New exploration opportunities in the offshore northern Perth Basin

2011 ◽  
Vol 51 (1) ◽  
pp. 45 ◽  
Author(s):  
Andrew Jones
Keyword(s):  
Seismic Data ◽  
Petroleum System ◽  
Residual Oil ◽  
Contributing Factors ◽  
Sequence Stratigraphic ◽  
Stratigraphic Framework ◽  
Stratigraphic Model ◽  
Half Graben ◽  
Age Constraints ◽  
Insight Into

The petroleum prospectivity of the northern Perth Basin has been assessed by Geoscience Australia (GA) as part of the Australian Government’s Offshore Energy Security Program, in support of the 2011 offshore acreage release. This assessment includes the first published synthesis of data from fourteen new field wildcat wells drilled in this part of the basin since the Cliff Head 1 discovery (2001), and the interpretation of new regional 2D seismic data acquired during GA survey 310. Most petroleum accumulations in the northern Perth Basin are associated with Permian and Triassic source and reservoir intervals, and are found onshore and nearshore (ie. Cliff Head, Frankland, Dunsborough and Perseverance discoveries). In addition to the technical and commercial successes, numerous wells in the offshore part of the basin have intersected residual oil columns indicative of trap breach. New and legacy palynological data from Permian to Cretaceous strata in offshore wells have been used to provide age constraints for a sequence stratigraphic framework for this part of the basin. New seismic data show Permo-Triassic strata that are stratigraphic equivalents of the productive onshore and nearshore Perth Basin petroleum system, also occur within Permian half-graben in the outer Abrolhos and Houtman sub-basins. Source rock, oil stain and fluid inclusion sampling from this interval suggest that the proven onshore petroleum system is also effective in the offshore. A refined tectono-stratigraphic model for the offshore basin provides insights into basin evolution, prospectivity and contributing factors driving trap breach. Geochemical sampling in the context of the new detailed sequence framework, including from recently dredged rock samples from incised canyons, has also provided insight into the potential effectiveness of a Jurassic/Cretaceous petroleum system in the Houtman and Zeewyck sub-basins.

Sedimentary Microfacies Analysis of Xingbei 1-3 Zone in Daqing Oilfield

2013 ◽  
Vol 734-737 ◽  
pp. 436-439
Author(s):  
Bai Quan Yan ◽  
Xue Jing Ma ◽  
Li Hui Yuan ◽  
Gui Pu Jing
Keyword(s):  
Spatial Distribution ◽  
High Resolution ◽  
Microfacies Analysis ◽  
Residual Oil ◽  
Body Type ◽  
Sequence Stratigraphic ◽  
Stratigraphic Framework ◽  
Sand Body ◽  
Sedimentary Microfacies ◽  
Oilfield Development

Putaohua reservoir is the principal producing formation in Daqing oilfield Xingbei block. The spatial distribution of single sand body is particularly important for the residual oil tapping in the middle-late stage of oilfield development. The paper studied sedimentary microfacies of Putaohua reservoirs in the zone, established high-resolution sequence stratigraphic framework of the area and a typical single sand body logging phase mode on the basis of logging features, finely portrayed single sand body type and spatial distribution on this basis to lay the solid geological foundation for oilfield subsequent residual oil tapping and provide a scientific geology guide.

Daqing Oilfield Sanan Putaohua Reservoir Sedimentary Microfacies Research

2013 ◽  
Vol 321-324 ◽  
pp. 886-889
Author(s):  
Bai Quan Yan ◽  
Dong Zhang ◽  
Er Shuang Gao
Keyword(s):  
Spatial Distribution ◽  
High Resolution ◽  
Late Stage ◽  
Residual Oil ◽  
Body Type ◽  
Sequence Stratigraphic ◽  
Stratigraphic Framework ◽  
Sand Body ◽  
Sedimentary Microfacies ◽  
Oilfield Development

Putaohua reservoir is the principal producing formation in the Daqing oilfield sanan block. The spatial distribution of single sand body is particularly important for the residual oil tapping in the middle-late stage of oilfield development. The paper studied sedimentary microfacies of Putaohua reservoir in the area, established high-resolution sequence stratigraphic framework of the area and a typical single sand body logging phase mode on the basis of logging features, finely portrayed single sand body type and spatial distribution on this basis, laied the solid geological foundation for the oilfield subsequent residual oil tapping, provided a scientific geosteering.

scholarly journals The Billund delta: a possible new giant aquifer in central and western Jutland

