scholarly journals Dorado discovery – unlocking a major new oil and gas play in the Bedout Sub-basin

2020 ◽  
Vol 60 (2) ◽  
pp. 778
Author(s):  
Melissa Thompson
Keyword(s):  
Joint Venture ◽  
Oil And Gas ◽  
Seismic Inversion ◽  
Source Rocks ◽  
High Quality ◽  
Well Control ◽  
Light Oil ◽  
Set Up ◽  
Inversion Techniques

In 2014, Santos (formerly Apache and Quadrant Energy Limited) acquired an operated exploration position over most of the under-explored Bedout Sub-basin. A multi-year exploration program was subsequently executed, targeting plays within Middle Triassic fluvio-deltaic sediments of the Lower Keraudren and Archer formations. Initial wells at Phoenix South and Roc established the presence of high-quality reservoirs, source rocks and hydrocarbon fluids, but the commerciality of these discoveries was impeded by the lack of existing production infrastructure in this frontier basin. In 2018, Santos and its Joint Venture partner, Carnarvon Petroleum, drilled Dorado-1, targeting stacked Archer Formation reservoirs in an erosional truncation trap set up by a major canyon system. The well encountered light oil and/or condensate rich gas in high-quality reservoir sands at each of the target intervals. Despite limited well control, burial depths on the order of 4000 m and imperfect seismic data, the pre-drill prognosis was remarkably accurate, largely due to the application of modern seismic inversion techniques. Subsequent appraisal drilling undertaken during 2019 demonstrated the discovery is larger than originally anticipated and has significantly de-risked a future development. New seismic acquired during 2019 will be used to further improve the understanding of Dorado reservoirs and to mature follow-up prospects for future drilling.

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.

Fatehgarh lacustrine turbidite potential, Barmer Basin, India

2019 ◽  
Vol 38 (4) ◽  
pp. 280-285
Author(s):  
Priyabrata Chatterjee ◽  
Utpalendu Kuila ◽  
B. N. S. Naidu ◽  
Hriday Jyoti Bora ◽  
Anil Malkani ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Integrated Approach ◽  
Seismic Inversion ◽  
Seismic Facies ◽  
Reservoir Quality ◽  
High Quality ◽  
Passive Margins ◽  
Seismic Waveform ◽  
Barmer Basin ◽  
Environment Maps

Global discovered resources of oil and gas in giant stratigraphic and structural-stratigraphic combination traps have increased by nearly 50% in the last 17 years. Among the biggest contributors are the large discoveries in deepwater turbidite systems in passive margins and rift basins. The current study area is located in the Barmer Basin in northwestern India. Barmer Basin is a prolific petroliferous basin with major oil discoveries in structural plays including Mangala, Bhagyam, and Aishwariya fields. The principal reservoirs in the structural highs are high-quality fluvial sandstones of the Paleocene Fatehgarh Formation. Lacustrine turbidite plays have been discovered in the overlying Paleocene Barmer Hill Formation, albeit with moderate to poor reservoir quality. The potential exists, however, for finding off-structure lacustrine deepwater turbidite plays in the Paleocene Fatehgarh with reservoir quality comparable to the high-quality fluvial facies encountered updip in the structural plays. An integrated approach was adopted to identify stratigraphic entrapments across the basin to chase high-quality Fatehgarh reservoirs. Gross depositional environment maps integrating new geoscientific data were created, followed by well-calibrated seismic geomorphology and seismic facies interpretations to identify the distal lacustrine deepwater turbidite system fed by the updip fluvial Fatehgarh systems. Worldwide, the critical risk elements associated with such plays are reservoir presence, quality, and lateral seal. Geophysical tools like unsupervised seismic waveform classification, spectral decomposition, and seismic inversion were applied to the available seismic data, and the results were integrated with the regional geology and well facies information to derisk the critical risk segments.

