An updated stratigraphic framework for the Georgina Basin, NT and Queensland

2013 ◽  
Vol 53 (2) ◽  
pp. 487 ◽  
Author(s):  
Tegan Smith ◽  
Andrew P Kelman ◽  
Robert Nicoll ◽  
Dianne Edwards ◽  
Lisa Hall ◽  
...  
Keyword(s):  
Sedimentary Rocks ◽  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Geological Time ◽  
Geological Time Scale ◽  
The Past ◽  
The North ◽  
Stratigraphic Framework ◽  
Southern Central ◽  
Siliciclastic Rock

The Georgina Basin is a Neoproterozoic to Lower Devonian sedimentary basin covering 325,000 km2 of western Queensland and the NT. It is a northwest-southeast-trending extensional basin, with prospective conventional and unconventional hydrocarbon targets in Cambrian and Ordovician carbonate and siliciclastic rock units. The unconventional gas and oil potential of the basin has led to recent exploration interest, although the basin has been relatively less explored in the past. At the southern end of the basin, depocentres contain up to 2.2 km of Cambrian to Devonian sedimentary rocks, overlying Neoproterozoic sedimentary rocks more than 1.5 km thick. The basin succession thins toward the north, where Cambrian sediments overlie the McArthur Basin sediments in the Beetaloo Sub-basin. Biostratigraphic interpretations of the prospective southern, central and eastern regions of the basin have been revised to reflect the 2012 Geological Time Scale (Gradstein, Ogg, Schmitz, and Ogg, 2012), resulting in an updated chronostratigraphic framework for the basin. The revised biostratigraphic interpretations have implications for important hydrocarbon source rocks. For example, the limestone unit in the southern parts of the basin, generally regarded as the Thorntonia Limestone, is of a different age to the type section for this unit, located in the Undilla Sub-basin. Additionally, the basal hot shale of the Arthur Creek Formation is diachronous across the Dulcie and Toko synclines, which may have ramifications for hydrocarbon exploration. This revised chronostratigraphic framework (by Geoscience Australia) for the Georgina Basin provides a baseline for the first basin-wide assessment of the unconventional hydrocarbon potential of the basin.

Palaeophysiology : the organic origin of some minerals occurring in sedimentary rocks

1917 ◽  
Vol 18 (84) ◽  
pp. 87-98 ◽  
Author(s):  
J. V. Samoilov
Keyword(s):  
Field Study ◽  
Sedimentary Rocks ◽  
First Year ◽  
Geological Exploration ◽  
The Past ◽  
The North ◽  
North Eastern ◽  
The Government ◽  
North Eastern Part ◽  
Phosphate Deposits

During the last few years I have applied myself to the study of some minerals occurring in the sedimentary rocks of a definite geological horizon. The success of my investigations was greatly favoured by the fact that the mineralogical material was collected during the course of the systematic geological exploration of the phosphate deposits of Russia, which during the past eight years has been under my immediate supervision.The explorations just mentioned were begun in the north-eastern part of European Russia, and several occurrences of barite were found in the first year during the field study of the phosphate deposits in the government of Kostroma.

scholarly journals The Kohistan between Gilgit and Chilas, northern Pakistan: regional tectonic implications

1996 ◽  
Vol 14 ◽  
Author(s):  
T. Khan ◽  
M. A. Khan ◽  
M. Q. Jan ◽  
M. Latif
Keyword(s):  
Sedimentary Rocks ◽  
Oceanic Island ◽  
Island Arc ◽  
Northern Pakistan ◽  
The Past ◽  
Volcanic Group ◽  
The North ◽  
Regional Tectonic ◽  
Back Arc ◽  
Field Geology

