HOW TO MANAGE CEOR BACK PRODUCED WATER ONSHORE? O.RAMBEAU, MH.ALVES

HOW TO MANAGE CEOR BACK PRODUCED WATER ONSHORE? O.RAMBEAU, MH.ALVES

PRESENTATION OUTLINE Problems with EOR projects at production Separation / Water Treatment Oil Treatment Discharge or Re-injection? R&D to meet the challenge Mimic a back viscosified produced water Separation and Water Treatment impacts Possibility to reduce Water Treatment impact

POLYMER EOR CHALLENGE TO WATER TREATMENT PFPW* Separation Oil treatment Oil to export Degasser water treatment *) Polymer flooding produced water Polymer removal? Back-produced water with polymer will impact separation. Back Produced Water with polymer will increase the oil content in water and makes it difficult to treat whatever the final destination of the PFPW Treated Low degradability of the polymer (20% degradation within 28 days according to HOCNF testing procedure) would recommend PWRI Removal of polymer from back-produced water creates large quantity of sludge *) Harmonised Offshore Chemical Notification Format Discharge? PWRI

CONTEXT AND OBJECTIVES Polymer (HPAM) used for chemical EOR injections in the reservoir: PARTIALLY HYDROLYSED POLY(ACRYLAMIDE): HPAM - Ultra high molecular weight used (17 18 MDa) - Hydrolysis grade (anionicity) approx. 25-30%

IMPACT OF PRESENCE OF POLYMER ON SEPARATION Tests with 20% of oil 4, 50 C, 6g/l salt 110 1h 100 Recovered water (%) 90 80 70 60 50 blank test, no HPAM test with reference additive, no HPAM blank test, with 500ppm of HPAM test with reference additive, with 500 ppm of HPAM Blank Without HPAM 1h With reference additive @100ppm 40 0 50 100 Time (min) Blank With reference additive @100ppm With 500ppm of HPAM Polymer has a positive impact on separation and negative on water quality

Viscosified water treatment / «conventional» additives 500ppm HPAM 500ppm Oil 4 Water salinity: 52g/l R= [additif]/[hpam] Cationic Coagulant : R >>> 1 Cationic Flocculant (up to R=1) After mechanical degradation Coagulant: R >>>1 and dirty water Anionic Green Flocculant (50ppm) + NaOH > 1% Loss of efficiency of clarifiers in presence of HPAM => Need new approach

SEPARATION FOR EOR FLOODING / ADDITIVES Focused on SP and ASP separation Literature : Demulsifiers for produced emulsions from SP and ASP processes (Nalco, ref 1-4) 1000ppm 30% oil 200ppm C8-TAB 100ppm Cocobetaine 200ppm C12-TAB 1) Energy Fuels 2011, 25, 555 561. 2) SPE-140860, 2011. 3) SPE-154044, 2012. 4) Energy Fuels 2012, 26, 2742 2750

EMULSION MAKE UP: FIRST STEP FOR SEPARATION Based on separation methodology Option: 10 and 80% oil Same emulsion duplicated 1) One for Separation (Bottle Tests) % separated water=f(t)

EMULSION MAKE-UP: SECOND STEP FOR WATER TREATMENT 2) One for water quality analysis Rayneri Turbine Water sampling Turbidity measurements (NTU) Determination of oil content (ppm) by IR

SYNTHETIC EMULSION 10% OIL 4 AND 500PPM HPAM D(0,5) [µm] T=0 (1 mix) 28 T=0 16 T=1h 8 T=4h 6 Without HPAM, for 6µm Decantation Time > 5h Huge emulsion < 10µm @ PWT

1 ST SCREENING: COMMERCIAL CATIONIC OR AMPHOTERIC ADDITIVES Tests with 10% of oil 4, 50 C, 6g/l salt, 500ppm of HPAM, 200ppm of additive 1) Separation 110 Recovered water (%) 105 100 95 90 85 80 75 70 0 10 20 30 40 50 60 70 Blank reference additive C08-TAB C12-TAB Cocobetaïne Time (min) Blank Reference additive C08-TAB C12-TAB Cocobetaïne Phases stabilization 60 min < 5 min 15 min 60 min 30 min Recovered water (%) 98 99 * * * * Oily water phase

