Study on the Volumetric Behavior of Base Oils, Brines, and Drilling Fluids Under Extreme Temperatures and Pressures
- Mario Zamora (M-I SWACO) | Sanjit Roy (M-I SWACO) | Kenneth S. Slater (M-I SWACO) | John C. Troncoso (M-I SWACO)
- Document ID
- Society of Petroleum Engineers
- SPE Drilling & Completion
- Publication Date
- August 2013
- Document Type
- Journal Paper
- 278 - 288
- 2013. Society of Petroleum Engineers
- 1.6 Drilling Operations, 1.11 Drilling Fluids and Materials, 1.11.2 Drilling Fluid Selection and Formulation (Chemistry, Properties)
- 6 in the last 30 days
- 1,166 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 10.00|
|SPE Non-Member Price:||USD 30.00|
Drilling-fluid densities vary significantly over wide ranges of temperatureand pressure, a concern that is particularly critical in deepwater, Arctic, andhigh-pressure/high-temperature. The variations can affect well integrity, welldesign, regulatory compliance, and drilling efficiency. Drilling-fluiddensities depend on the compressibility and thermal expansion of the fluids(liquids) and solids used in their formulation. Suitablepressure/volume/temperature (PVT) correlations for these fluids previously havebeen fairly inaccessible, primarily because of continually changing base fluidsand blends, and the lack of readily available test equipment. This study wasconducted to measure the volumetric behavior under extreme temperatures andpressures of a broad range of the oils, synthetics, and brines currently usedin industry to prepare oil-, synthetic-, and water-based drilling fluids. Itfollows a recent study that successfully qualified the commercially availabletest equipment. For the most part, tests for this study were run attemperatures from 36 to 600°F and pressures from atmospheric to 30,000 psi,ranges that generally exceed those provided in other published studies.Correlation coefficients are provided for reference and to demonstrate theiruse in a compositional, material-balance model to accurately predictdrilling-fluid density as a function of temperature and pressure. Tests run onfield drilling fluids are included to demonstrate how these data can be used inprocedures and software to predict equivalent static density and hydrostaticpressure during drilling operations.
|File Size||1 MB||Number of Pages||11|
API 2010. API RP 13D—Rheology and Hydraulics of Oil-Well DrillingFluids, sixth edition, American Petroleum Institute.
Baranthol, C., Alfenore, J., Cotterill, M.D. et al. 1995. Determination ofHydrostatic Pressure and Dynamic ECD by Computer Models and Field Measurementson the Directional HPHT Well 22130C-13. Paper SPE 29430 presented at the 1995SPE/IADC Drilling Conference, Amsterdam, The Netherlands, 28 February-2 March.http://dx.doi.org/10.2118/29430-MS.
Demirdal, B. and Cunha, J.C. 2007. Olefin-Based Synthetic-Drilling-FluidsVolumetric Behavior Under Downhole Conditions. Paper SPE 108159 presented atthe SPE Rocky Mountain Oil and Gas Symposium, Denver, Colorado, 16-18 April. http://dx.doi.org/10.2118/108159-MS.
Demirdal, B., Miska, S., Takach, N. et al. 2007. Drilling Fluids Rheologicaland Volumetric Characterization Under Downhole Conditions. Paper SPE 108111presented at the SPE Latin American and Caribbean Petroleum EngineeringConference, Buenos Aires, Argentina, 15-18 April. http://dx.doi.org/10.2118/108111-MS.
Grace Instrument, Houston, "M7500PVT Ultra HPHT Pycnometer."http://www.graceinstrument.com/M7500PVT_ Ultra_HPHT_Pycnometer.shtml.
Hemphill, T. and Isambourg, P. 2005. New Model Predicts Oil, Synthetic MudDensities. Oil & Gas J. 103: 56-58.
Hoberock, L.L., Thomas, D.C., and Nickens, H.V. 1982. Here's HowCompressibility and Temperature Affect Bottom-Hole Mud Pressure. Oil &Gas J. (22 March) 159-164.
Hussein, A.M.O. and Amin, R.A.M. 2010. Density Measurement of Vegetable andMineral Based Oil Used in Drilling Fluids. Paper SPE 136974 presented at theAnnual SPE International Conference, Tinapa-Calabar, Nigeria, 31 July-7 August.http://dx.doi.org/10.2118/136974-MS.
Isambourg, P., Anfinsen, B.T., and Marken, C. 1996. Volumetric Behavior ofDrilling Muds at High Pressure and High Temperature. Paper SPE 36830 presentedat the SPE European Petroleum Conference, Milan, Italy, 22-24 October. http://dx.doi.org/10.2118/36830-MS.
McMordie, W.O., Bland, R.G., and Hauser, J.M. 1982. Effect of Temperatureand Pressure on the Density of Drilling Muds. Paper SPE 11114 presented at theSPE Annual Technical Conference, New Orleans, Louisiana, 26-29 September. http://dx.doi.org/10.2118/11114-MS.
Peters, E.J., Chenevert, M.E., and Zang, C. 1988. A Model for Predicting theDensity of Oil-Based Muds at High Pressures and Temperatures. Paper SPE 18036presented at the 1988 SPE Annual Technical Conference, Houston, Texas, 2-5October. http://dx.doi.org/10.2118/18036-MS.
Zamora, M., Broussard, P.N., and Stephens, M.P. 2000. The Top 10 Mud-RelatedConcerns in Deepwater Drilling Operations. Paper SPE 59019 presented at the2000 SPE International Petroleum Conference, Villahermosa, Tabasco, Mexico, 1-3February. http://dx.doi.org/10.2118/59019-MS.
Zamora, M., Enriquez, F., Roy, S. et al. 2012. Measuring PVTCharacteristics of Base Oils, Brines, and Drilling Fluids Under ExtremeTemperatures and Pressures. Paper AADE-12-FTCE-44 presented at the AADE FluidsTechnology Conference and Exhibition, Houston, Texas, 10-11 April.