"10th annual latin american conference"
TRANSCRIPT
Santander10th Annual Latin American Conference
Raul Adalberto de CamposInvestor Relations Executive Manager
January 17-20, 2006Acapulco, Mexico
Petrobras 2015
2
The presentation may contain forecasts about future events. Such forecasts merely reflect the expectations of the Company's management. Such terms as "anticipate", "believe", "expect", "forecast", "intend", "plan", "project", "seek", "should", along with similar or analogous expressions, are used to identify such forecasts. These predictions evidently involve risks and uncertainties, whether foreseen or not by the Company. Therefore, the future results of operations may differ from current expectations, and readers must not base their expectations exclusively on the information presented herein. The Company is not obliged to update the presentation/such forecasts in light of new information or future developments.
Cautionary Statement for US investors
The United States Securities and Exchange Commission permits oil and gas companies, in their filings with the SEC, to disclose only proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. We use certain terms in this presentation, such as oil and gas resources, that the SEC’s guidelines strictly prohibit us from including in filings with the SEC.
Petrobras 2015
3
2006 – 45.002007 – 30.00
2008~2010 – 25.00Brent for funding (US$/bbl)
Linked to prices in the international market, without changes in the
relative pricesOil Products Prices
19.00Robustness Brent (US$/bbl)
4.2GDP – World (% pa) – PPP(*)3.7GDP – Latin America (% pa) – PPP
3.0FX rate (R$/US$)4.0GDP – Brazil (% pa)
2006-2010Indexes
Macroeconomic Assumptions
(*) PPP – purchase power parity
Petrobras 2015
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226300 307 337226 235 253
732 775894
95121 132
255
201196
117127
0
500
1,000
1,500
2,000
2,500
2003 2004 BP 2006-10LPG Gasoline Naphta Diesel + QAV Fuel Oil Others
Oil products market in Brazil presenting a high dynamism
Thous. bpd 2010
1,7631,700
2,060
+2,6% p.y.
Assumptions – domestic market
Does not include own refineries consumption
Petrobras 2015
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1.638,61692,17
808,71
1.380,81
162,45190,70
487,38
229,55 339,020
1000
2000
3000
4000
2003 2004 PN 2006/10*
Thermoeletric Industrial Other
Assumptions – domestic market
1,084.3
(30.7 MM3)
1,338.4
(37.9 MM3)
2010
(*) considers the total supplying capacity, including bi-fuel conversion, contingency demand managing and isolated system in the North region. In the previous plan only the forecasted shipping of the thermo-electric demand was contemplated.
Note: does not include Petrobras direct consumption
3,506.80(99.3 MM3)
MMcfd / (Million m3/day)
Petrobras 2015
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Investment Plan
34,1
6,7
11,41,11,0
2,1
4%12%
2%20%
60%
2%
E&P Downstream G&EPetrochemical Distribution Corporate
34.1
6.711.4
1.11.0
2.1
Note: Includes International
2006-10 PeriodUS$ 56.4 billion
11,41,11,0
• US$ 56.4 billion for 2006-2010, representing US$ 11.3 billion average annual investment, maintaining emphasis in E&P and Downstream projects;• US$ 9.9 billion average annual investment in Brazil and US$ 1.4 billion abroad.
Distribution by AreaDistribution by Business Segment
87%
13%
Brazil International
49.3
7.1
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Explanation on investment changes (consolidated)
1.338
5.605
6.446
8.503
34.481
BP 2015 New Cost Increase
Anticipated Others*
SP 2015 ===> 34,481 US$ millionBP 2006-2010 => 56,373 US$ million
* Others including: change in project scope, eliminations, chartering adjustments and other factors.
• Roncador P-55 and Jubarte P-57; • BS 500; • Integrated Refining-Petrochemical Unit; • Acquisition of Merchants Plants.
• NE/SE Network, • Gasene, • Golfinho Mod. 1 and 2; • RJS 409; • Piranema; • Marlim Leste P-53.