2004 ◽  
Vol 4 ◽  
pp. 21-24 ◽  
Author(s):  
Erik S. Rasmussen ◽  
Karen Dybkjær ◽  
Stefan Piasecki
Keyword(s):  
Drinking Water ◽  
High Resolution ◽  
Water Supply ◽  
Seismic Data ◽  
Saline Water ◽  
Shallow Groundwater ◽  
Coarse Grained ◽  
Sequence Stratigraphic ◽  
Drinking Water Resources ◽  
Stratigraphic Model

The search for new, deep-seated drinking water resources in Denmark has increased significantly during the past five years as a result of the discovery of excessive amounts of nitrate, pesticides and other pollutants in shallow groundwater boreholes (e.g. Nygaard et al. 2004, this volume). To find and map these aquifers, a multidisciplinary sequence stratigraphic approach has successfully been applied to the Miocene deposits of southern Jutland, where especially the Odderup and Ribe Formations are known as a main aquifer for drinking water from several test wells (Rasmussen et al. 2002). Recently, a more systematic study of the Miocene succession in central and western Jutland has been initiated by the Geological Survey of Denmark and Greenland (GEUS) under contract with local authorities. It includes detailed sedimentological descriptions of outcrops, sedimentological andlog-interpretations of new stratigraphic boreholes and interpretation of new high-resolution seismic data (Fig. 1). A number of outcrops and wells have been studied palynologically, resulting in a detailed dinoflagellate cyst stratigraphy and in palynofacies interpretations. The results of these studies have been integrated in the regional geological and stratigraphic model (Fig. 2). Two new aquifers have been discovered: the Bastrup sand and the Billund sand. The Bastrup sand has already been exploited as a main aquifer in central and southern Jutland, and has been referred to either the Ribe or Odderup Formations. However, new stratigraphic results reveal that the Bastrup sand is a separate unit in the Miocene succession. The Billund sand is a deep-seated aquifer located more than 100 m and often more than 150 m deep, and is therefore not penetrated by standard water supply wells which rarely reach c. 100 m. The Billund sand was first revealed by multichannel seismic data deriving from former oil-exploration carried out in the Billund area (Fig. 3A). The resolution of these seismic data is very poor, but one interpretation of the dipping reflectors (clinoforms) seen in Fig. 3A was of a delta complex. This agrees with outcrop studies along the fjords of eastern Jutland which suggest that a spit complex was deposited in this area during the Early Miocene. The Billund sand was tested by the Vandel Mark well in 2001, which penetrated c. 40 m of sand at a depth of 200 m. The presence of a regional major sand body was later confirmed by new high-resolution seismic data and by the Billund and Løvlund wells in 2002. The Billund well penetrated 50 m of medium- to coarse-grained sand, and chemical tests of the water quality were good. However, a water supply well at Fjand in western Jutland has had problems with so-called ‘brown water’ – water enriched in organic matter (humus). Saline water may also be expected close to older deep-seated faults. This paper summarises the results of a mapping programme of the Billund sand initiated in the summer of 2003.

scholarly journals Model of the structure of upper Miocene productive deposits odoptu area of the Okhotsk sea

2017 ◽  
pp. 48-53
Author(s):  
A. L. Volkonskaya ◽  
I. N. Kerusov ◽  
A. I. Konyukhov ◽  
E. E. Karnyushina ◽  
O. V. Krylov ◽  
...  
Keyword(s):  
Seismic Data ◽  
Sedimentary Cover ◽  
Research Area ◽  
Okhotsk Sea ◽  
Sea Level Changes ◽  
Sequence Stratigraphic ◽  
Stratigraphic Model ◽  
Integrated Interpretation ◽  
Model Graph ◽  
Geochronological Scale

Using the example of lower nutovsky thickness on Odoptu field discusses the possibility and efficacy of sequence-stratigraphic approach to integrated interpretation of seismic data and drilling materials. Sequence stratigraphic model, graph showing sea level changes and regional chronostratigraphic correlation chart with reference to the existing geochronological scale was developed for the formation of the sedimentary cover in the research area.

A NEW SEQUENCE FRAMEWORK FORTHE GREAT AUSTRALIAN BIGHT: STARTING WITH A CLEAN SLATE

2000 ◽  
Vol 40 (1) ◽  
pp. 95 ◽  
Author(s):  
J.M. Totterdell ◽  
J.E. Blevin ◽  
H.I.M. Struckmeyer ◽  
B.E. Bradshaw ◽  
J.B. Colwell ◽  
...  
Keyword(s):  
Source Rocks ◽  
Petroleum Exploration ◽  
Blue Whale ◽  
Growth Strata ◽  
Sequence Stratigraphic ◽  
Petroleum Systems ◽  
Lithospheric Extension ◽  
Stratigraphic Model ◽  
Half Graben ◽  
Great Australian Bight

