scholarly journals Mackenzie-Peel Platform and Ellesmerian Foreland Composite Tectono-Sedimentary Element, northwestern Canada

2021 ◽  
pp. M57-2016-5
Author(s):  
Karen M. Fallas ◽  
Robert B. MacNaughton ◽  
Peter K. Hannigan ◽  
Bernard C. MacLean
Keyword(s):  
Oil And Gas ◽  
Early Carboniferous ◽  
Oil Field ◽  
Passive Margin ◽  
Petroleum Exploration ◽  
Rock Formations ◽  
Devonian Shale ◽  
History Of ◽  
The One ◽  
Uplift And Erosion

AbstractThe Mackenzie-Peel Platform tectono-sedimentary element, and the overlying Ellesmerian Foreland tectono-sedimentary element, consist of Cambrian to Early Carboniferous shelf and slope sedimentary deposits in Canada&s northern Interior Plains. In this chapter, these elements are combined into the Mackenzie-Ellesmerian Composite Tectono-Sedimentary Element. The history of the area includes early extensional faulting and subsidence in the Mackenzie Trough, passive margin deposition across the Mackenzie-Peel Platform, local uplift and erosion along the Keele Arch, subsidence and deposition in the Ellesmerian Foreland, possible minor folding during the Ellesmerian Orogeny, and folding and faulting in Cretaceous to Eocene time associated with the development of the Canadian Cordillera. Recorded petroleum discoveries are within Cambrian sandstone (Mount Clark Formation), Devonian carbonate strata (Ramparts and Fort Norman formations), and Devonian shale (Canol Formation). Additional oil and gas shows are documented from Cambrian to Silurian carbonate units (Franklin Mountain and Mount Kindle formations), Devonian carbonate units (Arnica, Landry, and Bear Rock formations), and Late Devonian to Early Carboniferous siliciclastic units (Imperial and Tuttle Formations). Petroleum exploration activity within the area has occurred in several phases since 1920, most of it associated with the one producing oil field at Norman Wells.

scholarly journals OIL AND GAS MODELING GENERARION IN THE JURASSIC SEDIMENTS IN THE SOUTH-EASTERN OF THE WEST SIBERIAN PETROLEUM PROVINSE

2021 ◽  
Vol 2 (1) ◽  
pp. 38-43
Author(s):  
Elena A. Glukhova ◽  
Pavel I. Safronov ◽  
Lev M. Burshtein
Keyword(s):  
Heat Flow ◽  
Thermal History ◽  
Oil And Gas ◽  
Flow Density ◽  
Basin Modeling ◽  
Heat Flow Density ◽  
The West ◽  
One Dimensional ◽  
History Of ◽  
The One

The article presents the one-dimensional basin modeling performed in four wells to reconstruct the thermal history of deposits and reconstruct the effective values of the heat flow density.

Anabar-Lena Composite Tectono-Sedimentary Element, Northern East Siberia

2021 ◽  
pp. M57-2021-29
Author(s):  
A.K. Khudoley ◽  
S.V. Frolov ◽  
G.G. Akhmanov ◽  
E.A. Bakay ◽  
S.S. Drachev ◽  
...  
Keyword(s):  
Late Cretaceous ◽  
Oil And Gas ◽  
Foreland Basin ◽  
Early Carboniferous ◽  
Passive Margin ◽  
Source Rocks ◽  
East Siberia ◽  
Lena River ◽  
Petroleum Systems ◽  
Intracratonic Basin

