Uncontrolled copy
Schlumberger Procedures
July 2000
WELL TESTING
PROCEDURES MANUAL
Testing
Schlumberger Private
Rev
Date
Draft
Description
Originator
Reviewed
Approved
Uncontrolled copy
Schlumberger Procedures
July 2000
CONTROLLED COPY REGISTER
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Schlumberger Private
Uncontrolled copy
Schlumberger Procedures
July 2000
INDEX
1. RIG SPECIFIC PROCEDURES................................................................. 5
2. SURFACE TESTING ................................................................................. 6
Schlumberger Private
2.1
CHOKE MANIFOLD ..........................................................................................................6
2.1.1
Single Block ..........................................................................................................6
2.1.2
Double Block .......................................................................................................11
2.2
STEAM EXCHANGER .....................................................................................................15
2.2.1
General ...............................................................................................................15
2.2.2
Function Test At Wellsite ....................................................................................15
2.2.3
Directing Flow Through Coil................................................................................16
2.2.4
Directing Steam Supply.......................................................................................17
2.2.5
Choke Change Procedures.................................................................................18
2.3
SEPARATOR .................................................................................................................19
2.3.1
General ...............................................................................................................19
2.3.2
Function Test at Wellsite ....................................................................................20
2.3.3
Separator By-Passed ..........................................................................................21
2.3.4
Separator Start Up ..............................................................................................22
2.3.5
By-Passing the Separator ...................................................................................24
2.3.6
Separator Operating Procedure Check List ........................................................25
2.4
BURNER AND BOOM .....................................................................................................29
2.4.1
General ...............................................................................................................29
2.4.2
Burner Operating Procedures .............................................................................29
2.4.3
Switching Flare Booms .......................................................................................31
2.4.4
Burner Shut Down...............................................................................................32
2.4.5
Boom Assembly and Disassembly Procedures ..................................................33
2.4.6
Boom Hanging Procedure...................................................................................34
2.4.7
Boom Removal Procedure..................................................................................35
2.5
PIPEWORK ASSEMBLY PROCEDURES ............................................................................36
2.5.1
General ...............................................................................................................36
2.5.2
Weco Type Pipework ..........................................................................................36
2.5.3
Flanged Type Pipework ......................................................................................38
2.5.4
Techlok Clamp Type Pipework ...........................................................................40
2.6
PRESSURE TEST PROCEDURES ....................................................................................41
2.6.1
Pressure Test Surface Equipment......................................................................41
2.7
SAMPLING PROCEDURES ..............................................................................................46
2.7.1
Sampling - Trace Element Detection ..................................................................46
2.7.2
Sampling - Gas Gravitometer (Ranarex) Procedure...........................................48
2.7.3
PVT Surface Sampling........................................................................................49
2.7.4
Dead Oil Sampling ..............................................................................................50
2.8
EMERGENCY SHUT DOWN SYSTEM ...............................................................................52
2.8.1
General ...............................................................................................................52
2.8.2
Emergency Shut Down (ESD) Procedures .........................................................53
2.8.3
Function Test ......................................................................................................54
2.9
DATA ACQUISITIONS .....................................................................................................55
2.9.1
Data Acquisition Procedures...............................................................................55
2.9.2
Operating Procedures .........................................................................................56
2.10 TRANSFER PUMPS........................................................................................................56
2.11 SURGE TANKS .............................................................................................................57
2.11.1 General ...............................................................................................................57
2.11.2 Function Testing .................................................................................................58
2.11.3 Operating Procedure...........................................................................................59
Schlumberger Procedures
July 2000
3. WELL PERFORMANCE AND WELL CONDITIONS.............................. 60
3.1
FLOWING PROCEDURES ...............................................................................................60
3.1.1
Data Monitoring Requirements ...........................................................................60
3.1.2
Perforating Flow and Initial Shut-In Procedure ...................................................63
3.1.3
Initial Flow Clean-up Procedure ..........................................................................64
3.1.4
Initial Shut-in Period ............................................................................................67
3.1.5
Downhole Build-up Procedure ............................................................................69
3.1.6
Surface Build-up Procedure................................................................................70
3.2
HOSTILE WELL CONDITIONS .........................................................................................71
3.2.1
Common Surface Testing Problems...................................................................71
3.2.2
Foaming Prevention Procedures ........................................................................72
3.2.3
Water Emulsion Breaking Procedure..................................................................73
3.2.4
Hydrate Inhibition ................................................................................................74
3.2.5
Sand Control .......................................................................................................76
3.2.6
Hydrogen Sulphide (H2S) Well Testing ..............................................................80
3.3
CONTINGENCY PROCEDURES ........................................................................................87
3.3.1
Downhole Leaks..................................................................................................88
3.3.2
Downhole Test Tool Failure ................................................................................89
3.3.3
Hydrates..............................................................................................................90
3.3.4
Stuck Wireline.....................................................................................................92
3.3.5
Surface Leak Procedure .....................................................................................93
3.3.6
Unexpected H2S Procedures .............................................................................95
4. SPILLAGE PREVENTION....................................................................... 96
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4.1
GENERAL .....................................................................................................................96
4.2
WHILST SAMPLING .......................................................................................................97
4.3
WHEN RIGGING DOWN SURFACE LINES AND EQUIPMENT. .............................................98
4.4
DURING BURNER OPERATIONS .....................................................................................99
4.4.1
Preparation..........................................................................................................99
4.4.2
Operating Procedure.........................................................................................100
4.4.3
When Switching Flare Booms...........................................................................101
4.4.4
During Burner Shut Down. ................................................................................102
4.4.5
Operating Guidelines ........................................................................................103
Schlumberger Procedures
July 2000
1. RIG SPECIFIC PROCEDURES
Schlumberger Private
Page 5 of 103
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Schlumberger Procedures
July 2000
2. SURFACE TESTING
2.1 Choke Manifold
2.1.1 Single Block
A.
General
a.
Once the Choke Manifold is in situation it should be:
i)
ii)
b
Checked for Damage.
A FIT carried out.
The Choke Manifold should be rigged up in such a manner that it
can be operated:
i)
ii)
iii)
No Valves or Instruments should be rigged up prior to Final Hook
Up.
Note:-
B.
Prior to any work being performed on the Choke Manifolds, It
is imperative that isolation is secured Upstream and
Downstream.
Function Test at Wellsite
Preparation
i)
ii)
iii)
C.
All Valves are to be functioned and the number of Turns
Noted.
Choke boxes and Choke threads inspected for damage
and debris.
Pressure test the Choke Manifold on the Deck, prior to
lifting it into the Test Site, as per the following
guidelines.
Operating Procedure
a.
b.
c.
d.
The Choke Manifold should be moved to a Safe area, prior to
performing Pressure Testing Sequences. The area should be
cordoned off.
Fit all Bleed off Valves, Test Plugs and assemble the Test
Manifolds.
Fit Adjustable Choke Seat and Tip Assembly and check that the
choke zeros correctly without jamming closed..
i)
Connect Pressure Test Pump to the front of the Choke
Manifold.
ii)
Purge all air from the System.
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c.
Safely.
Efficiently.
Monitored from all angles with relative ease.
Schlumberger Procedures
July 2000
e.
f.
g.
h.
j.
D.
Perform Body test, against the Test Plug, with Valves 'open', to
5000 psi.
Close' Back Valves and bleed off pressure to 5000 psi.
Bleed off pressure, 'open' Back Valves and 'close' Front Valves.
Pressure test the Front Valves to 5000 psi.
Bleed off all pressure and 'open' Valves.
Well Start Up Through Adjustable Choke
a.
General
i)
b.
The Adjustable Choke is used mainly for beaning up
Wells during their unstable state, so as 'minimal' Valve
operations are needed in order to establish the correct
Choke the Well can be flowed for longer durations.
Preparation
i)
Ensure the Surface Equipment Downstream of the Choke
Manifold have their respective Valves 'open' for the flow
to be directed to the appropriate Flare/Burner or Tank.
The Adjustable Choke should be set at:
ii)
iii)
iv)
All Bleed Down Valves should be 'closed'.
Both Upstream and Downstream Valves on the Fixed
side of the Choke Manifold should be 'closed'.
Flow source Valves are lined up and fully 'opened' to the
Front of the Choke Manifold.
v)
Note:-
c.
A selected Small Choke 8/64"
The Fixed Choke Box should be installed with a
Choke Bean of expected Flow Period, size.
if there is a possibility of Hydrate Formation, then a
Chemical Injection for Hydrate Inhibition should be
started, just prior to 'Opening' the Well.
Operating Procedure
i)
Check Downstream Valve on the Adjustable side of the
Choke, is 'open'.
ii)
1.
2.
iii)
iv)
'Open' the Upstream Valve on the Adjustable
side of the Choke.
Immediately observe the Upstream and
Downstream pressure response.
If the Choke appears to be plugged, or there is no
appreciable response in pressure drop. Cycle the Choke
to ensure the Flow Path is clear.
The Well should now be observed flowing through the
System and can be beaned up according to requirements.
Note:- The pressure Upstream and Downstream of the Choke
Manifold is to be monitored at regular intervals and
observed at all times during Choke variations.
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1.
2.
Schlumberger Procedures
July 2000
Note:-
E.
if there is a possibility of Hydrate Formation, then a
Chemical Injection for Hydrate Inhibition should be
continued during choke bean up operations
Changing From Adjustable To Fixed Choke
a.
General
i)
b.
Preparation
i)
ii)
iii)
c.
The Fixed Choke should only be used for stable flow
periods and should not be used for cleaning up Wells
unless as a temporary measure if inspection of the
adjustable has to be inspected for any reason.
Two technicians are required for this operation:
One, assigned to the Fixed Side Valve and One, assigned
to the Adjustable Side Valve.
The Fixed Choke bean in the Manifold will have
previously been selected and installed.
Ensure that all Bleed down Needle Valves are 'closed'.
Operating Procedure
Ensure the Downstream Valve on the fixed Choke is
'open'.
ii)
1.
2.
iii)
iv)
It is imperative that at all times during this process the
Upstream and Downstream Choke pressures are observed
constantly. This will confirm that the Flow is being
directed through the desired route.
Once the flow path has been changed from the
Adjustable to the Fixed Choke:
1.
2.
v)
Operator one will start by 'opening' the fixed
choke once this has been established.
Operator two 'closes' the adjustable side
simultaneously.
Close' Downstream Valves on the on the
Adjustable Side.
Bleed off pressure to atmosphere via 'bubble
hose to bucket'.
Once the Upstream and Downstream Valve isolation has
been confirmed. The adjustable Choke Box Bonnet can
be removed to allow inspection of the adjustable Tip and
Seat.
IMPORTANT: two valve isolation is not present therefore
extreme care must be taken when performing these
operations. All pressure must be bleed off between the
isolating valves. If any leaks are observer once the choke
box bonnet is off then the well should be shut in.
Page 8 of 103
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i)
Schlumberger Procedures
July 2000
vi)
Remove the Bonnet retaining cap screws and withdraw
Bonnet from the Choke Box with adjustable Nozzle
assembly.
Insert specific pulling tool and remove Seat from within
the Choke Box.
Inspect Equipment and replace parts if necessary.
Assemble the Adjustable Choke Box Bonnet, zero and
secure with retaining cap screws.
Ensure all Bleed down Valves are 'closed' in readiness for
the next operation.
vii)
viii)
ix)
x)
F.
Changing From Fixed To Adjustable Choke
a.
General
i)
The Adjustable Choke should be used for
1.
2.
3.
b.
Unstable Flow Periods.
For cleaning up Wells
For a temporary Flow route while changing
Fixed Chokes.
Preparation.
ii)
iii)
c.
Two technicians shall be required for this operation:
One, assigned to the Fixed Side Valve.
One, assigned to the Adjustable Side Valve
The adjustable Choke in the Manifold will have
previously been set to the value already installed in the
Fixed side.
Ensure that all Bleed down Needle Valves are 'closed'.
Operating Procedure
i)
ii)
Ensure the Downstream Valve on the Adjustable Choke
side is 'open'.
1.
2.
iii)
iv)
It is imperative at all times during this process the
Upstream and the Downstream Choke pressures are
observed constantly. This will confirm that the Flow is
being directed through the desired route.
Once the Flow path has been changed from the Fixed to
the Adjustable Choke:
1.
2.
v)
Operator will start by 'opening' the Adjustable
Choke. Once this has been established.
Operator two 'closes' the Fixed side Valve
simultaneously.
'Close' Downstream Valves on the Fixed side.
Bleed off pressure to atmosphere via 'bubble
hose to bucket'.
Once the Downstream and Upstream Valve isolation has
been confirmed then the Fixed Choke Box Bonnet can be
removed to allow the new Fixed Choke Bean to be
installed.
Page 9 of 103
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i)
Schlumberger Procedures
July 2000
IMPORTANT: two valve isolation is not present therefore
extreme care must be taken when performing these
operations. All pressure must be bleed off between the
isolating valves. If any leaks are observer once the choke
box bonnet is off then the well should be shut in.
vi)
vii)
viii)
Remove Bonnet Insert specific pulling tool and remove
Choke from within Choke Box.
Insert New Choke tighten down the Bonnet and 'close'
Bleed Valves.
'Open' Back Valve on the Fixed Choke in readiness for
Choke change sequence as per 2.1.1. D. of these
Procedures.
Schlumberger Private
Page 10 of 103
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Schlumberger Procedures
July 2000
2.1.2 Double Block
A.
Choke Manifold Operations
General
i)
ii)
iii)
iv)
B.
Once the Choke Manifold is in place it should be checked for any damage
and a FIT carried out.
The Choke Manifold should be rigged up in such a manner to enable Safe
Operations and efficient monitoring with ease from all angles.
No Valves or Instruments should be rigged up prior to final hook up.
Prior to any work being performed on the Choke Boxes on the Well Test
Manifold it is imperative that isolation is secured Upstream and
Downstream.
Well Site Function Checks
a.
Preparation
i)
ii)
b.
Operating Procedure
i).
ii)
iii)
iv)
The Choke Manifold should be moved to a Safe Area
prior to performing Pressure Testing Sequences. The
Safe Area must be cordoned off.
Fit all Bleed-off Valves and Test Plugs, assemble the
Test Manifold.
Fit the Adjustable Choke Seat and adjust Choke
assembly.
1.
2.
v)
vi)
vii)
viii)
i)
xii)
C.
Connect the Pressure Test Pump to the front of
the Choke Manifold
Purge air from the System.
Perform Body Test against Test Plug with Valves 'open'
to 5000 psi.
Close the first set of Back Valves (inboard) and Bleedoff Downstream Pressure to 5000 psi.
Close second set of Back Valves (outboard) and Bleedoff Downstream Pressure to 5000 psi.
'Close' first set of Front Valves (outboard) and Bleed-off
Downstream Pressure to 5000 psi.
Close second set of front valves (inboard) and Bleed-off
Pressure 5000 psi.
1.
2
Bleed-off pressure
'Open' Valves.
Well Start Up through Adjustable Choke
Page 11 of 103
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iii)
All Valves are to be functioned and the number of turns
necessary Noted.
Choke Boxes and Choke Threads inspected for any
damage or debris.
Pressure Test the Choke Manifold on the Deck prior to
lifting into the Test Site as per the following guidelines.
Schlumberger Procedures
July 2000
a
General
i)
The Adjustable Choke is used mainly for Beaning up
Wells during their unstable state.
To enable minimal Valve Operations in order to establish
the correct Choke the Well can be 'flowed' at for longer
durations.
ii)
b.
Preparation
i)
Ensure the surface equipment Downstream of the Choke
Manifold will have their respective Valves already 'open'
for the flow to be directed to the appropriate
Flare/Burner or Tank.
The adjustable Choke should be set at a selected small
Choke of 8/64" and the Fixed Choke Box should be
installed with a Choke bean of expected Flow Period
size.
All four Upstream and Downstream Valves on the Fixed
side of the Choke Manifold should be 'closed'.
Flow source Valves are lined up and fully 'opened' to the
front of the Choke Manifold.
ii)
iii)
iv)
Note:-
Operating Procedure
i)
Check Downstream Valves on Adjustable side of Choke
Manifold are 'open'.
'Open' the Upstream Downstream Valve then the
Upstream Valve on the Adjustable side of the Choke and
observe the Upstream and Downstream pressure s
immediate response.
If the Choke appears to be plugged or there is no
appreciable response in pressure drop, cycle the Choke to
ensure the Flow Path is clear.
The Well should now be observed 'Flowing' through the
system and can be beaned up according to requirements.
ii)
iii)
iv)
Note:-
The pressure Upstream and Downstream of the Choke
Manifold is to be monitored at regular intervals and
observed at all times during Choke variations.
Page 12 of 103
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c.
If there is a possibility of hydrate formation the Chemical
Injection for hydrate inhibition should be stated just prior
to opening the Well.
Schlumberger Procedures
D.
July 2000
Changing from Adjustable to Fixed Choke
a.
General
The Fixed Choke should only be used for Stable Flow periods and
never used for Cleaning-up Wells.
b.
Preparation
i)
Two technicians will be required for this operation:
One, assigned to the Fixed, Side Valves.
One, assigned to the Adjustable Side Valves
The Fixed Choke bean in the Manifold will have
previously been selected and installed
Ensure that all Bleed-down needle Valves are 'closed'
ii)
iii)
c.
Operating Procedure
i)
ii)
iii)
iv)
1.
2.
v)
Once the Upstream and Downstream Double Valve
isolation has been confirmed. The Adjustable Choke
Box Bonnet can be removed to allow inspection of the
adjustable Tip and Seat.
Remove the Bonnet retaining cap screws and withdraw
the Bonnet with the nozzle assembly from the Choke
Box.
Insert specific Pulling Tool and remove Seat from within
the Choke Box.
Inspect the Equipment and replace parts if required.
Assemble the Adjustable Choke Bonnet Box, zero and
secure with the retaining cap screws. Ensure all Bleeddown Valves are 'closed' in readiness for the next
operation.
vi)
vii)
viii)
ix)
E.
Close' Upstream Downstream Valves and
Downstream Valves on the adjustable side.
Bleed-off pressure to atmospheric via 'Bubble
hose to Bucket'.
Changing From Fixed to Adjustable Choke
a.
General
Page 13 of 103
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Ensure the Downstream Valves on the Fixed Choke side
are 'open' and Upstream Downstream Valve is 'open'
'Open' the Upstream Downstream Valve, then Upstream
Valve on the Adjustable side of the Choke and observe
the Upstream and Downstream pressures immediate
response.
It is imperative that at all times during the process the
Upstream and Downstream Choke pressures are observed
as constant. This will confirm that the Flow is being
directed through the desired route.
Once the Flow Path has been changed from the
Adjustable to the Fixed Choke:
Schlumberger Procedures
July 2000
i)
b.
Preparation
i)
ii)
iii)
c.
The Adjustable Choke should only be used for Unstable
Flow periods for cleaning-up Wells and temporary Flow
Route whilst changing Fixed Chokes.
Two technicians will be required for this operation:
One, assigned to the Fixed Side Valves.
One, assigned to the Adjustable Side Valves.
The Adjustable Choke in the Manifold will have
previously been set to the valve previously installed in
the fixed side.
Ensure that all Bleed-down Needle Valves are 'closed'.
