Geology and hydrocarbon prospectivity of the northern Houtman Sub-basin

2017 ◽  
Vol 57 (2) ◽  
pp. 709 ◽  
Author(s):  
Irina Borissova ◽  
Chris Southby ◽  
Lisa Hall ◽  
Emma Grosjean ◽  
George Bernardel ◽  
...  
Keyword(s):  
Source Rock ◽  
Seismic Data ◽  
Systems Analysis ◽  
Lower Triassic ◽  
Multiple Source ◽  
Hydrocarbon Potential ◽  
Seismic Sequence ◽  
Regional Mapping ◽  
Petroleum Systems ◽  
Half Graben

New 2D seismic data acquired by Geoscience Australia in the northern Houtman Sub-basin of the Perth Basin provides important information on the prospectivity of this frontier area. To date, lack of quality seismic data and limited geological understanding have led to the perception that the hydrocarbon potential of the area is very low. However, interpretation of newly collected data suggests that the northern Houtman depocentre contains up to 15 km of pre-breakup sediments comprised of Permian, Triassic and Jurassic successions, which potentially contain multiple source rock, reservoir and seal intervals. The Permian syn-rift succession is confined to a series of large half-graben that are controlled by basement-involved faults separating the Houtman depocentre from the Bernier Platform. This succession is up to 10 km thick and is mapped throughout the inboard part of the new seismic grid. A prominent unconformity at the top of the Permian syn-rift sequence is overlain by a thick (up to 1800 m) and regionally extensive seismic sequence interpreted as the Lower Triassic Kockatea Shale. The thickness of the overlying Triassic succession ranges from approximately 1 km in the inboard part of the basin to up to 5 km further outboard. The Jurassic succession is thickest (up to 4 km) in the outboard part of the basin and is interpreted to contain sequences corresponding to the Cattamarra, Cadda and Yarragadee formations. Our study integrates new results from regional mapping, geophysical modelling and petroleum systems analysis, which enables a more accurate prospectivity assessment of this frontier basin.

Petroleum Systems Analysis of The Tungkal PSC Area, South Sumatra – A Means of Adding New Life to A Mature Area

2020 ◽  
Author(s):  
A. Livsey
Keyword(s):  
Seismic Data ◽  
Systems Analysis ◽  
Generation Model ◽  
Hydrocarbon Accumulation ◽  
Petroleum Systems ◽  
Oil Generation ◽  
Exploration Risk ◽  
Exploration Area ◽  
Hydrocarbon Charge ◽  
Surface Geology

South Sumatra is considered a mature exploration area, with over 2500MMbbls of oil and 9.5TCF of gas produced. However a recent large gas discovery in the Kali Berau Dalam-2 well in this basin, highlights that significant new reserve additions can still be made in these areas by the re-evaluation of the regional petroleum systems, both by identification of new plays or extension of plays to unexplored areas. In many mature areas the exploration and concession award history often results in successively more focused exploration programmes in smaller areas. This can lead to an increased emphasis on reservoir and trap delineation without further evaluation of the regional petroleum systems and, in particular, the hydrocarbon charge component. The Tungkal PSC area is a good example of an area that has undergone a long exploration history involving numerous operators with successive focus on block scale petroleum geology at the expense of the more regional controls on hydrocarbon prospectivity. An improved understanding of hydrocarbon accumulation in the Tungkal PSC required both using regional petroleum systems analysis and hydrocarbon charge modelling. While the Tungkal PSC operators had acquired high quality seismic data and drilled a number of wells, these were mainly focused on improving production from the existing field (Mengoepeh). More recent exploration-driven work highlighted the need for a new look at the hydrocarbon charge history but it was clear that little work had been done in the past few year to better understand exploration risk. This paper summarises the methodology employed and the results obtained, from a study, carried out in 2014-15, to better understand hydrocarbon accumulation within the current Tungkal PSC area. It has involved integration of available well and seismic data from the current and historical PSC area with published regional paleogeographic models, regional surface geology and structure maps, together with a regional oil generation model. This approach has allowed a better understanding of the genesis of the discovered hydrocarbons and identification of areas for future exploration interest.

