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

Transcription

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

2 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

3 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

4 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 %

5 IMPACT OF PRESENCE OF POLYMER ON SEPARATION Tests with 20% of oil 4, 50 C, 6g/l salt 110 1h 100 Recovered water (%) 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 Time (min) Blank With reference With 500ppm of HPAM Polymer has a positive impact on separation and negative on water quality

6 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

7 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, ) SPE , ) SPE , ) Energy Fuels 2012, 26,

8 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)

9 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

10 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 < PWT

11 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 (%) 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 (%) * * * * Oily water phase

12 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

13 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 (%) 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

14 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

15 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) y = 371,33x R² = 0, ,2 0,4 0,6 0, HC content (ppm) after 1h Absorbance at 2926 cm Oil 4, 50 C Oil 10, 70 C Blank reference Additive D1 D2

16 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%

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

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

19 IMPACT OF TIME ON EMULSION SEVERITY OiW (ppm) 400 Demulsifier efficiency on Oil 14 after 4h at 50 C no demulsifier 4H 50ppm demulsifier 4H 100ppm demulsifier 4H 200ppm demulsifier 4H 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.

20 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

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