Operating Procedure
i)
Ensure the Upstream Downstream Valve and
Downstream Valves on the Adjustable Choke side is
'open'.
ii)
1.
2.
iv)
It is imperative that at all times during this process the
Upstream and Downstream Choke pressures are observed
as constant. This will confirm that the Flow is being
directed through the desired route.
Once the Flow Path has been changed from Fixed to the
Adjustable Choke:
1.
2.
v)
vi)
vii)
viii)
'Close' Upstream Downstream Valve and
Downstream Valves.
Bleed-off pressure to Atmospheric via 'Bubble
hose to Bucket'
Once the Upstream and Downstream double Valve
isolation has been confirmed then the Fixed Choke Box
Bonnet can be removed to allow the new Fixed Choke
bean to be installed.
Remove Bonnet insert Special Pulling Tool and remove
Choke from within Choke Box.
Insert New Choke tighten down the Bonnet and 'Close'
Bleed-down Valves.
'Open' Back Valves on the Fixed Choke in readiness for
Choke change sequence, as per 2.1.2, D.
Page 14 of 103
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iii)
Operator one starts by 'opening' the Adjustable
Choke, once established.
Operator two 'closes' the Fixed side Valves
simultaneously.
Schlumberger Procedures
July 2000
2.2 Steam Exchanger
2.2.1 General
A
B
C
The Boiler is capable of delivering a maximum steam temperature of 372
deg F, where as the Exchanger Coil and Vessel Design limitations are 250
deg F.
Set the Steam Generator Control Pressure 'Stat' to restrict Steam
Temperature from the Boiler to a maximum of 250 deg F.
Once the Steam Exchanger is in location check for damage to Frame,
Piping Vessel and Instrumentation.
2.2.2 Function Test At Wellsite
A.
Preparation
a.
b.
B.
Well Site Function Test
a
b.
c.
d.
e.
Rig up Temperature Controller and check calibration.
Hook-up Compressed Air supply to Steam Exchanger and check
Air supply.
Function Test the Automatic Control Valve.
Hook-up Steam Supply and Function Test.
'Open' and 'close' all Valves noting the number of turns for each.
Page 15 of 103
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c.
The Steam Exchanger must be situated in such a position so that
Safe Operating Practices can be carried out.
Ensure proper access can be gained for Steam 'supply' and 'return'
lines to be rigged up safely.
Once in position FIT 1 can be carried out and Function Test
performed.
Schlumberger Procedures
July 2000
2.2.3 Directing Flow Through Coil
A.
General
a.
Prior to Start-up of the Well the Exchanger should be:
i)
ii)
B.
Preparation
a
For this particular operation the Steam Exchanger Adjustable
Choke must be inserted and cycled to the 'fully open' position so
as to enable a continuous Flow through the System without any
restrictions.
Note:-
The vessel should be up to temperature before switching flow
through the vessel.
b.
c.
All Bleed-down Valves should be 'closed'.
Install Dial Pressure gauges at the following pressure points. Coil
Inlet Outlet and on the Vessel.
Operating Procedure
a.
b.
c.
d
Ensure that Coil Outlet Valve is 'open'.
Slowly 'open' the Steam Exchanger Inlet Valve, simultaneously
'close' the Bypass Valve.
During this operation the process pressure at the Coil inlet and
outlet should be observed to ensure there is no pressure build-up.
i)
The Valves should be returned 1/4 of a turn from their
respective positions.
Page 16 of 103
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C.
By-passed and remain so until the Cleanup Flow Period
has been completed with no Sand production.
The B.S & W is at a maximum of 2% or less.
Schlumberger Procedures
July 2000
2.2.4 Directing Steam Supply
A.
a.
b.
c.
B.
Once the Process Flow has been established through the Coil, inject Steam
through to the Vessel.
a.
b.
C.
Set (TCV) Temperature Control Valve Control Box to the desired
Steam Temperature.
The TCV will respectively 'close' or 'open' on variation of the
pneumatic signal from the Control Box regulating the Flow of
Steam through the Vessel.
The operator of the Steam Generator 'opens' the Outlet Valve from the
Boiler to deliver Steam to the Exchanger.
Note:-
Any condensate remaining within the Exchanger Vessel will
initially be dispersed out through the Steam Trap until Steam
arrives at the Trap.
Once the Steam requirement is complete:
a.
b.
c.
d.
The Boiler Operator will 'close' the Steam Outlet Valve on the
Boiler to stop the delivery of Steam to the Exchanger Vessel.
The operator will not 'close' the Steam Trap Isolation Valve.
The operator will allow the Exchanger Vessel to cool down.
During the cooling down process the steam will condense and
drain by gravity through the Steam Trap.
Page 17 of 103
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D.
Close Drain Valve on the Steam Return 'Outlet' and 'open' the
Steam Return 'Outlet'
'Open' the Steam Trap Isolation Valve.
Allow any condensate within the System to drain out by gravity.
Schlumberger Procedures
July 2000
2.2.5 Choke Change Procedures
A.
General
When Flowing through the Steam Exchanger the Choke needs replacing.
The following procedure should be followed.
B
Operating Procedure
a.
b.
c.
d.
e.
f.
'Open' the Steam Exchanger Bypass Valve.
'Close' High Pressure Coil Inlet Valve.
'Shut-off' the Steam supply to the Vessel.
'Close' Low Pressure Outlet Valve
'Open' Needle Valve on Choke Box and Bleed off Coil Pressure to
a suitable container to avoid any chance of spillage.
When Coil pressure is observed to be fully bled off undo the
Choke Box Bonnet.
If the Bonnet is difficult to remove, check once again the Coil
Pressure is completely bled off.
g.
h.
j.
k.
l.
m.
Extract the Choke from the Box and replace with a new Choke.
Refit the Choke Box Bonnet and 'close' the Needle Valve.
'Open' Low Pressure Coil Outlet Valve.
Start Steam supply to Vessel.
'Open' High Pressure Coil Inlet Valve
'Close' Steam Exchanger Bypass Valve.
Page 18 of 103
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Note:-
Schlumberger Procedures
July 2000
2.3 Separator
2.3.1 General
A.
Prior to the flow being passed through the Separator:
a.
b.
The Well must be cleaned up through the Separator by-pass.
Until the BS & W solid content is 2% or less.
Schlumberger Private
Page 19 of 103
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Schlumberger Procedures
July 2000
2.3.2 Function Test at Wellsite
A.
General
a.
b.
B.
The main purpose of this function test is to check the operation of
the float versus the ACV operation
If there is no response, it must be assumed the float is damaged or
have moved from its operating position.
Preparation
a.
b.
c.
d.
e.
The compressed Air supply to the Control Instruments should be
'open'.
Check the stroking of all pressure and Level Controller Valves.
Ensure all Daniel Bleed-down Valves are 'closed' and that there is
no Orifice Plate lowered.
'Close' Daniel Slide Valve and Equaliser Valve. 'Open' the Bleeder
Valve at the same time.
i)
ii)
1.
2.
3.
C.
Set Wizard to fully 'open' ACV
Set Leveltrol to detect 'low' level.
All Bleed down Valves must be 'closed'.
Operating Procedure
a.
Pump water from Test Pump to the Gas Flare till returns are
observed..
b.
i)
ii)
iii)
iv)
c.
As the level increases, check operation of the Float by adjusting
the Level Trol.
Continue filling the Separator and checking the leveltrol / float
response.
Prepare to Pressure Test the Separator Vessel.
d.
e.
Open' Separator Inlet Valve.
Open' Gas manual.
'Shut' Oil Outlet.
'Shut' By-pass.
Page 20 of 103
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Schlumberger Private
iii)
All surface equipment to be rigged up and prepared for
Pressure Testing
Line up the Flow Path via the Gas By-pass to the Gas
Flare.
All Instruments to be rigged up and on line.
Schlumberger Procedures
July 2000
2.3.3 Separator By-Passed
A.
Preparation
a.
b.
B.
The surface equipment downstream of the Separator will have
their respective Valves already 'opened' up for the Flow to be
directed to the selected Flare/Burner.
All Bleed-off Valves are 'closed'.
Operating Procedure
Close' the Separator Inlet and Gas By-pass Valves.
b.
i)
ii)
'Open' Separator Oil Line By-pass valve.
'Close' Separator Oil Outlet Valve.
c.
i)
Commence with Cleanup flow to the Burners until
Oil/Gas reaches Surface.
When the System Back pressure at the Separator By-pass
is stabilised, the Cleanup flow should be continued
through the Separator Oil By-pass until stabilised
Flowrate and Tubing Head pressures have been achieved,
and BS&W measurements have fallen to the
recommended acceptable level.
ii)
Page 21 of 103
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Schlumberger Private
a.
Schlumberger Procedures
July 2000
2.3.4 Separator Start Up
A.
B.
General
a.
Upon completion of the cleanup, the flow should be diverted
through the Separator.
Note:-
Two technicians will be required to perform the following.
Preparation
a.
b
c.
d.
e.
f.
g.
All Bleed down Valves must be 'closed'.
All Pressure and Temperature Recorders/Indicators should be
installed and 'opened' on line.
The Compressed Air supply to the Control Instrumentation should
be 'opened'.
Check the stroking of all Pressure and Level Controller Valves.
Ensure all Daniel Bleed down Valves are 'closed' and there is no
Orifice Plate lowered.
'Close' Daniel Slide Valve and Equaliser Valve, 'open' the Bleeder
Valve.
'Close':
h.
If water is being produced in sufficient quantities to measure
i)
ii)
iii)
Set the Water Level Controller
'Open' the Water Line manual Outlet Valve
If no Water is being produced, ensure the Water Line
manual Outlet Valve remains 'closed'.
j.
i)
ii)
Set Oil Level Control Valves to 'closed' position.
'Open' Oil Line Manual Outlet Valve.
k.
i)
Set Gas PCV, set point, to give 15psi output to 'close' the
Valve.
Readjust set point to have the PCV approximately 10%
'open'.
ii)
C.
Oil Meter.
Floco and Rotron Isolation Valves.
Open' the Meter By-pass Valve.
Operating Procedure
a.
b.
c
d.
i)
'Open' Separator Inlet Valve.
ii)
'Open' Gas Outlet Valve.
iii)
Close' Separator Oil By-pass Valve.
Adjust the Separator Pressure to approximately 50% of the desired
Operating Pressure.
i)
Observe Separator for leaks.
ii)
Set the Separator to the required Operating Pressure.
i)
ii)
Stabilise the Oil Level by adjusting the Fisher LevelTrol.
Commence Oil Metering through the selected range of
the meter.
Page 22 of 103
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Schlumberger Private
i)
ii)
iii)
Schlumberger Procedures
D.
July 2000
e.
i)
ii)
'Open' required Oil Meter Valve.
Close' Meter By-pass Valve.
f.
Open' the Barton Manifold Valves to equalise the Pressure across
the Barton.
g.
i)
ii)
Select the desired Orifice Plate.
Remove Carrier Plate as per the following procedures.
Daniel Operating Procedure
a.
b.
c.
d.
e.
f.
The Daniel Side Valve and the Equaliser valve should be 'closed'.
'Open' Bleeder valve and check for Pressure.
Remove the stem from the grease Injector and insert grease stick
into the Injector.
Install Injector stem and slowly inject grease by rotating them.
i)
Loosen the Clamping Bar screws.
ii)
Rotate the Upper Carrier Shaft to free the Sealing Bar
and Sealing Bar Gasket.
Remove
i)
ii)
g.
m.
n.
o.
p.
q.
r.
s.
t.
u.
Note:-
i)
Rotate the Upper Carrier Shaft to lift the Orifice Carrier
Plate.
ii)
Remove the Carrier.
Install selected Orifice Plate.
'Close' Daniel Bleeder Valve.
Fit the Orifice Plate into the Plate Seal and install into Carrier.
Rotate the Upper Carrier Shaft clockwise and lower the Carrier
below the Sealing Bar Gasket level.
Inspect the Sealing Bar and refit using a new Sealing Bar Gasket.
Install the Clamping Bar and tighten the holding screws
methodically.
i)
Open' the Equalising Valve.
ii)
Rotate the Slide Valve Shaft clockwise to 'open' the Slide
Valve.
i)
Rotate the Upper Carrier Shaft clockwise.
ii)
Lower the Orifice Plate Carrier into the Daniel Upper
Body.
i)
Rotate the Lower Carrier Shaft clockwise.
ii)
Lower the Orifice Plate Carrier in the measurement
position in the Lower Daniel Body.
Rotate Slide Valve Shaft counter-clockwise and 'close' Slide
Valve.
i)
'Close' the Equalising Valve.
ii)
Open' Bleeder Valve slowly checking for Pressure.
'Close' Bleeder valve on completion of the Pressure Check.
'Close' Barton Manifold Valves and observe differential pressure
point on the recorder.
The Well should be flowing through the Separator with all
measurement systems functioning.
Page 23 of 103
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Schlumberger Private
h.
j.
k.
l.
The Clamping Bar.
The Sealing Bar and Gasket.
Schlumberger Procedures
July 2000
2.3.5 By-Passing the Separator
A.
General
Two Technicians should be involved with the by-passing procedures to
ensure a smooth and safe operation.
B.
Preparation
a.
b.
c.
d.
e.
f.
g.
h.
j.
k.
l.
m.
Note:-
C.
The Separator is now by-passed, with the flow passing directly
through to the Burners.
If the expected Back Pressure is going to be too high when the
Separator is by-passed, the Well can be shut-in, prior to the
Separator being by-Passed, assuming steps 'a', 'b' and 'c' of the
above procedure have been carried out.
If there are no further Flow Periods, the Separator should be bled
down.
Operating Procedure
a.
b.
c.
'Open' Oil Outlet Manual Valve and bleed off liquid to Burners.
'Open' Gas Manual Outlet valve and bleed off remaining Pressure.
On completion of the above, all Separator Valves should be
'closed' with the exception of the Oil By-pass Valve.
Note:-
Ensure there is an open route to the Flare or the Burners at all
times.
Page 24 of 103
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Schlumberger Private
j.
'Open' Barton manifold valves to equalise the pressure across the
Barton.
Lift the orifice plate and carrier as follows.
'Open 'Daniel Equalised Valve a maximum of two turns.
i)
Rotate slide valve shaft clockwise.
ii)
'Open' slide valve.
Rotate lower carrier shaft counter-clockwise to lift up carrier
plate.
Rotate upper carrier shaft counter-clockwise to lift carrier plate
into the Daniel upper body.
Turn the Slide Valve counter-clockwise to 'close' Slide Valve.
i)
'Close' Daniel Equaliser Valve.
ii)
'Open' slowly the Bleeder Valve to vent off Pressure from
the Upper Body.
Only when the Pressure Isolation has been secured can the
Clamping Bar and seal be removed, as per procedures.
Only when the Pressure Isolation has been secured can the
Clamping Bar and seal be removed, as per procedures.
By-pass the Oil Meter by 'opening' the by-pass Valve and 'closing'
the respective Meter Valve depending on which Meter Range was
selected.
'Open' appropriate Separator by-pass Valve.
i)
'Close' Separator Inlet Valve.
ii)
'Close' Oil outlet Manual Valve.
iii)
'Close' Gas Manual Outlet Valves.
Schlumberger Procedures
July 2000
2.3.6 Separator Operating Procedure Check List
A.
Preliminary Checks
a.
Check the Rupture Disc Pressure against the Separator Working
Pressure.
Rupture Pressure = WP + 10%
b.
Check the Identification Label on the Farris Safety Valve.
Opening Pressure = WP
c.
d.
e.
f.
g.
h.
j.
l.
m.
Check the Supply Pressure to the Pneumatic Controllers:
6-30 psi Controllers - Supply Pressure = 35 psi
3-15 psi Controllers - Supply Pressure = 20 psi
n
o
p.
Set the Proportional Band for both Wizard and Level-Troll
Controllers to 20.
Check that the Bourdon Tube in the Wizard is the desired Range.
Check the colour of the Proportional Band Bellows in the Wizard
and the Proportional Band Bourdon Tube in the Level-Troll.
6-30 psi Controllers - RED
3-15 psi Controllers - BLACK
Page 25 of 103
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Schlumberger Private
k.
Check the calibration of the Static and Differential Pressure.
Wind the Barton Chart and set the Differential Pen to correct time.
If H2S is expected, fill Upper Pots on either side of the differential
pressure unit with light oil.
'Close' Flange Tap connection Valves from the Daniel Orifice
Meter to the Barton Scrubber Pots.
Drain the Barton Scrubber Pots and 'close' the Drains.
'Open' the Equalising Valves on the Barton Differential Manifold.
Check that the Orifice Plate is in the Upper Compartment of the
Daniel.
Check that the Meter By-pass is 'open' and the Meter Valves are
'closed'.
Check that the Instrument Air Supply is on and the Pressure is set
at between 60 and 100 psi.
Schlumberger Procedures
July 2000
q.
Check the full travel of all Automatic Control Valves between:
6-30 psi. 3-15 psi.
r.
s.
t.
u.
v.
Note:-
B.
be sure the travel is in the correct direction
Check that the liquid Sight Glasses are not plugged and that the
Isolation Valves are in the Safety position.
'Close' all Drains and Valves opening to the exterior of the
Separator.
'Open' the Bleed Valve between the Mapegaz Swing Check Valve
and the Farris Safety Valve.
'Open' the Isolation Valve to the Pressure Gauge on top of the
Separator.
Make sure that the Isolation Valve to the Bourdon Tube of the
Wizard is 'open'.
It is useful to check the operation of the Level-Troll when filling
up the Separator for Pressure Test.
Start Up
a.
d.
e.
f.
g.
h.
j.
k.
l.
i)
ii)
iii)
m.
n.
Adjust the Separator to the desired Pressure.
Adjust the Separator Level as desired.
i)
ii)
iii)
p.
The Gas line ACV should be seen to 'open' as the
Separator begins to control.
If Not, 'open' the By-pass Valve.
Check that the Isolation Valve to the Wizard Bourdon
Tube is 'open'.
'Open' the Valve to the Rotron.
'Close' the By-pass.
Check the Flow Rate.
If the rate is less than 3400 bbl's/day, flow through the Floco
Meter.
Page 26 of 103
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Schlumberger Private
b.
c.
Well is flowing through Effluent By-pass on the Oil or Gas line
side.
Separator Inlet Valve, Oil and Gas Outlet Valves are 'closed'.
Set Wizard so the Gas Line ACV is 'just closed' with 30 or 15 psi
Output Pressure.
'Open' the Separator Inlet Valve slowly (fully 'open' after 10
seconds)
If a leak is seen or heard on the Separator Body, 'close' the Inlet
Valve, and investigate.
Allow the Separator to build up to Line Pressure.
(Separator Pressure < Down Stream Choke Pressure)
Check the Gas line ACV. If the Wizard is working correctly it will
be fully 'open' at this time.
Set Wizard so the Gas line ACV is 'just closed' at 30 or 15 psi
output pressure.
Set Level-Troll so the Oil line ACV is 'just closed' at 6 or 3 psi
Output Pressure
'Open' the Oil and Gas Outlet Valves.
While watching the Gas ACV, slowly 'close' the Separator Bypass Valve.
Schlumberger Procedures
July 2000
q.
r.
C.
s.
Slowly 'open' the Flange Tap connections to the Barton.
When the Separator Pressure is Stable, lower the appropriate
Daniel Orifice Plate.
