.32.42.42.62.83.23.34.5
9.1
EUA
China
Japan
India
Russia
Saud
i Arabia
Brazil
German
South Co
rea
Canada
Mexico
Iran
France
United Kingdo
m
Total Oil Consumption per Country* – 2010 (MM bpd)
19,15
Above 3 MM bpd Between 2‐3 MM bpd Under 2 MM bpd
Total Oil Consumption(Índex 1999 = 100)
90
110
130
150
170
190
210
230
1999 2001 2003 2005 2007 2009
BrazilEUAWorldOECDIndiaChina
* Including Ethanol + Biodiesel
6
SUPPLIER CHAIN DEVELOPMENT POLICY
Sustainability Competitiveness
Health, Safety and
the Environment
Industrial Performance
Fiscal Policy
Financeability Regulation
Foment micro and small companies
Industrial Policy
Industrial Capacity
Professional Qualification
Technological Qualification
Qualification
Maximize Local Content
Strategic Guidelines
TechnologyStimulate Supplier
ChainIncrease in Demand
Phase I Phase II Phase III
• Industrial Reactivation
• Consolidation of Shipyards
• Establishment of Supplier Chain
• Professional Qualification
• Technological Research and Development
• Consolidation of Production Chain
Local ContentInternational
Competitive Level> Local Content
7
1.855 1.971 2.004
321 317 334 435
618
1.120
111 132 144141
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
4.9% p.Y.
6,418
3,993
1,148543 Pre-Salt’0
00 boe
/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
Note: Does not include Non‐Consolidated International Production.
• Accomplishment of 30 EWTs from 2011 to 2015: 13 in the Pre‐Salt, 7 in the transfer of rights area and 10 in the post‐salt;
•Pre‐Salt participation in the total production will enhance from the current 2% to 18% in 2015 and 40.5% in 2020.
3,070
4,910
OIL, LNG AND NATURAL GAS PRODUCTION – BRAZIL AND INTERNATIONAL
8
INCREASE IN SALES VOLUMES
Sales Volume (thousand boe/day)
652 718 731 899
706 699 586231
312 320
480
542593 634125136 147
290
401
1,078
1,3151,2041,0971,453
1,739
997
2,317436
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
Fertil izers
Electric Energy
Biofuel s
International Sales(**)
Natura l Gas(***)
Exports
Other Dis tribuitors
Sa les 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.
(***) Natural Gas was converted to boe/d.
(*) Accomplished
10
57%31%
6%2% 1%1% 2%
E&P RTC
Gás,Energia & Gás Química Petroquímica
Distribuição Biocombustíveis
Corporativo
2010‐14 Business Plan
• 5% of investments will be made overseas, 87% of which in E&P.
2011‐15 Business PlanUS$224.7 billionUS$224.1 billion
BP 2011‐2015 INVESTMENTS VS. BP 2010‐14
53%
33%
2% 1%1% 2%
8%
(*) US$22.8 billion in Exploration
Natural Gas, Energy and Gas Chemic
DownstreamCorporate
RTM
Petrochemicals
Biofuels
11
224,0
10,8 8,6
1,5
23,732,1
224,70,6
6,4
180,0
185,0
190,0
195,0
200,0
205,0
210,0
215,0
220,0
225,0
230,0
change in investments carried over
from 2010‐14 BP to 2011‐15 BP 192,6
213,2
2010‐14 BP Forex rate impact
Exclusions Change in Budget
Change in Schedule
New Projects
2011‐15 BPChange in Scope
Change in Business Model
(US$ billion)
MAIN CHANGES: BP 2010‐2014 VS. BP 2011‐2015
• 87% of new projects focused in E&P, highlight to the transfer of rights area (US$12.4 billion).
