Exploration of an unconventional petroleum resource through extensive core analysis and basin geology interpretation utilising play element methodology: the Lower Goldwyer Formation, onshore Canning Basin, Western Australia

2019 ◽  
Vol 59 (1) ◽  
pp. 464 ◽  
Author(s):  
Jop van Hattum ◽  
Aaron Bond ◽  
Dariusz Jablonski ◽  
Ryan Taylor-Walshe
Keyword(s):  
Oil And Gas ◽  
Fluid Composition ◽  
Reservoir Properties ◽  
Oil And Gas Development ◽  
Flow Rates ◽  
Canning Basin ◽  
Petroleum Systems ◽  
Multi Stage ◽  
Play Elements ◽  
Extractable Organic Matter

Theia Energy Pty Ltd1 (Theia Energy) discovered a potential unconventional hydrocarbon resource in the Ordovician Lower Goldwyer (GIII) Formation shale located on the Broome Platform of the onshore Canning Basin. The collation, processing, analysis and interpretation of all available regional data culminated in a successful exploration well, Theia-1 (drilled in 2015), which, based upon petrophysical and core analyses, intersected a 70 m gross oil column at 1500–1570 m depth. Theia-1 recovered essential core and wireline log data required to analyse and assess the play elements and reservoir properties necessary for a viable shale oil and gas development. Utilisation of an ‘Unconventional Play Element’ methodology has proven the unconventional hydrocarbon potential of the GIII Formation, and preliminary modelling indicates that economic stimulated flow rates may be achieved. Further operations (a test well with multi-stage hydraulic fracture stimulation) are scheduled in the coming permit year to further quantify the presence of extractable organic matter in the GIII Formation, assess hydrocarbon flow rates, determine fluid composition and appraise commercial viability. This paper will discuss Theia Energy’s exploration campaign in the onshore Canning Basin starting with the regional evaluation, which encompassed all available geoscience data (offset wells, pre-existing seismic and potential analogue fields) and modern specialised shale analysis (sequence stratigraphy, paleogeography, geochemistry, unconventional petrophysics and petroleum systems modelling), to develop a robust regional geological model for the GIII Formation. Pre-drill analysis reduced exploration risk and successfully identified the key geological play elements essential for the successful Theia-1 exploration evaluation program.

CANNING BASIN AND GLOBAL PALAEOZOIC PETROLEUM SYSTEMS—A REVIEW

2005 ◽  
Vol 45 (1) ◽  
pp. 349 ◽  
Author(s):  
G.M. Carlsen ◽  
K. Ameed R. Ghori
Keyword(s):  
North America ◽  
North American ◽  
Oil And Gas ◽  
Oil Fields ◽  
North African ◽  
Canning Basin ◽  
Petroleum Systems ◽  
The North ◽  
Oil And Gas Fields ◽  
Gas Fields

There are more than 131 giant and super-giant oil and gas fields with Palaeozoic source and reservoir that are similar to the Canning Basin. These include Palaeozoic basins of North America, North Africa, and the North Caspian Basin of Kazakhstan and Russia.The productivity of these Palaeozoic petroleum systems depends on timing of generation and preservation of charge. Thick Ordovician, Permian, and Triassic evaporite deposits played a very important role in creating and preserving the North American, north Caspian, and north African giant oil and gas fields, respectively.The Mesozoic–Tertiary charged Palaeozoic systems are typically more productive than the Palaeozoic charged systems as exemplified by the north African basins.The Ordovician sourced and reservoired giant oil fields of the North American Mid-Continent are also highly productive. Within the Canning Basin, Ordovician sourced oil has been recovered on the Barbwire Terrace (in Dodonea–1, Percival–1 and Solanum–1) on the Dampier Terrace (in Edgar Range–1 and Pictor–1) and along the Admiral Bay Fault Zone (in Cudalgarra–1, Great Sandy–1, and Leo–1).The Canning Basin may be the least explored of the known Palaeozoic basins with proven petroleum systems. The Palaeozoic basins of North America are the most explored with 500-wells/10,000 km2 compared to the Canning Basin with only 4-wells/10,000 km2.The presence of five oil fields, numerous oil and gas shows and the well density in the Canning Basin (200 wells in 530,000 km2) suggests that further exploration is warranted. Critical analysis of the distribution of source rock, reservoir, seal, timing of generation versus trap formation and post accumulation modification for each tectonic unit of the Canning Basin is required.