• Bid 6 new exploration blocks; • Peroa Phase 2 (ES); • New projects in mature fields aiming to reduce declining rate;• Golfinho FPSO Mod. 3,• Additional offer of natural gas in Esp. Santo; • Bi-fuel conversion.
Petrobras 2015
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58.9
12.2
2004-2010FinancingCash Flow
56.4
14.7
2004-2010Debt Amortization
Investment
(US$ 71.1 billion)(US$ 71.1 billion)
(*) US$ 58.9 billions – Cash flow net of dividends
(**) Net of leasing and chartering amortization from 2006 to 2010 in the amount of US$ 2.3 billion
Sources and Uses
(*)
Investment Plan
(**)
Petrobras 2015
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1.8
7.8
43
8.3
5.8
23
2003
0.4
6.4
38
6.8
2.4
24
2004
1.5
8.6
28
4.4
2.9
15
2006-2010 Average
Oper. Cash Flow before interest and taxes / interest
Free Operating Cash Flow before dividends and debt amortization (US$ billion)
Cash Balance (end of the year) (US$ billion)
Net Debt/ Net Debt + Shareholders’ Equity (Leverage) (%) *
Long Term Funding (US$ billion)**
Return on Capital Employed (ROCE) (%)*
Targets
(*) BRGAAP (**) Includes conventional funding, project finance, leasing and chartering
Financial indicator forecasts show conditions for arranging finance and attractive returns, in spite of the adoption of conservative assumptions for long-term oil prices.
Financial Targets
Petrobras 2015
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25252530
45
50
38
2925
0
10
20
30
40
50
60
2002 2003 2004 2005 2006 2007 2008 2009 2010
(*) past data at nominal base, from 2006 on current value.
Petrobras’ Brent forecast (red)
37,535,0
32,5
30,0
27,5
25,0
22,5
20
25
30
35
40
12 13 14 15 16 17 18
ROCE
Ave
rage
Bre
nt p
rice
2006
–20
10
Brent curve variations – ROCE margin
correlation: Brent x Roce
(*)
Strategic plan based on conservative variables:
- Costs took in consideration BRENT at US$ 50- Future revenues based on BRENT price projected for the period
Ave
rage
Bre
nt p
rice
BRENT average @ US$
25 30 35 40
Sensitivity in 2010
• US$ 5.00 price change will result in a US$ 2.5 billion change inthe operational cash generation in 2010.
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Total production - Oil, NGL, Natural Gas
Corporate Targets
1,50 0 1,54 0 1,4 9 3 1,6 8 4
16 816 3
2 ,3 0 01,3 3 6
2 742 6 5
56 0
2 502 522 3 2
3 3 9
16 13 54 3
8 52 3
2 0 6
9 69 4
2 5
2 0 0 1 2 0 0 2 2 0 0 3 2 0 0 4 2 0 0 5 2 0 10 T arget
Oil and N GL - B raz i l N at ural Gas - B raz i lOil and N GL - Int ernacio nal N at ural Gas - Int ernacional
2,036
3,405
1,8101,636
9.0% p.y.
• As of 2006, light oil production from new projects will surpass 150 thous. bpd;• Crude oil exports of 522 thous. bpd.