In this paper, we present geological description of an area located between Gilgit and Chilas within the Kohistan terrane. This terrane has been considered an intra-oceanic island arc, formed due to northward subduction of the Neo-tethyan lithospheric plate. At present, it is squeezed between the Karakoram­ Asian and Indian continental plates. Both the contacts are marked by suture zones, that is, Shyok (MKT) in the north and Indus (MMT) sutures in the south, respectively. The investigated area consists of plutonic, metamorphosed volcanic and sedimentary rocks, the Chilas Complex, and the Kamila Amphibolite. The metamorphosed volcanic and sedimentary rocks are packaged into the Jagfot Group. This group comprises basal turbiditic sediments, intercalated with amphibolites and calc-silicates (the Gilgit Formation), followed upward by the Gashu-Confluence Volcanics = Chait Volcanic Group, and finally the Thelichi Formation = Yasin Group of Aptian-Albian age. The Thelichi Formation comprises a volcanic base (Majne volcanics) and overlying turbidites, local intercalation of marbles, volcaniclastics and lava flows. Greenschist and amphibolite facies are common in the Jaglot Group, and particularly the sillimanite in the Gilgit Formation. A pair of anticline (the Gilgit anticline) and syncline (the Jaglot syncline) make up the structural scenario. On the basis of field geology, we conclude that the entire Jaglot Group and its equivalents, the Yasin Group, Chait Volcanic Group in Kohistan, and Burjila Formation, Bauma Harel Formation and Katzarah Formation in Ladakh show intra-oceanic back-arc basin rather than island arc affinities as suggested in the past.

scholarly journals Stratigraphy and age of the Eocene Igtertivâ Formation basalts, alkaline pebbles and sediments of the Kap Dalton Group in the graben at Kap Dalton, East Greenland

2013 ◽  
Vol 61 ◽  
pp. 1-18 ◽  
Author(s):  
Lotte Melchior Larsen ◽  
Erik Vest Sørensen ◽  
W. Stuart Watt ◽  
Asger Ken Pedersen ◽  
Robert A. Duncan
Keyword(s):  
Field Work ◽  
Lava Flows ◽  
Radiometric Dating ◽  
Dyke Swarm ◽  
Geological Time ◽  
Geological Time Scale ◽  
The North ◽  
Northward Propagation ◽  
Volcanic Succession ◽  
Good Agreement

A NE–SW-trending graben at Kap Dalton on the Blosseville Kyst contains an at least 600 m thick succession of Eocene basalt lavas and sediments. The succession has been investigated by new field work, geochemical analysis and radiometric dating by the 40Ar-39Ar incremental heating method. The results show that the volcanic succession comprises about 220 m of the uppermost plateau basalt formation, the Skrænterne Formation. This is separated from the overlying lava flows of the Igtertivâ Formation by 7 m of sediments that represent a period of around six million years. The two formations can be distinguished by different trace element ratios. The Igtertivâ Formation comprises an at least 300 m thick main succession of flows dated to 49.09 ± 0.48 Ma, overlain by sediments of the Bopladsdalen Formation. A basal conglomerate in the sediments contains pebbles of alkaline igneous rocks of which three were dated at 49.17 ± 0.35 Ma, 47.60 ± 0.25 Ma, and 46.98 ± 0.24 Ma. The sediments are thus younger than 47 Ma. Above 30 m of sediments occur two Igtertivâ Formation lava flows dated to 43.77 ± 1.08 Ma. The overlying sediments of the Bopladsdalen and Krabbedalen Formations are therefore not older than about 44 Ma and palynological evidence shows that they are also not much younger than this. Use of the Geological Time Scale 2012 has resulted in good agreement between radiometric and palynological ages. The Igtertivâ Formation lava flows were fed from a regional coast-parallel dyke swarm indicating a new rifting episode at 49–44 Ma. This coincides with a major mid-Eocene plate reorganisation event in the North Atlantic and the start of northward-propagation of the Reykjanes Ridge through the continent. The Igtertivâ rift may have been directly instrumental for the initiation of this process.

20 Years of Horizontal Multistage Completions: A Summary of Industry Evolution in Unconventional and Conventional Plays

2021 ◽  
Author(s):  
Alberto Casero
Keyword(s):  
Industrial Revolution ◽  
Source Rocks ◽  
Petroleum Engineering ◽  
Hydraulic Fractures ◽  
Paradigm Shifts ◽  
Geological Time ◽  
The Past ◽  
Sand Control ◽  
Recoverable Resources ◽  
The Right

