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Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008
Chapter K ofThe 2008 Circum-Arctic Resource Appraisal
Professional Paper 1824
U.S. Department of the InteriorU.S. Geological Survey
COVERFishing boat in the Ilulissat Icefjord, Disko Bay, West Greenland, about 250 kilometers north of the Arctic Circle. The fjord is notable for its prolific iceberg production; the fast-moving tidal glacier Sermeq Kujalleq (also called Jakobshavn Isbrae) is a major outlet of the Greenland ice sheet. Photo by Flemming G. Christiansen, Geological Survey of Denmark and Greenland.
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008
By Donald L. Gautier
Chapter K ofThe 2008 Circum-Arctic Resource Appraisal Edited by T.E. Moore and D.L. Gautier
Professional Paper 1824
U.S. Department of the InteriorU.S. Geological Survey
U.S. Department of the InteriorDAVID BERNHARDT, Acting Secretary
U.S. Geological SurveyJames F. Reilly II, Director
U.S. Geological Survey, Reston, Virginia: 2019
For more information on the USGS—the Federal source for science about the Earth, its natural and living resources, natural hazards, and the environment—visit https://www.usgs.gov or call 1–888–ASK–USGS.
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Suggested citation:Gautier, D.L., 2019, Geology and assessment of undiscovered oil and gas resources of the East Greenland Rift Basins Province, 2008, chap. K of Moore, T.E., and Gautier, D.L., eds., The 2008 Circum-Arctic Resource Appraisal: U.S. Geological Survey Professional Paper 1824, 20 p., https://doi.org/10.3133/pp1824K.
ISSN 2330-7102 (online)
iii
The 2008 Circum-Arctic Resource Appraisal
Chapter A. Introduction to the 2008 Circum-Arctic Resource Appraisal (CARA) Professional Paper By Donald L. Gautier and Thomas E. Moore
Chapter B. Methodology for Assessment of Undiscovered Oil and Gas Resources for the 2008 Circum-Arctic Resource Appraisal
By Ronald R. Charpentier
North America
Chapter C. Geology and Assessment of Undiscovered Oil and Gas Resources of the Chukchi Borderland Province, 2008
By Kenneth J. Bird and David W. Houseknecht
Chapter D. Geology and Undiscovered Oil and Gas Resources of the Hope Basin Province, 2008 By Kenneth J. Bird, David W. Houseknecht, and Janet K. Pitman
Chapter E. Geology and Assessment of Undiscovered Oil and Gas Resources of the Arctic Alaska Petroleum Province, 2008 By David W. Houseknecht, Kenneth J. Bird, and Christopher P. Garrity
Chapter F. Geology and Assessment of Undiscovered Oil and Gas Resources of the Central Alaska Province, 2008
By Kenneth J. Bird and Richard G. Stanley
Chapter G. Geology and Assessment of Undiscovered Oil and Gas Resources of the Northwest Canada Interior Basins Province, Arctic Canada, 2008
By Marilyn E. Tennyson and Janet K. Pitman
Chapter H. Geology and Assessment of Undiscovered Oil and Gas Resources of the Franklinian Shelf Province, Arctic Canada and North Greenland, 2008
By Marilyn E. Tennyson and Janet K. Pitman
Chapter I. Geology and Assessment of Undiscovered Oil and Gas Resources of the Sverdrup Basin Province, Arctic Canada, 2008
By Marilyn E. Tennyson and Janet K. Pitman
Greenland
Chapter J. Geology and Assessment of Undiscovered Oil and Gas Resources of the West Greenland- East Canada Province, 2008
By Christopher J. Schenk
Chapter K. Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008
By Donald L. Gautier
iv
North Atlantic Ocean
Chapter L. Geology and Assessment of Undiscovered Oil and Gas Resources of the Jan Mayen Microcontinent Province, 2008
By Thomas E. Moore and Janet K. Pitman
Eurasia
Chapter M. Geology and Assessment of Undiscovered Oil and Gas Resources of the Mezen’ Basin Province, 2008
By Timothy R. Klett and Janet K. Pitman
Chapter N. Geology and Assessment of Undiscovered Oil and Gas Resources of the Timan-Pechora Basin Province, Russia, 2008
By Christopher J. Schenk
Chapter O. Geology and Assessment of Undiscovered Oil and Gas Resources of the East Barents Basins Province and the Novaya Zemlya Basins and Admiralty Arch Province, 2008
By Timothy R. Klett
Chapter P. Geology and Assessment of Undiscovered Oil and Gas Resources of the North Kara Basins and Platforms Province, 2008
By Timothy R. Klett and Janet K. Pitman
Chapter Q. Geology and Assessment of Undiscovered Oil and Gas Resources of the Northern West Siberian Mesozoic Composite Total Petroleum System of the West Siberian Basin Province, Russia, 2008
By Christopher J. Schenk
Chapter R. Geology and Assessment of Undiscovered Oil and Gas Resources of the Yenisey-Khatanga Basin Province, 2008
By Timothy R. Klett and Janet K. Pitman
Chapter S. Geology and Assessment of Undiscovered Oil and Gas Resources of the Northwest Laptev Sea Shelf Province, 2008
By Timothy R. Klett and Janet K. Pitman
Chapter T. Geology and Assessment of Undiscovered Oil and Gas Resources of the Lena-Anabar Basin Province, 2008
By Timothy R. Klett and Janet K. Pitman
Chapter U. Geology and Assessment of Undiscovered Oil and Gas Resources of the Tunguska Basin Province, 2008
By Craig J. Wandrey and Timothy R. Klett
Chapter V. Geology and Assessment of Undiscovered Oil and Gas Resources of the Lena-Vilyui Basin Province, 2008
By Timothy R. Klett and Janet K. Pitman
v
Chapter W. Geology and Assessment of Undiscovered Oil and Gas Resources of the Laptev Sea Shelf Province, 2008
By Timothy R. Klett and Janet K. Pitman
Chapter X. Geology and Assessment of Undiscovered Oil and Gas Resources of the Zyryanka Basin Province, 2008
By Timothy R. Klett and Janet K. Pitman
Chapter Y. Geology and Assessment of Undiscovered Oil and Gas Resources of the East Siberian Sea Basin Province, 2008
By Kenneth J. Bird, David W. Houseknecht, and Janet K. Pitman
Chapter Z. Geology and Assessment of Undiscovered Oil and Gas Resources of the Vilkitskii Basin Province, 2008
By Kenneth J. Bird, David W. Houseknecht, and Janet K. Pitman
Chapter AA. Geology and Assessment of Undiscovered Oil and Gas Resources of the Long Strait Basin Province, 2008
By Kenneth J. Bird, David W. Houseknecht, and Janet K. Pitman
Chapter BB. Geology and Assessment of Undiscovered Oil and Gas Resources of the Amerasia Basin Petroleum Province, 2008 By David W. Houseknecht, Kenneth J. Bird, and Christopher P. Garrity
Arctic Ocean
Chapter CC. Geology and Assessment of Undiscovered Oil and Gas Resources of the Lomonosov- Makarov Province, 2008
By Thomas E. Moore, Kenneth J. Bird, and Janet K. Pitman
Chapter DD. Geology and Assessment of Undiscovered Oil and Gas Resources of the Eurasia Basin Province, 2008
By Thomas E. Moore and Janet K. Pitman
vi
1. Input data for the North Danmarkshavn Salt Basin Assessment Unit2. Input data for the South Danmarkshavn Basin Assessment Unit3. Input data for the Northeast Greenland Volcanic Province Assessment Unit4. Input data for the Thetis Basin Assessment Unit5. Input data for the Liverpool Land Basin Assessment Unit6. Input data for the Jameson Land Basin Assessment Unit7. Input data for the Jameson Land Basin Subvolcanic Extension Assessment Unit
Appendixes[Available for download at https://doi.org/10.3133/pp1824K ]
ContentsAbstract ...........................................................................................................................................................1Introduction and Province Description ......................................................................................................1Petroleum System Elements ........................................................................................................................7Burial History Modeling ................................................................................................................................7Summary of Province Assessment Results ...............................................................................................7
North Danmarkshavn Salt Basin ......................................................................................................12Analogs Used in Assessment ..................................................................................................12
South Danmarkshavn Basin ..............................................................................................................15Analogs Used in Assessment ..................................................................................................15
Northeast Greenland Volcanic Province ........................................................................................16Thetis Basin ........................................................................................................................................16
Analogs Used in Assessment ..................................................................................................16Liverpool Land Basin ..........................................................................................................................17
Analogs Used in Assessment ..................................................................................................17Results ...........................................................................................................................................................18References Cited..........................................................................................................................................18Appendixes ...................................................................................................................................................20
vii
Figures
1. Map showing location of East Greenland Rift Basins Province and its constituent assess-ment units. ......................................................................................................................................3
2. Generalized geologic map of East Greenland Rift Basins Province and surroundingregions ............................................................................................................................................4
3. Time-stratigraphic chart showing generalized lithology for strata of the East Greenland RiftBasins Province ............................................................................................................................5
4. Two simplified cross sections through the northeast Greenland shelf showing the relativethickness of rocks of various ages in basins discussed in the text .....................................6
5. Onshore outcrop facies map and depth to top of postulated Upper Jurassic source rocksoffshore in the Danmarkshavn and Thetis Basins ...................................................................8
6. Burial history model and plots showing depths and vitrinite reflectance values interpretedfor strata in a depocenter in the southern Danmarkshavn Basin ........................................9
7. Lithostratigraphic column and total petroleum system events chart showing petroleum sys-tem elements for the East Greenland Rift Basins ..................................................................11
Tables
1. Input data for burial history model of Danmarkshavn Basin ........................................................102. Estimated volumes of undiscovered petroleum resources in the East Greenland Rift Basins
Province .......................................................................................................................................13
Chapter K
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008
By Donald L. Gautier
The 2008 Circum-Arctic Resource AppraisalEdited by T.E. Moore and D.L. Gautier U.S. Geological Survey Professional Paper 1824
Abstract In 2007 the U.S. Geological Survey (USGS) completed
an assessment of undiscovered, technically recoverable oil and gas resources in the East Greenland Rift Basins Province of Northeast Greenland. The province was selected as the proto-type for the U.S. Geological Survey Circum-Arctic Resource Appraisal (CARA). In collaboration with the Geological Survey of Denmark and Greenland (GEUS), the province was subdivided into nine geologically distinctive areas. Seven of these were defined as Assessment Units (AUs), of which five were quantitatively assessed. These are: North Danmarkshavn Salt Basin, South Danmarkshavn Basin, Thetis Basin, North-east Greenland Volcanic Province, and Liverpool Land Basin. Jameson Land Basin and the Jameson Land Basin Subvolcanic Extension were defined as AUs but were not quantitatively assessed.