'Close the Barton Differential Equalisation Valves.
Note:-
Check Differential Pressure is between 30-70% of Full Scale.
Choke Change
a.
b.
c.
d.
e.
f.
g.
h.
j.
D.
By-Pass and Shut Down
f.
g.
h.
'Open' Barton Differential Equalising Manifold.
Raise Daniel Orifice Plate.
By-pass Oil Meters.
Lower Separator Level to minimum.
Open Separator By-pass Valve, Oil or Gas, depending on the
Effluent.
'Close' the Separator Inlet Valve.
'Close' the Outlet Valve on the side the Well is by-passed to.
Bleed Separator Pressure from the Outlet on the side where the
by-pass Valve is still 'closed'.
SAFETY - Personnel Safety in case of H2S
a.
It is forbidden to use the Separator Gas to supply the Pilot Circuit
of the Separator.
This is because of leaks which:
i)
ii)
b.
Occur occasionally at the Pneumatic Controller
May occur accidentally.
Personnel MUST wear Protective Masks throughout the
operation.
Especially while:
i)
ii)
iii)
iv)
Performing Surface Sampling
Changing the Daniel Orifices
Operating the Shrinkage Tester
Resetting Operative Limits of the Separator.
e.
f.
"Buddy" System of work must apply at all times.
A MSA re-animation Kit must be available on the site.
Note:-
Schlumberger and Rig Crews must be trained on MSA Kit
operation.
Page 27 of 103
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Schlumberger Private
a.
b.
c.
d.
e.
E.
'Open' Barton Differential Equalising Manifold
Raise the Daniel Orifice Plate.
By-pass Oil Meters.
If operating close to the Upper Limit of the Separator capacity
BY-PASS THE SEPARATOR.`
Change the Choke size.
Return flow through the Separator (if by-passed)
Pass Flow through the Meter.
Once the Separator Pressure has stabilised, lower the Daniel
Orifice Plate.
'Close' the Barton Differential Pressure Equalising Valves.
Schlumberger Procedures
F.
July 2000
g.
In all cases, it is recommended to supply Separator Controls with
Compressed Air.
Note:-
Use of other clean gases (Separator Sweet Gas, Propane or even
Nitrogen) is allowed, only if there is no Compressed Air Supply
available.
h.
The Screws fixing and securing the straightening vane of the Gas
Metering Line must not be confused with a Pressure or
Temperature Pick-up.
Note:-
Accidents have been reported in the past where inexperienced
Operators have unlocked these Screws.
SAFETY - Equipment Safety
a.
b.
c.
Note:-
It is suggested:
1.
To connect the Breather Pipe, not to the flange of the
Rupture Disc, but to house the Rupture Disc Holder into
a Cylindrical Body connected to the Breather Pipe and
resting on the Separator Frame.
2.
To fill up the Annulus of the Rupture Disc Holder and
the Breather Pipe, with loose steel or mineral wool to act
as a Spark Arrestor.
e.
Whenever H2S is expected or suspected. A Lo-Pilot and an
Emergency Shut Down Station must be installed near the
Separator.
Always remove floats of liquid levels and Barton Gas Flow
Recorder during transportation, as floats are easily lost inside the
Separator, if not removed.
DO NOT Pressure Test the Separator with a Daniel Orifice
installed.
Never start-up a Separator with a Daniel Orifice Plate installed.
Check before testing, that the Gas Control Valve of the Separator
is 'open'.
Check that the Oil and Water Valves are 'closed'.
f.
g.
h.
j.
k.
l. Never Clean-up a Well through the Separator.
Page 28 of 103
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Schlumberger Private
d.
Only H2S rated Equipment must be used for Testing Operations.
This is especially necessary for all small items, such as Needle
Valve, Plug, Thermowells, etc.
Use items listed in the FOH III Chapter, General Information.
Regardless of what is written in the Maintenance Manual.
In case of malfunction of the Pressure Safety Valve, a Rupture
Disc fitted ensures additional Safety
Many clients require the outlet of the Rupture Disc to be
connected to a Breather Pipe, landing far away from the site.
A pipe with minimum OD of 4" and a bend radius of 1 Meter must
be used. as the Breather Pipe.
Schlumberger Procedures
July 2000
2.4 Burner and Boom
2.4.1 General
A.
B.
C.
Appropriate Safety Equipment should be worn as per the installations
Safety Procedures.
Ensure with the OIM that the Rigs Ancillary Equipment is covered and
protected from water and heat radiation and that ABB operating policy is
adhered to.
Once Boom installation has been completed operational checks as per FOH
2 FIT 1 must be performed.
2.4.2 Burner Operating Procedures
A.
Preparation
a.
Technicians to:
ii)
b.
Ensure all Valves on the Burner Heads are 'open' for the
required flow rate.
All Test Plugs have been removed after Pressure Testing.
Authorised Work Permits must be obtained prior to operating on
either Burner. i.e. 'Hot Work' and 'Over the Side' Work Permits.
Note:- For clarification purposes the Burners will be termed as Port and
Starboard.
In these procedures all Burning and Flaring Operations will
initially refer to as commencing through the Port Burner.
B.
Operating Procedure
a.
i)
ii)
iii)
b.
i)
ii)
Determine the prevailing wind direction and select the
Burner away from the Rig.
This should be clarified by the Installation Control
Room.
The procedure from here on will pertain to the Port
Burner unless stated otherwise.
Inform Control Room/Barge Master that Burner
operations are about to commence and from which
Burner.
Make a P.A. Announcement to inform all personnel of
the Hazardous Operations about to be performed.
Note:- Communications Channels to the Control Room must be
maintained at all times.
c.
Set the Burners so that the wind blows from the rear, which in turn
will allow the flame to burn directly out of the Burner Heads,
effecting better combustion.
Page 29 of 103
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Schlumberger Private
i)
Schlumberger Procedures
July 2000
d.
i)
ii)
e.
f.
g.
Note:-
Check the route of the flow from the Choke Manifold
making sure all appropriate Valves on this route are
'open' to the Port Burner.
The Gas and Oil Diverter Valves to the Starboard Burner
must be 'closed'.
'Open' Propane supply and ignite the Pilot Lights
Start the remote Air Compressors and 'open' the Valves on the Air
Diverter Manifold, directing the Flow of Air to the Port Burner.
Advise the Drill Floor/Control Room to turn on the Water for the
Burner Cooling Rings and Rig Cooling Curtains.
Only a small volume of water should be diverted to the Burner
Rings until the Effluent has ignited, then adjust accordingly to
maximise the Combustion Efficiency.
Schlumberger Private
Page 30 of 103
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Schlumberger Procedures
July 2000
2.4.3 Switching Flare Booms
Note:-
For clarification purposes the Port Burner and its Ancillary Equipment
are in the meantime still operational.
The change over will be to the Starboard Burner. (Oil and Gas are both
being Flared Off)
A.
Operating Procedure
a.
b.
c.
d.
Note:-
At this point the Air is still being supplied to the Port
Burner.
i)
Notify the Drill Floor/Control Room for the Water to be
turned on to the Burner Cooling Rings and the Rig
Cooling Curtains.
Only a small volume of water is required initially to the
Cooling Rings until the Effluent ignites.
Adjust accordingly to optimise Combustion Efficiency.
A Technician should be positioned directly at the Boom
area with a radio, maintaining contact with the
Technician at the Diverter Manifolds as the change over
procedure is being performed.
Maintaining communication links is essential and will
result in a smooth and efficient operation without causing
any adverse Pressure effects Upstream in the System.
'Open' the Starboard Burner Valve. Once the Effluent is
burning at the Starboard Burner, proceed to 'open' the
Starboard Gas Diverter Valve.
'Close' the Port Gas Diverter Valve when the Starboard
Gas Flare has been lit.
'Close' the Port Oil Diverter Valve.
ii)
f.
iii)
i)
ii)
g.
i)
ii)
iii)
h.
i)
ii)
'Close' the Port Air Diverter Valve, isolating the Air, and
commence with the following Shutdown Procedures.
The Air Compressors must continue supplying Air to the
Starboard Burner.
Page 31 of 103
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Schlumberger Private
e.
Inform the Control Room/Barge Master that the direction of the
flaring requires changing and that the Burner Booms are about to
change.
If necessary set the Burner so that the wind blows from the rear of
the Burner as detailed in the Start-up Operations.
i)
Ensure that the required Burner Head Valves are 'open'.
This will have been done prior to the Start-up.
ii)
'Open' the Propane supply to the Starboard Burner and
ignite the Pilot Lights
i)
Ensure the Air Valves on the Burner Head are 'open'.
This should have been done prior to the Start-up.
ii)
'Open' valve on the Air Diverter Manifold to the
Starboard Burner.
Schlumberger Procedures
July 2000
2.4.4 Burner Shut Down
A.
Operating Procedure
a.
b.
c.
d.
Once the Well is 'closed' in, allow the Oil and Gas Lines to the
Burner to depressurise and the Flare to extinguish.
Do not isolate the Propane to the Pilots until all the Effluent is
completely burnt off.
Upon completion of burning, turn off the Propane, Air and Water,
in that sequence. This will prevent any fall-out of burning
Hydrocarbon droplets into the Sea.
Do not close all Gas and Oil Diverter Valves to the Burners. A
route must be online in the event of an Emergency Venting.
Schlumberger Private
Page 32 of 103
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Schlumberger Procedures
July 2000
2.4.5 Boom Assembly and Disassembly Procedures
A.
General
a.
B.
Usually the Booms will have been assembled prior to being sent
offshore, if this is not the case, it is recommended to fit the Boom
onshore, mark and dismantle sequentially for reassembly offshore.
Preparation and Assembly Procedure
Before assembling the Boom, ensure there is sufficient room available to
lay the complete Boom out with enough additional space for personnel to
manoeuvre around and guide the sections into place without becoming
trapped, approximately 35m x 7 m is required.
a.
b.
c.
d.
i)
ii)
f.
g.
h.
Note:-
The two sections should be brought back into alignment.
The box section flanges mated on to their mating pin and
flange.
All 16 box section securing bolts can now be installed and torqued
to 100 Nm.
i)
Flanges could now be brought together.
ii)
Gaskets and flange bolts installed.
iii)
Flange bolts torqued to the recommended torque for the
flange type.
iv)
Tighten pipe retaining 'U' bolts on foot section.
The above steps could now be used to fit the Burner section.
Dis-assembly is a direct reversal of the assembly procedure,
except for the loosening of the pipe retaining 'U' bolts, which need
not be loosened.
Page 33 of 103
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Schlumberger Private
e.
The foot section should be laid down first and the pipe securing
'U' bolts loosened to allow lateral movement of the pipe along the
Boom.
The mid section should be laid down next with the two section
mating ends in line with a 1 meter gap.
Remove the protection from the mating pipe flanges.
The intermediate section of the Boom should now be lifted and
moved towards the foot section with the two centre lines of the
sections misaligned in such a way that the protruding flanges on
either section fit inside the hand rail uprights of the opposite
section.
Once the flanges are clear of this upright, but before the box
section flanges clash with their locating pins,
Schlumberger Procedures
July 2000
2.4.6 Boom Hanging Procedure
A.
General
a.
b.
c.
B.
All preparation and calculations for UBM boom installation
should be carried out according with FOH 2. Prior to the Boom
installation at site.
Certification of boom supports and fixings should be inspected.
ABB policy for working on Booms should be adhered to whilst
working on Booms.
Preparation and Procedure
Prior to any work over the side, the Platform Standby Boat must be called
in, and kept in constant contact with, by radio in the hands of an allocated
Watchman for the duration of the operation.
Lifebelts should be used and the Platform Permit to Work System strictly
adhered.
Schlumberger does not advise personnel to attach themselves via Safety
Harness to the Boom for these operations.
a.
c.
d.
e.
f.
g.
h.
j.
The Horizontal guy wire slack can now be taken up on Winches or
Block and Tackle and secured using bulldog clamps.
The Crane could now be released from the Boom.
Page 34 of 103
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Schlumberger Private
b.
Install and position 1" Vertical Guy Wires from padeyes on the
Boom Tower or from Spreader Beams on the King Pins
If the Boom is on the Deck attach 5/8" Guy Wires and secure on
Boom deck.
i)
The Boom should now be lifted by the crane and
positioned with the two connecting padeyes slotted into
their mating padeyes on the Base Plate.
ii)
The hinge pins could now be knocked in and secured
with splitpins.
i)
The boom should now be lifted into a position 30 degrees
to the horizontal. It is important that the weight of the
Boom be kept on the forward leg of the lifting sling and
the Base Plate.
ii)
The Crane jib should be swung and lifted, not simply
lifted which would transfer the weight to the rear leg.
An Operator must now go out onto the Boom, attach the 1" Vertical
Guy wires to the hanging points and remove the tape which holds
the two wires together, and return.
The weight could now be slowly released from the crane ensuring
that the guy wires sit the Boom at the desired angle of
approximately 14 degrees.
i)
The horizontal guy wires could now be fixed to the
Boom padeyes carried along the Boom length, ensuring
that their weight is taken by the Platform and the Boom
and that they are routed outside the vertical guy wires.
ii)
The Vertical guy wires could now be attached to their
Padeyes and the Operator can now leave the Boom.
Schlumberger Procedures
July 2000
2.4.7 Boom Removal Procedure
A.
General
This procedure is for the removal of the Boom from the Rig with Burner
Heads still attached.
B.
Preparation
a.
b.
c.
d.
C.
Prior to any work over the side, the Platform Stand-by Boat must
be called in and kept in constant contact with by radio. A
watchman must be allocated to do this for the duration of the
operation.
Lifebelts should be used when working over the side.
The Permit to Work System will be strictly adhered.
Schlumberger does not advise that should be attached to the Boom
via a Safety Harness for these operations.
Procedure
a.
b.
Note:-
d.
Lower Crane until the hinge pins become free to be moved
allowing Boom to be swung away from the Rig.
Note:-
e.
Ensure Tag Lines are secured to the Boom, front and
back.
At all times personnel must take care when removing
Pins and ensure proper tools are available.
Lower the Boom to a boat along side or. store on the Rig.
Page 35 of 103
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Schlumberger Private
c.
Prior to lifting the Boom all pipework and fixings are to be
removed and stored away from Boom working area.
i)
Attach Crane to the Padeyes on the Boom.
ii)
Crane to take the weight of the Boom.
iii)
Remove the Guy wires to allow the Boom to be hoisted
without any tension resulting in the side guys.
i)
The Boom could now be lifted to an angle that enables
the removal of the Vertical Guy Wires.
ii)
As soon as this is done the person on the Boom is to
return to the Rig side.
Schlumberger Procedures
July 2000
2.5 Pipework Assembly Procedures
2.5.1 General
A.
B.
C.
The major items of equipment must be positioned on site as per the
certifying authority approved layout diagram.
Any deviation from this and the Certifying Authority must be informed.
All Instrumentation and Components must be set up as indicated in the
approved Well Test Process Flow Diagram.
2.5.2 Weco Type Pipework
A.
Weco Pipework - Lipseal Type
a.
Assembly Procedure
i)
Check the Pipework for the following:
ii)
iii)
iv)
v)
vi)
vii)
viii)
ix).
b.
Remove the Protector Caps
Clean and inspect Weco sealing faces and threads for
mechanical
damage and rust.
Inspect 'O' ring seal for damage.
Visually inspect pipework internally for any
obstructions.
Lubricate and insert 'O' ring seal into Male Coupling.
Lubricate Weco Male and Female threads.
Line up Male and Female Couplings and assemble hand
tight
Tighten up Male with a brass sledge hammer to complete
make up, with all threads engaged.
Dis-assembly Procedure
i)
ii)
iii)
iv)
v)
vi)
B.
Size and Pressure Rating
Nature of service
Serial Number
In Test Certifying Authority Test Certificate.
Ensure that the system has been properly flushed with
water.
Ensure that the system has been depressurised.
Loosen the Male Coupling with a brass sledge hammer
and drain, but do not disconnect.
Ensure the Pipework is safely supported.
Unscrew the Male Coupling from the top, manually.
Clean and lubricate Male and Female Couplings and
install Protector Caps.
Weco Pipework - ‘O’ Ring Type
a.
Assembly Procedure
Page 36 of 103
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Schlumberger Private
1.
2.
3.
4.
Schlumberger Procedures
July 2000
i)
Check the Pipework for the following:
1.
2.
3.
4.
ii)
iii)
iv)
v)
vi)
vii)
viii)
ix).
b.
Size and Pressure Rating
Nature of service
Serial Number
In Test Certifying Authority Test Certificate.
Remove the Protector Caps
Clean and inspect Weco sealing faces and threads for
mechanical damage and rust.
Inspect 'O' ring seal for damage.
Visually inspect pipework internally for any
obstructions.
Lubricate and insert 'O' ring seal into Male Coupling.
Lubricate Weco Male and Female threads.
Line up Male and Female Couplings and assemble hand
tight.
Tighten up Male with a brass sledge hammer to complete
make up, with all threads engaged.
Dis-assembly Procedure
i)
iv)
v)
vi)
Page 37 of 103
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Schlumberger Private
ii)
iii)
Ensure that the system has been properly flushed with
water.
Ensure that the system has been depressurised.
Loosen the Male Coupling with a brass sledge hammer
and drain, but do not disconnect.
Ensure the Pipework is safely supported.
Unscrew the Male Coupling from the top, manually.
Clean and lubricate Male and Female Couplings and
install Protector Caps.
Schlumberger Procedures
July 2000
2.5.3 Flanged Type Pipework
A.
Flanged Pipework-Raised Face Type
a.
Assembly Procedure
i)
Check Pipework for the following:
1.
2.
3.
4.
ii)
iii)
Remove Protector Caps
Clean and inspect Flange faces for mechanical damage
and rust.
Select a 'spiral wound gasket' in accordance to
manufactures specifications. Clean and inspect same.
iv)
Always install a new Spiral Wound Gasket.
v)
Check that studs and nuts are according to manufactures
specifications. Clean and inspect same.
Visually inspect pipework internally for any obstructions.
Install required amount of bolts to maintain the Gasket
alignment
Install the Gasket.
Install the remaining bolts, tighten up manually,
controlling a parallel alignment between the Flange faces.
Tighten the bolts with a torque spanner to the
manufactures recommended torques.
viii)
ix)
x)
Dis-assembly Procedure
i)
ii)
iii)
iv)
v)
vi)
vii)
B.
Ensure that the system has been properly flushed with
water.
Ensure that the system has been depressurised.
Loosen bolts, move Flange to break the seal and drain,
but do not disconnect.
Ensure the pipework is safely supported.
Remove all bolts, disconnecting Flange faces.
Clean and inspect the pipe flange sealing faces for rust
and damage.
Lubricate faces and install Protectors, discard the old
Gasket.
Flange Pipework-Ring Groove Type
a.
Assembly Procedure
i)
Check pipework for the following:
1.
2.
3.
4.
Size and Pressure Rating
Nature of Service
Serial Number
In Test Certifying Authority Test Certificate.
Page 38 of 103
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Schlumberger Private
Note:-
vi)
vii)
b.
Size and pressure Rating
Nature of Service.
Serial Number
In Test Certifying Authority Test Certificate.
Schlumberger Procedures
July 2000
ii)
iii)
Remove protector caps.
Clean and inspect Flange faces for mechanical damage
and rust.
