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CHEMICAL EOR FIELD EXPERIENCE Oil Chem Technologies, Inc. Sugar Land, TX USA oil-chem

CHEMICAL EOR FIELD EXPERIENCE Oil Chem Technologies, Inc. Sugar Land, TX USA www.oil-chem.com. PRESENTATION OUTLINE. Introduction to Oil Chem EOR – past EOR - Oil Chem Technologies field experience to share EOR - future. PRESENTATION OUTLINE. Introduction EOR – past

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CHEMICAL EOR FIELD EXPERIENCE Oil Chem Technologies, Inc. Sugar Land, TX USA oil-chem

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  1. CHEMICAL EOR FIELD EXPERIENCEOil Chem Technologies, Inc.Sugar Land, TX USAwww.oil-chem.com

  2. PRESENTATION OUTLINE • Introduction to Oil Chem • EOR – past • EOR - Oil Chem Technologies field experience to share • EOR - future

  3. PRESENTATION OUTLINE • Introduction • EOR – past • EOR - Oil Chem Technologies field experience to share • EOR - future

  4. WHY EOR?

  5. Oil Recovery Overview BAVIER; BASIC CONCEPTS OF EOR PROCESSES(1991)

  6. WHY CHEMICAL EOR?

  7. ECONOMICS FOR FIELD ASP PROJECTS

  8. ROLE OF SURFACTANTS • Reduce interfacial tension • Wettability alteration • Polymer, CDG, BW, etc. can be used along with surfactants when mobility control is necessary

  9. SURFACE OR INTERFACIAL TENSIONS

  10. RELATIONSHIP BETWEEN CAPILLARY NUMBER AND OIL RECOVERY Nc =  µ / cosθ Nc =Capillary Number  = Darcy Velocity µ = Viscosity • = Interfacial Tension Θ=wetting angle

  11. PRESENTATION OUTLINE • Introduction • EOR – past • EOR - Oil Chem Technologies field experience to share • EOR - future

  12. LOUDON FLOOD - EXXON 1983 • 2.3% surfactant • 96% of the connate salinity • 0.3% pore volume • 0.1% Xanthan gum • 56 million pounds surfactant was injected in 9 months • 68% ROIP

  13. ROBINSON – MARATHON1983 • 10% surfactant – petroleum sulfonate • 0.8% hexanol as co-surfactant • 2.5% salt • No polymer • 0.1 pore volume • 19 –21% ROIP

  14. CHEMICAL EOR -PAST PROBLEMS Technical success but limited “commercial” success - Reasons?

  15. EOR BY CHEMICAL FLOOD Limited commercial success for the past two decades - Reasons? • Sensitivity to oil price • Limitations of chemicals • High surfactant concentration • Salinity optimization required • Potential emulsion block

  16. However, • Extensive lab evaluations and field pilot tests support the feasibility of chemical flooding • New chemicals and processes open the door for new opportunities • Recent field data using these new chemical and processes proves chemical flooding is an effective way to recover residual oil

  17. PRESENTATION OUTLINE • Introduction • EOR – past • EOR - Oil Chem Technologies field experience to share • EOR - future

  18. CURRENT PROJECTS • 21 Current projects • 20MT to 400 MT Surfactant/mo • 400 MT @ 0.1% = 28,000,000 bbl/mo injection • California 50,000 MT surfactant/yr @ 0.2% =155,000,000 bbl/yr • Build plant onsite

  19. CHINA EORPROJECTS • Heavy crude recovery • Low perm formation oil recovery • High temp. / high salinities • Effective, economical offshore EOR

  20. CHINA EORPROJECTS INJECTED, ON-GOING & APPROVED PROJECTS SS B2080, SS B5050, SS B1688, ORS-46L, ORS-97HF, ORS-41HF

  21. 1992-94: LAB EVALUATION Over 100 Surfactants Were Tested Including: • ORS-41 • Petroleum Sulfonates • Carboxylates • Lignin Sulfonate/Petroleum Sulfonates • Microbiological

  22. 1995 - INITIAL FIELD EVALUATION • Daqing No.4 Field - Oil Chem Technologies’ ORS-41 • Daqing No.1 Field – another US company’s Petroleum Sulfonate

  23. 1996-1998:ENLARGED FIELD EVALUATION ORS-41 was the ONLYsurfactant chosen for enlarged field evaluation. More than 7000 MT of the ORS-41 was injected in several field blocks and this confirmed the viability of the ASP process SPE 36748, 57288, 71061, 71491, 71492

