Solids Control Systems - SCS

Drilled solids in a drilling fluid can, and usually do, cause many problems while drilling wells. Drilling fluids containing excessive drilled solids increase trouble costs or Visible Non-Productive Time [NPT]. These costs are usually easily visible because the drilling rig can no longer drill. Drilling performance can be impacted by drilled solids and, frequently, be unnoticed. This higher drilling cost penalty is frequently accepted as 'normal'. Drilling performance is significantly affected by excessive drilled solids in the drilling fluid and might be considered an Invisible NPT. The Invisible NPT cost can be significantly larger than the Visible NPT. The list of problems created by drilled solids include stuck pipe, lost circulation, excessive wear on expendables, drill string vibration, poor cement jobs, low drilling rates, poor cuttings transport in the annulus, poor log interpretation, formation damage, creating a formation fluid influx by swabbing [even when running casing], and excessive expenditures for waste disposal. Each of these problems will be addressed during the course. Drilled solids are easier to remove when they are large. This means that solids control starts at the drill bit. Cuttings should be removed from beneath the bit as soon as they are generated. 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 few drilled solids. These cuttings must be brought to the surface without tumbling in the annulus. Cuttings transport will be discussed because it is essential for good solids control. 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. The tank arrangements do not have to be changed for different types of fluid if they are properly planned initially. Since hydrocyclones, and other components around a drilling rig, use centrifugal pumps, a discussion of impeller selection will ensure proper performance. The cost of dilution increases if the drilled solids removal efficiency is too low. Excessive dilution results in extra expenditures for the clean drilling fluid and also increases disposal costs. Procedures will be presented to allow calculations of removal efficiency. The economic impact of poor solids equipment efficiency can be very large. Excessive quantities of clean drilling fluid may be required because the proper equipment is not plumbed correctly. 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 NPT and increasing total drilling performance.

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.

You will Learn:

Participants will learn 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 - Waste Management