Devonian Petroleum Systems, Southern Alberta: Implications for

1
Devonian Petroleum Systems
Southern Alberta
Implications for Exploration Potential
December 10 2014
Andy Mort (GSC Calgary)
Len Stevens, Rick Wierzbicki (PrairieSky Royalty Ltd.)
2
DISCLAIMER
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Presentation.
2
3
Outline
 Background
 History
 Summary of conclusions from 1999 GSC study
 Recent discoveries
 This study
 Potential Devonian source intervals
 Review of historically reported shows in under-explored
plays
 Evidence for migration versus in-situ hydrocarbon
generation in Devonian unconventional reservoirs
 Implications
 Conclusions
 Acknowledgements
4
WCSB Atlas (1994): Ch. 31
5
WCSB Atlas (1994): Southern Alberta ?
 Poor reservoir
development
 Lack of petroleum
system elements e.g.
reef trend with adjacent
shale basin
 Sparse well control =
high risk
6
Devonian Petroleum Systems of the
WCSB (1999)
1.
2.
3.
4.
5.
6.
Elk Point (N. Alberta)
Winnipegosis
Norman Wells
Duvernay
Nisku
Mississippian
7
This Study
 Alberta Bakken:
(Lower Banff, Bakken,
Exshaw, Big Valley)
Ferguson
 Nisku: Enchant
 Cooking Lake/Leduc:
Del Bonita
 Beaverhill Lake core
 Winnipegosis: Rich
8
Elk Point System
•
•
•
•
•
Nearshore clastics and
carbonaceous shales,
restricted carbonate
platform capped with
evaporites
One oil pool at Rich,
Discovered 1986, OOIP 1.6
mmbbl, Cum 235 mbbls oil
(23 API) to date
Scattered oil shows on test
Self-sourcing from basal
algal laminites
Poor well control: 1 well
per 3 townships
Duvernay Well
Cambrian Well
GCSW: 70%
methane, sour
Elk Point Clastics
and Carbonaceous
Shales
Prairie Evaporite
Winnipegosis Well
Rich Winnipegosis Oil Production, 23 API
Winnipegosis Subcrop
Winnipegosis Well
Ordovician Subcrop
Calgary
Elk Point Subcrop
Elk Point Water Disposal
Elk Point Subcrop
Lethbridge
Immature Dawson Bay Source
Cambrian Inert Gas
9
Family 2A: Winnipegosis-sourced oils in
Southern Alberta
7-25-034-21W4 (Rich produced oil)
SFGC
C30
Winnipegosis Formation (Elk Pt Gp)
C29
Dawson Bay Formation
m/z 217
C31
C32
C33
C34
C35
GCMS
m/z 191
GCMS
10
Geochemistry 101: Origin of Gammacerane
Tetrahymanol
Gammacerane
http://water.epa.gov/type/watersheds/named/msbasin/
hypoxia101.cfm
Gammacerane is derived from bacterivorous ciliates which were partially feeding on green sulphur bacteria. This demonstrates that
anaerobic ciliates living at or below the chemocline are important sources for gammacerane, consistent with the fact that ciliates only
biosynthesize tetrahymanol if their diet is deprived of sterols. This leads to the conclusion that gammacerane is an indicator for water
column stratification, which solves two current enigmas in gammacerane geochemistry. Firstly, it explains why gammacerane is often
found in sediments deposited under hypersaline conditions but is not necessarily restricted to this type of deposits. Secondly, it
explains why lacustrine deposits may contain abundant gammacerane since most lakes in the temperate climatic zones are stratified
during summer.
Sinninghe-Damste, J.S., Kenig, F., Koopmans, M.P., Koster, J., Schouten, S., Hayes, J.M. & de Leeuw, J.W. (1995).
Evidence for gammacerane as an indicator of water column stratification. In: Geochimica et Cosmochimica Acta vol. 59 pp. 1895-1900.
