Production Monitoring - Scientific Workshop Final.pptx

Permanent Production
Monitoring
Observatories in Scientific Ocean Drilling
Lee Jackson & John Lovell
Schlumberger Reservoir Monitoring and Control
Rosharon, Texas

Drivers
Recovery
Reservoir Management driven
Monitor and Evaluate Production
Optimize Drainage
Update
Model
Reduced Intervention
No loss of production
Control
Monitor
Reduced risk
Real Time Evaluation
Combined with Flow Control devices
allows for immediate corrective actions.
Inflow
Inflow
Inflow
Inflow
Optimization
Inflow
Inflow
Inflow

The Early Days
• First Examples of Permanent
Production monitoring date back to
the early 1960’s
• Data would be required for several
weeks during production.
• Reliability was questionable.
• Early systems would monitor pressure
only.
3

Evolution
1978 - First subsea
wet mate connector
deployment
1972 - First
permanent strain
gauge installation
(SPE 18357)
1962 - Analog logging
gauge run on wireline
cable
1984 - First HP quartz
gauge developed
1989 – SLB
technology project for
"Permanent
Monitoring" initialized
1993 - Permanent
Quartz Gauge
(PQG)
commercialized
1992 - First remote
data communication
2003 - Revolution
in electrical
connectors with
Intellitite* series
2005 - Combining
downhole gauges
with DTS in hybrid
“NEON” cables
2006 - WellNET
downhole network
system
commercialized
2004 - NET series
generation of digital
gauges
2008 - Electrical
systems for
distributed sandface
measurements
1970 1980 1990 2000 2010
2011 - New series of
gauges with
increased multidropping
capabilities
2010 - Gauge
reliability
improvement
program
2012 - New
generation of
WellNET platform for
advanced IC systems

Current Technology
Pressure and temperature gauges
• Quartz and Sapphire gauges
• Ultra Low power SOI Gauges
• Fiber-optic P/T gauge
Distributed measurements
• Optical DTS (pumped or fixed fiber cable)
• Electrical sensor array system
300
(572)
250
(482)
200
( 392 )
175
( 347 )
150
( 302 )
100
( 212 )
50
( 122 )
0
0
Quartz Gauges
Sapphire Gauges
Fiber Optic Gauges
Conventional
NLQG-10
NDPG-10
Espionage
Electrical Gauges
NPQG-16
Fiber Optic Gauge
Ultra HP HT
345
690
1 034
1 379
1724
( 5 000 ) ( 10 000 ) ( 15 000 ) ( 20 000 ) ( 25 000 )
Working
Pressure
HP
HT
Fiber-optic gauge
NHQG-25
2068
( 30 000 )
Enablers
• Wellsite RT Connectors
• Acoustic Data Loggers
• WaveGliders
Future Technology
• UHPT Electronic Gauges
• Wireless Gauges

Downhole Monitoring Systems and Reliability
Reliability
System is a chain.
All links must be functional for system to work.
Downhole equipment
Gauge, cable, protectors
Surface and subsea equipment
Wellhead outlet, wet connector, flying leads
Acquisition card and SCM
Client MCS / SCADA
Compatible with system components from multiple suppliers
(interfacing challenges)
Project Management
Critical to Long Term Reliability
Subsea tree
Wellhead outlet
Wet connector
Harness and stab
Acq
Cable splice
SCM or
Data
Logger
Packer penetration
Flow control valve
Gauge cable head
Gauge and mandrel

Identifying Failure Modes
Surviving
1.0
0.9
0.8
0.7
2002-03
2000-01
1998-99
1995-97
0.6
0.5
1 2 3 4 5
Run Time (in years)
7

Identifying Failure Modes
8

Schlumberger Permanent Gauge Survival

Industry Growth
10

FloWatcher*
Permanent Downhole Flow Metering System
Applications
• Production allocation
• Well productivity and trend analysis
• Interference testing
• Pressure transient analysis
• Monitoring efficiency of electrical
submersible pumps (ESPs)
• Problem diagnosis

Applications
8 Single Sensor Gauges are
deployed across the reservoir
to monitor Gas/Oil and Water
contact points.
12