224.0 224.7
213.2
192.6
10.8
23.7
6.4
8.6
32.1
12
419.7
20.6
11.2 5.0
41.6
53.3
389.06.59.0
300.0
320.0
340.0
360.0
380.0
400.0
420.0
440.0
399.1
change in investments carried overfrom 2010‐14 BP to 2011‐15 BP
335.7
2010‐14 BP Forex rate impact
Exclusions Change in Budget
Change in Schedule
New Projects
2011‐15 BPChange in Scope
Change in Business Model
(R$ billion)
MAIN CHANGES: BP 2010‐2014 VS. 2011‐2015
13
Exploration & Production
+ US$8.7 billion
New Projects
• Inclusion of the Transfer of Rights
•New Pre‐Salt Units (Lula)
• Operating Infrastructure
• New Discoveries and R&D
Excluded, Revised and/or Postponed Projects
• Projects discontinued after unsuccessful exploratory phase
• Revision of Production Development Projects
KEY CHANGES IN PORTFOLIOReassignment of E&P investments
Gas & Energy
‐ US$4.6 billion
Supply (includes Petrochemicals)
‐ US$4.3 billion
New Projects
• New HPPs
Excluded, Revised and/or Postponed Projects
• Revision of the construction of gas pipeline and compressor station
• Exclusion of HPP projects from 2010 auctions
New Projects
• Lubricants unit (Comperj)
• Pipelines
• Expansion of the monobuoyssystem (São Francisco do Sul)
• Revap's adequacy
Excluded, Revised and/or Postponed Projects
• Fuel oil storage for thermal power plants
• Jet fuel logistics for Brasília
• Postponement of Premium I Refinery
15
• Foment workforce education
• Maintenance of relations with universities and technical colleges
• Competitive remuneration
• Retention program
• Sustainable health and pension plan
• Foment workforce education
• Maintenance of relations with universities and technical colleges
• Competitive remuneration
• Retention program
• Sustainable health and pension plan
• Managerial development
• Training of new managers/succession
• Rotation of managers and specialists
• On‐site training
• Managerial development
• Training of new managers/succession
• Rotation of managers and specialists
• On‐site training
• Internal and external mobility
• Allocation of new employees
• Career plan
• Internal and external mobility
• Allocation of new employees
• Career plan
HR Policies HR Policies Service provider managementService provider managementCompetency managementCompetency management
• Dissemination of knowledge
• Petrobras Mentor
• Lessons learned
• Dissemination of knowledge
• Petrobras Mentor
• Lessons learned
Human Resources PlanningHuman Resources Planning
Attraction and retention
Attraction and retention
Training and development
Training and development
Career and movement
Career and movement
Knowledge management
Knowledge management
Culture and values Culture and values Commitment and
satisfactionCommitment and
satisfactionHR communicationsHR communications
Environmental ManagementEnvironmental Management
Union relationsUnion relations
HUMAN RESOURCES“To become an international benchmark for people management in the
energy sector, its employees being its greatest asset.”
16
HUMAN RESOURCES
In Jan/11
61.070 63.673 65.971 68.968 74.422
24.34725.528 26.722
27.98528.608
2011 2012 2013 2014 2015
Projeção de Efetivo do Sistema Petrobras
Controladora Outras Empresas do Sistema Petrobras
85.41789.201
92.69396.953
103.030
0
5.000
10.000
15.000
20.000
25.000
30.000
35.000
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
0
500
1000
1500
2000
2500
3000
Personnel Production
55%
E&PPe
rson
nel Production
(thous. bbl/d)
Estima
ted
• PN 2011‐2015 requires extra human resources
•51% of the personnel were admitted less than 10 years ago, while 46% work for Petrobras for over 20 years
• Upstream segment will be the main sponsor of the personnel increase, which follows production growth.
Human Resources Projection
17
COMMITMENT TO ENERGY EFFICIENCY AND REDUCING GHG EMISSIONS
Objective
Voluntary Commitments(2009‐2015)
Investments(2010‐2015)
Maximize energy efficiency and reduce the intensity of greenhouse gas (GHG) emissions
• Reduce the energy intensity of RTM and Gas & Power operations by 10% and 5%, respectively;
• Reduce the intensity of natural gas flaring in E&P operations by 65%;
• Reduce the intensity of GHG emissions in E&P, Refining and Thermal Power operations by 15%, 8% and 5%, respectively.
US$ 1.2 billion will be invested in:
• RTM energy efficiency (US$ 270 million)
• Reducing natural gas flaring in E&P operations (US$ 322 million)
• Conversion of thermal power plants into combined cycle plants (US$ 373 million)
• R&D (US$ 200 million)
18
TECHNOLOGICAL CHELLENGES
Other renewableenergy sourcesPetrochemicals Gas chemic
Fuels, lubricantsand special
productsinnovation Biofuels
CO2 and other gases management
Watermanagement Energetic
Efficiency
Adding value anddiversifying products
Expanding the limitsExpanding the limits
Sustainability
MaximazingRecovery Factor
Developingproduction,
operations and pre-salt logistics
Operationaloptimazation
Solutions for natural gas
logistic in harshenvironments
New ExploratoryFrontiers
Middle destillatesmaximization
Sediments andfluids
characterization ofthe pre-salt andother complex
reservoirs
Development ofnew generationsea and subsea
Productionsystems
19
Other operatorsOther operators
International Research InstitutionsInternational Research Institutions
SuppliersSuppliers
Universities and Brazilian Research Institutions
Universities and Universities and Brazilian Research Brazilian Research InstitutionsInstitutions
PETROBRAS TECNOLOGICAL MANAGEMENT
• 4 Petrobras suppliers’ R&D centers in construction;• To meet local content requirements several companies intend to develop technological centers in Brazil.
