Well Control Equipment siminar for Hawler Drilling Institute in Koya University.

1. Well Control Equipment
Sarwar Salam-QHSE Sup.
Eurasia Drilling Company-EDC

2. Well Control
• Well control;

3. Blowout Preventers
• Blowout preventers (BOPs), in conjunction with
other equipment and techniques, are used to close
the well in and allow the crew to control a kick
before it becomes a Blowout.
• Blowout preventer equipment should be designed
to:
1. Close the top of the hole.
2. Control the release of fluids.
3. Permit pumping into the hole.
4. Allow movement of the inner string of pipe.

4. These requirements mean that there;
• Must be enough casing in the well to Provide an anchor
for the wellhead equipment,
• There must be provision for equipment to close the hole
with or without pipe in well,
• The Equipment must provide for the attachment of lines
for bleeding off pressure (Bleeding Off BOP control lines)
• It must allow pumping into the working string or
annulus.
B. O. Preventer Requirement

5. Preventer Types
Basic types of blowout preventers on drilling
rig are:
• Annular preventers
• Ram preventers
• Rotational preventers
• Diverters

7. API Bulletin D 13

8. Well Control Diagram
• Valve and Tools Drilling
Company, Rig 3 ;
Well Control Equipment Diagram;

9. Koomy unit
• An accumulator or Koomey unit is a unit used to
hydraulically operate Rams BOP, Annular BOP,
HCR and some hydraulic equipment.

10. Chock Manifold

11. Inside preventers
• Kelly cock (Upper and Lower)
• Inside blowout preventer (iBOP)
• Drill pipe float valve, or
• Drop in check valve
• Should be available for use when stripping the drill
String into or out of the hole.
• The valve(s), sub(s), or profile nipple should
Be equipped to screw into any drill string member in use.
(X/O)

12. Well Head
• The wellhead includes
all equipment placed on
top of the well to support
tubulars, provide seals,
and control the paths
and flow rates of fluids.
− All wellheads include at
least;
• − One casing head and casing hanger,
• − A tubing head and tubing hanger, and a
Christmas tree.

13. Testing and Maintenance of surface BOP
• All operational components of the BOP equipment
should be functioned at least once a weak to verify the
component’s intended operations, Function tests may
or may not include pressure tests.
• They should be alternated from the driller’s panel and
from mini-remote panels, if on location.
• Actuation times should be recorded as a data base for
evaluating trends.

14. Thanks For Your
Time and
Attention