1_BOP_Pressure test, specifications, standards.ppt

Blowout Preventor

1. BLOWOUT PREVENTER
Why Blowout Preventer are used?
•Kick : An influx of formation fluid into the wellbore
Выброс: Приток пластовой жидкости в ствол скважины
•Blowout : An uncontrolled flow of well fluids and/or
formation fluid from the wellbore or into lower pressured sub-
surface zones (underground blowout)
Фонтан: Неконтролируемый поток скважинных флюидов и / или
пластового флюида из ствола скважины или в зоны
подповерхностей с более низким давлением (подземный выброс)
•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.
…………… Позволяет скважине запечатывать, чтобы
ограничить скважинные флюиды в стволе скважины .
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: Выбор BOP
определяется следующими факторами:
• Maximum anticipated surface pressure. Максимальное
ожидаемое поверхностное давление.
• Size of casing, casing hanger, bit and other drilling tools to be
lowered through the BOP stack. Размер колонны, хангера для
обсадной колонны, долота и другие инструменты проходящие
через сборку ПВО.
• Space available between top of cellar pit and bottom of rotary
table. Пространство между шахтой и роторным столом .
• Matching flange connection according to the size and pressure
rating of wellhead flange. Соответствие фланцев в соответствии
с размером и давлением фланца устья скважины.
• Service conditions. Условия обслуживания.

3. 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. Максимальное давление, которое
оборудование может выдерживать (содержать) и контролировать.
Shell Test or Manufacturer Test or Body Test:
•Only once in the factory (1 раз на заводе)
•2M, 3M, 5M – 2 TIMES the RWP(rated working pressure)
(2 раза Номинальное рабочее давление)
•10M and above – 1.5 TIMES the RWP
BOP SPECIFICATION

4. BOP SPECIFICATION
•Closing Ratio =
•Min. Pr. Required to close =
•Opening Ratio =
•Min. Pr. Required to open =
Well Bore Pressure
Pr. Required to close
RWP
Closing Ratio
Well Bore Pressure
Pr. Required to open
RWP
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.

6. BASIC BOP OPERATION

7. CLOSING OF RAM BOP
Front packer sealing against pipe
Top seal energized by well bore
pressure at sealing surface of the
ram body
Well Pressure
Closing
chamber
Opening
chamber

8. CLOSING OF RAM BOP
Well Pressure
TOP SEAL
STEEL PLATE
PACKER RUBBER
RAM BLOCK
STEEL PLATE PUSHED BY
OTHER SIDE PACKER
STEEL PLATES

9. BLOCK ASSEMBLY

10. BLOCK ASSEMBLY

11. HYDRIL RAM PREVENTER

12. CAMERON RAM PREVENTER

13. RAM BOP SPECIFICATION
RAM BLOWOUT PREVENTER
MAKE MODEL BORE SIZE(INCHES)
MAX. WORKING
PRESSURE(PSI) CLOSING RATIO(C.R)OPENING RATIO(O.R.)
CAMERON
U-PIPE
 
 
7-1/16 ALL 6.90:1 2.20:1
11 15000 9.80:1 2.20:1
13-5/8 15000 10.60:1 3.60:1
U-SHEAR
 
11 15000 15.20:1 3.70:1
13-5/8 15000 10.80:1 4.50:1
HYDRIL
 
 
 MANUAL LOCK PIPE
 
 
7-1/16 3000/5000 4.80:1 1.50:1
7-1/16 10000 7.70:1 1.70:1
11 3000/5000 6.00:1 2.00:1
11 10000 6.90:1 2.40:1
13-5/8 3000/5000 4.80:1 2.10:1
13-5/8 10000 10.20:1 3.80:1
 MANUAL LOCK SHEAR PIPE
 
11 3000/5000 5.60:1 4.20:1
11 10000 11.70:1 4.00:1
13-5/8 3000/5000 10.10:1 4.70:1
13-5/8 10000 10.20:1 3.80:1
MULTI POSITION LOCK PIPE
 
 
 