Abstract In the past two decades, the advent of the Shale Gas Revolution (SGR) was made possible by the visionary idea that hydrocarbons contained in ultra-low permeability source rocks could be extracted using available technology. Usually, these hydrocarbons take geological time to migrate to higher permeability reservoir rocks until the right structural conditions evolve to extract as recoverable resources. However, paradigm shifts in drilling and completion engineering have enabled unlocking resources from these ultra-tight formations. The innovative idea at the base of this industrial revolution was the combination of horizontal well drilling and hydraulic fracturing, which allowed increasing the surface area available for hydrocarbon flow and overcame the slow and shallow hydrocarbon release from the source rock. This approach can be considered as a bridge between petroleum engineering based on radial diffusivity equation and mining engineering based on physically accessing and extracting the resource. To achieve the high number of hydraulic fractures needed for economical production, different execution techniques evolved and developed in what is known as horizontal multistage fracturing (HMSF) completions. Although HMSF is indescribably linked to SGR, it was surprisingly applied in tight gas formation and offshore sand control applications more than 30 or 40 years ago. SGR contributed to the fast development of new innovative systems engineered and deployed at scale all over North America land operations and was subsequently exported internationally in conventional, unconventional, land, and offshore applications. This paper will cover the most common HMSF completion systems types with a primary focus on unconventionals. It will encompass the evolution of these systems over the past several decades. It will also explore the opportunity case for conventional, and high permeability plays through a series of theoretical and real examples.

The Parisian Basin

2005 ◽  
Author(s):  
Yvette Dewolf ◽  
Charles Pomerol
Keyword(s):  
Sedimentary Basins ◽  
Geological Time ◽  
Geological Time Scale ◽  
Massif Central ◽  
North East ◽  
The North ◽  
Geological Map ◽  
Intracratonic Basin ◽  
Definition Of ◽  
Armorican Massif

The Parisian basin is a geographical entity whose limits are easily defined by the Armorican massif, the Massif Central, the Vosges, the Ardennes, and the English Channel. Both Burgundy and Poitou are transitional areas. The Paris basin, a more restrictive term, corresponds according to some geologists (Cavelier and Lorenz 1987) essentially to the Tertiary ‘part’ of the basin: the Île de France and surroundings. The relief of the Parisian basin results from two sets of factors: tectonic and climatic. These have operated from Triassic times until the Pleistocene and have led to the development of a geographically simple whole in its gross structure and form. However, within this framework individual natural regions (or geotypes) may be recognized. The Parisian basin is frequently considered as a model for sedimentary basins, displaying as it does, a classic framework of sedimentary formations (Pomerol 1978; Cavelier and Pomerol 1979; Cavelier et al. 1979; Pomerol and Feugueur 1986; Debrand-Passard 1995). This is evident from the geological map of France, and on the related cross-section. Indeed, the section shows the superposition of strata in a subsiding area, with a maximal thickness (3,200 m) in the Brie country. This arrangement illustrates the geometric definition of the Parisian basin, an intracratonic basin, 600 km in diameter, limited towards the west by the Armorican massif, the south by the Massif Central, the east by the Vosges, and the north-east by the Ardenno-Rhenan massif. The following geological overview is based upon the previously mentioned studies and the geological time scale. However, the analysis of the evolution of these sedimentary areas from Triassic to Neogene shows that the area named as the ‘Parisian basin’ was included in successive palaeogeographies (which were strongly influenced by adjacent seas) and overflowed across the basement regions that now act as the limits of the basin. The chronological order of the geological formations involved in the evolution of the Parisian basin according to Robin et al. (2000) is used in the following text. During the Triassic, the future Parisian basin was a gulf of the German Sea. This sea transgressed westwards and reached the meridian of Paris during the Keuper.

GREENSAND RESERVOIRS IN SILICICLASTIC SHORELINE SYSTEMS: FACIES MODELS FOR HYDROCARBON EXPLORATION

1998 ◽  
Vol 38 (2) ◽  
pp. 132
Author(s):  
I.A. Dyson
Keyword(s):  
Oil And Gas ◽  
Depositional Environments ◽  
Sediment Supply ◽  
Hydrocarbon Exploration ◽  
Correct Identification ◽  
North West ◽  
Sequence Stratigraphic ◽  
The North ◽  
Stratigraphic Framework ◽  
Physical And Chemical

Greensand reservoirs are particularly significant in siliciclastic shoreline systems. Formation of autochthonous glauconite is restricted almost exclusively to the rising limb of the relative sea level (RSL) curve. Depositional environments that are typically developed in response to a rise in RSL are estuaries, barrier bars and shoreface sands. In this setting, the greensands are diachronous and exploration for hydrocarbon reservoirs should ideally be based on a sequence stratigraphic framework. These deposits are characterised by a number of significant surfaces that differ greatly in their origin, geographic extent and chronostratigraphic significance, and their thickness depends on the rate of RSL rise and sediment supply. The identification of significant surfaces bounding or contained within depositional sequences is critical, especially where drillhole samples are either unreliable or not available for geochemical and palynological analysis. Abrupt physical and chemical changes often occur on or across these surfaces, e.g. porosity, permeability and the presence of Fe-rich authigenic minerals such as glauconite and siderite. Greensands deposited in estuarine, barrier bar and shoreforce environments have excellent oil and gas potentail. Early Cretaceous greensand reservoirs from the North West Shelf are best developed where they overlie ravinement surfaces. Recognition of greensands within estuarine, barrier bar and shoreface environments is dependent on the correct identification of facies and the subsequent interpretation of the bounding discontinuities.

