1. BLOWOUT PREVENTER
Why Blowout Preventer are used?
• Kick : An influx of formation fluid into the wellbore
• Blowout : An uncontrolled flow of well fluids and/or
formation fluid from the wellbore or into lower pressured
sub-surface zones (underground blowout)
• Blowout Preventer : An assembly of valves attached
to the casing head that allows the well to be sealed to
confine the well fluids in the wellbore.
Blowout preventer are of two types-
i) Annular BOP
ii) Ram BOP
2. CRITERIA FOR SELECTION OF
BOP
Selection of BOP determined by the following factors:
• Maximum anticipated surface pressure.
• Size of casing, casing hanger, bit and other drilling tools to
be lowered through the BOP stack.
• Space available between top of cellar pit and bottom of
rotary table.
• Matching flange connection according to the size and
pressure rating of wellhead flange.
• Service conditions.
3. BOP SPECIFICATION
Standard Sizes of BOP:
71/16”, 9”, 11”, 135/8”, 16¾”, 18¾”, 21¼”, 26¾”, 28”,
291/2”, 30”
Size refers to - ID, Nominal Diameter, Through bore
Rated Working Pressure (RWP):
2M, 3M, 5M, 10M, 15M, 20M
The maximum pressure that the equipment can withstand
(contain) and control.
Shell Test or Manufacturer Test or Body Test:
•Only once in the factory
•2M, 3M, 5M – 2 TIMES the RWP
•10M and above – 1.5 TIMES the RWP
4. BOP SPECIFICATION
• Closing Ratio = Well Bore Pressure
Pr. Required to close
RWP
• Min. Pr. Required to close = Closing Ratio
• Opening Ratio
Well Bore Pressure
= Pr. Required to open
RWP
• Min. Pr. Required to open Opening Ratio
=
5. RAM BOP
• Ram Preventers are designed to seal the annulus
by forcing two front packing elements which make
contact with each other and seal around the object
in the well bore.
• Pipe Ram : It seals around the well bore and the
fixed size of pipe.
• Blind Ram : It seals around the well if no pipe in the
well bore.
• Variable Bore Ram : It seals around several pipe
sizes depending on the range of variable bore ram.
• Shear Ram : It shear the pipe in the well and seal
the wellbore simultaneously.
7. CLOSING OF RAM BOP
Top seal energized by well bore
pressure at sealing surface of the
ram body Front packer sealing against pipe
Opening Closing
chamber chamber
Well Pressure
8. CLOSING OF RAM BOP
TOP SEAL
STEEL PLATE
STEEL PLATE PUSHED BY
OTHER SIDE PACKER
STEEL PLATES
RAM BLOCK PACKER RUBBER
Well Pressure
14. ANNULAR BOP
A large circular valve used to control wellbore fluid.
• Rounded Elastomer with reinforced steel segments
• Deforms the rubber radially inwards and seals
• Can close around different shapes such as square and
hexagonal kelly, drill collars, tool joint etc including wire line.
• Can not close on stabiliser, bit and under reamer.
• Can close on open hole.
15. ANNULAR BOP
Piston Indicator Hole
Wear Plate
Element Segment
Packing Element
Latched Head
Opening Chamber
Piston
Closing Chamber
Piston Seals
18. FUNCTION TEST
•Performed to verify the component’s intended
operations
•The test should be conducted when the drill string is
inside casing
•Function test should be carried out alternatively from
main control unit/derrick floor panel/auxiliary panel
•Actuation time of each equipment should be within
the limits specified by API RP53
•Recorded final accumulator pressure after all the
functions should not be less than 1200 psi or 200 psi
above the pre charged pressure of accumulator which
ever is maximum
•At least once in a week
19. FUNCTION TEST PROCEDURE
•Record initial Accumulator pressure
•Turn off both electric and pneumatic pumps
•Close Annular BOP and Pipe Ram BOP and
open HCR one by one
•Wait till pressure is stabilized
•Record the closing time (closing time starts from
turning the control lever till pressure stabilized)
•Turn on electrical/Pneumatic pump and open all
the preventer
•Record the opening time
•Record final Accumulator pressure
•Record all the results in the prescribed format
20. BOP FUNCTION TEST REPORT
RIG
DATE
WELL
PROJECT
BOP STACK DETAIL
1. Annular BOP
2. Single & Double ram type BOP
3. Upper pipe ram size
4. Lower pipe ram size
Sl. No. Description Function Time Accumulator Accumulator Remarks
Initial Pressure Final Pressure
1. Annular
2. Lower pipe
3. Upper pipe
4. Blind/Shear
5. Hyd. Valve on
Choke line
6. Hyd. Valve on
kill line
21. BOP PRESSURE TEST
(i) Low Pressure Test : 200 – 300 psi should be applied for a low
pressure test and the period is at least 5 minutes.
