1. Petrobras Domestic E&P
Results and Perspectives
Hugo Repsold Junior
General Manager for Domestic E&P Strategy and Portfolio
October, 2006

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.
2

3. Corporate Targets
Overview
3

4. Domestic E&P Strategy
• Increase production and reserves
Strengthen expertise in deep and ultra-deep waters;
Perform on-shore and in shallow water fields focusing on profitable
opportunities;
Implement practices and new technologies in areas with high
exploitation degree in order to optimize recovery factor;
Develop exploratory efforts in new frontiers in order to assure a
sustainable reserve / production ratio;
Guarantee a sustainable self-sufficiency in the long term;
Optimize development of proven reserves prioritizing on increasing
production of light oil and a minimum R/P ratio of 15 years;
Maximize and accelerate gas production and supply from E&P.
• Perform with operational excellence and social and
environmental responsibility
4

5. Domestic E&P Operations
Reserves (at December 31, 2005)
• Proven reserves of 13.23 billion boe
(SPE)
or 10.58 billion boe (SEC)
• Reserve life of 19.7 years (SPE) and
15.7 (SEC)
• Internal Reserve Replacement of
131.1% (SPE) and 101.3% (SEC)
Production (2005)
• 1,958 thousand boed (1,684 thousand
bpd oil)
• 5-year CAGR of 5.6% (5.8% oil)
F&D Cost
• US$ 3.45/boe (2003 – 2005) – SPE
Lifting Cost
• US$ 5.73/boe (2005)
Petrobras & Partners Exploratory Area (Nov/2005)
Other Companies
• 157.7 thousand km2 (Petrobras +
Partners)
• 153.4 thousand km2 (other
Companies)
Total: 311.1 thousand km2.
5

6. Oil and Gas Proven Reserves and Production
Oil and Gas Proven Reserves and Production
Publicly Traded Peer Group
Publicly Traded Peer Group
Proven Reserves SEC Criteria Production
(billion boe) (million boed)
ExxonMobil 22.4 ExxonMobil 4.1
Lukoil 20.3 BP 4.0
Petrochina 20.0 ShellGroup(RD) 3.5
BP 17.6 Petrochina 2.9
Chevron 12.1 Total 2.4
ShellGroup (RD) 12.0 Chevron 2.4
Petrobras 11.8 Petrobras 2.2
Total 10.7 ConocoPhillips 2.0
ConocoPhillips 9.4 Lukoil 1.9
ENI 6.7 ENI 1.7
Repsol-YPF 3.2 Repsol-YPF 1.1
0 5 10 15 20 25 0 1 2 3 4 5
Reserve Replacement Index (%) Petrochina 149%
ExxonMobil 121%
ConocoPhillips 100%
BP 95%
Petrobras 94%
Lukoil 91%
Total 87% Source: Evaluate Energy
Shell 77%
2005
ENI 23%
Chevron 13%
-101% % Repsol-YPF
-150 -100 -50 0 50 100 150 200
6

7. Proven Reserve Profile
7

8. Total Production – Oil & NGL and Natural Gas
Thousand boed 7.5% p.y.
4,556
278
7.8% p.y.
3,493 742
185
383 724
2,403
2,036 2,020 2,217
101
96 551
85 94 133
163 289
161 168
274
250 265
2. 812
2. 374
1, 880
1, 540 1, 684
1, 493
2003 2004 2005 T a r get 2 006 T a rg e t 2 0 1 1 2015
For ecast
Oi l and N GL - B r az i l N at ur al Gas - B r az i l
Oi l and N GL - I nt er naci ona l N at ur al Gas - I nt e r naci onal
8

9. Brazilian production curve
2.600 2,374
2,368
2,195 690
1,979 2,061
2.100 1,880 Net Increase
1,684
1.600
Thous. bpd
1.100
600 +
100
(154) (154)
(326)
(172) (508)
(400) (181) (697) 1,114
(897)
(189)
(201) Accumulated
(900) Natural Decline
(217)
(1.400)
2005 2006 2007 2008 2009 2010 2011
1,804
Total Production Accumulated Decline Annual Decline Gross Increase
9

