Academic literature on the topic 'Stratigraphic Otway Basin (Vic'
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Journal articles on the topic "Stratigraphic Otway Basin (Vic"
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Arditto, P. A. "THE EASTERN OTWAY BASIN WANGERRIP GROUP REVISITED USING AN INTEGRATED SEQUENCE STRATIGRAPHIC METHODOLOGY." APPEA Journal 35, no. 1 (1995): 372. http://dx.doi.org/10.1071/aj94024.
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Recent exploration by BHP Petroleum in VIC/ P30 and VIC/P31, within the eastern Otway Basin, has contributed significantly to our understanding of the depositional history of the Paleocene to Eocene siliciclastic Wangerrip Group. The original lithostratigraphic definition of this group was based on outcrop description and subsequently applied to onshore and, more recently, offshore wells significantly basinward of the type sections. This resulted in confusing individual well lithostratigraphies which hampered traditional methods of subsurface correlation.A re-evaluation of the Wangerrip Group stratigraphy is presented based on the integration of outcrop, wireline well log, palynological and reflection seismic data. The Wangerrip Group can be divided into two distinct units based on seismic and well log character. A lower Paleocene succession rests conformably on the underlying Maastrichtian and older Sherbrook Group, and is separated from an overlying Late Paleocene to Eocene succession by a significant regional unconformity. This upper unit displays a highly progradational seismic character and is named here as the Wangerrip Megasequence.Regional seismic and well log correlation diagrams are used to illustrate a subdivision of the Wangerrip Megasequence into eight third-order sequences. This sequence stratigraphic subdivision of the Wangerrip Group is then used to construct a chronostratigraphic chart for the succession within this part of the Otway Basin.
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Cliff, D. C. B., S. C. Tye, and R. Taylor. "THE THYLACINE AND GEOGRAPHE GAS DISCOVERIES, OFFSHORE EASTERN OTWAY BASIN." APPEA Journal 44, no. 1 (2004): 441. http://dx.doi.org/10.1071/aj03017.
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The Thylacine and Geographe gas fields were discovered in mid-2001 in the offshore Otway Basin, in permits T/30P and VIC/P43 respectively. Geographe is 55 km south of Port Campbell and Thylacine is a further 15 km offshore, in the depo-centre of the Shipwreck Trough, in water depths of 80 m to 100 m. The Thylacine–1 well intersected a 277 m gas column in Turonian to Santonian aged reservoirs. Geographe–1 intersected a 233 m gas column in a similar sedimentary section. Thylacine–2, 5.7 km west of Thylacine–1, confirmed the field extent, and flowed gas at 28 MMSCFD (0.79 Mm3/D). Critical to the discovery of these fields was the Investigator 3D seismic survey, which covered about 1,000 km2 of the central Shipwreck Trough. The pre-drill chance of success of both structures was high-graded as a result of excellent structural imaging and the conformance of amplitude and AVO anomalies to mapped closures. The interpretation of this survey and the subsequent drilling of the Thylacine and Geographe Fields have dramatically increased the understanding of the structure and stratigraphy of the offshore eastern Otway Basin particularly in relation to the Shipwreck Trough and the Sorell Fault Zone.Combined dry gas reserves at the proved and probable level stand at 0.85 TCF and condensate reserves at 10.7 MMBBL. The fields are undergoing integrated sub-surface, development and environmental studies with the aim of supplying the nearby southeastern Australian gas markets. The preferred development concept is a small jacket structure at Thylacine, followed by a subsea tie-in of the Geographe Field with onshore processing facilities near Port Campbell.
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Karvelas, Alex, Tekena West, Chris Nicholson, Steve Abbott, George Bernardel, Cameron Mitchell, Duy Nguyen, Merrie-Ellen Gunning, Irina Borissova, and Oliver Schenk. "New insights into the deep-water Otway Basin – Part 2. Tectonostratigraphic framework revealed by new seismic data." APPEA Journal 61, no. 2 (2021): 657. http://dx.doi.org/10.1071/aj20092.
