Arran Field Case Study: From conceptual model to Reservoir ... Field Case... · DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 3 Dana Petroleum 15 June
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Dana Petroleum
Arran Field Case Study:Arran Field Case Study: From conceptual model From conceptual model
to reservoir modelto reservoir modelJamie CollinsJamie Collins
Dana PetroleumDana Petroleum
DEVEX 2011DEVEX 2011
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 2
Dana Petroleum
15 June 2011
Contents
Acknowledgments
Arran field introduction and project objectives
Project strategy
Conceptual model
Key data observations
Core
Outcrop analogues
Seismic
Static reservoir modelling
Conclusions
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 3
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Acknowledgments
Partners
Esso Exploration & Production UK
Shell UK
Dyas
E.On Ruhrgas UK E&P
Dana team
Natalie Bordas-Le Floch
Jamie Collins
Brian Cullen - Reservoir Associates North Sea
John Downey
Steve Kenyon-Roberts
Paul Mattson - Logios Consulting
Jason White
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Arran Field located 240km east of AberdeenCentral Graben - Blocks 23/11 & 23/16
Gas condensate field
Palaeocene Forties Sst Member reservoirMedial Forties turbidite system
Eastern margin on-laps onto Jaeren High
StructureArran North - reservoir pierced by
Zechstein salt diapir
Arran South – Stratigraphic pinch-out to east, with local low relief four way dip closure
Project objectivesIncorporation of new 2010 3D seismic data
– Reinterpretation of all existing data
Support detailed well planning
– 3 well development
Arran Field Introduction
ArranRedrawn from Fraser et al., 2003
Petrostrat Regional Study
Northern North Sea
Moray Firth
Central North Sea
East Shetland Platform
Horda Platform
Central Graben
West Central Shelf
Utsira High
Witch Ground Graben
North
Vik
ing
Gra
ben
Cen
tral
Vik
ing
Gra
ben
Sout
h Vi
king
G
rabe
n
Jaeren High
Inner Moray Firth
Outer Moray Firth
Tail End GrabenMid North Sea High
Fladen Ground
Spur
Redrawn from Fraser et al., 2003
Redrawn from Petrostrat Regional Stufy
Arran Field
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Forties Sst pinch-out marginArran North
Arran South
Arran Field located 240km east of AberdeenCentral Graben - Blocks 23/11 & 23/16
Gas condensate field
Palaeocene Forties Sst Member reservoirMedial Forties turbidite system
Eastern margin on-laps onto Jaeren High
StructureArran North - reservoir pierced by
Zechstein salt diapir
Arran South – Stratigraphic pinch-out to east, with local low relief four way dip closure
Project objectivesIncorporation of new 2010 3D seismic data
– Reinterpretation of all existing data
Support detailed well planning
– 3 well development
Arran Field Introduction
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 6
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Base UK
HordaSeleForties Fm
Ekofisk
BCUTop TriassicTop saltRotliegend / Base Salt
Base Forties
Triassic
S
1 km
Salt
23/16b-10
Arbitrary Line 1992 23/16 3D Shell Reprocessed 2003 PSTM
Forties Seismic Pinchout
W E
LineLocation
Forties
Arran Seismic Cross Section
CGGV Quad 22 Regional Survey 2008
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 7
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Arran Field Data
Well data6 wells in immediate area, ~50% of
reservoir interval in wells cored
– Core coverage over entire Forties stratigraphy
– Wells located along axis of Forties fairway
Biostratigraphic, log & MDT data
– Limited DST data
CGG Veritas Quad 22 Regional 3D Survey 2008 Reprocessed 2010 to PreSDM
– Seismic inversion fluid cube
– Seismic Vshale volume
Partner analogue data from nearby fieldsTechnical and production experience
Reservoir connectivity
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 8
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Project Strategy
Seismic
Outcrop Analogues
Core
Seismic Attributes
Conceptual Model
Knowledge Sharing
Stratigraphic Framework
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 9
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Forties Reservoir Conceptual Model
Arran Field depositional settingsMedial parts of Forties turbidite systemEastern margin thins and pinches out
against Jaeren High
Preliminary core interpretations showStacked amalgamated and non-
amalgamated fairway sandstone bodies– High density turbidites
Extensively interbedded with – Heterolithic low density turbidite fringe
deposits – Slumps & debris flows– Hemipelagic and turbiditic shales
Moderate NTG system with poor reservoir qualityThin heterolithic faciesAvg. net porosity ~15%Avg. net permeability ~5mD
From Hempton et al, 2005 – Sele Fm Reservoirs
Arran
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 10
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Central fairway submarine channels and amalgamated sands `
Non amalgamated sands passing laterally into lobe margins
Thin bedded lobe fringes passing laterally into interlobe / abandonment shales
Forties Reservoir Conceptual Model
Tabular elongated turbidite lobe bodies - high density turbidites
Axial amalgamated lobe bodies, passing laterally towards heterolithic lobe fringes
Lateral migration of lobes over time
Conceptual model evolved through project life cycle, along with field interpretations
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 11
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Sandy Debrites & Slumps, 4
Interlobe / Abandonment Shale, 15
Channels & Amalgamated, 12
Non Amalgamated, 22
Thin Bedded Lobe Fringe, 10
Muddy Debrites, 14
Lobe Margin,24
Arran Core & Facies Interpretations
~50% of Arran reservoir interval coredDetail core facies interpretation7 key facies identifiedGrouped into depositional units to assist
with reservoir modelling
Moderate NTG system dominated by non amalgamated and lobe margin faciesLack of large erosive channel unitsAverage bed thickness dependent on
facies– Typically <50cm due to heterolithic
facies– Low energy lobe environment
Consistent with medial but marginal location within Forties turbidite systemPoorer average reservoir quality than
typical Forties fieldsDominated by thin heterolithic reservoir
units
High proportion of thin
heterolithic facies
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Non-Amalgamated Facies
• Massive and dewatered high density turbidites
• Beds are discrete depositional units, separated by preserved low energy bed tops
Non-Amalgamated & Lobe Margin Facies
Lobe Margin Facies
• Interbedded high density turbidites
• Linked debrites with muddy debrites
• Thin-bedded turbidites and slumps
Implications for static modelling and reservoir performance?
