Petrobras Domestic E&P Results and Perspectives
Hugo Repsold Junior General Manager for Domestic E&P Strategy and Portfolio
October, 2006 •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 CorporateCorporate TargetsTargets
OverviewOverview
3 DomesticDomestic E&PE&P StrategyStrategy • 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 DomesticDomestic E&PE&P OperationsOperations 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 OilOil andand GasGas ProvenProven RReserveseserves andand ProductionProduction PubliclyPublicly TradedTraded PeerPeer GroupGroup 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 012345
Reserve Replacement Index (%) Petrochina 149% ExxonMobil 121% ConocoPhillips 100% BP 95% Petrobras 94% Lukoil 91% Total 87% Source: Evaluate Energy 2005 Shell 77% ENI 23% Chevron 13% -101%% Repsol-YPF
-150 -100 -50 0 50 100 150 200 6 Proven Reserve Profile
7 Total Production – Oil & NGL and Natural Gas
7.5% p.y. Thousand boed 4,556
278 7.8% p.y. 3,493 742
185 2,403 383 724 2,217 2,036 2,020 101 96 551 85 94 133 163 289 161 168 274 250 265 2.812 2.374 1,880 1,684 1,540 1,493
2003 2004 2005 T ar get 2006 Target 2011 2015 For ecast Oi l and NGL - Br azi l Natural Gas - Brazil
Oi l and NGL - I nter naci onal Natural Gas - Internacional
8 Brazilian production curve
2.600 2,368 2,374 2,195 690 1,979 2,061 2.100 1,880 Net Increase 1,684 1.600
1.100
600 + Thous. bpd Thous. 100 (154) (154) (326) (172) (508) (697) (400) (181) (897) 1,114 (189) (201) Accumulated (900) (217) Natural Decline
(1.400) 2005 2006 2007 2008 2009 2010 2011 1,804 Total Production Accumulated Decline Annual Decline Gross Increase
9 Main Domestic Oil Production Projects
7 out of the 15 projects refer to after-2002 discoveries 2,600 AlbacoraAlbacora Leste Leste Thousand pbd P-50P-50 180,000180,000 bpdbpd ESS-130 RoncadorRoncador ESS-130 April/2006April/2006 Golfinho Mod III **** 2,374 P-52P-52 Golfinho Mod III **** 2,400 (FPSO) 180,000180,000 bpdbpd (FPSO) JubarteJubarte 100,000100,000 bpdbpd 20072007 Parque das FaseFase 1 1 20082008 Parque das P-34P-34 2,368 Conchas***Conchas*** Rio de Janeiro 60,00060,000 bpdbpd Rio de Janeiro Espadarte Mod II 100,000100,000 bpdbpd 2,200 Oct/2006Oct/2006 Espadarte Mod II 100,000100,000 bpdbpd 2,195 20112011 FPSOFPSO CapixabaCapixaba 20072007 Roncador GolfinhoGolfinho Mod. Mod. 11 FradeFrade Roncador P-55** 100,000100,000 bpdbpd 100,000100,000 bpdbpd P-55** 2,061 180,000 bpd 2,000 MayMay 20062006 20092009 180,000 bpd 1,979 MarlimMarlim Sul Sul 20112011 ModuleModule 22 JubarteJubarte Roncador Phase 2 Roncador P-51P-51 Phase 2 P-54 P-57 P-54 180,000180,000 bpdbpd P-57 180,000 bpd 1,800 1,880 180,000 bpd 20082008 180,000180,000 bpdbpd 20072007 20102010
PiranemaPiranema MarlimMarlim Leste Leste 20.00020.000 bpdbpd CidadeCidade de de VitóriaVitória P-53*P-53* 1,600 1,684 Dec.Dec. 20062006 GolfinhoGolfinho Mod. Mod. 22 100,000100,000 bpdbpd 180,000180,000 bpdbpd 20072007 20092009