11
Beaverhill Lake
System
•
•
•
Duvernay Wells
Winnipegosis and Cambrian Wells
Caroline Swan Hills Gas
Carbonate ramp and reefs
building up off Western
Alberta Ridge prograded
over by a north dipping
carbonate ramp
Large gas condensate field
in Swan Hills at Caroline
Discovered 1986, OGIP 2.3
TCF, Cum 2 TCF to date
Moberley, Calmut
Ramp Edges
Gas and 41 API oil on DST
Prograding Souris River
Carbonate Ramp
System
Calgary
Slave Point Platform
Oil and gas shows in DST,
core, and cuttings along
Moberley and Calmut
ramp edges and in Slave
Point equivalent sediments
around Davidson Salt Basin
•
High Helium and high CO2
in wells close to Sweet
Grass Hills Intrusives
•
Poor well control in south:
1 well per 3 townships
High TOC BHL
Core
BHL Core
Oil shows
Oil Flecked
Mud in DST’s
Davidson Salt
Basin
Oil Flecked
Mud in DST’s
Lethbridge
Oil flecked mud,
C02, CH4, Helium
12
BHL Hydrocarbon Potential
13
Geochemical analysis of core stains
 Stains are internally consistent (within well)
 Stains from the two wells appear very similar
 Complex n-alkane distribution
 Phytane>>Pristane = highly anoxic source
 Heavy oil stain but doesn’t look biodegraded
 Biomarkers (hopanoids) are exceptionally prominent
Norcen et al Scandia 11-18-016-16W
PCP HAYS 12-13-014-14W4
Pr
Ph
1812.98m
Pr
1687.10m
Ph
Ph
Pr
Ph
1813.50m
Pr
1688.50m
14
Details: hopanes (m/z 191)
Extended hopanes (homohopanes)
C29
Tricyclic terpanes
C30
Typical carbonatesourced oil
C31
C32
C33
C34
C35
PCP HAYS
12-13-014-14W4
C34!
C32!
Norcen et al Scandia
11-18-016-16W
15
Details: steranes (m/z 217 & 218)
C29
C27
C28
Typical carbonatesourced oil
PCP HAYS
12-13-014-14W4
Norcen et al Scandia
11-18-016-16W
16
Leduc System
•
•
•
•
Leduc has oil/gas
production and oil and gas
shows, challenge is
trapping, there are internal
barriers to flow, traps will be
structural and diagenetic
Most recent Leduc
penetrations on the
platform have been for
water source or disposal,
there have been deep tests
at Enchant and Countess
Oil produced at Del Bonita
(39 API) from Lower Leduc
and Cooking Lake (1980-81)
Poor well control in south: 2
wells per township
Duv. Src. Rx.
Duv. Src. Rx.
Duv. Src. Rx.
Leduc Oil
Water Cut Oil
Oil in Core
Calgary
Fairholme Carbonate Complex (Evaporitic to South and East)
Countess Deep Test
Leduc Gas
Leduc Sweet Gas
South West
Platform Margin
and Perdrix
source rock ~120
km (restored).
Enchant Deep Test
Free Oil
Lethbridge
Del Bonita
Cum 1227 bbl
39.6 API oil
Sour wet gas, some CO2
17
Banff to Base Cooking Lake Stratigraphic Cross
Section Flattened on Leduc
Banff
Cores
4
DSTs
Bakken
Exshaw
Wabamun
5
1
Nisku1,3
Perfs with oil
recovery
3,4
Leduc
6 core
samples
DST#2
sample
3 core
samples
1
Ck Lk
2
6
BHL
10-50
md
<1 md
1 reported oil sat. in Leduc core
No reported oil sats. in CK Lk core
2
1 md
<10 md
Oil tested and produced from
Cooking Lake, Leduc and Bakken
7 reported oil sats. in Leduc core
18
Samples
Faint solvent cut fluorescence
observed in Cooking Lake Fm core
(~2400m)
Oil recovered from DST #2 in
Cooking Lake Fm directly overlying
BeaverHill Lake Fm (1984)
Faint solvent cut fluorescence
observed in Leduc Fm core
(~2190m)
19
Rock-Eval Screening
Sample
Type
Depth (m)
Qty
TOC
STD
STD
0
70.7
5.01 0.76 12.18 0.48
442
Core
2398.70
70.7
0.21 0.02 0.02 0.27
Core
