gas lift automation

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e-petroleumservices.com

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

gas lift automation

Documents