Les Hydrocarbures de l extrême

Transcription

1 Journées Annuelles du Pétrole Les 21 et 22 octobre Paris, Palais des Congrès, Porte Maillot Les Hydrocarbures de l extrême ENHANCED OIL RECOVERY TOTAL EXPERIENCES Pascal Gauer

2 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 Producing fields forecasted decline (~5%/year) Frontier exploration M in. overburden 100m Possible sources of resource increase ~5m 00m 500 to 10 Non conventional production Getting more of existing resources Frontier exploration Non conventional production

3 EOR : Tertiary Recovery Factors RF % Miscible gas % 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 % to 40% Thermal +10 % to 30% P or ASP 5% to 20% depletion and WI Oil viscosity cp A significant increase of recovery factors and a production acceleration is economically possible in a high barrel price context. 3

4 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

5 Chemical EOR Project DALIA - CAMELIA POLYMER FLOODING 5-

6 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

7 DALIA - Deep Offshore Field - Polymer Injection Project Water injection design : bwpd 31 water injectors on 4 water injection lines 1 line / 5 injectors 3 additional lines on Full-Field Average water injection rate bwpd/well Injectivity Test : December 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 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 : 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 harbour : ~2days powder polymer to 7 3 FPSO mother solution HP pumps : 420m3/h & 150bars FPSO feed tank capacity to be defined : 0bar

8 Chemical EOR Pilots ASP FLOODING (ALKALIN SURFACTANT POLYMER ) 8-

9 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.

10 Microscopic Tertiary Oil Recovery from Sandstone Core Secondary Recovery 10 cm Tertiary Recovery EOR 1 Cumulative Oil Recovery Fraction Oil Fraction Pore Volume Water Injection Full size core 200 μm MEB 10 ASP inject.

11 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

12 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 ALKALI SURFACTANT CO-SURFACTANT POLYMER Need to supply of huge amount of Chemicals (average ~ 90 Kt/yr ~250 tons/day) 12 7 Full 8Field Period

13 R&D for Chemical EOR : pushing the limits Temperature C Surfactants TEMPERATURE ( C) Polymers 120 Expected domain extension Gabon Current domain of application 100 Indonesia 80 Angola 60 Middle East In-situ water salinity (g/l) Need to improve behavior in temperature, salinity, mechanical degradation, adsorption

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