16) Standardized Mobile Wellhead Compressor for Onshore ...alrdc.org/workshops/2014... ·...

Gas Well Deliquification WorkshopSheraton Hotel, Denver, Colorado

February 23 – 26, 2014

James Donald (presenter), Marco Marino, Kees Veeken (Shell)

Standardized Mobile Wellhead Compressor for Onshore Gas Wells in The Netherlands

Outline

• Background of Nederlandse Aardolie Maatschappij BV (NAM), Onshore gas, Netherlands

• The game of deliquification in NAM Onshore

• Portoflio review - defining a business case for Mobile Wellhead Compression (MWHC)

• Deriving design parameters for a generic MWHC

• The next step – integration with gas lift

Feb. 23 Feb. 23 Feb. 23 Feb. 23 ---- Feb 26 2014Feb 26 2014Feb 26 2014Feb 26 20142014 Gas Well 2014 Gas Well 2014 Gas Well 2014 Gas Well DeliquificationDeliquificationDeliquificationDeliquification Workshop Denver, ColoradoWorkshop Denver, ColoradoWorkshop Denver, ColoradoWorkshop Denver, Colorado 2222

NAM

3333November 2013November 2013November 2013November 2013

LAND ASSETLAND ASSETLAND ASSETLAND ASSET

NAM is a joint venture, shareholders Shell (50%) and ExxonMobil (50%).

~90 producing fields ~270 producing wells via 26 treatment facilities

The game of deliquification in NAM Onshore


Reduce critical velocity(e.g. foam injection)

Deliquification & ‘depressurization’ techniques

5555

Increase gas velocity(e.g. velocity string or gas lift)

Artificially lift water(e.g. downhole pump or plunger)

Reduce tubing pressure(e.g. third stage compressor)

Deliq operating envelope

6666

0.0

5.0

10.0

15.0

20.0

25.0

30.0

0.0 100.0 200.0 300.0 400.0 500.0

Tub

ing

pre

ssu

re (

ba

ra)

Flow rate Q (km3/day)

MWHC PERFORMANCE CURVES

PQ curve Sept 2012 PQ curve Sept 2013 PQ curve Sept 2014 PQ curve Sept 2015 PQ curve Sept 2016 MWHC (discharge=12barg)

Typical min. suction

pressure 2-stage

compressor (12bara)

Liquid loading line

Discharge 12bara

Additional

reserves

Operating area

foam injection

Operating line MWHC

(discharge 12bara)

Project objective“Maximize recovery of mature low-pressure fields by lowering the THP preventing the well to liquid load and preventing back-out”

Build a comprehensive portfolio

I. Settle on universal design conditionsII. Recognize interaction with other (deliquification)

developmentsSTANDARDISE

I. Define ‘generic’ BfD

7777

Satellite #1

Satellite #2

Satellite #3

Treatment facility/hub

CustomerGasunie Transport

Services

70-90bar

60-65bar

10-25bar 25-50bar

Portoflio review

• Defining a business case for Mobile Wellhead

Compression (MWHC)

• Consider the lifecycle of deliq methods


Discharge pressure – initial capacity compressor

9999

89898989

single single single single

wellswellswellswells

MWHC

Depletion compression

Discharge pressure – initial capacity compressor

10101010

With manifold solutions less compressors are

needed

28 possiblesingle wells + manifolds

54 possiblesingle wells

Choice of deliq methods


Compression (CO) – in all cases, recovers the most significant volumesContinuous Foam (CF) – complementary to compression (although not technically desirable due to foaming)Gas lift (GL) – complementary to compression

Ultim

ate

re

co

ve

ry

Deriving design parameters for a generic MWHC

• A generic design that meets 80-20 rule


FTHP (NFA @ LL) - Qmin (NFA @ LL)

Qmin Deliq [10^3 m^3/d]

40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400

90

80

70

60

50

40

30

20

10

Marking:

