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STUDY OF METHANE SOLUBILITY IN ORGANIC EMULSIONS APPLIED TO DRILLING FLUID FORMULATION

This study explores the solubility of methane in organic emulsions, specifically for the formulation of drilling fluids. The research includes literature review, experimental aspects, results, and conclusions.

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STUDY OF METHANE SOLUBILITY IN ORGANIC EMULSIONS APPLIED TO DRILLING FLUID FORMULATION

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  1. STUDY OF METHANE SOLUBILITY IN ORGANIC EMULSIONS APPLIED TO DRILLING FLUID FORMULATION AND WELL CONTROL Eduardo Monteiro

  2. Outline 1) Introduction 2) Literature Review 3) Experimental Aspects 4) Results 5) Conclusions

  3. 1) Introduction Drilling Fluids Functions: . Wellbore cleaning . Cooling and lubrication . Wellbore stability . Hydrostatic pressure Basic Requirements: . Formation damage prevention . Corrosion mitigation . Environmental regulation

  4. Drilling Fluids Liquids Gas-Liquid Mixtures Gases Aerated Water (mostly water) Water Oil Foam (mostly gas) Natural Gas Air • Conventional • Organic 1) Introduction Drilling Fluids Classification:

  5. 1) Introduction Drilling Fluids Circulation System:

  6. 1) Introduction Kick  Undesired influx of fluids from the formation into the wellbore • Conditions: • PBH< PForm • Permeable • formation

  7. 1) Introduction Kick  Blow Out

  8. 1) Introduction Objectives: • Review of the PVT behavior of oil based fluids used in drilling operations (state of the art); • Generation of PVT experimental data for organic emulsions which could be used to feed well control simulation packages; • Modeling of PVT properties and discussion : gas solubility and formation volume factor

  9. 2) Literature Review • O’Brien (1981) • Special attention when circulating an oil based drilling fluid because of the high gas solubility • Thomas et al. (1982) • Effects of gas solubility on kick detection . Saturation pressures at 100ºF . Diesel oil and a diesel based drilling fluid

  10. 2) Literature Review • O’Bryan et al. (1988) • Experimental study of the effects on solubility . Diesel 2, Conoco LVT, Mentor 28 . 100ºF, 200ºF and 300ºF . 13 ppg, 15.5 ppg and 18 ppg . Additivity hypothesis for solubility in emulsions:

  11. 2) Literature Review • O’Bryan et al. (1988) – cont. Methane Solubility in Mentor 28, Brine and Emulsifier

  12. 2) Literature Review • O’Bryan et al. (1990) • Effect of gas solubility on pit gain . Methodology for pit gain calculation . Pit gain is 80% smaller for oil based muds . Additivity hypothesis for formation volume factor of emulsions:

  13. 2) Literature Review • Berthezene et al. (1999) • Organic oils analysis . Diesel, mineral, olefin and ester . 194ºF . Up to 5,000 psi . Additivity hypothesis for solubility in ester based emulsions

  14. 2) Literature Review • Silva et al. (2004) . N-paraffin and Ester . 158ºF and 194ºF

  15. 3) Experimental Aspects • Apparatus Components Hg pump PVT cell Gasometer

  16. 3) Experimental Aspects • Apparatus Schematic Diagram • Cell Volume = 600 cm³ • Maximum Pressure = 10,000 psi • Maximum Temperature = 356 ºF

  17. 3) Experimental Aspects • Operation One more data point!!! Only more 600 hours to finish...

  18. 3) Experimental Aspects Procedure • . Liquid admission • . Methane admission • . Heating • . Pb determination • . Differential liberations

  19. 3) Experimental Aspects Methodology for Pb determination Bubble point Pressure

  20. P=Pb2 P<Pb1 P>Pb1 Gas Free Gas Liquid Liquid Liquid Hg Hg Hg Hg Hg 3) Experimental Aspects Methodology for Differential Liberation

  21. 4) Results Methane + Emulsion: . 3 compositions (OWR: 42/58, 60/40 and 75/25) at 158ºF . 1 composition (OWR: 60/40) at 194ºF . 2 tests for each pair composition-temperature Emulsion

  22. 4) Results Oil-Water Ratio Effect: Solubility

  23. 4) Results Oil-Water Ratio Effect: Formation Volume Factor

  24. 4) Results Oil-Water Ratio Effect: Specific Gravity

  25. 4) Results Solubility Modeling

  26. Silva et al. (2004) 4) Results Solubility Modeling . 158ºF  RsO-158 . 194ºF  RsO-194 . Rsbr: O’Bryan et al. (1988) regressions

  27. Experimental Data: OWR=42/58 OWR=60/40 OWR=75/25 Additivity Hypothesis: OWR=42/58 OWR=60/40 OWR=75/25 4) Results Solubility Modeling

  28. Experimental Data: OWR=60/40 Additivity Hypothesis: OWR=60/40 4) Results Solubility Modeling

  29. Silva et al. (2004) 4) Results Formation Volume Factor Modeling . 158ºF Bo158 . 194ºF Bo194 . Bbr: constant (1 vol/vol)

  30. Experimental Data: OWR=42/58 OWR=60/40 OWR=75/25 Additivity Hypothesis: OWR=42/58 OWR=60/40 OWR=75/25 4) Results Formation Volume Factor Modeling

  31. Experimental Data: OWR=60/40 Additivity Hypothesis: OWR=60/40 4) Results Formation Volume Factor Modeling

  32. 5) Conclusions • The oil fraction in the emulsion has shown an important effect on the PVT properties measured; • The comparison among experimental data and predicted results for emulsions showed good agreement for pressures up to 5,000 psia; • The NEW data obtained can be used on well control simulators that handle oil based fluids.

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