Select 'ring gasket' in accordance to manufacturers
specification. Clean and inspect same.
iv)
Note:-
Always Install A New Ring Gasket.
v)
Check that the studs and nuts are to the manufacturers
specifications, and are marked accordingly.
Visually inspect pipework internally for any obstructions.
Lubricate the Ring Gasket.
Install the Gasket into the ring grooves of one flange
Lubricate and install two bolts of the Flange face to
maintain alignment.
Install the remaining bolts, tighten up manually,
controlling a parallel alignment between the Flange faces.
Tighten the bolts with a torque spanner to the
manufacturers recommended Torques.
vi)
vii)
viii)
ix)
x)
xi)
b.
Dis-assembly Procedure
i)
iv)
v)
vi)
vii)
Page 39 of 103
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Schlumberger Private
ii)
iii)
Ensure that the system has been properly flushed with
water.
Ensure that the system has been depressurised.
Loosen bolts, move Flange to break the seal and drain,
but do not disconnect.
Ensure the pipework is safely supported.
Remove all bolts, disconnecting Flange faces.
Clean and inspect the pipe flange sealing faces for rust
and damage.
Lubricate faces and install Protectors, discard the old
Gasket.
Schlumberger Procedures
July 2000
2.5.4 Techlok Clamp Type Pipework
A.
Assembly Procedure
a.
Check pipework for the following:
i)
ii)
iii)
iv)
b
c.
d.
e.
Remove protector caps.
Clean and inspect the Hub Sealing surfaces for mechanical
damage and rust.
Visually examine pipework internally for any obstruction.
Inspect seal ring, insert into sealing face seat by hand and check
parallel stand-off is to the manufacturers recommended
specification.
If the Stand-off is less than that recommended the seal ring must
be replaced.
f.
g.
h.
j
Lubricate the Seal ring and the hub sealing faces.
Align the Hub Connectors and make up together.
Lubricate the clamps and locate on to the Hub Connector.
Lubricate and install two bolts with the spherical faces of the nuts
into the seating on the clamps. Tighten up manually and maintain
alignment of the hubs.
Install the remaining bolts and tighten evenly with a torque
spanner in accordance with the manufacturers recommendations.
A hammer can be used to tap the clamps into engagement as the
nuts are being tightened. Ensure the gaps on both side of the
clamps come together evenly.
Note:-
Do not attempt to correct badly misaligned piping by clamping
force alone.
Dis-assembly Procedure
a
b.
c.
d.
g.
Ensure that the system has been properly flushed with water.
Ensure that the system has been depressurised.
Ensure the pipework is safely supported.
Loosen all bolts, move the Connector to break the seal and drain,
but do not disconnect.
Remove all bolts and disconnect flange faces
Clean and inspect the seal ring and sealing faces for mechanical
damage and rust.
Apply a coat of lubricant to the Seal and Hub Connectors.
h.
Install Protector Caps.
e.
f.
Page 40 of 103
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Schlumberger Private
Note:-
k.
B.
Size and Pressure Rating
Nature of Service
Serial Number
In Test Certifying Authority Test Certificate
Schlumberger Procedures
July 2000
2.6 Pressure Test Procedures
2.6.1 Pressure Test Surface Equipment
A.
General
a.
b.
c.
d.
e.
B.
Preparation
b.
c.
d.
e.
Rig up a Chicksan line from the Choke Manifold to tie into the
Cement pump (this normally means tying into the Rig Manifold).
Check the example Pressure Testing Procedure against the P&ID
drawings. Recheck the Procedure on site against the physical
equipment.
Walk the lines to check if they are made up according to the P&ID
diagram and that all lines are chained down.
Ensure that the Stand-by Boat or Rescue Craft is in position/on
alert whenever personnel are working over the side of the Rig.
This includes any work on the Flare Booms.
Before Flushing through the Burners, check that the Standby
boat/Rescue Craft have moved clear.
Operating Procedure
a
b.
Refer to the P&ID schematic of the Surface Equipment Layout for
Pressure Test Valves
'Open' lines to both Flare Booms and ensure the following:
i)
ii)
iii)
iv)
v)
vi)
vii)
viii)
ix)
x)
xi)
xii)
xiii)
All lines are chained down.
Both Oil and Gas Diverter Valves are 'open'.
Heater Inlet Valves is 'open'.
Heater Choke is 'open'.
Heater Outlet Valve is 'open'.
Heater by-pass Valve is 'open'.
Separator Inlet Valve is 'closed'.
Separator Gas Outlet Valve is 'closed'.
Separator Oil Outlet Valve is 'closed'.
Separator Water Outlet Valve is 'closed'
Separator Gas By-pass Valve is 'open'.
Oil Manifold Surge Tank Diverter Line Valve is 'closed'.
Surge Tank Inlet Valve is 'open'.
Page 41 of 103
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Schlumberger Private
a.
C.
Check that the Work Permit held by the Well Test Supervisor
fully covers the scope of the operation.
Use water as the testing medium and, as far as possible, ensure
there is no air trapped in the equipment under test.
Always increase pressure in steps to the final test pressure.
i)
Ensure all areas exposed to High Pressure are roped off.
ii)
A PA announcement detailing the area where High
Pressure Testing will be taking place must be made
before the start of the operation.
During Flushing and Pressure Testing, if there are any unexpected
pressure build ups, bleed pressure off via the Cement Unit and
check the line up of all Valves.
Schlumberger Procedures
July 2000
xiv)
Oil Manifold Transfer Pump Line Valve is 'closed' and
the Bleed off Valve is 'open'.
xv)
Burner head Caps removed.
c.
With the Valves in the above positions, pump water to the Gas
Flare by-passing all Vessels to flush Lines, this also ensures no
debris flows into the system.
d.
i)
ii)
iii)
iv)
v)
vi)
When clear water appears at the Gas Flares, divert flow
to both Burner Heads.
When water appears at the Burner Heads flushing
through should be 'stopped'.
Stop pumping immediately if there is any Pressure Build
Up.
Bleed Pressure off via the Cement Unit.
Check position of the Valves.
By-pass the Heater and Separator as follows:
1.
2.
e.
With the Stand-by Boat on station:
g.
On successful completion of the previous Pressure Test Bleed off
pressure via the Cement Unit.
With the Stand-by Boat on Station:
i)
ii)
iii)
iv)
v)
vi)
vii)
h.
j.
Remove Burner Plugs/Caps from the Starboard Burner.
Install Burner Plugs/Caps in the Port Burner.
'Open' the Port Oil Line Diverter Valve.
'Close' the Starboard Oil Line Diverter Valve.
'Close' the Oil Manifold Surge Tank Diverter Line Valve.
'Open' the Surge Tank Inlet Valve.
Pressure Test the Port Flare Lines to 1000 psi for ____
minutes.
i)
On successful completion of the previous test, bleed off
pressure via the Cement Unit and remove Burner
Plugs/Caps.
ii)
'Open' Oil Line Diverter Valves and flush through to
confirm that the Oil Lines are 'open'.
Line up the Separator as follows:
i)
ii)
iii)
k.
Fit Burner Plugs/Caps to the Starboard Burner.
'Close' the Gas line Diverter Valves.
'Close' the Port Oil Line Diverter Valve.
Pressure Test Starboard Flare Line to 1000 psi for ____
minutes.
'Close' Oil and Gas line by-pass Valves.
'Open' Inlet Valve.
Ensure all Outlet Valves are 'closed'.
Fill Separator and Pressure Test the Separator Body, Separator
By-pass Line Valves and the Upstream Lines to 1,100 psi for ____
minutes.
Page 42 of 103
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Schlumberger Private
i)
ii)
iii)
iv)
f.
Heater - 'Close' Inlet Valve.
'Close' Outlet Valve.
'Open' By-pass Valve.
Separator 'Close' Gas By-pass Valve.
'Open' Oil line By-pass Valve.
Schlumberger Procedures
July 2000
l.
On successful completion of the Pressure Test bleed off the
pressure via the Cement Unit and:
i)
ii)
iii)
iv)
m.
n.
Pressure Test Separator Inlet Valve, Heater Body and
Downstream Coil to 1,100 psi for ____ minutes.
On successful completion of the last Test bleed off pressure via
the Cement Unit.
o.
i)
ii)
iii)
p.
Pressure Test Upstream Heater Coil and Upstream Lines to ____
psi for ___ minutes.
On successful completion of the last test, and while still holding
pressure,
q.
r.
'Close' Choke Manifold Back Valves.
Bleed off pressure at the Cement Unit to 500 psi.
Monitor Pressure at the Cement Unit to 500 psi.
Monitor pressure at the Cement Unit for ____ minutes.
On successful completion of the last test, bleed off pressure and:
i)
ii)
iii)
iv)
v)
s.
Install Blank Plug in the Heater Choke.
'Open' Heater Outlet valve.
Set Cement Unit Relief Valve to ____ psi.
Remove the Blank Plug from the Header Choke.
'Open' Heater By-pass Valve.
'Close' Heater Inlet Valve.
'Close' Choke Manifold back Valves.
Pressure Test Choke Manifold Body and Back Valves to
____ psi for ____ minutes.
On successful completion of the previous test, bleed off all
pressure and:
i)
ii)
Remove Blank Plug from Header Choke.
'Open' Heater By-pass Valve.
iii)
iv)
v)
'Close' Heater Inlet Valve.
'Close' Choke Manifold back Valves.
Pressure Test Choke Manifold and Back Valves to ____
psi for ___
minutes.
Bleed off pressure at the Cement Unit.
vi)
Operating Guidelines
a.
b.
Always check the Operating Procedure and Test Pressures against
the P&ID drawings and the physical equipment at the Well Site.
The aims of the Surface Equipment Pressure Tests are to :
Page 43 of 103
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Schlumberger Private
i)
ii)
iii)
iv)
D.
'Close' Separator Inlet Valve.
'Open' Heater Inlet Valve.
'Open' Heater Outlet Valve.
'Close' Heater By-pass Valve.
Schlumberger Procedures
July 2000
i)
Confirm that the Equipment does not leak at Working
Pressures.
ii)
Confirm that the Equipment is fit for the pressure duty it
may be subjected to during the Well Test.
Confirm that Flow can be diverted through the system as
required.
iii)
Notes:-
1.
2.
3.
4.
5.
6.
i)
7.
8.
9.
When the above Safety Valve is fitted
it shall be Pressure Tested in situ' as
part of the Flowhead Pressure testing
Procedure.
It is possible to Pressure Test both Burner
Heads simultaneously. Remove the Burner
plugs/Caps and Pressure Test both Diverter
Valves simultaneously.
However, if both
Diverter Valves are Tested simultaneously, it
will not be possible to identify which Diverter
Valve is leaking.
If a Diverter Valve and Burner Head are
Pressure Tested simultaneously it is possible to
visually check all lines and the Burner Head for
leaks.
If the source of a leak cannot be found then the
leak must be at the Oil Diverter Valve.
Note:
The Gas By-pass Valve can be 'closed' to
eliminate the Gas Diverter Valves as the source
of the leak.
10.
Choke changes require Isolation from both the
upstream and the downstream Flow. Therefore
Pressure Testing of the Choke Manifold must
include a Pressure Test on the Choke Manifold
Back valves from the downstream side.
Page 44 of 103
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No external leaks in the surface equipment,
however small, are tolerable.
High Pressure Pilots should be set to 90% of the
Pressure Test Value.
The Separator and lines downstream of the
Separator should be Pressure Tested to create an
Operating Envelope of at least 0 - 1000 psi. To
do this it is necessary to pressure test the
Separator to 1100 psi to allow the High Pressure
Trip to be set at 1000 psi.
On High Flow Rate Wells it may be necessary
to Pressure Test the Separator to a value closer
to its rated Working Pressure (1440 psi).
Where possible the lines to the Heater Choke
should be rated and Pressure Tested to allow
full WHCIP at the Heater Choke.
Where Sand Filters are installed upstream of the
Choke it is often necessary to install an
additional Valve to isolate the Sand Filters
during pressuring up for Perforating.
Schlumberger Procedures
July 2000
11.
If there is a non-return Valve in the Kill Line
ensure that trapped pressure is bled off on both
sides after completing individual Pressure Tests.
Schlumberger Private
Page 45 of 103
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Schlumberger Procedures
July 2000
2.7 Sampling Procedures
2.7.1 Sampling - Trace Element Detection
2.7.1.1 Preparation
The point of sampling should always be downstream of the
choke manifold ie. in a low pressure section of the system.
A semi-enclosed container eg. 1 gallon plastic bottle should
be utilised in order for well gas to completely displace air
from the container as air contamination will lead to a false
(low) reading. As always, a minimum of two valves should
be on the manifold, the inner valve should be fully open, the
outer valve used to control flow of well fluids into the
sampling container. If high levels of toxic gases are
expected, S.C.B.A should always be worn during sampling.
2.
Confirm the aspirating pump is functioning correctly by
conducting an air leakage test:If there is leakage in the aspirating pump, a lower (or no)
measured value may be obtained. The pump should be
checked prior to use for such leakage, the procedure is
detailed
below:-
a)
Insert an unbroken detector tube in the rubber tube
connector.
b)
Align the red dots on the pump shaft and stopper and pull
the handle fully out until it locks at the 100 ml mark.
c)
Wait for 3 minutes.
d)
Unlock the handle by giving it 1/4 turn, the handle should
return all the way to the 0 ml mark. If the handle fails to
return to the 0 ml mark, this indicates air leakage, which
should be corrected.
1.
Insert the tip of the gas detector tube into the tip cutter and
cut it by holding the base of the gas detector tube and
pulling it towards you. Repeat for other end.
2.
As the sample gas MUST be passed through the gas
detector in a definite direction, insert the gas detector tube
with the arrow mark pointing towards the aspirating pump.
3.
Introduce well fluids at a controlled rate into the sampling
container using the two valves as detailed previously.
2.7.1.2 Operation
Page 46 of 103
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Schlumberger Private
1.
Schlumberger Procedures
July 2000
Insert the gas detector tube into the container, ensuring that
the end of the tube does not contact any liquid or droplets
of liquid.
4.
Align the red dots on the pump shaft and stopper and pull
the handle fully out until it locks at the 100 ml mark.
Aspirate sample gas for the time indicated on the
instruction sheet for the type of tubes being used.
5.
Unlock the handle by giving it 1/4 turn. The handle should
not return by more than 5% (indicated by ring on shaft). If
it does, pull out and lock again until sampling is complete.
Shut off well fluid supply to sampling container.
6.
Read the concentration of trace element at the end of the
discoloured layer. Check in the "gas detector tube system
hand book" for the type and range of tube utilised to
ascertain if temperature correction is required - generally
speaking this will not be the case.
7.
Log the reading on the reading sheet.
Schlumberger Private
Page 47 of 103
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Schlumberger Procedures
July 2000
2.7.2 Sampling - Gas Gravitometer (Ranarex) Procedure
2.7.2.1 General:
1)
As the Ranarex has a maximum working pressure of 20
psi, a regulator should always be used in the supply line,
regulator WP 1500 psi, H2S Service. Operating pressure
should be 10-20 psi.
2)
If high concentrations of toxic elements are expected,
plastic gas supply hose must replaced by stainless steel
tubing. In an case, vented gas must be routed away from
fan intakes etc.
1)
Connect regulator to gooseneck on separator gas line, run
hose/tubing to lab cabin through cable entry tranit block.
Connect to gas inlet port on Ranarex. Connect relevant
outlet (SG > 1.000 - High Gas, SG < 1.000 - Low Gas) to
vent tubing. Ensure silicon gel crystals are blue in colour
(Dry).
2)
Test operation of Ranarex - power up, turn lock/unlock
knob to unlock indicator needle. Turn inlet valve knurled
knob from off to "0". Indicator needle should move to
1.000 mark on scale. Zero to this mark if necessary using
"zero adjust" screw on front cover. Once complete, turn
inlet valve to off, lock indicator needle and switch off
power.
1)
Power up Ranarex and unlock indicator needle. Turn inlet
valve to LG (for gas SG < 1.000), or HG (for gas SG >
1.000).
2)
Set inlet regulator midway between fully open and fully
closed.
3)
On separator gooseneck, open supply valves and adjust
regulator to give ± 15 psi outlet pressure.
4)
On Ranarex, adjust inlet regulator so that floating ball
reads approximately equivalent to gas SG.
5)
Read gas SG directly from scale, log on reading sheet.
6)
On separator, close supply valves and allow outlet
pressure to drop.
7)
Turn Ranarex inlet valve to "0" position, allow Ranarex to
purge to 1.000 mark, lock needle. Power down Ranarex.
2.7.2.2 Preparation:
Page 48 of 103
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2.7.2.3 Operation:
Schlumberger Procedures
July 2000
2.7.3 PVT Surface Sampling
Refer Oilphase Samling Procedures ETPS/J005/95-P073
Schlumberger Private
Page 49 of 103
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Schlumberger Procedures
July 2000
2.7.4 Dead Oil Sampling
a.
General
i)
Un-pressurised Oil Samples are normally taken during
and at the end of each Flow Period.
When Samples are taken during the Flow, they are
normally taken at the same time as pressurised Oil and
Gas Samples.
Sample size is normally 2 gallons
Large samples (45 gallons) are also required for each
flow period and are usually taken at the end of the Flow
Period.
Sample Containers should be clean (new) metal tins and
drums with tightly fitting Caps.
ii)
iii)
iv)
v)
Plastic Containers or should not be used as the sample
may react with it.
vi)
Dead Oil/Condensate Samples should be checked
regularly for BS&W and Gravity.
Procedures
i)
ii)
iii)
iv)
v)
vi)
vii)
c.
Sample Point.
i)
ii)
H.
Flush out the Sample Liner for at least one minute into
metal container.
If the colour of the liquid is changing, wait until the
colour is constant.
The rejected Liquid should be transferred to a waste oil
drum.
Spillage is to be kept to a minimum.
Fill the Sample Container and allow it to stand,
uncapped, until all the Gas has liberated.
When the sample has de-gassed, the container is to be
securely capped and a Sample Label prepared and
attached to it.
The container should then be stored in the shade.
The Sample Point on the Separator Oil Outlet line is used
for Dead Oil Condensate Sampling.
If samples are taken from a Gauge/Surge Tank, the Sample
Point on the Oil Exit Line should be used.
Surface Sampling Procedures - Miscellaneous
a.
b.
c.
d.
As a matter of routine, Samples of the Mud and Cushion must be
taken.
Any other liquid used in Well Operations, such as diesel, brine,
demulsifier, defoamer, etc. is to be sampled.
Organic based Samples are to be taken in metal containers while
Ionic based Samples should betaken in Plastic Bottles.
One litre samples are usually adequate.
Page 50 of 103
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Schlumberger Private
b.
Note:-
Schlumberger Procedures
July 2000
e.
f.
J.
Anything unusual produced from the Well, either Liquid or Solid,
should be sampled.
If there is any doubt whether to sample or not, then a Sample
should be taken. It is better to have too many Samples than too
few.
Sampling Requirements and Information
a.
b.
The Company Reservoir Engineer should advise how many
Samples are required during Flow Periods.
Sampling available consists of:
i)
ii)
iii)
iv)
v)
c.
A variety of containers are available for use in the above
techniques:
Single Phase PVT Sample Containers
600 cc Oil Bottles.
