Post on 25-Apr-2018
DELIQUIFICATION & REVIVAL
OF OIL AND GAS WELLS
USING SURFACE JET PUMPS
Recent applications and experience
8th European Conference on Gas Well De-liquification Groningen, 2013
By: Sacha Sarshar ,Caltec
CONTENTS;
• CAUSES OF LIQUID LOADING
• CHARACTISTICS OF FLOW THROUGH WELL BORE-FLOW
REGIME MAP
• SOLUTIONS TO DELIQUIFY OIL OR GAS WELLS
• IMPACT OF REDUCING THE FWHP
• INTRODUCTION TO SURFACE JET PUMP (SJP)
• PERFORMANCE OF JET PUMP
• EFFECT OF LIQUIDS IN LP AND HP GAS, AND HOW TO
COPE WITH IT
• BEST LOCATION FOR SJPS,ONSHORE AND OFFSHORE
• OPERATION AND CONTROL/INSTRUMENTATION
• HOW TO ASSESS THE PERFORMANCE OF THE SJP
Slide 2
CONTENTS CONTINUED....
• HOW TO COPE WITH CHANGES IN HP OR LP PRODUCTION
AND FLOW RATES
• HOW TO PREDICT PRODUCTION RATE AND INCREASE IN
PRODUCTION
• DESIGN ISSUES; CODES,MATERIAL
• OPERATION ISSUES; -
NOISE,TEMPERATURE,EROSION,CORROSION
• FIELD EXAMPLES
• ECONOMICS
• QUESTIONS AND ANSWERS
Slide 3
EFFECT OF FIELD DEPLETION ON WELL BORE PRESSURE
Inflow Parameters will change as the field depletes and the shape of the inflow performance curve will change, potentially due to factors like:
Changes in relative permeabilities over time Increase in water production
Reservoir compaction Closure of natural fractures
Production below saturation pressures
Gas is released from oil resulting an increase of GOR
Condensate is dropping in the reservoir resulting a decrease of LGR – condensate banking.
Slide 4
Effect of field depletion on well bore pressure and production
Increase of Non Darcy effect due to added turbulence
Increase of effective stress (difference between the overburden
and fluid pressures)
Closure of near well bore micro fractures
Closure of induced fractures
(fracture conductivity reduction)
Near wellbore damage
Fines migration build-up , Screen plugging
Sand production and build-up in well sump
Scale build-up / salt deposition
Slide 5
WELL FLOW PERFORMANCE PARAMETERS
• The well inflow rate is driven by:
Reservoir pressure/pressure maintenance
Well mechanical constraints (solid production, erosion,
completion envelope, screen integrity, water / gas coning
Back pressure on well (FWHP &FBHP)
Flow regime within the well bore
Phase envelope
Mechanical skin (near wellbore damage, perforation skin,
partial penetration skin, completion skin, sand control
Non Darcy skin
Well architecture ( tubing size, well depth, profile ...)
Facilities constraints (e.g. Water production capacity)
Slide 6
MAIN CAUSES OF LIQUID BUILD UP IN WELLS
• Low velocity of gas
• High FWHP, dictated by downstream process system
• Multiphase flow through well bore , leads to flow regimes
such as Churn flow, slugging etc,which affect both the
hydrostatic head and frictional losses
• Effect of viscosity& density of liquids and gas
• Inclined & horizontal profile of wells contribute to G-L
separation within the well bore and generation of slugs;
• liquid build up in pipelines could also aggravate the
problem ,increasing FWHP
• The flowing bottom hole pressure(FBHP) is the main factor
affecting production, but FWHP is also a useful guide
Slide 7
COMPARISON OF
FLOW REGIMES IN
HORIZONTAL AND
VERTICAL PIPES
Intermittent
Dispersed Bubble
Annular Mist
Wavy
Stratified
Superficial Gas Velocity (m/s)
Su
perf
icia
l L
iqu
id
Velo
cit
y (
m/s
)
Slug
Annular Mist
Froth
Bubble
Su
perf
icia
l L
iqu
id
Velo
cit
y (
m/s
)
V ≥ 5 m/s
Slide 8
TYPICAL INSTANTANIOUS FLOW REGIME
ASSOCIATED WITH MULTIPHASE FLOW
3
Slide 9
SEVERITY AND EXTENT OF LIQUID BUILD-UP
HOW SICK IS THE PATIENT?! • CASES WHEN LOWERING THE FWHP OR REGULAR SHUT-
DOWN IS SUFFICIENT TO REVIVE THE WELL- EFFECTIVENESS
AT WHAT FWHP/ FBHP?