Introduction to this special section: Quantitative interpretation

2021 ◽  
Vol 40 (10) ◽  
pp. 714-714
Author(s):  
Agnibha Das ◽  
Mita Sengupta
Keyword(s):  
Oil And Gas ◽  
Special Section ◽  
Magnetic Data ◽  
Fluid Composition ◽  
Quantitative Interpretation ◽  
Amplitude Analysis ◽  
Gas Reservoirs ◽  
Reservoir Properties ◽  
Reservoir Architecture ◽  
Oil And Gas Reservoirs

Quantitative interpretation (QI) is the geophysicist's endeavor to go beyond reservoir architecture. It is the effort to use geophysical measurements in understanding reservoir properties such as rock type, porosity, and fluid composition. QI often refers to the use of seismic amplitude analysis to predict lithology, porosity, and pore fluids away from the wellbore in oil and gas reservoirs. However, we can generalize and expand the concept of QI beyond seismic methods and beyond oil and gas reservoirs. In this special section, we feature five papers and cover not only seismic and well-log data, but also gravity and magnetic data. We address a hydrothermal reservoir in addition to several oil and gas reservoirs.

scholarly journals The Impact of Oil and Gas Development on the Landscape and Surface in Nigeria

2021 ◽  
Vol 4 (1) ◽  
pp. 9-17
Author(s):  
S M Nazmuz Sakib
Keyword(s):  
Air Pollution ◽  
Crude Oil ◽  
Niger Delta ◽  
Oil And Gas ◽  
Petroleum Industry ◽  
Oil And Gas Development ◽  
Lightning Strikes ◽  
Petroleum Systems ◽  
Petroleum Development ◽  
The Impact

This writing will focus on the impact on the impact of oil and gas development on the landscape, surface water and groundwater of the Niger Delta – while also assessing the various means of remediation in use. Geologically, the Niger Delta petroleum systems consist of Lower Cretaceous , Upper Cretaceous–lower Paleocene and Tertiary. When Nigeria became an independent nation on 1 October 1960, Shell–BP began to relinquish its acreage and its exploration licenses were converted into prospecting licenses that allowed development and production. The Federal Government of Nigeria started its Department of Petroleum Resources Inspectorate in 1970 and Nigeria joined the Organization of the Petroleum Exporting Countries in 1971. – and in order to take control of the country’s petroleum industry, Nigeria nationalized BP’s holding completely in 1979, and Shell–BP became Shell Petroleum Development Company of Nigeria. Oil spillages routinely occur in the Niger Delta. The official figures of SPDC show that between 1976 and 2001, 6,187 incidents in which 3 million barrels were spilled. The Niger Delta Environmental Survey An impact assessment of the 1983 Oshika oil spill. Spills of crude oil in Niger Delta farmlands have been reported since 1971. In general, toxicity depends on nature and type of crude oil , level of oil contamination, type of environment and degree of selective of individual organisms. Controlled burning effectively reduce the amount of oil in water, if done properly but it must be done in low wind and can cause air pollution. A principal target for emissions reduction is flaring and venting which causes most of the air pollution. Saltwater tanks can be often susceptible to lightning strikes due to build up in static electricity, with the spilled oil spreading to surrounding lands, waterways. This requires a secondary containment of the tanks that makes it easier to clean up the inevitable spill. In cases of expected major storms or flooding events, crude oil can be removed from tank batteries while refilling the tanks with saltwater to prevent them tipping over during the flooding event.