scholarly journals An updated and revised stratigraphic framework for the Miocene and earliest Pliocene strata of the Roer Valley Graben and adjacent blocks

2019 ◽  
Vol 98 ◽  
Author(s):  
Dirk K. Munsterman ◽  
Johan H. ten Veen ◽  
Armin Menkovic ◽  
Jef Deckers ◽  
Nora Witmans ◽  
...  
Keyword(s):  
The Netherlands ◽  
Seismic Reflection ◽  
Regional Scale ◽  
Seismic Facies ◽  
Well Log ◽  
Geological Time ◽  
Geological Time Scale ◽  
Seismic Reflection Data ◽  
Stratigraphic Framework ◽  
Roer Valley Graben

Abstract In the Netherlands, the bulk of the Miocene to lowest Pliocene sedimentary succession is currently assigned to a single lithostratigraphical unit, the Breda Formation. Although the formation was introduced over 40 years ago, the definition of its lower and upper boundaries is still problematic. Well-log correlations show that the improved lecto-stratotype for the Breda Formation in well Groote Heide partly overlaps with the additional reference section of the older Veldhoven Formation in the nearby well Broekhuizenvorst. The distinction between the Breda and the overlying Oosterhout Formation, which was mainly based on quantitative differences in glauconite and molluscs, gives rise to ongoing discussion, in particular due to the varying concentrations of glauconitic content that occur within both formations. In addition, the Breda Formation lacks a regional-scale stratigraphic framework which relates its various regionally to locally defined shallow marine to continental members. In order to resolve these issues, we performed renewed analyses of material from several archived cores. The results of archived and new dinocyst analyses were combined with lithological descriptions and wire-line log correlations of multiple wells, including the wells Groote Heide and Broekhuizenvorst. In this process, the updated dinocyst zonation of Munsterman & Brinkhuis (2004), recalibrated to the Geological Time Scale of Ogg et al. (2016), was used. To establish regionally consistent lithostratigraphic boundaries, additional data was used along a transect across the Roer Valley Graben running from its central part (well St-Michielsgestel-1) towards the southern rift shoulders (well Goirle-1). Along this transect, chronostratigraphic and lithostratigraphic analyses were integrated with well-log correlation and the analyses of seismic reflection data to constrain geometrical/structural relationships as well. The results led to the differentiation of two distinct seismic sequences distinguished by three recognisable unconformities: the Early Miocene Unconformity (EMU), the Mid-Miocene Unconformity (MMU) and the Late Miocene Unconformity (LMU). The major regional hiatus, referred to as the Mid-Miocene Unconformity, occurs intercalated within the present Breda Formation and compels subdivision of this unit into two formations, viz. the here newly established Groote Heide and the younger Diessen formations. Pending further studies, the former Breda Formation will be temporally raised in rank to the newly established Hilvarenbeek subgroup, which comprises both the Groote Heide and Diessen formations. Whereas these two sequences were already locally defined, a third sequence overlying the LMU represents two newly defined lithostratigraphical units, named the Goirle and the Tilburg members, positioned in this study at the base of the Oosterhout Formation. Besides their unique lithological characteristics, in seismic reflection profiles the Goirle and the Tilburg members stand out because of their distinct seismic facies. Use of an integrated, multidisciplinary and regional approach, an improved southern North Sea framework and more comprehensive lithostratigraphic subdivision of Neogene successions is proposed for the Netherlands, to make (cross-border) correlations more straightforward in the future.

scholarly journals A deep geoelectrical survey in the Southern Central Alps

1994 ◽  
Vol 37 (5 Sup.) ◽  
Author(s):  
L. Alfano ◽  
G. Lorenzoni ◽  
C. Melandri ◽  
M. Mocchi ◽  
G. Nuttini ◽  
...  
Keyword(s):  
Sedimentary Rocks ◽  
Electrode Array ◽  
High Resistivity ◽  
Central Alps ◽  
Data Set ◽  
The North ◽  
Geological Models ◽  
Southern Central ◽  
Very High ◽  
Upper Boundary

