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Gas Lift Automation
Dr Alasdair S BrownTechnical Manager
EPS Americas
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Automation
• A Requirement for fields with many wells• Intelligence needs built in to applications to
permit automated diagnosis• “Productisation” is important to shorten time
to implementation• Standard Interfaces for components to allow
quick integration. Concentrate software effort on integration rather than development
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Automation
• Solutions need to be robust and integrated on a solid, well designed basis, capable of scaling up to support total field operations
• Not put together by “garage mechanics with glue guns” – Larry Ellison on the need for software which requires less tailoring
• Need to integrate workflow across technical disciplines (“Knowledge Management”)
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Step Change Example - Refining
US Refining Efficiency
Throughout the nineties, US refining utilisation has improved radically.
This benefit was delivered through the application of Automation and Optimization IT.
1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 20000
5
10
15
20Millions Of Barrels Per Day
80
85
90
95
100Utilisation Rate
Capacity Utilisation
Year
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Objective - PDVSA identified the opportunity to make significant gains in production from mature fields in the Maracaibo area through integration of automation and optimisation technologies.
Scope– PDVSA awarded a contract to a consortium
led by ABB to deliver an integrated system (PRAP) to deliver these gains
– EPS deliverables included the optimisation systems and well modelling and diagnosis in the automated well testing subsystem
Dynamic Gas Optimisation
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DataReconciliation
DGO
Well ModelRecalibration
LegacyData
Systems
Pri
m.Changes
NeuralNets
Well
Test
System Geometry
ASMS
OM&S
Decoupled
CDMS
One iGES Server per BU
iGES-basedapplications
OracleIntermediate
DataBase
MiddlewareTransaction Services
SCADA ServerSCU 2
Real Time History
SCADA ServerSCU 7
Real Time History
PIHistorian
Crude/WaterTreatment
&Water Injection
Dynamic LeakDetectionPI Decoupled
from PRAP
Databaseservers
CDB
MasterRecollectors
PI API
SCADA ServerSCU 1
Real TimeHistoryAverageData
Real Time
SCADA ServerSCU 6
Real TimeHistoryAverageData
OPC
ABB Simcon
KBC UpRight EPS
Valmet
Stoner
ODBC
COM
PRAP Architecture
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7 May, 2001
Integration CaseStudy
Well CL243
THP
CHP
THT
Qgi
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e-petroleumservices.com7 Mayo, 200116:16
The casing pressure increasesrapidly...
THP
CHP
THT
Qgi
07/05/2001 16:16 Well 5042 :: CL243-1 :: Regla 42 de Pozo de ASMS :: SEDILAGrealiza una corrida inicial en el pozoCL243 porque la presión de casing cambió. La posible razónpodria ser:1. Múltiples puntos de inyección, o2. Falla en las válvulas de gas lift, o3. Comunicación Tubería-anular.SEDILAG debe confirmar la razón especifica.Una corrida de SEDILAG sera iniciada automaticamente.
5042 :: CL243-1 :: ASMS Well Rule 42 :: SEDILAG has performed an initial run on well CL 243because the casing pressure has changed. The possible reason could be:1. Multiple injection points, or2. A gas-lift valve failure, or3. Tubing-Annulus communication.SEDILAG should confirm the specific reason.A SEDILAG run will be initiated automatically.
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e-petroleumservices.com7 Mayo, 200116:16
A 75 minute timer starts to see if the new abnormal situation in the well stabilises before starting SEDILAG
CHP
THT
Qgi
THPUsing Zoom...
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MAX Function
MIN Function
THPCHP
QgiAVG Function7 May, 200117:32
The analysis of the trends and the extraction of data for the SEDILAG execution starts
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7 May, 200117:32
A SEDILAG run starts which combines these process data values with the production history and the WellFlo well model.
