Separation of Drilled Solids from Drilling Fluids

The types and quantities of solids (insoluble components) present in drilling mud systems play major roles in the fluid's density, viscosity, filter-cake quality/filtration control, and other chemical and mechanical properties. The type of solid and its concentration influences mud and well costs, including factors such as drilling rate, hydraulics, dilution rate, torque and drag, surge and swab pressures, differential sticking, lost circulation, hole stability, and balling of the bit and the bottom-hole assembly. These, in turn, influence the service life of bits, pumps, and other mechanical equipment. Insoluble polymers, clays, and weighting materials are added to drilling mud to achieve various desirable properties.

Drilled solids, consisting of rock and low-yielding clays, are incorporated into the mud continuously while drilling. To a limited extent, they can be tolerated and may even be beneficial. Dispersion of clay-bearing drilled solids creates highly charged colloidal particles (<2 mm) that generate significant viscosity, particularly at low shear rates, which aids in suspension of all solids. If the clays are sodium montmorillonite, the solids will also form thin filter cakes and control filtration (loss of liquid phase) into the drilled formation. Above a concentration of a few weight percent, dispersed drilled solids can generate excessive low-shear-rate and high-shear-rate viscosities, greatly reduced drilling rates, and excessively thick filter cakes. As shown in Figures 2.3 and 2.4, with increasing mud density (increasing concentration of weighting material), the high-shear-rate viscosity (reflected by the plastic viscosity [PV]) rises continuously even as the concentration of drilled solids (low-gravity solids [LGSs]) is reduced. The methylene blue test (MBT) is a measure of the surface activity of the solids in the drilling fluid and serves as a relative measure of the amount of active clays in the system. It does not correspond directly to the concentration of drilled solids, since composition of drilled solids is quite variable. However, it is clear that, in most cases, drilled solids have a much greater effect than barite on viscosity and that the amount of active clays in the drilled

50 45 40 35 30

I 20

9 10 11 12 13 14 15 16 17 18 19 Mud Weight (lb/gal)

Figure 2.3. Effect of Solids on Mud Weight of Water-Based Muds. (Courtesy of M-I SWACO.)

Mud Treatment Package Swaco

9 10 11 12 13 14 15 16 17 18 19 Mud Weight (lb/gal)

Figure 2.3. Effect of Solids on Mud Weight of Water-Based Muds. (Courtesy of M-I SWACO.)

Mud Viscosity Diagram

Figure 2.4. Effect of Mud Weight and MBT on Viscosity of Acceptable WBM. (Courtesy of

Figure 2.4. Effect of Mud Weight and MBT on Viscosity of Acceptable WBM. (Courtesy of

solids is one of the most important factors. Thus, as mud density is increased, MBT must be reduced so that PV does not reach such a high level that it exceeds pump capacity or causes well-bore stability problems.

As shown in Figure 2.4, increasing the mud density from 10 lb/gal to 18 lb/gal requires that the MBT be reduced by half [M-I llc]. Different mud densities require different strategies to maintain the concentration of drilled solids within an acceptable range. Whereas low mud densities may require only mud dilution in combination with a simple mechanical separator, high mud densities may require a more complex strategy: (a) chemical treatment to limit dispersion of the drilled solids (e.g., use of a shale inhibitor or deflocculant like lignosulfonate), (b) more frequent dilution of the drilling fluid with base fluid, and (c) more complex solids-removal equipment, such as mud cleaners and centrifuges [Svarovsky]. In either case, solids removal is one of the most important aspects of mud system control, since it has a direct bearing on drilling efficiency and represents an opportunity to reduce overall drilling costs. A diagram of a typical mud circulating system, including various solids-control devices, is shown in Figure 2.5 [M-I llc].