Onshore studies by GEUS and other organizations suggest that at least four stratigraphic intervals may contain potential source rocks for petroleum. The geological history of related areas in western Norway and burial history modeling suggest that Upper Jurassic strata are most likely to contain petroleum source rocks. A wide variety of possible trapping mechanisms are expected within the province. Potential traps in the North Danmarkshavn Salt Basin AU are dominated by structures formed through salt tectonics; those in the South Danmarkshavn Basin and the Northeast Greenland Volcanic Province are characterized by extensional structures and by stratigraphic traps in submarine fan complexes. Prospective inversion structures of Tertiary age are present along the west-ern margin of South Danmarkshavn Basin AU, and the large horst block structures that separate the Danmarkshavn and Thetis Basins may provide numerous opportunities for traps in fault blocks and along various facies-related permeability bar-riers. Possible reservoirs include shallow marine to nonmarine sandstones of Middle Jurassic age, sandstones in Upper Juras-sic synrift deposits, Cretaceous sandstones in submarine fan complexes, sandstones in Paleogene progradational sequences, and in Upper Carboniferous to Lower Permian warm-water
carbonate sequences, especially in northern Danmarkshavn Basin. Marine shales are expected to provide the main sealing lithologies in most AUs.
Most of the undiscovered oil, gas, and natural gas liquids are likely to be in the offshore areas of the province and are inferred to belong to an Upper Jurassic Composite Total Petro-leum System. The USGS estimated that the East Greenland Rift Basins Province contains approximately (mean) 31,400 million barrels oil equivalent (MMBOE) of oil, natural gas, and natural gas liquids. Of the five assessed AUs, North Dan-markshavn Salt Basin and the South Danmarkshavn Basin are estimated to contain most of the undiscovered petroleum.
Introduction and Province DescriptionGeological features of northeast Greenland suggest the
possibility of large petroleum potential, as well as high uncer-tainty and risk. The area was the prototype for development of methodology used in the U.S. Geological Survey (USGS) Circum-Arctic Resource Appraisal (CARA), and the Northeast Greenland Rift Basins Province (fig. 1) was the first province to be evaluated. The new study was deemed necessary because of information made available through collaboration with the Geological Survey of Denmark and Greenland (GEUS), which significantly changed the geological understanding of the area. In collaboration with GEUS the province was subdivided into nine geologically distinct areas. From those, seven assessment units (AUs) were formally defined, five of which were quan-titatively assessed. The CARA study superseded a previous USGS assessment of northeast Greenland completed in 2000 (Ahlbrandt and others 2005), from which it differs in several important respects: oil estimates were reduced and natural gas estimates were increased to reflect revised understanding of offshore geology. Despite the reduced oil estimates, the CARA indicates that northeast Greenland could be an important future petroleum province.
The East Greenland Rift Basins Province extends for more than 1,200 kilometers (km) from south of the Blosseville
2 The 2008 Circum-Arctic Resource Appraisal
Kyst Basin near 66° N to Kronprins Christian Land near 82º N (fig. 1), an area of approximately 500,000 km2, most of which lies beneath less than 500 meters (m) of water. The northern and northeastern boundary of the province is set along the approximate southern trace of the Greenland Fracture Zone/Trolle Land Fault Zone, thus excluding the Wandel Sea Basin (fig. 2). The province is as wide as 600 km; its western boundary follows the approximate limit of sedimentary rocks onshore and its eastern boundary tracks the continent-ocean transition. The province encompasses the sedimentary basins of northeastern Greenland, including Jameson Land Basin (Christiansen and others, 1992; Mathiesen and others, 1995; Stemmerik and others, 1993), and the less well known off-shore basins of the northeast Greenland shelf: Danmarkshavn Basin, Thetis Basin (Hamann and others, 2005), Liverpool Land Basin (Larsen, 1990) and the Blosseville Kyst Basin (Larsen, 1985) (fig. 2). The Tertiary volcanic rocks found off-shore between 67° and 75° N are included in the province and are presumed to cover thick sedimentary successions.
The Caledonian deformational belt (fig. 2), which formed as a consequence of the closing of the proto-Atlantic Ocean and the collision of the Laurentia and Baltica continents, is known to include more than 4,000 m of intensely folded and faulted sedimentary rocks of Cambrian to Devonian age. For the purposes of this study, deformed Caledonian rocks are assumed to be economic basement; the oldest strata considered in this assessment are Middle to Upper Devonian continental deposits (fig. 3), which accumulated during the crustal relax-ation and extensional faulting that followed the Caledonian orogeny. Since the Caledonian collision, northeastern Green-land has been the site of numerous episodes of multi-phase lithospheric extension, the most prominent of which were in the late Permian to Triassic, Late Jurassic to Early Cretaceous, and in mid-Cretaceous time (Surlyk, 1990; Blystad and others, 1995; Doré and others, 1999; Brekke, 2000; Surlyk, 2003), culminating in crustal separation during the Paleocene. The outer (easternmost) part of the shelf has been a passive margin since the early Eocene (Tsikalas and others, 2005).
The petroleum potential of northeast Greenland has long been postulated (Ulmishek, 1984; Haimilia and others, 1990) on the basis of (1) the plate tectonic model of the opening of the North Atlantic Ocean Basin (Kay, 1969; Talwani and Eldholm, 1977; Hinz and others, 1987); (2) investigations of outcrops onshore (Stemmerik and others, 1993; and (3) the geologic similarity of northeastern Greenland and the petro-liferous basins of northwestern Europe (Hinz and Schlüter 1980, Larsen 1984). As of 2011, with the exception of a few shallow research cores, the sedimentary basins of the province remain undrilled owing largely to their remote location and the possibility of sea ice any month of the year. The northeast Greenland shelf is of particular interest; potential field data have been used to identify major northeast-trending structural features (Larsen 1984, 1990) and, more recently, these features have been examined in greater detail following analysis of the proprietary KANUMAS seismic data (Hamann and oth-ers, 2005). South of Shannon Island, thick Tertiary volcanic
rocks of the East Greenland Volcanic Province largely cover the shelf. The Koldewey Platform, on the westernmost part of the shelf, is an area of relatively shallow (2 to 5 km) Caledo-nian rocks, overlain by a thin sedimentary cover thought to include upper Carboniferous to Permian carbonate rocks and lower Carboniferous siliciclastic sequences (fig. 4). In the eastern part of the Koldewey Platform, the Paleozoic section is overlain by various thicknesses of discontinuous and incom-pletely preserved Mesozoic strata. In some places, such as on Store Koldewey, Mesozoic rocks directly overlie Caledonian basement.
North-trending en echelon faults separate the Koldewey Platform from the Danmarkshavn Basin, which is a large, deep, northeast-trending sedimentary basin that is bounded by the Koldewey Platform on the west and by Danmarkshavn Ridge on the east (fig. 4). South of Store Koldewey the basin is limited by the Shannon High, a basement horst that prob-ably extends southward beneath the volcanic field. The basin is at least 400 km long in a northeast-southwest dimension, 50 km wide in the south, and 100 km wide at about 78° N. The central axis and principal depocenter of the basin is thought to contain a largely conformable section, more than 13 km thick, of (probable) Devonian to Holocene age sedimentary rocks. Numerous unconformities increase in significance and the sed-imentary strata thin and unconformities increase in magnitude northward and westward of the central Danmarkshavn Basin.
Interpretation of the KANUMAS seismic data and unpub-lished research seismic data acquired by the Alfred Wegener Institute has led to the identification of a major salt province in the northern part of Danmarkshavn Basin (Hamann and others, 2005; W. Jokat, written commun., 2007). The salt is inferred to be of late Carboniferous or possibly earliest Permian age (fig. 3) based upon regional paleogeographic reconstructions (Stemmerik, 2000). The evaporite sequence is, therefore, a likely equivalent to the lower part of the carbonate succession found onshore in North Greenland (Stemmerik, 2000), closely related to similar salt accumulations in Tromsø and Nordkapp Basins in the Barents Sea, and related to the Sverdrup Basin of northern Canada (Larssen and others, 2002). The salt is believed to have accumulated in a rapidly subsiding sag basin along the rift axis between Norway and Greenland (Gudlaugs-son and others, 1998).