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The inboard areas of the Otway Basin, particularly the Shipwreck Trough, are well explored and a petroleum-producing province. However, outboard in water depths greater than 500m, the basin is underexplored with distant well control and sparse 2D reflection seismic data coverage. The presence of a successful petroleum province onshore and in shallow waters raises the question as to whether these plays may extend further outboard into the deep-water areas. In the deep-water area, structural complexity and poor imaging of events in the legacy seismic data have resulted in interpretation uncertainty and consequentially a high-risk profile for explorers. The 2020 Otway Basin seismic program acquired over 7000-line km of 2D reflection seismic data across the deep-water Otway Basin. In addition, over 10000km of legacy 2D seismic data were reprocessed to improve the tie between the inboard wells and the new seismic grid. This new dataset provides the first clear insight into the structural and stratigraphic framework of this frontier area, including better imaging of the sedimentary section and the lower crust, increased structural resolution and improved calibration of the outboard seismic reflectors via ties to the inboard wells. Interpretation of the new data has led to an improved assessment of the structural elements and the extension of regional supersequences into the deep-water areas. These refinements have been used as input into petroleum systems modelling work and will provide a foundation for future work to understand petroleum prospectivity, including the distribution of source, reservoir and seal facies.
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Luxton, C. W., S. T. Horan, D. L. Pickavance, and M. S. Durham. "THE LA BELLA AND MINERVA GAS DISCOVERIES, OFFSHORE OTWAY BASIN." APPEA Journal 35, no. 1 (1995): 405. http://dx.doi.org/10.1071/aj94026.
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In the past 100 years of hydrocarbon exploration in the Otway Basin more than 170 exploration wells have been drilled. Prior to 1993, success was limited to small onshore gas fields. In early 1993, the La Bella-1 and Minerva-1 wells discovered significant volumes of gas in Late Cretaceous sandstones within permits VIC/P30 and VIC/P31 in the offshore Otway Basin. They are the largest discoveries to date in the basin and have enabled new markets to be considered for Otway Basin gas. These discoveries were the culmination of a regional evaluation of the Otway Basin by BHP Petroleum which highlighted the prospectivity of VIC/P30 and VIC/P31. Key factors in this evaluation were:geochemical studies that indicated the presence of source rocks with the potential to generate both oil and gas;the development of a new reservoir/seal model; andimproved seismic data quality through reprocessing and new acquisition.La Bella-1 tested the southern fault block of a faulted anticlinal structure in the southeast corner of VIC/P30. Gas was discovered in two Late Cretaceous sandstone intervals of the Shipwreck Group (informal BHP Petroleum nomenclature). Reservoirs are of moderate to good quality and are sealed vertically, and by cross-fault seal, by Late Cretaceous claystones of the Sherbrook Group. The gas is believed to have been sourced from coals and shales of the Early Cretaceous Eumeralla Formation and the structure appears to be filled to spill as currently mapped. RFT samples recovered dry gas with 13 moI-% CO2 and minor amounts of condensate.Minerva-1 tested the northern fault block of a faulted anticline in the northwest corner of VIC/ P31. Gas was discovered in three excellent quality reservoir horizons within the Shipwreck Group. Late Cretaceous Shipwreck Group silty claystones provide vertical and cross-fault seal. The hydrocarbon source is similar to that for the La Bella accumulation and the structure appears to be filled to spill. A production test was carried out in the lower sand unit and flowed at a rig limited rate of 28.8 MMCFGD (0.81 Mm3/D) through a one-inch choke. The gas is composed mainly of methane, with minor amounts of condensate and 1.9 mol-% C02. Minerva-2A was drilled later in 1993 as an appraisal well to test the southern fault block of the structure to prove up sufficient reserves to pursue entry into developing gas markets. It encountered a similar reservoir unit of excellent quality, with a gas-water contact common with that of the northern block of the structure.The La Bella and Minerva gas discoveries have greatly enhanced the prospectivity of the offshore portion of the Otway Basin. The extension of known hydrocarbon accumulations from the onshore Port Campbell embayment to the La Bella-1 well location, 55 km offshore, demonstrates the potential of this portion of the basin.
