19 09-2008 Solange da Silva Guedes na Rio Oil and Gas Expo Conference no Rio de Janeiro (somente em inglês)
 

19 09-2008 Solange da Silva Guedes na Rio Oil and Gas Expo Conference no Rio de Janeiro (somente em inglês)

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    19 09-2008 Solange da Silva Guedes na Rio Oil and Gas Expo Conference no Rio de Janeiro (somente em inglês) 19 09-2008 Solange da Silva Guedes na Rio Oil and Gas Expo Conference no Rio de Janeiro (somente em inglês) Presentation Transcript

    • Rio Oil & Gas 2008 70% Recovery factor: Petrobras Perspective Solange Guedes Executive Manager Petrobras S/A
    • Summary Overview of Petrobras E&P Reserves and 1 Production Forecasting Mature Fields Management Strategy: Continuing 2 IOR Improvement 3 Technological Challenges 4 Conclusions September/2006
    • Overview of Petrobras E&P Reserves and Production Forecasting
    • Overview of Domestic E&P - 2007 Reserves - SPE Proven reserves of 13.92 billion boe Internal Reserve Replacement of 123.6% Production 2,065 thousand boed (1,792 thousand bopd) 5-year CAGR of 5.6% Exploratory Area 140.3 thousand km²
    • Domestic Proven Reserve Development
    • Onshore Production Replacement (MM boe) 1.600 1.411,0 1.409,8 1.344,2 1.363,7 1.402,3 1.333,5 1.346,3 1.387,7 1.400,3 1.321,2 1.325,7 1.325,9 1.305,6 1.300 1.000 Equivalent Oil - Million boe 700 400 100 -200 78,5 [78,5] 164,5 [86] 255,8 -500 [91,4] 348,9 [93] 438,7 [89,8] 534,4 [95,7] 622,0 -800 706,0 [87,6] [84] 811,3 [105,3] 914,3 -1.100 [103] 1021,2 [106,9] 1110,2 Proved Reserves Cumulative Production Annual Production [89] 1196,5 -1.400 [86,3] 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007
    • Offshore Production Replacement (MM boe) 13.200 12427,4 12614,1 11701,4 11906,6 11191,8 11.200 9608,2 9.200 8186,3 8301,3 8282,5 7377,2 Equivalent Oil - Million boe 7174,3 7.200 6676 6187,1 5.200 3.200 1.200 -800 [214,7] 214,7 461,9 [247,2] 727,3 [265,4] 1045,2 [318] [369,1] 1414,3 -2.800 [417,2] 1831,6 [443,6] 2275,2 [501,4] 2776,6 [520,3] 3297,0 -4.800 [499,5] 3796,5 [546,6] 4343,1 [613,7] 4956,9 Proved Reserves Cumulative Production Annual Production [630,1] -6.800 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007
    • Domestic E&P Profile 2007 Production 2007 Proven Reserves (SPE) 9% 10% 4,5% 16,0% 23% 13,3% 58% 66,2% 2,065 thousand boed 13.92 billion boe Onshore Onshore Shallow water (0-300m) Shallow water (0-300m) Deep water (300-1500m) Deep water (300-1500m) Ultra-deep water (> 1500m) Ultra-deep water (> 1500m) 24% Current Exploratory Area 38% 11% 140.3 thousand km2 27% 65% of the concession areas are located in deep / ultra-deep waters.