Onshore Petroleum Centre of Excellence—collaboration by industry partners, government and TAFE to deliver trained staff for an expanding onshore petroleum industry

2015 ◽  
Vol 55 (2) ◽  
pp. 496
Author(s):  
Venner Bettina ◽  
Wood Chris ◽  
Welsh Kevin ◽  
Mossman Fiona ◽  
Goiak Paul ◽  
...  
Keyword(s):  
Gas Flow ◽  
Joint Venture ◽  
Oil And Gas ◽  
Petroleum Industry ◽  
Gas Production ◽  
Mechanical Equipment ◽  
Production Environment ◽  
Oil And Gas Production ◽  
Training Facility ◽  
Set Up

Santos, Beach Energy and Senex Energy are collaborating with the SA Government and TAFE SA to set up a hub for onshore oil and gas training in Adelaide. The training facility provides a fully immersive simulated oil and gas production environment, as well as static equipment displays for demonstration and educational purposes. It is used for technical training, including safety, environmental and sustainable operational principles and key maintenance activities. The simulated production environment includes different pump types, gas compressors, a pig launcher and receiver, gas metering skid, field separator and small tanks, as well as associated pressure safety valves, flow valves and other instruments. Water is used to simulate oil and air is used to simulate gas flow. The static equipment display includes various valve types, flanges and a wellhead. Santos, as operator of the SA Cooper Basin joint venture (of which Beach Energy is a member), has committed significant oil and gas production and mechanical equipment, engineering design, transportation and installation of the training facility’s equipment. The SA Government, Senex Energy and Beach Energy have committed funding for fit-out, capital works and the running of the facility for the first two years. Industry partners GPA Engineering, Fyfe Engineering, Logicamms, Veolia Environmental Services, Toll Energy, Transfield Services, Ottoway Engineering, Bureau Veritas, MRC Group, Max Cranes, Whitham Media Australia, Inductabend, Toyota Australia, James Walker Australia, Coventry Fasteners, Centralian Controls and Central Diesel are providing expertise and services. The training facility officially opened on 16 February 2015

scholarly journals Hydrocarbon generation from Carboniferous-Permian coaly source rocks in the Huanghua depression under different geological processes

2020 ◽  
Vol 17 (6) ◽  
pp. 1540-1555
Author(s):  
Jin-Jun Xu ◽  
Qiang Jin
Keyword(s):  
Oil And Gas ◽  
Vitrinite Reflectance ◽  
Source Rocks ◽  
Bohai Bay ◽  
Hydrocarbon Generation ◽  
Oil And Gas Exploration ◽  
Geological Processes ◽  
Light Oil ◽  
Huanghua Depression ◽  
Higher Temperature

AbstractNatural gas and condensate derived from Carboniferous-Permian (C-P) coaly source rocks discovered in the Dagang Oilfield in the Bohai Bay Basin (east China) have important implications for the potential exploration of C-P coaly source rocks. This study analyzed the secondary, tertiary, and dynamic characteristics of hydrocarbon generation in order to predict the hydrocarbon potentials of different exploration areas in the Dagang Oilfield. The results indicated that C-P oil and gas were generated from coaly source rocks by secondary or tertiary hydrocarbon generation and characterized by notably different hydrocarbon products and generation dynamics. Secondary hydrocarbon generation was completed when the maturity reached vitrinite reflectance (Ro) of 0.7%–0.9% before uplift prior to the Eocene. Tertiary hydrocarbon generation from the source rocks was limited in deep buried sags in the Oligocene, where the products consisted of light oil and gas. The activation energies for secondary and tertiary hydrocarbon generation were 260–280 kJ/mol and 300–330 kJ/mol, respectively, indicating that each instance of hydrocarbon generation required higher temperature or deeper burial than the previous instance. Locations with secondary or tertiary hydrocarbon generation from C-P coaly source rocks were interpreted as potential oil and gas exploration regions.