AbstractAnabar-Lena Composite Tectono-Sedimentary Element (AL CTSE) is located in the northern East Siberia extending for c. 700 km along the Laptev Sea coast between the Khatanga Bay and Lena River delta. AL CTSE consists of rocks from Mesoproterozoic to Late Cretaceous in age with total thickness reaching 14 km. It evolved through the following tectonic settings: (1) Meso-Early Neoproterozoic intracratonic basin, (2) Ediacaran - Early Devonian passive margin, (3) Middle Devonian - Early Carboniferous rift, (4) late Early Carboniferous - latest Jurassic passive margin, (5) Permian foreland basin, (6) Triassic to Jurassic continental platform basin and (7) latest Jurassic - earliest Late Cretaceous foreland basin. Proterozoic and lower-middle Paleozoic successions are composed mainly by carbonate rocks while siliciclastic rocks dominate upper Paleozoic and Mesozoic sections. Several petroleum systems are assumed in the AL CTSE. Permian source rocks and Triassic sandstone reservoirs are the most important play elements. Presence of several mature source rock units and abundant oil- and gas-shows (both in wells and in outcrops), including a giant Olenek Bitumen Field, suggest that further exploration in this area may result in economic discoveries.

THE DISCOVERY HISTORY OF THE UNIVERSITY OIL FIELD, EAST BATON ROUGE PARISH, LOUISIANA

Geophysics ◽  
1948 ◽  
Vol 13 (3) ◽  
pp. 371-386
Author(s):  
Gordon Atwater
Keyword(s):  
Oil And Gas ◽  
Salt Water ◽  
Oil Field ◽  
State University ◽  
East Baton Rouge Parish ◽  
Louisiana State University ◽  
Shallow Wells ◽  
History Of ◽  
History Of The University ◽  
The University

The localized occurrence of salt water in shallow wells on and near the Louisiana State University campus, in addition to shells collected during the drilling of these wells, attracted the attention of geologists to this area prior to 1926. A torsion balance survey in 1931 was followed by a dry hole drilled in 1933 southeast of the present field. Three separate reflection seismograph surveys during the period of 1934 to 1937, on each one of which a well was drilled without establishing production, were made on the University structure prior to discovery in 1938. The location based on the first reflection seismograph survey should have resulted in the discovery of both the shallow and deep production, and the discovery location was finally made because of the oil and gas shows encountered in this abandoned test. After discovery, an additional reflection survey was made to detail the structure as an aid in development.

scholarly journals Chapter 4. Paleozoic granitoid magmatism of South and Middle Tien Shan in Uzbekistan

2020 ◽  
pp. 102-163
Author(s):  
Dmitry L. Konopelko ◽  
Keyword(s):  
Early Carboniferous ◽  
Tien Shan ◽  
Passive Margin ◽  
Granitoid Magmatism ◽  
Northern Margin ◽  
The North ◽  
History Of ◽  
Different Depths ◽  
Andean Type ◽  
Tectonic Settings

The Paleozoic evolution of the Southern and Middle Tien Shan terranes is generally associated with the history of two ocean basins - the Turkestan and Paleotethys. Ages of ophiolites indicate the opening of the oceans in Cambrian – Ordovician, and partial closure with formation of an island arc in the northern part of the basin in Ordovician - Silurian. At the northern margin of the Turkestan ocean, the northward subduction under the Middle Tien Shan continued until Devonian, which led to formation of an active margin with granitoids emplaced between 429 and 416 Ma. In the late Devonian, subduction-related magmatism terminated and the whole region developed as passive margin. Northward subduction resumed in the early Carboniferous and formed magmatic Andean-type belt exposed in the Chatkal-Kurama terrane. Late Carboniferous collision resulted in crust thickening and emplacement of postcollisional granitoids. Formation of postcollisional intrusions in different terranes took place in various tectonic settings. Shoshonitic granitoids of the Chatkal-Kurama terrane formed as a result of slab break off at postcollisional stage. Voluminous postcollisional magmatism of Kyzylkum can be explained by delamination of lower crust and its replacement by the material of astenospheric mantle. Coeval emplacement of geochemically contrasting granitoids in the North Nuratau fault zone could result from contemporaneous melting of different protoliths at different depths in a translithospheric shear zone.