10. Main Domestic Oil Production Projects
7 out of the 15 projects refer to after-2002 discoveries
after-
2,600
Albacora Leste
Albacora Leste
P-50
Thousand pbd
P-50
180,000 bpd
180,000 bpd ESS-130
ESS-130
April/2006
April/2006
Roncador
Roncador
P-52
P-52
Golfinho Mod III ****
Golfinho Mod III **** 2,374
2,400 (FPSO)
(FPSO)
180,000 bpd
180,000 bpd
Jubarte
Jubarte 100,000 bpd
100,000 bpd
2007
2007 Parque das
Fase 1
Fase 1 2008 Parque das
P-34
P-34
2008 2,368 Conchas***
Conchas***
60,000 bpd Rio de Janeiro
Rio de Janeiro
60,000 bpd 100,000 bpd
100,000 bpd
2,200 Oct/2006 Espadarte Mod II
Espadarte Mod II
Oct/2006
FPSO Capixaba
100,000 bpd
100,000 bpd
2007
2,195 2011
2011
FPSO Capixaba 2007
Golfinho Mod. 1 Frade
Frade Roncador
Roncador
Golfinho Mod. 1
100,000 bpd 100,000 bpd
100,000 bpd P-55**
P-55**
2,000
100,000 bpd
May 2006
2,061 2009
2009 180,000 bpd
180,000 bpd
May 2006
2011
1,979 Marlim Sul
Marlim Sul
Jubarte
2011
Module 2
Module 2 Jubarte
Roncador
Roncador P-51 Phase 2
Phase 2
P-51
P-54
P-54 180,000 bpd P-57
P-57
180,000 bpd
1,800 180,000 bpd 180,000 bpd
1,880 180,000 bpd
2007
2007
2008
2008 180,000 bpd
2010
2010
Piranema
Piranema
Cidade de Vitória
Cidade de Vitória Marlim Leste
Marlim Leste
20.000 bpd
20.000 bpd
1,600 1,684 Dec. 2006
Dec. 2006 Golfinho Mod. 2
Golfinho Mod. 2 P-53*
P-53*
100,000 bpd
100,000 bpd 180,000 bpd
180,000 bpd
2007
2007 2009
2009
1,400
2005 2006 2007 2008 2009 2010 2011
10

11. Corporate Targets
Capital Expenditures
and Costs
11

12. Investment Plan
Exploration 7.7
Production Development 33.0
2007-2011 2007-2011
Area Difference Difference (%)
(BP 2006-10)* (BP 2007-11)
E&P 25.0 40.7 15.7 63
Downstream 14.3 23.1 8.8 62
G&E 4.6 7.2 2.6 56
International 6.7 12.1 5.4 82
Distribution 0.9 2.2 1.3 131
Corporate 1.0 1.7 0.7 81
Total 52.4 87.1 34.7 66
The forecast indicates an annual investment average of US$ 17.4
billion between 2007 and 2011.
(*) Obs.: US$ 52.4 related to the investments of the previous Plan regarding the 2007-2011
period, i.e. US$ 56.4 - 2006 investments + 2011 investments.
12

13. Competitive Cost Structure
2003–2005 Average 2005 Lifting Costs1
Finding & Development Costs ($/boe)
($/boe)
16 15.14 15.06 10.00 9.39
14
8.00
12 6.80
9.62 5.88
10 5.73 5.54
6.00
5.08
8 7.55
7.04 6.81
6.07
6 4.00
2.76
4
2.00
2
0 0.00
Chevron Royal Total BP Petrobras Exxon Average Exxon Chevron Petrobras³ Royal BP Total Average
Dutch/ Fina Elf Mobil Mobil Dutch/ Fina Elf
Shell² Shell
Notes:
1 Per company financials and J.S. Herold. Excludes corporate G&A
2 For the 2002–2004 period
3 Without government participation
13