Expenses (investments and costs): US$ 1.3 bi / year
20
50 50 thematicthematic network network withwith 80 80 institutionsinstitutions
ANPANP
Scientific Scientific CommitteeCommitteeInstitutionInstitution
partnerpartner 11Institution Institution partner 5partner 5
InstitutionInstitutionpartnerpartner 22 InstitutionInstitution
partnerpartner 33
InstitutionInstitutionpartnerpartner 44
MCTMCTFINEPFINEPCNPqCNPq
-- Physical and Human infrastructurePhysical and Human infrastructure-- RH trainingRH training-- R & D ProjectsR & D Projects-- Technological ServicesTechnological Services
UNIVERSITIESUNIVERSITIES
INCUBATORINCUBATOR
Research CentersResearch Centers
SUPPLIERSSUPPLIERS
CENPESCENPES(manager)(manager)
STRATEGIC PARTNERS
22Based on 2011‐2012 forecasts: Banks (Source: Bloomberg)
Based on 2013‐2015 forecasts: PIRA, DOE, CERA, WoodMackenzie, IEA
Petrobras’sOutlook
95
80
US$/bbl
OIL PRICE 2010‐2015
23
• Oil price
• Foreign Exchange Rate
• Growth of the Brazilian Market
• Average Realization Price (ARP) – Brazil»International Parity
»International margins per product
• Oil and products exports and imports
• Investment Program
• Disinvestment and business restructuring
• Raising of third‐party funds
Key variables for Cash Generation and Investment Level
KEY VARIABLES THAT IMPACT THE CASH FLOW AND FINANCEABILITY
Propositions
Not carry out new Capitalization
Keep the investment grade
24
125,0148,9
224,7 224,7
91,467,0
31,4 30,926,1 26,1
13,6 13,6
Scenario A Scenario B
US$ 256.1 US$ 255.6US$ 256.1 US$ 255.6 Key assumptions
Scenario A (Basis) Scenario B
Exchange rate (R$/US$)
1.73 1,73
Brent (US$/bbl)
2011 – 110 2011 – 110
2012 – 80 2012 – 95
2013 – 80 2013 – 95
2014 – 80 2014 – 95
2015 – 80 2015 – 95
Leveraging(Average) 29% 26%
Net Debt/EBITDA (Average)
1.9 1.5
ARP (R$/bbl) 158 177Debt AmortizationInvestments
Disinvestment and RestructuringCashThird‐Party Resources (Debt)Operating Cash Flow (After Dividends)
Sources Use Sources Use
CASH GENERATION AND INVESTMENTSDisinvestment and traditional funding sources that suit the Plan
26
• Annual investments of more than US$ 4 billion in exploration;
• Investments of US$ 12.4 billion in the assignment agreement areas in 2011‐15
• In the BP 2010‐2014, the forcasted investment for the Pre‐Salt was of US$33 billion
Pre‐Salt
US$ 53.4 billion
Post‐Salt
US$ 64.3 billion
17%
65%
Production Development
18%
Exploration
Infrastructure68%
Other areasAssignment Agreement
26%Pre‐salt
6%
Exploration
Production Development
Pre‐salt37%
Assignment Agreement
Other areas48%
15%
E&P investments in Brazil: US$117.7 bn
TOTAL E&P INVESTMENTS IN BRAZIL– 2011‐15 BUSINESS PLAN
Note: Pre‐salt includes Basins in Santos, Campos and Espírito Santo
27
1.971 2.004 2.100
3.070
0
500
1000
1500
2000
2500
3000
2009 2010 2011 2012 2013 2014 2015
’000 bpd
Marlim LesteFPSO Cidade de
Niterói100,000 bpd26‐Feb‐09
Marlim SulModule 2SS P‐51
180,000 bpd24‐Jan‐09
Lula PilotoFPSO Cidade de Angra dos Reis100,000 bpd
Cachalote andBaleia Franca FPSO Capixaba100,000 bpd