(ii) High Pressure Test :
High pressure test for RAMS and auxiliary equipment
High pressure test to rated working pressure of RAMS BOP and
auxiliary equipment OR rated working pressure of your wellhead. Select
the lower number. For example, you BOP is rated for 5000 psi and your
wellhead is rated for 3000 psi. Your high pressure test for the RAMS
BOP and auxiliary equipment must be only 3000 psi.
Pressure duration at least 5 minutes.
High pressure test for Annular Preventer
High pressure test should apply to 70% of rated working pressure or
RAMS test pressure. Select the lower number. For example, you test
your ram at 3000 psi and the annular working pressure is 5000 psi. You
need to test your annular to 3000 psi (70% of annular RWP is 3500
psi).Pressure duration at least 5 minutes.
22. BOP PRESSURE TEST
PRESSURE TEST
•To check the integrity of all the joints in BOP stack,
BOP seals and Valves.
•Clear water is considered as the best test fluid
•A stable low test pressure as well as stable high test
pressure should be maintained for at least 5
minutes.
PRESSURE TEST FREQUENCY
•Prior to Spud or upon Installation
•After repairs – Limited to the affected component
•Not to exceed 21 Days
24. PRESSURE TESTING
CUP TESTER TEST PLUG
The cup of the tester gives Designed to seat in well head
effective sealing in the casing and seal
Limited to 70-80% of the burst Can be tested up to RWP of
of upper part of casing Ram BOP
Yield strength of drill pipe Different makes of well head
may limit the test pressures. have different types of test
rams plugs
Can not be used to test blind/ Blind/ Shear Blind Rams can
shear blind be tested.
25. BOP PRESSURE TEST
1. Run-in 2-3 stands of HWDP
2. Make-up Test Plug
3. Make-up 1 single of 5” D/P
4. Make-up Kelly
5. Open McEvoy valve and keep it in open position
6. Make-up 2” hole fill-up line
7. Close Annular or Ram BOP (whichever is tested)
8. Flushed all the lines(through choke manifold)
9. Start pump and raise pressure to 200 psi
10. Wait for at least 5 mins, observe if any pressure drop.
11. If positive, check for any leakage
12. If negative, increase pressure to 300 psi
13. Repeat step 10 and 11, if negative
14. Increase pressure in increment of 100 psi up to the desired value and repeat
step 10 and 11 after every increment
15. Record the test readings
16. Bleed off pressure.
26. PROJECT: TEST FLUID- WATER/NITROGEN WELL NO.:
RIG: DATE:
TEST EQUIPMENT- TEST PUMP/CEMENTING UNIT
Sl. TYPE OF BOP TEST PRESSURE & DURATION Rem
No. Low Pressure Duration High Pressure Duration arks
Annular BOP
Upper pipe ram
Lower pipe ram
Blind/Shear ram
Choke manifold
Kill manifold
Hyd Valve on choke line
Hyd Valve on kill line
HP Valves on choke & kill
manifold
UKC
LKC
FOSV
Inside BOP
27. IMPORTANT POINTS
• Prior to conducting Pressure Test inform every single person
on Rig i.e. Pre-operation meeting
• Do not allow any person to go near cellar area or below
derrick floor
• Before conducting test, discuss with DIC
• Take care test plug properly sit on well head, preferably test
plug and well head make are same.
• Make sure McEvoy valve is opened before conducting test, as
casing will get pressurized if closed and leakage is there.
• Anchor 2” hole fill-up line properly before conducting test
• Conduct test in presence of at least one experience person
• If pressure test is conducted with test plug, take care of
Riser(as test plug might get stuck during pulling out). Conduct
test, if possible before R/up of Riser.
