HYDROCARBON POTENTIAL OF THE NORTH WANGANUI BASIN, NEW ZEALAND

1977 ◽  
Vol 17 (1) ◽  
pp. 94
Author(s):  
H. McQuillan
Keyword(s):  
Sediment Supply ◽  
Source Rocks ◽  
Oil Companies ◽  
The North ◽  
Clastic Sediments ◽  
Potential Reservoir ◽  
History Of ◽  
Wrench Fault ◽  
Available Information ◽  
Coal Measures

The proximity of the North Wanganui Basin to the onshore Kapuni and offshore Maui gas/condensate fields of the adjacent Taranaki Basin has attracted the interest of oil companies for some time. Exploration during the late 1950's and early 1960's delineated several prospective traps. Some of these were subsequently drilled and, apart from minor gas indications, were dry holes. Data from the sixteen wells drilled are on open file and these together with other available information are incorporated in a series of maps representing stages in the evolution of the basin.The sedimentary history of the North Wanganui Basin began early in the Oligocene when a shallow north to south marine transgression saw the infilling of structurally defined northeast-southwest trending depressions in the folded Mesozoic basement. As the relief of the peripheral landmass was reduced the former basin irregularities were smoothed out and the way was paved for the spread of carbonate rich seas from which a suite of carbonate grainstones and packstones was deposited during the middle Oligocene. Late Oligocene time saw the renewed influx of clastic sediments as movements on the dominant wrench fault basement structure brought revived relief to areas of sediment supply. At that time the southern margin of the basin possibly merged westwards with the Taranaki Basin. Punctuated by periods of vulcanicity centred west of the present coastline, a thick sequence of mud, silt and sand, dominantly marine but locally including terrestrial coal measures, makes up the Miocene succession. Sedimentation controlled by growth faulting is characteristic, and the east-west barrier of the Pipiriki High persisted in restricting the southern extension of the basin during that time. The Miocene closed with a tilting movement hinged on the Pipiriki High such that subsequent Pliocene and Pleistocene sedimentation followed a south-east migrating depocentre in the quite separate South Wanganui Basin.Hydrocarbon indications in the basin itself are few. The presence there of potential reservoir and source rocks in addition to the proven production in the adjacent Taranaki Basin are reason for some optimism in the further evaluation of the hydrocarbon prospects of the North Wanganui Basin.

scholarly journals Evaluation of hydrocarbons generated from the Permo-Carboniferous source rocks in Huanghua Depression of the Bohai Bay Basin, China

2018 ◽  
Vol 36 (5) ◽  
pp. 1229-1244
Author(s):  
Xiao-Rong Qu ◽  
Yan-Ming Zhu ◽  
Wu Li ◽  
Xin Tang ◽  
Han Zhang
Keyword(s):  
Oil And Gas ◽  
Source Rocks ◽  
Bohai Bay ◽  
Hydrocarbon Generation ◽  
Burial History ◽  
Bohai Bay Basin ◽  
Important Conclusion ◽  
The North ◽  
Huanghua Depression ◽  
History Of

The Huanghua Depression is located in the north-centre of Bohai Bay Basin, which is a rift basin developed in the Mesozoic over the basement of the Huabei Platform, China. Permo-Carboniferous source rocks were formed in the Huanghua Depression, which has experienced multiple complicated tectonic alterations with inhomogeneous uplift, deformation, buried depth and magma effect. As a result, the hydrocarbon generation evolution of Permo-Carboniferous source rocks was characterized by discontinuity and grading. On the basis of a detailed study on tectonic-burial history, the paper worked on the burial history, heating history and hydrocarbon generation history of Permo-Carboniferous source rocks in the Huanghua Depression combined with apatite fission track testing and fluid inclusion analyses using the EASY% Ro numerical simulation. The results revealed that their maturity evolved in stages with multiple hydrocarbon generations. In this paper, we clarified the tectonic episode, the strength of hydrocarbon generation and the time–spatial distribution of hydrocarbon regeneration. Finally, an important conclusion was made that the hydrocarbon regeneration of Permo-Carboniferous source rocks occurred in the Late Cenozoic and the subordinate depressions were brought forward as advantage zones for the depth exploration of Permo-Carboniferous oil and gas in the middle-northern part of the Huanghua Depression, Bohai Bay Basin, China.