Marlim SulSS P‐56Module 3
100,000 bpd
JubarteFPSO P‐57180,000 bpd
Baleia AzulFPSO Cid. de Anchieta
100,000 bpd
RoncadorFPSO P‐62Module 4
180,000 bpd
RoncadorSS P‐55Module 3
180,000 bpd
Papa‐Terra TLWP P‐61 &FPSO P‐63150,000 bpd
Guará (North) FPSO 150,000
bpd
Pre‐Salt Projects
LulaTLDFPSO BW Cidadede S. Vicente30,000 bpd01‐May‐09
FPSO Frade100,000 bpd20‐Jun‐09
Parque dasConchas
FPSO E. Santo100,000 bpd29‐Sept‐09
Parque das Baleias
FPSO P‐58180,000 bpd
FPSO Cid. de Itajaí
80,000 bpdTiro PilotoSS‐11
30,000 bpd
MexilhãoJaquetaNG
Guará TLDFPSO Dynamic
Producer30,000 bpd
ESP/MARIMBÁFPSO
40,000 bpd
UruguáFPSO Cidade de
Santos35,000 bpd
NG Projects
ARUANÃFPSO
100,000 bpd
Guará Piloto 2FPSO Cid. São
Paulo120,000 bpd
Lula NEFPSO Cid. de
Paraty120,000 bpd
MarombaFPSO
100,000 bpd
SIRI2 Jaquetas e
FPSO100,000 bpd
CernambiFPSO 150,000
bpd
Lula 3 Central FPSO
150,000 bpd
Franco 1 FPSO 150,000 bpd
Lula 4 Alto FPSO
150,000 bpd
BALEIA AZULPost‐SaltFPSO
60,000 bpd
Juruá NG
Post‐Salt Projects
TambaúFPSO Cidadede Santos
NG
Assignment Agreement Projects
LARGE PROJECTS SUSTAIN THE INCREASE IN PRODUCTION
28*No volumes have been announced regarding the Marlim Leste and Albacora Leste discoveries.
• Additional recoverable volume from discoveries:
• Post‐salt: Marimbá, 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
VARREDURA PROJECT: TECHNOLOGICAL DEVELOPMENT AND EXPLORATORY OPTIMIZATION
Descobertas do Pré-sal na Bacia de Campos2009/10 (VARREDURA)
Descobertas do Pré-sal na Bacia de Campos2009/10 (VARREDURA)
67 exploratory wells will be drilled between 2011 and 2015
Operation Sweep
New technologies generate E&P efficiency gains and lead to production growth between 2011 and 2015
Sea Water Capture and Injection
Underwater Oil/Water SeparationVASPS
Underwater Electric Pump in Skid
Multi‐stage Fractured Wells TLWP
Discoveries in Campos Pre-salt basin 2009/10 (Varredura)
29
Development Stage
Duration: 4 yearsExtendable for 2 more years
Variable, according to Development Plan
Total Duration: 40 years, extendable for 5 more years according to specific criteria
DEVELOPMENT OF THE TRANSFER OF RIGHTS UNDER IMPLEMENTATION
Commerciality Statement
Exploration Stage Production Stage
Area 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020
Franco
lara surroundings
Florim
NE of Tupi
South of Guará
South of Tupi
Resources already available for:
• 8 Exploratory wells• 2 contingent Exploratory wells • 1 EWT• 3 contingent EWTs• 3D Seismic
First 4
production
units
undergoing
contracting
(*)
New technologies and resource allocation
determination
* Conversion at the Inhaúma shipyard
31
US$70.6 billion
• Expansion of the downstream segment: Refinery in the NE, Premium I and II, and Comperj;
• Serving the local market: Modernization, conversion, and hydrodesulfurization;
• Operating improvement: maintenance and optimization of the industry, SMES, and R&D;
• Fleet Increase
• Allocation of the national oil: oil supply for refineries and infrastructure for oil exports.
