Two sensors, one installed at the Return Flow Line and the other at the Bell Nipple, are combined by an algorithm to produce Flow Rate Out in gpm or m3/min that delivers unprecedented levels of accuracy and precision. Whether using the AFH% to produce Flow Out % (Flow Height) or the more advanced AFH-GPM to produce volumetric Flow Out GPM, the system wide sensitivity, crucial for seeing micro-kicks/losses and clearly defining flowback signatures is unprecedented. We have at least one case where through flowback signatures allowed the operator to mitigate a possible wellbore instability issue by seeing a consistent signature depicting transition from normal flowback to that of a ballooning/breathing wellbore. Detection of warning/anomaly was later on proven > 3 hours ahead as compared with the traditional flow paddle sensor.
Obtaining reliable density measurements from Active Pits remained elusive even after most providers shifted to submersible electronic diaphragms from traditional hydraulic capillaries. Especially for drilling circulation where old mud meets new mud nearly continuously, errors caused by tank agitation of up to 0.5 ppg makes the best “single density” sensors fall short. Many have opted to slip stream through an industry standard Coriolis, not realizing that the mud sample remains affected by agitation as well as gas entrainment thus readings remain questionable.
Real mud density in a tank is measured within the confines of the tank, represented by the entirety of the tank's content and condition. To isolate and remove agitation effects, a sensor array (i.e., multiple measurements) with smart averaging and compensation algorithm is necessary. This is precisely what TPA was designed for.
Enabling real-time drilling fluid diagnostics with % Oil, % Water, % LGS & % HGS that allows the opportunity to optimize the drilling fluids engineering process. By optimizing the dilution costs, reducing drilling waste and increasing solids control efficiency we can reduce overall costs and improve both environmental and safety overall. With the primary well control barrier better managed, overall reduction NPT and ILT is achieved. Incremental approach to implementing a SiCon system installation on various locations can include active tank/mud pump suction, return line at the shakers as well as the centrifuge suction and effluent lines while delivering cost benefits at every stage. SiCon will help Engineers connect the dots between drilling fluids dilution, solids control efficiency and waste management. The has also been a strong push toward ESG Compliance and the reduction in GHG emissions that is also being monitored using our systems & advisory.
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