• CASES WHEN AN INITIAL DELIQUIFICATION IS NEEDED
,FOLLOWED BY OPERATION UNDER A LOWER FWHP ,USING
SURFACE JET PUMPS
- SEVERAL OPTIONS EXIST FOR THE INITIAL
DELIQUIFICATION SUCH AS USE OF FOAMING AGENTS OR
USE OF DOWNHOLE SYSTEMS.
• CASES WHERE A DOWNHOLE SYSTEM /SOLUTION IS
NEEDED,BUT REDUCING FWHP WILL ENHACE PRODUCTION
Slide 10
SELECTION OF SUITABLE SOLUTION DEPENDS ON;
• SEVERITY OF LIQUID LOADING
• RESERVOIR PRESSURE
• WELL INFLOW CHARACTERISTICS
• AVAILABILITY OF HP FLUIDS IF SJP IS USED
• PLATFORM OR SITE CONSTRAINTS
• ECNOMICS
Use of surface jet pumps is the simplest technique,
provided there is sufficient source of motive flow
Slide 11
SELECTION PROCESS FOR WELL DELIQUIFICATION
Case1(Mild) Case 2(Medium) Case 3 (Sever)
Slide 12
Lowering the
FWHP by SJP is
sufficient
Well loaded, initial
offloading is needed
Lower FWHP by SJP
After initial offloading
Use SJP plus
intermittent
offloading
Downhole system needed
SJP could enhance downhole system
COMMON REMEDIAL SOLUTIONS TO WELL DE-IQUIFICATION
• Regular gas blow down to atmosphere
• Lower flowing wellhead pressure ( use of jet pump
technology or other methods)
• Well shut-in Intermittently
• Use of foaming agents/intermittent or continuous
• Tubing size modification/velocity string
• Artificial lift systems (Downhole) including downhole jet
pumps
• Best solution is dictated by well status,resevoir
characteristics, available source of energy, platform
constraints and economic consideration
Slide 13
INTRODUCTION TO SURFACE JET PUMPS
Slide 14
Surface Jet Pump Technology
Some possible HP sources-;
- HP WELLS (oil or gas wells) - COMPRESSOR RECYCLED GAS
- HP GAS FROM PROCESS SYSTEM - A SINGLE PHASE (LIQUID) PUMP
- HP LIQUID(OIL,WATER)
Removable
Nozzle
Removable
Mixing tube /Diffuser
Patented Universal Design Ejector / Jet Pump
Slide 15
HP Flow
LP Flow
Combined Flow
Ve
loc
ity
Pre
ss
ure
1 3 4 5 6 7 2 8
HP
LP
Discharge
Nozzle Mixing tube Diffuser
Jet Pump Flow Dynamics
16
MAIN FACTORS AFFECTING THE PERFORMANCE
~ HP/LP PRESSURE RATIO
~ HP/LP FLOW RATIO
~ GAS/LIQUID RATIO(LP FLOW)
(oil or gas production cases)
Secondary
factors;
- Mol. weight
- Temperature
- Liquid in gas
phase
Slide 17
EFFECT OF LIQUIDS PRESENT IN LP GAS
18
Gas as the motive flow
MULTIPHASE CHOKING IN JET PUMP :
A CRITICAL FACTOR NOT COMMONLY KNOWN
Slide 19
TYPES AND RANGES OF SJP APPLICATIONS
• Revival of dead wells (oil&gas wells)/ de-liquification
• Boost production from oil or gas wells
• Boost pressure of LP gas in a process system
• De-bottleneck compressors
• Eliminate intermediate compressors
• Prevent HP wells impose back pressure on LP wells
• Prevent flaring LP gas
• Others to meet process requirements
Slide 20
SOME FIELD EXAMPLES
Slide 21
WELL REVIVAL –SPILAMBERTO FIELD,ITALY
Source of HP flow; HP gas well
Benefits;
Gain in gas production by 23,000
sm3/d (0.812MMscfd)For almost
two years
Slide 22
BP Inde, UKCS
Benefits
Used 68 MMscfd of gas from LP Shell
wells into the exiting facilities.