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Kopsen, E., and T. Scholefield. "PROSPECTIVITY OF THE OTWAY SUPERGROUP IN THE CENTRAL AND WESTERN OTWAY BASIN." APPEA Journal 30, no. 1 (1990): 263. http://dx.doi.org/10.1071/aj89016.
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Recent hydrocarbon discoveries in the non-marine rift fill sequence of the Otway Basin at Windermere, Katnook and Ladbroke Grove have upgraded the importance of this relatively poorly known interval of the sedimentary column and provide hydrocarbon trapping models for future exploration. Using a seismic stratigraphic approach based on high resolution seismic data and the geological re-evaluation of many key early wells, a clearer pattern has emerged for the distribution of major reservoir and seal units.The best reservoirs occur in the Crayfish Group 'A', 'B' and 'D' units and the Windermere Member of the Lower Eumeralla Formation. One of the most critical elements in controlling the more prospective areas is the diagenetic characteristics of the main hydrocarbon objective units. Reservoir quality is significantly affected by the abundance or absence of volcanic detritus and depth of burial, and as a result, the most attractive reservoir is the Crayfish 'A' lying at depths shallower than 3000 m. Lateral fault seals and good vertical seals are present at various stratigraphic levels through the sequence for the development of effective traps in fault blocks and anticlines.The Casterton Group and the basal coal measures zone of the Lower Eumeralla Formation overlying the Windermere Member are identified as the most prospective oil sourcing units in the sequence. Secondary oil sourcing intervals occur within the Crayfish 'C' unit and at the top of the Lower Eumeralla Formation. A higher drilling success rate is now expected in the future with hydrocarbon fairways in the supergroup expected to comprise:Fault blocks and anticlines in the more basinal areas, e.g. the Katnook and Ladbroke Grove gas fields.The 'shoulders' of the main rift depocentres where fault traps will be most prevalent, e.g. the Kalangadoo CO2 discovery.Portions of the northern platform lying on migration pathways extending from the main graben (hydrocarbon kitchen) areas.
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Nicholson, Chris, Steve Abbott, George Bernardel, and Merrie-Ellen Gunning. "Stratigraphic framework and structural architecture of the Upper Cretaceous in the deep-water Otway Basin – implications for frontier hydrocarbon prospectivity." APPEA Journal 62, no. 2 (May 13, 2022): S467—S473. http://dx.doi.org/10.1071/aj21072.
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Geoscience Australia has undertaken a regional seismic mapping study that extends into the frontier deep-water region of the offshore Otway Basin. This work builds on seismic mapping and petroleum systems modelling published in the 2021 Otway Basin Regional Study. Seismic interpretation spans over 18 000 line-km of new and reprocessed data collected in the 2020 Otway Basin seismic program and over 40 000 line-km of legacy 2D seismic data. Fault mapping has resulted in refinement and reinterpretation of regional structural elements, particularly in the deep-water areas. Structure surfaces and isochron maps highlight Shipwreck (Turonian–Santonian) and Sherbrook (Campanian–Maastrichtian) supersequence depocentres across the deep-water part of the basin. These observations will inform the characterisation of petroleum systems within the Upper Cretaceous succession, especially in the underexplored deep-water region.
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Cooper, G. T., K. C. Hill, and M. Wlasenko. "THERMAL MODELLING IN THE EASTERN OTWAY BASIN." APPEA Journal 33, no. 1 (1993): 205. http://dx.doi.org/10.1071/aj92016.