scholarly journals Are Employees in Oil and Gas Companies More Vulnerable to Hypertension Than the General Population of Working Age? Evidence From Men and Women in Northwest of China

2021 ◽  
Author(s):  
Ying Liang ◽  
Tianle Che ◽  
Kyriacos Kyriacou ◽  
Siming Liu ◽  
Haiyue Zhang ◽  
...  
Keyword(s):  
Blood Pressure ◽  
Oil And Gas ◽  
Oil Field ◽  
Shaanxi Province ◽  
Cross Sectional ◽  
Hypertension Prevalence ◽  
Working Age ◽  
History Of ◽  
Sectional Analysis ◽  
Oil And Gas Companies

Abstract Objective To examine whether the employees of an oil and gas company in Shaanxi Province are more vulnerable to hypertension than the general residents, aged 18-60, living in the same geographical region. Design Cross-sectional analysis of the hypertension prevalence of two different population by using propensity score matching (PSM). Participants Employees of Changqing Oil Field Filiale took part in Health Risk Factors Survey (2013) and residents took part in the National Health Service Survey (2013) in Shaanxi Province, China. Main outcome measures The primary outcome was hypertention which was defined as systolic blood pressure of at least 140 mm Hg, or diastolic blood pressure of at least 90 mm Hg, or self-reported antihypertensive medication use in the previous 2 weeks, or self-reported history of hypertention. Results Changqing employees were much younger, with a higher proportion of men, and their lifestyle was less healthy, with higher BMI, more drinkers and smokers. Before PSM, hypertension prevalence of Changqing employees was slightly lower than Shaanxi residents (5.8% vs 7.6%). After PSM, the results of the adjusted logistic model showed that Changqing employees were more likely to be hypertensive (OR =1.10, 95% CI =1.02-1.19, P =0.01). Among the male samples, Changqing employees were more likely to be hypertensive (OR =1.43, 95% CI =1.31-1.58, P <0.01), while the opposite was true for the female samples (OR=0.64, 95%CI=0.56-0.73, P<0.01). Conclusion Changqing’s employees, as a whole, and male employees in particular, were more vulnerable to hypertension than the general residents of the region. However, the reverse was found for female employees.

DEPOSITIONAL HISTORY OF THE SOUTHERN TAROOM TROUGH, QUEENSLAND

1995 ◽  
Vol 35 (1) ◽  
pp. 344
Author(s):  
J.W. Beeston ◽  
O. Dixon ◽  
P.M. Green
Keyword(s):  
Oil And Gas ◽  
Oil Field ◽  
Depositional History ◽  
Oil And Gas Fields ◽  
Depositional Settings ◽  
Sediment Input ◽  
History Of ◽  
Complex Relationships ◽  
Gas Fields ◽  
Seismic Reflector

The Permian succession in the southern Taroom Trough is generally believed to be the source of hydrocarbons in the Roma Shelf oil and gas fields and the Moonie oil field. The succession is characterised by complex relationships between marine and fluvio-deltaic facies which reflect marked differences in the depositional history of the Trough.On the basis of transgressive events, the succession has been subdivided into four sedimentary cycles, the boundaries of which do not always correspond to formation boundaries or seismic horizons. Notably, the top coal in any area forms a prominent seismic reflector, but coals in individual areas can be demonstrated to occur at different stratigraphic positions relative to the major interval of coal development. These higher coals reflect changing depositional settings with time.Palaeogeographic reconstructions demonstrate a complex depositional history of sediment input onto a shallow shelf from differing directions and with different rates of input.

