Download - IDPT - 06 - Blow-Out Prevention System
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Well ControlPM
WELL CONTROL
IPM IDPT
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Hydrostatic Pressure
In w hich vessel is the hydrostati c pressure the highest
They are the same in all cases
BECAUSE
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Hydrostatic Pressure
Hydrostat ic Pressure is a function of verti cal depth and densit y
Hydrostat ic pressure in a w ell = 0.052 x TVD x M ud W eight
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Hydrostatic Pressure
6240 psi 7800 psi 5616 psi 6058 psi
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Hydrostatic Pressure
6240 psi 5616 psi
6000 psi 6000 psi
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Causes of Kicks
There are 5 major causes of kicks
1. Fai lure to f i ll the hole2. Sw abbing
3. Lost Ci rculat ion4. Insuf f ici ent mud we ight5. Loss of riser dri l l ing f luid column
But in al l cases it is because of hydrostat ic pressure < format ion pressu
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Kick DetectionA kick cannot occur w ithout a w arning sign or variations w ith return flow
Important warning signs are• Increase in return f low
• W el l f low ing w i th pumps of f• Increase in p it volume• Hole not t aking correct volume w hile POOH
Also consider• Dri l l ing BREAKS
• Decrease in pump pressure• Increase in pump strokes• Change in dr i ll ing f luid propert i
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Kick Detection Equipment
Increase in return f low – Flow showW ell f low ing w i th pump of f – visual or f low show
Increase in pit volume – pit volume tot alizers (PVT)Hole not t aking correct volume – Trip Tank
Drill ing Breaks – can be seen by dril ler or dril l ing graphs
Pump pressure decrease – pressure gauge
M ud pump speed – SPM gauge
Dril l ing f luid properties – detected by mud w atcher during testing
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Kick Detection Equipment
W hat is the most important piece of w ell controlequipment on the rig?
The Trip Tank
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Flow Checks
Involves physically checking the l evel of fl uid in the annulus
Flow check are to be done• Af ter dri l ling break
• Just before pul l ing bi t off bottom prior to a tr ip
• At the last casing shoe• Prior to pul l ing the BHA out of the hole
AND
ANY TIM E THERE IS A DOUBT
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Kick Containment
The size and severit y of a kick depends upon
• the degree of underbalance
• the format ion permeabil i ty• the length of t ime the w el l remains underbalanced
Any suspected kick should be shut in as fast as possible
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Shut in Procedures
Depends on w hich operation is taking place
Drill ing, t ripping, casing, etc
Depend on t he type of stack (surface or sub sea)
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BOP Equipment
Consists of 4 main components
1. The BOP stack
2. The accumulator uni t
3. The choke manifold
4. The ki l l l ine
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BOP Stack
The BOP stack is located over the w ell head and under drill fl oor in surface BOP’s
They might include
• Annular preventer• Pipe ram preventer
• Dri ll ing spool• Bl ind/shear ram preventer• Casing head housing
The stack is assembled i n many arrangements depending upon requirements
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BOP Stack
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Annular Preventer
Are available in dif ferent sizes, makes and pressure rati ngsAl l contain a steel reinforced rubber packing that close around tubulars
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Ram Preventers
Ram preventers close on the dril l pipe by moving rams f rom a retracted posit ionThey operate in pairs and seal the space below them w hen closed
They have openings that match the diameter of pipe for w hich they are designedAlso come in dif ferent sizes, makes and pressure ratings
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Ram Preventers
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Accumulator
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Accumulator Bottle
Bladder Assembly
Shell
Fluid Port Assembly
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Accumulator Sizing
PRECHARGE VOLUME ATACCUMULATOR
OPERATING PRESS
MIN OPER PRESS 200psi ABOVE
PRECHARGE PRESS
USABLE
VOLUME
- MOST ALL MODERN ACCULULATORS ARE 3000 psi WORKING PRESSURE
N
o n - F l a m m a b l e G a
s
1200 psi
1000 psi
A c c u m u l a t o r
F l u i d
3000 psi
A l t Si i
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Accumulator SizingSLB STANDARD
ECIFICATION:
Close all (rams and annul ar) functions and Open all HCRs valves
Open all (rams and annular) functions and Close all HCRs valves
Close AnnularOpen choke line remot e operated valve