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Vitrinite reflectance data across the Otway Ranges yield a thermal maturity map that indicates the presence of a broad NE-SW trending anticline with strong vergence to the southeast. Surface Rv max values for the central part of the ranges are >1.5 whilst those on both limbs decrease to Apatite fission track analysis of seven Eumeralla (Lower Cretaceous) samples from the coast around Wye River yields an AFTA age of 90±5 Ma, consistent with similar cooling ages measured around most of the SE Australia margin. Modelling of the data is consistent with a stratigraphic age of -100 Ma, rapid heating to −80°C for −5 Ma followed by cooling from 95–80 Ma and further cooling in the Miocene.Geologically the very large asymmetric anticline can be explained by inversion of a thick rift sequence along a major, listric northwest-dipping fault, perhaps soling at mid-crustal levels. This is consistent with structures observed offshore in the Torquay Embayment and is being tested by the AGSO deep seismic profile BMR 920T1. Observed gravity highs in the Otway Ranges may be associated with inverted high density sediments. Fission track analysis indicates that the major cooling was at −90 Ma, which is therefore likely to be the time of inversion. However, this implies compression during continental breakup, the mechanisms of which are not fully understood.
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Bendall, Betina, Anne Forbes, Dan Revie, Rami Eid, Shannon Herley, and Tony Hill. "New insights into the stratigraphy of the Otway Basin." APPEA Journal 60, no. 2 (2020): 691. http://dx.doi.org/10.1071/aj19035.
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The Otway Basin is one of the best known and most actively explored of a series of Mesozoic basins formed along the southern coastline of Australia by the rifting of the Antarctic and Australian plates during the Cretaceous. The basin offers a diversity of play types, with at least three major sedimentary sequences forming conventional targets for petroleum exploration in the onshore basin. The Penola Trough in South Australia has enjoyed over 20 years of commercial hydrocarbon production from the sandstones of the Early Cretaceous Otway Group comprising the Crayfish Subgroup (Pretty Hill Formation and Katnook sandstones) and Eumeralla Formation (Windermere Sandstone Member). Lithostratigraphic characterisation and nomenclature for these sequences are poorly constrained, challenging correlation across the border into the potentially petroleum prospective Victorian Penola Trough region. The Geological Survey of Victoria (GSV), as part of the Victorian Gas Program, commissioned Chemostrat Australia to undertake an 11-well chemostratigraphic study of the Victorian Otway Basin. The South Australia Department for Energy and Mining, GSV and Chemostrat Australia are working collaboratively to develop a consistent, basin-wide schema for the stratigraphic nomenclature of the Otway Basin within a chemostratigraphic framework. Variability in the mineralogy and hence inorganic geochemistry of sediments reflects changes in provenance, lithic composition, facies changes, weathering and diagenesis. This geochemical variation enables the differentiation of apparently uniform sedimentary successions into unique sequences and packages, aiding in the resolution of complex structural relationships and facies changes. In this paper, we present the preliminary results of detailed geochemical analyses and interpretation of 15 wells from across the Otway Basin and the potential impacts on hydrocarbon prospectivity.
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Lee, Si Ying, Bee Jik Lim, Arwindran Anantan, and Alexander Karvelas. "New insights into the deep-water Otway Basin – Part 1. Integrated depth imaging workflows unravelling the subsurface." APPEA Journal 61, no. 2 (2021): 652. http://dx.doi.org/10.1071/aj20100.