1 ST SCREENING: COMMERCIAL CATIONIC OR AMPHOTERIC ADDITIVES Tests with 10% of oil 4, 50 C, 6g/l salt, 500ppm of HPAM, 200ppm of additive 2) Water quality analysis T=1h T=4h T=1h T=4h blank C08-TAB 514 NTU 297 NTU > 800 NTU > 800 NTU C12-TAB cocobetaine >> 800 NTU >> 800 NTU These additives favorize OiW >> 800 NTU > 800 NTU

2 ND SCREENING: COMMERCIAL OR IN DEVELOPMENT ADDITIVES Tests with 10% of Oil 4, 50 C, 6g/l salt, 500ppm of HPAM, 200ppm of additive 1) Separation 110 Recovered water (%) 105 100 95 90 85 80 75 70 0 10 20 30 40 50 60 70 Time (min) A1 A2 A3 D2 D1 Reference additive D1 D2 A1 A2 A3 Phases stabilization Recovered water (%) < 5 min < 5 min 7 min < 5 min < 5 min < 5 min 99 99 99 97 97 98

2 ND SCREENING: COMMERCIAL OR IN DEVELOPMENT ADDITIVES Tests with 10% of Oil 4, 50 C, 6g/l salt, 500ppm of HPAM, 200ppm of additive 2) Water quality analysis Confirmed on Oil 10

WATER AT SEPARATION OUTLET 300 Calibration curve of oil 10 10% oil, 500ppm HPAM => Blank Oil 4 : OiW# 500ppm Blank Oil 10: OiW # 200ppm Blank Oil 14: OiW # 400ppm Oil content (ppm) 250 200 150 100 50 0 y = 371,33x R² = 0,9994 0 0,2 0,4 0,6 0,8 600 500 400 HC content (ppm) after 1h Absorbance at 2926 cm -1 300 200 Oil 4, 50 C Oil 10, 70 C 100 0 Blank reference Additive D1 D2

COMPARISON OF COMMERCIAL ADDITIVES AFTER 1H 10% OIL 4, 50 C 10% OIL 10, 70 C D2 NTU 171: -66% NTU 44: -59% D1 NTU 630: +22% NTU 44: -59%

SEPARATION EFFICIENCY Blank 1H 3 H 24 H D1 80% Oil 4, 70 C, salt 6g/l, 500ppm HPAM 93 NTU 90 NTU

IMPACT OF HPAM CONTENT ON EMULSION SEVERITY OiW (ppm) Demulsifier efficiency on Oil 14 after 1h at 50 C 400 350 300 250 no demulsifier 1H 200 50ppm demulsifier 1H 150 100ppm demulsifier 1H 100 200ppm demulsifier 1H 50 0 0 100 200 300 400 500 600 HPAM (ppm) For 500ppm content of HPAM and 10% oil, tested demulsifier has a benefit effect on water quality effect (<200ppm in 1hour)

IMPACT OF TIME ON EMULSION SEVERITY OiW (ppm) 400 Demulsifier efficiency on Oil 14 after 4h at 50 C 350 300 250 200 150 no demulsifier 4H 50ppm demulsifier 4H 100ppm demulsifier 4H 200ppm demulsifier 4H 100 50 0 0 100 200 300 400 500 600 HPAM (ppm) Time is the first help for water quality even in presence of polymer For 500ppm HPAM, demulsifier would be mandatory, rate to be optimized on field.

WAY FORWARDS A first step of solution for polymer flooding on onshore fields: Take care of the water at separation stage and upstream (the right demulsifier) Design separation onshore increasing residence time for water quality Preliminary screening of additives required at lab scale Tests on water treatment process in progress: conventional ones Tests on water treatment process in progress: adapted ones To be adapted for polymer flooding Offshore: residence time in minutes

DISCLAIMER AND COPYRIGHT RESERVATION The TOTAL GROUP is defined as TOTAL S.A. and its affiliates and shall include the person and the entity making the presentation. Disclaimer This presentation may include forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 with respect to the financial condition, results of operations, business, strategy and plans of TOTAL GROUP that are subject to risk factors and uncertainties caused by changes in, without limitation, technological development and innovation, supply sources, legal framework, market conditions, political or economic events. TOTAL GROUP does not assume any obligation to update publicly any forward-looking statement, whether as a result of new information, future events or otherwise. Further information on factors which could affect the company s financial results is provided in documents filed by TOTAL GROUP with the French Autorité des Marchés Financiers and the US Securities and Exchange Commission. Accordingly, no reliance may be placed on the accuracy or correctness of any such statements. Copyright All rights are reserved and all material in this presentation may not be reproduced without the express written permission of the TOTAL GROUP.