2,0202,217
Thou
sand
boe
d
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2,200
2,100
2,000
1,910
1,684
2,300
1,400
1,600
1,800
2,000
2,200
2,400
2005A 2006 2007 2008 2009 2010
Corporate Targets
Albacora LesteP-50
180,000 bpdApril 2006
Albacora LesteP-50
180,000 bpdApril 2006
BarracudaP-43
150,000 bpdCaratinga
P-48150,000 bpd
2005
BarracudaP-43
150,000 bpdCaratinga
P-48150,000 bpd
2005
JubartePhase 1
P-3460,000 bpd
2H 06
JubartePhase 1
P-3460,000 bpd
2H 06
Marlim LesteP-53
180,000 bpd2008
Marlim LesteP-53
180,000 bpd2008
GolfinhoMod. 1
100,000 bpd2006
GolfinhoMod. 1
100,000 bpd2006
RJS-409Espadarte
100,000 bpd2007
RJS-409Espadarte
100,000 bpd2007
Frade100,000 bpd
2009
Frade100,000 bpd
2009
RoncadorP-52
180,000 bpd2007
RoncadorP-52
180,000 bpd2007
RoncadorP-54
180,000 bpd2007
RoncadorP-54
180,000 bpd2007
Marlim SulModule 2
P-51180,000 bpd
2008
Marlim SulModule 2
P-51180,000 bpd
2008
Piranema20,000 bpd
2006
Piranema20,000 bpd
2006
GolfinhoMod. 2
100,000 bpd2007
GolfinhoMod. 2
100,000 bpd2007
AlbacoraExtension
100,000 bpd2010
AlbacoraExtension
100,000 bpd2010
RoncadorP-552010
RoncadorP-552010
GolfinhoFPSO Mod. 3100,000 bpd
2010
GolfinhoFPSO Mod. 3100,000 bpd
2010
JubartePhase 2
P-572010
JubartePhase 2
P-572010
Thou
sand
boe
d
Domestic production will grow at an average of 6.4% per year
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Corporate TargetsDevelopment of Natural Gas and Oil Production in the Santos Basin
Pólo BS-500 (RJ)Pólo BSPólo BS--500 (RJ)500 (RJ)
Pólo Mexilhão (SP)Pólo Mexilhão (SP)Pólo Mexilhão (SP)
Pólo Centro (SP, RJ)Pólo Centro (SP, RJ)Pólo Centro (SP, RJ)
Pólo Sul (SP, PR, SC)Pólo Sul (SP, PR, SC)Pólo Sul (SP, PR, SC)
Pólo Merluza (SP)Pólo Pólo MerluzaMerluza (SP)(SP)
(Área de 352.000 km2 de 0 a 3000m)
Pólo BS-500 (RJ)BS- 500 Pole (RJ)
Pólo Mexilhão (SP)Mexilhão Pole (SP)
Pólo Centro (SP, RJ)Center Pole (SP, RJ)
Pólo Sul (SP, PR, SC)South Pole (SP, PR, SC)
Pólo Merluza (SP)Merluza Pole (SP)(SP)
(352.000 km Area2 from 0 to 3000m)
• US$ 18 billion over the next 10 years to be invested by Petrobras and partners ;• Increase of 12 million m3/day in the supply of gas as from the 2H 08;• By the end of 2010, this volume should have grown to 30 million m3/day;• Reducing the country’s dependence on imported gas.
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Corporate TargetsInternal Replacement Proven Reserve Rate (SPE)
13.02 12.350.88
2004 2005
Finds in Exploratory Blocks:• Papa-Terra, in the Campos Basin; • Uruguá e Tambaú, in the Santos Basin; • Canapu, in the Espírito Santos Basin – Offshore; • Inhambu, in the Espírito Santos Basin – Onshore; • Acauã, in the Rio Grande do Norte Basin;• Anambé, in the Alagoas Basin – Onshore• Jandaia, in the Recôncavo Basin.
Finds in production field concession (Ring Fence)• Albacora Leste in the Rio de Janeiro E& P Business Unit – UN-RIO• Marlim and Albacora, in the Campos Basin E&P Business Unit – UN-BC.
Re-evaluations of existed fields in 2005•Roncador field in the Rio de Janeiro Exploration and Production Business Unit – UN-RIO, and Badejo (membro Siri), in the Campos Basin Exploration and Production Business Unit – UN-BC.
Production(0.67 billion boe)
13.23
2005 Internal Replacement
0.88
0.67= 131 %
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Oil and NGL Lifting Costs
US$/bbl
Corporate Targets
3.36
4.26
5.95
4.88
5.83
4.48
2003 2004 1Q 05 2Q 05 3Q 05 Current2010 BP
Petrobras 2015
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2,300
1,271
1,712 1,895
1,596
1,869
1,050
1,250
1,450
1,650
1,850
2,050
2,250
2000 2001 2002 2003 2004 Jan-Set 05 2010Oil Production Oil Products Sales Throughput
Low operational flexibility
High operational flexibility
Business Strategies
• Domestic oil production will exceed throughput;• In 2010 oil products sales will be equal to throughput;• Increase of the domestic oil participation in throughput, reaching 91% in 2010.
