• SNF conceptual study about BoD, SoR for TLP and FSO, polymer properties, process, operation, logistics options, costs, ... • Lab studies of polymer AN125SH and FP5115 into field reservoir water, sea water and mix of both waters • SNF Answer: ‘The temperature being 86°C , the Flopaam 3630S (copolymer of acrylamide and acrylate) will not be stable . So we propose to use a polymer containing some sulfonated moieties , stable up to 100 °C , and also with less tendency to hydrolyzation . Flopaam AN125SH is a copolymer of acrylamide and ATBS (sulfonate monomer) , Flopaam 5115 is a terpolymer of acrylamide ATBSacrylate (the ATBS will pr event further hydrolysis or precipitation) . Both polymers should be tested on long term stability to select the best one in term of economic Technical ratio . AN125 will be the best in term of long term stability , but its cost is slightly higher.’
Enhanced Oil Recovery Polymer Flooding SNF Conceptual Study • SNF conceptual study about BoD, SoR for TLP and FSO, polymer properties, process, operation, logistics options, costs, • Lab studies of polymer AN125SH and FP5115 into field reservoir water, sea water and mix of both waters • SNF Answer: ‘The temperature being 86°C , the Flopaam 3630S (copolymer of acrylamide and acrylate) will not be stable So we propose to use a polymer containing some sulfonated moieties , stable up to 100 °C , and also with less tendency to hydrolyzation Flopaam AN125SH is a copolymer of acrylamide and ATBS (sulfonate monomer) , Flopaam 5115 is a terpolymer of acrylamide /ATBS/acrylate (the ATBS will pr event further hydrolysis or precipitation) Both polymers should be tested on long term stability to select the best one in term of economic/ Technical ratio AN125 will be the best in term of long term stability , but its cost is slightly higher.’ OCTL test SNF conceptual study October 15 | Page SNF study - Polymer Injection Facilities • Polymer Powder 50000 bpd @ 500 ppm October 15 | Page Polymer Flooding simulation EOR Mechanism: Polymer augmented increases water viscosity, improve mobility ratio and sweep efficiency polymer solution viscosity PLYVISC polymer water viscosity concentration multiplier lb/stb [-] Csalt 7.01 lb/stb (20000 ppm) from SALTNODE 0.0 1.0 0.1753 5.0 0.3505 10.0 0.7010 20.0 / Viscosity multiplier • Invoke EOR option keywords in Eclipse: PLYVISC, PLYADS, PLYMAX, PLYROCK, WPOLYMER, Polymer Viscosity 90 80 Csalt 6000 ppm 70 Csalt 20000 ppm 60 Csalt 35000 ppm 50 40 30 20 10 0 500 1000 1500 2000 Polymer Concentration (ppm) • Assumption to increase Water Viscosity 10 times with Polymer concentration of 1000 ppm as SNF suggestion Region Aquifer WI Oil Leg WI • Timing: Starting at Feb 2022 (at the end of drilling campaign – water cut about 40%) North East 3 North West • Polymer Injection in Oil Leg Water Injectors only South West Total • Polymer Concentration: 500 ppm (0.1753 lb/stb) Chemical Injection simulation – 2D model Relative Permeability 1 0.9 0.9 0.8 0.8 0.7 0.7 Fractional Flow 0.6 0.6 0.5 0.5 0.4 0.4 0.3 0.3 0.2 0.2 0.1 0.1 0 0 0.1 0.2 0.3 0.4 Kro 0.5 0.6 Krw 0.7 fw 0.8 0.9 0.1 0.2 0.3 0.4 Base case Polymer 1000 ppm Surfactant2 0.5 0.6 0.7 0.8 0.9 Polymer 500 ppm Surfactant1 ASP Polymer assumption: • Increase displacing viscosity by – 10 times Surfactant Flooding assumption: • Wettability to favourable • Sor reduce to 5% Chemical Injection simulation – 2D model FOPR FOPR PF000 FOE FOPR PF001 FOPR SF000 FOPR SP000 FOE PF000 40 FOE