an introduction to fibre-optic distributed acoustic sensing...
TRANSCRIPT
© Copyright OptaSense Ltd. 2013
An introduction to fibre-optic
Distributed Acoustic Sensing and
its impact on IOR and EOR
Finding Petroleum: New technologies for
describing and monitoring reservoirs
David Hill, CTO
26 November 2013
© Copyright OptaSense Ltd. 2013 2
A quick Summary Our services
1. Hydraulic Fracture Profiling:
Measurement of fluid / proppant placement
2. Permanent Wellbore Monitoring:
Visualising flow dynamics & obtaining PLT readings without well intervention.
3. Seismic Recording: On demand full well bore imaging without intervention.
© Copyright OptaSense Ltd. 2013
Who we are
© Copyright OptaSense Ltd. 2013 4
OptaSense®
• OptaSense™ is part of the QinetiQ Group, a UK based multinational R&D organisation employing 9,000 people worldwide, with revenues of around $2.5 billion per year.
Oil Field Services
OFS Operations Centre, Calgary
• OptaSense™ has 165 staff and is headquartered in the UK with offices in USA, Canada, UAE and Australia.
© Copyright OptaSense Ltd. 2013 5
OptaSense® Oil Field Services Applications
Oil Field Services
Completions
Cement cure monitoring
Hydraulic Fracture
Profiling (HFP)
Cross Well Communication
Microseismic
Production
Steam flow profiling
Casing leak detection
Production Logging
Evaluation
Land based Vertical Seismic Profiling (VSP)
Offshore Vertical Seismic Profiling (VSP)
© Copyright OptaSense Ltd. 2013 6
OptaSense® Oil Field Services Applications
Oil Field Services
Completions
Cement cure monitoring
Hydraulic Fracture
Profiling (HFP)
Cross Well Communication
Microseismic
Production
Steam flow profiling
Casing leak detection
Production Logging
Evaluation
Land based Vertical Seismic Profiling (VSP)
Offshore Vertical Seismic Profiling (VSP)
© Copyright OptaSense Ltd. 2013
Completions
© Copyright OptaSense Ltd. 2013 8
Hydraulic Fracture Profiling Real-time DAS-HFP™ display
Pump
rates
Long
period
DAS
Short
period
DAS
DTS
Uptake
calc
© Copyright OptaSense Ltd. 2013 9
Hydraulic Fracture Profiling Using OptaSense DAS-HFP™ to monitor an effective fracture treatment
© Copyright OptaSense Ltd. 2013 10
Hydraulic Fracture Profiling Real-time estimation of proppant and fluid placements
Proppant Placement Fluid Placement
Stage 3
Perf 1 5 7
Perf 2 68 61
Perf 3 5 7
Perf 4 22 25
0
10
20
30
40
50
60
70
80
DA
S C
aclc
ula
ted
% D
istr
ibu
tio
n
© Copyright OptaSense Ltd. 2013 11
Microseismic event detection For passive and frac generated events
Well head
Channel 300
Channel
400
• Detection of low frequency, high magnitude (>-1.5) microseismic events initiated at reactivated faults.
• Geolocation using 1 component (1C) sensor possible using shaped array localization
Time (ms)
Vert
ical
part
of w
ell
Heal of
well
Horizonta
l
part
of w
ell
P-wave:
5.37e+03 m/s
S-wave:
3.29e+03 m/s
Another
smaller micro-
seismic event
© Copyright OptaSense Ltd. 2013
Production
© Copyright OptaSense Ltd. 2013 13
Flow assurance
• Permanent Production Logging:
– Gas & Liquid rates per Well / Zone / Perf, and 2-phase flow
Cost reduction and increased understanding
In-flow
In-flow
In-flow
DAS optical
sensing cable
Bend
Well Head
GLM 1
GLM 2
Packer
ICV D
ICV C
ICV B
V ≈ 1 m/s
Slug flow in a vertical well section
• Flow assurance near term targets:
– Qualitative detection of fluid entry at perforations.
– Quantitative inflow profiling over perforations.
– Quantitative axial-flow profiling over stages.
– Quantitative (slug) velocity profiling over stages.
© Copyright OptaSense Ltd. 2013 14
Flow assurance Examples of DAS data taken on unconventional gas producers
Courtesy of Shell
© Copyright OptaSense Ltd. 2013 15
Qualitative flow monitoring Horizontal well with fibre behind casing
3D visualisation
of flow
2D waterfall
of flow
Dep
th
Time
Replay speed x1,120
© Copyright OptaSense Ltd. 2013 16
Courtesy of Shell
Flow Assurance
• Production profiles estimated from DAS-PLT™ for three sequential production periods in an unconventional gas producer.