10 lt/20 lt Gas Bottles.
Various Plastic Containers.
25 lt, 11 lt, 5 lt, 1 lt IATA Cans.
45 Gallon Drums (Teflon lined)
Once number and type of samples have been decided upon, a
Sampling Inventory should be kept, listing all Samples
chronologically.
Details should include:i)
ii)
iii)
iv)
v)
vi)
vii)
Sample Number (relating to particular DST, i.e. 1 or 2)
Date and Time taken.
Sample Bottle Number (relating to actual bottle number)
Volume of Sample.
Nature of Sample.
Container number in which samples are shipped/stored.
Location to which Samples are sent.
Page 51 of 103
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i)
ii)
iii)
iv)
v)
vi)
d.
Bottom Hole PVT Samples
Surface Monophasic PVT Samples.
Surface Separator PVT Samples (Oil and Gas)
Dead Oil Stock Tank Samples.
Separator Water Samples.
Schlumberger Procedures
July 2000
2.8 Emergency Shut Down System
2.8.1 General
A.
B.
C.
D.
The Emergency Shut Down System consists of High Pressure Control
Lines operating actuated Valves either on the Flowhead or stand alone
Isolation Valves.
These actuated valves are linked to the Low pressure Pilot System, which,
when pressure is lost, shut down all, or selected, Valves, depending on
which button or High/Low Pilot is activated.
If the requested, a subsea Safety Valve can be included into the system to
provide a means for a downhole Shutdown.
The Pilot air pressure can be bled off by any of the following operations
causing the Well to be shut in.
a.
b.
c.
e.
g.
Page 52 of 103
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f.
Push/Pull ESD button.
Over pressure will activate HI Pilot.
Loss of Pressure will activate LQ Pilot.
The valves which will close are determined by how the System is
set up at the Start of the job.
After Shut down, once the problem has been rectified, the system
will have to be reset and re- pressurised and the valves 'opened' in
a controlled order against a 'Closed' Choke Manifold
Once this is done, the well can be opened as per normal Operating
Procedures.
Schlumberger Procedures
July 2000
2.8.2 Emergency Shut Down (ESD) Procedures
A.
General
a.
b.
B.
Preparation
a.
b.
c.
d.
c.
d.
e.
Connect the Air Supply to the ESD Console.
Open' Air supply and check that all Valves of the ESD Stations
are 'closed' and there is no Air leaks in the circuit.
The Air Supply should read 5-10 bar at the Pressure Gauge prior
to 'opening' the Air supply valve.
Adjust the Air pressure by means of the Pressure Controller.
'Open' Air Flow Regulator.
Charge the Air Pilot Circuit.
Once Air Pilot Circuit has been charged, Hydraulic Pressure can
then be applied to 'open' the SDV's Actuator.
Equipment List
Note:-
The equipment list will vary in accordance with Specific Test
Designs generally as follows:-
a.
b.
c.
d.
e.
f.
SDV1
SDV2
PSL1
PSL2
PSH2
PHS3
Flow Line Actuator Valve
Flow Line Isolation Valve
Pressure Sensor upstream of Choke Manifold.
Pressure Sensor 'Low' upstream of Separator.
Pressure Sensor 'High' upstream of Separator.
Pressure Sensor 'High' Steam Exchange Vessel.
Page 53 of 103
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C.
During Rig up of Pneumatic Control Lines, ensure that lines are
well tied down, protected and obscure from Walkways and Deck
loading areas.
During Safety Meetings all personnel must be made aware of ESD
Button locations and Shut Down Procedures according to the
Clients requirements.
Schlumberger Procedures
July 2000
2.8.3 Function Test
Note:-
During Pressure Testing Sequences all Hi-Lo Pilots and ESD Buttons are
to be function tested. The following Procedures are a general guide in
order to function test.
For more detailed operations refer to Section 2.8.
A.
B.
Pressure Test against Choke Manifold and set PSL1 to 1000 - 2000 psi
below expected stabilised flowing Wellhead Pressure.
Bleed off Pressure and note the following:
a.
b.
C.
D.
E.
'Open' SDV1 and isolate PSL1.
Set PSH2 to 1260 psi.
'Open' Choke Manifold and Pressure Test against Separator Inlet Manifold
and trip PSH2.
Note:-
'Open' SDV2 and set PSL2 to 200 psi.
Bleed off Test Pressure, tripping PSL2.
Note:-
H.
K.
M.
Response Time of SDV1 Closure.
'Open' SDV1 and function test using ESD Manual Buttons. Note:Response Time of each Button.
Function SDV2 using ESD Panel.
Note:-
L.
Response Time of SDV2 closure. Isolate PSL2.
Set PSH3 to 190 psi and function test using D.W.T.
Note:-
J.
Response Time of SDV2 closure.
Response Time of SDV2 Closure.
Prior to 'opening' the Well, activate the Hi Pilots to desired pressure
according to Test Design requirements.
Once the Well is clean and on Stable Choke, activate Lo Pilots to Test
Design requirements.
Note:
Isolation of Pilots to be done on Pneumatic Lines, all pressure
Sensing Lines from Flow Lines and Isolation Valves are to
remain 'open'.
Page 54 of 103
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F.
G.
Trip Pressure
Response time of SDV1 Closure.
Schlumberger Procedures
July 2000
2.9 Data Acquisitions
2.9.1 Data Acquisition Procedures
A.
General
a.
b.
c.
B.
Prior to shipment to the Offshore Location, all Electronic Sensors
to be utilised will have been calibrated onshore.
A copy of all Coefficients shall be carried to the offshore location
in order to conduct onsite calibration checks.
Once all Electronic Sensors are connected to the Computer
Acquisition System (CAS), a calibration check against the
corresponding Mechanical Recorders should be conducted.
Preparation
a
b.
i)
ii)
This probe must be immersed in Hydraulic Oil within the
Thermowell.
Bimetallic Strap on Sensor:- This Sensor should be
strapped onto the relevant piece of equipment and
insulated from the external environment accordingly.
d.
e.
All Electrical Components should be suitably 'earthed'.
Sensor Coefficients should be installed onto the Computer of the
CAS System.
Note:-
Once rigged up, the CAS System can be 'switched on' and
Electrical Communications with the Sensors can now be
established.
Page 55 of 103
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c.
Connect all Sensor Pressure Sensing connections to their
corresponding Pressure Ports utilising 1/4" Incoloy tubing
instrumentation liners and as per the P&ID Diagram.
All Instrumentation Liners to and from the Pressure Sensors
should be purged through with Hydraulic Oil, using a Martin
Decker Hydraulic Hand Pump.
Temperature Sensors come in two categories: Intrusive
Thermowell type probe:-
Schlumberger Procedures
July 2000
2.9.2 Operating Procedures
A.
On completion of the rig up and confirmation of sensor communication, it
is the responsibility of the Computer Acquisition Specialist to set up all the
relevant parameters and alarms in order to Monitor and report, efficiently
and safely, the well characteristics in accordance with the Client's
requirements.
Note:-
All set-up's are carried out by the Computer Acquisition Specialist
by manual manipulation at the computer keyboard.
a.
Onsite calibration checks of pressure and temperature Sensors
should be conducted.
Pressure and Temperature, Minimum and Maximum Alarms
should be set in accordance with Equipment Specifications and
expected Well conditions
b.
Typical Alarm Settings are as follows:i)
ii)
iii)
iv)
v)
vi)
Note:-
c.
d
e.
Note:-
The above Alarm settings are only guidance figures, it
may be required to set them in accordance with the client
requirement for specific cases.
Flow rate Alarms are set in accordance with Initial Rates obtained
during stabilisation period.
All parameters and units should be set up in accordance with the
client's requirements in order to attain the Client's required
presentation requirements.
Computer Acquisition System should be initiated prior to Well
Test activities commencing.
The monitoring of Data shall be of 24 hour coverage, with an
Operator in attendance at all times.
2.10 Transfer Pumps
As per pump specific operating procedures
Page 56 of 103
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Temperature T1 & T2:
Almax 360 deg F (90% of Equipment rating)
Almin 60 deg F(Ambient temperature)
Temperature T3 & T4:
Almax 315 deg F (90% of Equipment rating)
Temperature T5:
Almax 180 deg F (90% of Equipment rating)
Almin 60 deg F(Ambient temperature)
Temperature T6:
Almax 225 deg F (90% of Equipment rating)
Almin 60 deg F (Ambient temperature)
Pressures P1, P2 & P3:Almax 13500 psi(90% of Equipment rating)
Almin 1000 psi (approx' value, dependent on Flow
condition)
Pressure P4:
Almax 1000 psi (90% of High Pilot set Point)
Almin 220 psi (10% above Low Pilot set Point)
Schlumberger Procedures
July 2000
2.11 Surge Tanks
2.11.1 General
A
Prior to the surge tank being rotated from transportation position to
operational position:a)
b)
c)
d)
It must be inspected for damage.
It must be fitted with slings of proper lifting capacity, with proper
certification.
If sight glasses are transported separately, these should be
installed.
Check that all valves open to atmosphere are fully closed.
These include: All 3" butterfly valves
All ball valves e.g. on sightglasses.
Sightglasses feed lines on top of tank, or on gas lines.
Note:
B
Any of the above valves which are not required during normal
operation should also be plugged off.
Lifting Surge Tank to Operational Position (Vertical).
b)
c)
d)
e)
f)
g)
h)
Check with crane driver whether main block or ship line is
required, depending on weight of tank.
Secure crane to lifting slings.
Ensure that a means of restraint is available to prevent tank from
swinging violently as it reaches the vertical position. These could
include:i)
Slings wrapped round a fixed anchor point (e.g. A
samson post) and the frame of the tank. Obviously if this
is used, the banksman must ensure that , the sling cannot
be subjected to excessive forces during lifting.
ii)
Position tank on pipe beams prior to lifting, such that one
of the beams will act as a restraint.
Ensure that an experienced banksman is used.
If the operation takes place on a semi-submersible, extra cable
should be taken because of the roll and pitch of the rig due to
wave motion.
Carefully lift the surge tank to the vertical position, ensuring that
the crane boom head is kept directly above the lifting slings. This
will keep the crane wire in a vertical position, there-by reducing
the possibility of violent swinging of the tanks as it reaches the
vertical position.
Spreader beams will normally be required to spread the load.
These should be in position prior to uplifting the tank, and should
be welded down *unless not deemed necessary by senior rig
personnel e.g. on a jack-up).
Position the tank on the spreader beams, release the crane from
lifting slings. If required, the tank should be welded to the
spreader beams - mandatory on semi-submersibles and drillships.
Page 57 of 103
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a)
Schlumberger Procedures
July 2000
2.11.2 Function Testing
A
Function Testing at the Wellsite.
a)
b)
B
Preparation
a)
b)
c)
d)
C
The main purpose of the function test is to check the operation of
the sightglasses and (if fitted), high level alarm.
If there is no response, it must be assumed the part of the system is
damaged or "Shut-off". Steps should be taken to redress the
situation.
If applicable, the compressed air supply to the instruments should
be "open".
If applicable, check the stroking of the pressure control valve.
Ensure pressure control valve is "open", effluent inlet valve(s) are
"open", effluent and water dump outlet valves are "closed".
Ensure all small gauge needle/ball valves open to atmosphere are
"closed" and plugged off. Those connected to pressure gauges,
pressure controllers etc. are "open".
Function Testing
b)
c)
The tank should be filled in a controlled manner. This would
normally take place during meter factor proving. The alarm
should sound and filling operations should stop.
While the tank is filling, check operation of sighglasses. Re-check
while emptying the tank.
Pump out the tank to the downwind burner, refer to transfer pump
operating procedures.
Page 58 of 103
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a)
Schlumberger Procedures
July 2000
2.11.3 Operating Procedure
A
Flowing to tank
a)
b)
c)
d)
e)
f)
h)
Page 59 of 103
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g)
These procedures do not differentiate between single and double
compartment tank and as such do not detail individual inlet, oil
outlet or water outlet valves.
The inlet butterfly valve should never be used to control flow, and
therefore should be left in the open position. Flow will be
controlled by the oil manifold valves, which should be in either
fully open or fully closed position.
The "tank level sheet", form ABB-OPE-F087, should be used to
record tank levels throughout all operations (see page ???)
When ready to flow to tank, record the initial tank level. If
flowing oil to the tank, the water from meter factor checks should
have been drained to below sightglasses feed pipe, in order to
prevent U-tubing and false readings caused by the effect of two
differing fluids in tank and sightglasses.
Open oil manifold "tank" valve and close oil manifold "bypass"
valve. The tank level should be monitored and recorded as in c)
above. Observe for leaks at all fittings and connections.
If necessary, set the surge tank pressure control valve to the
required operating pressure.
Once required volume of oil has passed into the tank, bypass tank
open oil manifold "bypass" valve and close oil manifold "tank"
valve.
If effluent flow rates and pump capacity are compatible, it is
possible to "flow to" and "pump from" tank simultaneously. As
before, tank level must be monitored continuously and recorded at
regular intervals. In this case it is recommended that tank level is
maintained at "half-way" in order to allow "time to react" in event
of pump failure or increase/reduction in flow rate.
Schlumberger Procedures
July 2000
3. WELL PERFORMANCE AND WELL CONDITIONS
3.1 Flowing Procedures
3.1.1 Data Monitoring Requirements
A
General
a.
b.
Note:-
B.
and
the
and
is a
Preparation
a.
c.
Ensure all Pressure and Temperature Recorders are online and
fully calibrated on site, prior to Operations.
It is imperative that all Electronic Sensors are cross checked with
the corresponding Mechanical Systems.
Ensure all relevant Wellhead and Separator Reading Sheets are
available at the Choke Manifold and Separator Test areas.
Operating Procedure.
a.
During Perforating, Flow Period Data Acquisition is centred on
monitoring:i)
ii)
iii)
b.
c.
d.
These measurements are monitored and stored by CAS at 1
second intervals, the corresponding Mechanical Data is logged at
1 minute intervals and noted on Wellhead Reading Sheets.
Once the Well has been confirmed as perforated, testing
operations are conducted in accordance with the Clients Test
program.
Measures monitored in addition to that previously mentioned are
as follows:i)
ii)
iii)
iv)
v)
vi)
vii)
e.
Wellhead Pressure (WHP).
Wellhead Temperature (WHT).
Casing Pressure (CSGP).
Wellhead Downstream Pressure (WHDCP).
Separator Gas Pressure (GASP).
Separator Gas Deferential Pressure (GASDP).
Separator Oil Temperature (OILT).
Separator Gas Temperature (GAST).
Separator Oil Volume (OILV).
Separator Water Volume (WATERV).
As a general rule all mechanical surface Pressures and
Temperatures after a Choke change or during a build up period
are monitored at the following times:-
Page 60 of 103
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b.
C.
The following procedures are guidelines for the monitoring
recording of all associated Well Test Data.
Data recorded by Electronic Sensors is stored within
Computer Acquisition System (CAS)
Whereas all Mechanical Data is logged on Wellhead
Separator Reading Sheets, for every Electronic Sensor there
corresponding back up Mechanical Sensor.
Schlumberger Procedures
July 2000
f.
i)
ii)
iii)
iv)
1 minute intervals for the first 10 minutes.
5 minute intervals for the period 10 - 45 minutes.
15 minutes intervals for the period 45minutes - 6 hours.
30 minute intervals for the period 6 hours onwards.
Note:-
The above is only a general guidance, as all monitoring
of Well Test Data is done in accordance with the Clients
requirements.
During Testing Operations, Acquisation Sampling Rates of the
Electronic Sensors can be altered by Operator manipulation on
the CAS, but as a general rule monitoring is as follows:i)
ii)
iii)
iv)
D.
WHP at Wellhead is monitored at 5 second intervals.
WHT, CSGP and WHDCP at Wellhead is monitored at
15 second intervals.
GASDP, GASP, GAST and OILT are monitored at 15
second intervals, at the Separator.
OILV1, OILV2 and WATERV are monitored at 60
second intervals, at the Separator.
Operating Guidelines
b.
c.
d.
e.
On conducting clean up Flow periods, it is imperative to closely
monitor all Well data by cross checking Mechanical and
Electronic readings in order to evaluate Well activity.
At this stage, it is imperative to formulate Well Characteristics,
hence Well Data trends must be corroborated by cross checking
all corresponding Mechanical and Electronic Sensors.
On stabilisation of the Well, it may be requested to divert the
Effluent flow through the Test Separator in order to evaluate
Well Productivity.
In the event that the Well Effluent is diverted through the
Separator, it is imperative that once Separator stabilisation has
been obtained, Initial Flow Rates are validated.
In order to validate the Initial Flow Rates, all Mechanical
measures are noted and Flow Rates calculated manually by use of
INFOH1 Charts / Tables.
Note:-
Once Flow Rates have been calculated, all rates must be cross
checkedwith the computed Flow Rates obtained from the CAS.
f.
If Initial Rates are satisfactory, Flow Rate reporting shall
commence utilising the CAS.
Note:-
All Mechanical Data collection shall still be conducted at 15
minute intervals.
g.
Once every hour, at a minimum, all computer acquired Flow
Rates must be cross checked with manually calculated Flow
Rates.
h.
If at any time spurious Flow Rates are obtained, the Sensors
concerned must be investigated in order to evaluate if there are
any malfunctions of the sensors, equipment or if Well
Productivity is unstable
Page 61 of 103
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a.
Schlumberger Procedures
July 2000
Note:-
Any spurious Data will be immediately noticed by means of
'Alarm' activation within the Computer Acquisition System.
Schlumberger Private
Page 62 of 103
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Schlumberger Procedures
July 2000
3.1.2 Perforating Flow and Initial Shut-In Procedure
A.
General
The following procedures are guidelines and assume T.C.P's are being
used to perforate the Well.
B.
Preparation
a.
b.
C.
Ensure all Safety Systems are checked and put on-line, prior to
the operation start-up.
Valves are lined up to perforate the Well as per the Program.
Operating Procedure
a.
b.
c.
d.
Pressure up Annulus to 'open' P.C.T.
Perforate Well as per the Program.
After perforating, allow Well to Flow against a 'closed' Choke for
___minutes.
Monitor WHP, WHT and CSGP.
After ____ Minutes, bleed off Annulus pressure to 'close' PCT
for downhole build-up for ____ minutes.
Schlumberger Private
Page 63 of 103
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Schlumberger Procedures
July 2000
3.1.3 Initial Flow Clean-up Procedure
A.
General
a.
Prior to, 'opening', the Well, hold a Safety meeting on the Rig
Floor. Discuss the following points:i)
ii)
iii)
iv)
v)
B.
Location of Emergency Shut Down (ESD) buttons and
the necessary action in the event of an ESD.
Actions to be taken in the event of H2S being detected.
All welding operations must cease and all 'Hot Work'
Permits to be withdrawn or issued for the duration of the
Flow Period.
All nonessential personnel must keep clear of the Rig
Floor and Well Test Area, for the duration of the Flow
Period.
No Crane movements over any of the Well Test
Equipment or Flow Lines.
Preparation
a.
i)
ii)
iii)
The entire Flow Path should be physically checked
ensuring that all Valves are in the correct positions to
ensure the Separator and Steam Exchanger are bypassed.
In the event of Hydraulic Valves being utilised, the
Hydraulic Operating Pressures should be checked in
accordance with the Visual Indicators on the Valve
Operating Actuators
Ensure the following:1.