he accumulat or volume of the BOP system sould be sized to keep a remaini ng stored
ccumulat or pressure of 1380 kPa (200 psi) orore above the minimum recommended
recharge pressure aft er conducting the
llow ing operations (w ith pumps inoperative):
TOP RAMS
BLIND RAMS
BOTTOM RAMS
ANNULAR
BOTTOM RAMS
1
65
32
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Accumulator Sizing
Calculation of Usable (Bottle) Volume
1.676.670Liquid Vol
10,00010,00010,000P x V
8.333.3310Gas Vol
120030001000Pressure
UseableOperatingPre-Charge
UV =6.67 – 1.67
UV =5
12 3
N o n - F l a m m a b l e G a s
3000 psi
1200 psi
1000 psi
A c c u m u l a t o r
F l u i d USABLE
VOLUME
A l t Si i
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EXAMPLE:
BOP Equipment: 1 Annular + 3 Rams +HCR Valve
Usable Volume (UV): = 133 Gal
Closing Volume (CV): 20 + (3 x 10) + 1 = 56 Gal
Nominal (Bottle) Volume (NV): 2 x UV = 266 Gal
Opening Volume (OV): 20 + (3 x 10) + 1 = 56 GalClosing Volume (CV): 20 = 20 GalOpen Choke Line Valve (OV): 1 = 1 Gal
Accumulator SizingSLB STANDARD
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Choke Manifoldn assembly of HP flanged f it t ings
everal lateral outletstt ached to the BOP stack w ith choke line
hoke helps to maintain back pressure
his prevents further inf luxhe fluid from w ell can be diverted
he choke is operated manuall y or remotely choke panel is usually on rig f loor
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1 2 3 4
5 76
8 9 10
11 12 13
From Choke line
Choke Manifold
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Inside BOPKel ly Cock or FOSV
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Inside BOPGray Valve
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Float Valves
SPECIFICATION:
Prevent sudden inf lux entry into the dril l st ring
Prevent back flow of annular cuttings from plugging bit nozzles
ither plain or ported f loats are acceptable
Float valves must be used w hile dril ling and opening hole prior to sett ingsurface casing or any time the posted w ell control plan is to divert and can
also be used in deeper sections of t he hole. They:
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From Choke I m p i n
g e m e n t
P
l a t e
Baffle Plates
1. Diameter and length controls theamount of pressure in separator
2. Height and diameter and internaldesign control separation efficiency
Drain Linew/Valve
Vent Line
No Valves!!
MUD
G A S
3. Height of ‘U’-Tube (D) and distance frombottom of separator to top of ‘U’-Tubecontrols fluid level and stops gas from goinout of the bottom
S
i p h o n B r e a k e r
D
d N o V a l v e
s ! !
Mud
Mud Gas Separator
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Mud Gas Separator
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Kill Line
At tached to the BOP stack
Usually directly opposite choke line
Used to pump fl uid into t he annulus to either
• keep hole ful l during losses• to keep balance w ith heavy mud
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To manifold
From Dowell Unit
1 2 3 4
5 76
8 9 10
11 12 13
From Choke line
To Poor Boy
essure Test Procedure
ake sure hole is full
ressure Test Dowell surface lines
lose shear rams
ll kill line valves open, all choke line valves open
essure Test Choke Manifold:
• 8 - 11 - 12 - 13 CLOSED
• 1 - 2 - 3 - 4 - 5 - 6 - 7 - 9 - 10 OPEN
• 5 - 7 - 9 - 10 - 12 CLOSED
• 1 - 2 - 3 - 4 - 6 - 8 - 11 - 13 OPEN
• 6 - 1 - 4 CLOSED
• 2 - 3 - 5 - 7 - 8 - 9- 10 - 11 - 12 - 13 OPEN
• 2 - 3 - 6 CLOSED• 1 - 4 - 5 - 7 - 8 - 9- 10 - 11 - 12 - 13 OPEN
- All Choke Manifold valves open
- Close choke line outside valve and pressure test
- Reopen Choke Line outside valve - END DOWELL
- Reopen shear rams
- Pick up 1 jt HWDP
- Close Annular
- Open Dowell valve
- Close Kill Line inside valve, close Choke Line Middle valve and pressur
test
- Reopen Kill Line inside valve, reopen Choke Line Middle valve
- Close Kill Line outside valve, Close HCR valve and pressure test
- Reopen kill Line outside valve, Reopen HCR valve
- Reopen Annular
- Close pipe ram and pressure test
All pressure tests 500 psi low, 1000 psi high, 5 minutesValves 1 and 4 on choke manifold only to 500 psi
BOP Test
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Testing BOP’s
Choke
Manifold
TOP RAMS
BLIND RAMS
BOTTOM RAMS
ANNULAR
BOTTOM RAMS
Kill Line
Wellhead
Test Pump
1
65
4
7
8
3211
10
9 12
1
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Testing BOP’s
Wellhead
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Testing BOP
Plug Type Tester
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Testing BOP’s
Choke
Manifold
TOP RAMS
BLIND RAMS
BOTTOM RAMS
ANNULAR
BOTTOM RAMS
Kill Line
Wellhead
Test Pump
1
65
4
7
8
3211
10
9 12
1
i O
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Testing BOP’s
Choke
Manifold
TOP RAMS
BLIND RAMS
BOTTOM RAMS
ANNULAR
BOTTOM RAMS
Kill Line
Wellhead
Test Pump
1
65
4
7
8
3211
10
9 12
1
T i BOP’
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Testing BOP’s
Cup Type Tester