scholarly journals Rock-Eval pyrolysis data for petroleum-potential evaluation based on well cuttings and core samples from eastern Nevada collected during 1990

1990 ◽  
Author(s):  
C.E. Barker ◽  
R.C. Johnson ◽  
F.G. Poole ◽  
T.A. Daws ◽  
C.N. Threlkeld
Keyword(s):  
Petroleum Potential ◽  
Core Samples ◽  
Potential Evaluation ◽  
Rock Eval

GEOCHEMICAL CHARACTERISTIC OF THE SILURIAN ROCKS FROM THE EASTERN PART OF MOLDAVIAN PLATFORM (ROMANIA)

2021 ◽  
Vol 16 (1) ◽  
pp. 17-30
Author(s):  
Octavian COLŢOI ◽  
◽  
Flori CULESCU ◽  
Gilles NICOLAS
Keyword(s):  
Organic Matter ◽  
Geochemical Characteristic ◽  
Petroleum Potential ◽  
The North ◽  
North Eastern ◽  
High Maturity ◽  
Cap Rock ◽  
Rock Eval ◽  
Part Thickness ◽  
North Eastern Part

The scope of this paper is to assess the hydrocarbon potential of Silurian, respectively, the maturity of this stratigraphical interval, based, especially, of the geological and geophysical data derived from eight boreholes located in the north-eastern part of Moldavian Platform - Romania. The main conclusion is that the organic matter contents measured in the core and cutting samples of the different wells are low with the Organic Carbon (TOC) (residual) mainly clearly lower than 1%. Due to the poorness of the sample and the high maturity the petroleum potential and organic matter cannot be assessed. Estimation of the initial TOC allows to differentiate a richer interval at 24 – 27m thick below the top of Silurian. It shows higher TOC with estimated initial TOC reaching 3.6 % weight at the most. The maturity is high and shows a rapid increase with depth between around 2% at 200m and 4% eq. VRr at 1100m. An estimation of the eroded cap-rock is of around 3000m. Mineral carbon content obtained from Rock Eval permits to separate two lithological intervals: carbonated in the upper part (thickness of 250-300m), argillaceous in the lower part.

Use of Tmax as a thermal maturity indicator in orogenic successions and comparison with clay mineral evolution

Clay Minerals ◽  
2010 ◽  
Vol 45 (1) ◽  
pp. 115-130 ◽  
Author(s):  
F. Dellisanti ◽  
G. A. Pini ◽  
F. Baudin
Keyword(s):  
Strong Relationship ◽  
Thermal Maturity ◽  
Petroleum Potential ◽  
Short Range Ordering ◽  
Formation Zone ◽  
Organic Matter Type ◽  
Rock Eval ◽  
Mixed Layers ◽  
The Relationship ◽  
Oil Formation

AbstractThe relationship between three parameters, the Tmax given by Rock-Eval pyrolysis, the illite content in illite-smectite mixed layers (I-S) and the Ku¨bler Index (KI) has been investigated in the Cretaceous–Neogene, sedimentary syn-orogenic successions in the Northern Apennines (Italy). A strong relationship was found between maturity stages of kerogen, illite content in I-S and KI. The oil formation zone for continental organic matter (Type III), delimited by Tmax between 434 and 465ºC, corresponded to rocks with short-range ordering R1, I-S with illite content between 60 and 85% and KI values in the range 0.85–0.65 (ºΔ2θ). Over-mature rocks were characterized by Tmax >465ºC, a long-range ordered I-S with an illite content >85% and KI in the range 0.65–0.45 (ºΔ2θ). The relationship permits use of both mineralogical parameters and Tmax to estimate palaeotemperatures in sedimentary successions and it can be exploited in hydrocarbon research to evaluate the petroleum potential.

scholarly journals Optical (visual) Kerogen assessment of Enugu Shale, Anambra Basin, Southeastern Nigeria: Implications for source rock potential and thermal maturation

2021 ◽  
Vol 19 (1) ◽  
pp. 123-132
Author(s):  
Osita Igwebuike Chiaghanam ◽  
Okechukwu Nicodemus Ikegwuonu ◽  
Chikodi Jennifer Ekwegbalu ◽  
Emmanuel Ude Aniwetalu ◽  
Kingsley Chukwuebuka Chiadikobi
Keyword(s):  
Source Rock ◽  
Sedimentary Basins ◽  
Geochemical Data ◽  
Carbonaceous Shale ◽  
Thermal Alteration ◽  
Southeastern Nigeria ◽  
Petroleum Potential ◽  
Anambra Basin ◽  
Kerogen Type ◽  
Rock Eval