2.
3.
4.
5.
6.
7.
8.
9.
Pilot to the relevant Burner is lit.
The Water Screen is in Operation.
A Well Test Operator is stationed near the
Burner.
The Steam Generator is fully fired up.
The Adjustable Choke has been correctly
'zeroed'.
A suitable sized Fixed Choke is installed on the
fixed side of the Choke.
The Work Permit has been re-endorsed for the
Testing Phase of Operations.
The Radio Operator has notified:
a.
The Coastguard of the Rig's intention
to commence Flaring
b.
The Standby Boat and any Helicopters
of the Rig, intention to 'open' up the
Well.
Make a Tannoy announcement to inform Rig
Personnel that the Well is about to be 'opened'
up.
Page 64 of 103
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Prior to 'opening' the Well for the Initial Clean-up Flow Period,
as detailed by the Client's Test Program, the Well shall be flowed
either to a Gauge / Surge Tank or to the Burner Heads. The
flowing must be checked:-
Schlumberger Procedures
C.
July 2000
Operating Procedure
a.
Make a final check on:
i)
The wind direction
and
ii)
b.
c.
d.
e.
Pressure up the Annulus to 'open' the Tester Valve and allow the
Wellhead Pressure to stabilise.
Check the position of the Tester Valve and cycle to a 'Fail Safe'
position, i.e.. Not 'locked open'.
With the Adjustable Choke set at 8/64" Choke, 'open' the front
Valve on the Choke Manifold.
Monitor the 'downstream' Choke Pressure.
If the Pressure rises fast, the Well should be 'shut-in' and the
problem investigated.
f.
g.
Bean up Well in 4/64" stages, or as instructed by the Engineer.
Monitor Annulus Pressure and bleed off as required.
Note:-
Annulus Pressure will rise as the Well heats up.
h.
When Hydrocarbons reach the surface, monitor for H2S and CO2
at the Choke Manifold, at ____ minute intervals, until levels have
stabilised.
The Well will be considered 'clean' when:-
i)
ii)
iii)
BS and W has been 'constant' for over 2 hours.
The Solids content is < 1%.
The Wellhead Pressure is 'constant' or declining as a 'log
function' of time.
k.
When the Well is cleaned up, divert the Well through a Fixed
Choke.
Divert the Flow through the Separator.
l.
Operating Guidelines
a.
Do not conduct the Initial Flow Period with the Tester Valve in a
'locked open' position.
Note:-
Always cycle the Tester Valve to a 'Fail Safe' position.
b.
All Choke Tips must be integral or screwed and pinned to the
Shaft.
A Choke Tip that comes off will slam into the Choke Seat
resulting in a sudden increase in Well Head Pressure.
Note:-
c.
On Low Rate Wells it can be advantageous to switch to a Fixed
Choke if the Adjustable Choke is plugged with debris.
Page 65 of 103
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Note:-
j.
D.
There are no boats a adjacent to the Rig.
Schlumberger Procedures
July 2000
Note:- If a Fixed Choke is used for the Clean up Flow, it could become
damaged or partly plugged and must therefore be inspected of
changed out for the Main Flow period.
d.
For Gas Wells the Flow must initially be directed to the Burners.
Note:-
Only if the Well does not appear to be flowing may the Well be
diverted to the Surge Tank for a short period of time to confirm if
the Well is Dead.
e.
For Oil Wells, no more than half the cushion is to be flowed to
the Surge Tank. The Flow is then diverted to the Burners.
If the Well is producing Solids, at least one String Volume
should be produced between Choke changes.
During clean-up it is not necessary to maintain critical Flow
across a Choke, so doing would compromise the complete
removal of Mud / Brine from the Casing.
When the Well is clean, critical Flow can be re-established by
Beaning down the Choke as required.
Clean-up is most easily detected from looking back at the process
trends (WHP, WHT, BS&W and is easier to spot in hindsight
rather than as it happens.
f.
g.
h.
j.
E.
Contingencies
If during the Initial/Clean-up Flow period 'Zero' Pressure and / or
'No Flow' is evident, under the instruction of the Client Reservoir
Engineer it may be advisable to proceed as follows:i)
ii)
Continue flowing the Well to the Gauge/Surge Tank
whilst monitoring the Fluid returns via a Sampling Hose
at the Choke Manifold
By submerging the Hose in a drum of water it may
become apparent that the Well is in fact:
1.
2.
iii)
b.
Indicating Positive Flow (Indicated
produced bubbles)
Indicating Negative Flow (Indicated
reducing water level).
by
by
'Close' in the Well at the Choke Manifold and monitor
for any Pressure indication, utilising the Bourdon Type
Pressure Gauges, positive and negative pressure can be
monitored.
In the event of Flow being established, if any one of the
following unexpected Hostile Well conditions are encountered,
refer to Section 3.2. 'Hostile Well Condition's'.
i)
ii)
iii)
iv)
v)
Excessive Solids production after Well Fluids have
reached surface.
Hydrate formation downstream of the Choke Manifold.
Foaming or Emulsified Oil.
Sand production.
H2S > 50 ppm.
Page 66 of 103
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a.
Schlumberger Procedures
July 2000
3.1.4 Initial Shut-in Period
A.
General
The following Procedures assume the Well is 'open' to the front Valves of
the Choke Manifold and ready to be flowed until stable, prior to switching
the flow through the Separator.
B.
Preparation
a.
b.
c.
Ensure Data Acquisition requirements and Sampling frequencies
are properly set up and running.
Ensure all ESD stations and Hi-Lo Pilots are activated. As PSL 1
is a variable set Pilot it is required that this Pilot is set at
approximately 1000 - 2000 psi below the stabilised flowing
Wellhead pressure.
Before diverting Flow to the Separator check the following:-
vi)
C.
Operating Procedure
a.
b.
c.
d.
D.
The Orifice Plate is raised.
The Oil Meters are by-passed.
All Valves to the Sampling Points etc. are 'closed'.
The Instrument Air supply is 'on'.
Manual Valves downstream of the Control Valves are
'open'.
The Gas and Oil Lines are correctly lined up to the
Flare.
'Open' Choke Manifold on small adjustable Choke and Bean up
to selected Choke Size.
Switch Flow to fixed Choke and allow Well to stabilise taking
standard readings.
Monitor the upstream and downstream pressures across the
Choke for signs of 'plugging' or 'cutting out'
Note:Always maintain Downstream Pressure to within
equipment Design Pressure.
Divert Flow to Separator and produce at stable conditions on a
Fixed Choke for ____ Hours.
Operating Guidelines
a.
b.
Monitor Annulus Pressure (This will increase as Well heats up).
Bleed off Annulus Pressure as required to maintain Annulus
Pressure between ____ psi and ____ psi.
Note:-
Never use an Adjustable Choke for the Stable Flow Period to the
Separator.
Shrinkage:-
c
i)
ii)
iii)
Estimate shrinkage using the Shrinkage Tester and
correlations.
Compare measured Flow Rate times Shrinkage Factor,
against Gauge/Surge Tank readings (allow time for the
shrinkage of the Gauge Tank to occur).
Any significant difference should be investigated.
Page 67 of 103
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i)
ii)
iii)
iv)
v)
Schlumberger Procedures
July 2000
Note:-
Possible causes of difference are, Gas entrainment in the Oil Line
or mechanical damage to the Oil Meter.
d.
Transducer Lines:i)
ii)
e.
f.
Note:-
Transducer Lines must be bled down to prevent any
liquid build up at the Orifice Plate or in the Transducer
Lines.
If lifting the Plate and bleeding the Lines makes a
difference to the calculated Flow Rate, then the Plate
and Lines must be lifted/bled down more frequently at
some time during the Main Flow Period (Not while
taking PVT Separator Samples).
Critical Flow should be maintained across the Choke during the
Main Flow Period, unless the Well Objectives specially state
otherwise.
When practical, Chemical Injection should be stopped at least 1
hour or, a minimum of two Separator Volumes before the taking
of Separator PVT Samples.
The following operations can effect the quality of PVT Separator
Samples and should be avoided if possible:Switching Burners while Sampling.
Switching Flow from the Burners to the Surge Tank.
Changing the Orifice Plate.
Changing the Steam Exchanger operating conditions.
Changing the Separator Level Controller.
Changing the Separator Pressure Controller.
Page 68 of 103
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i)
ii)
iii)
iv)
v)
vi)
Schlumberger Procedures
July 2000
3.1.5 Downhole Build-up Procedure
A.
General
After Flowing the Well at Stable Rate for the required time, the Well
should be shut-in downhole at the PCT. The procedure for this operation
is as follows:-
B.
Preparation
a.
b.
C.
By-pass Meter and lift the Orifice Plate.
Switch the Propane to the Burners 'on'.
Operating Procedure
a.
b.
c.
d.
f.
Bleed off Annulus Pressure to 'close' PCT.
Monitor Wellhead Pressure till it drops to around 500 psi from
the Flowing Pressure, giving a good indication of PCT 'closure'.
'Close' Choke and observe WHP to establish good seal downhole
By-pass the Separator. See Section 2.4.5.
Allow WHP to stabilise before rigging up any Wireline.
Schlumberger Private
Page 69 of 103
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Schlumberger Procedures
July 2000
3.1.6 Surface Build-up Procedure
A.
General
After Flowing Well at stable rate for the required time, the Well should be
Shut-in at Surface at the Well Test Choke Manifold.
The procedure for this operation is as follows:-
B.
Preparation
a.
b.
c.
d.
C.
Operating Procedure
a.
b.
e.
f.
'Close in' Well at Choke Manifold.
Monitor Wellhead Pressure to ensure that there is a positive
indication of 'closure'.
By-pass Separator. See Section 2.4.5.
Once 'closure' is assured, 'close' in Production Tree Flow Wing
Valves.
Bleed off Surface Pressure at Choke Manifold to Burner Heads
and ensure 'Zero' Pressure throughout all Surface Equipment Test
Lines.
Monitor Surface Pressure at Production Tree Swab Valve.
Operating Guidelines
a.
b.
c.
All Pressure monitoring shall be conducted at the Production
Tree Swab valve Pressure Ports by Schlumberger Personnel.
All Data monitoring shall be in accordance to Client's
requirements.
Data collection between Mechanical and Electrical Sensors to be
cross-checked in order to validate relevant Data.
Page 70 of 103
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c.
d.
D.
By-pass Meter and lift Orifice Plate.
Switch Propane to Burners 'on'.
Ensure Computerised Data Acquisition (CDA) is set to Client's
requirements.
Ensure relevant Wellhead Data Sheets are available.
Schlumberger Procedures
July 2000
3.2 Hostile Well Conditions
3.2.1 Common Surface Testing Problems
CAUSES
CONSEQUENCES
- High viscosity
FOAMING
- Heavy gases
( C2, C3 and CO2 )
SOLUTIONS
- Poor separation and
metering
- Chemical additives
( Silicon )
- Pumping difficulties
- Heating
- Water
- Increase retention time
- Water vapor condensation - Plugging
- Heating
- Low temperature / High
pressures
- Chemical Injection
HYDRATE
- Poor flow characteristics - Heating before separator
- Heating of the tanks
- Exceptionally diesel
mixing
EROSION
- High solids content
- High velocity
- Safety Hazard
- Increase pipe wall
thickness
- uncontrolled leaks
- Decrease velocity
- Excessive clean up time
- Avoid tortuous flow path
- Damage to equipment
- Special equipment
Page 71 of 103
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HIGH VISCOSITY - Heavy crude oil
Schlumberger Procedures
July 2000
3.2.2 Foaming Prevention Procedures
A.
General
Foaming is caused by the liberation of micro bubbles in the oil, due to
either a large pressure drop or a delayed gas evolution caused by
liberation of heavier Gases (C2, C3, CO2).
Note:-
Foaming will prevent good Separation, ruin Gas and Liquid
Metering and Sampling.
Foaming can cause oil 'carry-over' to the gas flare and pollute the sea.
B.
Preparation
a.
b.
C.
Rig up Chemical Injection Pump upstream of Choke Manifold.
Lower level in Separator by increasing Separator Pressure.
Procedures
a.
To prevent foaming, the following factors can be of assistance:i)
iii)
Page 72 of 103
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ii)
Increase the Temperature of Fluid by passing Flow
through the Steam Exchanger.
Inject Anti Foam Chemicals upstream of Choke
Manifold.
Increase the retention time in Separator.
Schlumberger Procedures
July 2000
3.2.3 Water Emulsion Breaking Procedure
A.
General
a.
B.
If any Emulsion is being produced, this will affect the Oil and
Water Rates respectively, so it is important to break the Emulsion
down.
Procedure
a.
The break down of Emulsion can be done by:i)
ii)
Increase the Separator Temperature.
Inject Demulsifying Chemicals.
Schlumberger Private
Page 73 of 103
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Schlumberger Procedures
July 2000
3.2.4 Hydrate Inhibition
3.2.4.1
(Part 1) Hydrate Inhibition
A.
a.
Natural Gas always contains Water Vapour and Reservoir Gas is
nearly always saturated with Water Vapour under Reservoir
conditions.
b.
Temperature and Pressure changes from Subsurface to Surface,
always cause condensation of part of this Water, both, within the
Well by drop in Temperature of the Gas moving to the Surface,
and in Surface Equipment when Temperature is dropped by
Throttling or Expansion.
c.
Free Water in Gas is a serious problem because it tends to freeze
in the Field Equipment in the form of Hydrates, making Meters
and Valves inoperative and even plugging Chokes or Pipelines.
d.
Natural Gas Hydrates have the appearance of hard Snow and
consists of Chemical Compounds of light hydrocarbons and
liquid Water.
e.
Natural Gas Hydrates are formed at Temperatures above the
normal Freezing Point of Water when lower hydrocarbons
dissolve in Liquid Water under certain conditions.
f.
The above formation process is accelerated when there are High
Gas Velocities, Pressure Pulsations or other agitation, such as at
elbows, which cause mixing of Hydrate components.
g.
The Higher the Gas Pressure, the Higher the Temperature at
which Hydrates will form.
h.
The Higher the Specific Gravity of the Well Steam, the Higher
the Temperature is for Hydrate Formation.
j.
At equal Pressures Ethane, Propane, H2S and CO2 form
Hydrates at Higher Temperatures than Methane.
k.
Hydrate Formation is therefore promoted by the presence of
these Components in the Gas, whereas N2 and Penthane plus
have no noticeable effect.
l.
Reduction of the Pressure by free expansion below 5000 psi
(Expansion above this point has little effect), results in a lowering
of the Gas Temp.
Hydrate Removal/Prevention
A.
General
Page 74 of 103
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3.2.4.2
General
Schlumberger Procedures
July 2000
a.
b.
c.
d.
B.
Preparation
a.
b.
c.
d.
High / Low Pilots are set to correct values (Normally 10% below
Maximum Working Pressure of the section of line) and are
Function Tested on Site to check operation.
Pipework is rated for Maximum Shut-in Pressure or protected by
the appropriate High / Low Pilots.
Pressures throughout the Production System must be continually
monitored to observe for build-up in Pressure or Wash out across
the Chokes.
Methanol and Glycol should be available for injection into the
Well Stream to:
i)
Break down Hydrates
or,
ii)
Prevent formation of Hydrates.
Procedures
a.
Heating the Gas above the Temperature of Hydrate Formation.
i)
Heating the Fluid will reduce the chances of Hydrate
Formation so it is advisable to have the Heater as close
as possible to the back of the Choke or if possible use
the Choke on the Heater to control the Well so long as
the Heater is rated for the Maximum Well Shut-in
Pressure.
b.
Injecting Glycol upstream of the Choke Manifold as soon as Gas
is at Surface may prevent the formation of Hydrates.
Reducing line pressure when Hydrates have formed, to allow
them to melt.
c.
Note:-
This solution is however only temporary and is not always
applicable.
d.
Injecting anti-freezing agents such as Methanol (Methyl Alcohol)
upstream of the Choke Manifold, causes Liquid Water deposits to
dissolve and so not contribute to Hydrate Formation.
During Wireline Operations it is recommended to inject Glycol to
prevent Hydrate forming on moving wire.
e.
Page 75 of 103
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C.
Special measures are necessary to prevent obstructions in Gas
Lines resulting from Hydrate deposits at Low Temperature.
During Well Testing, one or a combination of the following
Procedures may be used.
Hydrate Formation can occur at any point in the Process
Equipment causing a blockage in the line which will lead to an
'over pressure' of that particular section of Pipe, effectively
shutting the Well in at the point where the Hydrate occurs.
To cover for the above possibility we have to make sure a
number of options are covered.
Schlumberger Procedures
July 2000
3.2.5 Sand Control
3.2.5.1
Sand Control Overview
A.
General
a.
If a relatively large amount of Sand is produced during Clean-up
periods, then problems could arise from:i
ii)
b.
The erosion problem is by far the worst because it can happen
very quickly giving little chance of discovery before it is too late.
Note:-
If Sand is expected either by knowledge of having an
unconsolidated formation or by carrying out a Sand frac,
measures can be taken to prevent or reduce the problems which
arise from flowing Sand. As follows:i)
A Sand Filter System can be installed into the Process
set-up, this consists of different sizes of Filters which
will catch the Sand before it reaches the Process
Equipment.
If very large quantities of Sand production are expected,
then the completion should be designed either with a
Gravel Pack downstream or a dedicated Clean-up Line
at Surface which by-passes the Normal Production
Equipment.
Preparation
Sand production can be monitored by installing In-Flow Probes which
record the amount of Particle impacts and calculates a Sand Production
Rate, extra Pipework, fittings and Valves and Ancillary Equipment
required.
C.
Procedures
a.
b.
c.
Pipework wall thicknesses can be monitored before and during
the Clean-up Flow , to give a regular check on the effects of
erosion.
If Sand production is expected to be large, a Sand Filter System
can be installed into the Process Set-up. This consists of different
sizes of Filter which will catch the Sand before it reaches the
Process Equipment.
If very large quantities of Sand production are expected, then the
completion should be designed either with a Gravel Pack
downstream or a dedicated Clean-up Line at Surface which will
by- pass the normal Production Equipment.
Note:-
A lot of thought should be given to designing a set-up to handle
Sand Production because it is potentially the most hazardous of
Well Test Operations.
d.
When large quantities of Sand are produced requiring the test to
be aborted, care must be taken to reduce the Flow gradually to
prevent the Tubing Plugging.
Page 76 of 103
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ii)
B.
Erosion of Pipework.
Plugging of Tubing.
Schlumberger Procedures
July 2000
Note:-
It is recommended that the Flow Rate be reduced at the Choke
Manifold in steps of 8/64" every 1/4 hour or, by 2 Tubing String
Volumes 8/64" change, whichever time is longer.
3.2.5.2 Sand Control Procedures
A.
Preparations
a.
b.
Note:-
c.
d.
e.
g.
h.
j.
B.
For weight determination of lbs. per bbl of Oil, a separate
procedure will be required.
Ensure Portable Centrifuge is available to eliminate time
difficulties due to travel between Choke and Lab Cabin.
Extra Pipework, fittings and Valves (Full Flow), plus Thickness
Testing Equipment must be available, including back ups.
Install Chokes at Booms. The rig up to be done so that the line is
as straight as possible, using reinforced elbow bends.