A deep geoelectrical survey was carried out on the Southern Central AIps, to the north of Bergamo, by means of the “continuous polar dipole-dipole” electrode array. Among the 6 profiles executed, 4 revealed the existence of a substratum with very high resistivity values (15 000-40 000 ohm.m) and a flat not very deep upper boundary; its thickness exceeds the maximum expIoration depths of the soundings (1 to 6 km). On the grounds of general considerations and resistivity field data set, it is possible to infer that the high values should be ascribed to endogenous rather than to sedimentary rocks. A problem arises since these geophysical results are not in agreement with some geological models.

Interrogating the Constitutionality of Federal Character Principle in Nigeria

2018 ◽  
Vol 9 (07) ◽  
pp. 20492-20498
Author(s):  
Aborisade Olasunkanmi ◽  
Christopher Agulanna
Keyword(s):  
Ethnic Groups ◽  
Research Work ◽  
National Unity ◽  
The Past ◽  
The North ◽  
Inhibiting Factors

This work interrogates federal character principle (FCP) in Nigeria. The FCP was designed to fundamentally address the striking features of Nigeria politics of intense struggles for power among the different ethnic groups in the country between the elites from the North and their Southern counterparts and the various segments, but the practice of FCP in Nigeria so far raises curiosity and doubts. Given the outcome of the interrogation, this research work discovered and conclude that federal character has not indeed achieve its objective in the Nigeria, the study finds that Ethnocentrism, Elitism, Mediocrity, Mutual suspicion amongst others accounts for some inhibiting factors of the FCP in Nigeria. Like many other provisions of the Constitution, the Federal Character principle was meant to correct some imbalances experienced in the past, but it has created more problems than it has attempted to solve. Rather than promote national unity, it has disunited Nigerians. There is an urgent need to use more of professionals and result oriented Nigerians to carry out national tasks, than to use unprogressive people due to this "Federal character" issue. Nigeria should be a place where one's track records and qualifications are far greater than just "where they come from" or their lineage if Nigerian truly want to progress.

Oil to Source Rock Correlation Using Biomarker Data Through Pattern Matching and Fingerprinting Analysis in “Kitkat” Field, Jabung Block, South Sumatra Basin

2020 ◽  
Author(s):  
S., R. Muthasyabiha
Keyword(s):  
Pattern Matching ◽  
Source Rock ◽  
Vitrinite Reflectance ◽  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Maturity Level ◽  
Fingerprinting Analysis ◽  
Kerogen Type ◽  
Oil Characteristics ◽  
Biomarker Data

Geochemical analysis is necessary to enable the optimization of hydrocarbon exploration. In this research, it is used to determine the oil characteristics and the type of source rock candidates that produces hydrocarbon in the “KITKAT” Field and also to understand the quality, quantity and maturity of proven source rocks. The evaluation of source rock was obtained from Rock-Eval Pyrolysis (REP) to determine the hydrocarbon type and analysis of the value of Total Organic Carbon (TOC) was performed to know the quantity of its organic content. Analysis of Tmax value and Vitrinite Reflectance (Ro) was also performed to know the maturity level of the source rock samples. Then the oil characteristics such as the depositional environment of source rock candidate and where the oil sample develops were obtained from pattern matching and fingerprinting analysis of Biomarker data GC/GCMS. Moreover, these data are used to know the correlation of oil to source rock. The result of source rock evaluation shows that the Talangakar Formation (TAF) has all these parameters as a source rock. Organic material from Upper Talangakar Formation (UTAF) comes from kerogen type II/III that is capable of producing oil and gas (Espitalie, 1985) and Lower Talangakar Formation (LTAF) comes from kerogen type III that is capable of producing gas. All intervals of TAF have a quantity value from very good–excellent considerable from the amount of TOC > 1% (Peters and Cassa, 1994). Source rock maturity level (Ro > 0.6) in UTAF is mature–late mature and LTAF is late mature–over mature (Peters and Cassa, 1994). Source rock from UTAF has deposited in the transition environment, and source rock from LTAF has deposited in the terrestrial environment. The correlation of oil to source rock shows that oil sample is positively correlated with the UTAF.

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