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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Extra info for Drilling Fluids Processing Handbook
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 .