Page 245 - Well Control for Completions and Interventions

Well Kill, Kick Detection, and Well Shut-In 239

• Formation permeability (K). This is needed to calculate potential
losses and determine if LCM is going to be needed.
• Shut-in tubing head pressure (SITP).
• Shut-in casing head pressure (SICP).
• Tubing fluid type and density including oil/water contact (OWC) and
gas/oil contact (GOC) if known.
• Tubing linear capacity.
• Annulus fluid type and density.
• Casing and liner linear capacity.
• Annulus linear capacity.
• Tubing and casing burst and collapse limits.
• Completion configuration—critical depths:
• Tubing depth, including any changes in diameter.
• Packer depth.
• Depth of circulation ports.
• Type of circulation device (if relevant).
• Depth of seating nipples (if relevant) for barriers.
• Casing configuration and shoe depth.
• Liner top and liner shoe depth (if relevant).
• In sand control screen completions: screen mesh size for sizing LCM.
• Surface well control equipment:
• BOP configuration and working pressure.
• Choke manifold configuration.
• Wellhead configuration and condition.
• Pump capacity, strokes per barrel, and working pressure.
• Fluid storage.
If the well kicks during the completion or workover operation, the
same data would be used to restore control.

7.2.2 Wellbore preparation
When planning a well kill in preparation for a rig assisted workover, con-
sider killing the well before the rig is on location. Substantial cost savings
can be made as the rig is required for less time. Preparatory work can
include:
• Integrity testing of the Christmas tree valves (and sub-surface valve if
fitted).
• Integrity testing of the wellhead valves and seals.
• Performing drift runs to locate any restrictions in the tubing.