A quantitative approach to regional screening of petroleum systems, Westralian Superbasin

2015 ◽  
Vol 55 (2) ◽  
pp. 401
Author(s):  
Christopher Paschke ◽  
Rob K. Sawyer ◽  
Catherine Belgarde ◽  
Chris Yarborough ◽  
Christina Huenink
Keyword(s):  
Source Rock ◽  
Systems Analysis ◽  
Regional Scale ◽  
Source Rocks ◽  
Regional Study ◽  
Seismic Line ◽  
Petroleum Systems ◽  
Reflection Seismic ◽  
Stratigraphic Position

The greater Westralian Superbasin comprises multiple petroleum systems ranging in age from the Early Paleozoic to the Paleogene (Bradshaw et al, 1994). A subset of these systems is typified by marine incursions with a deposition of liquids-prone source rocks. Variability in Westralian sediment fill and source rock stratigraphic position can be demonstrated on a continuous mega-regional 2D deep reflection seismic line that extends from Carnarvon through Browse and into the Bonaparte Basin. Beginning in 2013, BHP Billiton initiated a comprehensive regional study of the Westralian margin to better risk existing and new play fairways. From this work, a hydrocarbon systems analysis from the Dampier Sub-basin and its application for exploration as a regional analogue is described. From a compilation of both open-file and proprietary data, a subset of Dampier well penetrations was chosen, based on the quality of available source rock data. 1D models were constructed and thermally calibrated to BHP Billiton’s recent re-interpretation of the sub-regional crustal architecture. The ultimate expelled petroleum (UEP) was calculated at each well and then extrapolated regionally to determine the total basin hydrocarbon potential. Maturity of the source rock is described using the state of thermal stress (STS) parameter (Pepper and Corvi, 1995). Compared with more data- and labour-intensive 3D basin modelling, integration of 1D basin models, UEP and STS parameters allow for a rapid quantitative and regional-scale basin analysis. Using this workflow in data-constrained basins like the Dampier Sub-basin serves as an important analogue for assessing and risking petroleum systems in both of the established and frontier portions of the Australian margin.

Petroleum systems analysis of the northern Houtman Sub-basin

2017 ◽  
Vol 57 (2) ◽  
pp. 755 ◽  
Author(s):  
Lisa Hall ◽  
Emmanuelle Grosjean ◽  
Irina Borissova ◽  
Chris Southby ◽  
Ryan Owens ◽  
...  
Keyword(s):  
Systems Analysis ◽  
Source Rocks ◽  
Rock Properties ◽  
Hydrocarbon Generation ◽  
Petroleum Systems ◽  
Systems Model ◽  
Potential Source ◽  
Lithospheric Extension ◽  
Half Graben ◽  
Potential Field Modelling

Interpretation of newly acquired seismic data in the northern Houtman Sub-basin (Perth Basin) suggests the region contains potential source rocks similar to those in the producing Abrolhos Sub-basin. The regionally extensive late Permian–Early Triassic Kockatea Shale has the potential to contain the oil-prone Hovea Member source interval. Large Permian syn-rift half-graben, up to 10 km thick, are likely to contain a range of gas-prone source rocks. Further potential source rocks may be found in the Jurassic–Early Cretaceous succession, including the Cattamarra Coal Measures, Cadda shales and mixed sources within the Yarragadee Formation. This study investigated the possible maturity and charge history of these different source rocks. A regional pseudo-3D petroleum systems model was constructed using new seismic interpretations. Heat flow was modelled using crustal structure and possible basement composition determined from potential field modelling, and subsidence analysis was used to investigate lithospheric extension through time. The model was calibrated using temperature and maturity data from nine wells in the Houtman and Abrolhos sub-basins. Source rock properties are assigned based on an extensive review of total organic carbon, Rock Eval and kinetic data for the offshore northern Perth Basin. Petroleum systems analysis results show that Permian, Triassic and Early Jurassic source rocks may have generated large cumulative volumes of hydrocarbons across the northern Houtman Sub-basin, whereas the Middle Jurassic–Cretaceous sources remain largely immature. However, the timing of hydrocarbon generation and expulsion with respect to trap formation and structural reactivation is critical for the successful development and preservation of hydrocarbon accumulations.

Geochemical underpinnings of Australia's offshore hydrocarbon prospectivity

2014 ◽  
Vol 54 (1) ◽  
pp. 415
Author(s):  
Marita Bradshaw ◽  
Dianne Edwards ◽  
Chris Boreham ◽  
Emmanuelle Grosjean ◽  
Jennifer Totterdell ◽  
...  
Keyword(s):  
Source Rock ◽  
Lower Triassic ◽  
Source Rocks ◽  
Petroleum Systems ◽  
Isotopic Analyses ◽  
Marine Source ◽  
History Of ◽  
Hydrocarbon Sources ◽  
Geochemical Analyses ◽  
Gippsland Basin