Thou
sand
boe
d
Petrobras 2015
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Business Strategies - Downstream
1,670 1,659 1,727 1,708 1,6681,804
1,674 1,6041,726
1,7201,542 1,537 1,533 1,619
1,676 1,6911,589
1,66587
84
7779
81 80
8184
86
8987 83 91
73
8077
79 77
600
800
1,000
1,200
1,400
1,600
1,800
3Q03 4Q03 1Q04 2Q04 3Q04 4Q04 1Q05 2Q05 3Q0570
75
80
85
90
95
100
Domestic oil products production Oil products sales volumePrimary processed installed capacity - Brazil (%) Domestic crude as % of total
• The increase in light imported oil caused domestic refining utilization to rise to 91%;• Domestic oil as a percent of throughput remained flat despite the higher utilization, as investments in conversion enabled Petrobras to process more of its heavy crude;• The higher refining utilization factor reduced the need for more expensive imports of oil products.
Domestic refining and sales
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Downstream
Investment Plan
61%
15%
8%
16%
RefiningPipelines & Terminals TransportShip TransportPetrochemical
US$ 12.9 billion in the downstream segment…
...of which US$ 8 billion in refining
41%
14%
12%
25%
8%
Diesel and gasoline quality ExtensionMainteinance and HSE ConversionOther
US$ 3.3
US$ 2.0US$ 1.1
US$ 1.0
US$ 0.6
US$ 8,0
US$ 2,0
US$ 1,9
US$ 1,0
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Refining Costs
US$/bbl
• The increase in refining costs reflects higher costs for operating more complex units and sophistication in the quality of products;
• Costs still in line with the oil industry as a whole.
Corporate Targets
1.141.34
1.822.06
1.93 2.02
2003 2004 1Q 05 2Q 05 3Q05 Current 2010BP
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Investments in improving fuel quality
HDT: Hydro-treatment Unit HDS: Hydrodesulphurization
20096 thous. m3/d1 HDT for diesel
20093 thous. m3/d1 HDT for naphtha cock
US$ 210 MMOperating4 thous. m3/d1 HDT for diesel
REDUC20085 thous. m3/d1 HDS for gasoline
20095 thous. m3/d1 HDT for diesel
20062 thous. m3/d1 HDT for naphtha cock
US$ 125 MMAug/053.5 thous. m3/d1 HDT for diesel
REGAP20084 thous. m3/d1 HDS for gasoline
20103 thous. m3/d1 HDT for diesel
20083 thous. m3/d1 HDT for naphtha cock
20098 thous. m3/d2 HDS for gasolineRLAM
20098.5 thous. m3/d1 HDT for diesel
US$ 134.7 MMMay/055 thous. m3/d1 HDS for diesel
REPAR20095 thous. m3/d1 HDS for gasoline
Investment amountStart-upCapacityProjectPlant
Petrobras 2015
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Investments in improving fuel quality
HDT: Hydro-treatment Unit HDS: Hydrodesulphurization
20102 thous. m3/d1 HDS for gasoline
20104 thous. m3/d1 HDS for dieselRECAP
2009-1 HDT for diesel
20086 thous. m3/d1 HDT for diesel
REVAP 20097 thous. m3/d1 HDS for gasoline
20083 thous. m3/d1 HDT for naphtha cock
USD 182 MMNov/055 thous. m3/d1 HDT for diesel
REPLAN20098 thous. m3/d2 HDS for gasoline
20096 thous. m3/d1 HDT for naphtha cock
20108 thous. m3/d1 HDT for diesel
20085 thous. m3/d1 HDS for gasolineRPBC
20082.2 thous. m3/d1 HDT for diesel
20054 thous. m3/d1 HDT for diesel
REFAP 2008-1 HDS for gasoline
Investment amountStart-upCapacityProjectPlant
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Investments in conversion
20052 thous. m3/d1 coking unitREFAP
2010Under evaluation1 coking unitREPLAN
2010Under evaluation1 coking unitREGAP
20085 thous. m3/d1 coking unitREVAP
20065 thous. m3/d1 coking unitREDUC
20124 thous. m3/d1 coking unitRELAM
20095 thous. m3/d1 coking unitREPAR
20057 thous. m3/d1 URFCC
Start-upCapacityProjectPlant
Petrobras 2015
23(*) Domestic Imports and Private Refineries
International Production339
Brazilian Production2.300
339 522+
1.710
Imports350
522
Brazilian Throughput 1.869
Brazilian Oil ProductsConsumption 2.060
Oil 159
Oil Products (*)191
International Sales861
68
Liquids production flow: in 2010 international sales will reach 861 thous. bpd
Business Strategies
Thous. bpd
Petrobras 2015
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P-Xylene/PTA/PET Complex
PQU Expansion – Mauá / São Paulo
Rio Polímeros – Duque de Caxias / Rio de JaneiroPetrochemical Complex at Bolivia border
