Provenance of Upper Jurassic to Lower Cretaceous synrift strata in the Terra Nova oil field, Jeanne d’Arc basin, offshore Newfoundland: A new detrital zircon U-Pb-Hf reference frame for the Atlantic Canadian margin

AAPG Bulletin ◽  
2020 ◽  
Vol 104 (11) ◽  
pp. 2325-2349
Author(s):  
Alexander D. Hutter ◽  
Luke P. Beranek
Keyword(s):  
Reference Frame ◽  
Detrital Zircon ◽  
Lower Cretaceous ◽  
Upper Jurassic ◽  
Oil Field ◽  
Jeanne D'arc Basin ◽  
Terra Nova ◽  
Jeanne D'arc

Variations in mixed-layer illite/smectite diagenesis in the rift and post-rift sediments of the Jeanne d'Arc Basin, Grand Banks offshore Newfoundland, Canada

2004 ◽  
Vol 41 (4) ◽  
pp. 401-429 ◽  
Author(s):  
Iftikhar A Abid ◽  
Reinhard Hesse ◽  
John D Harper
Keyword(s):  
Mixed Layer ◽  
Fine Fraction ◽  
Upper Jurassic ◽  
Grand Banks ◽  
Depth Profiles ◽  
Jeanne D'arc Basin ◽  
Central Ridge ◽  
Jeanne D'arc ◽  
Layer I ◽  
Mixed Layers

Mixed-layer illite/smectite (I/S) clays were analyzed from 22 deep exploration wells from the Jeanne d'Arc Basin on the Grand Banks offshore Newfoundland, the host of large commercial hydrocarbon accumulations discovered in the last two and a half decades. The fine fraction of the clays (<0.1 µm) consists mainly of mixed-layer I/S with minor amounts of kaolinite, illite, and chlorite. Smectite and (or) smectite-rich I/S clays were supplied to the Jeanne d'Arc Basin from Upper Jurassic to Tertiary times. Smectite-rich I/S clays occur only in shallow samples irrespective of geologic age. The proportion of illite in I/S mixed-layers, as well as the degree of ordering, increase with depth and temperature indicating that smectite-rich I/S clays have been progressively illitized in both rift and post-rift sediments of the Jeanne d'Arc Basin during burial. The transition from random to R1-ordered I/S occurs between subsurface depths of 1940 and 3720 m and crosses major stratigraphic boundaries. The transition from R1- to R3-ordered I/S generally occurs below 4000 m depth. Variable shapes of I/S depth profiles reflect the influence of temperature, fluid migration, subsidence history, basin structure, lithology, and salt diapirism on I/S diagenesis. Based on these variations, the basin can be subdivided into 4 regions with different illitization gradients. In the Southern Jeanne d'Ac Basin, advanced I/S diagenesis probably reflects uplift and denudation and (or) higher paleogeothermal gradients. Rapid increase of percent illite in I/S with depth in the Trans-Basinal Fault area is most likely controlled by upward flow of hot, K+-bearing fluids along faults. The migration of hydrocarbons probably followed the same pathways as the illitizing fluids. Delayed illitization in the Northern Jeanne d'Arc Basin and Central Ridge area reflects insufficient K+ supply because of a lack of detrital K-feldspar in the host sediment, the absence of faulting, and the presence of thick shale intervals. These findings show that I/S depth profiles may vary within the same sedimentary basin due to a variety of geological factors. Single wells generally cannot be considered representative for the basin as a whole.

A Hydrocarbon Charge Model of the Hibernia Drainage Area, Jeanne d'Arc Basin, Offshore Newfoundland

1994 ◽  
Vol 12 (4) ◽  
pp. 295-323
Author(s):  
Mark Williamson ◽  
Kevin Coflin ◽  
Scott King ◽  
Kevin Desroches ◽  
Phil Moir ◽  
...  
Keyword(s):  
Oil Field ◽  
Drainage Area ◽  
Secondary Migration ◽  
Jeanne D'arc Basin ◽  
The North ◽  
Charge Model ◽  
Jeanne D'arc ◽  
Hydrocarbon Charge ◽  
Volume Estimates ◽  
Migration Loss

An integration of map based and geological/geochemical modelling methodologies has enabled us to image the burial, subsidence, thermal and organic maturation histories of an area which, given its present and past structural geometry, drains into the Hibernia Oil Field. Our models indicate that the deeper parts of the Hibernia Drainage Area (HDA) contributed significant volumes of hydrocarbons, as early as 80–100 Ma, to the Hibernia structural culmination. The shallower portion of the HDA, such as the area vertically below pooled petroleum at Hibernia, has only been contributing hydrocarbons during the last 30–40 Ma. Translation of the modelled maturation history into volumetric estimates of generated, expelled and migrated oil within the area is accomplished assuming a 20% saturation threshold prior to hydrocarbon flow from the source to the reservoir/carrier system. Secondary Migration loss is estimated through assuming a reservoir/carrier-wide residual saturation of 2%. Our volume estimates suggest that the defined HDA was unable to provide sufficient charge volumes to fill the Hibernia structure and that additional charge must have been available from a drainage area to the north across the Nautilus fault. Extrapolation of HDA volumes throughout specifically defined play areas and the broader Jeanne d'Arc Basin suggests that, after accounting for secondary migration loss and assuming 30% recovery efficiency, some 2,015 106m3 (12,650 Mmbbls) of oil remains to be discovered. Our models do not account for losses due to biodegradation processes. Although this is not thought to be significant within the HDA, it will reduce basin-wide resources estimates and requires further study.