Geotemperature Evolution of the Ordovician Strata in the Tarim Basin and its Petroleum Geology Significance

2012 ◽  
Vol 622-623 ◽  
pp. 1638-1641
Author(s):  
Zong Lin Xiao ◽  
Qing Qing Hao ◽  
Zhong Min Shen
Keyword(s):  
Tarim Basin ◽  
Oil And Gas ◽  
Petroleum Exploration ◽  
Upper Ordovician ◽  
Tahe Oilfield ◽  
Oil Resources ◽  
Oil And Gas Resources ◽  
Steady State Heat ◽  
The One ◽  
Oil Cracking

The Tarim basin is an important petroleum basin in China, which produces a large amount of oil and gas resources. This paper calculates the geotemperature of the middle-upper Ordovician basal boundary during the main geological periods using the one-dimensional steady-state heat conduction equation. The simulation result reveals that from the late Ordovician to the present, the Manjiaer sag in the Tabei depression retains the highest temperature in the Tarim basin, and its highest temperature reaches 400°C in the present, while other areas in the Tarim basin have undergone relatively low temperature. Only in the Manjiaer sag of the Tabei depression and the Yecheng and Tanggubasi sags in the Southwest depression, the temperature exceeds 250°C, reaching the condition of liquid oil cracking into gas. Geotemperature of the middle-upper Ordovician basal boundary in the Tahe oilfield of the Central uplift is lower than 250 °C. It is thus inferred that there are abundant oil resources in the Ordovician strata of the Tahe oilfield. This study may provide effective geotemperature data for the next petroleum exploration in the Tarim basin.

NEOGENE TECTONICS IN SE AUSTRALIA: IMPLICATIONS FOR PETROLEUM SYSTEMS

2001 ◽  
Vol 41 (1) ◽  
pp. 37 ◽  
Author(s):  
J.A. Dickinson ◽  
M.W. Wallace ◽  
G.R. Holdgate ◽  
J. Daniels ◽  
S.J. Gallagher ◽  
...  
Keyword(s):  
Late Miocene ◽  
Oil And Gas ◽  
Petroleum Exploration ◽  
Petroleum Systems ◽  
Australian Plate ◽  
Late Tertiary ◽  
Petroleum Generation ◽  
History Of ◽  
Petroleum Accumulation ◽  
Gippsland Basin

The influence of Neogene tectonics in the SE Australian basins has generally been underestimated in the petroleum exploration literature. However, onshore stratigraphic and offshore seismic data indicates that significant deformation and exhumation (up to one km or more) has occurred during the late Tertiary-Quaternary. This tectonism coincides with a change in the dynamics of the Australian plate, beginning at around 12 Ma, resulting in a WNW–ESE compressional regime which has continued to the present day.Significant late Miocene tectonism is indicated by a regional angular unconformity at around the Mio-Pliocene boundary in the onshore and nearshore successions of the SE Australian basins.Evidence of on going Pliocene- Quaternary tectonism is widespread in all of the SE Australian basins. Late Tertiary tectonism has produced structures in the offshore SE Australian basins which have been favourable targets for petroleum accumulation (e.g. Nerita structure, Torquay Sub-basin; Cormorant structure, Bass Basin). In the offshore Gippsland Basin, most of the oil- and gas-bearing structures have grown during Oligocene-Recent time. Some Gippsland Basin structures were largely produced prior to the mid- Miocene, while others have a younger structural history. In areas of intense late Tertiary exhumation and uplift (e.g. proximal to the Otway and Strzelecki Ranges), burial/maturation models of petroleum generation may be significantly affected by Neogene uplift.Many structures produced by late Miocene-Pliocene deformation are dry. These relatively young structures may post-date the major maturation episodes, with the post-structure history of the basins dominated by exhumation and cooling.