US$ 2.0 billion investment for 2006-2010
Polypropylene Unit – São Paulo
Acrylic Complex – Minas Gerais
PTA Unit – PernambucoIntegrated Refinery-petrochemical Unit – Rio de Janeiro
Main Projects
Petrochemical investments: pro-active role searching for synergies with refining
Investment Plan
In the previous 2006-2010 Business Plan, Petrochemical investments totaled US$ 0.6 billion.
Petrobras 2015
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US$ 4.5 billion investment for 2006-2010
Gas Delivery Development Plan - PDEGGas Pipeline Paulínea-Jacutinga
Southeast-Northeast NetworkBolívia-Brasil Gas Pipeline compression (up to 34 MM m3/day)Gasbel Extension
Urucu-Coari-Manaus Gas Pipeline
Northeast Gas Pipeline Network
Southeast-Northeast Gas Pipeline (GASENE)Principal Gas Pipeline Projects
Natural Gas investments: infra-structure investments to increase delivery capacity
Investment Plan
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Renewable energy
UTEs (conclusion and cycle closing of existing plants)
US$ 1.3 billion investment for 2006-2010
Bi-fuel conversion
Acquisitions
Activities
Energy investments: consolidating Petrobras position in power generation.
Investment Plan
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• Investments will go towards the following priority sources of energy:
• Wind power generation;
• Biomass energy;
• Photo voltaic;
• Bio-diesel production.
• Main Targets for 2010:
• Availability of 169 MW;
• Produce 8,200 bpd of bio diesel.
Renewable Energy
Business Strategies
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168 163
33996
206
94
2004 2005 Current 2010 BPOil and LGN Natural Gas
International
262 259
545
US$ 2.1 boeLifting Costs US$ 1.8/boe Refining Costs
154Throughput – Abroad (thous. bbl/day)
2010Corporate Targets
Production (thous. boed)
Corporate Targets
Petrobras 2015
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Final Remarks
• Continuing and significant growth in the output of Brazilian oil, including the post 2010 period, with sustainable self-sufficiency in oil as from 2006;
• CAPEX in the upgrading of the refinery complex for improving the quality of products and value-added of national oil;
• Consolidation of the infrastructure for the development of the natural gas market;
• The Plan allows for the concomitant operation of all the authorized thermo-electric power plants within the 2006-2010 timeline; this involves the supply of domestic gas, importing of Bolivian gas, gas-powered thermal operations on a bi-fuel basis and the emergency handling of natural gas demand;
• Selective expansion in the petrochemicals sector plays a more prominent role in the 2006-2010 Business Plan;
• The fleet renewal program set out in the previous Plan was left unchanged;• Petrobras will consolidate its position in the Brazilian market for renewable
energy for the 2006-2010 period; • To achieve leadership in all segments of the consumer market in the
distribution area, Petrobras’ consolidation in the LPG market merits particular attention with the acquisition of Liquigás;
Petrobras 2015
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• In the Company’s international business, 82% of CAPEX is directed towards countries which are core to Petrobras’ overseas activities and 87% will go to the E&P segment;
• The high oil prices and the growth in activities, principally the production of oil in Brazil and overseas, ensures the generation of sufficient cash to finance 78% of capex for the 2006-2010 period;
• Based on the assumptions adopted, the financial forecasts indicate good conditions for funding and returns as well as for guaranteeing the Company’s solvency and liquidity;
• As a basis for sustaining the implementation of the 2006-2010 Business Plan, Petrobras maintains as the basic pillars on which its corporate performance rests, growth, profitability and social and environmental responsibility;
• In this context, the Plan includes the allocation of the necessary resources for the Company to achieve standards of excellence in the areas of safety, the environment and health.
