2 Update from BP on gas well deliquification - Artificial lift Up… · • “MoW Gas Well...

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





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



Hydrocarbon Based Foamer

13









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



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



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:

− [email protected]

• 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

2 Update from BP on gas well deliquification - Artificial lift Up… · • “MoW Gas Well...

Documents

Transcript of 2 Update from BP on gas well deliquification - Artificial lift Up… · • “MoW Gas Well...