Applications
5 Zone Intelligent Completion with Monitoring and Control
13

Subsea Considerations
In hydrocarbon subsea wells, many completions are deployed
in separate stages so that the pressure integrity of each stage
can be confirmed before the next stage is run in. Also
simplifies any subsequent workover activity.
This translates to the need of a “wet-mate” to join cables in
one completion stage to the next.
Such wet-mates have proven notoriously unreliable… so far
14

Dual Stage Completion – Telemetry/Power Solution
Inductive coupling transmits power and data
No rotational alignment
Tolerant of debris
No exposed electrical contacts
Contraction joint provides depth tolerance
Snap-latch provides mechanical feedback
Merges data onto existing P/T control line
No additional subsea tree penetrations
15

Sandface Array Technology Components
Flux Station acts as a repeater.
Quartz Gauges and multiple array on
same twisted-pair control line
Subsea card for SCM or DIU
Spoolable array of miniaturized temperature
sensors incorporated onto cable
Inductive coupler for wireless power and
data communication
Wellhead outlet and wet-mate
Able to power dozens of P/T gauges and
spools of sensors (up to 600)
Interpretation software to provide flow-profiling,
fluid identification, etc

Case Studies of Subsea Arrays
Cleanup data
Cleanup data and Flow Profile
Cross-flow before/aftercleanup
Zonal Interference and Production
Flow Profile
Test run showed leaking isolation valve

Multiwell Analysis for Reservoir Mapping
Shut in
Producing
Original reservoir has sands
penetrated by two wells

Multiwell Analysis for Reservoir Mapping
Shut in
Producing
Interference analysis shows
unexpected connectivity
between two sand bodies

Subsea Geothermals
Radical lateral variations in temperature

Reservoir Geothermal Possibilities
4 o C 4 o C
4 o C 4 o C
OR
Isothermal contours strongly
driven by seabed
Isotherms less strongly driven by
seabed

Reservoir Temperature in these wells
was Controlled By Sea Water Depth

Reservoir Geothermal Possibilities
4 o C 4 o C
4 o C 4 o C
Sea-bed dominates – gives implications to the reservoir barriers

Long-term Methane Hydrate Monitoring
Goal: characterize MH hydrate production process during dissociation (production test)
To surface
Orange ball
Water Depth
1,000m
Wet-mate connector (Elec.)
Wet-mate connector (Elec.)
26” OH, 20” CH
MH reservoir
12-1/4”OH, 9-5/8”CH
DTS optic line
Well depth 370m
MH reservoir
60m
TAS array line
Clamp
Distance from production well ~50m

Long-term Methane Hydrate Monitoring
Goal: characterize MH hydrate production process during dissociation (production test)
4. Surface
DTS, Controller,
Wet-mate
TAS DTS Pressure
Battery
Cable Protector Vessel
Connector for ROV
2. Seafloor
MT2
Monitoring wells
MT1
3. Surface-seafloor
MC
Production well
Surface System
Water Depth
1,000m
Subsea
Cable
1. Downhole
Well depth 370m

Measurement Specifications
Optical DTS
Digital TAS
Measurement Range Entire wellbore Hydrate Zone of Interest
Measurement Resolution 1m 2m
Sensor Length 450m 390m
Measurement Accuracy ±0.5ºC ±0.1ºC
Measurement Resolution 0.01ºC 0.001ºC
Monitoring Duration > 18 months (600D) During deployment &
production test (only)

Resolution/Accuracy of Array
1mdegC/10mins

System Connectivity Diagram
3m
Surface
system on
vessel
Acoustic
Transponder
USB Storage
TAS
RS485 +
Power
WMC
holder panel
WMC
Electrical
(DTS)
~ 1.5km
3m
Bulkhead
4- Ports
‘Orange Ball’
Schlumberger
Downhole
Optical
Splice
Chamber
DTS
Controlline
Electrical
(TAS)
Field splice
Elec. Manual Mate
Opt. pre-made splice

Conclusions
Significant progress towards subsea reservoir monitoring:
• Reliability (>10yr life) is now routine)
• Production measurements moving from above the
production packer, to data along the sandface.
• Distributed measurement (electrical and optical) complement
single-point data
• Subsea hardware has been deployed in observation and
production wells, with water communication by ROV,
accoustic and hard-wired.
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