    • Mature Fields Management Strategy: Continuing IOR Improvement Mature Fields - E&P Strategy Integration Integrity Cost Technology, Process, People
    • Domestic Fields Green Fields 41% Domestic Production 2.065 mil boed Brown Fields 59% Offshore Brown Fields Production 69% 1.218 mil boed Onshore 31%
    • Onshore Equivalent Oil in Place Volumes In Place = 17.1 billion boe Produced 19% Remain in Place 68% Reserves 13% Total RF = 32%
    • Offshore Equivalent Oil in Place Volumes In Place = 97 billion boe Produced 8% Reserves 20% Remain in Place 72% Total RF = 28%
    • RECAGE Corporate program focused on the improvement of production levels of fields with high degree of exploitation. Main Objectives Main Objectives Improve production levels Improve the Recovery Factor Costs optimization Reduce decline rates Lengthening the economic life
    • First Phase (2004-2008) Main focus: onshore and shallow water mature fields Increase water injection and velocity drainage up to 10% VOIP and final WOR up to 35; Improve reservoir management practices; Optimize steam injection and water injection projects; Remove bottlenecks in production facilities; Optimize lift systems; Reduce drilling and workover costs – onshore operations (rigless operations)
    • RECAGE: main results 4% Increase on Recovery Factor (average from 206 fields) 2004 2007 31% 35% 9000 Total Reserves (Brown Fields) MM boe 8000 7333 7125 6877 7000 6075 6000 5000 4000 3000 13,2% 3,6% 2,9% 2000 1000 0 2004 2005 2006 2007 Time (year) Additional Recoverable Volume: 1258 MM boe
    • Onshore Sergipe mature fields - production history and forecasting History Forecast 0,08 RECAGE Phase 1 Total 0,06 Oil rate (MMbbl/day) Carmópolis 0,04 Camorim 0,02 Siririzinho Dourado 0,00 1963 1973 1983 1993 2003 2013 2023 2033 2043 2053 Time (year) ∆RF = 4%
    • Canto do Amaro Field Increase the water injection up to 7% VOIP per year Drill 200 new wells (injectors and producers) Selectivity only for injectors Commingled completion High volume of water produced BPD 50000 Revitalization Project 45000 40000 35000 30000 25000 20000 15000 10000 5000 0 ∆RF = 5% 1986 1991 1996 2001 2006 2011 2016 2021 Production History Project
    • Miscible CO2 Injection - Miranga Field Pilot Project (april, 2009) 250 3.000.000 200 2.400.000 150 1.800.000 Cumulative Additional Production (m3) Additional Production (m3/d) 100 1.200.000 50 600.000 Also, a CCS effort in Brazil ∆RF = 10% 0 0 2008 2011 2014 2017 2020 2023 2026 2029 2032 2035 2038 2041 2044 2047
    • Well Technology: Multifractured Horizontal Wells (HRMF) Bonito Field: low-permeability carbonate reservoirs Production Unit Oil Pipeline Gas Pipeline ∆RF = 15% - 20%
    • Campos Basin: The maturity phase has arrived Discovery: 1974 – Garoupa Field N First Oil Production: 1977 – Enchova Field Water Depth: 50 - 1500m Floating Production Systems: 32 (23 SS, 9 FPSO) Fixed Platforms: 15 Sea water Injection Total Stationary Production Units : 46 Produced water Reinjection Planned Sea water Injection Producing Fields: 39
    • Marlim Field: different phases of production Marlim Projects 400 RF = 50% RF = 52% RF = 55% 350 Thousand BPD RF = 47% 83 300 100 51 RF = 46% 250 81 67 200 150 2008 2009 2010 2011 2012 2013 2014 2015 Production maintenance Increase Processing Marlim Phase 2 Marlim Phase 3 Marlim Phase 4 Marlim 13 new 100processing December/07RFand P-37 Increase waternew wells –bbl/dto and 2 injectors) 70% – Phase 4: preparing the basis in 2010 wells (11 producers achieve 6 thousand in FPSOs P-35 around (900 MM bboe additional)
    • Marlim Field : technologies to achieve higher RFs VASPS BCSS 4D Seismic BCS CAISSON 2011 2009 2010 2012 SSAO ANM Piggy-back TLWP SBMS* RWI* Well technolgies
    • Campos Basin - Recovery Factor Evolution Recovery Factor (%) Time (years)
    • Technological Challenges to achieve higher recovery factors PROPES
    • Recovery toolbox Water injection Conventional wells HC gas injection Horizontal wells 4D Seismics Raw sea water injection Multilateral wells WAG SMART wells MEOR ERD wells Steam HRMF wells CO2 injection Light Well Intervention Polymer injection Real Time Operations Centers Topside processing Sub sea separation Down hole separation Sub sea pumping & compression Down hole pumping & compression Boosting systems (VASPs, SBMS..)