scholarly journals Generation, migration, accumulation, and dissipation of oil in Northern Iraq

GeoArabia ◽  
2005 ◽  
Vol 10 (2) ◽  
pp. 39-84 ◽  
Author(s):  
H.V. Dunnington
Keyword(s):  
Lower Cretaceous ◽  
Large Scale ◽  
Upper Cretaceous ◽  
Upper Jurassic ◽  
Oil Field ◽  
Lateral Migration ◽  
Upward Migration ◽  
Factors Affecting ◽  
Northern Iraq ◽  
Late Tertiary

ABSTRACT Most of the known oil accumulations of Northern Iraq probably originated by upward migration from earlier, deeper accumulations which were initially housed in stratigraphic or long-established structural traps, and which are now largely depleted. The earlier concentrations had their source in basinal sediments, into which the porous, primary-reservoir limestones pass at modest distances east of the present fields. Development of the region favored lateral migration from different basinal areas of Upper Jurassic and Lower-Middle Cretaceous time into different areas of primary accumulation. Important factors affecting primary accumulation included: (1) early emergence and porosity improvement of the reservoir limestones, followed by burial under seal-capable sediments; (2) the timely imposition of heavy and increasing depositional loads on the source sediments, and the progressive marginward advance of such loads; (3) progressive steepening of gradients trending upward from source to accumulation area; (4) limitation of the reservoir formations on the up-dip margin by truncation or by porosity trap conditions. In late Tertiary time, large-scale folding caused adjustments within the primary reservoirs, and associated fracturing permitted eventual escape to higher limestone reservoirs, or to dissipation at surface. The sulfurous, non-commercial crudes of Miocene and Upper Cretaceous reservoirs in the Qaiyarah area are thought to stem from basinal radiolarian Upper Jurassic sediments, which lie down dip, a few tens of miles east of these fields. Upper Cretaceous oils of Ain Zalah and Butmah drained upward from primary accumulations in Middle Cretaceous limestones, which were filled from basinal sediments of Lower Cretaceous age situated in a localized trough a few miles northeast of these structures. The huge Kirkuk accumulation, now housed in Eocene-Oligocene limestones, ascended from a precedent accumulation in porous Middle-Lower Cretaceous limestones, which drew its oil from globigerinal-radiolarian shales and limestones of the contemporaneous basin, a short distance east of the present field limits. Eocene-Oligocene globigerinal sediments, considered by some the obvious source material for Kirkuk oil, seemingly provided little or no part of the present accumulation. The reservoir formation may have been filled from these sources, to lose its oil by surface dissipation during the erosional episode preceding Lower Fars deposition. Upper Cretaceous basinal sediments probably contributed nothing to known oil field accumulations, though they may have subscribed to the spectacular impregnations of some exposed, Upper Cretaceous reef-type limestones. Neither Miocene nor pre-Upper Jurassic sediments have played any discernible role in providing oil to any producing field. Indigenous oils are thought to be negligible in the limestone-reservoir formations considered.

The Miller Field, Blocks 16/7B, 16/8B, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 159-164 ◽  
Author(s):  
S. K. Rooksby
Keyword(s):  
North Sea ◽  
Seismic Data ◽  
Lower Cretaceous ◽  
Upper Jurassic ◽  
Oil Field ◽  
The South ◽  
Submarine Fan ◽  
Western Margin ◽  
Average Porosity ◽  
Slow Velocity

AbstractThe Miller Oil Field is located on the western margin of the South Viking Graben in UKCS Blocks 16/7b and 16/8b. The oil is trapped in Upper Jurassic turbidite sands shed from the Fladen Ground Spur via the Brae complex submarine fan systems. The reservoir sands are of good quality with an average porosity of 16% and permeabilities occasionally in excess of 1 Darcy. The trap is formed within a subtle structural-stratigraphic combination. Overlying slow velocity Lower Cretaceous sediments produce a time flat which, after depth conversion, produces a 3-way dip closed feature. The trap is completed by stratigraphic pinchout of the reservoir sands to the northwest. The most recent (1985) seismic data allow the top reservoir reflector to be picked directly, which was not the case during the exploration and appraisal phase, when only the Top Kimmeridge Clay seismic pick could be made. The estimate of recoverable hydrocarbons is currently 300 MMBBL of oil and 570 BCF of gas. Development drilling commenced early in 1989. No results are yet available.

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