PF001 FOE SF000 FOE SP000 0.8 Polymer +Surfactant Surfactant 0.7 Polymer 0.6 Water 0.5 20 Foe Oil production rate (STB/DAY) 30 0.4 0.3 10 0.2 0.1 0 200 400 600 800 1000 1200 1400 0 1000 2000 Polymer Flooding • The 2D cross section model gives improvement of UR about 6-8% • DeltaP between Producer and Injector increase as higher polymer concentration injection 3000 Polymer Flooding simulation – 2D model WBHP 2D Polymer Flooding FOPR PLYFLOOD003 FOPR PLYFLOOD004 20 5500 15 4500 Bottom hole pressure (PSIA) Oil production rate (STB/DAY) FOPR PLYFLOOD005 10 01/19 Case name PLYFLOOD003 PLYFLOOD004 PLYFLOOD005 WBHP INJ1 PLYFLOOD005 WBHP PROD1 PLYFLOOD005 WBHP PROD1 PLYFLOOD003 WBHP PROD1 PLYFLOOD004 WBHP INJ1 PLYFLOOD003 WBHP INJ1 PLYFLOOD004 3500 2500 01/20 01/21 01/22 01/23 Case description as 001 but WI Temp 187, Polymer ppm as 003 but WI Temp 187, Polymer 1000 ppm as 003 but WI Temp 187, Polymer 2000 ppm 1500 01/19 UR 6.425 6.99 7.24 01/20 %Variance 0.0 8.8 12.7 01/21 01/22 01/23 01/24 RF 66% 72% 74% Profile of 2D model: • The 2D cross section model gives improvement of UR about 6-8% • DeltaP between Producer and Injector increase as higher polymer concentration injection 01/25 Polymer Flooding simulation – 2D model 2D Polymer Flooding FOPR PF000 FOPR PF003 FOPR PF001 FOPR PF004 FOE FOPR PF002 FOPR PF005 FOE PF000 FOE PF003 40 FOE PF001 FOE PF004 FOE PF002 FOE PF005 0.8 0.7 0.6 0.5 Foe Oil production rate (STB/DAY) 30 20 0.4 0.3 0.2 10 0.1 0 01/19 01/20 01/21 01/22 1000 2000 3000 Polymer Flooding simulation – Full Field model Polymer Flooding FOPR PH30_P136F4 FOPT PH30_P136F10 FOPT PH30_P136F4 FOPR PH30_P136N RF vs PV Injected FOPR PH30_P136F10 FOPT PH30_P136N FOE PH30_P136N 120K 350MM FOE PH30_P136F4 FOE PH30_P136F10 0.4 ASP Flooding from 2022 300MM Polymer flooding 100K Ref case - Water Flooding 0.3 200MM 60K 150MM Foe 80K Oil production total (STB) Oil production rate (STB/DAY) 250MM 0.2 40K 100MM 0.1 20K 50MM Start Polymer injection 05/19 05/21 05/23 05/25 05/27 05/29 05/31 05/33 05/35 05/37 05/39 05/41 05/43 05/45 0 0.5 1.0 1.5 2.0 2.5 3.0 Pv Injected UR % Case name Case description (mmstb) Variance RF % 0.0 31.6% PH30_P136F4 WTemp 187 degF, Polymer injection ppm - Ref case xxx 3.5 32.7% PH30_P136F10 WTemp 187 degF, Polymer injection 500 ppm yyy 6.0 33.5% PH30_P136N WTemp 187 degF, Polymer injection 500 ppm + Alkaline + Surfactant zzz Profile FFM: • However, the PF full field simulation result is not promising due to the loss in injectivity of the Water Injectors (especially in the oil leg) => Need more injectors or increase injection pressure • Looking for scenario to fracture these injection wells • Combined with other chemicals as ASP Flooding or other EOR methods Way forward •Cost and Economics evaluation •Core experiment program for polymer flooding •Pilot test •Full field application October 15 | Page 10 ... higher polymer concentration injection 3000 Polymer Flooding simulation – 2D model WBHP 2D Polymer Flooding FOPR PLYFLOOD003 FOPR PLYFLOOD004 20 5500 15 4500 Bottom hole pressure (PSIA) Oil production... PH30_P136F4 FOE PH30_P136F10 0.4 ASP Flooding from 2022 300MM Polymer flooding 100K Ref case - Water Flooding 0.3 200MM 60K 150MM Foe 80K Oil production total (STB) Oil production rate (STB/DAY) 250MM... study October 15 | Page SNF study - Polymer Injection Facilities • Polymer Powder 50000 bpd @ 500 ppm October 15 | Page Polymer Flooding simulation EOR Mechanism: Polymer augmented increases water