The 1999 release of offshore petroleum exploration acreage in the Great Australian Bight and the acquisition of high quality seismic datasets covering the Bight and Duntroon Basins, have provided a timely opportunity to reassess the stratigraphic and tectonic evolution of the area. A sequence stratigraphic framework for the Great Australian Bight region has been developed based on the interpretation of exploration wells in the Bight and Duntroon basins and a grid of new and reprocessed seismic data in the Bight Basin. Previous formation-based nomenclature has emphasised lithostratigraphic correlations rather than the chronostratigraphic relationships. The new sequence framework underpins an analysis of play elements and petroleum systems and is helping to identify new exploration opportunities.Deposition in the Bight and Duntroon Basins commenced in the Late Jurassic during a period of lithospheric extension. Extensive half graben systems were filled with fluvial and lacustrine clastic sediments (Sea Lion and Minke supersequences). Potential source rocks within these supersequences are immature at Jerboa-1 in the Eyre Sub-basin, however higher maturities are expected within adjacent half graben and in the Ceduna and Recherche Sub-basins. The syn-rift successions are overlain by widespread Berriasian to Albian fluvio-lacustrine to marine sediments of the Southern Right and Bronze Whaler supersequences. The onlapping sag-fill geometry of these Early Cretaceous packages in the Eyre, Ceduna and inner Recherche Sub-basins suggests that they were deposited during a period of thermal subsidence.Accelerated subsidence commencing in the late Albian led to the deposition of the marine shales of the Blue Whale supersequence, followed by a period of gravity-controlled faulting and deformation in the Cenomanian. The White Pointer supersequence is characterised by growth strata associated with a series of listric faults that sole out in underlying ductile shales of the Blue Whale supersequence. Open marine conditions during the Turonian-Santonian (Tiger supersequence) were followed by the development of massive shelf margin delta complexes in the late Santonian-Maastrichtian (Hammerhead supersequence). The progradational to aggradational stratal geometries within the Hammerhead supersequence suggest initial high rates of sediment input that subsequently waned during this period. An overall transgressive phase of sedimentation in the Early Tertiary (Wobbegong supersequence) was followed by the establishment of open marine carbonate shelf conditions from the Early Eocene onward (Dugong supersequence). Organic geochemical studies show that the Bronze Whaler to White Pointer supersequences have good source rock potential in the relatively proximal facies intersected by existing petroleum exploration wells. Our sequence stratigraphic model predicts the likelihood of widespread late Aptian, Albian, Cenomanian-Santonian, and Campanian marine shales, which underpin four potential marine petroleum systems.

Deep Dive Into The Mesozoic Play Potential Beneath The Batui Thrust: A Case Study in The Offshore Matindok, The Eastern Arm of Sulawesi

2021 ◽  
Author(s):  
F. Bahesti
Keyword(s):  
Seismic Data ◽  
Seismic Energy ◽  
Petroleum System ◽  
Source Rocks ◽  
Hydrocarbon Potential ◽  
Deep Dive ◽  
Main Challenge ◽  
Half Graben ◽  
Risks Assessment

This article summarized the exploration ideas and methods for a closer look at the Mesozoic hydrocarbon potential in the Banggai Basin, offshore Matindok, Eastern Arm of Sulawesi. The area is one of the Pertamina EP’s working area which located in the frontier basin that has an acreage exceeding 10,000 sqkm. A major portion of the Mesozoic play in the basin is still under explored, whilst/whereas the existence of an active Cenozoic petroleum system in the offshore Matindok has been confirmed by Tiaka Producing Field. The main challenge in exploring the Mesozoic section in the Matindok Block is imaging it below the ophiolite complex / ultra-mafic layer of the Batui thrust, as well as the thick Neogene carbonate. These barriers inhibit the penetration of seismic energy that resulted in low-quality seismic data beneath the thrust. In order to generate its play concept, massive exploration efforts have been conducted in the Matindok Block since 2017. It consists of onshore geological fieldwork, high-resolution satellite data processing, and the new acquisition of shallow-marine transition 2D seismic data. Potential mature source rocks of the Triassic Tokala marine shale was found in the outcrops nearby the Batui thrust. In the seismic interpretation, the equivalent Jurassic to Cretaceous outcrops that dominated by the fluvio-deltaic sandstones, have been interpreted as pinched-out features along the margin of half graben structures. This area was compressed during the Late Miocene to Plio-Pleistocene shortening events, and intensively imbricated the Cenozoic to present-day sediments on the Batui thrust, but put the Paleozoic - Mesozoic half-grabens beneath the Batui thrust decollement. Finally, the finding of this study is able to demonstrate the petroleum-system risks assessment of the Mesozoic hydrocarbon potential.

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