14. Domestic Lifting Cost
Lifting Costs and Government Take per Barrel
54,50
25,0
50
20,0
38,29
40
US$/boe
28,74 14.65
15,0 28,13 25,47
24,11 30
10.7
10,0 8.5 8,9
7.0 6.6 7.0 20
6,4
3,7 4,0 5,1
5,0 3,3 10
4,3 5,7 5,6
3,3 3,3 3,0 3,4
0,0 0
2000 2001 2002 2003 2004 2005 2011
Lifting Cost Government Take Brent
Lifting costs expected to stabilize
♦ Production increases
♦ Technological enhancements
♦ Wells, platforms and plants automation
♦ Optimization of logistics, operations and administrative processes
14

15. Petrobras’ Drilling Rigs
2003 2004 2005
Total Total Brazil International Total
Onshore 25 47 22 19 41
Offshore 41 43 42 4 46
Owned Rigs: 31
Total 66 90 64 23 87
Leased: 56
• Petrobras’ leasing contracts are long term, averaging a 5 years length;
• In 2005, 18 offshore drilling rigs were owned by Petrobras;
• In August 2005, Petrobras renovated 24 drilling rigs contracts.
• In July 2006, Petrobras signed contracts worth R$ 10.5 billion for the charter of six drilling
units:
• 4 rigs will operate in water depths of up to 2,000 meters (seven-year term contract,
renewable for further seven years);
• 2 rigs will operate at depths down to 2,400 meters (units chartered for 5 years,
renewable for the same period);
• In September 2006, the Company contracted two ultra-deepwater rigs for its drilling
operations in the Gulf of Mexico. The contracts have 5 and 6 years term.
15

16. Recent Exploration
Efforts and Results
16

17. Exploration Activities - 1998/2005
wells & seismic
611 exploration wells
Espírito Santo 40 wells offshore
31% overall success ratio
Campos 186 wells offshore
Last year (2005) 55%
Santos 65 wells offshore
Other Basins
216 wells onshore 1998/2005
104 wells offshore
~ 450,000 km 2D seismic
~ 92,240 km2 3D seismic
17

18. Number of Concessions in Brazil
Petrobras Concessions
Petrobras Concessions
Other
Other Total
Total
Concessions
Concessions 100%
100% Parnerships Total Companies Brazil
Companies Brazil
W.I Parnerships Total
W.I
Exploration Blocks
Exploration Blocks 59
59 66
66 125
125 218
218 343
343
Exploration EP´s
Exploration EP´s 24
24 6
6 30
30 0
0 30
30
Production
Production 273
273 19
19 292
292 29
29 321
321
Total
Total 356
356 91
91 447
447 247
247 694
694
Petrobras & Partners
Other Companies
18

19. Petrobras’ Current Exploration Portfolio
EXPLORATORY AREA Santos
Santos
157.7 thousand km2 39.4 milkm22
39.4 milkm
Campos
Campos
Other (*) 13.1 mil km22
Pará Maranhão-Barreirinhas 13.1 mil km
4% 3% 25%
Sergipe Alagoas 5%
Potiguar-Ceará 6%
8%
Santos
Bahia Sul 9%
Campos 6%
Solimões
10% 11%
Espírito Santo 11% Espírito
São Francisco Foz do Amazonas Espírito
Santo
Other Basins* Santo
10.1 mil km22
10.1 mil km
40 % of the concession areas in Campos, Espírito Santo e Santos basins.
Other basins: Pelotas (2%), Ceará (0.8%) and Recôncavo (0,2%)
*
19

20. Expansion of Exploration Frontiers
and New Oil Producing Districts
Fields discovered until 1984
Fiels discovered between 1984 and 2001
Fields discovered in 2002/2003 (Light oil)
(Light oil)
Oil and gas discoveries under evaluation
(Heavy oil)
(Heavy oil)
ESS-130
ESS-
ESS-130
(Light oil)
(Light oil)
BC-20
Gas
Gas Gas and light oil
Gas (Heavy oil)
(Heavy oil)
BS-500
20

21. Main Discoveries - 2002/2005
Natural Gas 15.5 TCF
Light Oil 1 billion boer
17 º API Oil 2.1 bilhões boe
Jubarte & Cachalote 1 billion boer
TOTAL 4.1billion boe
+ 15.5 TCF
6.6 billion boer
Sergipe-Alagoas Basin
Light Oil
Espirito Santo Basin
Light Oil & Natural Gas
Campos Basin
Producible Heavy Oil & Light Oil
Santos Basin
Natural Gas & Light Oil
21