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The Otway Basin is a northwest-southeast trending passive margin rift basin over 500km long and forms part of the Jurassic-Cretaceous Australian Southern Rift System. Exploration for oil and gas has, to date, focused on the onshore shelfal portions targeting thick early Cretaceous depocentres. Outboard, under deep-water areas, potential hydrocarbon resources in thick late Cretaceous depocentres remain significantly under-explored, with limited sparse legacy 2D seismic lines and no wells drilled to date. As a result, little is known about the potential continuation of the proven hydrocarbon plays, or indeed the presence of new plays, in the outboard areas. The 2020 Otway Basin seismic program was carried out with the key objectives being to infill data gaps outboard through the acquisition of new 2D seismic lines and improve the quality of legacy datasets inboard through reprocessing. A comprehensive broadband processing and depth imaging workflow was designed to address the inherent subsurface challenges that have inhibited legacy imaging campaigns. The results of this seismic program are improving the interpretability of the full stratigraphic sequence whilst also unravelling deeper crustal elements. This is providing a better understanding of the distribution of regional stratigraphic sequences, both laterally across the basin, and from the shelf to deep-water areas for the first time. As a result, new insights are being gained on both the basin evolution and potential for working petroleum systems.
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Williamson, P. E., C. J. Pigram, J. B. Colwell, A. S. Scherl, K. L. Lockwood, and J. C. Branson. "PRE-EOCENE STRATIGRAPHY, STRUCTURE, AND PETROLEUM POTENTIAL OF THE BASS BASIN." APPEA Journal 25, no. 1 (1985): 362. http://dx.doi.org/10.1071/aj84031.
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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.
Dissertations / Theses on the topic "Stratigraphic Otway Basin (Vic"
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Moss, Graham 1957. "The Oligocene of southern Australia : ecostratigraphy and taxic overturn in neritic foraminifera / Graham David Moss." 1995. http://hdl.handle.net/2440/18527.
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Loose sheets comprise of profiles of the Oligocene.Bibliography: leaves 89-158.
158, [60] leaves, [16] leaves of plates : ill., maps ; 30 cm. + seven charts (some folded)
Title page, contents and abstract only. The complete thesis in print form is available from the University Library.
This study investigates a late Eocene to Miocene succession of diverse mid-latitude assemblages of foraminifera from carbonates and calcareous muds and sands on the southern Australian margin. It contrasts foraminiferal profiles from the restricted St. Vincent and Murray Basins with the Otway Basin that is more exposed to oceanic conditions.
Thesis (Ph.D.)--University of Adelaide, Dept. of Geology and Geophysics, 1995
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Moss, Graham 1957. "The Oligocene of southern Australia : ecostratigraphy and taxic overturn in neritic foraminifera / Graham David Moss." Thesis, 1995. http://hdl.handle.net/2440/18527.
Full textAbstract:
Loose sheets comprise of profiles of the Oligocene.Bibliography: leaves 89-158.
158, [60] leaves, [16] leaves of plates : ill., maps ; 30 cm. + seven charts (some folded)
This study investigates a late Eocene to Miocene succession of diverse mid-latitude assemblages of foraminifera from carbonates and calcareous muds and sands on the southern Australian margin. It contrasts foraminiferal profiles from the restricted St. Vincent and Murray Basins with the Otway Basin that is more exposed to oceanic conditions.
Thesis (Ph.D.)--University of Adelaide, Dept. of Geology and Geophysics, 1995
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Svendsen, Lotte. "Seal evaluation of a fluvial-lacustrine rift to post-rift succession, the Early Cretaceous Eumeralla Formation, Otway Basin, Australia." 2004. http://hdl.handle.net/2440/37743.
