Exploration & Development in Southern Caribbean Frontier Basins - Presentation Proposal Form
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Exploration & Development in Southern Caribbean Frontier Basins - Early Bird Fee
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A collection of abstracts from more than 50 academic papers regarding the controls and impacts of inorganic and organic diagenesis on mudstone hydrocarbon generation, reservoir properties and seal quality.
Saudi Aramco hopes to push the boundaries of exploration by creating and encouraging new technologies. The company said it is pursuing the promise of “the fourth industrial revolution” through Big Data and supercomputing and investigations into nanotechnology applications.
This workshop will bring the attendees up to date with the latest academic and case-studies from the field of advanced surface logging technologies.
The USGS estimated (2013) that the Late Devonian to Early Mississippian Bakken Formation holds in excess of 7 billion barrels (~1.1 billion m3) of recoverable oil, making it one of the top 50 largest oilfields in the world. Most of the production comes from shallow-marine sandstones of the Middle Bakken Member that are directly over- and underlain by extremely organic-rich shale source rocks (Upper and Lower Bakken Shale members respectively). Although not oil-productive everywhere, the Middle Bakken forms a relatively sheet-like unit that covers an area of over 200,000 square miles (~520,000 km2) of the intracratonic Williston Basin.
The vertical juxtaposition of shallow-marine reservoir and more distal source rocks over such a large area, without intervening transitional facies, is unusual from a stratigraphic perspective. One possible explanation would require global fluctuations of sea level to drive geologically rapid and extensive shoreline movements in this relatively stable basin. Forced regression associated with falling sea level could explain the lack of transitional facies (e.g., inner shelf) between the distal Lower Bakken Shale and the overlying Middle Bakken (a sharp-based shoreface). Subsequent sea-level rise would have caused rapid and extensive transgression, leading to the observed stratigraphic relationships between the Middle and Upper Bakken members. But what could have caused the changes in sea level?
A considerable body of evidence points to a Late Devonian-Early Mississippian ice age that covered portions of Gondwana (e.g., parts of present-day Brazil) that were situated close to the paleo South Pole. This ice age consisted of more than one glacial/interglacial cycle and was probably triggered by massive removal of CO2 from the atmosphere by land plants and organic-rich shales. Some evidence indicates that at least 100 m of sea-level drop took place during one of the Famennian glaciations, which would have effectively drained the Williston Basin and induced major shoreline progradation. Melting of the ice sheets would have caused transgression and reflooding of the basin and deposition of the Upper Bakken Shale. Other basins around the world record similar evidence for glacioeustacy near the Devonian-Mississippian transition. The glacial/interglacial cycles are expressed differently from basin to basin, reflecting the interplay between fluctuations of global sea level and each basin’s history of subsidence and sediment supply.
The Shale Revolution caught geophysicists off guard. Shales had been studied for a variety of reasons (e.g., relationships between velocity, compaction and pore pressure) but not as low-porosity reservoirs that show vertical heterogeneity at all possible scales. Consequently, many geophysicists have framed shale-play imaging problems using inappropriate tools and paradigms. In this presentation, I present five characteristics of shale plays that should enable improved geophysical analyses.
In a recent EXPLORER, Marlan Downey lamented that he had not fully appreciated the idea that source rocks could serve as reservoir rocks for oil and natural gas. He was not alone.
In 1965, G.T. Philippi, a Shell geochemist, made the novel proposal that petroleum was generated from organic matter in sediments that had been buried deeply enough to be exposed to warmer earth temperatures, converting the organic matter, with heat and time, to petroleum.
How does diagenesis affect rock physics? What is the relationship of the burial history to the rock physics? Both have a dramatic impact on the rock physics properties of not only the reservoir, but also the source and seals. Welcome to an interview with Per Avseth, who discusses rock physics and quantitative seismic interpretation. He also talks with us about how developing an effective rock physics model requires the integration of geological, geophysical, geochemical, and petrophysical information.
The fine-grained sediments and rocks that constitute most of the sedimentary record have received tremendous research attention in the past decade. This talk reviews some of the technologies that have supported these advances and summarizes current knowledge of the diagenetic processes that drive the evolution of bulk rock properties of mud in the subsurface.