2406.40
70
0.23 0.01 0.01
Core
2413.50
Core
Amoco et al Spring
Coulee
05-16-002-22W4
Aberford Atlantis Delb
04-30-001-21W4
STD
STD
PC(%)
RC%
MINC%
243 10 0.06
1.1
3.91
4.2
419
10 129 0.53
0.01
0.2
12.7
0.1
412
4
43 0.58
0.01
0.22
12.5
70.3
0.05 0.02 0.05 0.01
446
100 20 0.28
0.01
0.04
3
2187.60
70.2
0.31 0.18 0.25 0.03
427
81
10 0.41
0.04
0.27
12.4
Core
2187.20
70.8
0.31 0.13 0.15 0.16
418
48
52 0.47
0.03
0.28
11.9
Core
2190.75
70.6
0.28
0.17 0.19
422
61
68 0.36
0.03
0.25
12.3
Core
2183.00
70.6
0.22 0.08 0.11 0.19
427
50
86 0.43
0.02
0.2
10.6
Core
2184.40
71
0.35 0.18 0.22 0.19
426
63
54 0.45
0.04
0.31
12
Core
2186.00
70.5
0.99 0.27 0.67 0.22
455
68
22 0.29
0.09
0.9
10.7
STD
0
70.5
441
241 11 0.06
1.09
3.91
4.1
5
S1
0.1
S2
S3
0.71 12.04 0.56
Aberford Atlantis Delb
04-30-001-21W4
2184.40
Tmax
HI
OI
PI
Cooking Lake & Leduc cores
are organically lean but
Rock-Eval PI values confirm
the presence of low
amounts of migrated
hydrocarbons.
20
Core extract saturate fraction GC
04-30-001-21W4
C15
05-16-002-22W4
6.00
5.90
9.0
2398.7m
8.0
5.85
2183.0m
C30
8.5
C25
C20
5.95
9.5
5.80
5.75
7.5
C35
5.70
7.0
5.65
6.5
5.60
6.0
5.55
5.50
5.5
6
6
8
10
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
54
56
58
60
62
64
66
8
10
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
54
56
58
60
62
64
66
68
68
7.4
7.00
6.90
7.2
6.80
6.70
2184.0m
7.0
6.60
2406.4m
6.50
6.40
6.30
6.20
6.8
6.6
6.4
6.10
6.2
6.00
5.90
6.0
5.80
5.70
5.8
5.60
5.50
5.6
5.40
6
8
10
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
54
56
58
60
62
64
66
68
5.4
7.4
6
8
10
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
54
56
58
60
62
64
66
68
5.68
7.2
5.66
7.0
2186.0m
5.64
6.8
2413.5m
6.6
6.4
5.62
5.60
5.58
6.2
5.56
6.0
5.54
5.8
5.52
5.6
5.50
6
8
10
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
54
56
58
60
62
64
66
68
5.48
6
8
10
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
54
56
58
60
62
64
66
68
5.82
5.80
2187.2m
5.78
GC envelopes show little similarity or obvious systematic
variation. Isoprenoids (e.g. Pristane, Phytane) are very low
in abundance or absent. Pr/Ph<1.0 in all cases (where
present), suggesting highly reducing depositional
conditions.
5.76
5.74
5.72
5.70
5.68
5.66
5.64
5.62
5.60
5.58
5.56
5.54
5.52
6
8
10
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
54
56
58
60
62
64
66
68
5.85
2187.6m
5.80
5.75
5.70
5.65
5.60
5.55
5.50
6
8
10
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
54
56
58
60
62
64
66
68
5.72
5.70
5.68
2190.75m
5.66
5.64
5.62
5.60
5.58
5.56
5.54
5.52
5.50
6
8
10
12
14
16
18
20
22
24
26
28
30
32
34
36
38
40
42
44
46
48
50
52
54
56
58
60
62
64
66
68
21
Core extracts saturate GCMS m/z 191
04-30-001-21W4
1 S (m/z192)
05-16-002-22W4
2398.70m
2 t24T
3 Ts
4
C29H
C30H
2183.0m
2406.40m
2184.0m
2413.50m
Core extracts give similar results. Diagnostic features
(see upper left trace) include:
1. Presence of elemental sulfur (despite attempted removal with
Cu). S8 is visible in m/z 192 but at low mass resolution the
peak is commonly observed in m/z 191
2186.0m
2187.2m
2187.6m
2. Very high C24 tetracyclic terpane relative to extended
cheilanthanes (almost absent)
3. Very high Ts relative to Tm
4. C29 Norhopane dominates C30 Hopane
These features are consistent with a
carbonate/evaporite source facies.