Production increased by 25%
Increased intake capacity of
compressor
De- bottlenecked exiting compressor
Removed liquids from LP wells and
the pipeline
Solution ; Used HP recycled gas to power
SJP, to draw-in low pressure satellite Shell
wells
Low Pressure
Gas Wells
Jet Pump
Export
Kilo
Juliet
Subsea Line
Davy Line
Bessemer
Dp
Separator
Compressor
Award winning solution
Slide 23
Chevron, USA (GOM)
Solution ; HP gas from the existing compressor
on recycle used to power the jet pump
Benefits
Lowered arrival p at the platform by 200 psi
Increased gas velocity and improved flow regime
in wells
• Removed bulk of liquids in the pipeline, causing
a further 140psi drop at the wellhead
(340 psi total pressure drop).
• Production increased by 24%.
• 2.5 Bscf of otherwise lost reserves recovered.
•Flow delivered at higher pressure to compressor
suction increased compressor throughput.
Export 40MMSCFD
7.4 MMSCFD 850 psig
400 psig 200 psig
Ejector 1250 psig
Sales
Sub sea
manifold
Recycle gas
GEMINI
process
(Php/Plp=4.9.Qhp/Qlp= 2.11,Pd/Plp=2 )
Slide 24
27 miles
HP Well
LP Well
15 km
Pipeline
Drying
unit
Compressor
At eductor:
Pressure ratio HP/LP = 5
Flow ratio HP/LP = 3
Gas liquid ratio (m3 liquid per 1 million m3 gas)
HP well 65
LP well 30
Caltec
Jet Pump
Groet field surface jet pump
Slide 25
Slide 26
HP Well
LP Well
15 km Pipeline
Drying
unit
Compressor
Case 1 At eductor:
Pressure ratio HP/LP = 4
Flow ratio HP/LP = 2.3
Case 2 At eductor:
Pressure ratio HP/LP = 10
Flow ratio HP/LP = 7
Caltec
Jet Pump
Bergen Drying Facility surface jet pump
Slide 27
28
Production optimisation by surface jet pump
Flow well T Analog value Analog value Analog value Analog value Analog value Return set point
K5ENC_QV101T.PV
kNm3/d
K5ENC_TT_101_T
°C
K5ENC_PT_101_T
Bar
K5ENC_PT_103_T
BAR
K5ENC_PT_105_T
BAR
K5ENC_PT_107_T
BAR
K5ENC_ROCV_101_T_SP
%
K5ENC T = well 1 26/05/2008 09:49:03.893
days-336 -308 -280 -252 -224 -196 -168 -140 -112 -84 -56 -28
50
100
150
200
0
250
0
100
0
50
0
50
0
50
0
50
0
100
0.00
11.87
4.54
10.11
24.18
58.78
197.11
142.39
50.86
25.81
8.26
1.44
2.75
94.99
14/01/2008 16:47:42.74546
Re-start of the well after a
closed-in period of two
years , with reduced FTHP
from 40 to 26 bar using
SJP
After ten moths
maximum stable flow
reached using SJP
Alaska, USA
Benefits;
• Used available wasted energy
to off-load the well.
• Total production from well raised to 7
MMscfd from 2.5 MMscfd. Production
increased by 180%.
• Liquid loading cycle was reduced, hence
more sustainable production gain.
Solution ; Used HP gas from long-string to off-
load the well via surface jet pump
Dual Completion
Well
Gas Jet Pump
LP Wet gas
HP Gas
Slide 30
ANGSI FIELD MALAYSIA
REVIVAL OF 16 GAS WELLS
OIL PRODUCTION - WELLCOM BOOST SYSTEM
LOW PRESSURE
OIL WELLS
JET PUMP
TO PIPELINE
GAS
LIQUID
I-SEP
BOOSTER PUMP
COMMINGLER
LIQUID
HIGH PRESSURE GAS GAS
LIQUID
Commingler
Php/Plp=7.9
Qhp/Qlp=3.23
Pd/Plp=1.46
Slide 33
WELLCOM SYSTEM ; OFFSHORE MALYSIA Lift gas as the motive flow+ A booster pump to boost the liquid phase
Jet pump
I-SEP
HI-SEP
Booster
Pump
Slide 34
I-SEP
Slide 35
COMPACT SEPARATOR TO
SEPARATE GAS FROM LIQUIDS
SIZE MATTERS !
HI-SEP
I-SEP
Slide 36
I-SEP
On-Shore, Italy
Benefits
• Backpressure reduction on the wells of up to
11 bar was achieved.