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The Early Cretaceous Eumeralla Formation is regarded as an ineffective regional top seal in the Otway Basin, largely due to sand interbeds providing preferential hydrocarbon migration pathways. A deeper water lacustrine facies consisting of interbedded siltstones and claystones and massive claystones is developed at the base of the Eumeralla Formation in some wells. This interval ( Unit VI ) was deposited within a transgressive to early highstand systems tract and has better sealing properties than the other overlying Eumeralla Formation intervals. Theoretical gas column heights that the various Eumeralla Formation facies can support were calculated from mercury injection capillary pressure ( MICP ) analysis. Results range from 4 meters to 812 meters, and indicate that the fine-grained, lower Eumeralla Formation intervals have a higher seal capacity than the sand rich upper Eumeralla facies. However, the floodplain-dominated sediments commonly developed within the lower Eumeralla Formation are coal-rich and therefore associated with a high risk of brittle failure. Shallow lacustrine sediments have higher seal integrity, but are lithologically variable with extensive secondary porosity developed from dissolution of feldspar. The deeper lacustrine Unit VI provides the best Eumeralla seal for potential Katnook Sandstone and Windermere Sandstone Member reservoirs. Unfortunately, Unit VI is the only Eumeralla facies that is not developed entirely throughout the South Australian Otway Basin. The gamma ray log is generally unable to identify Eumeralla sandstone interbeds due to the sand's high volcanoclastic content. An integration of log data with seismic data, palynology, conventional core, and sidewall core and cuttings descriptions has enabled the seal geometry of the Eumeralla Formation to be determined. The deeper lacustrine Unit VI is locally developed in the St Clair Trough and on the flank of the Merino High. It is absent in the central Penola Trough and the Robe Trough, but could potentially be developed within the undrilled southern Penola Trough and in the Tantanoola Trough. Unit VI occurs preferentially in basins formed on the hanging wall of half grabens during late rift to early sag. The risk of top seal fracturing is considered high in the Robe Trough, and the Eumeralla Formation is very sandy in the central Penola Trough. Good seals are likely to be developed in the southern, predominantly offshore Otway Basin where Eumeralla sediments are generally deeper, and therefore more affected by mechanical compaction and diagenesis.Thesis (M.Sc.)--Australian School of Petroleum, 2004.
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Lyon, Paul John. "A systematic assessment of fault seal risk to hydrocarbon exploration in the Penola Trough, Otway Basin, South Australia." 2008. http://hdl.handle.net/2440/49488.
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A new depth-based method of seismic imaging is used to provide insights into the 3D structural geometry of faults, and to facilitate a detailed structural interpretation of the Penola Trough, Otway Basin, South Australia. The structural interpretation is used to assess fault kinematics through geological time and to evaluate across-fault juxtaposition, shale gouge and fault reactivation potential for three selected traps (Zema, Pyrus and Ladbroke Grove) thus providing a full and systematic assessment of fault seal risk for the area. Paper 1 demonstrates how a depth-conversion method was applied to two-way time seismic data in order to redisplay the seismic in a form more closely representative of true depth, here termed ‘pseudo-depth’. Some apparently listric faults in two-way time are demonstrated to be planar and easily distinguishable from genuine listric faults on pseudo-depth sections. The insights into fault geometry provided by pseudo-depth sections have had a significant impact on the new structural interpretation of the area. Paper 2 presents the new 3D structural interpretation of the area. The geometry of faulting is complex and reflects variable stress regimes throughout structural development and the strong influence of pre-existing basement fabrics. Some basement-rooted faults show evidence of continual reactivation throughout their structural history up to very recent times. Structural analysis of all the live and breached traps of the area demonstrate that traps associated with a basement rooted bounding fault host breached or partially breached accumulations, whereas non-basement rooted faults are associated with live hydrocarbon columns. Papers 3 and 4 demonstrate that for all the traps analysed (Zema, Pyrus and Ladbroke Grove), initial in-place seal integrity was good. The initial seal integrity was provided by a combination of both favourable across fault juxtaposition (Ladbroke Grove) and/or sufficiently well developed shale gouge over potential leaky sand on sand juxtaposition windows to retain significant hydrocarbon columns (Zema, Pyrus). The palaeocolumns observed at Zema and Pyrus indicate that there has been subsequent post-charge breach of seal integrity of these traps while Ladbroke Grove retains a live hydrocarbon column. Evidence of open, permeable fracture networks within the Zema Fault Zone suggest that it is likely to have recently reactivated, thus breaching the original hydrocarbon column. Analysis of the in-situ stress tensor and fault geometry demonstrates that most of the bounding faults to the selected traps are at or near optimal orientations for reactivation in the in-situ stress tensor. The main exception being the Ladbroke Grove Fault which has a NW-SE trending segment (associated with a relatively high risk of fault reactivation and possible leakage at the surface) and an E-W trending segment (associated with a relatively low risk of fault reactivation and a present day live column). The free water level of the Ladbroke Grove accumulation coincides with this change in fault orientation.http://proxy.library.adelaide.edu.au/login?url= http://library.adelaide.edu.au/cgi-bin/Pwebrecon.cgi?BBID=1339545
Thesis (Ph.D.) - University of Adelaide, Australian School of Petroleum, 2008
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Lyon, Paul John. "A systematic assessment of fault seal risk to hydrocarbon exploration in the Penola Trough, Otway Basin, South Australia." Thesis, 2008. http://hdl.handle.net/2440/49488.