2190.75
22
Core extracts aromatic GCMS
Phenanthrenes & Dibenzothiophenes
Ion 178.00 (177.70 to 178.70): X11457ARR.D\data.ms (Phenanthrene)
Ion 192.00 (191.70 to 192.70): X11457ARR.D\data.ms (Methylphenanthrenes)
Abundance
Ion 184.00 (183.70 to 184.70): X11457ARR.D\data.ms (Dibenzothiophene)
Ion 198.00 (197.70 to 198.70): X11457ARR.D\data.ms (Methyldibenzothiophenes)
2200000
Further evidence for an carbonate/evaporite source for these
oils is visible in the aromatic fraction where sulphurcontaining compounds dominate the TIC (Total Ion
Chromatogram). The comparison shown (right) of sulphurcontaining dibenzothiophenes (red, brown) with
hydrocarbon-only phenanthrenes (green, blue) clearly shows
the high degree of sulfur incorporation into the extractable
organic matter.
2000000
1800000
1600000
1400000
1200000
1-methylphenanthrene
1000000
1-methyldibenzothiophene
800000
600000
400000
200000
0
28.00
Time-->
30.00
32.00
34.00
36.00
38.00
40.00
42.00
44.00
23
Del Bonita DST#2 oil: Whole Oil GC
Oil recovered from DST #2 in
Cooking Lake Fm (1984)
240
220
C10
200
180
C15
160
Whole Oil Gas Chromatogram (below) indicates loss
of light ends, probably due to evaporation. The
absence of a hump representing an Unresolved
Complex Mixture (UCM) suggests no biodegradation.
A slight odd-even predominance in the lower
molecular weight alkanes suggests the oil is fairly low
maturity. Pr/Ph is about 1.1, equivalent to dysoxic
depositional environment (not reliable as a
standalone parameter - further confirmation
required)
140
120
C20
100
C25
80
C30
60
C35
Pr
Ph
40
20
0
0
5
10
15
20
25
30
35
40
45
50
55
60
65
70
75
80
85
24
Del Bonita DST#2 oil: saturate GCMS
Unlike the very unusual and distinctive molecular signature
produced by the core extracts, the produced oil from the Del
Bonita DST is consistent with many Devonian oils. Certain
features*, notably the strong C24 tetracyclic terpane peak, and
anomalously high C34 in the homohopane series suggest that
this oil correlates most probably with the Family 5C oils
(Montana Nisku) based on results in the 1999 Devonian
Petroleum Systems study.
The oils do not appear related to the core extracts
C30
m/z 191.2
C29
Ts
*
C24tetra
Tm
C23tri
St27
C31
C32
*
C33 C34
C35
St29
St21
St28
St22
m/z 217.2
25
Leduc (paleogeography)
Pedrix source rock to the
southwest of the Fairholme
Carbonate complex would have
been an early source of
hydrocarbon to the Leduc aged
carbonate platform.
Shields and Geldsetzer 1992
26
Nisku Patch reefs and drape pools
Nisku
System
•
•
•
Prograding carbonate
shelves, evaporitic
lateral and top seals,
salt and faulting related
structural traps and
facies traps
Duvernay sourced oil (in
Northern area)
migrated into system as
well as self sourced
from algal laminates in
the Moat and in the
Arcs Evaporitic Shelf
Oil produced at
Enchant, Discovered
1987, Cum >46 mmbbls
oil (26 API), 70 BCF gas
to date
Nisku Moat
Wayne Swalwell Nisku Oil
Calgary
Verger Nisku Oil
Nisku Biostromal Shelf
Enchant Nisku Oil
Cum >46 mmbbls oil (26 API),
70 BCF gas since 1985
Lethbridge
Arcs Evaporitic Shelf
27
Family 5B: Nisku-sourced in S. Alberta
(Enchant Field (26.2°API))
14-25-014-16W4, Arcs Formation
08-03-015-16W4 1375.64m Arcs Formation
SFGC
SFGC
GCMS
GCMS
Stylolites
GCMS
GCMS
Stained fracture surfaces
28
Relevance of Oils Families to S Alberta
1.