Petroleum source rocks of Western Australia

2018 ◽  
Vol 58 (1) ◽  
pp. 282 ◽  
Author(s):  
K. Ameed R. Ghori
Keyword(s):  
Western Australia ◽  
Oil And Gas ◽  
Source Rocks ◽  
Lower Permian ◽  
Burial History ◽  
Canning Basin ◽  
Petroleum Systems ◽  
Northern Carnarvon Basin ◽  
Coal Measures ◽  
Carnarvon Basin

Petroleum geochemical analysis of samples from the Canning, Carnarvon, Officer and Perth basins identified several formations with source potential, the: • Triassic Locker Shale and Jurassic Dingo Claystone of the Northern Carnarvon Basin; • Permian Irwin River Coal Measures and Carynginia Formation, Triassic Kockatea Shale and Jurassic Cattamarra Coal Measures of the Perth Basin; • Ordovician Goldwyer and Bongabinni formations, Devonian Gogo Formation and Lower Carboniferous Laurel Formation of the Canning Basin; • Devonian Gneudna Formation of the Gascoyne Platform and the Lower Permian Wooramel and Byro groups of the Merlinleigh Sub-basin of the Southern Carnarvon Basin; and • Neoproterozoic Brown, Hussar, Kanpa and Steptoe formations of the Officer Basin. Burial history and geothermal basin modelling was undertaken using input parameters from geochemical analyses of rock samples, produced oil, organic petrology, apatite fission track analysis (AFTA), heat flows, subsurface temperatures and other exploration data compiled by the Geological Survey of Western Australia (GSWA). Of these basins, the Canning, Carnarvon, and Perth basins are currently producing oil and gas, whereas the Southern Carnarvon and Officer basins have no commercial petroleum discovery yet, but they do have source, reservoir, seal and petroleum shows indicating the presence of petroleum systems. The Carnarvon Basin contains the richest identified petroleum source rocks, followed by the Perth and Canning basins. Production in the Carnarvon Basin is predominantly gas and oil, the Perth Basin is gas-condensate and the Canning Basin is oil dominated, demonstrating the variations in source rock type and maturity across the state. GSWA is continuously adding new data to assess petroleum systems and prospectivity of these and other basins in Western Australia.

The Paleozoic prospectivity of the Browse Basin, Australia

2020 ◽  
Vol 60 (2) ◽  
pp. 685
Author(s):  
Said Amiribesheli ◽  
Joshua Thorp ◽  
Julia Davies
Keyword(s):  
Seismic Data ◽  
Inversion Algorithm ◽  
Reservoir Properties ◽  
Depth Migration ◽  
Canning Basin ◽  
Petroleum Systems ◽  
Amplitude Versus Offset ◽  
Long Offset ◽  
Well Data

Most of the discovered hydrocarbons in the Browse Basin occurred within the Mesozoic intervals, while deeper Paleozoic sequences have been seldom explored. Lack of Paleozoic exploration in the Browse Basin has been attributed to the lack of well penetrations, poor understanding of the petroleum systems and paucity of seismic data. The onshore Canning Basin with several commercial fields and discoveries is the most appropriate analogue for understanding the Paleozoic sequences in the region. With the integration of geophysical data (i.e. gravity, magnetic and seismic), well data and geology, the Paleozoic prospectivity of the Browse Basin can be further enlightened. Modern long offset (8 m) Vampire 2D seismic data were acquired by Searcher to address some of the complex challenges in the Browse Basin. Reservoir quality of the Brewster Formation, volcanic discrimination within the Plover Formation and identification of deeper Triassic and Paleozoic plays are some examples of these challenges in the Browse Basin. Recently Searcher reprocessed this regionally important Vampire 2D seismic dataset that ties to 60 wells. The broadband pre-stack depth migration reprocessed data were inverted to extract three petro-elastic properties of acoustic impedance, Vp/Vs and density by three-term amplitude versus offset inversion algorithm to improve imaging of deeper plays and delineate reservoir properties. This paper discusses how several potential Paleozoic reservoir-seal pairs can be identified in the Browse Basin by utilising the integration of Vampire 2D seismic data, quantitative interpretation products, regional geology and knowledge of the Canning Basin’s fields and discoveries. Previously there was little exploration of Paleozoic plays because they could not be imaged on seismic data. The potential Paleozoic reservoirs identified in this study include Permo-Carboniferous subcrop, Carboniferous-Devonian anticline and Carboniferous-Devonian rollover plays.