GEOLOGY, SOURCE ROCKS AND HYDROCARBON GENERATION IN THE CLARENCE-MORETON BASIN

1982 ◽  
Vol 22 (1) ◽  
pp. 5
Author(s):  
A. R. Martin ◽  
J. D. Saxby
Keyword(s):  
Vitrinite Reflectance ◽  
Source Rocks ◽  
Geochemical Data ◽  
Hydrocarbon Potential ◽  
Hydrocarbon Generation ◽  
Tectonic Events ◽  
History Of ◽  
Rock Eval ◽  
Coal Measures ◽  
Migration Pathways

The geology and exploration history of the Triassic-Cretaceous Clarence-Moreton Basin are reviewed. Consideration of new geochemical data ('Rock-Eval', vitrinite reflectance, gas chromatography of extracts, organic carbon and elemental analysis of coals and kerogens) gives further insights into the hydrocarbon potential of the basin. Although organic-rich rocks are relatively abundant, most source rocks that have achieved the levels of maturation necessary for hydrocarbon generation are gas-prone. The exinite-rich oil-prone Walloon Coal Measures are in most parts relatively immature. Some restraints on migration pathways are evident and igneous and tectonic events may have disturbed potentially well-sealed traps. Further exploration is warranted, even though the basin appears gas-prone and the overall prospects for hydrocarbons are only fair. The most promising areas seem to be west of Toowoomba for oil and the Clarence Syncline for gas.

THE HYDROCARBON POTENTIAL OF THE PENOLA TROUGH, OTWAY BASIN

1995 ◽  
Vol 35 (1) ◽  
pp. 358 ◽  
Author(s):  
R. Lovibond ◽  
R.J. Suttill ◽  
J.E. Skinner ◽  
A.N. Aburas
Keyword(s):  
Early Cretaceous ◽  
Seismic Data ◽  
Oil And Gas ◽  
Direct Detection ◽  
Source Rocks ◽  
Well Control ◽  
Potential Reservoir ◽  
Half Graben ◽  
History Of

The Penola Trough is an elongate, Late Jurassic to Early Cretaceous, NW-SE trending half graben filled mainly with synrift sediments of the Crayfish Group. Katnook-1 discovered gas in the basal Eumeralla Formation, but all commercial discoveries have been within the Crayfish Group, particularly the Pretty Hill Formation. Recent improvements in seismic data quality, in conjunction with additional well control, have greatly improved the understanding of the stratigraphy, structure and hydrocarbon prospectivity of the trough. Strati-graphic units within the Pretty Hill Formation are now mappable seismically. The maturity of potential source rocks within these deeper units has been modelled, and the distribution and quality of potential reservoir sands at several levels within the Crayfish Group have been studied using both well and seismic data. Evaluation of the structural history of the trough, the risk of a late carbon dioxide charge to traps, the direct detection of gas using seismic AVO analysis, and the petrophysical ambiguities recorded in wells has resulted in new insights. An important new play has been recognised on the northern flank of the Penola Trough: a gas and oil charge from mature source rocks directly overlying basement into a quartzose sand sequence referred to informally as the Sawpit Sandstone. This play was successfully tested in early 1994 by Wynn-1 which flowed both oil and gas during testing from the Sawpit Sandstone. In mid 1994, Haselgrove-1 discovered commercial quantities of gas in a tilted Pretty Hill Formation fault block adjacent to the Katnook Field. These recent discoveries enhance the prospectivity of the Penola Trough and of the Early Cretaceous sequence in the wider Otway Basin where these sediments are within reach of the drill.

BURIAL HISTORY OF THE EASTERN OFFICER BASIN, SOUTH AUSTRALIA

1995 ◽  
Vol 35 (1) ◽  
pp. 307 ◽  
Author(s):  
R. Moussavi-Harami ◽  
D. I. Gravestock
Keyword(s):  
South Australia ◽  
Bounded Sequence ◽  
Source Rocks ◽  
Sediment Loading ◽  
Burial History ◽  
Fine Grained ◽  
Accommodation Space ◽  
The North ◽  
History Of ◽  
Well Data