Final Remarks
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Conference Call / Webcast3rd Quarter 2005
(Brazilian Corporate Law)
Petrobras 2015
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The presentation may contain forecasts about future events. Such forecasts merely reflect the expectations of the Company's management. Such terms as "anticipate", "believe", "expect", "forecast", "intend", "plan", "project", "seek", "should", along with similar or analogous expressions, are used to identify such forecasts. These predictions evidently involve risks and uncertainties, whether foreseen or not by the Company. Therefore, the future results of operations may differ from current expectations, and readers must not base their expectations exclusively on the information presented herein. The Company is not obliged to update the presentation/such forecasts in light of new information or future developments.
Cautionary Statement for US investors
The United States Securities and Exchange Commission permits oil and gas companies, in their filings with the SEC, to disclose only proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. We use certain terms in this presentation, such as oil and gas resources, that the SEC’s guidelines strictly prohibit us from including in filings with the SEC.
Disclaimer
Petrobras 2015
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E&P’ oil prices
47.83
37.4843.04
54.24
61.53
51.59
29.43 32.0228.42
41.59
35.3844.02
35.11
26.16 29.5326.79
36.1432.88
56.39
49.3344.1939.70
27.41 28.79 30.7734.38
38.98
3Q03 4Q03 1Q04 2Q04 3Q04 4Q04 1Q05 2Q05 3Q05
Brent (average) Average sales price OPEC Basket
• The spread between the average sales price for Petrobras crude oil and Brent declined as the demand for low sulfur heavy crude oil increased.
Petrobras 2015
34Source: Purvin & Gertz
Refining Margins limited by the conversion capacity
US Gulf Refining Margins(US$/bbl, 2004 currency)
* Forecast for the year average. Last Update: aug/05
(2)
0
2
4
6
8
10
12
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
*
Maya Coking (Heavy Oil)Isthmus CokingIsthmus Cracking
• Strong demand for medium and light oil products enabled refiners with heavy oil processing capacity to increase margins;•Environmental specifications in the USA and Europe, low inventories, and limited refining and conversion capacity, strengthened refining margins.
Petrobras 2015
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Domestic oil and NGL production
1,725
1,511 1,543
1,730
1,523
3Q04 4Q04 1Q05 2Q05 3Q05
thou
sand
bpd
∆ = 13.3%
• 13.3% increase as compared to 3Q04 due to the start-up of P-43 (Barracuda) and P-48 (Caratinga) platforms in dec/04 and feb/05, respectively;• Compared to 2Q05, production remained at the same level due to scheduled stoppages in some platforms (P-18 and P-20), natural gas compression adjustments in P-48 unit and a drought in the Amazon river, which limited production in Urucu field.
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Net exports of oil and oil products
Imports (thousand bpd) Exports (thousand bpd)
233 233 181 161343 247
228 235
221244
32
206 213203
2001 2002 2003 2004 1Q05 2Q05 3Q05Oil Oil Products
397 326 319450
322 333 393
326216
105109
46 83115
2001 2002 2003 2004 1Q05 2Q05 3Q05Oil Oil Products
723542
424559 508 439 446 409 396
368
564
416235
491
• During 3Q05, diesel imports increased to meet growth in seasonal domestic demand (3.3% increase in the sales volume of oil products as compared to 2Q05);• Imports of light oil increased to adjust production output to meet seasonal shift in internal consumption; • Increase in gasoline exports due to high demand in the USA;• Decrease in oil exports due to logistic difficulties caused by Gulf of Mexico hurricanes.