A
B
2ft cell
A
B
A
B
2ft cell
A
B
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Outcrop Analogue Data – Gres d’Annot
Vicinity of Col de Cayolle
• Key observations:
• 3D appreciation for reservoir distribution and architecture
• Lateral and vertical facies transition
• Reservoir connectivity
~ 10m Thick-bedded submarine sandlobe
Lateral and vertical facies transition
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A) Amalgamated thick bedded high density sand-lobe – Arran field.
B) Thick-bedded high density turbidites of slightly channellised depositional sandlobes
A
B
C
D
D) Lobe-fringe low density turbidites
C) Thin-bedded lobe- fringe - Arran field.
Core - Outcrop Analogue Data
Col de la Moutiere Col de la Moutiere
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B D
Seismic - Outcrop Analogue Data
Chalufy - Gres d’Annot
CGGV Quad 22 Regional Survey 2008
Seismic scale architecture
Bed scale architectures
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Seismic Interpretations
CGGV 2008 seismic data
Seismic Vshale volume
Detailed integration of all data
Seismic & attributes
Stratigraphic framework
Outcrop analogue
Vshale data clearly identifies low Vshale regions
Sand rich reservoir intervals
Used to assist with reservoir characterisation
Lateral migration of seismic lobe units with time
Consistent with conceptual model
2010 CGGV VShale BL
Top Forties
Base Forties
Top Forties
Base Forties
CGGV Quad 22 Regional Survey 2008
Sand rich lobes identified from
Vshale data
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 17
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Seismic Attribute Data
Seismic Vshale volumeSpatial relationship and distribution of
turbidite units
Proportional slices through Vshale volumeElongated lobe bodies identified
Northwest-southeast orientation
Possible slump bodies derived from Arran North diapir
Vshale volume controls reservoir facies distribution during static modellingSpatial relationships
Palaeoflow azimuth data
Lobe dimensions
Vshale volume used to assist with well planning optimisation
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Palaeoflow Azimuth Data
Upper Forties-Vshale slice
Lower Forties-Vshale slice
Lateral migration of lobe towards
field margin
Local deflection of lobesForties turbidite
palaeoflow data
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Static Modelling
Non Amalgamated Facies
Vshale
Prob
abili
ty
Facies Probability Grid
Good correlation of Vshale vs Facies
Vshale used to condition facies model
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Arran Facies Modelling
Vshale facies probability data applied
Used to control reservoir distributions, proportions & lobe azimuths
Analogue and well data used to determine reservoir dimensions
Maintain facies spatial relationship
Amalgamated sand rich axis passing laterally into marginal heterolithic lobe fringes
Slumps / debrites derived from
Arran North diapir
Andrew High trend
Salt diapir
Andrew High trend
DEVEX 2011 - Arran Field Case Study: From conceptual model to reservoir model 21
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Arran Facies Model-2ft slice
Slump bodies sourced from diapir
Moderate reservoir passing downdip and laterally into poorer
heterolithic reservoir
Arran Facies Modelling
Vshale facies probability data applied
Used to control reservoir distributions, proportions & lobe azimuths
Analogue and well data used to determine reservoir dimensions
Maintain facies spatial relationship
Amalgamated sand rich axis passing laterally into marginal heterolithic lobe fringes
Slumps / debrites derived from
Arran North diapir
Andrew High trend
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Low Vshale resulting in good reservoir quality
23/16b-1st
23/16b-1stTransition from poor to good reservoir captured in Vshale and facies model
Arran Facies – Vshale Cross Section
Moderate Vshale indicating heterolithic reservoir facies
• Reservoir model consistent with • Conceptual model• Core & outcrop observations• Seismic characterB
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Low Vshale resulting in good reservoir quality
23/16b-1st
23/16b-1stTransition from poor to good reservoir captured in Vshale and facies model
Arran Facies – Vshale Cross Section
Moderate Vshale indicating heterolithic reservoir facies
• Reservoir model consistent with • Conceptual model• Core & outcrop observations• Seismic characterB
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Model Uncertainties
Key uncertainties include
Seismic scale reservoir characterisation
– Is it sufficient to predict detailed reservoir performance?
– Facies distribution & connectivity – especially towards field margin
– Kv/Kh permeability
Limited well test data to quantify reservoir uncertainties
Knowledge sharing with partners proved critical to quantify uncertainties
Adjacent Forties field analogue data and production experience
Vertical and lateral connectivity
– Facies distribution
– Permeability
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Conclusions
Successful integration of cross discipline subsurface data
Detailed reservoir model constructed
Key uncertainties captured
Study supports detailed well planning
Close collaboration of all disciplines from start to finish
Objectives and uncertainties of various disciplines captured early in project lifecycle
Support from Joint Venturers
– Technical and production experience from analogue fields utilised
Lessons learnt from project captured to feed back into future model builds
Reservoir connectivity due to modelling parameters
Ongoing evolution of conceptual model and field interpretations
– Must allow flexibility for an evolving and iterative approach
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Project Strategy
Seismic
Outcrop Analogues
Core
Seismic Attributes
Conceptual Model
Knowledge Sharing
Stratigraphic Framework
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