Journées Annuelles du Pétrole Les 21 et 22 octobre 2008 - Paris, Palais des Congrès, Porte Maillot Les Hydrocarbures de l extrême ENHANCED OIL RECOVERY TOTAL EXPERIENCES Pascal Gauer
NEW FRAMEWORK OF E&P INDUSTRY - Production becomes more & more challenging Oil : ~ 45 Million bbls/day of new production in the coming 10 years... Valorising existing ressources Expected demand (~1,6%/year) (Million bbls/d) 100 New production 80 60 Producing fields forecasted decline (~5%/year) 40 20 Frontier exploration 0 2000 2002 2004 2006 2008 2010 2012 M in. overburden 100m Possible sources of resource increase 10 000 000 ~5m 00m 500 to 10 Non conventional production Getting more of existing resources Frontier exploration Non conventional production 1 000 000 2 2014
EOR : Tertiary Recovery Factors RF % Miscible gas 80 60 40 +15% to 30% 40% to 50% RF = 70% +20% to 40% Alkaline / Surfactant / Polymers 40% to 50% 20 +5% to 15% Polymers only 20% to 30% WI / GI 0.1 Chemical / Thermal Chemical WI WI 10 +20% to 40% Thermal +10 % to 30% P or ASP 5% to 20% depletion and WI 100 1000 Oil viscosity cp A significant increase of recovery factors and a production acceleration is economically possible in a high barrel price context. 3
Significant resources yet to be produced Oil resources ~3,000 Bboe 100 years Gas resources a gain of 60 billion barrels of oil Unconventional resources for every extra oil shale, shale gas, coal bed methane, tight gas 1%OOIP 70 years ~2,000 Bboe 115 years Heavy oil 95 years 50 years 33 years of production at current pace New discoveries and increased recovery rate 60 years of production at current pace Identified resources Conventional oil mainly in the Middle East More than 50% of global gas resources in Russia, Iran and Qatar Heavy oil concentrated in Canada and Venezuela Transportation and liquefaction constraints limit global access to isolated resources Oil and gas resources require increasing technological proficiency and higher capital expenditures to be brought onstream source : Total estimates 4
Chemical EOR Project DALIA - CAMELIA POLYMER FLOODING 5-
Polymer flood to improve the sweep efficiency Objective : Increase water viscosity Improve mobility control Sensitive to temperature, salinity, shear stress (valves, fittings, well/formation interface) µw reduction High salt Low salt Adsorbs on rock material µw reduction, permeability reduction 6
DALIA - Deep Offshore Field - Polymer Injection Project Water injection design : 375 000 bwpd 31 water injectors on 4 water injection lines 1 line / 5 injectors 3 additional lines on Full-Field Average water injection rate 12 500 bwpd/well Injectivity Test : December 2008 1 line injection : 2009 Plant Polymer factory production ~50tons/day 2 sister ships : Powder Carriers with process shuttling between Europe & Dàlia site 65tons Polymer mother solution at 5g/l FPSO Dàlia FPSO water Rail transport : Powder storage & transfer to ~36 wagons for ~1 batch 3 trains of 12 wagons length of 1 train : ~250m Distance Sete / Dàlia site : 4600 Powder Carrier Stay @ Dàlia site : ~45days mother solution plant Clean Sand, High permeability Oil viscosity 3-7 cp Low temperature 50 C Formation water Salinity 130 g/l Injection water desulfated sea w. Polymers HPAM: 7 t/day (1 line) Expected incremental + 6% OOIP Distance Powder Carrier / FPSO : ~100m or ~2000m 65tonswagon equipment within harbour Cargo Barge polymer transfer pump : 420m /h & ~10bars Round trip duration @10knots : 40days Equipped with Initial Full Field design barge corresponding Loading duration : ~2days : 50T/day polymer 2 boats (+/- 1 FPSO water transfer)pump :420m3/h & 5bars Transit duration @ harbour : ~2days powder polymer to 7 3 FPSO mother solution HP pumps : 420m3/h & 150bars FPSO feed tank capacity to be defined : 0bar
Chemical EOR Pilots ASP FLOODING (ALKALIN SURFACTANT POLYMER ) 8-
Physico-Chemical EOR formulation: design & validation Formulation Laboratory Conditions Reservoir Conditions 12 to 18 months needed ph UV cond. NaCl P2 P1 Injection pump 9 Solution for injection Fraction collector HPLC GC Ionic chrom.
Microscopic Tertiary Oil Recovery from Sandstone Core Secondary Recovery 10 cm Tertiary Recovery EOR 1 Cumulative Oil Recovery Fraction 0.8 0.6 Oil Fraction 0.4 0.2 0-2.0 4.0 6.0 8.0 10.0 12.0 14.0 Pore Volume Water Injection Full size core 200 μm MEB 10 ASP inject.
Indonesia : Alkaline Surfactant Polymer OOIP 1750 MMbbl RF 48%, 30 years production, 550 accumulations, 388 wells light oil, low salinity, high permeability OOIP Considered for Alkaline Surfactant Polymer EOR: 340 MMbbl, 18 reservoirs EOR stake: Delta RF: +20% OOIP, 70 MMbbls Pilot in 2010 11
Full Field - Tentative Development Timeline STUDIES 5 Spot Field Pilot Full Field Expansion Reservoir Level Field Trial Time Chemicals (tons/year) EOR Screening Physico-Chemical Core floods Geo-modeling Archictecture Concept Full Field stakes Chemicals (tons/year) Basic Engineering Construction Supply of Chemical Chemical injection on a 5 spot Monitoring Interpretation Chemical injection on a full reservoir level Monitoring Interpretation PHASE PHASE 1 PHASE 2 PHASE 3 4 Injection rate ~ 200 Kbwpd 80 000 ALKALI SURFACTANT CO-SURFACTANT POLYMER 70 000 60 000 50 000 40 000 30 000 20 000 10 000 1 2 3 4 5 6 Need to supply of huge amount of Chemicals (average ~ 90 Kt/yr ~250 tons/day) 12 7 Full 8Field Period
R&D for Chemical EOR : pushing the limits Temperature C Surfactants TEMPERATURE ( C) 160 140 Polymers 120 Expected domain extension Gabon Current domain of application 100 Indonesia 80 Angola 60 Middle East 40 20 0 0 50 100 150 200 250 In-situ water salinity (g/l) Need to improve behavior in temperature, salinity, mechanical degradation, adsorption 13 300
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