7-1/16 3000/5000 5.40:1 1.60:1
11 10000 8.20:1 1.70:1
13-5/8 5000 5.20:1 2.10:1
13-5/8 10000 10.60:1 3.80:1
MULTI POSITION LOCK SHEAR
PIPE
 
 
 
11 3000/5000 6.00:1 4.20:1
11 10000 12.40:1 4.00:1
13-5/8 3000/5000 10.60:1 4.70:1
13-5/8 10000 10.60:1 3.80:1
SL w/14"
 
 
 
 
7-1/16 10000/15000 13.90:1 7.14:1
11 10000 7.11:1 7.62:1
11 15000 7.11:1 2.80:1
13-5/8 5000 10.85:1 10.02:1
13-5/8 10000 7.11:1 2.14:1

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.
Может закрываться вокруг различных форм, таких как
квадратный и шестиугольный келли, бурильные ошейники,
инструмент и т. Д., Включая проводную линию.
• Can not close on stabiliser, bit and under reamer.
• Can close on open hole.

15. Wear Plate
Element Segment
Packing Element
Latched Head
Opening Chamber
Piston
Closing Chamber
Piston Seals
ANNULAR BOP
Piston Indicator Hole

16. CLOSING SEQUENCE OF ANNULAR BOP

17. ANNULAR BOP SPECIFICATION
ANNULAR BLOWOUT PREVENTER
MAKE

MODEL BORE SIZE(INCHES) MAX. WORKING PRESSURE(PSI)
MH KOOMEY N
7-1/16 5000
7-1/16 10000
HYDRIL
GK
7-1/16 5000
7-1/16 10000
11
5000
11 10000
13-5/8 5000
13-5/8 10000
GL 13-5/8 5000
CAMERON D
7-1/16 3000/5000
7-1/16 10000
11 3000/5000
11 10000
13-5/8 3000/5000
13-5/8 10000
SHAFFER S
7-1/16 3000/5000
7-1/16 10000
11 5000
11 10000
13-/58 5000
13-5/8 10000

18. •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 Время срабатывания каждого оборудования
должно быть в пределах, указанных 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 Зафиксированное
окончательное давление аккумулятора после того, как все
функции должны быть не ниже 1200 фунтов на квадратный дюйм
или 200 фунтов на квадратный дюйм выше предварительно
заряженного давления аккумулятора, который когда-либо был
максимальным
•At least once in a week
FUNCTION TEST

19. •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
FUNCTION TEST PROCEDURE

20. RIG
WELL
BOP STACK DETAIL
DATE
PROJECT
1. Annular BOP
2. Single & Double ram type BOP
3. Upper pipe ram size
4. Lower pipe ram size
Sl. No.DescriptionFunctionTimeAccumulator
Initial Pressure
Accumulator
Final Pressure
Remarks
1. Annular
2. Lower pipe
3. Upper pipe
4. Blind/Shear
5. Hyd. Valve on
Choke line
6. Hyd. Valve on
kill line
BOP FUNCTION TEST REPORT

21. (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.
BOP PRESSURE TEST

22. PRESSURE TEST
•To check the integrity of all the joints in BOP stack, BOP
seals and Valves.
•Clear water is considered (считается) 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 (Перед спуском или
после установки)
•After repairs – Limited to the affected component
•Not to exceed 21 Days
BOP PRESSURE TEST

23. TEST EQUIPMENT

24. PRESSURE TESTING
CUP TESTER TEST PLUG
The cup of the tester gives
effective sealing in the casing
Designed to seat in well head
and seal
Limited to 70-80% of the burst
of upper part of casing
Can be tested up to RWP of
Ram BOP
Yield strength of drill pipe
may limit the test pressures.
rams
Different makes of well head
have different types of test
plugs
Can not be used to test blind/
shear blind
Blind/ Shear Blind Rams can
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. Sl.
No.
TYPE OF BOP TEST PRESSURE & DURATION Rem
arks
Low PressureDurationHigh PressureDuration
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
PROJECT: TEST FLUID- WATER/NITROGEN WELL NO.:
RIG: DATE:
TEST EQUIPMENT- TEST PUMP/CEMENTING UNIT

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.