1.1%4.5%
26.4%
0.8%15.2%
Allocation of the national oil
International
Fleet Expansion
Serving the local market
Expansion of the downstream segment
Operating improvement
1.0%
23.9%
13.9%
4.9%
Investments in Petrochemicals amount to US$3.8 billion
NEW REFINERIES, FUEL QUALITY AND MODERNIZATION SUM UPTO 74% OF RTM INVESTMENTS
32
• Investments in refining capacity expansion to support the Brazilian market growth
PRODUCTION, DOWNSTREAM AND DEMAND IN BRAZIL
1,81
1
2,20
5 3,21
7
1,97
1
2,00
4
2,10
0 3,07
0
4,91
0
1,79
2
1,79
8
1,93
3
2,14
7
2,20
80
1,000
2,000
3,000
4,000
5,000
2009 2010 2011 2015 2020
OIL and LNG Production ‐ Brazil Processed Feedstock ‐ Brazil Oil Product Market Scenario A
Thous bpd
Refinaria Abreu e Lima
(RNE)230 mil bpd
(2012)
COMPERJ(1º phase)165 mil bpd
(2013)
PREMIUM I(1ª phase)300 mil bpd
(2016)
PREMIUM I(2ª phase)300 mil bpd
(2019)
PREMIUM II300 mil bpd
(2017)
COMPERJ(2º phase)165 mil bpd
(2018)
2,536
3,0952,643
3,327
33
Capacity: 230,000 bpd
Stage: Implementation
Startup: 2012
REPRE I
Comperj
Nordeste Refinery
Capacity: 330,000 bpd
Stage: Implementation
Startups: 2013 and 2018
Capacity: 300,000 bpd
Stage: Preliminary License issued
Startup: 2017
REPRE II
RNE
Comperj
Capacity: 600,000 bpd
Stage: Earthworks
Startup: 2016 and 2019
Premium I Refinery Premium II Refinery
60’s50’s 70’s 80’s 90’s 00’s
RLAM
RECA
PRP
BC
REMAN
REDUC
REGAP
REFA
P
REPLAN
REPA
R
REVA
P
RNEST
COMPERJ
10’s
32 years
Launch of Petrobras’ Refineries
• Learning curve from the two new refineries (RNEST and Comperj) to reduce the CAPEX at the Premium refineries
INVESTMENTS IN DOWNSTREAM EXPANSION – 2011‐15 BP
PREM
IUM I
PREM
IUM II
34
2011 2012 2013 2014 2015
Regular Gasoline
Transition Regular Gasoline 0.005% S
RECAP Diesel and Gasoline
REFAP Gasoline
REGAP Gasoline
RLAM Gasoline
RPBC Gasoline
REPAR Gasoline
REPLAN Gasoline
REVAP Gasoline
2011 2012 2013 2014 2015
Diesel S-1800
Diesel S-500
Diesel S-50
Diesel S-10
RECAP Diesel and Gasoline
RLAM Diesel
REFAP Diesel
REPLAN Diesel
REGAP Diesel
RPBC Diesel
REGAP Revamp HDT
GASOLINE QUALITY DIESEL QUALITY
REDUC Gasoline
REDUC Diesel
INVESTMENTS IN OIL PRODUCT QUALITY AND CONVERSION PROGRAMS TOTALAPPROXIMATELY US$ 16 BILLION* IN 2011‐15 BUSINESS PLAN
*Includes investments in coking units
REPARDiesel
• Investments in oil product quality meet environmental and emission reduction regulations;
• Higher quality oil products lead to better margins.
36
6%
21%
45%
26%
2%
5,9
3,4
0,30,8
2,8
INVESTMENTS IN GAS, ENERGY, AND GAS‐CHEMICALS 2011‐2015
LNG
Network
Electric Energy
Gas‐chemicals plants (Nitrogenized)
2011‐15 InvestmentsUS$13.2 billion
International
• Cycle of investments in the expansion of the transportation network to be completed in 2011;
• Consolidated investment in thermal power generation;
• Operating in the LNG chain, and serving the thermal power market;
• Increased portion of investments allocated to the conversion of natural gas into urea, ammonia, methanol, and other fertilizers, and gas‐chemicals.