• Simple to operate with no rotating parts
• Net extra oil gain of 350 bbl/d with additional
1.5 MMscfd of gas was achieved.
Multi Awards winning solution
HP oil well as the source of motive flow
Slide 37
I-SEP
WELLCOM APPLICATION: Cendor, Malaysia
I-SEP
TO PROCESS
SYSTEM JET PUMP
COMMINGLER
FROM HP WELL
FROM LP WELL
GAS
LIQUID
WELLCOM BOOSTING SYSTEM
Wellcom oil system ; multiphase HP
wells were used to bring in closed
low pressure oil wells.
Benefits
• Used available energy from HP well
• 20% pressure boost for LP wells.
• Increased production by over 35%
( 150 b/d )
• Improved flow regime in well bore,
stabilising production.
FTHP 360 psia
FTHP 69.6 PSIA
87 psia
450 b/d+0.138 MMSCFD
3612 b/d
Dp FWHP; 17.4 psi
I-SEP
Slide 38
Record of flowing bottomhole pressure before and
after installing the jet pump system
700
750
800
850
900
950
1000
1050
1100
1150
1200
06:0
0:0
0
06:5
7:0
0
07:5
4:0
0
08:5
1:0
0
09:4
8:0
0
10:4
5:0
0
11:4
2:0
0
12:3
9:0
0
13:3
6:0
0
14:3
3:0
0
15:3
0:0
0
16:2
7:0
0
17:2
4:0
1
18:2
1:0
2
19:1
8:0
2
20:1
5:0
2
21:1
2:0
2
22:0
9:0
2
23:0
6:0
2
00:2
1:0
0
01:1
8:0
1
02:1
5:0
1
03:1
2:0
1
04:0
9:0
1
05:0
6:0
1
06:0
3:0
1
07:0
1:5
4
07:5
9:3
2
Flowing bottomhole pressure (FBHP)
FBHP Dp =140 psi
Dp at wellhead=17.4 psi
Slide 39
USES OF THE TEST SEPARATOR
•Well testing
•Well testing/metering at reduced FTHP
•Well revival
18 October, 2013 Presentation title 41
LP Wells
Test Header
Production Header
Test Separator
M
M
Well Revival
Gas Jet Pump
Well Revival
Liquid Jet PUMP
HP Gas
HP Liquid Gas
Liquid
COMMERCIAL - IN - CONFIDENCE
©Caltec Limited 2010. This information contains Caltec’s proprietary intellectual property and is not to be disclosed to a third party without the pri or written consent of Caltec Limited. Caltec Limited, Medway Court, Cranfield, Bedfordshire MK43 0FQ United Kingdom : Tel: +44 (0)1234 750144 Email: info@caltec. com www.caltec.com
Closed drain
(option 1)
To vent or flare (option3)
WELL REVIVAL USING THE TEST SEPARATOR
APPLIES TO BOTH GAS AND OIL WELLS
(Option 2)
Test Separator
M
M
M
PT
HP
Well
LP
Wells
Test Header
Production
Header
Test Cooler
Production
Cooler 14” Sub Sea
Line to CPP
Commingler
)
Alternative
use of
booster pump
To Pressure
Relief Line
PT
PT
TT
Well Revival Jet Pump
PT
PT
TT
Gas Jet Pump
PT PT
LP Silencer
Discharge
Silencer
LP Silencer
Discharge
Silencer
Jet Pump Skid
Silen
cers
Skid
Jet Pump Skid
Silen
cers
Skid
Slide 42
EFFECT OF SJP COMBINED WITH GAS LIFT
INCREASED PRODUCTION
Slide 43
Gaslift injection
system
Pay zone
Production
via Tubing
Wellcom system &
Gaslift injection
Pay zone
Well production
Lift gas
Surface
Wellbore
Well
Wellhead
Pro
du
ced
Oil F
low
rate
Gaslift Injection Flowrate
Gaslift injection
Additional
production
SJP
To downstream process
HP
EFFECT OF COMBINED GAS LIFT AND SJP
Depth Lift Gas
(ft) 0 MMscfd 0 MMscfd 2 MMscfd 2 MMscfd 4 MMscfd 4 MMscfd0 Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble
700 Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble
1425 Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble
2125 Slug Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble
2850 Slug Slug Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble
3550 Slug Slug Dispersed Bubble Dispersed Bubble Dispersed Bubble Dispersed Bubble
4275 Slug Slug Slug Dispersed Bubble Dispersed Bubble Dispersed Bubble
4975 Slug Slug Slug Slug Dispersed Bubble Dispersed Bubble
5700 Bubble Flow Slug Slug Slug Dispersed Bubble Dispersed Bubble
6400 S.P. Turbulent S.P. Turbulent Slug Slug Slug Dispersed Bubble
7125 S.P. Turbulent S.P. Turbulent Slug Slug Slug Slug
7825 S.P. Turbulent S.P. Turbulent Slug Slug Slug Slug
8546 S.P. Turbulent S.P. Turbulent Slug Slug Slug Slug
9246 S.P. Turbulent S.P. Turbulent Bubble Flow Bubble Flow Slug Slug
9971 S.P. Turbulent S.P. Turbulent S.P.Turbulent S.P.Turbulent Slug Slug
10696 S.P. Turbulent S.P. Turbulent S.P.Turbulent S.P.Turbulent Slug Slug
FWHP (psig) 300 150 300 150 300 150BHP (psig) 3940 3825 3785 3738 3744 3714
Oil flow rate (bbl/d) 2869 3440 3642 3875 3845 3998
dQ (bbl/d) - 571 773 1006 ** 976 ** 1129Water flow rate (bbl/d) 3804 4560 4827 5137 5097 5300
Gas flow rate (MMscfd) 2.3 2.752 2.91 3.1 3.076 3.1984
Slide 44
0
773
976
1041 1026
571
1006
1129 1151 1114
0
200
400
600
800
1000
1200
1400
0 1 2 3 4 5 6 7 8 9
dQ
(b
op
d)
Lift Gas (MMscfd)
Comparison of Gas Lift and use of SJPs and Effect on Production Increase
Gas Lift Only
Gas Lift + SJP
Pay zone
Gas lift injection
system Well production
Surface
Wellbore
Pay zone
Wellhead
Gas lift injection valves
Liquid level
To production process
SJP
Recycle
Gas lift Compressor Injection Gas
USE OF SJP TO RAISE THE PRESSURE OF LIFT GAS FOR
INCREASING GAS INJECTION DEPTH
SOME ISSUES RELATED TO DOWNHOLE JET PUMPS
Slide 47
Effectiveness of downhole jet pumps for well revival
• Traditionally liquid has been the motive flow.
Effective mainly for maintaining production from
shallow oil wells with low GOR
• Effective in lifting heavy oil using a diluent fluid to
reduce viscosity(Vega field- Agip)
• Limited experience in using gas as the motive flow.
HP gas is not effective in boosting the bottomhole
pressure
• Gas can be injected at bottomhole as lift gas via a
number of specially designed nozzles to generate a
good mixture.
Slide 48
DOWNHOLE JET PUMP-GAS AS MOTIVE FLOW
Slide 49
FACTORS TO CONSIDER
FOR USE OF DOWNHOLE JET PUMPS
• PRODUCTION (OIL OR GAS)
• GOR AND GVF
• WELL DEPTH AND PROFILE
• WELL FLUIDS STAUS AT BOTTOMHOLE(GVF)
• FOR OIL WELLS USE OF JET PUMP AND HP GAS
AS THE MOTIVE FLOW WILL BE BENEFICIAL-IN
THIS CASE ALSO CONSIDER USE OF MULTI-
NOZZLE GAS INJECTION
Slide 50
DESIGN &OPERATION ISSUES
•NOISE
•JT EFFECT
• INSTRUMENTATION
•CONTROL
•CHANGE OF INTERNALS
•PERFORMANCE
MONITORING/ACCEPTANCE
•MATERIALS/CODES
Slide 51
In-line Acoustic silencers for LP
and Discharge Side Streams
18 October, 2013 Presentation title 52
Slide 53
P TP T
P
T
JET PUMP
HP
Recommended Instrumentation for Jet Pump System
COMMERCIAL-IN-CONFIDENCE
©Caltec Limited 2011. This information contains Caltec’s proprietary intellectual property and is not to be disclosed to a third party without the prior written consent of Caltec Limited.