Danmarkshavn Ridge is a northeast-trending complex of westward dipping fault blocks, which separates Danmark-shavn Basin from Thetis Basin to the east (fig. 4). Known from potential field data and from the KANUMAS seismic records, Danmarkshavn Ridge is 10 to 60 km wide and extends for more than 80 km from a well-defined basement high beneath Tertiary volcanic rocks in the south to a gentle platform at 78° N. The principal controlling fault of Danmarkshavn Ridge, which bounds its eastern margin, has a heave of more than 10 km and a throw of at least 7 km. Hamann and others (2005) estimated that 2 to 3 km of upper Paleozoic and Mesozoic rocks were eroded from the top of the ridge prior to deposi-tion of a Tertiary sedimentary succession that may be as old as Paleocene.
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008 3
NorthDanmarkshavnSalt Basin AU
Thetis Basin AU
Unnamed AU,not assessed
SouthDanmarkshavn
Basin AU
Northeast GreenlandVolcanic Province AU
JamesonLand Basin AU
LiverpoolLand Ridge AU,not assessed
Jameson Land BasinSubvolcanicExtension AU
LiverpoolLand Basin AU
G R E E N L A N D
WANDEL SEA
GREENLAND SEA
BAFFIN
BAY
I C E L A N D
DENMARK
STRAIT
KronprinsChristian Land
StoreKoldewey
Shannon Island
Kong Oscar Fjord
GREENLAND
Maparea
Assessment Unit (AU) boundary
Province boundaryEXPLANATION
0°10° W20° W30° W40° W50° W60° W70° W 80° N
75° N
70° N
65° N
10° E
0 300 KILOMETERS100 200
0 300 MILES100 200
Figure 1.
Stereographic North Pole projection, NAD 83
Figure 1. Map showing location of East Greenland Rift Basins Province and its constituent assessment units.
4 The 2008 Circum-Arctic Resource Appraisal
Lena Trough
Mohns Ridge
Jan Mayen fracture zone
ICELAND
Kolbe
insey
Ridg
e
BlossevilleKyst Basin
Liver
pool
L
and
B
asin
D
eform
ation fro
nt of C
aledonian fold belt
Trolle Land Fault
Wandel Sea Basin
James
on
La
nd
Bas
in
LiverpoolLandRidge
KangerlussuaqBasin
Danm
arks
havn
Danmar
ksha
vn
Ridge
Thetis
Basin
GR
EE
NL
AN
D
Greenland
fracture zone
Kolde
wey
Plat
form
Iceland-FaroeLarge Igneous Province
GREENLAND
S
EA
Jan Mayenmircocontinent
Mid-ocean ridge basaltsat the seabed
Basin
Cross sectionof figure 4A
Cross sectionof figure 4B
BoreasBasin
Northeast
Greenland
Volcanic Province
East Greenland
Volcanic Province
GREENLAND
Maparea
Sedimentary successionStable shelf and platform—Commonly contain carbonate as well as clastic depositsShelves with rift and thermo-isostatic (sag) basins—Typically consist of both siliciclastic
and carbonate deposits and in places evaporitesExtensional basin on continental crust along the margin of an adjoining ocean
basin—Contains mainly siliciclastic depositsPrograded sedimentary succession across predominately rifted passive margin of an
existing ocean basin—Contains siliciclastic depositsOcean basin—Eupelagic, hemipelagic, or turbidite deposits overlying mid-ocean
ridge basalt (MORB) or ocean-continent transitional crustIntercalated volcanic rocks near the surface of sedimentary successionDepositional boundary of sedimentary succession—Dashed
where approximate Axis of structural trough—Dashed where approximateAxis of structural ridge—Dashed where approximateActive sea-floor spreading axis—Dashed
where approximateContinent-ocean boundary—Dashed
where approximateFault, undifferentiated—Dashed
where approximate, dotted where covered
Boundary of nonprospectiveterranes—Dashed where approximate
Province boundaryAssessment unit boudaryModern shoreline
EXPLANATION
80° N
65° N
30° W
40° W
50° W
60° W50° W
40° W
30° W
20° W
10°
W
0°
70° N
75° N
Base from Esri, used herein under licenseStereographic North Pole projection
Mapping modified from Grantz and others, 20100 100 200 MILES
0 100 200 KILOMETERS
Figure 2. Generalized geologic map of East Greenland Rift Basins Province and surrounding regions (modified from Grantz and others, 2010).
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008 5
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Figu
re 3
.
NOR
THW
EST
SOUT
HEAS
T
50 100 150 200 250 300 350 400DevonianCarboniferousPermianTriassicJurassicCretaceousTertiary
Ma
T IV
T III
T II
T I
K II
K I
J III
J II
J I
PT II
PT I
CP II
CP I
DC II
DC I
Seis
mic
seq
uenc
es
Kold
ewey
Pla
tform
Neo
gene
Pale
ogen
e
Late
Late
Late
Late
Late
Late
Mid
dle
Mid
dle
Mid
dle
Early
Early
Early
Early
Early
Early
Danm
arks
havn
Bas
inDa
nmar
ksha
vn R
idge
Thet
is R
idge
Shel
f edg
eM
argi
nal h
igh
COB
Ocea
nic
crus
t
Youn
ger s
ectio
n ba
sed
mos
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sei
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seq
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ratig
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Olde
r sec
tion
base
d m
ostly
on o
nsho
re g
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gy
Inve
rsio
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ruct
ure
Terti
ary
uplif
t
Salt
mov
emen
t
Tim
esc
ale
Cont
inen
tal d
epos
its
Shal
low
mar
ine
depo
sits
Mar
ine
depo
sits
Carb
onat
es
Evap
orite
s
Volc
anic
rock
s
EXPL
AN
ATIO
N
Major fault movement
Stra
tigra
phic
inte
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that
con
tain
s co
ncen
trate
d or
gani
c m
atte
r
? S
tratig
raph
y un
certa
in
Figu
re 3
. Ti
me-
stra
tigra
phic
cha
rt sh
owin
g ge
nera
lized
lith
olog
y fo
r stra
ta o
f the
Eas
t Gre
enla
nd R
ift B
asin
s Pr
ovin
ce. T
he M
iddl
e an
d Up
per D
evon
ian
rock
s ar
e th
e ol
dest
con
side
red
in th
e as
sess
men
t of
petro
leum
reso
urce
s in
the
prov
ince
. COB
, con
tinen
t-oce
an b
ound
ary.
M
odifi
ed fr
om H
aman
n an
d ot
hers
(200
5).
6 The 2008 Circum-Arctic Resource Appraisal
0WEST EAST
A
BNORTHWEST SOUTHEAST
Figure 4.
KoldeweyPlatform
DanmarkshavnRidge
LiverpoolLand
Danmarkshavn Basin
Jameson Land BasinLiverpool Land Basin
(Inner) (Outer)
Thetis Basin
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
EXPLANATION
Pliocene-Pleistocene
Neogene
Paleogene
Cretaceous
Upper Permian-Jurassic
Devonian-middle Permian
Caledonian basement/? lower Paleozoic
Oceanic crust
Tertiary intrusives
10 20 30 40 500
10 20 30 40 50
MILES
KILOMETERS0
10 20 30 40 500
10 20 30 40 50
MILES
KILOMETERS0
DC I - CP IIPT I
PT II
K II
K IJI- JIII
T I T IIT III
T IV
K I?J III
Two-
way
trav
el ti
me,
in m
illis
econ
ds
Two-
way
trav
el ti
me,
in m
illis
econ
ds
Figure 4. Two simplified cross sections through the northeast Greenland shelf showing the relative thickness of rocks of various ages in basins discussed in the text. Locations of cross sections are shown in figure 2. Stratigraphic intervals (TI, KII, and so on) are identified in the stratigraphic chart in figure 3 and in table 1. Modified from Hamann and others (2005).
Immediately east of Danmarkshavn Ridge, the Thetis Basin (fig. 4) comprises a thick succession of Cretaceous and Tertiary strata that accumulated as rift-sag basin and passive-margin deposits, respectively. Although older sedimentary rocks are probably present, thick Cretaceous age strata fill the basin to the acoustic basement. Thetis Basin is geologi-cally similar in structure and stratigraphic relationships to the Vøring and Møre Basins on the Norwegian continental margin (Scheck-Wenderoth and others, 2007).
South and east of Thetis Basin, the continental shelf is marked by an area of high relief named the “Marginal High” by Hamann and others (2005). The Marginal High is believed to consist of Tertiary volcanic rocks extruded during the initial opening of the Atlantic Basin at the end of the Paleocene (Hinz and others, 1993). South of about 75°30’ N, extrusive rocks of probable Tertiary age inferred from aeromagnetic and seismic data (Larsen, 1990) are interpreted to overlie thick pre-Tertiary sedimentary sequences similar to those north of the volcanic field. Offshore and south of the volcanic field,
thick sedimentary rocks have been recognized in seismic data to the east of Liverpool Land. The sedimentary section of Liverpool Land Basin is thickest where it overlies continental crust, thinning to the east across the continent-ocean bound-ary; the upper 6 km of strata in the Liverpool Land Basin form a prograding sedimentary wedge of Paleogene and Neogene age. South of Liverpool Land Basin, more than 4 km of post-middle Eocene sedimentary rocks overlie Paleogene volcanic rocks, which, in turn, probably rest on Mesozoic and Paleo-cene sedimentary strata.