22. Discoveries & Reserves
Discoveries (2002/2005): 6,6 billion boe
Proved Reserves: 3,1 billion boer
Campos Basin: 2,0 billion boer (Jubarte, Cachalote, Baleia Franca,
Campos Basin: 2,0 billion boer (Jubarte, Cachalote, Baleia Franca,
Baleia Azul, Baleia Anã, Papa-Terra, Abalone, Ostra, Nautilus,
Baleia Azul, Baleia Anã, Papa-Terra, Abalone, Ostra, Nautilus,
Argonauta and Ring-Fences of Marlim Leste, Espadarte &
Argonauta and Ring-Fences of Marlim Leste, Espadarte &
Albacora;
Albacora;
Santos Basin: 0,8 billion boer (Mexilhão, Uruguá, Tambaú & Lagosta)
Santos 0,8 billion boer (Mexilhão, Uruguá, Tambaú & Lagosta)
Espírito Santo Basin: 0,25 billion boer (Golfinho & Canapu)
Espírito 0,25 billion boer (Golfinho
Sergipe-Alagoas Basin: 0,05 billion boer (Piranema)
Sergipe-Alagoas boer (Piranema)
Probable & Possible Reserves: 1,5 billion boer
Still in Appraisal (2006): 2,0 billion boer
22

23. Domestic E&P
Exploration Portfolio:
Sustaining Growth Beyond 2011
23

24. Production per Basin (July, 2006)
55.6 (000 bpd) Oil 84.9 (000 bpd) Oil
56.7 (000 boe/d) Gas
boe/d) 18.2 (000 boe/d) Gas
boe/d)
53.4 (000 bpd) Oil
27.1 (000 boe/d) Gas
boe/d)
48.7 (000 bpd) Oil
31.4 (000 boe/d) Gas
boe/d)
BR 100% e BR Partners
Other Companies
4,2 (000 bpd) Oil 83.1 (000 bpd) Oil
0.7 (000 boe/d) Gass
boe/d) 20.3 (000 boe/d) Gas
boe/d)
DOMESTIC PRODUCTION Campos Basin
Offshore... 1,726.7 (000 boe/d) 1,449.3 (000 bpd)Oil (81.2%)
Onshore.... 342.9 (000 boe/d) 123.3 (000 boe/d) Gas (43.%)
Total....: 2,069.6 (000 boe/d)
3.0 (000 bpd) Oil
Oil.: 1,785.1 (000 bpd) 6.8 (000 boe/d) Gas
boe/d)
Nat. Gas: 284.5 (000 boe/d)
Total....: 2,069.6 (000 boe/d)
24

25. Exploration Perspectives
Exploration Perspectives
Paleozoic basins
Paleozoic basins Equatorial margin basins
Equatorial margin basins
Light oil/condensate
Light oil/condensate (frontier)
(frontier)
& natural gas
& natural gas High risks & high rewards
High risks & high rewards
natural gas & light oil
natural gas & light oil
Eastern/Norteastern
Eastern/Norteastern
margin basins
margin basins
Light oil & natural gas
Light oil & natural gas
Jequitinhonha basin
Jequitinhonha basin
(new province??)
(new province??)
Proterozoic basin
Proterozoic basin
High risks
High risks
natural gas
natural gas
Espirito Santo, Campos &
Espirito Santo, Campos &
Santos basins
Santos basins
Search for new producible
Search for new producible
heavy oil discoveries
heavy oil discoveries
Search for light oil & natural
Search for light oil & natural
gas discoveries
gas discoveries
25

26. Exploration Portfolio:
Hydrocarbon Potential Distribution
SOLIMÕES
EQUATORIAL MARGIN
1.4%
10.3%
SEAL &
RECÔNCAVO
4.5¨%
BAHIA SOUTH
16.5¨%
SÃO FRANCISCO
0.2 %
ESP.SANTO
11.0¨%
CAMPOS
PELOTAS
28.7¨%
Petrobras
0.1 %
Other Companies
SANTOS
27.3¨%
78%
26

