BP Deliquification Dr. Werner Schinagl Gas Well Deliquification Network Leader MoW
BP Deliquification
Dr. Werner SchinaglGas Well Deliquification Network Leader MoW
2
Agenda
General Points
• “MoW Gas Well Deliquification Network” – the value of sharing
experience
Technology Pieces
• PDPs – first installation in an oilfield
• Eductors – delivering value
• Joint Industry Project: Sliding Sleeve SSSV
• Surfactant Treatments – the success continues and new products
being trialled
• Plunger Idea
3
MoW Network – Value of sharing Experience
• “MoW Gas Well Deliquification Network” has been operational for
approx 2 years
• Sharing experiences / ideas / new technology on a regular basis has
greatly added value across BP
− Network members help each other and ensure appropriate
people attend well reviews, peer reviews,…
− Technology spreads faster into all gas assets
− Most gas assets have increased awareness of liquid loading and
deliquification technology available
− Training modules give inexperienced personnel chance to learn
about basics of Gas Well Deliquification
− Tools for assets to help themselves exist
4
PDPs – first installation
• Positive Displacement Pump (head generated by pump is
decoupled from flowrate)
• Positive displacement action generated by 2 screws rotating against
each other
• 1st installation in January 2007 in an oilfield
− Unknown oil rate of new well (pump less sensitive to application
errors compared to ESP)
− Unknown reservoir support for area targeted by well
− Installed submersed (on a DH motor – like an ESP)
• Pump taken to ~60 [%] free gas at intake
• Currently issues with system (cable, motor? – pump does not seem
to be the problem)
5
PDPs – way forward
• More tests planned with twin screw pump in
oilfield
− Running from surface with rods and DH
gearbox
− Taking technology in oil wells offshore and
gas wells onshore
− TARGET: running technology in gas wells
offshore
6
Eductor Technology
• Successfully installed several eductors for lowering WHP and
deferring onset of liquid loading
• Success rate of application in BP: 100%
• Production gain due to ~ 30% backpressure reduction: ~ 25%
• Various eductors in BP:
− Some take HP source from compressor (re-cycle)
− Some take HP from higher pressure well
ECA220
Pressure 30.0 barg Pressure 73 barg
Flow 35 mmscfd
Pressure 19 barg
RS60 mmscfd
7
Eductor Technology
• Next steps:
− Standardized package on rental basis to
go for short-term opportunities as a
complete “turn-key-solution”
− Application in multi-phase environment
8
JIP: Torus SSSV
• “Enabling technology”: SSSV that works based on sliding sleeve
principle:
− Permanent feed-through capability without compromising fail-safe
closed feature
− Feed-through allows stationary, rotational or reciprocating motion
− Non elastomeric type seals (no elastomers used)
− Ideal for retrofitting artificial lift in existing wells avoiding workover
− Applications include: Capillary String, PCP and Plunger Lift
9
JIP: Torus SSSV
Flowport Open
Flowport Closed
10
JIP: Torus Safety Valve
LINK
11
Surfactant Treatments
• Continued success and learning with surfactant treatments globally
− ~ 80% success rate of batch treatments
− Longer time online
− Higher gas production
− Separate presentation by Norman Laing
about North Sea success
• Build of “continuous batch skids”
− Implementation in 2008
• Results of surfactant trials in Sharjah (UAE)
12
� Avg Daily Production before the trial : 4.1 MM scf
� Avg Daily Production during the trial : 5.25 MM scf
� Avg Production increase during the trial period : Gas
1.15 MM scf/d, 50 BPD Condensate & 36 BPD LPG
0
100
200
300
400
500
01/0
6/20
0705
/06/
2007
09/0
6/20
0713
/06/
2007
17/0
6/20
0721
/06/
2007
25/0
6/20
0729
/06/
2007
03/0
7/20
0707
/07/
2007
11/0
7/20
0715
/07/
2007
19/0
7/20
0723
/07/
2007
27/0
7/20
0731
/07/
2007
04/0
8/20
0708
/08/
2007
12/0
8/20
0716
/08/
2007
20/0
8/20
0724
/08/
2007
28/0
8/20
0701
/09/
2007
05/0
9/20
0709
/09/
2007
13/0
9/20
0717
/09/
2007
21/0
9/20
07
WH
P &
WH
T
0
1
2
3
4
5
To
tal
Flo
w
