scholarly journals Hydrocarbon reservoir potential in Paleozoic strata in the Hudson Bay Basin, northern Canada

2012 ◽  
Author(s):  
K Hu ◽  
J Dietrich
Keyword(s):  
Hudson Bay ◽  
Northern Canada ◽  
Hydrocarbon Reservoir ◽  
Reservoir Potential

Chronological list of expeditions and historical events in northern Canada. V. 1790–1821

Polar Record ◽  
1971 ◽  
Vol 15 (99) ◽  
pp. 893-920
Author(s):  
Alan Cooke ◽  
Clive Holland
Keyword(s):  
Hudson Bay ◽  
Hudson's Bay Company ◽  
Historical Events ◽  
New Techniques ◽  
Northern Canada ◽  
North West ◽  
The North ◽  
Rupert's Land ◽  
New Policies ◽  
Hudson’S Bay Company

During the period covered by this instalment of our list, the accomplishments of the North West Company, both in geographical exploration and in the realization of profits were great. It consolidated its position in the fur-rich Athabasca district and, with a few posts along Mackenzie River, began to draw in the furs of that immense territory. Its traders invaded not only the western part of Rupert's Land but even Hudson Bay itself. The Hudson's Bay Company rose only slowly to the challenge of its formidable rival, but, gradually, it began to adopt new policies and new techniques and to meet the North West Company on its own grounds and on its own terms. Finally, after a bitter struggle that was almost the destruction of both companies, the Hudson's Bay Company, in 1821, effectively absorbed the North West Company in a coalition that gave the older company greater strength than ever and a wider monopoly than Prince Rupert had thought of.

THE YELLOW DRUM FORMATION—A HYDROCARBON RESERVOIR, CANNING BASIN, WESTERN AUSTRALIA

1986 ◽  
Vol 26 (1) ◽  
pp. 310
Author(s):  
H.T. Moors
Keyword(s):  
Western Australia ◽  
Crystalline Rock ◽  
Oil Reservoir ◽  
Depositional Model ◽  
Canning Basin ◽  
Fine Grained ◽  
Hydrocarbon Reservoir ◽  
Reservoir Development ◽  
Reservoir Potential

The Yellow Drum Formation has an extensive distribution on the Lennard Shelf of the Canning Basin. It straddles the Devonian-Carboniferous boundary and is a peritidal clearwater deposit. The environment of deposition controlled the diagenetic path followed by the sediments. The bulk of the formation was penecontem-poraneously dolomitized to a fine-grained crystalline rock with moderate porosity, with permeability too low to be an effective oil reservoir. However, in some facies the dolomite was coarser grained producing a good reservoir. Tertiary porosity was created by later leaching of remnant calcite, turning a good reservoir into an excellent reservoir.The environment of deposition is readily identified from examination of the sediments, which can then be located in a depositional model. From this the reservoir potential can be predicted. Conversely, from the identification of the portion of the depositional model in which the sediments were deposited it is possible to predict in what direction better reservoir development exists.

Hydrocarbon Reservoir Potential of the Taranaki Basin, Western New Zealand

1988 ◽  
Vol 6 (3) ◽  
pp. 248-262 ◽  
Author(s):  
P.H. Robinson ◽  
P.R. King
Keyword(s):  
New Zealand ◽  
Late Cretaceous ◽  
Late Eocene ◽  
Hydrocarbon Reservoir ◽  
Future Activity ◽  
Terrestrial Sediments ◽  
Potential Reservoir ◽  
Sandstone Reservoir ◽  
Reservoir Potential ◽  
Sand Bodies

Taranaki Basin is a proven petroleum producing region, with commercial quantities of hydrocarbons from late Eocene paralic and terrestrial sands, and Miocene-latest Pliocene shelf sands. Other sediments with sub-commercial hydrocarbon accumulations, shows or potential reservoir features have also been encountered. The paralic and terrestrial sediments were deposited during periodic shoreline fluctuations in the Paleogene and were capped by transgressive terrigenous and carbonate muds. Other sand bodies, generally of bathyal and shelf setting and representing increasing regional tectonism, are found throughout the late Eocene to Pliocene sequence. Paleogeographic reconstructions depicting the maximum sand development during the Paelocene to Pliocene provide potential sandstone reservoir maps. These highlight onshore Taranaki and the Eocene paleoshoreline trend as areas of greatest prospectivity. Future activity should also consider the potential of the relatively unexplored late Cretaceous-Paleocene and Pliocene sandstone sequences.

