Hydraulic Workovers
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Transcript of Hydraulic Workovers
Hydraulic Workovers, HWO
• A hydraulic workover is an intervention accomplished under well pressure and without killing the well. Some snubbing operations, most wireline work and most coiled tubing work is done under pressure, through isolation barriers. The difference with HWO is that the conveyance system allows circulation at higher rates than CT, rotation and heavier pulls than wireline or CT.
• The ability to move pipe under pressure eliminates well kills, damage, cleanup time and loss of production.
• Snubbing is a larger well work segment that may include rig draw-works assistance (mechanical) pipe movement and hydraulic units as well.
– Snubbing – moving pipe against pressure that would push it from the well.
– Stripping – moving pipe when its weight would pull it into the well if released.
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Other HWO Operations
• Hot Tapping – drilling through pipe with isolation and barriers to provide a circulation port to an area with trapped pressure.
• Gate Valve Drilling – provides an opening through a stuck gate valve
• Related Operations
– Freezing the wellhead
– Sealant injection
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Rig Assistance
• Rig draw-works assistance
– Rig or hydraulic jacks
– Slower than hydraulic
– Used for larger pipe – typically casing when running in against a kick or a flow drilled well.
Draw works
Traveling Slips
Floor Sheaves
Tube being moved
BOP and stripper seal
Bottom plug
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Hydraulic Workover Equipment
• Provide pressure and load control of tubulars run in and removed from the well.
• Usually have three or more barriers with contingencies for repair while the job is in progress.
• The bottom of the pipe is plugged while running.
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HWO Job Procedure/Equipment Illustrations
1. Operate within load, pressure and component ratings.
2. Modifications to critical components require engineering authorization and redesign.
3. Pipe guides (or braces) are required when snubbing.
4. BOP stack must meet minimum specific requirements for pressures, repair options and spacing required by couplings and tools.
5. Slips must include both traveling and stationary slips to hold both pipe light and pipe heavy operations. Multiple slips are required for specific operations – pulling stuck pipe, milling, pulling shallow plugs, etc.
6. Daylight may limit operations. 8/25/2015 5
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HWO Job Procedure/Equipment Illustrations
7. Max pull set by safety factor and pipe condition – usually 80% of minimum yield.
8. Max wellhead working pressure is 80% of rated pressure at equipment condition.
9. Modifications to critical components require engineering authorization and redesign.
10. Use hydraulic lock when milling. Do not use clamps when moving pipe or transmitting torque.
11. Pressure test BOP stack and all lines and valves before entering well.
12. Have an open stabbing valve with wrench in the basket.
13. Pumping units must have a relief valve (manned while operating).
14. Kill lines must have a check valve close to the BOP stack.
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Hydraulic Workover Unit
• A ‘Snubbing System’ is basically a well servicing system
capable of running and retrieving jointed pipe under live well
conditions (but not necessarily high pressure).
• A snubbing unit or Hydraulic Workover (HWO) unit can be
used for:
– drilling new wells (underbalanced if required)
– side-tracking existing wells (underbalanced if required)
– completion (underbalanced if required)
– fishing (underbalanced if required)
– gravel packing (underbalanced)
– perforating (underbalanced)
– clean-out (underbalanced)
• Advantage is that the well does not require killing.
• Can carry out some work as a rig as long as tubulars are less
than 103/4” OD.
• HWO Unit useful for pulling CT completions
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Live Well Workovers
• less fluids lost to formation = less damage
• shorter time with well off-line
• less problems with kill fluids
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Components
• A pipe movement system - cable assisted or rig assisted
• A sealing stack of pipe rams that allows passage of tool joints and equipment into and out of a well under pressure.
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A view of the pressure connection tube
between the upper isolation chamber
and the well.
Equipment in the stack
A HWO stack involves several pressure control surfaces and spacer tubes between the pipe rams to allow the passage of tool joints and equipment such as packers and pumps.
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Schematics
from Cudd
Pressure
Control
Hydraulic snubber - top
of stroke.
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1. Close upper or
traveling slips.
2 Open lower or
stationary slips.
3. Activate hydraulic
pressure to pull down
on pipe and force it
into the well.
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Weight Necessary to Pull Wire into a Wellhead
Under Pressure
0
50
100
150
200
250
300
350
400
450
500
0 2000 4000 6000 8000 10000
Well Head Pressure, psi
Weig
ht
Necessary
to
Pu
ll
Wir
elin
e in
to t
he W
ell, lb
s
0.072" Wire
0.092" Wire
0.108" Wire
0.125" Wire
3/16" Wire
5/16" Wire
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Snubbing Pressure vs. WHP and Wire or
Tubing Size
0
5000
10000
15000
20000
25000
30000
35000
40000
45000
50000
0 1000 2000 3000 4000 5000
Well Head Pressure, psi
Sn
ub
bin
g F
orc
e o
r W
eig
ht
Re
qu
ire
d t
o E
nte
r W
ellh
ea
d,
lbs
0.108" Wire
3/16" Wire
1.5" CT
2-3/8" Tbg
2-7/8" Tbg
3-1/2" Tbg
4-1/2" Tbg
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Drill pipe pushed out of
a well by pressure.
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Hydraulic snubber
nearing bottom of
stroke.
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1. Close lower or
stationary slips.
2. Open upper or
traveling slips.
3. Activate hydraulics
to extend cylinders.
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Stop tool joint
immediately above top
pipe ram on snubbing
stack.
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Tool joint above top
ram. System
pressurized below.
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Open upper ram and
pass tool joint into
upper straddled area.
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Close upper ram and
prepare to pressurize
upper straddled area.
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Upper straddled area
pressurized, prepare to
open middle ram.
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Open middle ram
and pass tool joint
into well.
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Sealing against the pipe
• Stripper Friction has several variables – pipe OD, pipe surface condition, lubrication, type of packing, length of packing, etc. In general, for a good seal:
– 500 lb per square inch on a stripper packing
– 1000 lb per square inch on an annular
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General rules of thumb
• It takes about 1 second per 1000 feet (MD) each way for a change in the choke setting to be see as a change in pressure at the pump.
• Max Flow Rate in BPM = 2 x (ID in inches)2
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Description of job
Length of
guns
Location
Depth of well
Surface PSI
TCP guns 33/8” using DHSV
1,200’
Valhall/ N. Sea
13,123
2900
TCP guns 33/8” w/auger system using DHSV
250’
Valhall/ N. Sea
12,467
2755
TCP guns 41/2” w/ aligning knobs using DHSV
500’
Valhall/ N. Sea
14,108
3190
Halliburton Deployment system TCP guns 41/2”
850’
Statfjord B
13,123
1957
Halliburton Deployment system TCP guns 41/2”
1,100’
Statfjord C
14,108
1812
TCP guns 41/2” using DHSV
450’
Gulfaks B
15,420
1595
TCP guns 41/2” using DHSV
600’
Gulfaks C
15,092
1740
Halliburton Deployment System TCP guns 4 ½”
2,800’
Statfjord B
16,076
3552
TCP guns 4 ½” using DHSV
1,800’
Sleipner
13,780
3045
TCP guns 4 ½” using DHSV
3,200’
Gulfaks B
17,717
2755
TCP guns 4 ½” Using FIV Valve
1,400’
Veslifrik
12,795
2610
Halliburton Deployment System TCP guns 4 ½”
950’
Gulfaks C
13,780
3190
Halliburton Deployment System TCP guns 4 ½”
1,100’
Gulfaks A
13,451
2682
Perforating Guns Run Under Pressure
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