Trial Start End of Injection WHP WHT FLow Rate
- Foamer used : New Hydrocarbon Base Product RE 6000 FMO
- Injection rate average : 17 GPD
- Total injected volume : 550 USG
Injection Period
� Avg Daily Production before the trial : 1.35 MM scf
� Avg Daily Production during the trial : 2.24 MM scf
� Avg Production increase during the trial period : Gas
0.89 MM scf/d, 39 BPD Condensate & 28 BPD LPG
Foamer used is new hydrocarbon based product, annulus injection
50
100
150
200
250
300
350
01-J
un-0
705
-Jun
-07
09-J
un-0
713
-Jun
-07
17-J
un-0
721
-Jun
-07
25-J
un-0
729
-Jun
-07
03-J
ul-0
707
-Jul
-07
11-J
ul-0
715
-Jul
-07
19-J
ul-0
723
-Jul
-07
27-J
ul-0
731
-Jul
-07
04-A
ug-0
708
-Aug
-07
12-A
ug-0
716
-Aug
-07
20-A
ug-0
724
-Aug
-07
28-A
ug-0
701
-Sep
-07
05-S
ep-0
709
-Sep
-07
13-S
ep-0
717
-Sep
-07
21-S
ep-0
7
WH
P &
WH
T
0
1
2
3
4
5
6
7
To
tal
Flo
w,
MM
sc
f/d
Trial Star End of Injection WHP WHT FLow Rate
Injection Period
- Foamer used : New Hydrocarbon Base Product RE 6000 FMO
- Injection rate average : 21 GPD
- Total injected volume : 550 USG
Hydrocarbon Based Foamer
13
� Avg Daily Production before the trial : 2.39 MM scf
� Avg Daily Production during the trial : 3.04 MM scf
� Avg Production increase during the trial period : Gas
0.65 MM scf/d, 29 BPD Condensate & 20 BPD LPG
� Avg Daily Production before the trial : 3.16 MM scf
� Avg Daily Production during the trial : 3.24 MM scf
� Avg Production increase during the trial period : Gas
0.08 MM scf/d, 4 BPD Condensate & 2 BPD LPG
Foamer used is water based foamer, annulus injection
50
150
250
350
450
550
01/0
6/20
0705
/06/
2007
09/0
6/20
0713
/06/
2007
17/0
6/20
0721
/06/
2007
25/0
6/20
0729
/06/
2007
03/0
7/20
0707
/07/
2007
11/0
7/20
0715
/07/
2007
19/0
7/20
0723
/07/
2007
27/0
7/20
0731
/07/
2007
04/0
8/20
0708
/08/
2007
12/0
8/20
0716
/08/
2007
20/0
8/20
0724
/08/
2007
28/0
8/20
0701
/09/
2007
05/0
9/20
0709
/09/
2007
13/0
9/20
0717
/09/
2007
21/0
9/20
07
WH
P &
WH
T
1
2
3
4
5
6
To
tal
Flo
w
Trial Start End of Injection WHP WHT FLow Rate
- Foamer used : Water Base Foamer FMW 3059
- Injection rate average : 17 GPD
- Total injected volume : 550 USG
Trial Period
50
100
150
200
250
300
350
01/0
6/20
0705
/06/
2007
09/0
6/20
0713
/06/
2007
17/0
6/20
0721
/06/
2007
25/0
6/20
0729
/06/
2007
03/0
7/20
0707
/07/
2007
11/0
7/20
0715
/07/
2007
19/0
7/20
0723
/07/
2007
27/0
7/20
0731
/07/
2007
04/0
8/20
0708
/08/
2007
12/0
8/20
0716
/08/
2007
20/0
8/20
0724
/08/
2007
28/0
8/20
0701
/09/
2007
05/0
9/20
0709
/09/
2007
13/0
9/20
0717
/09/
2007
21/0
9/20
07
WH
P &
WH
T
0
1
2
3
4
5
6
To
tal
Flo
w
foamer injection start WHP WHT FLow Rate
Drop in flow rate was due to problem of the plant
compresor K 7000 which increased the suction
pressure and affected in some flow lines
- Foamer used : Water Base Foamer FMW 3059
- Injection rate average : 12 GPD
- Total injected volume : 550 USG
Trial Still under going
Water Based Foamer
14
� Lab test was performed prior the field trial to screen out the different types of
foamers
� Two types of foamers were selected for the field trial: a new hydrocarbon
based product and traditional water base foamer
� Foamer was injected through the annulus in the 4 wells (Packerless
completion)
� Foamer injection rate was started with ~70 GPD then, modified to ~10 GPD
� Defoamer injection system was prepared inside the plant to prevent any
potential plant upsets due to receiving large volume of foamer
� Injection of foaming agents did benefit well bore hydraulics and improved
production of the 4 wells
� Total gain in production: 69 MMSCF gas, 3065 BBL Condensate & 2185 BBL
LPG
Sharjah Results
15
Plunger Idea with SSSV
• Aim of sharing the idea is to kick the development of the tool off –
perhaps as a JIP. Service Companies / Vendors interested in
development of the tool are welcome to get in touch with me:
• The following slide shown contains confidential information. A patent
application for the information contained in the following slide has
been filed.
16
Plunger Lift Idea with SSSV
• LINK
17
Q&A