While some dilution with fresh treated mud is necessary and even desirable, sole reliance on dilution to control buildup of drilled solids in

Drilling Fluid

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:

Vdiiution (bbl drilling fluid/bbl drilled solids) = (100 - Vsolids)/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, VSoiids <5% is desirable, whereas for a density of 18 lb/gal, Vsolids <2 or

3% is best. When Vsoiids = 5%, the equation above gives VdUution = 19 bbl drilling fluid/bbl drilled solids. The cost of this extra drilling fluid (neglecting downhole losses) is the sum of the cost of the drilling fluid itself plus the cost to dispose of it. This dilution cost is generally so high that even a considerable investment in solids-control equipment is more economical.

Solids removal on the rig is accomplished by one or more of the following techniques:

  • Screening: Shale shakers, gumbo removal devices
  • Hydrocycloning: Desanders, desilters
  • Centrifugation: Scalping and decanting centrifuges
  • Gravitational settling: Sumps, dewatering units

Often these are accomplished using separate devices, but sometimes these processes are combined, as in the case of the mud cleaner, which is a bank of hydrocyclones mounted over a vibrating screen. Another important hybrid device is the cuttings dryer (also called a rotating shaker), which is a centrifuge fitted with a cone-shaped shaker; this apparatus is used to separate cuttings from NAF-based muds and strip most of the mud from the cuttings' surfaces before disposal. Additional devices can help to enhance solids-removal efficiency. For example, a vacuum or atmospheric degasser is sometimes installed (before any centrifugal pumps, typically between the shakers and desanders) to remove entrained air that can cause pump cavitation and reduction in mud density. Refer to Chapter 5 on Tank Arrangements for more details.

With the advent of closed loop systems, dewatering of WBMs has received strong impetus, and it has been found useful to add a dewatering unit downstream of a conventional solids-control system [Amoco]. Dewatering units usually employ a flocculation tank—with a polymer to flocculate all solids—and settling tanks to generate solids-free liquid that is returned to the active system. Dewatering units reduce waste volume and disposal costs substantially and are most economical when used to process large volumes of expensive drilling fluid.

Solids-control equipment used on a rig is designed to remove drilled solids—not all solids—from a drilling fluid. As such, the equipment has to be refined enough to leave desired solids (such as weighting material) behind while taking out drilled solids ranging in size from several millimeters to just a few microns. Although such perfect separation of desired from undesired solids is not possible, the advantages offered by the solids-control equipment far outweigh their limitations. Each device is designed to remove a sufficient quantity and size range of solids. The key to efficient solids control is to use the right combination of equipment for a particular situation, arrange the equipment properly, and ensure that it operates correctly. This, in turn, requires accurate characterization of the drilled solids, along with optimal engineering and maintenance of the drilling fluid.

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  • michael
    Why is removing solids from drilling mud so important?
    9 years ago
  • Habte
    How to remove solids from drilling fluid?
    6 years ago
  • tyler
    What operates efficiently in fluids but not in solids?
    6 years ago
  • aristide
    How to separate gold from drilling fluid?
    5 years ago
  • maxima
    How to remove solids from high viscosity fluid?
    5 years ago
  • almaz
    Do solids reduce viscosity of mud?
    3 years ago
  • benjamin
    How to remove plastic viscosity mechanically?
    3 years ago
  • Kathryn
    How to separate solids from fluids?
    3 years ago
  • marcho
    What is Drilled solid?
    2 years ago
  • arianna greece
    Why solids are removed from drilling muds?
    1 year ago
  • Whitney
    How do you test for acid insoluble particles in drilling fluids?
    1 year ago
    How to densify fluid with a solid?
    1 year ago
  • billy white
    How too seperate oil from solids?
    1 year ago
  • Derek Mosley
    How to flocculate high solids mud systems?
    11 months ago
  • fiyori
    How to separate mud oil water?
    10 months ago
  • Aoife
    What is the optimal gforce to remove low gravity solids for drilling mud?
    8 months ago
  • isembard
    How to separate solids by
    7 months ago
    Why is drilling fluid separation important?
    11 days ago

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