Schlumberger

Industry Article: HPHT Testing

201301_hpht_ot_tn
Publication: Oilfield Technology
Volume: January
Issue: 2013
Publication Date: 01/01/2013

With global oil and gas demand driving additional exploration in deeper plays, operators increasingly rely on accurate measurement of flow and thermal stability in oil-base drilling fluids in extremely high pressures and temperatures. Fluid loss from thermal instability and associated complications can hobble even the best designed drilling programs. In challenging high pressure, high temperature (HPHT) environments, operators continue to prefer invert drilling fluids to water-base systems because of the former’s superior thermal stability. But little rheological data from extreme HPHT conditions above 500°F and 30,000 psi have been published due to a lack of suitable drilling fluid and viscometers. However, recent tests using four different types of HPHT viscometers have led to a simple rheological model to predict oil-base mud behavior under extreme HPHT conditions.



Download: HPHT Testing (1.11 MB PDF)

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