Caltec Limited, Medway Court, Cranfield, Bedfordshire MK43 0FQ United Kingdom : Tel: +44 (0)1234 750144 Email: info@caltec.com www.caltec.com
RECOMMENDED INSTRUMENTATION
FOR SURFACE JET PUMP SYSTEM
MEASURING THE LP GAS FLOW RATE IS RECOMMENDED
PERFORMANCE OF THE SJP AND EFFECT OF HP
AND LP PRESSURE AND FLOW RATE
•Nozzle performance
•SJP response to LP flow rate
•Well performance VS SJP performance
Slide 55
18 October, 2013
18 October, 2013
20
25
30
35
40
45
50
55
0 5 10 15 20 25 30 35
Inle
t L
P p
ressu
re (
barg
)
Inlet LP flowrate (MMscfd)
HP=60 MMscfd @ 100 barg Double LP liquid flow No LP liquid flow
SJP Discharge Pressure = 50 barg
SJP design point:
HP = 60 MMscfd @ 100 barg
LP = 24.65 MMscfd @ 41.8 barg
+ 2216 bbl/d liquid
Discharge = 50 barg
Base Case Surface Jet Pump (SJP) Performance LP pressures vs. LP intake flow rates and the effect of liquid on SJP performance
Maximum flow through
SJP before choking
Operating curve 1
Caltec ref: 2215
15/05/12
Rev C
COMMERCIAL-IN-CONFIDENCE
©Caltec Limited 2012. This information contains Caltec’s proprietary intellectual property and is not to be disclosed to a third party without the prior written consent of Caltec Limited. Caltec Limited, Medway Court, Cranfield, Bedfordshire MK43 0FQ United Kingdom : Tel: +44 (0)1234 750144 Email: info@caltec.com www.caltec.com
Double LP liquid flow rate:
LP = 24.65 MMscfd @ 46.8 barg
+ 4432 bbl/d liquid
No LP liquid flow rate:
LP = 24.65 MMscfd @ 36.8 barg
+ 0 bbl/d liquid
IPR
DD1
D
raw
do
wn
DD2
Pressure
(Psi)
IPR
Well performance curve In different years
Original tangent line for PI at DD1
New tangent line for PI
Production rate
Jet pump performance
Pro
du
cti
on
pre
ssu
re
CHANGES TO PI AT DIFFERENT FWHPs
Production increase
Operating point
KEY; DD1 & DD2; DRAWDOWN 1&2
HOW THE PERFORMANCE OF THE WELL AND THE SJP MATCH
MATERIALS/CODES/ORIENTATION/LOCATION
• MATERIALS BASED ON FLUIDS COMPOSITION AND
COMPATIBILITY WITH PIPE WORK (CS,STAINLESS
STEEL,DUPLEX..)
• CODES; PIPELINE CODE(B31.3),PED,LOCAL/CLIENT
REGULATIONS.
• ORIENTATION; HORIZONTAL,VERTICAL,INCLINED
• LOCATION; DICTATED BY SITE CONDITIONS
Slide 59
Skid availability 4 to 6 weeks from order
Motive fluid HP Gas
HP Inlet pressure 50 - 140 bar (*)
LP Pressure boost 5 - 20 bar (*)
Pressure rating ANSI 1500#
Material LTCS NACE
CTP sizes (Jp-6) HP 3”, LP 4”, Discharge 6”
CTP sizes (Jp-10) HP 6”, LP 8”, Discharge
10”
CTP sizes (Jp-16) HP 8”, LP 12”, Discharge
16”
Gas Jet Pump System
Jet Pump
Skid ~ 1.5 m
~ 4 m ~ 2.4 m
LP Gas
Jet Pump
Discharge Silencer
LP Silencer
HP Gas
Vent
Drain
Drain
Drip Pan
CTP
Tie-in
Point (CTP)
Silencers
Skid
~ 1.5 m
~ 3.5 m
~ 2.4 m
Vent
ECONOMICS; USE OF SURFACE JET PUMPS
• Low capital cost
• Capital recovery within a few weeks to a few months
• Short delivery period ; 8 to 14 weeks
• Practically no operation cost /passive operation
• Practically no maintenance cost
• Alternative solutions more complex and costlier
• Rental option available to minimise capital cost
• Short life period is economically acceptable
• Could enhance what is achieved by other
deliquification systems
Slide 61
CLOSING REMARKS
• Simplicity & cost effectiveness makes jet pump solutions
very attractive & economical
• A good tool for initial well deliquification before the situation
worsens
• In addition to economic benefits, eliminating intermediate
compressors, deferring compressor upgrading or reducing
liquid hold up in pipelines are additional benefits
• The system can work well with other deliquification
solutions
• Installing tie-in points during shut downs simplifies
installation
• Rental option justifies very short operation life
Slide 62
THANK YOU
QUESTIONS WELLCOME
Slide 63