For purposes of assessment, the East Greenland Rift Basins Province was subdivided into nine geologically distinctive areas, seven of which were designated as assess-ment units, of which five were quantitatively assessed. The seven designated assessment units are: (1) Northern Dan-markshavn Salt Basin, (2) Southern Danmarkshavn Basin, (3) Thetis Basin, (4) Northeast Greenland Volcanic Province, (5) Liverpool Land Basin, (6) Jameson Land Basin, and (7) the Jameson Land Basin Subvolcanic Extension (figs. 1, 2).
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008 7
Petroleum System ElementsOnshore studies suggest that at least four stratigraphic
intervals may contain source rocks for liquid petroleum (Christiansen and others, 1992). In consideration of the closely related geological history of western Norway, of outcrops of Jurassic strata in eastern Greenland (Surlyk, 2003), and of the origin and distribution of world petroleum (Ahlbrandt and oth-ers, 2005), Upper Jurassic strata in northeastern Greenland are inferred to contain particularly promising source rocks (fig. 5); burial history modeling of postulated Jurassic source rocks in northeast Greenland Shelf is further discussed below.
Possible trapping mechanisms are expected to vary widely across the province. Potential traps in the North Dan-markshavn Salt Basin AU are dominated by structures formed through salt tectonics; those in the South Danmarkshavn Basin and the Northeast Greenland Volcanic Province AU are probably characterized by extensional structures and by stratigraphic traps in submarine fan complexes (Surlyk, 1978). Potentially prospective inversion structures of Tertiary age are present along the western margin of South Danmarkshavn Basin AU; the large horst blocks of the Danmarkshavn Ridge, which separates the Danmarkshavn and Thetis Basins, may provide numerous opportunities for traps, as does the uncon-formity between Cretaceous and Paleogene strata, and various facies-related permeability barriers. For the purposes of this assessment, Danmarkshavn Ridge, west of its major bounding fault, is included in the South Danmarkshavn Basin AU.
Possible reservoirs are considered most likely within shallow marine to nonmarine sandstones of Middle Jurassic age, in Upper Jurassic syn-rift deposits, in Cretaceous sand-stones of the submarine fan complexes, within progradational sequences of Paleogene age, and in upper Carboniferous to lower Permian warm-water carbonate strata, especially in the northern Danmarkshavn Basin. Marine shales are expected to provide the main sealing lithologies in most AUs.
Burial History ModelingThe burial history of potential source rocks in northeast
Greenland was analyzed using the commercial burial history modeling software Petromod, version 10, by Integrated Explo-ration Systems (now owned by Schlumberger Limited). One-dimensional models were built for various selected localities in the Northeast Greenland Rift Basins Province. One of these localities, at the intersection of two KANUMAS seismic lines in the south Danmarkshavn Basin, was selected to model the burial history of the province (fig. 6); input data for the burial history model are given in table 1.
In collaboration with GEUS scientists, approximate time-stratigraphic boundaries were identified on the KANUMAS seismic lines and time-depth relations were estimated using time-depth models from various parts of the Arctic including the Beaufort Sea, the Barents Sea, and the Norwegian Sea.
A subsurface geologic model was developed (fig. 7), which incorporated known stratigraphic relations from onshore outcrops in Greenland and from western and northern Norway, which is the conjugate transatlantic margin of northeastern Greenland. Heat flow history was reconstructed from the interpreted tectonic/geological history of the southern Dan-markshavn Basin, and the heat flow model was then compared to and calibrated with interpreted thermal histories from the Norwegian Sea provided by the Norwegian Petroleum Direc-torate (NPD). Additional inputs for the burial history model include interpretations of episodes of erosion, water depth, and sediment/water interface temperature, and kerogen reaction rates (kinetics).
The burial history model was used to estimate the range of possible thermal maturity to be expected in stratigraphic intervals that have potential source rocks. Particular atten-tion was paid to the interpreted burial and thermal history of postulated Jurassic strata. A map of present day depths to the top of the postulated Jurassic strata was developed in collabo-ration with GEUS scientists, who have access to the propri-etary KANUMAS seismic data, and using publicly available potential field data (fig. 5). When combined with the inferred burial history, the map provides an important tool for inter-preting thermal maturity of postulated source rocks at various locations on the northeast Greenland Shelf.
From the burial history model (fig. 6), postulated source rocks of Late Jurassic age are interpreted to have been buried to the oil window over wide areas of the northeast Greenland shelf, and to have been buried to a time-temperature regime of supermaturity with respect to oil generation at any local-ity deeper than approximately 5 km. Maturation may have occurred as early as the Late Cretaceous in the depocenters of the South Danmarkshavn Basin. In North Danmarkshavn Salt Basin and in areas of South Danmarkshavn Basin that have thinner post-Jurassic sediment, oil maturation probably did not occur until Paleocene time or later.
Summary of Province Assessment Results
Five AUs were included in the assessment of the petro-leum potential in the East Greenland Rift Basins Province: North Danmarkshavn Salt Basin, South Danmarkshavn Basin, Northeast Greenland Volcanic Province, Thetis Basin, and Liverpool Land Basin. Assessment Unit boundaries are shown in figures 1 and 2. The Jameson Land Basin and the Jameson Land Basin Subvolcanic Extension AUs were considered to have less than a 10 percent chance of containing a technically recoverable hydrocarbon accumulation larger than the mini-mum size of 50 million barrels of oil-equivalant oil, gas, and natural gas liquids (50 MMBOE). The high risk was assigned because onshore studies of Jameson Land geology and exploratory drilling in the basin decades ago suggest that pos-sible source rock intervals are relatively poor in concentrated
8 The 2008 Circum-Arctic Resource AppraisalA
B
-1,0
00 to
-2,0
00
Dep
th to
Upp
er J
uras
sic
sour
ce ro
cks,
in m
eter
s
-2,0
00 to
-5,0
00
> -5
,000
-5,00
0
-5,0
00
-4,0
00
-3,0
00
-3,0
00 -1,000
-4,0
00
-8,000
-5,0
00
-5000
-8,0
00
-5,0
00 -7,000
-1,00
0-2,00
0
-5,000
-5,0
00
-6,00
0
-5,000
-4,000
-4,000
-7,00
0
-5,00
0
-7,000
-3,000
-3,000
-2,000
-6,000
-6,0
00
-8,00
0
-6,000-6,0
00
-8,0
00
-7,000
-6,0
00
-7,000
-6,00
0
-3,000
-7,00
0
-3,0
00
-4,000
-5,000
-4,0
00
-2,0
00
-5,0
00
-700
0
-6,000
-2,000
-5,0
00
-6,0
00
-1,000
-5,000
-2,000
-3,0
00
-6,000
-3,000
-8,000
-6,0
00-8,
000
-5,0
00
-300
0
-7,000
-4,0
00-7
,000
-800
0-4
000
-400
0
-600
0
-7000
-600
0
-300
0-2
000
-5000
-5,000-7,000-6,000-8,
000
-4,000
-6,0
00
-4,000
-3,00
0
-5,00
0-5
,000
-3,0
00-4,
000
-4,0
00
-4000
-2,0
00-3
,000
-5,000-4,000
-3000
-4,0
00
-3,000
-3,000
-3,0
00 -3,00
0
-2,000-2,00
0 -2,000
-3,000
-4,000
-5,00
0
-5,0
00-6
,000
-6,0
00
-2,0
00
-5,0
00
-6,00
0
-2,0
00
Danmarkshavn
Ridge
Stor
e Ko
ldew
ey
Dan
ebor
g
Danm
arks
havn
10°
75°
20°
80°
5010
00
5010
0
MIL
ES
KILO
MET
ERS
0
Out
crop
faci
es a
nd d
epth
to to
p of
pos
tula
ted
Upp
er J
uras
sic
sour
ce ro
ck
Figu
re 5
.
Mar
ine
sand
ston
e/m
udst
one
hete
rolit
h
Offs
hore
mar
ine
mud
ston
e
Deep
-wat
er m
arin
esa
ndst
one
bodi
es
Clav
erin
g
Geog
raph
ical
Soci
ety
Trai
l
Floo
ding
sur
face
Gerlait MemberCardlocerarklaft Member
Kuhn
Hoch
este
tter
Forla
nd
Wol
last
onFo
rland
Hold
with
Hope
Stor
eKo
ldew
ey
Berriberg Formation
510
0
510
MIL
ES
KILO
MET
ERS
0
NEX
PLA
NAT
ION
EXPL
AN
ATIO
N
Figu
re 5
. On
shor
e ou
tcro
p fa
cies
map
(A) a
nd d
epth
to to
p of
pos
tula
ted
Uppe
r Jur
assi
c so
urce
rock
s of
fsho
re in
the
Danm
arks
havn
and
The
tis B
asin
s (B
). Pr
epar
ed in
coo
pera
tion
with
th
e Ge
olog
ical
Sur
vey
of D
enm
ark
and
Gree
nlan
d (G
EUS)
. Loc
atio
n of
th
e bu
rial h
isto
ry m
odel
illu
stra
ted
in fi
gure
6 is
sho
wn
by a
red
dot.