Use 4" Clean-up lines from Sacrifical Choke Manifold fitted with
two fixed Chokes at each Boom and one Master-flo Adjustable
Choke downstream of the Sacrifical Choke Manifold.
Prior to rig up, all Pipework and key Wash Out Areas of the
Process System are to be tallied and Thickness Values reported
for washout potential Post Test Analysis. (See fig 2, fig 3)
As large a Sump as possible should be available for
contingencies and to enable Sand consolidation well below the
Test Tools, particularly if T.C.P Guns are run.
Install Hi-lo Pilots between Boom Chokes and All other Process
Equipment by HAZOP Analysis.
Coil Tubing and Ancillary Equipment to be onboard and rigged
up during Flowhead Rig-up Procedures (Coil Tubing Rig-up
Procedures)
Operating Procedures
a.
b.
c.
d.
Run Test String and drop T.C.P Guns as soon as possible. (If
applicable)
'Open' Well through the Sacrifical Choke, by-passing Sand Trap
for clean-up to Boom Chokes and establish Sand quantities as
soon as possible by taking BSW downstream of the Sand Trap.
As soon as the Cushion is displaced, monitor CO2 and H2S as
soon as possible.
Once the Sand Rate (Established) is found, switch on Sandec for
Optimum Choke Size Determination and Sand Depletion
Monitoring.
Note:-
Follow Multiphase Sandec Procedures for Optimisation.
e.
Switch flow through the Sand Traps as per Sand Filter Operating
Procedure and Fig 1, Schematic.
Once the Sand Rate is stable and under control through the Sand
Trap, flow the Well through Process Choke Manifold.
Switch the Flow through the Separator once Sand Control is
established.
If large quantities of Sand are present, calculate the Volume and
its effects according to Well Shut- in Procedure.
f.
g.
h.
Page 77 of 103
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f.
Install in-flow Probes which record the amount of particle
impacts and calculate Sand Production Rate.
All BSW to be taken in 100 cc receptacles for improved
percentage accuracy and weight determination if required.
Schlumberger Procedures
July 2000
Note:-
3.2.5.3
Check thickness of Sacrifical Process Lines and replace elbows as
needed, in case Flow needs to be switched back to Sacrifical Lines.
Sand Filter Operating Procedure (Ref: Fig 1)
Note:-
A.
Ensure that V1 is always kept 'closed' throughout the operation. It is
not needed at all.
Start-up Procedure, Flowing through Pot A.
a.
b.
c.
B.
To Switch from Pot A to Pot B.
a.
b.
m.
n.
Note:-
Ensure Valves V11 and V13 are 'closed'.
Slowly 'open' V17, V16, V15 and V14 in this order to equalise
pressure from Pot A to Pot B.
When Pressure between Pot A and Pot B is equalised, 'open' V5.
'Open' V6.
'Open' V4.
'Open' V7. The Flow is now passing through Pot A and Pot B.
'Close' V9.
'Close' V2.
'Close' V8.
'Close' V3.
'Close' V17, V16, V15 and V14. The Flow is now passing
through Pot B, with Pot A isolated.
Slowly 'open' V10. This will bleed pressure from Pot A.
When pressure in Pot A is zero, 'open' V12 to drain liquid from
Pot A.
The Filter Screen can now be removed and checked for any Sand.
To Switch from Pot B to Pot A.
a.
b.
c.
d.
e.
f.
g.
h.
j.
k.
l.
m.
o.
Note:-
Ensure V12 and V10 are 'closed'.
Slowly 'open' V14, V15, V16 and V17, in order to equalise
pressure from Pot B to Pot A.
When pressure between Pot B and Pot A is equalised, 'open' V3.
'Open' V8.
'Open' V2.
'Open' V9. The Flow is now passing through Pot B and Pot A.
'Close' V7.
'Close' V4.
'Close' V6.
'Close' V5.
'Close' V17, V16, V15 and V14. The Flow is now passing
through Pot A, with Pot B isolated.
Slowly 'open' V11. This will bleed pressure from Pot B.
When Pressure in Pot B is zero, 'open' V13 to drain liquid from
Pot B.
The Filter Screen can now be removed and checked for any Sand.
Page 78 of 103
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c.
d.
e.
f.
g.
h.
j.
k.
l.
C.
Ensure Valves V1, V4, V5, V6, V7, V10, V12, V15, V16 and
V17 are 'closed'.
Ensure Valves V2, V3, V8 and V9 are fully 'open'.
The Well can now be 'opened' with the Flow directed through Pot
A.
Schlumberger Procedures
July 2000
3.2.5.4 Sand Monitoring Procedures
A.
Operating Guidelines
Once Hook-up is completed and Pressure Tested, a schematic
drawing should be made showing every Elbow from the
Wellhead to the Burner Booms (Fig.2).
Note:-
This drawing should incorporate two measure points for each
Elbow, as shown.
b.
A Thickness measure should be taken at each of the points before
any Flow Periods occur. This should be recorded on a separate
sheet as shown. (Fig.3).
When Flowing commences BS & W's should be taken as per
normal practice. These should be taken downstream of the Sand
Filter.
If BS & W's show Sand, then a finer mesh Filter must be inserted
into Sand Pot.
Thickness Tests should be conducted every hour. The results
should be logged on the sheet shown in Fig.3.
If during a Flow Period the Thickness Test Log shows that a
particular Elbow is nearing its minimum thickness limit, a
decision must be made to abort the Flow Period.
If, after a Flow Period the Thickness Test Log shows that a
particular Elbow is nearing its minimum thickness limit, then this
Elbow must be replaced and Pressure Tested before any
subsequent Flow Period can take place.
c.
d.
e.
f.
g.
Page 79 of 103
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a.
Schlumberger Procedures
July 2000
3.2.6 Hydrogen Sulphide (H2S) Well Testing
A.
The Main Safety Points are as follows:a.
b.
c.
d.
e.
f.
Permit To Work Procedures will be followed without exception.
Liquid Nitrogen is a Cryogenic Liquid with a boiling point of 195.9 °C. Any contact with Liquid Nitrogen will produce severe
cold burns to the skin and eyes.
Nitrogen Gas is an Asphyxiant and should only be used in a well
ventilated area.
All High Pressure Flow Lines should be secured to the deck at
regular intervals by cable.
All non-essential Personnel will remain out of the Work Site
during operations.
Ensure Annulus Return Line Relief Valve is 'open' at all times
when displacing the Well Fluid.
Ensure all discharge Lines from Relief Valves are directed away
from the Work Site.
g.
Monitor and record Pump Pressures and Wellhead Pressures
continuously throughout the operation.
Warning' signs should be placed on the Flowhead and relevant
parts of the Panel indicating Coiled Tubing Operations are in
progress.
Regular announcements should be made regarding High Pressure
Nitrogen Operations, using Coiled Tubing.
A Safety Meeting should be held prior to the Operations. This
meeting will include a discussion of Procedures, Contingency
Plans, Emergency Plans and Platform 'Alarms'.
Cordon off Work Area with Red and White tape and post
'Warning' Signs.
Shear Seal Valves/Combi-BOP's will be operated from Coiled
Tubing Cabin and Remote Panel on the Rig Floor.
h.
j.
k.
l.
m.
Page 80 of 103
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Note:-
Schlumberger Procedures
July 2000
3.2.6.1 General Procedures
Note:-
If H2S is suspected, all Testing Personnel will be masked up at Initial
flow.
De-masking will be allowed after it has been determined that the H2S Levels are
below those specified in the "Guidelines For Working With Hydrogen
Sulphide".Section 3.2.6.3.
A.
B.
Condition 1
H2S Level Unknown
a.
Unloading of Wells.
b.
POOH with Completion Test Tools.
c.
Circulating bottoms up.
d.
Procedures:i)
ii)
iii)
All non-essential Personnel to stay in Accommodation.
All Essential Personnel must wear BA Sets.
Stand-by Boat to be alerted and positioned up wind of
the Rig.
Condition 2
Stream
H2S Level less than 10ppm in Air or below 250 ppm in
C.
Condition 3.
a.
D.
Procedures:i)
Non-essential Personnel to stay in Accommodation.
ii)
Essential Personnel must have BA Set's standing-by.
iii)
Check all Sensors and Safety Equipment for Valid
Certification of Maintenance and Reliability.
Procedures:i)
Non-essential Personnel to stay in Accommodation.
ii)
Essential Personnel to Mask-up on hearing the Tannoy
announcement.
iii)
Control Room to instruct all non-essential Personnel to
go to Safe Briefing Area within Accommodation.
iv)
Shut-in Well, continued operations will be at the
discretion of the OIM, after consideration of all the
relevant factors.
Condition 4.
a.
H2S Levels above 10 ppm in Air or above 250 ppm in
Stream
H2S levels above 1500 ppm in Stream
Procedures:i)
All Working Personnel outside Pressurised Areas will
be in 'buddy' teams.
ii)
If a Person is seen to collapse in an area, immediately
close in Well at the Surface Tree Wing Valve and
evacuate the Area.
The Rig Emergency Team with BA Sets are the only
Personnel who should give assistance to the victim.
iii)
Levels of 25ppm in Air must be relayed to town.
iv)
'Opening' the Rig wind wall doors to allow maximum
Air Flow is essential.
v)
If H2S concentration in Air is 250 ppm or greater, the
Stand-by Boat or Helicopters should not approach the
Rig. Evacuation should proceed via the Rigs Lifeboats.
Page 81 of 103
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a.
Schlumberger Procedures
3.2.6.2
July 2000
Essential Precautions
A.
General
a.
b.
c.
NO LEAKS OF ANY SORT ARE PERMISSIBLE, in
Equipment to be used during Testing Operations when H2S is
present.
d.
Separator Instruments and any other Pneumatic Equipment shall
be supplied from Compressed Air. Produced Gas shall not be
used to operate any equipment.
The Shrinkage Tester and galvitometer when used shall be vented
to a Safe place.
Breathing Apparatus (BA) must be worn when sampling Well
Effluents and performing any Equipment Operation that may
result in an exhaust of Gas, changing Chokes etc.
Equipment over Pressure Relief Valves Systems shall be vented
through a dedicated Relief line overboard to the Burners. Tank
Vents shall also be directed overboard.
f.
g.
H2S Safety Equipment and General Precautions
a.
b.
c.
d.
e.
f.
g.
h.
j.
Sufficient positive pressure Breathing Apparatus Sets should be
located at Strategic Working Areas to ensure that the 'on tour'
personnel each have one (60 minute type).
All Personnel will be familiar with the operations of Equipment
that will be utilised.
Training on the proper use of Equipment will be given to all
relevant Personnel, prior to Testing.
Rig H2S Alarm System should be thoroughly Function Tested
and checked prior to start of Test.
A complete First Aid Kit must be available on board the Rig.
A meeting will be held prior to Perforating the Well to ensure
that all personnel are familiar with H2S Symptoms and
Emergency Procedures.
All Personnel should be made fully aware of their duties during
any possible Emergency without any doubts.
The Test Crew and the Rig Crew will monitor for H2S with
Draeger Tubes at the Choke Manifold as soon as Hydrocarbons
are produced to the surface and thereafter every Hour.
Checks shall also be taken from the Separator Oil, Water, and
Gas Outlets.
Page 82 of 103
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Note:-
e.
B.
The following general practices are essential to minimise the time
to detect H2S and for Oxygen deficiency in confined spaces.
As H2S is heavier than Air, these checks should be taken at deck
level.
A 'buddy' system should be operated during these checks,
whereby an observer will be situated in a Safe Area whilst the
other performs the Gas Checks.
In confined areas a Safety Harness with a Safety Rope should be
worn, with the Safety Rope being held by the 'observer' at the
ready for immediate retrieval of the Operator in the event that the
Operator requires assistance through H2S exposure.
Schlumberger Procedures
July 2000
Note:-
Should any H2S be detected the Client's Representative must be
informed immediately.
k.
Personnel will be instructed on "Guidelines For Working with
Hydrogen Sulphide".
During Initial Testing, Rig Personnel will be directed to keep
clear of the area downwind and below the Test
Equipment/Pipework.
Stand-by Boat and or Work Boat will be on 'alert' and directed to
stay up wind of the Rig.
l.
m.
n.
The Test String, Wellhead, BOP's and Surface Test
Equipment will conform to NACE Standards for Sour
Service as applicable.
3.2.6.3 Guidelines for Working With Hydrogen Sulphide
A.
Open Hole Logging
a.
b.
B.
When pulling out of the Hole, all Tools and Cables shall be
washed with Scavenger and sprayed with Inhibitor.
BA Sets to be worn when handling RFT Samples and Chamber,
until Chamber has been purged.
Testing
To cope with this eventuality, the following precautionary guide
lines must be taken.
a.
b.
c.
d.
e.
f.
g.
h.
A Safety Meeting should be held well in advance of Testing
when all Personnel are to be informed that H2S is present or,
likely to be present.
All Testing Equipment shall be certified and approved for H2S
Sour Service as per NACE MR-01-75 latest edition.
Unless otherwise stated below, all normal Testing Procedures
will be observed i.e. First opening of Tools will be in daylight.
On Initial Opening of the Well, BA Sets shall be worn by all
Personnel on the Rig Floor, Test Deck Area and Mud Room, and
they will continue to be worn until the concentration level of H2S
being produced has been established.
Depending on the level of H2S, Personnel will be permitted to
unmask in accordance with testing conditions.
In stream H2S will be monitored every 10 minutes during initial
Flow until Gas Level has been determined. There after every 30
minutes.
Positive sources of Ignition will be provided for both Oil and Gas
Burners.
The Testing Period referred to in this section is defined as 'whole
time' from the Well being Perforated until the Well is Killed and
the Test String recovered to Surface.
All non-essential Personnel shall restrict themselves to the
Accommodation Area during Testing Periods.
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Note:- This phase of Drilling Operations will be the first time at which
H2S may be produced at Surface, consequently the Risk Factor is
higher.
Schlumberger Procedures
July 2000
The control of all Personnel movements is the responsibility of
the OIM who will consult with the Clients Drilling Foreman.
j.
BA Sets will be worn by all Personnel outside the accommodation
during Initial Test Well opening and during Testing Operations,
should H2S be present.
Note:-
The requirements to Mask-up will be sounded via a Tannoy
message and/or a Gas Alert 'Alarm', as circumstances dictate.
k.
When H2S is present in stream, no Test will be conducted if
Wind Speed is less than 15 or more than 40 knots.
Note:-
The OIM may decide that the direction of the Wind presents a
hazard e.g. Blowing onto the Accommodation, and will terminate
the Test.
l.
All non-essential Personnel should be taken off the Rig before
commencement of Test.
No 'open' tanks will be used for the collection of Flow Products.
Surge Tanks and Separators will be equipped with Overboard
Vents/Relief Lines to Flare or to below lowest Rig Level.
Testing Personnel will Mask-up prior to operating Valves or
'opening' Equipment that had contained H2S, for example,
Changing Chokes, using Bubble Hose, and Sampling.
There will probably be a background level of H2S during Testing
which can come from a variety of sources, i.e. Incomplete
Combustion at the Flare, Weeping Valves, Flanges, Chicksan,
etc. It is important to be aware of this background level of H2S
and monitor it closely for any increase and take the appropriate
action.
The Installation should also be monitored for Sulphur Dioxide
(SO2), which is a by-product of burning H2S, using hand
operated Monitors (Draeger Tubes).
m.
n.
o.
p.
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Note:-
Schlumberger Procedures
July 2000
q.
At the end of the Test:i)
ii)
Note:-
H2S Scavenger may be added to the Mud.
r.
s.
Prior to pulling out of Hole, slug Tubing with Inhibitor.
Five minutes before the first Test Tool, i.e. Reverse circulate
Valve, all Drill Floor Personnel will Mask-up with BA Sets and
will continue to wear them until the Test String has broken out
and the Sample Chambers have been emptied and 'purged'.
Note:-
When deciding on the specific action to be taken in the event of
certain levels of H2S in the Air at the sensors and the
concentration of H2S, it must be remembered that both the
concentration of H2S in the Air at the Sensors and the
concentration of H2S in-stream must be considered.
t.
Whichever Condition has the more stringent precautions, will be
taken.
H2S In Steam
a.
20 - 150 ppm
i)
Note:-
ii)
iii)
iv)
b.
Flow Periods may continue into the night.
The Well may be re-opened at night provided that no
Surface Lines had been 'opened' (broken) within the
Test System.
Test duration should be kept to a minimum.
150 - 250 ppm.
i)
ii)
iii)
iv)
c.
Personnel who are masked-up at Initial Well 'opening'
can now de-mask, if concentration level is established to
be below 150 ppm.
Tannoy instructions will be made. Exceptions will be
Personnel operating Valves or who are involved in
sampling Well Effluent.
Personnel in the Testing Area and Rig Floor will maskup, Tannoy instructions will be given.
Flow Periods may continue into the night.
Well will NOT be opened at Night.
No Helicopters to land on Rig when Well is Flowing.
250 - 500 ppm.
i)
ii)
iii)
All Personnel outside the Accommodation will Maskup.
If H2S concentration level stabilises above 250 ppm,
'Close-in' Well and report circumstances to Shore Base
and await orders.
Opening and Flow Periods will be conducted during
Daylight Hours only.
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C.
Reverse circulate the Tubing contents to the Flare.
Circulate conventionally until satisfied the Mud
Sulphide level is stable and pH is acceptable.
Schlumberger Procedures
July 2000
iv)
d.
No Helicopters to land on Rig while Well is Flowing.
Over 500 ppm.
i)
All Personnel outside Accommodation will mask- up,
Tannoy instructions will be given.
Well will be immediately 'Shut-in' and Test terminated.
Report circumstances to Shore Base.
ii)
iii)
D.
Note:-
The above Limits may be raised depending on
circumstances.
Note:-
Tannoy instructions will be made. Exceptions will be
Personnel operating Valves or who are involved in
sampling Well Effluent.
H2S in Atmosphere
a.
It is very likely that a background level of H2S will be in the
atmosphere during Testing Operations. This may result from
Incomplete Combustion at the Flare, Venting of Gasses during
Sampling, Weeping Valves, etc.:
Note:-
a.
b.
c.
Vessels and Lines should be 'flushed' to remove all traces of H2S.
Additionally, Vessels should be labelled with a Red Tag and
marked H2S to warn that entry into these Vessels is a potential
Risk.
Onshore, third Party Inspection shall be arranged to verify the
absence of H2S before the Equipment is Worked on.
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E.
It is extremely important that this background level is monitored
throughout the Rig by a series of Sensors.
De-Commissioning
Schlumberger Procedures
July 2000
3.3 Contingency Procedures
A
General:
Planning for Contingencies is a key part of the Test Design.
By considering what could go wrong with each piece of Equipment and every
Operation, a Hazard Analysis of the Test Programme could be made to identify
any difficulties that may be encountered and the Test so designed to deal with
them.
These Contingency Procedures usually form an appendix to the Well Test
Programme.
The Contingency Procedures should be studied before each stage of the Well
Test where they may be required, to enable Wellsite Personnel to be on the alert
to handle the problems if they occur.
Contingency Procedures must be clearly referenced in the Test Programme Text,
where the particular Procedure is given for the relevant Operation.
The Test Programme should follow the order of the operations so that it can be
followed in a logical sequence.