Molecular and isotopic analyses of oils and gases can provide information on the depositional environment, maturation and age of their source rocks, and the post expulsion history of the hydrocarbons generated. Source rock analyses can determine their potential to generate hydrocarbons of varying type over specific thermal ranges, as well as demonstrating the strength of oil- or gas-to-source correlations. Together, this geochemical interpretation can provide insights about the extent of petroleum systems and can help delineate the relationships between hydrocarbon occurrences in a basin and across the continent. Oils that do not fit the well-established framework of oil families and Australian petroleum systems point to new source rock fairways. Examples include vagrant oils with lacustrine affinities found at various locations on the western Australian margin. Other examples are oil occurrences in the Gippsland Basin whose geochemical signatures contrast with the dominant non-marine oils, supporting the existence of a viable marine source rock facies. In under-explored and frontier basins, geochemical analyses of potential source rocks can provide key evidence to underpin new exploration efforts. For example, the recent acreage uptake in the Bight Basin was supported by Geoscience Australia’s recovery and analysis of oil-prone marine source rocks, and in the northern Perth Basin by new geochemical analysis extending the distribution of Lower Triassic Hovea marine source rocks offshore. Geoscience Australia has now embarked on a regional petroleum geological program that includes a national source rock study aimed at identifying and characterising Australia’s hydrocarbon sources, families and 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.

scholarly journals Integrated petroleum systems analysis to understand the source of fluids in the Browse Basin, Australia

2017 ◽  
Vol 57 (2) ◽  
pp. 781 ◽  
Author(s):  
Tehani Palu ◽  
Lisa Hall ◽  
Emmanuelle Grosjean ◽  
Dianne Edwards ◽  
Nadege Rollet ◽  
...  
Keyword(s):  
Source Rock ◽  
Systems Analysis ◽  
Saturation Pressure ◽  
Phase Behaviour ◽  
Dew Point ◽  
Source Rocks ◽  
Fluid Composition ◽  
Burial History ◽  
Terrestrial Organic Matter ◽  
Petroleum Systems

The Browse Basin is located offshore on Australia’s North West Shelf and is a proven hydrocarbon province, hosting gas with associated condensate in an area where oil reserves are typically small. The assessment of a basin’s oil potential traditionally focuses on the presence or absence of oil-prone source rocks. However, light oil can be found in basins where source rocks are gas-prone and the primary hydrocarbon type is gas-condensate. Oil rims form whenever such fluids migrate into reservoirs at pressures less than their dew point (saturation) pressure. By combining petroleum systems analysis with geochemical studies of source rocks and fluids (gases and liquids), four Mesozoic petroleum systems have been identified in the basin. This study applies petroleum systems analysis to understand the source of fluids and their phase behaviour in the Browse Basin. Source rock richness, thickness and quality are mapped from well control. Petroleum systems modelling that integrates source rock property maps, basin-specific kinetics, 1D burial history models and regional 3D surfaces, provides new insights into source rock maturity, generation and expelled fluid composition. The principal source rocks are Early–Middle Jurassic fluvio-deltaic coaly shales and shales within the J10–J20 supersequences (Plover Formation), Middle–Late Jurassic to Early Cretaceous sub-oxic marine shales within the J30–K10 supersequences (Vulcan and Montara formations) and K20–K30 supersequences (Echuca Shoals Formation). These source rocks contain significant contributions of terrestrial organic matter, and within the Caswell Sub-basin, have reached sufficient maturities to have transformed most of the kerogen into hydrocarbons, with the majority of expulsion occurring from the Late Cretaceous until present.

Novel geometric classification of 3D seismic and its application to the Habshan clinoforms of Western Oman

2021 ◽  
Vol 40 (3) ◽  
pp. 186-192
Author(s):  
Thomas Krayenbuehl ◽  
Nadeem Balushi ◽  
Stephane Gesbert
Keyword(s):  
Sequence Stratigraphy ◽  
Seismic Data ◽  
Northwestern Part ◽  
Full Potential ◽  
Seismic Sequence ◽  
3D Seismic ◽  
Level Curve ◽  
Seismic Sequence Stratigraphy

The principles and benefits of seismic sequence stratigraphy have withstood the test of time, but the application of seismic sequence stratigraphy is still carried out mostly manually. Several tool kits have been developed to semiautomatically extract dense stacks of horizons from seismic data, but they stop short of exploiting the full potential of seismo-stratigraphic models. We introduce novel geometric seismic attributes that associate relative geologic age models with seismic geomorphological models. We propose that a relative sea level curve can be derived from the models. The approach is demonstrated on a case study from the Lower Cretaceous Kahmah Group in the northwestern part of Oman where it helps in sweet-spotting and derisking elusive stratigraphic traps.

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