HOW TO EVALUATE EXPLORATION PROSPECTS

Geophysics ◽  
1964 ◽  
Vol 29 (3) ◽  
pp. 434-444 ◽  
Author(s):  
Ben F. Rummerfield ◽  
Norman S. Morrisey
Keyword(s):  
Oil And Gas ◽  
Dominant Role ◽  
The United States ◽  
Oil Field ◽  
Petroleum Exploration ◽  
Oil Companies ◽  
The Status ◽  
Modern Business ◽  
Quantitative Analyses ◽  
Risk Cost

Analytical evaluations raise petroleum exploration from the realm of educated guessing to a quantitative decision level that is compatible with modern business techniques. Management and explorationists can thus appraise the merits of an area and/or exploration program and expect to derive optimum results with a minimum risk. All petroleum exploration programs have one common goal: To find and exploit reserves of oil and gas at a profit. Today the economic factors are playing a dominant role in the highly competitive world petroleum situation. In order to justify his existence in the forecast 70‐billion‐dollar exploration effort during the next ten years, the scientist must translate his thoughts into terms the nontechnical business man or executive can readily grasp. The obvious common language is dollars and cents in terms of anticipated profits. These economic terms transcend the semantics barrier that normally exists between the executive and the oil finder. Various methods are discussed to show how geophysicists and geologist can convert exploration factors into anticipated profit‐to‐risk ratios. The authors include examples. Significant factors contributing to a successful exploration program are: (1) The exploration and economic analysis must be compatible with, and integrated into, modern business techniques. That is, the analysis must enhance the executive’s ability to make decisions. (2) The explorationist must recognize and avoid “marginal ventures,” because 60 percent of the wells completed in the United States are submarginal economically. (3) The laws of probability must be taken into consideration when establishing an exploration program. (4) To insure success, a company must hold risks to a minimum. This can be accomplished, in part, by participating in a large number of potentially profitable ventures, and/or by taking only a part of each drilling venture rather than the entire deal. (5) Anticipated profit‐to‐risk cost ratios can be estimated for many areas. Oil companies can use this information in evaluating and accepting wildcat prospects that have at least double the normal odds of developing into a profitable oil field. The scientist who applies quantitative analyses skillfully will quickly achieve both recognition within his company and the status of a key decision‐maker in his company’s exploration program.

scholarly journals The Neogene seismic stratigraphy and uplift history of the Otago Shelf, New Zealand

2021 ◽  
Author(s):  
◽  
Michael Clark
Keyword(s):  
New Zealand ◽  
Passive Margin ◽  
Source Rocks ◽  
Lithospheric Flexure ◽  
Petroleum Generation ◽  
History Of ◽  
Sequence Boundaries ◽  
Seismic Reflection Profiles ◽  
Uplift And Erosion ◽  
Asthenospheric Upwelling

<p>The Otago continental shelf is a prospective petroleum area on the east side of the South Island New Zealand. During the Neogene it evolved from a post-rift to passive margin as giant progrades extended eastward across the shelf, fed by tectonic uplift and erosion of the Southern Alps to the west. Seismic reflection profiles reveal an uplifted limestone horizon near the Dunedin Volcano. This may be caused by a buoyant load under the lithosphere and can be spatially and temporally linked to the Dunedin Volcano and geophysical anomalies in the area.  This thesis utilises 2D and 3D seismic data to map Neogene sequence boundaries over the Otago Shelf. Seven such sequence boundaries have been mapped based on distinctive seismic characteristics above and below these surfaces. These surfaces have been tied to nearby petroleum and Integrated Ocean Drilling Project wells using biostratigraphic data and then used to generate a series of isopach and depth maps that document the Neogene evolution of this margin. The maps depict the deposition of Neogene sediment and provide age constraints to structural events in the basin such as the uplift near Dunedin and fault movement on the Endeavour High.  The maps are then used to develop a lithospheric flexure model where uplift is interpreted to have been caused by asthenospheric upwelling beneath Dunedin. The model provides insight into the conditions that led to the flexure of the lithosphere, specifically the elastic thickness of the plate and the magnitude and depth distribution of buoyant intrusive material that fed the Dunedin Volcano. Asthenospheric upwelling explains elevated heat flow around Dunedin and would result in enhanced petroleum maturity. This highlights the potential for petroleum generation in source rocks immediately offshore from Dunedin.</p>

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