The next step: Quantitative inflow profiling – DAS-PLT™
© Copyright OptaSense Ltd. 2013 17
Well control
• No flow over ICV D when high pressure zone A is open
Smart oil producer
MID FREQUENCY BAND
Courtesy of Shell
© Copyright OptaSense Ltd. 2013
Evaluation
© Copyright OptaSense Ltd. 2013 19
OptaSense experience
• OptaSense is the industry leader in providing DAS-VSP™
– Experience conducting VSP in completed, horizontal, fishhook and slim-hole wells
– Over 80,000 shots of data acquired in field operations
– Typically hundreds of levels acquired with every shot
Providing VSP using DAS
2013 winner of the Hart’s E&P Meritorious Award for
Engineering Innovation (Geoscience)
© Copyright OptaSense Ltd. 2013 20
DAS-VSP™
• Non-intrusive
– VSP in wells inaccessible to geophones
• Permanent
– Lower cost on-demand monitoring
• Full vertical coverage
– Better imaging
– Faster acquisition
• Retrofitable
– Deployable on tubing
– Synergies with in-well monitoring
• Robust
– Operable in HTHP wells
Providing unique advantages
Examples of OptaSense DAS-VSP™ seismic gathers
© Copyright OptaSense Ltd. 2013 21
Reservoir monitoring
• EOR Surveillance Project
– Well and Reservoir Management to increase Ultimate Recovery by 5%
– Areal surveillance to track steam conformance
– Piloted monitoring methods over 1P area
Steam Injection for thermal Enhanced Oil Recovery (EOR)
• Key Challenges
– Very busy brown field
– Unstable steam injection
– Various sources of industrial noise
17P Development Steam in 2013
1P steam injection since Q1 2009
2nd footprint
1st footprint
1P 125m
1 k
m
10-acre inverted 7-spot patterns
• Key Uncertainties
– Vertical and horizontal sweep
– Steam injection preferential path
– Growth rate of the steam chest
© Copyright OptaSense Ltd. 2013 22
Reservoir monitoring Data & Imaging – DAS on tubing vs. Geophones clamped to casing
Geophone
DAS
DAS image Geophone image
Natih EC
Reservoir
VSP well
2 vibes, 4 sweeps 1 vibe, 3 sweeps
• Field trial in 2012 DAS/DTS (on tubing) & geophones in the same well
• Data DAS noisier than geophones / lower SNR / tubing ringing
• Images Comparable / DAS slightly lower frequency, narrower
• Acquisition time Would be comparable if using two vibes for DAS
Walk-away VSP Raw data
© Copyright OptaSense Ltd. 2013 23
• To monitor steam chest and heat development within the 17P pattern area
• To advise on future pattern spacing / design and infill strategy
1P steam injection
since Dec 2008
2nd footprint:
7P
1st footprint:
10P
1P 250m
1 k
m
10-acre inverted 7-spot patterns
Flower
Pattern
17P steam in Sept 2013
Reservoir monitoring Areal Surveillance Objectives
© Copyright OptaSense Ltd. 2013 24
seismic coverage
by 1 DAS well
Reservoir monitoring
• December 2013 – Install DAS & DTS fibre-
optic cable in eight wells
• January 2014 – Acquire baseline 3D
DAS-VSP™ using virbroseis
• 2015, 2016, 2017 – Repeat survey
First ever multi-well 3D DAS-VSP™, simultaneous recorded worldwide
AL-188
AL-11
AL-105
AL-140
AL-191 AL-126
Observation
Injection
Production
Existing DAS Baseline DAS coverage outline
AL-128
AL-185
© Copyright OptaSense Ltd. 2013 25
Dual well 3D VSP in deepwater
• FO cable deployed on the production string
• No rig time required
– Drastically savings
– Repeat at any time
Made possible by DAS-VSP™
• Two wells acquired simultaneously
• 50,000 shots in seven weeks
• ~1,400 DAS levels using pre-existing FO cable
• 70,000,000 traces
Courtesy of Shell
© Copyright OptaSense Ltd. 2013 26
Dual well 3D DAS-VSP™ in Deepwater Utilising DAS-VSP™ data
• Excellent data quality
• Velocity calibration for positioning of new well
• Time-lapse imaging for water-injection monitoring
© Copyright OptaSense Ltd. 2013
Summary
© Copyright OptaSense Ltd. 2013 28
DAS provides unique sensing opportunities Multiple application applied over the life of the well
Time
Construction Completion Production
Flow back
Repeat VSP
Repeat VSP
Abandonment
Cement Job Assessment
Frac Monitoring
Flow
Subsidence monitoring
Baseline VSP
Microseismic Monitoring
Valve / Pump Monitoring
MMV VSP
Vertical Seismic Profile
Hydraulic Fracture Profiling
Hydraulic Fracture
Characterisation
Flow Assurance
Wellbore Integrity
Monitoring
X-Well Comms
Casing leak detection
© Copyright OptaSense Ltd. 2013 29
Thank you
© Copyright OptaSense Ltd. 2013