The Geochemical Characteristics of High Quality Hydrocarbon Source Rocks - A Case Study of Hailaer Basin

2013 ◽  
Vol 868 ◽  
pp. 107-112
Author(s):  
Dan Ning Wei ◽  
Gui Lei Wang
Keyword(s):  
Organic Matter ◽  
Oil And Gas ◽  
Geochemical Characteristics ◽  
Source Rocks ◽  
Common Source ◽  
Hydrocarbon Source Rock ◽  
High Quality ◽  
Hydrocarbon Source Rocks ◽  
Study Zone ◽  
Hydrocarbon Expulsion

The distribution of high quality hydrocarbon source rocks plays an important role in the accumulation of oil and gas. As a result, the identification of geochemical characteristics of high quality source rocks is the key to discriminate the distribution of high quality source rocks accurately. By core observation and sample analysis, taking Wuerxun-Beier depression in Hailaer Basin as the target regions, we make accurate discrimination of high quality hydrocarbon source rock developmental characteristics and comparison with common source rocks. The research shows that: (1) the hydrocarbon expulsion efficiency in study zone is high due to the alternating deposits of high quality hydrocarbon source rocks and sandstones. The high quality hydrocarbon source rocks deposited in the reducing environment to strong reducing ones, whereas common rocks deposited in oxidizing environment to weak oxidizing ones. (2) the occurrence of organic matter of high quality hydrocarbon source rocks is mainly in stratified enrichment type. The organic matter develops parallel bedding or basic parallel bedding. However, the distribution of organic matter of common source rocks is porphyritic and heterogeneous, or interrupted lamellar. (3) the hydrocarbon potential of high quality hydrocarbon source rocks is more than ten times that of common source rocks. (4) the content of organic carbon in high quality source rocks is high and the content of chloroform asphalt A is relatively low, which reflects that the hydrocarbon expulsion efficiency of high quality source rocks in the sand-shale interbeds of study zone is high.

New exploration opportunities in the offshore Houtman and Abrolhos sub-basins, northern Perth Basin, WA

2013 ◽  
Vol 53 (1) ◽  
pp. 97 ◽  
Author(s):  
Nadege Rollet ◽  
Chris Nicholson ◽  
Andrew Jones ◽  
Emmanuelle Grosjean ◽  
George Bernardel ◽  
...  
Keyword(s):  
Joint Venture ◽  
Oil And Gas ◽  
Strong Support ◽  
Lower Triassic ◽  
Source Rocks ◽  
Burial History ◽  
Sequence Stratigraphic ◽  
Petroleum Systems ◽  
Integrity Analysis ◽  
Geochemical Studies

The 2013 Acreage Release Areas W13-19 and W13-20 in the offshore northern Perth Basin, Western Australia, cover more than 19,000 km2 in parts of the Houtman, Abrolhos, Zeewyck and Gascoyne sub-basins. The Release Areas are located adjacent to WA-481-P, the only active offshore exploration permit in the Perth Basin, granted to joint venture partners Murphy Australia Oil Pty Ltd, Kufpec Australia Pty Ltd and Samsung Oil and Gas Australia Pty Ltd in August 2012. Geoscience Australia recently undertook a regional prospectivity study in the area as part of the Australian Government’s Offshore Energy Security Program, which provides fresh insights into basin evolution and hydrocarbon prospectivity. A sequence stratigraphic framework, based on new biostratigraphic sampling and interpretation, and an updated tectonostratigraphic model, using multiple 1D burial history models for Permian to Cenozoic sequences, have been developed. New geochemical studies of key offshore wells demonstrate that the oil-prone source interval of the Lopingian–Lower Triassic Hovea Member extends regionally offshore into the Abrolhos Sub-basin and potentially as far as the Houtman Sub-basin. This is supported by fluid inclusion data that provide evidence for palaeo-oil columns within Permian reservoirs in wells from the Abrolhos Sub-basin. Oil trapped in fluid inclusions in Houtman-1 can be linked to Jurassic source rocks, suggesting that multiple petroleum systems are effective in the Release Areas. The presence of active petroleum systems is also supported by the results of a recent marine survey. Potential seepage sites on the seafloor over reactivated faults correlate with hydroacoustic flares, pockmarks and dark colored viscous fluids that were observed over the areas. This may indicate an active modern-day petroleum system in the Houtman Sub-basin. Finally, a trap integrity analysis was undertaken to mitigate exploration risks associated with trap failure during Early Cretaceous breakup and provides a predictive approach to prospect assessment. These results provide strong support for the presence of active petroleum systems in the offshore northern Perth Basin and upgrade the prospectivity of the Release Areas.

