Download Drilling Fluids Processing Handbook by ASME Shale Shaker Committee PDF

By ASME Shale Shaker Committee

The one source to be had to the drilling and petroleum engineer on drilling fluids processing.

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The mud is very costly. The dilution volume required to compensate for contamination of the mud by 1 bbl of drilled solids is given by the following equation: Vdilution (bbl drilling fluid/bbl drilled solids) ¼ ð100 À Vsolids Þ=Vsolids where Vsolids is the volume of drilled solids expressed in volume percentage. As discussed earlier, drilled solids become less tolerable with increasing mud density. For drilling-fluid densities less than 12 lb/gal, Vsolids<5% is desirable, whereas for a density of 18 lb/gal, Vsolids<2 or 24 Drilling Fluids Processing Handbook 3% is best.

In those days, a coarse screen was 4 to 10 mesh and a fine screen was a 12 mesh. These units were quite popular because no electricity was required and the settling pits did not fill so quickly. Revolving drum units have just about disappeared. The vibrating screen, or shaker, became the first line of defense in the solids-removal chain and for a long time was the only machine used. Early shakers were generally used in dry sizing applications and went through several modifications to arrive at a basic type and size for drilling.

Of course, in so doing, the fluid itself assumes this cuttings burden, and if the cuttings are not removed from the fluid, it very quickly loses its ability to clean the hole and creates thick filter cakes. To enable on-site recycling and reuse of the drilling fluid, cuttings must be continually and efficiently removed. 2 Types of Drilling Fluids Drilling fluids are classified according to the type of base fluid and other primary ingredients: . Gaseous: Air, nitrogen . Aqueous: Gasified—foam, energized (including aphrons) Clay, polymer, emulsion .

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