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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
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 4444
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
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 8888
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
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 11111111
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
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 12121212
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?
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 15151515
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
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 17171717
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
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 23232323
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
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 25252525
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
26262626
Feb. 23 - 26, 2014 2014 Gas Well Deliquification Workshop Denver, Colorado
27
Copyright
Rights to this presentation are owned by the company(ies) and/or author(s) listed on the title page. By submitting this presentation to the Gas Well Deliquification Workshop, they grant to the Workshop, the Artificial Lift Research and Development Council (ALRDC), and the Southwestern Petroleum Short Course (SWPSC), rights to:
– 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.
The views, opinions, and conclusions expressed in these presentations and/or training materials are those of the author and not necessarily those of the Sponsoring Organizations. The author is solely responsible for the content of the materials.
The Sponsoring Organizations cannot and do not warrant the accuracy of these documents beyond the source documents, although we do make every attempt to work from authoritative sources. The Sponsoring Organizations provide these presentations and/or training materials as a service. The Sponsoring Organizations make no representations or warranties, express or implied, with respect to the presentations and/or training materials, or any part thereof, including any warrantees of title, non-infringement of copyright or patent rights of others, merchantability, or fitness or suitability for any purpose.