  24. DAQING CENTRAL WELL SPE 57288

  25. DAQING CENTRAL FIELD SPE 84896

  26. HEAVY OIL RECOVERY BY CREATING WATER EXTERNAL PSEUDO-EMULSION

  27. HEAVY OIL PSEUDO-EMULSION Control 0.1% SF-100 Surfactant

  28. HEAVY OIL PSEUDO-EMULSION 0.1% SF-100 Surfactant Control

  29. HEAVY OIL PSEUDO-EMULSION 0.1% SF-100 Surfactant Control Oil Viscosity < 200 cps Oil Viscosity = 6,700 cps

  30. LAB CORE FLOOD DATA Oil Recovery, % Water flood Injection Volume, PV

  31. LOW PERM INJECTIVITY ENHANCER • Permeability: 0.1 – 10 md • High water injection pressure makes water flood unfeasible • FI series surfactants reduced injection pressure, increased injectivity • Effectively increased the injectivity in several fields in China and USA

  32. CANADA EOR PROJECTS • HEAVY CRUDE • TAR SAND • LOWER RESERVOIR TEMPERATURES • FRESH WATER SOURCES • HIGH SALINITY RESERVOIRS • FRACTURED CARBONATE FORMATIONS

  33. CANADA EOR PROJECTS INJECTED, ON-GOING & APPROVED PROJECTS SS B2080, SS B5050, SS B1688, ORS-46L, ORS-97HF, ORS-41HF Some field results will be published upon completion of projects

  34. NORTHERN CANADA SP PROJECT • Heavy oil field, API = 12 -13 • Under polymer flood • Added 0.1% surfactant with polymer in November, 2006 • ~ 3 months later, the water cut reduced from 97% to 58%

  35. UNITED STATES EOR PROJECTS • FRESH WATER SOURCES • HIGH SALINITY RESERVOIRS • FRACTURED CARBONATE FORMATIONS • LOW PERMEABILITY

  36. UNITED STATES EOR PROJECTS INJECTED, ON-GOING & APPROVED PROJECTS ORS-41HF (2), ORS-62, ORS-97, ORS-46HF, ORS-162, SS-7593, SS B1688(2)

  37. SHO-VEL-TUM FIELD • On production > 40 yrs, extensive water flood, produced 4 bbl/day • ASP started on 2/98, using Na2CO3 and ORS-62 • Total incremental oil > 10,444 bbl (22 bbls/day) in 1.3 years SPE 84904

  38. OIL SATURATION AFTER ASP INJECTION SPE 84904

  39. MELLOTT RANCH WYOMINGASP PROJECT • 0.1% ORS-46HF, 1% NaOH, 1300 PPM polymer • Recovered 989,000 bbl or 16.4 % OOIP between 2003 and 2005 • Injection volume decreased 2,800,000 bbl due decreased water cut

  40. ASP MELLOTT RANCH ASP PROJECT - ORS-46HF WATER FLOOD SINCE 1966

  41. BIG SINKING, KENTUCKY Project Information • Crude oil : 100 Million bbl • Bottom Hole Temperature: 30oC • Depth: 1150 ft • Thickness: 25 feet (7.32 meter) • Permeability: 45 mD SPE 100004

  42. BIG SINKING, KENTUCKY Chemical injected: 0.8% NaOH + 0.1% ORS-162HF Problems overcome: • IFT lowered from 23.6 to 0.001 mN/m • Poor water injectivity • High water cuts • 220% increase in injectivity • Large field trial scheduled to begin in 12/2007 SPE 89384

  43. BIG SINKING, KENTUCKY SPE 89384

  44. TANNER FIELD, WYOMING Project Information • Crude oil : 21o API • Bottom Hole Temperature: 175oF • Depth: 8915 ft • Thickness: 25 ft • Porosity: 20% • Permeability: 200 mD SPE 100004

  45. TANNER, WYOMING SPE 100004

  46. SOUTHEAST ASIA PROJECTS • HEAVY CRUDE • HIGH TEMPERATURES • ENVIRONMENT CONCERNS • FRESH WATER SOURCE

  47. SOUTHEAST ASIA PROJECTS INJECTED, ON-GOING & APPROVED PROJECTS SS 6-72LV, SS 8020

  48. OFFSHORE ALKALINE SURFACTANT (AS) PROJECT • SEA WATER IS SOFTENED ON THE PLATFORM • SINGLE WELL TEST SUCCESSFULLY PERFORMED USING SS 6-72LV INJECTED WITH NAOH • PILOT PROJECT WILL PROCEED

  49. SOUTH AMERICA PROJECTS • VARIOUS RESERVOIR CONDITIONS • MANY EOR CANDIDATE FIELDS – • OFFSHORE & INLAND • ASPHALTENE REMOVAL / WELLBORE • DAMAGE REMOVAL • IMPROVED GAS RECOVERY/REDUCED • WATER CUT

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