Unconventional hydrocarbons: Australia's old rocks prove their worth

2013 ◽  
Vol 53 (2) ◽  
pp. 472
Author(s):  
Marita Bradshaw ◽  
Chris Boreham ◽  
Lidena Carr ◽  
John Laurie ◽  
Lisa Hall ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Oil Field ◽  
Tight Gas ◽  
Lower Paleozoic ◽  
Canning Basin ◽  
Petroleum Systems ◽  
Unconventional Hydrocarbons ◽  
Basin Area ◽  
Conventional Oil ◽  
Made In

Australia’s search for petroleum began in the onshore basins where extensive areas of Paleozoic marine sequences, with some high-quality source rock intervals and spectacular outcrop, encouraged sporadic exploration for many decades. For these efforts, there were some rewards, including the discovery of the Mereenie oil field in Ordovician rocks, the Amadeus Basin in 1960s, and the Blina discovery in Devonian carbonates in the Canning Basin during the early 1980s. Since the late 1980s, however, the focus of exploration has shifted offshore where more and larger discoveries were made in the Mesozoic marginal basins, which today contain about 90% or more of Australia’s conventional oil and gas. Now, however, the focus has shifted back to the onshore, recognising the potential for shale and tight gas and oil in these older rocks. The onshore basin area under exploration license has nearly doubled from 2010–12; several major international companies have joined local explorers in testing the worth of Australia’s lower Paleozoic and Proterozoic petroleum systems, and new discoveries have been made in several basins. Geoscience Australia and its partners in the state and NT surveys are undertaking new assessments and studies across a number of these basins.

scholarly journals AN ESSAY ON THE IMPACT OF OIL AND GAS DEVELOPMENT ON THE LANDSCAPE AND SURFACE IN NIGERIA

2021 ◽  
Author(s):  
S M Nazmuz Sakib
Keyword(s):  
Niger Delta ◽  
Best Practice ◽  
Oil And Gas ◽  
Oil And Gas Development ◽  
Ecological Zones ◽  
Oil Companies ◽  
Petroleum Systems ◽  
Oil And Gas Fields ◽  
Niger Delta Region ◽  
The Impact

In Nigeria, the self-proclaimed ‘Giant of Africa’, the same scenario has been playing for the past fifty years to devastating effects especially in the Niger Delta, where oil is extracted in Nigeria. The entry of oil companies into the Niger Delta has no doubt brought great financial wealth. Despite these concerns, multinational oil companies operating in the Niger Delta region have failed to adopt best practice strategies for risks mitigation and comply with environmental regulations. This essay will focus on the impact on the impact of oil and gas development on the landscape, surface water and groundwater of the Niger Delta – while also assessing the various means of remediation in use.A total of about 1,182 exploration wells have been drilled to date in the delta basin, and about 400 oil and gas fields of varying sizes have been documented. Geologically, the Niger Delta petroleum systems consist of Lower Cretaceous, Upper Cretaceous–lower Paleocene and Tertiary. According to , a large portion of the world’s oil and gas reserves are in tertiary terrigenous passive continental margins – accounting for the significant hydrocarbon deposits Nigeria’s Niger Delta. The ecological zones can be broadly grouped into tropical rainforest in the northern part of the Delta and mangrove forest in the warm coastlines of the south.

