Drilling Fluid Systems
1. In the context of gas hydrate bearing reservoirs; the low-temperature thickening of drilling fluids would generally lead to an increase in ECD @ bottom of the well, which can easily lead to downhole complicated situations such as lost circulation.
If so, how do we manage to weaken the sensitivity of drilling fluid viscosity and shear force to temperature?
Also, how do we keep rheological parameters nearly as a constant in that low-temperature range?
Feasible to replicate all these experimental observations @ laboratory-scale to actual field-scale implementation?
2. Would it remain feasible to design and adopt a drilling fluid technology with ‘intelligent features’ such as ‘self-identification’; ‘self-tuning’; and ‘self-adaptation’ that would remain conducive to fundamentally solving various technical problems of drilling fluids; and thereby, enabling the drilling fluid to automatically identify the complex downhole environment; and to adjust the performance of the drilling fluid automatically?
3. With intelligent drilling fluids; Will we be able
(a) To achieve successful drilling in difficult drilling areas such as gas hydrate bearing sediment formations?
(b) To minimize the cost of treating agents?
(c) To facilitate the sustainable use of drilling fluids?
(d) To initially identify changes in the external environment of the fluid such as downhole pressure and temperature?
(e) To initially identify changes in the internal environment of the fluid such as pH value and salinity?
(f) To adjust the physical and chemical properties such as density, rheology and emulsification type – through such intelligent additives?
Given a plenty of ML algorithms to deduce the best possible and optimized solution, how exactly to go ahead with selecting an appropriate ML algorithm for the above 6 different cases?
4. In the context of various approaches considered to improve drilling efficiency, in general, a higher density of drilling muds remains required as the depth of operations keeps increasing; and; such high-density muds is generally achieved by adding Barite in significant quantities (exceeding 500 kg/m3).
If yes, what is the very purpose of deducing clay-free drilling fluid?
If not, to what extent, ‘clay free drilling fluids’ would be able
(a) To reduce the hydrodynamic loads on the wellbore?;
(b) To reduce the ECD of the drilling fluid?; and
(c) To avoid the ‘pipe sticking’ (resulting from the formation of a filter cake with poor qualities)?
Feasible to replicate the above scenario at laboratory-scale?
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