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008 9
TII
T I
K II
K 1
J II
J I
PT II
PT I
CP II
CP 1
DC 1
Caledonian
Temperature, in degrees Celsius
Buria
l dep
th, i
n m
eter
s
0
2,500
5,000
7,500
10,000
12,500
15,000
17,500
0.3 100 200 300 500400 600 700 800 907
Heat flow100
80
60
40
Mill
iwat
ts p
ersq
uare
met
erDe
gree
s Ce
lsiu
s
41
20
0
-17
Sediment-waterinterface temperature
-200
0
450
Met
ers
Paleowater depthSilurian Devonian Carboniferous Permian Triassic Jurassic Cretaceous Paleogene
Neogene
CenozoicMesozoicPaleozoicOrdovician
Boundary parametersAge, in millions of years ago
460 400 300 200 100 0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
9,000
10,000
11,000
12,000
13,000
14,000
15,000
16,000
17,485
0
Buria
l dep
th, i
n m
eter
s
TII
T I
K II
K 1
J II
J I
PT II
PT I
CP II
DC 1
Caledonian
0.00 1.00 2.00 3.00 4.00 4.75
Vitrinite reflectance, in percent
TII
T I
K II
K 1
J II
J I
PT II
PT I
CP II
CP 1
DC 1
Caledonian
Silurian
Devonian Carboniferous Permian Triassic Jurassic Cretaceous Paleogene NeogeneCenozoicMesozoicPaleozoic
415 400 300 200 100 0
Age, in millions of years ago
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
9,000
10,000
11,000
12,000
13,000
14,000
15,000
16,000
17,555
0
Buria
l dep
th, i
n m
eter
s
EXPLANATIONImmature (0.6% Ro)Oil zone (0.6–1.25% Ro)Gas zone (1.25–2.0% Ro)Overmature (2.0% Ro)Source rock interval
East Greenland Rift Basins Province 5200Burial History Model
Figure 6.
Figure 6. Burial history model and plots showing depths and vitrinite reflectance values (in percent Ro) interpreted for strata in a depocenter in the southern Danmarkshavn Basin. Location of the modeled site is shown on figure 5. Input data for the model are summarized in table 1.
10 The 2008 Circum-Arctic Resource Appraisal
Stra
tigra
phic
in
terv
alTo
p de
pth,
in
met
ers
Bot
tom
de
pth,
in
met
ers
Thic
k-ne
ss, i
n m
eter
s
Stra
ta
erod
ed,
in m
eter
s
Beg
in
depo
sitio
n,
Ma
End
de
posi
tion,
M
a
Beg
in
eros
ion,
M
a
End
eros
ion,
M
a
Prin
cipa
l lit
holo
gies
Petr
oleu
m
syst
em
elem
ent
Tota
l or
gani
c ca
rbon
, in
wei
ght
perc
ent
Petr
omod
ki
netic
mod
el
Hyd
roge
n in
dex,
in
mg
HC/
g TO
C
Sedi
men
t su
rfac
e0
T IV
033
033
01
0Si
lty sa
ndst
one
Ove
rbur
den
0N
one
0TI
II33
033
00
200
233
32
Sand
ston
e an
d sh
ale
Res
ervo
ir0
Non
e0
TII
330
1,13
080
010
055
232
1Sa
ndst
one
and
silts
tone
Ove
rbur
den
0N
one
0
TI1,
130
2,21
01,
080
100
6556
5655
Silty
sand
ston
eO
verb
urde
n0
Non
e0
KII
2,21
04,
910
2,70
013
165
Sand
ston
e an
d si
ltsto
neR
eser
voir
0N
one
0
KI
4,91
06,
035
1,12
514
613
2Sa
ndst
one
and
cong
lom
erat
eR
eser
voir
0N
one
0
JIII
6,03
56,
135
100
150
146
Shal
eSe
al0
Non
e0
JIIS
6,13
56,
235
100
155
150
Shal
eSo
urce
5U
nger
er (1
990)
(Spe
kk)-
CS
390
JII
6,23
57,
535
1,30
016
916
0Sa
ndst
one
and
cong
lom
erat
eR
eser
voir
0N
one
0
JI7,
535
8,43
590
030
020
017
017
016
9C
oal a
nd si
lt-st
one
Sour
ce2
Ung
erer
(199
0)T3
Åre
_CS
150
PTII
8,43
59,
435
1,00
024
520
0Sh
ale
and
sand
-st
one
Res
ervo
ir0
Non
e0
PTII
S9,
435
9,53
510
025
024
5Sh
ale
and
lime-
ston
eSo
urce
5B
ehar
et
al(1
997)
_T2
-CS
350
PTI
9,53
510
,535
1,00
028
025
0Li
mes
tone
Res
ervo
ir0
Non
e0
CPI
I10
,535
12,1
851,
650
315
280
Lim
esto
ne a
nd
evap
orite
Und
erbu
r-de
n0
Non
e0
CP1
12,1
8512
,685
500
329
315
Silts
tone
Und
erbu
r-de
n0
Non
e0
DC
112
,685
16,9
854,
300
700
396
340
340
329
Sils
tone
and
sh
ale
Und
erbu
r-de
n0
Non
e0
Cal
edon
ian
16,9
8517
,485
500
460
415
Bas
emen
t roc
ksU
nder
bur-
den
0N
one
0
Tabl
e 1.
In
put d
ata
for b
uria
l his
tory
mod
el o
f Dan
mar
ksha
vn B
asin
(sho
wn
in fi
g. 6
).
[T, T
ertia
ry; K
, Cre
tace
ous;
J, Ju
rass
ic; P
T Pe
rmia
n-Tr
iass
ic; C
P, C
arbo
nife
rous
; DC
, Dev
onia
n; M
a, m
illio
n ye
ars a
go; w
t%, w
eigh
t per
cent
; mgH
C/g
TOC
, mill
igra
ms h
ydro
carb
on p
er g
ram
tota
l org
anic
car
bon]
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008 11
Basin evolution
Petroleum system
Tectonic setting
Rock type
Sour
ce ro
ck
Fold
ing,
faul
ting
and
igne
ous
activ
ity
Seal
s
Rese
rvoi
r roc
k
Trap
s
Petr
oleu
m lo
ss
Mat
urat
ion
and
mig
ratio
n
Convergent
Divergent
Cratonic
Divergent
Cratonic
Divergent
Cratonic
Divergent
Cratonic
Divergent
Cratonic
Transpress
Convergent
Earth system
Geological time scaleSea level curve, in meters
Ave
rage
glo
bal
tem
pera
ture
, in
deg
rees
cel
cius
Sour
ce r
ocks
15° 20° 200 100 0 Eon
Era
Perio
d
Epoc
h
Age
Ma
12.5
2.8
29.0
2.6
25.0
1.2
8.0
0.4
8.0
0.3
9.0
1.0
0.2
560
580
20
40
60
80
100
120
140
160
180
200
220
240
260
280
300
320
340
360
380
400
420
440
460
480
500
520
540
CommentsSn
owba
ll Ear
th
Prot
eroz
oic
Neop
rote
rozo
ic
Ediac
aran
Cam
brian
Lower
Middle
FurongianPaibian
Lower
Middle
Tremadocian
Darriwilian
Upper
Himantian
Ordo
vician
Silur
ian
PridoliLudlow
Wenlock
LlandoveryTelychian
Aeronian
Rhuddanian
SheinwoodianHomerian
Gorsfan
Ludfordian
Early
Middle
Emsian
Pragian
Lochkovian
Eifelian
Paleo
zoic
Devo
nian
Late
Middle
Early
Late
Middle
Early
Late
Middle
Early
Late
Middle
Early
Early
Late
Late
Famennian
Frasnian
Carb
onife
rous
Miss
issipp
ian
Tournaisian
Visean
Serpukhovian
BashkirianPenn
sylva
nian Gzhelian
Kasimonian
Asselian
SakmarianCisuralian
Moscovian
Perm
ian
Guadalupian
Kungarian
Artinskian
Lopingian
Capitanian
RoadianWordian
Wuchiapingian
ChanghsingianInduan
Trias
sicJu
rasic
Olenekian
Anisian
Ladinian
Carian
Norian
Rhaetian
Hettangian
Sinemurian
Pliensbachian
Toarcian
AalenianBajocianBathonianCallovian
Oxfordian
Kimmeridgian
TithonianMes
ozoic
Cret
acou
s
Berriasian
Valanginian
Hauterivian
Barremian
Aptian
Albian
Cenomanian
TuronianConiacian
Santonian
Campanian
Maastrichtian
Danian
Ceno
zoic
Paleo
gene
Paleocene
Eocene
Oligocene
Miocene
PliocenePleistocene
Neog
ene
SelandianThanetian
Ypresian
Lutetian
BartonianPriabonian
Rupelian
Chattian
AquitanianBurdigalian
LanghianSerravallian
TortonianMessinian
Cala
bria
nGe
lasi
an
Piac
enzia
nZa
ncle
an
EXPLANATION
Marine shale
Marine shelf sandstone
Condensed deposits
Carbonate deposits
Evaporite deposits
Sandstone
Unconformity
Earth system
Identified presence
Rock typeOcean anoxic event
Petroleum system
Figure 6
Figure 7. Lithostratigraphic column and total petroleum system events chart showing petroleum system elements for the East Greenland Rift Basins Province. Developed using data from and in collaboration with the Geological Survey of Denmark and Greenland (GEUS). Source rocks column shows the percent of the world’s total petroleum reserves generated by source (modified from Ulmishek and Klemme, 1990). Average global temperature data is from Frakes and others (1992) and Barrett (2003). Sea level curve is from Golonka and Kiessling (2002) and Hardenbol and others (1998). Geologic time scale is that of Gradstein and others (2004).