Note:-
A better approach might be to include each Contingency Procedure at
the point in the Test Programme where it might need to be applied ,
rather than consigning it to an appendix where it might be overlooked.
This could only be possible for the expected contingencies, not the
unexpected which could occur at any time during the Test Programme.
For each Test Programme, the problems, and hence the action to be taken, will
differ.
Contingency Guidelines for some of the problems that most frequently occur are
given in this Section.
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The Test Programme must be broken down into short Sections, which describe
the steps to be taken at each stage.
Schlumberger Procedures
July 2000
3.3.1 Downhole Leaks
A.
Downhole leaks will be detected by a change in Annulus Pressure.
The action to be taken depends on the following:a.
b.
B.
C.
The Test can only be continued if:
a.
b.
The leak is small enough and,
The Annulus Pressure is decreasing slowly.
Note:-
The leak must be closely monitored. In all other cases the Test
must be terminated and the Well must be 'Killed'.
For a major leak, with the Annulus Pressure decreasing fast:
a.
b.
If the Annulus Pressure is increasing, it means Hydrocarbon is entering the
Annulus.
a.
b.
c.
E.
Bullhead the Well.
Maintain the Annulus Pressure in full to keep the Downhole
Tester Valve 'open' while Bullheading.
'Close-in' the Well at Surface whilst lining up to Reverse
Circulate the Well.
Pressure up further on the Annulus to activate the Downhole
circulating Valve.
Reverse out the Tubing Contents.
After proceeding with the rest of the programmed Well Kill Procedure,
Pull the Test String with care, as the leak may have washed out and
weakened a connection.
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D.
The size of the Leak.
The direction of the Leak.
Schlumberger Procedures
July 2000
3.3.2 Downhole Test Tool Failure
A.
Downhole Tester Valve
a.
b.
c.
d.
B.
If the Tester Valve fails to 'close', the Pressure build-up will be
made with Surface Closure.
Although the increased Wellbore Storage will mask the early
time date, the rest of the build-up will be valid.
Wellsite Calculations should be made to estimate the time over
which Wellbore Storage Effects will predominate, and the time
taken to semi-steady the state, in order to determine whether the
Pressure Build-up should be extended.
When the Well has to be 'Killed', the Test Tool should be cycled
until it 'closes' or, it is clear that the Tool will not operate. In the
latter case, the Well will have to be Bullheaded.
Downhole Circulating Valve
a.
b.
Two Downhole Circulating Valves are included in the Test
String, one as a back-up Valve. If both Circulating Valves do not
work, then the following action must be taken, dependent on
whether the Downhole Tester Valve can be 'locked open' or not.
If the Downhole Tester Valve can be 'locked open'.
c.
Cycle the Tester Valve to the 'locked open' position.
Bullhead the Tubing Contents.
Pick-up the String to unseat the Packer.
Reverse circulate through the 'locked open' Tester
Valve.
If the Downhole Tester Valve cannot be 'locked open'
i)
ii)
iii)
iv)
v)
Bullhead the Tubing Contents, with Sea Water, if
possible.
Rig-up the Wireline Pressure Equipment.
Run a Tubing Puncher and Perforate the lowermost
Tubing Joint.
Rig down the Wireline Equipment.
Reverse Circulate through the holes shot in the Tubing.
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i)
ii)
iii)
iv)
Schlumberger Procedures
July 2000
3.3.3 Hydrates
Note:A.
If Hydrate Formation is possible on the Test, the Heater must be used.
During a Test, if ice is forming on the outside of the Pipework:
a.
b.
c.
B.
If Hydrate Blocking does occur:
a.
Inject Methanol upstream of the blockage and allow time for it to
soak.
Note:-
Do not allow a large Pressure Differential to build up across the
Plug, as this could damage the Surface Equipment when it comes
free.
b.
If accessible, play a Steam Hose on the Pipework in the area of
the Blockage.
Unlatching the Sub Sea Test Tree should be done sooner than later.
The unlatching will be considered a Hazardous Operation once the Heave
exceeds 2 metres, because of the danger to the Rig Crew at the moment of
'release'.
The normal procedure for unlatching the Sub Sea Test Tree is as follows:a.
b.
c.
d.
e.
f.
g.
h.
i.
j.
k.
l.
m.
Bleed off the Annulus Pressure to 'close' the downhole Test
Valve.
Bleed off the Control Line to 'close' the Sub Sea Test Tree.
Bleed off the Pressure within the Landing String via the Choke
Manifold.
Confirm that the Sub Sea Test Tree Valve is not leaking by
closing in at the Choke Manifold and observing for any Pressure
Build-up.
Clear the Rig Floor of any non-essential Personnel.
Slack off the weight on the Compensator to 5000 lbs above the
Landing String Weight, to ensure that the Latch Assembly will be
pulled/jump above the top of the Tree, avoiding any damage by
Heave.
'Close' Flowhead Kill Arm Valve and disconnect the Kill Line.
'Close' Flowhead Flow Arm Valve and disconnect the Coflexip
Hose at the Data/Injection Header, if on the Rig Floor.
Disconnect the Hydraulic Hose to the ESD Flowhead Flow Arm
Valve.
Centre the Rig over the Wellhead and slack off the Elevators.
Pressure up on the Unlatch Line.
Pick-up Landing String till clear of the BOP's and allowing for
the Heave.
'Close' the Blind Rams.
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C.
The Well Flow should be diverted to the Heater
The Heater Choke should be used instead of letting the Pressure
Drop, which will cause Hydrates to form at the Choke Manifold.
Hydrates form from the cooling effect of adiabatic expansion of a
gas as the pressure drops across the Choke. Use of the Heater
Choke would help to prevent this from happening.
Schlumberger Procedures
D.
July 2000
Emergency Procedure for Unlatching the Sub Sea Test Tree.
a.
b.
c.
Bleed off the Control Line to 'close' the Sub Sea Test Tree
If time allows, Bleed off the Pressure within the Landing String
via the Choke Manifold.
Pressure up the Unlatch Line to 'release' the Landing String.
Schlumberger Private
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Schlumberger Procedures
July 2000
3.3.4 Stuck Wireline
A.
Wireline Operations during a D.S.T are usually kept to a minimum
because of the risks entailed.
Sticking of Tools can occur for a variety of reasons.
B.
Fishing Operations using Wireline down the Well on a semi-submersible
Rig should not be conducted without serious considerations of other
options.
The following procedure should be followed:a.
b.
c.
d.
Complete the Test Programme, if it is possible to do so.
Bullhead the Tubing Contents with Sea Water, if possible.
Pull the weak point if Electric Line or drop a Kinley Cutter if
Slick Line.
Kill the Well by Reverse Circulation and Pull the Tubing.
Schlumberger Private
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July 2000
3.3.5 Surface Leak Procedure
A.
General
a.
In all Cases, except a leak below the Flowhead:
i)
b.
If the leak is below the Flowhead:
i)
c.
d.
'Close' in at the Sub Sea Test Tree.
'Shut' the Downhole Tester Valve.
If Wireline is in the Hole:
i)
B.
Activate the Emergency Shut Down System.
'Close' the Lubricator Valve.
Procedures
The action to be taken subsequently will depend upon the severity and
location of the leak.
a.
If the Leak was downstream of the Chokes.
b.
If the leak was upstream of the Chokes.
i)
ii)
iii)
c.
'Close' the Well in at the Choke Manifold.
Remove any Wireline from the Well and 'close' the
Flowhead Master Valve.
All the Lines should be allowed to Bleed Off.
The Separator should be isolated.
If the leak was on the Landing String.
i)
ii)
iii)
iv)
v)
The Test will have to be suspended.
Time may allow for a Pressure Build-up Downhole,
whilst the damage is investigated.
The connection which leaked may have been washed out
and hence the String will be weakened.
If possible, the Sub Sea Test Tree should be unlatched.
The Landing String pulled, the leak detected and
repaired, allowing the Test to be continued.
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i)
Schlumberger Procedures
July 2000
d.
Prior to repairing any leaks:
i)
ii)
iii)
iv)
e.
After repairing the leak.
i)
Note:-
Two Valves must be 'closed' in line Upstream from the
leak.
The System should be bled off downstream of the first
upstream Valve before the second Valve is 'closed'.
If H2S is present, the Lines must be 'flushed' with Water
before breaking any connections.
The cause of the leak must be established, action must
be taken to try and avoid a recurrence.
The section of pipework which contained the leak must
be Pressure Tested as per the Test Program.
Discussions should be held with the Onshore
Reservoir/Petroleum Engineer concerning the Leak details and
repairs, to decide whether it is worthwhile continuing with the
Pressure Build-up or, 'open' up the Well to Flow again.
Schlumberger Private
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3.3.6 Unexpected H2S Procedures
A.
General
It is Standard Practice to Plan for some level of H2S on a Wildcat Well.
However, if the Surface Equipment or the Test String, especially the
Tubing, is not rated for H2S, the Test should be suspended.
a.
At level of H2S below 20 ppm in the Well Stream, Testing can
continue as long as:i)
ii)
iii)
iv)
b.
At levels of H2S above 20 ppm but below 150 ppm in the Well
Stream, continue only if:-
vii)
viii)
Onshore approval is given.
All the Equipment is rated for H2S.
Breathing Apparatus is carried by Essential Personnel.
Non-essential Personnel remain in the Accommodation.
No Wireline Operations are conducted.
No Operations are conducted during the hour of
darkness.
The Wind Speed exceeds 10 knots.
All Test Areas are well ventilated.
Above 150 ppm H2S in stream, abandon the Test and Bullhead
the Tubing Contents.
Refer "Guidelines For Working With Hydrogen
Sulphide".Section 3.2.6.3.
Page 95 of 103
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i)
ii)
iii)
iv)
v)
vi)
c.
All the Equipment is rated for H2S.
No Wireline Operations are conducted.
The Well is not Flowed during the hours of darkness.
The Test Program does not exceed 24 Hours.
Schlumberger Procedures
July 2000
4. SPILLAGE PREVENTION
4.1 General
A.
It is Schlumberger's policy to carry out Operations as Safely and as Environmental
clean as possible. Schlumberger's Training given, and Maintenance programmes,
ensures any leakage from Equipment is kept to the absolute minimum.
However, during the course of Operations, accidental spillage or leakage may
occur for various reasons, at Operating conditions, or Weather condition changes.
In order to avoid any accidental spillage onboard a Rig whilst Sampling, Flaring
or Disposing of Well Effluents or Chemicals, Schlumberger Personnel ensure the
Standard Operating Procedures and Practices, as per the Operating Manuals and
Training Instructions, are carried out.
B.
Preparation
a.
b.
d.
Note:-
e.
f.
These operations are purely dependent on the Rig supplies.
If the System/Supply is found to be unsatisfactory, Schlumberger shall
inform the Rig Operator and OIM in order to rectify the Lack of Supply.
If a Full Burn Function Test is required, Schlumberger will take Rig Diesel
to their stock tanks and pump the Diesel to the Burners where a Visual
Inspection can be carried out and given approval.
Prior to breaking Process Lines and Hoses which contain Well Fluids, for
Inspection, Service or Maintenance purposes, the Operations
Supervisor/Technician is to ensure all Fluids are flushed using Fresh or Sea
Water to approved Vessels or Burners.
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c.
Prior to starting an Operation, the Equipment to be used is Function and
Pressure Tested for Operational Integrity.
When a Valve is to be 'opened' in order to Sample Well Effluent, a suitable
and approved Vessel must be used and backed up with Spillage Protection.
The Vessel must be disposed of in a prearranged Procedure, acceptable to
the Rig Operator/Company.
Prior to Burning Operations, Schlumberger ensures the correct Air Pressure
is supplied to its Atomisation System by supplying Third Party Approved
Air Compressing Equipment.
Once the Burners are rigged up, the Water Cooling and secondary Burning
System is Function Tested for correct Volumes and Pressure.
Schlumberger Procedures
July 2000
4.2 Whilst Sampling
A.
B.
C.
D.
Fit all Valves and Outlets with Hoses or suitable Lines and ensure they
terminate inside the Vessel to be used to contain the Effluent.
A suitable Spillage Tray, twice the volume and area is to be placed under
the Sampling Vessel.
Once Sampling is complete, empty all Vessels and Spill Trays into Waste
Disposal Drums clearly marked and labelled WASTE OIL or whatever the
Fluid is contained in the Drum.
The appropriately marked Waste Drums must be logged and their identity
given to the Rig OIM for Manifest and shipment via Rig Operator's
Procedures for Disposal.
Schlumberger Private
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4.3 When Rigging Down Surface Lines And Equipment.
A.
B.
C.
D.
Note:-
Ensure all Pressure is bled off via the appropriate route and vented to a safe
area or flared according to Operating Procedures for the chosen method.
Flush Equipment with Fresh or Sea Water, or purge through with Nitrogen.
Observe purged Fluid replacement with Purging Fluid until 100%.
Break connections at points most likely to contain fluids to be contained
according to their Gravity and observe lines to be clean.
Prior to Work Starting, connections with volumes that can be contained in
containers for later disposal to Waste Drums, can be bled as in Step 1 of
this procedure and observed Clean.
Schlumberger Private
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July 2000
4.4 During Burner Operations
4.4.1 Preparation
A.
Technicians to ensure;
a.
b.
B.
Note:-
All Valves on the Burner Heads are 'open' for the required Flow
Rate
All Test Plugs have been removed after Pressure Testing.
Prior to Operations on Burners, correctly Authorised Work Permits must be
obtained, to include 'Hot' Work and 'Over the Side' Work Permits.
For clarification purposes the Burners will be termed as Port and
Starboard.
In these Procedures all Burning and Flaring Operations will initially refer to as
commencing through the Port Burner.
Schlumberger Private
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July 2000
4.4.2 Operating Procedure
A.
Determine the prevailing Wind direction and select the Burner that will
burn 'away' from the Rig.
Note:-
This should be clarified by the Installation Control Room.
The Procedure from here on will pertain to the Port Burner unless stated
otherwise.
B.
C.
Note:-
E.
F.
G.
Note:-
a.
Inform the Control Room/Barge Master, that Burner Operations
are about to commence and from which Burner (Port).
b.
Make a PA Announcement to inform all Personnel of Hazardous
Operations about to commence.
Note:-
Communication Channels to the Control Room must be
maintained at all times via Portable Radios.
Set the Burner so that the Wind blows from the rear, which in turn will
allow the Flame to burn directly out of the Burner Heads, effecting better
combustion.
Check the route of the Flow from the Choke Manifold making sure all
appropriate Valves on the route are 'open' to the Port Burner.
The Gas and Oil Diverter Valves to the Starboard ç Burner must be
'closed'.
'Open' the Propane supply and Ignite all the Pilot Lights.
'Start' the remote Air Compressors and 'open' the Valves on the Air
Diverter Manifold, directing the Flow of Air to the Port Burner.
Advise the Drill Floor/Control Room to turn on the Water for the Burner
Cooling Rings and Rig Cooling Curtains.
Only a small Volume of Water should be diverted to the Burner Rings
until the Effluent has ignited, then adjusted accordingly to maximise the
Combustion Efficiency.
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D.
Prior to starting;
Schlumberger Procedures
July 2000
4.4.3 When Switching Flare Booms
Note:-
For clarification purposes, the Port Burner and its ancillary equipment
are still operating.
The change-over will be to the Starboard Burner. (Oil and Gas are still being
flared off).
A.
Operating Procedure
a.
b.
c.
d.
e.
Inform the Control Room/Barge Master that the direction of
Flaring requires changing and that the Burner Boom are about to
be changed over.
If necessary set the Burner so that the Wind blows from the Rear
of the Burner as detailed in the Startup.
'Open' the Propane Supply to the Starboard Burner and ignite the
Pilot Lights.
Ensure the Air Valves on the Burner Heads are 'open' (this should
have been done prior to Startup).
'Open' Valve on the Air Diverter Manifold to the Starboard
Burner.
At this point the Air is still being supplied to the Port Burner.
f.
Notify the Drilling Floor/Control Room for the Water to be turned
on to the Burner Cooling Rings and Rig Cooling Curtains.
Note:-
Only a small Volume of Water is required initially, to the Burner
Cooling Rings until the Effluent has ignited. Then adjusted
accordingly to optimise Combustion Efficiency.
g.
A Technician should be positioned directly at the Boom area with
a radio, maintaining contact with the Technician at the Diverter
Manifolds as the Change-over Procedure is being performed.
Note:-
Maintaining communication links is essential and will result in a
smooth and efficient operation without causing any adverse
Pressure effects upstream in the system.
h.
'Open' the Starboard Burner Oil Diverter Valve.
Once the Effluent is burning at the Starboard Burner;
i)
ii)
iii)
j.
Proceed to 'open' the Starboard Gas Diverter Valve.
When the Starboard Gas Flare has been lit, 'Close' the
Port Gas Diverter Valve.
'Close the Port Oil Diverter Valve.
'Close' the Port Air Diverter Valve isolating the Air.
Commence with the following Shutdown Procedure:-
Note:-
The Air Compressors must continue operating to supply Air to
the Starboard Burner.
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Note:-
Schlumberger Procedures
July 2000
4.4.4 During Burner Shut Down.
A.
Operating Procedure
a.
Once the Well is 'closed' in;
i)
Allow the Oil and Gas lines to the Burner to depressurise.
Allow the Flare to extinguish.
ii)
Note:-
b.
c.
Do not isolate the Propane to the Pilots until all the
Effluent is completely burnt off.
Upon completion of the burning,
i)
Turn off the Propane, Air and Water, in that sequence.
Note:-
This will prevent any fall-out of burning Hydrocarbon
droplets into the Sea, causing pollution
Do not 'close' all Gas and Oil Diverter Valves to the Burners.
Note:- A Route must be on-line in the event of any Emergency
Venting.
Schlumberger Private
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July 2000
4.4.5 Operating Guidelines
Note:-
If after taking all the necessary precautions and following the Schlumberger
Operating Procedures, 'spillage', or a 'spill' is noticed either on-board or overboard, the following action is to be taken in order to prevent any further Spillage
of Contaminants.
A.
B.
Isolate the source of the leak or spillage either automatically or manually.
If spillage is on-deck and 'Minor' (Localised).
The Test Crew will clean same as directed by Supervisors, using Rig supplied
detergents and removal equipment. The waste to be disposed of in clearly
marked, waste Drums or Rubbish Skips
If spillage is on-deck and 'Minor' but (Widespread).
Inform Supervisors/OIM, ask for assistance and Removal Guidance.
If spillage is on-deck and 'Major'(Widespread in Vents and Drains)
Inform Supervisor/OIM for assistance and Removal Guidance.
If spillage is in the Sea, source the cause and check all Operating Conditions,
using the following guidelines:-
C.
D.
E.
a.
b.
c.
d.
Check spillage is not from carry-over of Oil in Gas Lines.
Check spillage is not from poor Burning Efficiency.
Check spillage is not from leaking Lines.
Check spillage is not from 3rd Party Equipment.
Note:-
If necessary, 'stop' the Operation.
Inform the OIM/Company Rep of,
a.
b.
F.
The source of the spillage,
The Action taken to prevent any further spillage.
Prior to continuation of Operations, in all cases where spillage is
concerned, the Problem or even the Procedure, is to be reviewed with the
appropriate Supervisor, and rectified accordingly.
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Once found, adjust or maintain according to requirements in order to 'stop'
the spillage.