The intracratonic Officer Basin of central Australia was formed during the Neoproterozoic, approximately 820 m.y. ago. The eastern third of the Officer Basin is in South Australia and contains nine unconformity-bounded sequence sets (super-sequences), from Neoproterozoic to Tertiary in age. Burial history is interpreted from a series of diagrams generated from well data in structurally diverse settings. These enable comparison between the stable shelf and co-existing deep troughs. During the Neoproterozoic, subsidence in the north (Munyarai Trough) was much higher than in either the south (Giles area) or northeast (Manya Trough). This subsidence was related to tectonic as well as sediment loading. During the Cambrian, subsidence was much higher in the northeast and was probably due to tectonic and sediment loading (carbonates over siliciclastics). During the Early Ordovician, subsidence in the north created more accommodation space for the last marine transgression from the northeast. The high subsidence rate of Late Devonian rocks in the Munyarai Trough was probably related to rapid deposition of fine-grained siliciclastic sediments prior to the Alice Springs Orogeny. Rates of subsidence were very low during the Early Permian and Late Jurassic to Early Cretaceous, probably due to sediment loading rather than tectonic sinking. Potential Neoproterozoic source rocks were buried enough to reach initial maturity at the time of the terminal Proterozoic Petermann Ranges Orogeny. Early Cambrian potential source rocks in the Manya Trough were initially mature prior to the Delamerian Orogeny (Middle Cambrian) and fully mature on the Murnaroo Platform at the culmination of the Alice Springs Orogeny (Devonian).

PRE-EOCENE STRATIGRAPHY, STRUCTURE, AND PETROLEUM POTENTIAL OF THE BASS BASIN

1985 ◽  
Vol 25 (1) ◽  
pp. 362 ◽  
Author(s):  
P.E. Williamson ◽  
C.J. Pigram ◽  
J.B. Colwell ◽  
A.S. Scherl ◽  
K.L. Lockwood ◽  
...  
Keyword(s):  
Mineral Resources ◽  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Seismic Survey ◽  
Normal Faults ◽  
Petroleum Potential ◽  
Northerly Direction ◽  
Potential Reservoir ◽  
Well Data ◽  
Coal Measures

Exploration in the Bass Basin has mainly concentrated on the Eocene part of the Eastern View Coal Measures with the pre-Eocene stratigraphy hardly being tested. Structural mapping using a good quality Bureau of Mineral Resources regional seismic survey and infill industry seismic data, in conjunction with seismic stratigraphy and well data, has generated an understanding of the structure and stratigraphy of the pre- Eocene basin, which suggests that exploration potential exists in structural and stratigraphic leads of both Paleocene and Cretaceous age.The Paleocene structure is influenced by the reactivation of normal faults developed at the time of the mid Cretaceous rift unconformity and reflects drape over deeper features. Consequently fault dependent structural closures often persist from Paleocene to (?)Jurassic levels. Possible stratigraphic traps are also observed against horst blocks and around the basin margins. The longitudinal fault directions are northwest and west northwest with an oblique northerly direction and a prevailing north northeasterly transverse direction.The Paieocene and Upper Cretaceous part of the Eastern View Coal Measures consists of sands, shales and coals deposited in alluvial fans, on flood plains, and in lakes. These are underlain by Early Cretaceous Otway Groups, sands, shales and volcanics. Both intervals have potential reservoir and source rocks and often occur at mature depths. No pre-Otway Group sediments have been encountered in wells in the Bass Basin. However, the Permo- Carboniferous and possibly Triassic strata that occur in Northern Tasmania exhibit reservoir and source rock potential and may extend offshore beneath the Bass Basin.Pre-Eocene structural and stratigraphic studies of the Bass Basin thus point to reservoir and hydrocarbon source potential for possible multiple hydrocarbon exploration targets.

A History of Research on Hunter Fault System or "Lineament"

1987 ◽  
Vol 6 (2) ◽  
pp. 205-213 ◽  
Author(s):  
J. Dickins
Keyword(s):  
New South ◽  
Fault System ◽  
Upper Permian ◽  
Tectonic Movement ◽  
The North ◽  
History Of Research ◽  
South Wales ◽  
Unpublished Thesis ◽  
History Of ◽  
Coal Measures

The Hunter Fault System or "Lineament" separates the Permian and Triassic of Sydney Basin in New South Wales from the relatively complicated region to the north and east with exposed Carboniferous and older rocks and an increasing amount of identified Permian. David in his inimitable fashion grasped the essentials in 1907. He noted that the fold movements began towards the end of the Upper Permian with an important phase between the Upper Coal Measures and the Narrabeen Series. He also noted the main north-south component. The interest kindled by David was reflected in the work of Browne, Carey, Osborne, Raggatt, and Voisey. These workers established that the Carboniferous was affected by tectonic movement prior to the Permian and that the main ("orogenic") folding of the Permian/Triassic began with deposition of the Muree Formation and continued during the Upper Permian with overthrusting at the end of the Permian followed by strong rotational stress. This entire episode was called the Hunter-Bowen Movement by Carey and Browne in 1938. They also noted that the area of the subsequently developed Sydney Basin supplied sediment in the Carboniferous to the north and east. Raggatt, in his unpublished thesis of 1938 had already concluded that increasing compression led to upthrusting and eventually to torsion. Much of this seems to have been lost sight of in recent work. Current work confirms that the Permian/Triassic folding began with the Muree and that prior to this in the Permian a northwest to southeast graben was present to the south and west of the Hunter structure. Prior to the Permian the area of the Sydney Basin supplied detritus in the Carboniferous north and east of the Hunter structure apparently indicating a long-lived structure or lineament on which a reversal of movement took place.

scholarly journals IV.—The Age of the “Pennine Chain.”