Full textAbstract:
A new depth-based method of seismic imaging is used to provide insights into the 3D structural geometry of faults, and to facilitate a detailed structural interpretation of the Penola Trough, Otway Basin, South Australia. The structural interpretation is used to assess fault kinematics through geological time and to evaluate across-fault juxtaposition, shale gouge and fault reactivation potential for three selected traps (Zema, Pyrus and Ladbroke Grove) thus providing a full and systematic assessment of fault seal risk for the area.
Paper 1 demonstrates how a depth-conversion method was applied to two-way time seismic data in order to redisplay the seismic in a form more closely representative of true depth, here termed ‘pseudo-depth’. Some apparently listric faults in two-way time are demonstrated to be planar and easily distinguishable from genuine listric faults on pseudo-depth sections. The insights into fault geometry provided by pseudo-depth sections have had a significant impact on the new structural interpretation of the area.
Paper 2 presents the new 3D structural interpretation of the area. The geometry of faulting is complex and reflects variable stress regimes throughout structural development and the strong influence of pre-existing basement fabrics. Some basement-rooted faults show evidence of continual reactivation throughout their structural history up to very recent times. Structural analysis of all the live and breached traps of the area demonstrate that traps associated with a basement rooted bounding fault host breached or partially breached accumulations, whereas non-basement rooted faults are associated with live hydrocarbon columns.
Papers 3 and 4 demonstrate that for all the traps analysed (Zema, Pyrus and Ladbroke Grove), initial in-place seal integrity was good. The initial seal integrity was provided by a combination of both favourable across fault juxtaposition (Ladbroke Grove) and/or sufficiently well developed shale gouge over potential leaky sand on sand juxtaposition windows to retain significant hydrocarbon columns (Zema, Pyrus). The palaeocolumns observed at Zema and Pyrus indicate that there has been subsequent post-charge breach of seal integrity of these traps while Ladbroke Grove retains a live hydrocarbon column.
Evidence of open, permeable fracture networks within the Zema Fault Zone suggest that it is likely to have recently reactivated, thus breaching the original hydrocarbon column. Analysis of the in-situ stress tensor and fault geometry demonstrates that most of the bounding faults to the selected traps are at or near optimal orientations for reactivation in the in-situ stress tensor. The main exception being the Ladbroke Grove Fault which has a NW-SE trending segment (associated with a relatively high risk of fault reactivation and possible leakage at the surface) and an E-W trending segment (associated with a relatively low risk of fault reactivation and a present day live column). The free water level of the Ladbroke Grove accumulation coincides with this change in fault orientation.Thesis (Ph.D.) - University of Adelaide, Australian School of Petroleum, 2008
Conference papers on the topic "Stratigraphic Otway Basin (Vic"
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Conti, Jonathan. "A Stratigraphic Study of the Crayfish Group in the Penola Trough, Otway Basin." In International Conference and Exhibition, Melbourne, Australia 13-16 September 2015. Society of Exploration Geophysicists and American Association of Petroleum Geologists, 2015. http://dx.doi.org/10.1190/ice2015-2210822.
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