1,400 2005 2006 2007 2008 2009 2010 2011
10 CorporateCorporate TargetsTargets
CapitalCapital ExpendituresExpenditures andand CostsCosts
11 InvestmentInvestment PlanPlan
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 CompetitiveCompetitive CostCost StructureStructure
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 10 5.88 6.00 5.73 5.54 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 DomesticDomestic LiftingLifting CostCost
Lifting Costs and Government Take per Barrel
54,50
25,0 38,29 50 20,0 28,13 28,74 14.65 40 24,11 25,47 15,0 10.7 30 8.5 10,0 7.0 8,9 7.0 6.6 20
US$/boe 6,4 5,1 5,0 3,7 3,3 4,0 10 5,7 5,6 3,3 3,3 3,0 3,4 4,3 0,0 0 2000 2001 2002 2003 2004 2005 2011
Lifting Cost Government Take Brent
Lifting costs expected to stabilize ♦ Production increases ♦ Technological enhancements ♦ Wells, platforms and plants automation ♦ Optimization of logistics, operations and administrative processes
14 Petrobras’ Drilling Rigs
2003 2004 2005 Total Total Brazil International Total
Onshore 25 47 22 19 41
Offshore 41 43 42 4 46 Owned Rigs: 31 Total 66 90 64 23 87 Leased: 56
• Petrobras’ leasing contracts are long term, averaging a 5 years length; • In 2005, 18 offshore drilling rigs were owned by Petrobras; • In August 2005, Petrobras renovated 24 drilling rigs contracts. • In July 2006, Petrobras signed contracts worth R$ 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 RecentRecent ExplorationExploration EffortsEfforts andand ResultsResults
16 ExplorationExploration ActiActivitiesvities -- 1998/2005 1998/2005 wellswells && seismicseismic
611 exploration wells Espírito Santo Î 40 wells offshore Î 31% overall success ratio Campos Î 186 wells offshore Last year (2005) Î 55% Santos Î 65 wells offshore
Other Basins
Î 216 wells onshore 1998/2005 Î 104 wells offshore ~ 450,000 km 2D seismic ~ 92,240 km2 3D seismic
17 NumberNumber of of Concessions Concessions in in BrazilBrazil
PetrobrasPetrobras ConcessionsConcessions Other Other TotalTotal ConcessionsConcessions 100%100% CompaniesCompanies ParnershipsParnerships Total Total BrazilBrazil W.IW.I ExplorationExploration BlocksBlocks 59 59 66 66 125 125 218 218 343 343 ExplorationExploration EP´sEP´s 24 24 6 6 30 30 0 0 30 30 ProductionProduction 273 273 19 19 292 292 29 29 321 321
TotalTotal356356 91 91 447 447 247 247 694 694
Petrobras & Partners Other Companies
18 Petrobras’ Current Exploration Portfolio
EXPLORATORYEXPLORATORY AREAAREA SantosSantos 22 157.7157.7 thousandthousand km km 39.439.4 milkm milkm22
CamposCampos Other (*) 13.1 mil km22 Pará Maranhão-Barreirinhas 13.1 mil km 4% 3% 25% Sergipe Alagoas 5% Potiguar-Ceará 6% 8% SantosSantos Bahia Sul 9% CamposCampos 6% 10% Espírito Santo Solimões 11% Espírito Santo 11% Espírito São Francisco Foz do Amazonas Espírito Santo OtherOther Basins Basins** Santo 10.110.1 mil mil km km22
Î 40 % of the concession areas in Campos, Espírito Santo e Santos basins.
