Abstract
ABSTRACT Estimation has been made of the applicability and reliability of five well known oil well pressure drop prediction methods and for each method guidelines are presented concerning their accuracy as a function of flowrate, tubing size, liquid velocity, water cut and wellbore angle of deviation. New methods are presented for modelling pressure loss in retrograde gas-condensate wells. These methods employ redefined flow pattern map boundaries based upon the utilisation of available well test data and are superior in accuracy to existing multi-flow regime and no-flow regime, methods of interest. Fourteen crude oil compositions, five retrograde gas-condensate compositions and a total of 102 welltest pressure surveys from a wide range of North Sea fields are used to ascertain the suitability of the correlations. The fluid PVT properties are generated by the Peng Robinson equation of state and the Schmidt Wenzel equation of state is employed for improved liquid density predictions. Generally, the predictions compare most favourably with laboratory measured data. In addition, full consideration of transient heat-transfer to the formation is included in the modelling.
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