1879 ◽  
Vol 6 (11) ◽  
pp. 500-504
Author(s):  
E. Wilson
Keyword(s):  
The Other ◽  
The South ◽  
The West ◽  
The North ◽  
History Of ◽  
The One ◽  
Coal Measures ◽  
Hilly Tract

The “Pennine Chain” is the name (restored about fifty years ago by Conybeare and Phillips from the “Alpes Penini” of the Romans) for that hilly tract of country that stretches from the borders of Scotland on the North to the centre of Derbyshire on the South. This important range possesses the structure of a great, though complex, anticlinal, the result of a meridional movement of upheaval that took place at a remote period in the physical history of our island.This axis of elevation, which ranges a little west of Narth through North Derbyshire and Yorkshire, throws off the Coal-measures of Yorkshire and Derbyshire on the one side, and those of Lancashire and North Staffordshire on the other, with a steeper did on the West, and a gentler inclination on the East. The maximum of this upheaval is attained in North Derbyshire, where a dome-shaped mass of Mountain Limestone has been exposed at the surface at an altitude of 1500 feet above the sea.

scholarly journals Source rocks

1982 ◽  
Vol 8 ◽  
pp. 73-86
Author(s):  
Holger Lindgreen ◽  
Erik Thomsen ◽  
Per Wrang
Keyword(s):  
Source Rock ◽  
North Sea ◽  
Oil Fields ◽  
Source Rocks ◽  
Published Data ◽  
The North ◽  
East Midlands ◽  
The North Sea ◽  
Northern North Sea ◽  
Coal Measures

Little has been published on source rocks of Paleozoic and Mesozoic ages in the North Sea. Gas in many fields of the southern North Sea is known to originate from Late Carboniferous Coal Measures, (Eames 1975). In the East Midlands area of England, the oil in Carboniferous reservoirs is believed to originate from Carboniferous rocks (Bernard & Cooper 1981). Several papers published on the oil fields in the southern and northern North Sea suggest a Late Jurassic source rock (see review by Weismann 1979 and Bernard & Cooper 1981). Also Early and Middle Jurassic shales are suggested as possible source rocks in parts of the North Sea (Fuller 1975, Oudin 1976). Published data on source rock conditions in the Danish sector is limited to Weismann (1979).

Northern Houtman Sub-basin prospectivity—preliminary results

2016 ◽  
Vol 56 (2) ◽  
pp. 577
Author(s):  
Irina Borissova ◽  
Chris Southby ◽  
George Bernardel ◽  
Jennifer Totterdell ◽  
Robbie Morris ◽  
...  
Keyword(s):  
Seismic Data ◽  
Source Rocks ◽  
Large Igneous Province ◽  
The North ◽  
Structural Style ◽  
Igneous Province ◽  
Line Spacing ◽  
History Of

In 2014–15 Geoscience Australia acquired 3,300 km of deep 2D seismic data over the northern part of the Houtman Sub-basin (Perth Basin). Prior to this survey, this area had a very sparse coverage of 2D seismic data with 50–70 km line spacing in the north and an industry grid with 20 km line spacing in the south. Initial interpretation of the available data has shown that the structural style, major sequences, and potential source rocks in this area are similar to those in the southern Houtman and Abrolhos sub-basins. The major difference between these depocentres, however, is in the volume and distribution of volcanic and intrusive igneous rocks. The northern part of the Houtman Sub-basin is adjacent to the Wallaby Plateau Large Igneous Province (LIP). The Wallaby Plateau and the Wallaby Saddle, which borders the western flank of the Houtman Sub-basin, had active volcanism from the Valanginian to at least the end of the Barremian. Volcanic successions significantly reduce the quality of seismic imaging at depth, making it difficult to ascertain the underlying thickness, geometry and structure of the sedimentary basin. The new 2D seismic dataset across the northern Houtman Sub-basin provides an opportunity for improved mapping of the structure and stratigraphy of the pre-breakup succession, assessment of petroleum prospectivity, and examination of the role of volcanism in the thermal history of this frontier basin.

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