The study of gas hydrates in nature has been ongoing for over 40 years. Significant strides have been made in our understanding of the occurrence, distribution, and characteristics of marine and permafrost associated gas hydrates.
Field Trip Leader: Andreas Scharf, Sultan Qaboos University (SQU)
Date: 12th December
Time: 7.30am – 7pm
Registration Deadline: 20th November
The Jabal Akhdar in the Oman Mountains forms a ~90 km x 60 km large dome. The core of this dome consists of Precambrian sedimentary rocks, including source rocks. These rocks are separated by the overlying rocks by an angular unconformity. Rocks above this unconformity are the Permo-Mesozoic shelf carbonates of the Arabian passive margin. During the Late Cretaceous, the Arabian shelf was overthrust by the Semail Ophiolite and Hawasina rocks. Final doming was during the Eocene to Miocene. Thus, the Jabal Akhdar Dome provides insights to several deformation events.
This field trip will start near Al-Hamra and traverse the Jabal Akhdar Dome from the southern margin. Our road leads to a spectacular vista point at about 2000 m elevation. From this site we will study the regional folds in Precambrian formations as well the impressive cliffs of Permo-Mesozoic rocks. Within the core of the dome we will investigate Paleozoic refolded folds as well as syndepositional extensional faults within the Precambrian strata (Figs. 1 & 2). In Wadi Bani Kharous, the angular unconformity is superbly exposed (Fig. 3). The field trip will further inspect ductile and brittle deformation in the Mesozoic shelf carbonates (Fig. 4). Deformation is due to gravitational collapse and related extension immediately after ophiolite emplacement and final doming.
Date: Friday December 13, 2019
Location: Central coastal Lebanon north of Beirut. The visited towns will include Qartaba, Laqlouq, Tannourine, Chekka and Byblos
Fees: US$ 550 (Members) | US$ 750 (Non-members)
Investigate the Cretaceous to Miocene carbonate platforms in Lebanon to draw analogy to Zohr, Explore the depositional environment of the Campanian source rocks, visualise the large structures of the Levant margin (e.g. the Qartaba structure) analogous to the offshore structures and have a concept of the scale.
Departure time: 8:00 AM from hotel
Stop 1: Qartaba village: Overview of the stratigraphy and depositional environment of the Levant margin by looking at a panoramic view of the stratigraphic succession.
Stop 2: Laqlouq: quick stop to visualize the folding of the Qartaba anticline
Stop 3: Tannourine: Overview of the large E-W strike-slip faults and discussion on their geodynamic history and implications on the petroleum system
Stop 4: Tannourine-Douma road: Overview of the Cretaceous carbonate monocline and discussion on facies variation
Stop 5: Chekka quarry: Examine the Campanian thermogenic source rocks and the Paleocene depositional systems.
Stop 6: Ras Chekka: observe the Eocene carbonates, the Miocene reefs and the hiatus between the Lutetian-Burdigalian
End of the trip by 5:00 PM
Figure 1: The map of the region visited in this fieldtrip
The AAPG Latin America & Caribbean Region and the Colombian Association of Petroleum Geologists and Geophysicists (ACGGP) invite you join us for GTW Colombia 2020, a specialized workshop bringing leading scientists and industry practitioners to share best practices, exchange ideas and explore opportunities for future collaboration.
The 2-day workshop brings together technical experts and industry leaders from Colombia and throughout the Americas to take a multidisciplinary look at future opportunities for exploration and development of Southern Caribbean Frontier Basins.
The gas transport in organic-rich shales involves different length-scales, from organic and inorganic pores to macro- and macrofractures. In order to upscale the fluid transport from nanoscale (flow through nanopores) to larger scales (to micro- and macrofractures), multicontinuum methodology is planned to be used.
Cross disciplinary workflows play an important part of successful characterization of shale reservoirs. This course discusses how the artificial kerogen maturity of organic-rich Green River shale affects the petrophysical, micro-structural, geochemical and elastic properties.
The Niobrara Petroleum System of the U.S. Rocky Mountain Region is a major tight petroleum resource play.
The Mississippian-Devonian Bakken Petroleum System of the Williston Basin is characterized by low-porosity and permeability reservoirs, organic-rich source rocks, and regional hydrocarbon charge.
This e-symposium is ideal for geologists, geophysicists, engineers and other geoscientists who are involved in gas shale exploration and production.
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