THP
CHP
THT
Qgi
SEDILAG RUN OUTPUT DETAIL FILE:
[HEADER]Well=CL243Diagnosis date=07/05/2001Current period=5/5/2001-1/1/2038Previous period=0/0/0-4/5/2001Requested by=ASMS WR 42
[BSW_LINEAR_FIT]Iteration1=30,66.427,-9.00933e-005,-0.0549152,-0.549152
[BSW_AVERAGE_FIT]Iteration1=30,0.650667,0.0707537,0.707537Iteration2=30,0.650667,0.0707537,0.707537
[PRODUCTION_DATA]BSW=0.6507QF=1064.0RGP=339.0QGI=1.2API=20.00RF=118.4RGF=1249.1
[CHART_DATA]Chart date=7/5/2001CHP=1354.1CHP_descriptor=ITHP=0.0THP_descriptor=IMANP=1467.0MANP_descriptor=CQGI=1.2QGI_descriptor=CCycle=17.0
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7 de Mayo, 200117:32
As a result of the SEDILAG diagnosis, an alarm is produced.
THP
CHP
THT
Qgi
07/05/2001 17:32 Well 7005 :: CL243-1 :: SEDILAG Rule 5 :: SEDILAG has estimated potential incremental production of 96.761 BPD as a result of analysis of circular chart dated 2001/05/07-17:31:02. The well will be tested with Priority 3. Continuous gas-lift diagnosis indicates: ’Unstable multi-point injection. The gas is being injected through valve 6 which is the deepest in the well. The PCVO/PTO test indicates that valve(s) 5 is/are cycling open and closed.’ The recommendation of the continuous GL diagnosis is ‘Consider replacing the valve(s) which is/are cycling open and closed. The estimated incremental production is 96.8 STB/D.’
07/05/2001 17:32 Well 7005 :: CL243-1 :: SEDILAG Rule 5 :: SEDILAG has estimated potential incremental production of 96.761 BPD as a result of analysis of circular chart dated 2001/05/07-17:31:02. The well will be tested with Priority 3. Continuous gas-lift diagnosis indicates: ’Unstable multi-point injection. The gas is being injected through valve 6 which is the deepest in the well. The PCVO/PTO test indicates that valve(s) 5 is/are cycling open and closed.’ The recommendation of the continuous GL diagnosis is ‘Consider replacing the valve(s) which is/are cycling open and closed. The estimated incremental production is 96.8 STB/D.’
Integrationwith Well TestOptimization
Comes from SEDILAG andconfirms the suspicions ofASMS!
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e-petroleumservices.comResults• An integrated production model was built
by EPS and interfaced to the SCADA system.
• The initial implementation covered some 250 wells in Lake Maracaibo
• This pilot phase generated quantifiable gains of between 2% and 7% in the areas covered resulting in a bottom line performance gain of $36 million per annum.
• The success of the pilot has given PDVSA the confidence to implement this technology through all its assets - this is projected to improve financial performance by $800 million per annum
Dynamic Gas Optimisation
The DGO application optimizes the use of gas as a fuel and between the different consumers.
Fuel, Qgc
FormationGas, Qgf
Other uses= Qgf-Qgc
LiftGas,Qgi
Oil + Water+$ -$
-$
+$
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i-DOObjective – short term gains of 3-7% in production,
medium term – unit cost reductions of up to 35%Scope• Used on a daily basis to manage the asset and
make operational decisions including• Hydrocarbon Accounting• Production Reporting• Environmental Reporting• Production Loss Management• Production Forecasting • On-line “Real Time”
– Field Production Optimisation– Production Welltest Diagnosis
Delivery• An integrated set of tools linked to real time data
acquisition systems for on-line operation
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i-DO
Implementation
• Build on existing products
• Reduce risk through virtually an “off-the-shelf” solution– All components configurable (without software
changes) for different assets
– Generic SCADA interfaces available
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Intelligent Daily Operations
Production Allocation(PALMS)
Hydrocarbon Accounting(PALMS)
DiagnosisRules
(WPAS)
Optimiser(ReO)
Control Module(i-DO)
BHP Data Interpretation(PanSuite)
Surface Network Models(ReO)
Material Balance
Resevoir Models(MatBal)
SC
AD
A I
nter
face
Inte
rfac
e to
oth
er a
ppli
cati
ons
Fie
ld S
CA
DA
Sys
tem
Eco
nom
ic
mod
el
R
isk
an
alys
is
Oth
er
apps
Internet/Intranet
users
Models(WellFlo)
Well
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