* Other basins: Pelotas (2%), Ceará (0.8%) and Recôncavo (0,2%)
19 ExpansionExpansion ofof ExplorationExploration FrontiersFrontiers andand NewNew OilOil ProducingProducing DistrictsDistricts
Fields discovered until 1984 Fiels discovered between 1984 and 2001 Fields discovered in 2002/2003 (L(Lightight oil oil)) Oil and gas discoveries under evaluation ((HeavyHeavy oil oil))
ESSESS-130-130 (L(Lightight oil oil))
BC-20BC-20 GGasas GGasas andandlight lightoil oil ((HeavyHeavy oil oil))
BS-500BS-500 20 MainMain DiscoveriesDiscoveries -- 2002/2005 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
T O T A L 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 DiscoveriesDiscoveries && ReservesReserves
DiscoveriesDiscoveries (2002/2005):(2002/2005): 6,66,6 billionbillion boeboe
ÎÎ ProvedProved Reserves:Reserves: 3,13,1 billionbillion boerboer
99 CamposCampos Basin:Basin: 2,02,0 billionbillion boerboer(Jubarte, (Jubarte, Cachalote,Cachalote, BaleiaBaleia Franca, Franca, BaleiaBaleia Azul, Azul, BaleiaBaleia Anã, Anã, Papa-Terra,Papa-Terra, Abalone,Abalone, Ostra,Ostra, Nautilus,Nautilus, ArgonautaArgonauta and and Ring-FencesRing-Fences ofof MarlimMarlim Leste, Leste, EspadarteEspadarte & & Albacora;Albacora;
99 SantosSantos Basin:Basin: 0,80,8 billionbillion boerboer(Mexilhão, (Mexilhão, Uruguá,Uruguá, TambaúTambaú & & Lagosta)Lagosta)
99 EspíritoEspírito Santo Santo Basin:Basin: 0,250,25 billionbillion boerboer(Golfinho (Golfinho & & Canapu)Canapu) 99 Sergipe-AlagoasSergipe-Alagoas Basin: Basin: 0,050,05 billionbillion boerboer(Piranema) (Piranema) ÎÎ ProbableProbable && PossiblePossible Reserves:Reserves: 1,51,5 billionbillion boerboer ÎÎ StillStill inin AppraisalAppraisal (2006):(2006): 2,02,0 billionbillion boerboer 22 DomesticDomestic E&PE&P
ExplorationExploration Portfolio:Portfolio: SustainingSustaining GrowthGrowth BeyondBeyond 20112011
23 Production per Basin (July, 2006)
55.6 (000 bpd) Oil 84.9 (000 bpd) Oil 56.7 (000 boe/d) Gas 18.2 (000 boe/d) Gas
53.4 (000 bpd) Oil 27.1 (000 boe/d) Gas
48.7 (000 bpd) Oil 31.4 (000 boe/d) Gas
BR 100% e BR Partners Other Companies 4,2 (000 bpd) Oil 83.1 (000 bpd) Oil 0.7 (000 boe/d) Gass 20.3 (000 boe/d) Gas
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) Oil.: 1,785.1 (000 bpd) 3.0 (000 bpd) Oil 6.8 (000 boe/d) Gas Nat. Gas: 284.5 (000 boe/d) Total....: 2,069.6 (000 boe/d) 24 ExplorationExploration PerspectivesPerspectives
PaleozoicPaleozoic basinsbasins EquatorialEquatorial marginmargin basinsbasins ÎÎLightLight oil/condensateoil/condensate (frontier)(frontier) && naturalnatural gasgas ÎÎHighHigh risksrisks && highhigh rewardsrewards ÎÎnaturalnatural gasgas && lightlight oiloil
Eastern/NorteasternEastern/Norteastern marginmargin basinsbasins ÎÎLightLight oiloil && naturalnatural gasgas ÎÎJequitinhonhaJequitinhonha basinbasin (new(new province??)province??) ProterozoicProterozoic basin basin ÎÎHighHigh risksrisks ÎÎnaturalnatural gasgas
EspiritoEspirito Santo,Santo, CamposCampos && SantosSantos basinsbasins ÎÎSearchSearch forfor newnew producibleproducible heavyheavy oiloil discoveriesdiscoveries ÎÎSearchSearch forfor lightlight oiloil && naturalnatural gasgas discoveriesdiscoveries
25 ExplorationExploration Portfolio:Portfolio: HydrocarbonHydrocarbon PotentialPotential DistributionDistribution
SOLIMÕES EQUATORIAL MARGIN 1.4% 10.3%
SEAL & RECÔNCAVO 4.5¨%
BAHIA SOUTH 16.5¨% SÃO FRANCISCO
0.2 % ESP.SANTO 11.0¨%
CAMPOS 28.7¨% PELOTAS Petrobras 0.1 % Other Companies SANTOS 78%78% 27.3¨%
