optimizing production from liquid loading wells - · pdf fileoptimizing production from liquid...
TRANSCRIPT
Outline
Introduction
Field Issues
2013 Optimisation Activities
Well Cycling Optimisation
Batch Foam Optimisation
Lessons Learned & Best Practices
2
The Field
A large gas-condensate field located in the UKCS
First gas was around 1998
65% of GIIP recovered to date
Gas is trapped in Lower Cretaceous deepwater sands
Reservoir strongly layered with multiple reservoir intervals separated
by thick shales
Low – Moderate permeability
Developed using long, deviated wells with large tubing IDs
3
2013 Production Challenge
5
Multiple elements contributing to a
more robust production
performance process:
1. Cycle Well Optimisation
2. Batch Foam Treatment
Optimisation
3. Improving Measurement
Techniques
4. Production Performance
Reviews
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We
llh
ea
d P
res
su
re [
bar]
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40
50
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Flo
wli
ne
Te
mp
era
ture
[d
eg
C]
Liquid loading well -
frequent low pressure
routing necessary
(cycling)
Liquid loading well post-batch foamer treatment -
less frequent low pressure routing necessary
Well Cycling & Batch Foamer Treatments
6
Well Cycling Optimisation Study
19 liquid loading wells
Maximum of 3 wells through low pressure system at once
Each well takes around 7-8hours to unload & stabilise
7
Cycle Well Uptime Cycle Well Production
Model
8
Time
TH
P [
ba
rg]
TH
T [
de
gC
]
Ga
s R
ate
[m
mscfd
]
THT Lower Limit
Test points obtained by routing well
through Platform Test Separator
Decline rate assumed through test
points
Typical THT decline input &
relationship assumed between THT
& Q
Well Cycling Tool Workflow
9
Input duration
of next cycle
Model
calculates
current Q for
each well
Cum. gas
predicted over
next cycle
Cycle
Advantage
determined
Cycling
Advantages
ranked
PE to QC
results &
perform well
movement
Become
more
predictive
Optimise
Production
vs. Uptime
Batch Foam Treatment Optimisation
Foamer (surfactant) is batch-injected into low rate wells to decrease
the critical gas rate and encourage de-liquification
Foam decreases the density (rL) and surface tension (mL) of the liquid,
in turn increasing the liquid unloading potential
Used on this gas condensate field with original trials 5 years ago
Effectiveness highly variable… why? Optimisation… how?
10
MSc Project Outline – Imperial College
1. Literature Review
External knowledge
Internal data
2. Foam Effectiveness
Well Completion
Geographic Position
Dynamic Effects
3. Foam Optimisation
Injection Volume
Foam Soak Time
4. Field Production Trials
Potential Benefit
11
Ref. 12, 16
Foam Optimisation – Volume?
C
A. Pressure Survey
B. Downhole Gauge
C. Acoustic Survey
Pressure
Dep
th
B
THP
DHG
Downhole Gauge
Liquid Level
Pressure
Dep
th PLT
Liquid Level
A Ref. 4
12
Foam Optimisation – Volume!
E.g.
Wellbore liquid volume +/- < 1.5
barrels
Foam injection volume +/- < 0.05
barrels
QC
13
Well
Details
Foam Optimisation – Time?
Foamer
Viscosity Foamer
Density
Gas
Z-Function Gas
Density
Film Flow Model
Ref. 6, 14, 24, 28
Ref. 8, 13, 19
(Adapted from Jackson 1955)
14
Field Production Trials
Test Case:
1x of ≈ 6-8 regular cycle wells:
Result:
Increased well up-time (+12 hrs/wk)
MP utilisation reduced by ≈ 36 hrs/wk
Extrapolated to one year this is worth
over £2M (at £0.66 / therm)
‘Standard’
‘Optimised’
12HR
16
The Future for the Field
Time
Ga
s R
ate
Low Rate Well Work Over Development
Long Term Compression
2010 New Wells
2011 Capillary Strings
Cycling
Base
17
Best Practices & Lessons Learned
Best Practices
Close offshore & onshore collaboration
is crucial to project success
Never assume a routine activity is fully
optimised
Challenging current processes by
interpreting & gathering the correct data
& streamlining the process can lead to
significant benefits
18
Lessons Learned
Production optimisation can be
successful with minimal associated cost
The combined effect of multiple small
optimisation opportunities can have a big
impact to total production
References
20
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3. Coleman, S.B., Clay, H.B., McCurdy,
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