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Average Realization Price - ARP
• ARP-USA significantly affected by the hurricane season.• ARP Brazil continued to follow medium and long term international price trends;• 9.0% increase in ARP Brazil compared to the 2Q05; 51.6% in the last 12 months;• On Sept. 10, Gasoline and Diesel prices increased 10% and 12% respectively (including impact of CIDE and PIS/COFINS); •The price of Brent continued to trend upward;
20
40
60
80
100
Dec-02 Mar-03 Jun-03 Sep-03 Dec-03 Mar-04 Jun-04 Sep-04 Dec-04 Mar-05 Jun-05 Sep-05
ARP Brazil (US$/bbl) Brent Average Price ARP USA (w/ volumes sold in Brazil)
60.26
73.20
61.54
3Q05Average
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Sales Volume
• 3Q05/ 3Q04: oil product sales’ volume was particularly affected by increased diesel demand (seasonal demand related to agriculture), higher domestic demand for natural gas as well as international sales.• In this same period oil exports decrease due to logistic difficulties caused by the hurricanes in Gulf of Mexico;• When comparing 9M05/ 9M04 the main cause of the increased total sales volumes were the exports and natural gas demand.
Thousand bpd 3Q05 2Q05 % 9M05 9M04 %
Total Oil Products 1,720 1,665 3 1,658 1,619 2Alcohol, Nitrogen and others 26 23 13 26 31 (16)Natural Gas 235 222 6 224 205 9Total Domestic Market 1,981 1,910 4 1,908 1,855 3Exports 509 572 (11) 496 441 12International Sales 413 334 24 388 424 (8)Total International Market 922 906 2 884 865 2Total 2,903 2,816 3 2,792 2,720 3
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Expressive Operational Results in the 3Q05R
$ m
illio
n
(1) Earnings before financial revenues and expenses, equity in results of non-consolidated companies and taxes.
4,930
9,576
11,809
17,939
32,359
5,632
10,630
12,488
20,601
35,711
Net Income
Operating Profit (1)
EBITDA
COGS
Net Revenues
2Q05 3Q05
10.4%
14.8%
5.7%
11.0%
14.2%
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Changes in Net Profit – R$ million (2Q05 versus 3Q05)
1,730 1,725Oil, NGL and Condensate – thousand bpd
Tax benefits
4,930746
70
4,184
3,352 2,662
364
1,096 1,378
5,632
2Q05 Net Income Income COGs OperatingExpenditures
Fin., Non Op. andOther Exp. and
Gains Inv. InSubsidiaries
Minority Interest Taxes 3Q05 Net Income
• 3Q05 net income was 14% higher than last period result; it would be even higher, about 34%, if tax benefits were excluded from 2Q05 results.
4,930
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41
9.698
3.516 1.483
60 11.64949
71
2Q05Operating
Profit
Effect ofprices on theNet Revenue
Effect ofvolumes on
the NetRevenue
Effect of theaverage costson the COGs
Effect of thevolumes on
the COGs
OperatingExpenses
3Q05Operating
Profit
∆ = 20%1.730 1.725
Changes in Operating Profit (3Q05 vs. 2Q05) – R$ millionE&P
Oil, NGL and Condensate – thousand bpd
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4.15 4.094.75
5.954.88
5.83
2Q 04 3Q 04 4Q 04 1Q 05 2Q 05 3Q 05
Lifting Costs without Gov. Take
∆ = +19.5% or US$ 0.95
Main causes
+ US$ 0.71/boe: Third parties services and charges, higher expenses with charter of platforms from third parties and readjustment of charter rate of FPSO-MLS due to high oil price;
+ US$ 0.34/boe: FX rate effect due to the Real appreciation compared to Dollar;
- US$ 0.17/boe: Recovery of expenses related to partnerships, mainly in Albacora Leste and Coral.