12 The 2008 Circum-Arctic Resource Appraisal
oil-prone organic matter, and have had burial histories that are not conducive to oil generation and preservation. The Jameson Land Basin Subvolcanic Extension AU is probably geologi-cally similar to Jameson Land and therefore shares its geo-logical risks, but has the additional uncertainty of essentially hidden geology, which, in this case, adds to the risk. Following the CARA methodological protocols they were therefore not quantitatively assessed.
Descriptions of the assessed AUs are given in the text below. The probabilistic results of individual AU assessments and the aggregated province assessment of conventional oil and gas accumulations larger than 50 MMBOE are summa-rized in table 2.
North Danmarkshavn Salt Basin
Assessment Unit Description.—Stratigraphically, the AU includes the entire sedimentary section from the Caledonian basement to the seafloor. Geographically, the AU is bounded by the coast of northeast Greenland on the west; by the eastern boundary fault of Danmarkshavn Ridge on the east; by the southern limit of significant salt deformation on the south, and by the Wandel Sea Basin on the north (figs. 1, 2).
Geological Analysis of Assessment Unit Probability.—The likelihood that the North Danmarkshavn Salt Basin AU contains at least one accumulation greater than the minimum field size of 50 MMBOE is considered to be approximately 60 percent (0.57) based on an interpretation of the principal petro-leum system/AU elements, which are discussed below.
Charge.—Regional studies indicate that numerous stratigraphic intervals in northeast Greenland contain organic carbon-rich strata (fig. 3). But for the purposes of assess-ment, only two intervals, the Lower to Middle Triassic and the Upper Jurassic, were included in the burial history model (fig. 6). The well-known importance of Upper Jurassic source rocks to petroleum generation in the Norwegian Sea and the North Sea suggests that the Upper Jurassic is the most likely petro-leum source rock in northeast Greenland as well. Interpreta-tion of regional seismic data and one-dimensional modeling indicates that Upper Jurassic strata have probably entered the oil window in most of North Danmarkshavn Basin; petroleum generation may have begun in the Late Cretaceous. Migration pathways are highly complex due to salt-induced deformation; oil may also have entered the province from the south. A prob-ability of 0.9 was assigned for charge sufficiency in this AU.
Reservoir Rocks, Traps, and Seals.—Fluvio-deltaic sandstones of Middle Jurassic age, equivalent to the Pelion Member of the Vardekløft Formation onshore (Surlyk, 2003), are postulated to be the most important reservoirs in the AU. Other reservoir intervals may include submarine fans of Cre-taceous age, Lower Jurassic marine sandstones, and carbonate rocks of late Carboniferous and early Permian age. In addi-tion, reservoir lithologies may include Triassic sandstones and progradational sandstones of Tertiary age. Structural trap-ping is expected to be predominantly controlled by diapiric
salt-induced structures. Also, unconformities and fault traps associated with Late Jurassic extension, inversion anticlines, platform margin stratigraphic and fault block traps related to Paleocene continental breakup, and various stratigraphic traps are anticipated. Seals are expected to be provided by evapo-rites of late Carboniferous or early Permian age and by marine shales of Jurassic, Cretaceous, and Tertiary age. A probability of 0.9 was assigned for adequacy of reservoirs, traps and seals in this AU.
Timing of Generation of Hydrocarbons and Preservation of Accumulations.—On the basis of initial one-dimensional modeling, oil generation is inferred to have begun in Late Cretaceous time and to have continued episodically until the present in various parts of the AU. Structures that formed prior to migration may have been available for charge. Salt structures formed subsequent to migration may provide traps for remigrated hydrocarbons but may also destroy previ-ously formed accumulations. Significant preservation risk is postulated, owing to (1) complex effects of salt deformation; (2) uncertainty in seal integrity of shale intervals; (3) possible post-oil-window maturity in deeper areas; and (4) gas expan-sion and oil displacement due to regional late Tertiary uplift. Accordingly, a probability of 0.7 was assigned to adequacy of timing and preservation of fields greater than the minimum size within this AU.
Analogs Used in AssessmentNumbers of Fields.—Interpretation of the proprietary
KANUMAS seismic survey and of unpublished seismic sections collected by the Alfred Wegener Institute (W. Jokat, written commun.) suggests that the structural style of North Danmarkshavn Salt Basin is controlled primarily by episodic salt deformation that began as early as Permian time and con-tinued into the Holocene. Therefore, estimation of field density (number of accumulations >50 MMBOE per 1,000 km2) relied upon the analog field densities of all 18 AUs in the USGS Analog Database (Charpentier and others, 2008) that are clas-sified as having dominant salt-induced structures. This analog set exhibits a nearly uniform distribution across the range of field densities.
Field Size Distribution.—The minimum field size required for a full assessment under the Circum-Arctic Resource Appraisal is 50 MMBOE. The median field size (about 115 MMBOE) is similar to the median field size of the 18 AUs in the USGS Analog Database that report a predomi-nance of salt-induced structures. The low-probability maxi-mum field size truncation point of 20 billion BOE (barrels of oil equivalent) reflects the largest value from the analog set, excluding one outlying value judged to be inappropriate for this AU because it occupies a structure larger than any known subsurface feature in this area of Greenland.
Estimated Maximum Field Size.—The province geolo-gist recommended an expected maximum field size of 2 to 3 billion BOE, based on the distribution of maximum field sizes
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008 13
Table 2. Estimated volumes of undiscovered petroleum resources in the East Greenland Rift Basins Province.
[Estimates are for risked, undiscovered, technically recoverable resources. F95 represents a 95-percent chance of at least the amount tabulated; other fractiles are defined similarly. Std. dev., standard deviation; N/A, not assessed]
Assessment unit name F95 F50 F5 Mean Std. dev.
Oil, in million barrels (MMBO)
North Danmarkshavn Salt Basin
0.00 1,989.17 11,793.38 3,274.31 4,236.50
South Danmarkshavn Basin 0.00 3,228.45 13,995.75 4,384.12 4,822.34Northeast Greenland Volca-
nic Province0.00 0.00 2,757.09 497.30 1,024.28
Thetis Basin 0.00 0.00 2,095.35 537.01 775.99Liverpool Land Basin 0.00 0.00 1,122.37 209.38 453.16Jameson Land Basin N/A N/A N/A N/A N/AJameson Land Basin Sub-
volcanic ExtensionN/A N/A N/A N/A N/A
Associated/dissolved gas, in billion cubic feet (BCFG)
North Danmarkshavn Salt Basin
0.00 3,827.38 26,779.18 7,255.43 11,198.91
South Danmarkshavn Basin 0.00 6,325.41 32,081.29 9,700.31 12,848.42Northeast Greenland Volca-
nic Province0.00 0.00 6,212.23 1,105.14 2,467.25
Thetis Basin 0.00 0.00 4,907.85 1,184.23 1,910.65Liverpool Land Basin 0.00 0.00 2,528.33 463.98 1,146.87Jameson Land Basin N/A N/A N/A N/A N/AJameson Land Basin Sub-
volcanic ExtensionN/A N/A N/A N/A N/A
Natural gas liquids, in million barrels (MMBNGL)
North Danmarkshavn Salt Basin
0.00 264.24 2,123.16 569.91 1,042.78
South Danmarkshavn Basin 0.00 448.63 2,603.36 761.06 1,183.48Northeast Greenland Volca-
nic Province0.00 0.00 492.13 86.98 224.85
Thetis Basin 0.00 0.00 397.48 92.86 169.52Liverpool Land Basin 0.00 0.00 199.66 36.67 106.04Jameson Land Basin N/A N/A N/A N/A N/AJameson Land Basin Sub-
volcanic ExtensionN/A N/A N/A N/A N/A
Assessment unit name Assessment unit probability
North Danmarkshavn Salt Basin 0.648South Danmarkshavn Basin 0.72Northeast Greenland Volcanic Province 0.256Thetis Basin 0.486Liverpool Land Basin 0.288Jameson Land Basin 0.072Jameson Land Basin Subvolcanic Extension 0.042
14 The 2008 Circum-Arctic Resource Appraisal
Assessment unit name F95 F50 F5 Mean Std. dev.
Nonassociated gas, in billion cubic feet (BCFG)
North Danmarkshavn Salt Basin
0.00 23,820.21 107,408.66 32,755.65 37,472.29
South Danmarkshavn Basin 0.00 19,343.89 83,621.43 26,251.49 28,802.63Northeast Greenland Volca-
nic Province0.00 0.00 16,550.52 3,002.67 6,168.58
Thetis Basin 0.00 0.00 12,488.54 3,206.45 4,631.31Liverpool Land Basin 0.00 0.00 6,739.63 1,254.71 2,689.12Jameson Land Basin N/A N/A N/A N/A N/AJameson Land Basin Sub-
volcanic ExtensionN/A N/A N/A N/A N/A
Liquids, in million barrels (MMBL)
North Danmarkshavn Salt Basin
0.00 2,283.61 10,729.86 3,237.32 3,855.86
South Danmarkshavn Basin 0.00 1,843.72 8,362.22 2,598.15 3,002.90Northeast Greenland Volca-
nic Province0.00 0.00 1,650.81 297.05 621.12
Thetis Basin 0.00 0.00 1,251.14 317.40 472.30Liverpool Land Basin 0.00 0.00 672.21 124.18 276.72Jameson Land Basin N/A N/A N/A N/A N/AJameson Land Basin Sub-
volcanic ExtensionN/A N/A N/A N/A N/A
Largest oil, in MMBL
North Danmarkshavn Salt Basin
255.82 1,265.79 7,394.35 2,163.88 2,550.58
South Danmarkshavn Basin 348.86 1,524.42 8,102.34 2,468.80 2,679.85Northeast Greenland Volca-
nic Province167.95 451.69 1,522.42 590.02 448.71
Thetis Basin 106.55 293.52 1,073.00 399.39 334.64Liverpool Land Basin 87.61 233.98 909.46 329.63 297.70Jameson Land Basin N/A N/A N/A N/A N/AJameson Land Basin Sub-
volcanic ExtensionN/A N/A N/A N/A N/A
Largest nonassociated gas, in BCFG
North Danmarkshavn Salt Basin
2,733.71 11,648.60 57,222.01 18,000.58 18,155.41
South Danmarkshavn Basin 2,071.86 9,249.21 49,214.88 14,947.77 16,382.29Northeast Greenland Volca-
nic Province1,005.38 2,704.66 9,038.30 3,525.18 2,675.45
Thetis Basin 635.96 1,761.72 6,385.82 2,381.27 1,978.15Liverpool Land Basin 524.04 1,399.48 5,436.25 1,974.23 1,792.23Jameson Land Basin N/A N/A N/A N/A N/AJameson Land Basin Sub-
volcanic ExtensionN/A N/A N/A N/A N/A
Table 2. Estimated volumes of undiscovered petroleum resources in the East Greenland Rift Basins Province.—Continued.