26 ExploratoryExploratory WellsWells 2006-20102006-2010
MEQ (13) Solimões (3) Ceará (7)
Potiguar (47)
SEAL& REC (54)
S.Francisco (2) Bahia Sul (43)
Esp.Santo (69) TOTAL BRASIL (# wells) = 368 (69)
Investments:Investments: US$ US$ 4.1 4.1 billion billion
Campos (62) 65%65%
Petrobras Santos (66) Other Companies Pelotas (2)
27 DomesticDomestic E&PE&P
DevelopmentDevelopment ofof NaturalNatural GasGas ReservesReserves
28 Domestic Natural Gas Market
140 Million m3/day 121.0 121.0 120 30.0 100 34.0 17.7% p.y. 80 38.6 60 45.4 71.0 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 PLANGAS December/2008
Cacimbas (20 MM m3/d)
Peroá (10 MM m3/d)
Lagoa parda Belo Horizonte Vitória Pólo Golfinho ESS-164 +16.3 MM m3/d (*) Ubu Golfinho + Canapu Pq. Baleias + BC10
Cabiúnas Campinas Garoupa ESS-130 Rio de Janeiro Caraguatatuba Namorado Enchova REDUC Pampo RPBC Platforms from UN-BC and UN-RIO Tambaú +6.4 MM m3/d (*)
Mexilhão Uruguá TOTAL SOUTHEAST: Merluza - II Merluza 40 MM m3/d (BM-S-3/ BM-S-7, Lagosta SPS-25) +1.5 MM m3/d (+ 24.2 MM m3/d) (*)
(*) Additional to the current supplay 30 Natural Gas Supply Curve
Million m3/day 14 out of the 27 projects refer to after 2002 discoveries Roncador SPS25 RJS633 Cavalo (P-55) ESS164 2009 2010 Marinho 2011 2008 2010 Urucu 80 Mexilhão 70 Start gas Sales 2009 2007 70.6 70 Roncador Golfinho 65.2 Parque das (P-54) Mód 2 Canapu Conchas 2007 2007 2008 Tambaú/Uruguá 2011 60 2010 Peroá- Frade
Jubarte Fase 2 associated GN Non GN associated Cangoa 2009 49.4 (P-57) Fase 1 Marlim Leste 50 2010 2006 (P-53) Marlim Sul 2009 ESS130 Mód 2 Manati 40 34.1 2008 (P-51) 2006 2008 3027.5 Piranema Peroá- 2006 Cangoa Roncador Fase 2 (P-52) 2007 20 Jubarte 2007 Albacora Albacora (P-34) Complement Leste 2006 Espadarte 2007 10 (P-50) Mód. 2 2006 Golfinho Mód 1 2007 2006 0 2006 2007 2008 2009 2010 2011
31 DomesticDomestic E&PE&P
PartnershipsPartnerships
32 ConcessionsConcessions inin PartnershipsPartnerships
26 Oil & Gas Companies
Production Fields Exploration Blocks (284) (134)
268
16 68 66
Petrobras (100%) Partnerships
33 PartnershipsPartnerships withwith PetrobrasPetrobras
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 Petrobras’Petrobras’ Partners 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 DomesticDomestic E&PE&P
DevelopmentDevelopment ApproachApproach andand TechnologicalTechnological HistoryHistory
36 PetrobrasPetrobras DevelopmentDevelopment ApproachApproach 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 TheThe MainMain PetroleumPetroleum ProvinceProvince inin BrazilBrazil 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 CamposCampos Basin:Basin: AA GiantGiant TechnologyTechnology LabLab
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 Monobuoys 3 1
39 Petrobras´Petrobras´ Records Records inin Completion/ProductionCompletion/Production andand ExplorationExploration DrillingDrilling OffshoreOffshore
OTCOTC OTCOTC 19921992 20012001
Exploration Wells Vs. Maximun Water-Depths by year
40 InstalledInstalled SubseaSubsea Trees Trees xx OilOil OperatorOperator
506 256 Petrobras Royal Dutch/Shell 256 Statoil 212 bp 148 ExxonMobil 137 ChevronTexaco 128 Hydro 117 Amerada-Hess (Triton) 105 Total 99 ConocoPhillips 73 Eni Kerr-McGee 72 BHP Billiton 68 Other 534
0 100 200 300 400 500 600
Source: Quest SUBSEA-DATA-BASE 41 Petrobras'Petrobras' TechnologicalTechnological HistoryHistory • 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 DomesticDomestic E&PE&P
ConclusionsConclusions
43 ConclusionsConclusions
