THERMAL SCIENCE

International Scientific Journal

Authors of this Paper

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Zhiqiang Tang

,

Qian Li

,

Hu Yin

THE NEAR-WELLBORE PRESSURE CALCULATION MODEL INCORPORATING THERMOCHEMICAL EFFECT

ABSTRACT
The potential difference of hydraulic pressure, solute concentration and temperature between the drilling fluid and the formation fluid can induce the flow of solvent and cause changes in the pore pressure during drilling a tight formation, which may result in wellbore instability. According to the continuity equation of fluid, the pore pressure calculation model considering the effect of thermochemical coupling is established and the solution of the pore pressure in the Laplace domain is given. Using this model, the effects of the temperature, solute concentration and viscosity of drilling fluid on the pore pressure around the wellbore are simulated. The results show that, when the wellbore pressure is higher than the formation pressure and the solute concentration of the drilling fluid is larger than that of the formation fluid, the near-wellbore pore pressure will decrease first and then increase during drilling a tight formation, and increasing the drilling fluid temperature will decrease the pore pressure. Increasing the solute concentration of the drilling fluid can inhibit the increase of the pore pressure.
KEYWORDS
tight reservoir, pore pressure, solute concentration, temperature, coupling effect
PAPER SUBMITTED: 2017-03-29
PAPER REVISED: 2017-08-06
PAPER ACCEPTED: 2017-08-06
PUBLISHED ONLINE: 2017-09-09
DOI REFERENCE: https://doi.org/10.2298/TSCI170329186T
CITATION EXPORT: view in browser or download as text file
THERMAL SCIENCE YEAR 2018, VOLUME 22, ISSUE Issue 1, PAGES [623 - 630]
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The near-wellbore pressure calculation model incorporating thermochemical effect

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