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008 15
from the analog set. This size is consistent with the largest field in the geologically related Central Graben of the North Sea (Ekofisk oil field), which also has salt-induced structures.
Oil Versus Gas Fields, Ancillary Properties, and Coprod-uct Ratios.—As there are no direct data concerning the distribution of oil, gas, and related properties in northeastern Greenland, the assessment relied on global statistical averages from the USGS Analog Database (Charpentier and others, 2008) and from the specific analog of the oil and gas fields of the Halten Terrace AU in the Norwegian conjugate margin of the North Atlantic Basin, the geographically closest assess-ment unit to northeastern Greenland.
South Danmarkshavn Basin
AU Description.—Stratigraphically, the South Danmark-shavn Basin AU includes the entire sedimentary section from the Caledonian basement to the seafloor. Geographically, the AU is bounded by the coast of northeast Greenland on the west; by the eastern boundary fault of Danmarkshavn Ridge on the east; by the southern limit of extensive salt deformation on the north, and by the northern limit of volcanic cover on the south (see figs. 1, 2).
Geological Analysis of Assessment Unit Probabil-ity.—The likelihood that the South Danmarkshavn Basin AU contains at least one accumulation greater than the minimum field size of 50 MMBOE is considered to be approximately 70 percent (0.729) on the basis of interpretation of principal petroleum system/AU elements, which will be discussed below.
Charge.—Source rocks may include upper Carboniferous lacustrine shales, upper Permian marine marls, Lower Jurassic lacustrine shales, and Upper Jurassic marine shales. Interpreta-tion of regional seismic data and one-dimensional modeling indicates that Upper Jurassic strata have probably entered the oil window in all areas of the AU except on the western margin, on and adjacent to the Koldewey Platform. In some parts of the AU, the Upper Jurassic rocks may have entered the oil window as early as the Late Cretaceous. In the deeper parts of the AU, especially where the Upper Jurassic strata are deeper than 5,000 m, it is likely that these source rocks have passed through the oil window and are now supermature with respect to oil generation. KANUMAS seismic data and 1-D modeling indicate that Upper Jurassic strata are buried through the oil window in the deepest part of Danmarkshavn Basin; oil generation began in the Late Cretaceous. Elsewhere, the Upper Jurassic strata entered the oil window at various times from the Late Cretaceous through the Neogene. Principal migra-tion pathways are upward and westward toward the Koldewey Platform and upward and eastward toward Danmarkshavn Ridge. A probability of 0.9 was assigned for charge sufficiency in this AU.
Reservoir Rocks, Traps, and Seals.—Fluvio-deltaic sandstones of Middle Jurassic age are postulated to be the most important reservoirs in this AU. Other reservoir intervals may include submarine fans of Cretaceous age, Lower Jurassic
marine sandstones, and carbonate rocks of Late Carboniferous and early Permian age. In addition, reservoir lithologies may include Triassic sandstones and progradational sandstones of Tertiary age. Unconformities and fault traps associated with Late Jurassic extension, inversion anticlines along the west-ern margin of the AU, and platform margin stratigraphic and fault-block traps (especially on the western flank of Danmark-shavn Ridge), are related to Paleocene continental breakup. Stratigraphic traps associated with channelized sandstones in fans and progradational sequences are to be expected. Seals are anticipated to be provided by marine shales of Jurassic, Cretaceous or Tertiary age. A probability of 0.9 was assigned for adequacy of reservoirs, traps and seals in this AU.
Timing of Generation of Hydrocarbons and Preservation of Accumulations.—The likelihood of Late Jurassic source rocks and oil generation in Cretaceous and later time suggests a timing risk for pre-Jurassic reservoirs, except in structur-ally high positions on Koldewey Platform and on the flanks of Danmarkshavn Ridge. Significant preservation risk to some reservoirs and traps reflects (1) uncertainty in the seal integrity of shale intervals; (2) post-oil-window maturity that affects hydrocarbon phase and reservoirs in deeper areas; and (3) gas expansion and oil displacement resulting from Cenozoic uplift on Koldewey Platform. Nevertheless, a probability of 0.9 was assigned to adequacy of timing and preservation of one or more fields greater than the minimum size within this AU.
Analogs Used in AssessmentNumbers of Fields.—Interpretation of the proprietary
KANUMAS seismic survey and work on outcrops onshore suggest that the structures controlling field size distribution derive principally from various episodes of tectonic extension and rift/sag subsidence, which accommodated the deposition of thick Cretaceous submarine fan complexes and formation of the Danmarkshavn Ridge. The estimated minimum num-ber of accumulations in the South Danmarkshavn Basin AU is derived from the full range of field densities of the 32 rift/sag basin AUs in the USGS Analog Database (Charpentier and others, 2008). The maximum field densities in the analog set are consistent with those observed in the Central Graben and Viking Graben of the North Sea, which, together with the Halten Terrace, are the geologically most similar basins known to the assessors.
Field Size Distribution.—The minimum field size required for a full assessment under the Circum-Arctic Resource Appraisal is 50 MMBOE. The median value reflects the approximate midpoint in the median sizes of the 32 rift/sag basin AUs in the USGS Analog Database. The low-probability upper truncation of the log normal distribution was selected such that the largest of the inversion structures on the western margin of the AU would exhibit four-way closure and be filled to spill point (approximately 35 billion BOE).
Estimated Maximum Field Size.—In the province geologist’s judgment, the geological setting of the South Danmarkshavn AU, being a rift/sag basin filled largely by
16 The 2008 Circum-Arctic Resource Appraisal
Cretaceous-age submarine fan deposits, suggests the presence of an accumulation of similar size to the Forties oil field of the Central Graben in the North Sea (Wills, 1991). Therefore, the province geologist expects that, if charged, there is a 50 percent chance of an accumulation of approximately 4 billion BOE.
Oil Versus Gas Fields, Ancillary Properties, and Coprod-uct Ratios.—The input values relied upon global statistical averages from the USGS Analog Database (Charpentier and others, 2008) and the specific analog of the oil and gas fields from the Halten Terrace AU of the Norwegian Sea, which were believed to have the most similar source-rock burial his-tory of any previously studied AUs.
Northeast Greenland Volcanic Province
Assessment Unit Description.—Stratigraphically, the Northeast Greenland Volcanic Province AU includes the entire sedimentary section from the basement to the seafloor. Geo-graphically, the AU is bounded by the Greenland Platform on the west, by the continent-ocean boundary on the east, by the north limit of pervasive volcanic rocks on the north, and by the south limit of volcanic cover near Kong Oscar Fjord on the south (figs. 1, 2).
Geological Analysis of Assessment Unit Probability.—The likelihood that South Danmarkshavn Basin extends, unin-terrupted, beneath the Paleocene volcanic rocks was judged to be about 0.5. If present, the likelihood that the extended South Danmarkshavn Basin AU contains at least one accumulation greater than the minimum field size of 50 MMBOE is consid-ered to be approximately 70 percent (0.729). Therefore, the combined probability for the existence of at least one accumu-lation of the minimum size is approximately 0.365.
Analogs Used in Assessment.—South Danmarkshavn Basin AU is used as an internal analog; the assessment of the Northeast Greenland Volcanic Province is based upon the scenario that the geological properties of the South Danmark-shavn Basin AU extend beneath the Paleocene volcanic cover of the Northeast Greenland Volcanic Province.
Thetis Basin
Assessment Unit Description.—Stratigraphically, the The-tis Basin AU is defined to include all strata from at or below the acoustic basement to the seafloor. Geographically, the AU extends from the main boundary fault of Danmarkshavn Ridge on the west to the continent-ocean boundary or ocean-conti-nental transition zone on the east, and from the southern limit of significant salt deformation on the north to the northeastern limit of volcanic cover on the south and southwest (figs. 1, 2).
Geological Analysis of Assessment Unit Probability.—The overall likelihood that the Thetis Basin AU contains at least one accumulation of 50 MMBOE or greater is judged to be approximately 45 percent (0.448) based on an interpreta-tion of principal petroleum system/AU elements, which are discussed below.