• 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 PetrobrasPetrobras atat aa GlanceGlance ResultsResults andand PerspectivesPerspectives
EndEnd
ThankThank YouYou forfor youryour AttentionAttention
45 DomesticDomestic E&PE&P
Annex:Annex: CurrentCurrent FieldField DevelopmentsDevelopments
46 MarlimMarlim Sul Sul Field Field DevelopmentDevelopment
ModuleModule 11 HighlightsHighlightsModule Module 22 Module Module 33 Module Module 44 Module 1 Module 1 P-40P-40 // P-38P-38 Complem. Complem. Operating ProductionProduction WellsWells 13 13 6 6 10 10 10 10 Complementar InjectionInjection WellsWells 8 8 5 5 9 9 9 9 CapacityCapacity (bpd)(bpd) 155,000155,000 100,000 100,000 180,000 180,000 100,000 100,000 UnderUnder m FirstFirst OilOil 2001 2001 2004 2004 2008 2008 2013 2013 FeasibilityFeasibility 0 Study 0 ProductionProduction P-40P-40 (SS)(SS) Study 0 FPSO-MLSFPSO-MLS P-51(SS) P-51(SS) ND ND 1 FPSO SystemSystem P-38P-38 (FSO)(FSO) APIAPI 23-27 23-27 25 25 22 22 16 16 Marlim Sul m 0 P-40 0 5 P-38 1 Water depth: Module 3 850 - 2,400 m
P-51
Gas pipeline Oil pipeline Module 2 m 00 25 Module 4
47 RoncadorRoncador Field Field DevelopmentDevelopment
ProductionProduction wellswells 8 8 18 18 11 11 11 11 InjectionInjection wellswells 3 3 11 11 6 6 7 7 underunder CapacityCapacity (bpd)(bpd) 100.000 100.000 180,000 180,000 180,000 180,000 180,000 180,000 feasibilityfeasibility FirstFirst oiloil 2002 2002 2007 2007 2007 2007 2010 2010 studystudy APIAPI 1818 ProductionProduction systemsystem FPSO FPSO BrasilBrasil SS SS P-52P-52 FPSO FPSO P-54P-54 SS SS P-55P-55 APIAPI 27 27 toto 3131 27 27 toto 3131 18 18 22 22
Water depth: 1,500 – 1,900 m P-52
1,500 m MODULE 1A FPSO Brasil
MODULE MODULE P-54 MODULE 3 2 4 1,900 m P-55
48 BarracudaBarracuda && CaratingaCaratinga Field Field DevelopmentDevelopment
HighlightsHighlightsBarracuda Barracuda Caratinga Caratinga
ProductionProduction WellsWells 20 20 12 12 InjectionInjection WellsWells 14 14 8 8 Water depth: CapacityCapacity (bpd)(bpd) 150,000 150,000 150,000 150,000 700 -1,200 m FirstFirst OilOil 12/21/2004 12/21/2004 02/28/2005 02/28/2005 ProductionProduction SystemSystem P-43 P-43 (FPSO)(FPSO) P-48 P-48 (FPSO)(FPSO) APIAPI 25 25 23 23
49 AlbacoraAlbacora Leste Leste Field Field DevelopmentDevelopment
HighlightsHighlights
ProductionProduction WellsWells 17 17
InjectionInjection WellsWells 14 14 Water depth: CapacityCapacity (bpd)(bpd) 180,000 180,000 1,100 -1,500 m FirstFirst OilOil 2006 2006 ProductionProduction SystemSystem P-50 P-50 (( FPSOFPSO )) APIAPI 18,3 18,3
P-50
50 MarlimMarlim Leste Leste Field Field DevelopmentDevelopment
HighlightsHighlights
ProductionProduction WellsWells 14 14 InjectionInjection WellsWells 8 8
CapacityCapacity (bpd)(bpd) 180,000180,000
FirstFirst OilOil 2009 2009
ProductionProduction SystemSystem P-53 P-53 (FPU)(FPU)
APIAPI 21,5 21,5 FPU Water depth: 820 – 1,500 m
51 JubarteJubarte FieldField DevelopmentDevelopment
HighligthsHighligthsPilot Pilot Phase Phase 11 Phase Phase 22
ProductionProduction wellswells 1 1 4 4 21 21 InjectionInjection wellswells 7 7 CapacityCapacity (bpd)(bpd) 20,000 20,000 60,000 60,000 180.000 180.000 FirstFirst OilOil 2002 2002 2006 2006 2010 2010 ProductionProduction SystemSystem Seillean Seillean FPSO FPSO P-34P-34 FPSO FPSO P-57P-57 o oAPIAPI 1717 17 17 17 17
Water Depth: 1,240–1,350 m
52 DevelopmentDevelopment ofof thethe GasGas FiFieldselds PeroáPeroá and and CangoCangoáá 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 DevelopmentDevelopment ofof thethe PiranemaPiranema Field Field (light(light oiloil SESE))
54