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Advanced HPHT Drilling Fluid & Wellbore Integrity Analysis

Advanced HPHT Drilling Fluid & Wellbore Integrity Analysis

Advanced HPHT Drilling Fluid & Wellbore Integrity Analysis
Advanced HPHT Drilling Fluid & Wellbore Integrity Analysis
Advanced HPHT Drilling Fluid & Wellbore Integrity Analysis

Description

  1. Project ID: DW-74-B-Simulation
  2. Laboratory Location: Advanced Geomechanics & Fluids Facility
  3. Primary Objective: Validate rheological stability and shale inhibition at 22,000 feet.
  4. Base Fluid: Synthetic Isomerized Olefin (C16-C18 blend).
  5. Weighting Material: Micronized Barite (4.2 Specific Gravity).
  6. Target Density: 17.2 pounds per gallon (ppg).
  7. Water-to-Oil Ratio (WOR): 20:80.
  8. Internal Phase Salinity: 250,000 mg/L Calcium Chloride.
  9. Mixing Temperature: 120°F (standard lab ambient).
  10. High-Temperature Exposure: 375°F for a 16-hour aging period.
  11. Aging Method: Dynamic rolling in stainless steel pressure cells.
  12. Pre-Aging Rheology at 150°F:
  13. 600 RPM: 88 cP
  14. 300 RPM: 52 cP
  15. 200 RPM: 38 cP
  16. 100 RPM: 24 cP
  17. 6 RPM: 8 cP
  18. 3 RPM: 6 cP
  19. Post-Aging Rheology at 150°F:
  20. 600 RPM: 94 cP
  21. 300 RPM: 56 cP
  22. Plastic Viscosity (PV): 38 cP.
  23. Yield Point (YP): 18 lb/100ft².
  24. Low-End Rheology (6/3 RPM): Maintained above 5 cP to ensure cuttings transport.
  25. Gel Strength (10 second): 10 lb/100ft².
  26. Gel Strength (10 minute): 18 lb/100ft².
  27. Gel Strength (30 minute): 22 lb/100ft².
  28. Fragile Gel Index: Confirmed (low pump-initiation pressure required).
  29. Electrical Stability (ES): 650 Volts (indicates strong emulsion).
  30. HTHP Filtration Test: 3.8 mL filtrate loss at 350°F/500 psi differential.
  31. Filter Cake Thickness: 1.5 mm (smooth and non-erodible).
  32. Excess Lime Concentration: 3.5 ppb (pounds per barrel).
  33. Solids Content by Volume: 28% total solids.
  34. Low Gravity Solids (LGS): 4% (within acceptable limits for ROP optimization).
  35. Shale Inhibition Test: 98.2% recovery of Pierre Shale cuttings.
  36. Linear Swell Meter Results: 1.2% swelling over 24 hours.
  37. Lubricity Coefficient: 0.08 (Metal-on-Metal).
  38. Sag Factor (Static): 0.518 (minimal settling observed).
  39. Dynamic Sag Test: 0.02 lb/gal variance during 30-minute shear.
  40. Particle Size Distribution (PSD): D50 measured at 18 microns.
  41. Contamination Test: 10% Vol seawater influx tolerated without flocculation.
  42. CO2 Sensitivity: Negligible change in YP after 50 psi CO2 injection.
  43. Corrosion Rate: 1.2 mils/year on P110 steel coupons.
  44. Oxygen Scavenger Efficiency: 99% reduction in dissolved O2.
  45. Friction Reducer Performance: 15% reduction in circulating pressure simulated.
  46. ECD Management: Equivalent Circulating Density maintained within 0.4 ppg margin.
  47. Tool Compatibility: Verified safe for Viton and Nitrile elastomers.
  48. MWD Signal Transmission: Attenuation within -12 dB limits.
  49. Disposal Compliance: Passed LC50 toxicity test for offshore discharge.
  50. Status: Fluid formulation approved for field deployment in Phase 1.