Thecate Hydroids from the Shelf Waters of Northern Canada

1970 ◽  
Vol 27 (9) ◽  
pp. 1501-1547 ◽  
Author(s):  
Dale R. Calder
Keyword(s):  
North America ◽  
New Records ◽  
High Arctic ◽  
Common Species ◽  
Hudson Bay ◽  
Northern Canada ◽  
Foxe Basin ◽  
First Time

Based largely on collections from the Calanus–Salvelinus expeditions, 54 species of thecate hydroids were identified from the shelf waters of northern Canada between northeastern Newfoundland and the Alaska–Yukon border. Common species included Halecium muricatum, Calycella syringa, Campanularia integra, C. speciosa, C. volubilis, Gonothyraea loveni, Filellum serpens, Lafoea gracillima, Sertularella polyzonias, S. tricuspidata, Sertularia schmidti, and S. similis. Halecium groenlandicum, H. scutum, Cuspidella procumbens, Calycella gracilis, and Sertularia schmidti are new records for North America; Ptychogena lactea is previously known from this continent only as the medusa. Twenty-two species are reported in northern Canada for the first time, bringing to 71 the number of thecate species recorded from the region. Nearly half of the 71 species recorded are circumpolar in distribution, and over two-thirds transgress both arctic and subarctic zones.Most samples had a paucity of hydroids, particularly those from the high arctic. Collection records indicate that the most favourable regions for hydroids in northern Canada are the Strait of Belle Isle, eastern Ungava Bay, eastern Hudson Strait, northern and southeastern Hudson Bay, Foxe Channel, and northern Foxe Basin.

scholarly journals Assessing accuracy of gas-driven permeability measurements: a comparative study of diverse Hassler-cell and probe permeameter devices

2013 ◽  
Vol 5 (2) ◽  
pp. 1163-1190 ◽  
Author(s):  
C. M. Filomena ◽  
J. Hornung ◽  
H. Stollhofen
Keyword(s):  
Sedimentary Rocks ◽  
Detailed Comparison ◽  
Sample Analysis ◽  
Hydrocarbon Reservoir ◽  
Lower Permeability ◽  
Correlation Tests ◽  
Outcrop Analog ◽  
Reservoir Potential ◽  
Selection Of ◽  
Permeability Data

Abstract. Permeability is one of the most important petrophysical parameters to describe the reservoir potential of sedimentary rocks, contributing to problems in hydrology, geothermics, or hydrocarbon reservoir analysis. Outcrop analog studies, well core measurements, or individual sample analysis take advantage of a variety of commercially available devices for permeability measurements. Very often, permeability data derived from different devices need to be merged within one study, e.g. outcrop mini-permeametry and lab-based core plug measurements. To enhance accuracy of different gas-driven permeability measurements, device-specific aberrations need to be taken into account. The application of simple one-to-one correlations may draw a wrong picture of permeability trends. For this purpose, transform equations need to be established. This study presents a detailed comparison of permeability data derived from a selection of commonly used Hassler cells and probe permeameters. As a result of individual cross-plots, typical aberrations and transform equations are elaborated which enable corrections for the specific permeameters. Permeability measurements of the commercially available ErgoTech Gas Permeameter and the TinyPerm II probe-permeameter are well-comparable over the entire range of permeability, with R2 = 0.967. Major aberrations are identified among the TinyPerm II and the mini-permeameter/Hassler-cell combination at Darmstadt University, which need to be corrected and standardized within one study. However, transforms are critical to their use, as aberrations are frequently limited to certain permeability intervals. In the presented examples, deviations typically tend to occur in the lower permeability range < 10 mD. Applying standardizations which consider these aberration intervals strongly improve the comparability of permeability datasets and facilitate the combination of measurement principles. Therefore, the utilization of such correlation tests is highly recommended for all kinds of reservoir studies using integrated permeability databases.

Tectonostratigraphic development and hydrocarbon reservoir quality on a convergent margin: East Coast, North Island, New Zealand

2009 ◽  
Vol 49 (2) ◽  
pp. 600
Author(s):  
Brad Field ◽  
Jan Baur ◽  
Kyle Bland ◽  
Greg Browne ◽  
Angela Griffin ◽  
...  
Keyword(s):  
Late Cretaceous ◽  
East Coast ◽  
Fractured Reservoirs ◽  
Hydrocarbon Exploration ◽  
Passive Margin ◽  
Source Rocks ◽  
Reservoir Quality ◽  
High Porosity ◽  
Hydrocarbon Reservoir ◽  
Reservoir Potential

Hydrocarbon exploration on the East Coast of the North Island has not yet yielded significant commercial reserves, even though the elements of a working petroleum system are all present (Field et al, 1997). Exploration has focussed on the shallow, Neogene part of the succession, built up during plate margin convergence over the last ∼24 million years. Convergent margins are generally characterised by low-total organic carbon (TOC) source rocks and poor clastic reservoir quality due to poor sorting and labile grains. However, the obliquely-convergent Hikurangi subduction margin of the East Coast has high TOC source rocks that pre-date the subduction phase, and its reservoir potential, though variable, has several aspects in its favour, namely: deep-water rocks of high porosity and permeability; preservation of pore space by overpressure; the presence of fractured reservoirs and hybrid reservoirs, where low clastic permeability is enhanced by fractures. The East Coast North Island is a Neogene oblique subduction margin, with Neogene shelf and slope basins that developed on Late Cretaceous-Paleogene passive margin marine successions. The main hydrocarbon source rocks are Late Cretaceous and Paleocene and the main reservoir potential is in the Neogene (Field et al, 2005). Miocene mudstones with good seal potential are common, as is significant over-pressuring. Neogene deformation controlled basin development and accommodation space and strongly-influenced lateral facies development and fractured reservoirs. Early to Middle Miocene thrusting was followed by later Neogene extension (e.g. Barnes et al 2002), with a return to thrusting in the Pliocene. Local wells have flow-tested gas shows.

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