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Changes in Operating Profit (3Q05 vs. 2Q05) – R$ millionDownstream
3.104
1.559
4.308
16 725
1.255
1.641
2Q05Operating
profit
Effect ofprices on theNet Revenue
Effect ofvolumes on
the NetRevenue
Effect of theaverage coston the COGS
Effect ofvolumes onthe COGS
Operatingexpenditures
3Q05Operating
profit
Operating Profit Evolution – R$ million
• Quarterly result affected by increases in oil and oil products imports, and the high cost of purchasing oil and oil products.
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1.32 1.321.67 1.82
2.06 1.93
2Q 04 3Q 04 4Q 04 1Q 05 2Q 05 3Q 05
Domestic Refining Cost
Domestic Refining Costs (US$/bbl)
Decrease due to:
• 12% increase in the feedstock processed;
• Lower consumption of catalysts and chemical products in the current quarter due to higher rate of imported light oil;
• Factors partially offset by scheduled stoppages in RPBC and REDUC units.
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Contribution of the Business Segments to the Operating Profit 3Q05 vs. 2Q05 (R$ million)
9.576
1.951 2.379
152 157 95 145
10.6301.427
2Q05Operating
Profit
E&P Downstream Gas &Energy
Distribution International Corporate Eliminations 3Q05Operating
Profit
• 11.0% growth in Operating Profit mainly due to higher international prices for our exports, increases in volumes of oil products sold domestically, and higher ARP during the period;• Eliminations reflects the effect oil price escalation in the downstream purchases, especially since 2Q05, distributed between COGS and Inventory.
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Cash Breakdown(R$ million)
(25.000)
(15.000)
(5.000)
5.000
15.000
25.000
'3/31/2004 6/30/04 9/30/04 12/31/04 3/31/05 6/30/05 9/30/05
(1.200)
(800)
(400)
0
400
800
1.200
Abroad In Brazil with FX correctionIn Brazil CDI CashFinancial Income
Cas
h
Fina
ncia
l Rev
enue
s
FX rate change*
∆+6.8% ∆-8.0% ∆-7.1% ∆0.4% ∆-11.8%
* US Dollar end of period price
∆-5.5%
• Financial income when expressed in Reais is highly influenced by the exchange rate, given the substantial cash balances that are indexed to the dollar as a hedge against dollar denominated debt and costs.
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Petrobras’ Leverage Ratio
Leverage
R$ million Sep-05 Jun-05 Mar-05
Short-term debt 8,991 9,645 11,419
Long-term debt 38,422 40,866 46,092
Total debt 47,413 50,511 57,511
Net debt 26,203 33,316 39,883
32%
26%
19% 19%
37%
43%42%40%
36%
20%17%16% 16% 16%
1Q04 2Q04 3Q04 4Q04 1Q05 2Q05 3Q05
Net debt/Net capitalizationShort-term debt/Total debt
• 21% decrease in net debt as a result of Real appreciation and strong cash generation.
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2005 (1) 2004 (2)
(=) Net Cash from Operating Activities 29,857 17,695 (-) Cash used in Cap. Expend. (15,385) (14,307) (=) Free Cash Flow 14,472 3,388 (-) Cash used in Financing and Dividends (11,473) (10,486) Financing (6,372) (5,023) Dividends (5,101) (5,463) (=) Net Cash Generated in the Period 2,999 (7,098) Cash at the Beginning of Period 18,211 27,577 Cash at the End of Period 21,210 20,479
R$ millionJan-Sep
Consolidated Cash Flow Statement
(1) As of January 1, 2005, the Special Purpose Companies whose activities are directly or indirectly controlled by Petrobras were included in the Consolidated Financial Statements, as per CVM Instruction No. 408/2004.(2) To facilitate comparability, Special Purpose Companies were also included in the financial statements of 2Q-2004 and 1H-2004.
• Outstanding cash generation in the quarter, resulting in higher cash balances, despite the increase in capital expenditure and net debt repayments.
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For further information please contact:
Petróleo Brasileiro S.A – PETROBRASInvestor Relations Department
E-mail: [email protected]. República do Chile, 65 – 22nd floor
20031-912 – Rio de Janeiro, RJ(55-21) 3224-1510 / 3224-9947