Introduction
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.
In this intermediate course, it is designed to focus on practical methods to design a functional
and optimum Drilling fluids solids removal system, best practices, and continuous assessment
methodologies. The course will highlight why solids removal must be optimized, hoe to recognize
solids build on hole problems, and drilling efficiency, and how to look for culprit or design/operational
flaws in the system. Also, 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.
Course Objectives
To enhance the participants’ knowledge, skills, and ability necessary to apply the analysis
procedures applicable for all drilling rigs, large and small, as well as any drilling fluid, and to determine
the optimum drilled solids removal efficiency for each target drilled solids concentration.
By the end of this course, participant will be able to:
- Understand the economics of good solids control and its consequences on mitigating hole
problems.
- Discuss the effects of different types of solids on drilling performance.
- Discuss how to determine the quality and quantity of different solids in a drilling fluid.
- Review of best operating practices and design requirements of solids control equipment, their
proper sequences, and rules of thumbs for weighted and unweighted fluids.
- Review and practice the different methods to assess solids removal efficiencies for each piece
of equipment and for the whole system performance.
- Cover the solids removal system efficiency and optimization.
- Focus on rig auditing, applying corrective measures and their impact on drilling efficiency and
hole problems mitigation.
- Arrange each component of a drilling fluid processing plant for proper performance.
- Evaluate each component of a drilling fluid processing plant (called mud tanks).
- Evaluate the effect of drilled solids on drilling fluid properties.
- Minimize drilling fluid discarded
Who Should Attend?
- Drilling Engineers.
- Drilling Rig Supervisors.
- Tool Pushers.
- Drilling Managers.
- Operating Company Personnel.
- Reservoir Engineers.
Course Outlines:
- 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 Hydro-Cyclones and Centrifuges Separate Drilled Solids.
- How Equipment should be Arranged on a Drilling Fluid Processing Plant.
- Selection of the Proper Centrifugal Pump Impeller.
- Mud Tank Agitation.
- Mud Gun Placement.
- Degasser Operation and Objective.
- Guidelines for Effective Drilled Solids Removal.
- Trip Tank Operation.
- Calculation of Solids Removal Efficiency.
- Evaluation of Mud Cake Compressibility.
- Development of 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.