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Transcript of Maximize chance of drilling injected sand: Examples from ... · Location & history • Block 9/18...
![Page 1: Maximize chance of drilling injected sand: Examples from ... · Location & history • Block 9/18 • Discovered in 1987 • Production started in 1993 • Injection wing targeted](https://reader030.fdocuments.us/reader030/viewer/2022041208/5d64dcf088c99317158b76c8/html5/thumbnails/1.jpg)
Maximize chance of drilling injected sand: Examples from Gryphon area
Guillaume Berthereau
7th May 2014
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Agenda
Quad 9: location, history & geological settings
Derisking new targets
Drilling strategy: associated risks & uncertainties
Conclusion
Optimize well path design
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Location & history• Block 9/18
• Discovered in 1987
• Production started in 1993
• Injection wing targeted for the first time
in 2001
• Production from injection wings started
in 2004
• STOIIP: 412 MMstb
• Cumulative oil (to date): 121 MMstb
• New 3D survey in 2011
• 3D processed (2011)
• 4D processed (1990, 2002 & 2011)
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Regional depositional model
Gryphon
Maclure
Harding
• Early Eocene Balder Formation
• Episodic deposition of basin floor high density offset stacked turbidites sandstone
• Sourced from failure of the Dornoch shelf/delta front to west
• Slowed by the slope of the Crawford Ridge
Tullich
Top Balder (TWT)
From Newman & al., 1993
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Geological settings: sand remobilisation
5619.00
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5622.00
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5625.00
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5628.00
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5628.00
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5631.00
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5622.00
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5625.00
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DYKE
DYKE
INJECTION
BRECCIA
DYKE
Feeder dyke
system
DYKE
Stepped
discordant
base
• Remobilisation of the turbidites sandstone
in early Frigg times
• Creation of multi scale (from core to
seismic scale) injection wings
• Mainly within Balder sometimes extending
into Frigg age Horda Formation
T Sele
T Balder
Adapted from Hurst and Cartwright
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Challenges• Identify and derisk new targets in an
already mature field
• Infill targets
• Near field exploration
• Assess STOIIP:
• Injectite generally tuned and dipping
• Sub-seismic injected sand
• N/G (thin sand / seismic resolution)
• Moved contacts (production /
injection)
• Drilling challenges
Top Balder (Z)
Min
. am
plitu
de –
GO
C/O
WC -
CIf
ullsta
ck
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Derisking injectites: parent sand and intrusion path
Lithology volume
CI full stack
Depositional sand
Balder Fm
Top Sele
Top Balder
Injected sand
North West
South East
• Parent sand presence: volume, quality, distance
• Relationship between intrusion and parent sand
Sand
Sand
Amplitude anomaly
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Derisking injectites: Reservoir
FaultingVariance map over
CIMG anomaly
Gas capMin. amplitude GOC-200ft / 0ft
Top balder
jackup
Gas cap
GOC
OWC
Injectite
geometry
AVO QC
Bowl
shape
Elongated
shape
Intercept
Gra
die
nt
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Derisking injectites: 4D
• 4D observed theoretically only due to fluid movement
(no significant pressure change)
• Fluid movements over Gryphon:
• Gas into oil (due to production): softening
• Water into oil (due to production): hardening
• Oil into gas (water injection): hardening
• Detect and estimate moved contacts
• Integration of seismic and dynamic model: sim2seis
Amplitude anomaly
4D (water coning)
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Drilling strategy• 2 strategies:
• 1 single target
• Combination of targets
• Depends on:
• Economics
• Drill ability
• Minimum net sand
Sum –ve amplitude
Fluid vol. (2011)
GOC/OWC
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On the risk of drilling along strike…
• Well drilled on top of injected body (Dipping SE)
• Best pay section matching with main amplitude
anomaly
• Otherwise more thin sand corresponding to dimmer
amplitude (poorer N/G)
• Still a good producer though: Does it matter as long
as drilling on top of the injectites?
• Miss the main sand because of:
• Lateral positioning (seismic migration)?
• Depth conversion error?
oGOC
oOWC
Top Balder
Top Sele
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Injectite positioning uncertaintyMovement due to migration:
Δx= (V * TWT * sinθ) / 2
• Migration velocity used for depth
conversion
• Calibrated to well data
• All scaler values between 0.99 and 1.01
(1% error)
TWT Balder = 1.65s
% Velocity error: 1%
Vav Balder ~ 6600ft/s
ft
Movement due depth conversion error:
Depth error (De)
θ
Δx= De / Tanθ
• 1 st. deviation error at Top Balder= 27ft
• 1 st. deviation error at Top Sele= 44ft
• Dip of injectites: between 10 and 30°
ft
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Optimizing well path: depth conversion
• 3 velocity models proved reliable available
• Selection of the best depth conversion on the target area
based on:
• Statistics of surrounding wells: Balder / Sele / HC
• 4D around targeted area and/or surrounding wells
• Fluid contact assessment: gas cap
Water coning
Water coning
Water coning
Hard
en
ing
So
ften
ing
Gas coning
Gas coning
Gas coning
GOC
OWC
GOC
OWCBrightening stops at GOC
Amplitude
Amplitude
TV
Dss
TV
Dss
Depth conversion 1
Depth conversion 2
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Optimizing well path design: Datum
• Dealing with 3 phases:
• Significant gas cap
• Oil phase
• Strong aquifer
• Relatively homogeneous PHIE, Sw (undrained)
• Optimum datum depends on:
• Sand distribution
• Presence of 3 phases
• 4D: consistency between 4D seismic and
simulation model (sim2seis)
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Conclusion
• Understanding the distribution of injectites and their characteristics helps
identifying and derisking more challenging infill or near field targets
• Importance of understanding connection with aquifer and gas cap of every
single injectite for simulation model
• Importance of depth conversion assessment in well path optimization
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Acknowledgment