Marking

Color by

InScope-Short

Firm

Notional

Out of Scope

Shape by

InScope-Short

Firm

Notional

Out of Scope

Size by

Sum(TUBE ID [in])

≥ 6,76

≤ 2,88

Fthp – minimum rate (@ Liquid loading)

13131313

West & North production systems

Tube ID ≈ 4 inTube ID ≈ 3 in

Tube ID ≈ 6 in

Max dischargepressure = 20 bara

FTHT (NFA @ LL) - Qmin (NFA @ LL)

Qmin Genrem [10^3 m^3/d]

50 100 150 200 250 300 350 400 450 500 550

90

85

80

75

70

65

60

55

50

45

40

35

30

25

Marking:

Marking

Marker by

(Row Number)

Color by

InScope-Short

Firm

Notional

Out of Scope

Shape by

InScope-Short

Firm

Notional

Out of Scope

Ftht – minimum rate (@ Liquid loading)

14141414

West & North production systems

Max inlet temperature = 60 °C

Defining liquid capacity

Where to draw the line? What about possible formation water breakthrough in the future?


LGR limit per possible MWHC candidates

16161616

Max rate = 420 kNm^3/d

Max LGR = max liquid rate/rate

The comfort factorThe comfort factorThe comfort factorThe comfort factor

Slug size


Key parameters:

Tubing ID ^2 Difference in CITHP and FTHP

Designed for: 1 m3 produced within minutes. Matches (limited) field data

Theoretical slug sizes

Summary design criteria

18181818

Criteria Abbreviation Value Unit

Closed in tubing wellhead pressure CITHP ≤80 barg

Flowing tubing wellhead pressure FTHP ≤12 barg

Max. skid inlet temperature FTHT ≤60 °C

Max. skid outlet temperature ≤80 °C

Overall liquid rate 50 m3/d

Slug size (instantaneous; within 1 min.) S 1.0 m3

Number of slugs at start-up 1x

Carbondioxide content CO2 10 mol%

Hydrogensulfide content H2S 0.5 mbar

Sand (continuous production) ≤0.2 kg/mln.Nm3

Oil carry-over ≤5 ppm

Corrosion inhibitor content ≤1000 ppm

Concept table third stage compression

19191919

Centrifugal Reciprocating Rotary screw Gas Jack

Capacity (mln.Nm3/d)

>10 0,05-10 0.01-1.0 <0.01

Min. suction pressure (bara)

>10 3-4 1.1-5 1.1

Max. dischargepressure (bara)

200 100-300 20-50 20

Compression ratio1.2-1.5 per impeller

2-4 per stage 2-10 2-20

Advantages

�High capacity�Medium/high efficiency

�2-Stage machinesoffer high efficiency�High discharge pres.�Low CAPEX (1-stage)�Sour gas solution

�Wide operating range�High compression ratio�Capable of handling

various gas compositions

�Low/medium CAPEX and maintenance cost

�Simple design�High compression ratio�Capable of

handling various

gas compositions�Low CAPEX

Disadvantages

�High CAPEX�Narrow operating range e.g. flexibility�Specialized maintenance & control

�High maintenance cost e.g many moving parts� Each unit is designed for a specific gas comp.�Vibrations

�Low adiabatic efficiency�Short life expectancy�Noise

�Low capacity�Not following

Shell DEP/DEMs

�Noise and

vibrations�EU regulations

Selected

MWHC Functional modules

20202020

1. Pre- treatment

Optional:

Sand/Foam/Large slugs

2a.Slug handling &

3. Compression 4. Fluid mixing2.Slug handling

& liquid separation

(small)

Mobile wellheadcompressor

7. Air cooling

8. Power supply

6. Liquid pumping

5. Oil processing

SKIDDABLE

”PLUG AND PLAY”