27. Exploratory Wells 2006-2010
MEQ (13)
Solimões (3) Ceará (7)
Potiguar (47)
SEAL&
REC (54)
S.Francisco
(2) Bahia Sul (43)
Esp.Santo (69)
TOTAL BRASIL (# wells) = 368
Investments: US$ 4.1 billion
Investments: US$ 4.1 billion
Campos (62) 65%
Petrobras Santos (66)
Other Companies
Pelotas (2)
27

28. Domestic E&P
Development of Natural
Gas Reserves
28

29. Domestic Natural Gas Market
140 Million m3/day
121.0 121.0
120
34.0 30.0
100
17.7% p.y.
80
38.6
60 71.0
45.4
40 13.5
20 24.8 48.4
20.0
0 7.1
Consumed in 2005 Potential Demand Potential Supply 2011
2011(*)
Thermoelectric PP Industry Other
LNG National Production Bolivian Imports
* Potential consumption for power generation, considering maximal dispatch for every
thermoelectric power plant
29

30. PLANGAS
December/2008
Cacimbas (20 MM m3/d)
Peroá (10 MM m3/d)
Peroá
Lagoa parda
Belo Horizonte
Vitória Pólo Golfinho
ESS-164
ESS-
+16.3 MM m3/d (*)
Ubu Golfinho + Canapu
Pq. Baleias +
BC10
Cabiúnas
Cabiú
Campinas
Garoupa ESS-130
ESS-
Rio de Janeiro
Caraguatatuba
Namorado
Enchova
REDUC Pampo
RPBC
Platforms from
UN-BC and UN-RIO
UN- UN-
Tambaú
Tambaú +6.4 MM m3/d
(*)
Uruguá
Uruguá
Mexilhão TOTAL SOUTHEAST:
Merluza
Merluza - II 40 MM m3/d
(BM-S-3/ BM-S-7,
(BM- BM- Lagosta
SPS-25)
SPS- +1.5 MM m3/d (+ 24.2 MM m3/d)
(*)
(*) Additional to the current supplay
30

31. Natural Gas Supply Curve
Million m3/day 14 out of the 27 projects refer to after 2002 discoveries
Roncador
SPS25 RJS633 Cavalo (P-55)
80 ESS164
2008
2009 2010 Marinho 2011
2010
Urucu
Start gas Sales
Mexilhão 70
70 2007
2009
70.6
Roncador Golfinho 65.2 Parque das
60 (P-54) Mód 2 Canapu Conchas
2007 2007 2008 Tambaú/Uruguá 2011
2010
Peroá-
50 Cangoa
Frade
2009
Jubarte Fase 2
GN Non associated
GN associated
(P-57)
Fase 1 49.4 Marlim Leste
2010
2006 (P-53)
Marlim Sul
40 ESS130 Mód 2
2009
Manati (P-51)
2008
2006 2008
34.1
30 Piranema Peroá-
Cangoa
27.5 2006
Roncador Fase 2
20 (P-52) 2007
Jubarte 2007 Albacora
Albacora (P-34)
Complement
Leste 2006 Espadarte
10 (P-50) Mód. 2
2007
2006 Golfinho Mód 1 2007
2006
0
2006 2007 2008 2009 2010 2011
31

32. Domestic E&P
Partnerships
32

33. Concessions in Partnerships
26 Oil & Gas Companies
Production Fields Exploration Blocks
(284) (134)
268
16 68 66
Petrobras (100%)
Partnerships
33

34. Partnerships with Petrobras
Opportunities for Petrobras
• Reduction of risk exposure
• Business leverage
• Access to scarce resources (e.g. deepwater rigs)
Why associate with Petrobras ?
• Geological & Technological knowledge
• Experience
• Existing infrastructure
34

35. Petrobras’ Partners
Exploration E&P Production Development
(17 companies) (5 companies) (4 companies)
Amerada Hess
TotalFinaElf Repsol-YPF
Encana
Exxon-Mobil
Shell UP Petróleo Brasil
ChevronTexaco Devon
Unopaso TDC do Brasil
Statoil Partex
Coplex Ipiranga
BG
El Paso Petrogal Starfish Frade Japão Petróleo
Kerr-McGee
Petroserv
Maersk Oil
Queiroz Galvão Eni
Wintershall
35

