Solids Control Systems - SCS

Discipline: Well Construction/Drilling
Level: Specialized
Instructors who teach this course:
  • Mr. Hector C. Moreno
  • Dr. Leon H. Robinson

  • About the course
  • Designed For
  • You will learn
  • Course Content
Drilling fluids containing too many drilled solids increase trouble costs or visible and invisible Non-Productive Time [NPT]. Visible NPT costs are usually easily visible because the drilling rig can no longer drill. Invisible NPT can be more expensive because it relates to drilling performance, excessive volumes of drilling fluid because of dilution requirements, as well as cementing problems. Cement barriers often fail because of poor filter cake quality during well production. Each of these problems will be addressed during this course.

All drilling fluid surface treatment systems should have three identifiable sections: Suction, Addition, and Removal. The suction section must blend the fluid so that the mud weight in the drill pipe is the same from top to bottom. Well control procedures demand it. Tank volumes, agitation, mud guns, and additional procedures are discussed to insure a homogeneous fluid.

Drilled solids are easier to remove when they are large. Solids control starts at the drill bit. Failure to remove the cuttings results in regrinding by the next row of bit teeth and decreases drilling rate. Cuttings removal from beneath the drill bit is improved by using drilling fluid containing fewer drilled solids. Removal of drilled solids require an understanding of the performance of shale shakers, hydrocyclones, mud cleaners, and centrifuges. These are discussed in great detail. An improperly plumbed drilling fluid surface system can prevent this equipment from performing their proper functions.

Analysis procedures applicable for all drilling rigs, large and small, as well as any drilling fluid, will be discussed. Procedures will be presented to determine the optimum drilled solids removal efficiency for each target drilled solids concentration. This course provides relatively simple guidelines for eliminating most of the visible and invisible NPT, and increasing total drilling performance and significantly decreasing cost.
Only people interested in eliminating non-productive time while drilling; such as: drilling engineers, drilling rig supervisors, tool pushers, drilling managers, operating company personnel and reservoir engineers.
How To:
  • Evaluate the effect of drilled solids on the total cost of a well
  • Remove drilled solids expeditiously from beneath the drill bit (solids control starts at the bit)
  • Transport drilled solids to the surface
  • Arrange each component of a drilling fluid processing plant for proper performance
  • Evaluate each component of a drilling fluid processing plant (called mud tanks)
  • Determine the Equipment Solids Removal Efficiency of the system
  • Understand the new API RP 13C (Solids Control)
  • Evaluate the effect of drilled solids on drilling fluid properties
  • Minimize drilling fluid discarded
  • Analysis of different aspects of drilling which are affected by drilled solids
  • Solids transport capabilities of a drilling fluid
  • How shale shakers separate drilled solids
  • The new API shaker screen designation and how it works
  • Types of motion of shale shakers
  • How hydrocyclones and centrifuges separate drilled solids
  • How equipment should be arranged on a drilling fluid processing plant
  • Selecting the proper centrifugal pump impeller
  • Mud tank agitation
  • Mud gun placement
  • Degasser operation and objective
  • Guidelines for effective drilled solids removal
  • Trip tank operation
  • Calculating Solids Removal Efficiency
  • Evaluating mud cake compressibility
  • Developing a thin, slick compressible filter cake in a well bore, drilling a well bore which allows casing to be moved while cementing, maintaining a homogeneous fluid to fill drill pipe (important for well control)