Process flow scheme MWHC

DP

= 1

00

ba

rg

60

0k

W

DP

= 2

5b

arg

PC

V-1

01

1. Slug separation

2. Cooling

3. Mist separation

4. Compression

5. Oil separation

IN

OUT

Design life MWHC skid = 25years

0

1

2

3

4

5

6

7

8

0 50,000 100,000 150,000 200,000 250,000 300,000 350,000 400,000 450,000 500,000

Su

ctio

n p

ress

ure

(b

ara

)

Flow rate (Nm3/d)

Operating envelope MWHC

20%

40%

60%

80%

Compressor performance curves

22222222

BBBB

AAAA

Compressor loadCompressor loadCompressor loadCompressor load

CCCC

DDDD

Discharge = 12baraDischarge = 12baraDischarge = 12baraDischarge = 12baraDischarge = 20baraDischarge = 20baraDischarge = 20baraDischarge = 20bara

Discharge = 3baraDischarge = 3baraDischarge = 3baraDischarge = 3bara

Next steps.....gas lift


Well performance curves

with compression and gas lift only gas lift

Gas lift with MWHC

Gas lift recovers more than continuous foam

Gas lift with wellhead compression (2bara) recovers 30% more

Feb. 27 Feb. 27 Feb. 27 Feb. 27 ---- Mar. 2, 2011Mar. 2, 2011Mar. 2, 2011Mar. 2, 20112014 Gas Well 2014 Gas Well 2014 Gas Well 2014 Gas Well DeliquificationDeliquificationDeliquificationDeliquification Workshop Denver, ColoradoWorkshop Denver, ColoradoWorkshop Denver, ColoradoWorkshop Denver, Colorado 24242424

Ultim

ate

reco

very

Gas lift with MWHC


With SPM

RetrofitStraddle to maintain well barrier.Completions:>= 4 ½<= 3 ½”

Workover is

cost prohibitive

recycle

Well operating envelope: Corrosion – wet gas

Technical work to be done

Conclusions

Conclusions and Achievements:Bottom-up approach proved to be successful. Analysis enabled by

simple screening tool to analyse many wells

Parameters for MWHC for Basis for Design delivered

Gas Lift and Continuous Foam not an alternative to MWHC

Gas Lift to be preferred to Continuous Foam with MWHC

Next steps:Design specific solutions or alternative compressors for wells outside

of current MWHC operating envelope

Subsurface retro-fit solution to enable gas lift

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Feb. 23 - 26, 2014 2014 Gas Well Deliquification Workshop Denver, Colorado

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Copyright

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– Display the presentation at the Workshop.

– Place it on the www.alrdc.com web site, with access to the site to be as directed by the Workshop Steering Committee.

– Place it on a CD for distribution and/or sale as directed by the Workshop Steering Committee.

Other use of this presentation is prohibited without the expressed written permission of the author(s). The owner company(ies) and/or author(s) may publish this material in other journals or magazines if they refer to the Gas Well Deliquification Workshop where it was first presented.

Feb. 23 - 26, 2014 2014 Gas Well Deliquification Workshop Denver, Colorado

28

Disclaimer

The following disclaimer shall be included as the last page of a Technical Presentation or Continuing Education Course. A similar disclaimer is included on the front page of the Gas Well Deliquification Web Site.

The Artificial Lift Research and Development Council and its officers and trustees, and the Gas Well Deliquification Workshop Steering Committee members, and their supporting organizations and companies (here-in-after referred to as the Sponsoring Organizations), and the author(s) of this Technical Presentation or Continuing Education Training Course and their company(ies), provide this presentation and/or training material at the Gas Well Deliquification Workshop "as is" without any warranty of any kind, express or implied, as to the accuracy of the information or the products or services referred to by any presenter (in so far as such warranties may be excluded under any relevant law) and these members and their companies will not be liable for unlawful actions and any losses or damage that may result from use of any presentation as a consequence of any inaccuracies in, or any omission from, the information which therein may be contained.

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16) Standardized Mobile Wellhead Compressor for Onshore ...alrdc.org/workshops/2014... ·...

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