The program is designed for the prediction, treatment, and control of common scale deposits in oil and gas wells.
Program uses: either measured pH or P-CO2 at STP; Pitzer electrolyte theory to calculate activity coefficients; PengRobinson EOS for gas fugacity coefficients; ethylene glycol and methanol effect activity coefficients for calcite, barite, gypsum, celestite, and halite. Numerous “what-if” calculations can also be done.


Coastal Chemical also utilizes various methods and techniques for testing of scale formation and inhibition.


Scale formation in gas and oil wells is a common and persistent problem during production, treatment, transportation, and disposal of co-produced saltwater; inhibition of this scale formation is a priority.


As a member of the Rice University Brine Consortium, Coastal Chemical uses the ScaleSoftPitzer Software for determining scaling potential.


The Dynamic Scale Loop is used to determine the effectiveness of scale inhibitors on formation and prevention of scale using the tube block method. This method allows for flow, pressure and temperature variances. It considers the adherence of scale to pipework.

Anions and cations are introduced separately into the loop and scaling time is measured. Once a blank scaling time is determined, scale inhibitors are added to the cations and scaling time measured.


In accordance with NACE procedures TM0197 and TM0374, Coastal Chemical uses ion loss, turbidity and kinetic turbidity at 532nm to determine scale formation and inhibitor efficiency. As scale precipitates, the brine becomes turbid (cloudy). A turbidity meter or laser is used to measure the changes in the solution to monitor onset and the effectiveness of the scale inhibitor.


Contact Coastal Chemical to learn how scale prediction solutions can improve your gas and oil well performance.

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