Consideration of the Influence of Carbonate Cement on the Accuracy of Prediction of Well Start-Up Flow Rates in Deep Reservoirs of the West Siberian Oil and Gas Basin on the Example of Reservoir U1 Formation

2021 ◽  
Author(s):  
Sergey Petrovich Mikhaylov ◽  
Anastasia Andreevna Shtyrlyaeva
Keyword(s):  
Oil And Gas ◽  
Reservoir Properties ◽  
Flow Rates ◽  
Carbonate Cement ◽  
Tectonic Processes ◽  
Accurate Forecast ◽  
Shallow Strata ◽  
Productivity Potential ◽  
Starting Flow ◽  
The Impact

Abstract Oil reservoirs are often affected by tectonic processes throughout their lifetime. Tectonic processes contribute to the impact on the formation of a number of mechanical and chemical factors. These factors change the composition and structure of the reservoir and this affects the reservoir properties of the reservoir. Deep-seated reservoirs experience a longer and more intense impact of tectonic processes. A more detailed study of the composition and properties of reservoirs for an accurate forecast of reservoir properties and their productivity potential is due to this. Standard log interpretation methods have been developed based on shallow strata. These methods do not allow taking into account secondary changes in the reservoir and make the calculations of the starting flow rates of wells reliable. J1 stratum West Wing on Nizhnevartovsky set is a prime example of this.

Basin Analog Investigations Answer Characterization Challenges of Unconventional Gas Potential in Frontier Basins

2008 ◽  
Vol 130 (4) ◽  
Author(s):  
Kalwant Singh ◽  
Stephen A. Holditch ◽  
Walter B. Ayers
Keyword(s):  
North American ◽  
Creative Thinking ◽  
Oil And Gas ◽  
Computer Software ◽  
Resource Development ◽  
Engineering Practice ◽  
Reservoir Properties ◽  
Unconventional Gas ◽  
Petroleum Systems ◽  
Oil And Gas Resources

To meet future global oil and gas demands, the energy industry will need creative thinking that leads to the discovery and development of new fields. Unconventional gas resources, especially those in frontier (exploratory) basins, will play an important role in fulfilling future energy needs. To develop unconventional gas resources, we must first identify their occurrences and quantify their potential. Basin analog systems investigation (BASIN) is a computer software that can rapidly and inexpensively evaluate the unconventional gas resource potential of frontier basins. BASIN is linked to a database that includes petroleum systems and reservoir properties data from 25 intensely studied North American “reference” basins that have both conventional and unconventional oil and gas resources. To use BASIN, limited data from a frontier or “target” basin are used to query the database of North American reference basins and rank these reference basins as potential analogs to the frontier basin. Based on analog comparisons, we can predict unconventional gas resources and make preliminary engineering decisions concerning resource development and the best drilling, completion, stimulation, and production practices to use in the frontier basin. Initial software validation shows consistent results. If a basin is selected as the target basin while the same basin is also in the reference basin list, the results show that the basin is a 100% analog to itself. Other basins in the reference basin list are less than 100% analogs. Also, BASIN performed favorably when it was tested against analog basin decisions made by of a team of industry experts. BASIN rapidly and inexpensively identifies and ranks reference basins as analogs to a frontier basin, providing insights to potential gas resources and indicating the preliminary best engineering practice for resource development. It is an effective tool that provides guidance to inexperienced professionals and new perceptions for seasoned experts.

Consideration of Geopolitical Challenges within the Analysis of Geoenvironmental Risks for Oil and Gas Development of the Russian Arctic

2019 ◽  
Vol 16 (6) ◽  
pp. 50-59
Author(s):  
O. P. Trubitsina ◽  
V. N. Bashkin
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Optimal Operation ◽  
The Arctic ◽  
Stage Model ◽  
Oil And Gas Development ◽  
Gas Industry ◽  
The Impact ◽  
Further Development ◽  
Geopolitical Risks

The article is devoted to the consideration of geopolitical challenges for the analysis of geoenvironmental risks (GERs) in the hydrocarbon development of the Arctic territory. Geopolitical risks (GPRs), like GERs, can be transformed into opposite external environment factors of oil and gas industry facilities in the form of additional opportunities or threats, which the authors identify in detail for each type of risk. This is necessary for further development of methodological base of expert methods for GER management in the context of the implementational proposed two-stage model of the GER analysis taking to account GPR for the improvement of effectiveness making decisions to ensure optimal operation of the facility oil and gas industry and minimize the impact on the environment in the geopolitical conditions of the Arctic.The authors declare no conflict of interest

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