Charge.—Source rocks may include deeply buried Upper Jurassic marine shales, as well as marine shales of Cretaceous or Tertiary age. Lower Cretaceous and older strata probably entered the oil window in Paleocene time. Late Cretaceous and Paleogene strata may have entered the oil window during the Neogene; most Mesozoic strata have been buried through the oil window and are now supermature with respect to oil generation. Postulated migration pathways are upward into overlying Tertiary progradational sequences and westward to the margin of Danmarkshavn Ridge or eastward to the Marginal Uplift. A probability of 0.8 was assigned for charge adequacy for this AU.
Reservoir Rocks, Traps, and Seals.—Channelized sand-stones and fans in eastward-advancing Tertiary progradational strata and sandstones in Cretaceous submarine fan complexes deposited in the pre-Paleogene rift/sag basin are postulated to be the principal reservoir rocks of this AU. Trapping geome-tries are mainly stratigraphic traps associated with the Tertiary progradational strata and the rift/sag basin fill of Mesozoic age. In addition, the possibility exists for traps in fault blocks along the margin of Danmarkshavn Ridge and for unconfor-mity traps along the eastern marginal high. Seals are intrafor-mational within the stratigraphic traps, and ultimate top seals are provided by shales of Tertiary age. A probability of 0.8 was assigned to the adequacy of reservoir lithologies and trap geometries sufficient to contain at least one accumulation of the minimum size within the AU.
Timing of Generation of Hydrocarbons and Preserva-tion of Accumulations.—In comparison with other AUs in the East Greenland Rift Basins Province, hydrocarbon generation and migration in the Thetis Basin would have been relatively late in the burial history. Late generation as a result of progra-dation of thick Cretaceous and Tertiary strata is considered beneficial to timing and preservation. Preservation of oil is extremely unlikely in Mesozoic strata because of their high temperature exposure due to deep burial during the Cenozoic. Siliciclastic strata may be insufficient to provide effective seals for gas accumulations. For this reason a probability of 0.7 was assigned for adequacy of timing and preservation of one accumulation of minimum size within the AU.
Analogs Used in AssessmentNumbers of Fields.—The USGS Analog Database (Char-
pentier and others, 2008) was searched for analogs in slope, clinoform, and turbidite depositional settings and in rifted passive margins. The full distribution of field densities from those analogs was used to estimate the range of numbers of undiscovered fields within the AU.
Field Size Distribution.—Field sizes in the USGS Analog Database (Charpentier and others, 2008) from slope, clino-form, and turbidite depositional settings and from the rifted-passive-margin tectonic settings were considered, as were several specific analogs from the margins of the Atlantic basin, including the Vøring and Møre Basins. The minimum field size required for a full assessment under the Circum-Arctic Resource Appraisal is 50 MMBOE; the median value was
Geology and Assessment of Undiscovered Oil and Gas Resources of the East Greenland Rift Basins Province, 2008 17
chosen from the central tendency of the analog sets. The trun-cation point of the log-normal field size distribution was set at approximately 8 billion BOE, consistent with the absolute maximum field size in the analog set.
Estimated Maximum Field Size.—The maximum field size was estimated based on review of the limited geologi-cal information available for Thetis Basin, including its distal setting compared to Southern Danmarkshavn Basin, the great thickness and exceedingly deep burial of much of the Cretaceous rift/sag basin fill, and the uncertain lithologies of the Tertiary progradational strata. The province geologist estimated a probability of 0.5 that an accumulation of 800 MMBOE or more might be present within the AU. This size is the median of maximum field sizes among the analog basins used in assessment of the Thetis Basin.
Oil Versus Gas Fields, Ancillary Properties, and Coprod-uct Ratios.—These parameters were estimated in reference to the specific analog of hydrocarbon fill observed in fields of the Halten Terrace on the Norwegian conjugate margin, as discussed above, and from global statistical averages.
Liverpool Land Basin
Assessment Unit Description.—Stratigraphically, the Liverpool Land Basin AU includes all strata from the acoustic basement to the seafloor. Geographically, the AU extends from the Liverpool Land uplift on the west, to the continent-ocean boundary on the east and southeast. The Liverpool Land Basin AU extends northward to the Northeast Greenland Volcanic Province (see figs. 1, 2).
Geological Analysis of Assessment Unit Probability.—The overall likelihood that the Liverpool Land Basin AU contains at least one accumulation of 50 MMBOE or greater is judged to be approximately 20 percent (0.224) on the basis of an interpretation of the principal petroleum system and AU elements, which are discussed below.
Charge.—Source rocks are speculated to include now deeply buried Upper Jurassic marine shales, as well as shales of Cretaceous or Tertiary age. Initial one-dimensional mod-eling suggests that Cretaceous and older strata probably entered the oil window in the Neogene. Upper Cretaceous and Paleogene strata may also have entered the oil window during the Neogene; most Mesozoic strata have been buried through the oil window and are now supermature with respect to oil generation. Postulated migration pathways are upward into overlying Cenozoic progradational sequences and westward to the margin of Liverpool Land and eastward beyond the continent-ocean boundary. Because of the doubtful presence of Upper Jurassic strata, a probability of 0.4 for charge adequacy was assigned to this AU.
Reservoir Rocks, Traps, and Seals.—Channelized sand-stones and fans in eastward-advancing Tertiary progradational strata are postulated to be the principal reservoir rocks of this
AU. Trapping geometries are mainly stratigraphic traps associ-ated with the Tertiary progradational strata. In addition, the possibility exists for traps in fault blocks along the margin of Liverpool Land and for unconformity traps along the eastern transition to the continent-ocean boundary. Seals are intrafor-mational within the stratigraphic traps, and ultimate top seals are provided by shales of Neogene age. A probability of 0.7 was assigned to the adequacy of reservoir lithologies and trap geometries sufficient to contain at least one accumulation of the minimum size within the Liverpool Land Basin AU.
Timing of Generation of Hydrocarbons and Preservation of Accumulations.—Generation and migration is believed to have taken place as late as Neogene time, as a result of burial beneath thick Tertiary progradational strata. However, the siliciclastic strata of the Neogene succession may be insuf-ficient to provide effective seals for gas accumulations. For this reason a probability of 0.8 was assigned for adequacy of timing and preservation of one accumulation of minimum size within the AU.
Analogs Used in AssessmentNumbers of Fields.—The USGS Analog Database (Char-
pentier and others, 2008) was searched for analogs in slope, clinoform and turbidite depositional settings and in rifted passive margins. The full distribution of field densities from those analogs was used to estimate the range of numbers of undiscovered fields within the AU.
Field Size Distribution.—Field sizes of analog AUs having similar slope, clinoform, and turbidite depositional systems within rifted passive margin tectonic settings were considered, as were several specific analogs from the margins of the Atlantic Ocean Basin, including the Vøring and Møre Basins. The minimum field size necessary for assessment was set by the CARA protocol; the median value was chosen from the central tendency of the analog sets. The truncation point of the log-normal field size distribution was set at approximately 8 billion BOE, consistent with the absolute maximum field size in the analog set.
Estimated Maximum Field Size.—The maximum field size was estimated from the extremely limited geological information available for Liverpool Land Basin; it has a distal setting compared to Southern Danmarkshavn Basin, exceed-ingly deep burial of pre-Tertiary strata, and uncertain litholo-gies of the progradational systems. The province geologist estimated a probability of 0.5 that an accumulation of 800 MMBOE or more might be present within the AU. This size is the median value for maximum field sizes within the searched analog sets.
Oil Versus Gas Fields, Ancillary Properties, and Coprod-uct Ratios.—These parameters were estimated by analogy of hydrocarbon fill in fields of the Halten Terrace on the Norwe-gian conjugate margin and from global statistical averages.
18 The 2008 Circum-Arctic Resource Appraisal
ResultsAlthough the risks and uncertainties are high, north-
east Greenland may contain large quantities of recoverable petroleum. The entire East Greenland Rift Basins Province is estimated to contain about 31.4 BBOE oil, gas, and natural gas liquids, thus ranking fourth among the 25 assessed CARA provinces with quantitatively assessed resources. The undis-covered, technically recoverable oil and gas resources are estimated to be almost entirely offshore and concentrated in two assessment units: (1) South Danmarkshavn Basin, with a mean estimate of 4.4 BBO and 26.3 TCF of gas, and (2) the North Danmarkshavn Basin, with a mean estimate of 3.3 BBO and 32.7 TCF of gas. Much smaller resource volumes are estimated in the other quantitatively assessed AUs.
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20 The 2008 Circum-Arctic Resource Appraisal
Appendixes
Appendixes are available online only, and may be accessed at https://doi.org/10.3133/pp1824K
Appendix 1. Input data for the North Danmarkshavn Salt Basin Assessment Unit Appendix 2. Input data for the South Danmarkshavn Basin Assessment Unit Appendix 3. Input data for the Northeast Greenland Volcanic Province Assessment UnitAppendix 4. Input data for the Thetis Basin Assessment UnitAppendix 5. Input data for the Liverpool Land Assessment UnitAppendix 6. Input data for the Jameson Land Basin Assessment Unit Appendix 7. Input data for the Jameson Land Basin Subvolcanic Extension Assessment Unit
Menlo Park Publishing Service Center, California Manuscript approved for publication May 15, 2017 Edited by Claire LandowskiLayout by Vivian Nguyen
Gautier—G
eology and Assessm
ent of Undiscovered O
il and Gas Resources of the East G
reenland Rift Basins Province, 2008 —
Professional Paper 1824 Chapter KISSN 2330-7102 (online)https://doi.org/10.3133/pp1824K