Discovery of the lower Cambrian high-quality source rocks and deep oil and gas exploration potential in the Tarim Basin, China

AAPG Bulletin ◽  
2018 ◽  
Vol 102 (10) ◽  
pp. 2123-2151 ◽  
Author(s):  
Guangyou Zhu ◽  
Feiran Chen ◽  
Meng Wang ◽  
Zhiyao Zhang ◽  
Rong Ren ◽  
...  
Keyword(s):  
Tarim Basin ◽  
Lower Cambrian ◽  
Oil And Gas ◽  
Source Rocks ◽  
High Quality ◽  
Oil And Gas Exploration

THE SIGNIFICANCE OF HYDROCARBON SHOWS AND OIL RECOVERIES IN THE LONGREACH AREA, CENTRAL QUEENSLAND

1989 ◽  
Vol 29 (1) ◽  
pp. 157
Author(s):  
C.C. Hodge ◽  
N.J. Russell ◽  
M. Smyth
Keyword(s):  
Joint Venture ◽  
Oil And Gas ◽  
Vitrinite Reflectance ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Variable Nature ◽  
Water Well ◽  
Reflectance Measurements ◽  
Cooper Basin ◽  
Commercial Oil

In 1925, over 40 gallons of oil were recovered from the Longreach town- water well. More recently, Corona 1, drilled by the ATP 271P Joint Venture in 1984, recovered 9 m (0.5 bbls) of oil in the drill pipe.These oil recoveries, along with several water- bore oil and gas occurrences, are all located in the Longreach area, Central Queensland, over 100 km north- northeast of the Cooper Basin zero edge. The oil recoveries and shows are therefore considered to be the product of source rocks other than those of the Cooper Basin.The Birkhead Formation, the unit considered most likely to source the Longreach and Corona oils, has been studied with a view to understanding the nature of hydrocarbon generation in the vicinity of the Maneroo Platform. The variables measured include (1) thickness of the shale units, (2) volume and type of dispersed organic matter (DOM) and (3) maturity (vitrinite reflectance). Measurements were taken from 10 exploration wells through the whole formation to provide uniform comparative assessment.The Birkhead Formation in the Maneroo Platform area is shown to have an anomalously low sandstone- to- shale ratio, vitrinite reflectance values (Rm(o)) consistently greater than 0.7 per cent and a favourable petroleum generative geochemistry.These results emphasise the highly variable nature of the Eromanga Basin sequence, and therefore its diverse generative potential, and highlight the encouraging prospectivity of the Maneroo Platform area despite the present lack of commercial oil discoveries.

A method of technical diagnostics for offshore structures

1994 ◽  
Vol 16 (2) ◽  
pp. 43-48
Author(s):  
Do Son
Keyword(s):  
Diagnostic Method ◽  
Joint Venture ◽  
Oil And Gas ◽  
Residual Life ◽  
Life Time ◽  
Offshore Structures ◽  
Technical Diagnostics ◽  
Offshore Platforms ◽  
South Vietnam ◽  
Local Destruction

This paper describes the results of measurements and analysis of the parameters, characterizing technical state of offshore platforms in Vietnam Sea. Based on decreasing in time material characteristics because of corrosion and local destruction assessment on residual life time of platforms is given and variants for its repair are recommended. The results allowed to confirm advantage of proposed technical diagnostic method in comparison with others and have been used for oil and gas platform of Joint Venture "Vietsovpetro" in South Vietnam.

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