2.
3.
4.
5.
6.
Elk Point (N. Alberta)
Winnipegosis
Norman Wells
Duvernay
Nisku
Mississippian
29
Maturity constraints: VRo
30
Maturity constraints: Tmax
31
Wabamun
System
•
•
•
•
•
•
•
•
Multiple reservoirs
Mid-Wabamun Crossfield
shelf margin shoals
Big Valley Member
dolomites
Stettler Dolomites
Bakken Siltstone
Lower Banff sand/siltstone
The Lower Banff, Exshaw, Big
Valley play at Ferguson
Discovered 2011, OOIP 375
mmbbl , Cum 2.4 mmbbls oil
(31 API) to date and Keho
have seen the most success
recently
Source: Exshaw
MidWabamun
Crossfield
Marine
Nevis Stettler ~60
mmbbl OOIP
Crossfield Sour Gas,
some oil
Mid to Upper Wabamun
“Stettler” evaporitic
platform
Enchant Stettler
Keho Penny Kipp Big Valley
Banff Sand Trend
Blood Del Bonita Bakken
Ferguson Lower Banff Sand:
~375 mmbbls OOIP
32
Structural Fabric
Marian J. Warren, Jenner GeoConsulting, 2000
33
Compressional and Extensional faults
South Alta. (Lemieux, CSPG Bull. 1999)
34
BFS Residual and Fault Trends
35
Gravity/Magnetic Data Maps, EUB/AGS Special Report 72, Lyatsky, Pana, Grobe
Vulcan Low
Montania/Medicine Hat Block
36
Major Basement Features and
Lineaments
Zaitlin, Warren, Potocki, Rosenthal and Boyd, CSPG Bull. 2002
Composite basement elements superimposed on BQ units
37
Magnetic Data Maps, EUB/AGS Special Report 72, Lyatsky, Pana, Grobe
Sun Angle 45 degree, direction
38
Magnetic Data Maps, EUB/AGS Special Report 72, Lyatsky, Pana, Grobe
39
Sweet Grass Hills, intrusives and dyke swarms, that
should have cooked the rock locally
40
Implications
 Source rocks and
reservoirs present
in many Devonian
formations
 Facies changes
create
stratigraphic traps
 Structural fabric
creates structural
traps
Dawson Bay
41
Elk Point System
•
•
•
•
•
Nearshore clastics and
carbonaceous shales,
restricted carbonate
platform capped with
evaporites
One oil pool at Rich,
Discovered 1986, OOIP 1.6
mmbbl, Cum 235 mbbls oil
(23 API) to date
Scattered oil shows on test
Self-sourcing from basal
algal laminites
Poor well control: 1 well
per 3 townships
Duvernay Well
Cambrian Well
GCSW: 70%
methane, sour
Elk Point Clastics
and Carbonaceous
Shales
Prairie Evaporite
Winnipegosis Well
Rich Winnipegosis Oil Production, 23 API
Winnipegosis Subcrop
Winnipegosis Well
Ordovician Subcrop
Calgary
Elk Point Subcrop
Elk Point Water Disposal
Elk Point Subcrop
Lethbridge
Immature Dawson Bay Source
Cambrian Inert Gas
42
Beaverhill Lake
System
•
•
•
Duvernay Wells
Winnipegosis and Cambrian Wells
Caroline Swan Hills Gas
Carbonate ramp and reefs
building up off Western
Alberta Ridge prograded
over by a north dipping
carbonate ramp
Large gas condensate field
in Swan Hills at Caroline
Discovered 1986, OGIP 2.3
TCF, Cum 2 TCF to date
Moberley, Calmut
Ramp Edges
Gas and 41 API oil on DST
Prograding Souris River
Carbonate Ramp
System
Calgary
Slave Point Platform
Oil and gas shows in DST,
core, and cuttings along
Moberley and Calmut
ramp edges and in Slave
Point equivalent sediments
around Davidson Salt Basin
•