36. Domestic E&P
Development Approach and
Technological History
36

37. Petrobras Development Approach
Subsea Equipment and Floating
Production Units:
• Reservoir Characteristics
• Favorable Sea Environmental
Conditions
• Early Production Unit as a Field-scale
Lab for Definitive Systems
• Extended Well Testing & Phased
Development
• Lower Capital Exposure & Early
Cash Flow
• Anticipation of First Oil & High Level of
Flexibility
• Field-proven & Reliable Technology
• Partnerships with the Main Suppliers
37

38. The Main Petroleum Province in Brazil
Campos Basin Main Data (Dec 2005)
82% of the Domestic Reserves & Production
Discovery 1974 - Garoupa field
Water depths 50 - 3,400 m
Floating Production Units 26 (12 SS, 13 FPSO, 1 FSO)
Fixed platforms 13
Production fields 41 (15% of the Total)
Pipeline Network 3,443 km
38

39. Campos Basin: A Giant Technology Lab
Petrobras’ Records Petrobras’ Offshore Facilities
Installed Planned
Equipment Dec/2005 (2006)
Completion & Production at 1886 m
Subsea Trees 565 40
Subsea Manifolds 58 2
Subsea Flexible
Flowlines (km) 2,902 371
Umbilicals
(km) 1,798 242
Rigid Pipelines
(km) 1,558 304
Floating Production 26
Units
4
Feb/2002: Exploration Well at 2853 m
2853
Monobuoys 3 1
39

40. Petrobras´ Records in Completion/Production
and Exploration Drilling Offshore
OTC
OTC OTC
OTC
1992
1992 2001
2001
Exploration Wells Vs. Maximun
Water-Depths by year
40

41. Installed Subsea Trees x Oil Operator
Petrobras 506
Royal Dutch/Shell 256
Statoil 256
bp 212
ExxonMobil 148
ChevronTexaco 137
Hydro 128
Amerada-Hess (Triton) 117
Total 105
ConocoPhillips 99
Eni 73
Kerr-McGee 72
BHP Billiton 68
Other 534
0 100 200 300 400 500 600
Source: Quest SUBSEA-DATA-BASE
41

42. Petrobras' Technological History
• First technological program - PROCAP (1986-1991): enable
production feasibility up to 1,000 m water depth
• Second version of the program – PROCAP 2000 (1992-1999):
enable production feasibility up to 2,000 m water depth
• Albacora and Marlim fields producing around 750.000 bpd of oil
• Ability to operate competitively in deep and ultra deep waters
• Further technological developments (PROCAP 3000) will provide
conditions to extend the operational scenario to 3,000 m water
depth
42

43. Domestic E&P
Conclusions
43

44. Conclusions
• Investment Plan is supported by a strong cash flow generation;
• Current portfolio allows a strong production growth to meet the
corporate targets;
• The company remains focused in deep and ultra-deep water
environment due to high revenue projects;
• Investment in technology to be able to produce up to 3,000 m of
water depth;
• Develop exploratory efforts in order to ensure a sustainable
reserve / production ratio;
• Perform with operational excellence and social and
environmental responsibility.
44

45. Petrobras at a Glance
Results and Perspectives
End
Thank You for
your Attention
45

46. Domestic E&P
Annex: Current
Field Developments
46

47. Marlim Sul Field Development
Module 1
Module 1
Highlights
Highlights Module 2
Module 2 Module 3
Module 3 Module 4
Module 4
Module 1 Module 1
P-40 // P-38
P-40 P-38 Complem.
Complem.
Production Wells
Production Wells 13
13 6
6 10
10 10
10
Operating Complementar Injection Wells
Injection Wells 8
8 5
5 9
9 9
9
Capacity (bpd)
Capacity (bpd) 155,000
155,000 100,000
100,000 180,000
180,000 100,000
100,000 Under
Under
m
First Oil
First Oil 2001
2001 2004
2004 2008
2008 2013
2013 Feasibility
Feasibility
00
Production P-40 (SS) Study
Study
Production P-40 (SS) FPSO-MLS P-51(SS) ND
10 FPSO-MLS P-51(SS) ND
FPSO System
System
API
API
P-38 (FSO)
P-38 (FSO)
23-27
23-27 25
25 22
22 16
16
Marlim Sul
m
P-40
00
15
P-38
Water depth:
Module 3 850 - 2,400 m
P-51
Gas pipeline
Oil pipeline
Module 2
0 m
2 50
Module 4
47