    • 4D Seismic Interpretação 4D Seismic S4D - Casos Applications of 4D Seismic Applications of Identificação de Caracterização de Áreas Lavadas Falhas Selantes 13 wells - 9 relocated Identificação de Capa de Gás Marlim Field Anisotropia de Permeabilidades Identificação de Ajuste de Histórico Falhas e Área de de Poços Sobrepressão. 2 262 kgf/cm 2 305 kgf/cm Capa de Gás Identificaçãoand Falhas Falha Selante Faults de Anisotropia de Permeability Ajuste Histórico Gas Caps Área de Sobrepressão Sealing Faults Permeabilidade Production Overpressure Areas Anisotropy com suporte S4D History Matching
    • Subsea raw water injection (RWI) Structure Filters Mid-water Inlet Pump Controls Scenario: Injection Well Albacora Field (2009) Light oil 180000 1st Revitalization cycle Unconsolidated sandstone 160000 140000 2nd Revitalization cycle bpd 120000 100000 80000 2003 2007 60000 40000 RF 40% 47% 20000 0 out/44 out/47 out/53 out/50 out/41 out/38 out/29 out/99 out/05 out/11 out/17 out/20 out/23 out/26 out/32 out/35 out/87 out/93 out/02 out/08 out/14 out/90 out/96
    • Subsea system oil-water separation Pilot Project in Marlim Field (jan. 2010) Scenario: GAS OIL & GAS • Marlim Field (2010) • Heavy oil PRODUCTION • Very unconsolidated sandstone OIL OIL – WATER GAS SEPARATION SEPARATION WATER OIL & GAS FLOWLINE INJECTION WELL SUBSEA OIL-WATER SEPARATION PRODUCTION WELL PRODUCED FLUIDS PRODUCED WATER INJECTION FLOWLINE
    • Boosting Systems SBMS VASPS - Vertical Annular subsea multiphase pumping BCSS Separation & Pumping System Marlim Field - to be installed (2009) Marimbá Field (P-8)
    • Offshore Polymer Injection New scenario: Heavy oil offshore field (~15o API) Excellent permoporosity quality Recovery Process: viscosified water (by polymer injection) Example: PapaTerra field (DW: 1200 m - Campos Basin) High porosity and permeability 15º API Polymer Flood Equipment oil viscosity: 50 to 150 cP Horizontal wells with OHGP TLWP and FPSO Benefits - preliminary analysis : Increase Recovery Factor : ∆RF = 7% Decrease water production Seminário “OG21-Workshop for Enhanced Oil Recovery”
    • Real Time Operation Centers Picture
    • RECAGE – Phase 2 Expand the concept of Phase 1 to all fields, including the Deepwater Fields Revitalization Investment on key technologies (EOR process, light well intervention, subsea processing and complex well geometries) Phase 2 Fenix Project: recovery factors benchmarking x reservoir technical limits identification for all Petrobras fields (onshore and offshore)
    • RECAGE – Phase 2 - Ambition Offshore Fields Recovery factor of: 70% on platform, low complex reservoir fields 60% on subsea, low complexity reservoir fields Onshore Fields Recovery factor of: 70% on light oil and/or low complex reservoirs fields 35% on extra heavy oil and/or high complex reservoirs fields
    • 70% RF is becoming a reality Field Location Recovery Factor (%) Marlim offshore 56 Bicudo offshore 56 Lagoa Parda onshore 61 Araças onshore 61 Rio Urucu onshore 61 Piraúna offshore 63 Namorado offshore 64 Miranga onshore 67 Buracica onshore 69
    • Final Remarks During at least the next 20 years, oil and gas production from mature fields will supply at least half of the World’s demand for energy. Old paradigms for oil and gas production will be eclipsed by new practices, new drivers and new technologies geared towards increased recovery from mature fields. The continued high oil price scenario, coupled with new tools, technologies and processes will make 70% recovery targets for low complexity reservoirs a reality .