37
Adequação da Malha de Gasodutos UTEs Compromissos Novas UTEs a Gás NaturalEnergia Renovável: Eólica e Biomassa Regaseificação de GNL Liquefação de Gás NaturalTransformação Química do GN
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
UFN III (Sept/14)
UFN V (Dec/14)
Regás Bahia
(Sept/13)
New NG HPPs
Urucu‐Manaus
Gasbel II
Gasduc III
Gastau
Gasene
Gaspal II
Gasan II
Pilar‐Ipojuca
Atalaia‐Itaporanga
Cacimbas‐Vitória
Catu‐Pilar
Japeri‐Reduc
Gascav
Gascar
LNG Pecém
LNG BGUA
Conversion of Biofuel TPPTermoaçu
1st Investment CycleCOMPLETED
2nd Investment Cycle2nd Investment Cycle
20112011‐‐2015 BP2015 BP
2ND INVESTMENT CYCLE: MONETIZATION OF THE PRE‐SALT RESERVES
Cubatão
Ammonium Sulfate (May/13)
ARLA 32 (October/11)
Gas FSO
(Dec/15)
Ecomps + Delivery Spots + Network Maintenance
Acquisition TPPs
UPGN Cabiúnas –Route 2 Pre‐Salt
(Aug/14)
Adaptation of the Gas Pipelines Network (US$3.3 billion)New TPPs run on Natural Gas (US$1.7 billion)
LNG regasification (US$0.8 billion)
Chemical Transformation of NG (US$5.5 billion)
TPP Commitments (US$0.9 billion)Renewable Energy: Wind Power and Biomass (US$0.02 billion)
Natural Gas Liquefaction (US$1.8 billion)
% of T
otal In
vestmen
t
UFN IV (Dec/17)
38
813813
291
2,936
2,271
1,109
13
3
6
0
1.000
2.000
3.000
4.000
2011 2015 2020
Thou
s.to
n /y
ear
-
5
10
15
20
25
30
Ammonia Urea Natural Gas Consumption
Generation Intalled CapacityFertilizer Production
420420
581
6.6946.0988.894
3430
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
Million
cm/d
7,114
9,475
6,518
Million
cm/day
NEW ASSETS USING HIGHER NATURAL GAS PRODUCTION
UFN III (Sep/2014)
UFN IV (Jun/2017)
UFN V (Sep/2015)
• Brazil currently imports 53% of the total ammonia consumption in the country. Will be self‐sufficient in 2015;
• We currently import 53% of the total urea consumed. This amount will reduce to 28% in 2015, 16% in 2017 and 22% in 2020.
39
Total
Demand
Demand from Thermal Power Plants: Petrobras + Third parties
NATURAL GAS SUPPLY & DEMAND BALANCE (MILLION M3/D)
Firm
Flexible30
24
30
24
30
24
202020152011
Total
Supply173149106 20015196
Downstream
UPGN
Fertilizers61
32
1639
2517
Petrobras’ Demand: Downstream + Fertilizers
Non‐thermal power
Demand from NG Distributors
202020152011
2011 2015 2020
2011 2015 2020
2011 2015 2020
Guanabara BayPecém
Bahia41
20
1441
20
1421
14
Bolivian Supply
National NG Supply to the Market
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/m³
4969
936
9
9 Northern Region
Other Regions
55
78
102
SUPPLY
41
INVESTMENTS IN DISTRIBUTION
Share in the automotive and global markets
2011‐2015 BPUS$3.1 billion
21%
18%
13%
42%
Mercado Automotivo
Mercado Consumidor
Operações e Logística
Liquigás
Internacional 6%
33.731.330.930.6
38.6 38.8 38.5 40.6
0
10
20
30
40
50
2009 2010 2011 2015
Automotive Market (%) Global Market (%)
Automotive Market
Consumer Market
Operations & Logistics
International
43
INVESTMENTS IN BIOFUELS
2011‐2015 INVESTMENTS US$4.1 billion
273%
1.5
Pbio Partners
5.6
16%
735
855
Pbio Partners
Market Share Pbio+Partners:• 2011: 28%• 2015: 26%
Biodiesel supply (’000 m³)
592 712
143143
2011 2015
Ethanol supply (million m³)
0.9
3.10.6
2.5
2011 2015
Market‐share Pbio+Partners:• 2011: 5.3%• 2015: 12%
47%
7%
32%
14% Etanol
Logística para Etanol
Biodiesel
R&D
1,9
1,3
0,60,3
45
INVESTMENTS: INTERNATIONAL AREA
Key Projects:
• Cascade / Chinook
• Saint‐Malo
• Tiber
Key Projects:
• BoliviaSan Alberto / San Antonio Serving the Brazilian market
• PeruIntegrated Gas Project – Lots 57 and 58 Oil Production – Lot X
Key Projects: • NigériaAkpoAgbamiEgina
• AngolaBlock 26
US$11 billion
Activities in 27 countries in the E&P, RTCP, Distribution, and G&E segments
Africa’s West Coast
Gulf of Mexico
Latin America
Corporate
Distribution
G&E
E&P
RTCP
87%
1%
3% 2%7%