48. Roncador Field Development
Production wells
Production wells 8
8 18
18 11
11 11
11
Injection wells
Injection wells 3
3 11
11 6
6 7
7
under
under
Capacity (bpd)
Capacity (bpd) 100.000
100.000 180,000
180,000 180,000
180,000 180,000
180,000
feasibility
feasibility
First oil
First oil 2002
2002 2007
2007 2007
2007 2010
2010 study API 18
study API 18
Production system
Production system FPSO Brasil
FPSO Brasil SS P-52
SS P-52 FPSO P-54
FPSO P-54 SS P-55
SS P-55
API
API 27 to 31
27 to 31 27 to 31
27 to 31 18
18 22
22
Water depth:
1,500 – 1,900 m
P-52
1,500 m
MODULE
1A
FPSO Brasil
MODULE
MODULE
P-54
2
MODULE
3
4 P-55
1,900 m
48

49. Barracuda & Caratinga Field Development
Highlights
Highlights Barracuda
Barracuda Caratinga
Caratinga
Production Wells
Production Wells 20
20 12
12
Injection Wells
Injection Wells 14
14 8
8
Water depth: Capacity (bpd)
Capacity (bpd) 150,000
150,000 150,000
150,000
700 -1,200 m First Oil
First Oil 12/21/2004
12/21/2004 02/28/2005
02/28/2005
Production System
Production System P-43 (FPSO)
P-43 (FPSO) P-48 (FPSO)
P-48 (FPSO)
API
API 25
25 23
23
49

50. Albacora Leste Field Development
Highlights
Highlights
Production Wells
Production Wells 17
17
Injection Wells
Injection Wells 14
14
Water depth: Capacity (bpd)
Capacity (bpd) 180,000
180,000
1,100 -1,500 m First Oil 2006
First Oil 2006
Production System
Production System P-50 (( FPSO ))
P-50 FPSO
API
API 18,3
18,3
P-50
50

51. Marlim Leste Field Development
Highlights
Highlights
Production Wells
Production Wells 14
14
Injection Wells
Injection Wells 8
8
Capacity (bpd)
Capacity (bpd) 180,000
180,000
First Oil
First Oil 2009
2009
Production System
Production System P-53 (FPU)
P-53 (FPU)
API
API 21,5
21,5
FPU Water depth: 820 – 1,500 m
51

52. Jubarte Field Development
Highligths
Highligths Pilot
Pilot Phase 1
Phase 1 Phase 2
Phase 2
Production wells
Production wells 1
1 4
4 21
21
Injection wells
Injection wells 7
7
Capacity (bpd)
Capacity (bpd) 20,000
20,000 60,000
60,000 180.000
180.000
First Oil
First Oil 2002
2002 2006
2006 2010
2010
Production System
Production System Seillean
Seillean FPSO P-34
FPSO P-34 FPSO P-57
FPSO P-57
o
o API
API 17
17 17
17 17
17
Water Depth:
1,240–1,350 m
52

53. Development of the Gas Fields Peroá and Cangoá
INTEGRATED PROJECT
CACIMBAS - VITÓRIA (ES)
•Gas pipelines
26 inch- 112 km
16 inch - 15 km
• Capacity 4.0 MMm³/d
• Pressure 100 kgf/cm²g
• Starting in the Cacimbas
GasTreatment Unit (UTGC),
23 km north of Lagoa Parda
• Ending in the Lagoa Parda
– Vitória gas pipeline, near
ther Vale do Rio Doce
Company.
53

54. Development of the Piranema Field (light oil SE)
54