High Helium and high CO2
in wells close to Sweet
Grass Hills Intrusives
•
Poor well control in south:
1 well per 3 townships
High TOC BHL
Core
BHL Core
Oil shows
Oil Flecked
Mud in DST’s
Davidson Salt
Basin
Oil Flecked
Mud in DST’s
Lethbridge
Oil flecked mud,
C02, CH4, Helium
43
Leduc System
•
•
•
•
Leduc has oil/gas
production and oil and gas
shows, challenge is
trapping, there are internal
barriers to flow, traps will be
structural and diagenetic
Most recent Leduc
penetrations on the
platform have been for
water source or disposal,
there have been deep tests
at Enchant and Countess
Oil produced at Del Bonita
(39 API) from Lower Leduc
and Cooking Lake (1980-81)
Poor well control in south: 2
wells per township
Duv. Src. Rx.
Duv. Src. Rx.
Duv. Src. Rx.
Leduc Oil
Water Cut Oil
Oil in Core
Calgary
Fairholme Carbonate Complex (Evaporitic to South and East)
Countess Deep Test
Leduc Gas
Leduc Sweet Gas
South West
Platform Margin
and Perdrix
source rock ~120
km (restored).
Enchant Deep Test
Free Oil
Lethbridge
Del Bonita
Cum 1227 bbl
39.6 API oil
Sour wet gas, some CO2
44
Nisku Patch reefs and drape pools
Nisku
System
•
•
•
Prograding carbonate
shelves, evaporitic
lateral and top seals,
salt and faulting related
structural traps and
facies traps
Duvernay sourced oil (in
Northern area)
migrated into system as
well as self sourced
from algal laminates in
the Moat and in the
Arcs Evaporitic Shelf
Oil produced at
Enchant, Discovered
1987, Cum >46 mmbbls
oil (26 API), 70 BCF gas
to date
Nisku Moat
Wayne Swalwell Nisku Oil
Calgary
Verger Nisku Oil
Nisku Biostromal Shelf
Enchant Nisku Oil
Cum >46 mmbbls oil (26 API),
70 BCF gas since 1985
Lethbridge
Arcs Evaporitic Shelf
45
Wabamun
System
•
•
•
•
•
•
•
•
Multiple reservoirs
Mid-Wabamun Crossfield
shelf margin shoals
Big Valley Member
dolomites
Stettler Dolomites
Bakken Siltstone
Lower Banff sand/siltstone
The Lower Banff, Exshaw, Big
Valley play at Ferguson
Discovered 2011, OOIP 375
mmbbl , Cum 2.4 mmbbls oil
(31 API) to date and Keho
have seen the most success
recently
Source: Exshaw
MidWabamun
Crossfield
Marine
Nevis Stettler ~60
mmbbl OOIP
Crossfield Sour Gas,
some oil
Mid to Upper Wabamun
“Stettler” evaporitic
platform
Enchant Stettler
Keho Penny Kipp Big Valley
Banff Sand Trend
Blood Del Bonita Bakken
Ferguson Lower Banff Sand:
~375 mmbbls OOIP
46
Conclusion
 Excellent potential Devonian Source Rocks and
Seals, Existing Pools
 Most observed Devonian sources are highly anoxic
evaporitic carbonate systems
 Spatial extent of source rock difficult to constrain
 E-W maturity zones are not clearly defined
 Sparse Deep Drilling
 Conventional and unconventional reservoirs (low
permeability evaporitic dolomites)
 Significant structuring and faulting
 Good potential for significant undiscovered
unconventional resource present in Southern
Alberta
47
Acknowledgements
 PrairieSky Royalty Limited for permission
to present
 Encana for commissioning the original
research study
 GSC for permission to present