Palynological analysis was carried out on Ten (10) samples from outcrops of the Campanian Enugu Formation, a component  lithostratigraphic unit of the Anambra Basin, using the acid maceration techniques for recovering acidinsoluble organic-walled microfossils. Two main lithological units were encountered, which include: carbonaceous shale and siltstone. Result from kerogen  laboratory examination reveals two (2) main groups of palynofacies association namely; palynofacies (A and B), based on the change in particulate organic matter constituents of organic residue extract. Palynofacies A is characterized by abundant opaques debris with common terrestrial phytoclasts, which occupy the southwestern and northwestern parts of the studied area, whereas palynofacies B  dominates in the northeastern part, characterised by abundant phytoclasts followed by frequent opaques debris. Kerogen type III with gas-prone material is suggested for both palynofacies. The examined exine of spore/ pollen grain are pale yellow – yellow, with Thermal Alteration Index TAI of 1+ to 2- and Vitrinite Reflectane (R o) (0.3 % - 0.4 %) in palynofacies A, and yellow – yellow brown, with Thermal Alteration Index TAI of 2- to 2, and Vitrinite Reflectane (R o) of 0.3% - 0.5% in palynofacies B. These revealed source rock that is thermally immature to slightly mature but has potential to generate mainly gas. The kerogen data generated using transmitted light microscopy correlated well with geochemical data obtained using rock-eval pyrolysis method, and this shows the method a reliable tool for assessing  petroleum potential in any given sedimentary basins.

GEOCHEMICAL TOOLS FOR EVALUATING PETROLEUM GENERATION IN MIDDLE PROTEROZOIC SEDIMENTS OF THE McARTHUR BASIN, NORTHERN TERRITORY, AUSTRALIA

1994 ◽  
Vol 34 (1) ◽  
pp. 692 ◽  
Author(s):  
Roger E. Summons ◽  
Dennis Taylor ◽  
Christopher J. Boreham
Keyword(s):  
Vitrinite Reflectance ◽  
Land Plant ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Strongly Correlated ◽  
Petroleum Potential ◽  
Petroleum Generation ◽  
Early Palaeozoic ◽  
Geochemical Analyses ◽  
Rock Eval

Maturation parameters based on aromatic hydrocarbons, and particularly the methyl-phenanthrene index (MPI-1), are powerful indicators which can be used to define the oil window in Proterozoic and Early Palaeozoic petroleum source rocks and to compare maturities and detect migration in very old oils . The conventional vitrinite reflectance yardstick for maturity is not readily translated to these ancient sediments because they predate the evolution of the land plant precursors to vitrinite. While whole-rock geochemical tools such as Rock-Eval and TOC are useful for evaluation of petroleum potential, they can be imprecise when applied to maturity assessments.In this study, we carried out a range of detailed geochemical analyses on McArthur Basin boreholes penetrating the Roper Group source rocks. We determined the depth profiles for hydrocarbon generation based on Rock-Eval analysis of whole-rock, solvent-extracted rock, kerogen elemental H/C ratio and pyrolysis GC. Although we found that Hydrogen Index (HI) and the Tmax parameter were strongly correlated with other maturation indicators, they were not sufficiently sensitive nor were they universally applicable. Maturation measurements based on saturated biomarkers were not useful either because of the low abundance of these compounds in most Roper Group bitumens and oils.

scholarly journals Source Rock Evaluation of the Upper Triassic Baluti Formation in Bekhme-1 and Gulak-1 Wells from Akri-Bijeel Block, Kurdistan-Iraq

2021 ◽  
Vol 5 (1) ◽  
pp. 50-59
Author(s):  
Ayad N. F. Edilbi ◽  
Kamal Kolo ◽  
Blind F. Khalid ◽  
Mardin N. Muhammad Salim ◽  
Sana A. Hamad ◽  
...  
Keyword(s):  
Source Rock ◽  
Upper Triassic ◽  
Organic Carbon Content ◽  
Hydrocarbon Generation ◽  
Petroleum Potential ◽  
Fold And Thrust Belt ◽  
Potential Source Rock ◽  
Source Rock Evaluation ◽  
Area North ◽  
Rock Eval

This study reports on the petroleum potential of the Upper Triassic Baluti Formation in Bekhme-1 and Gulak-1 Wells from Akri¬-Bijeel Block within the Bekhme Anticline area, North of Erbil City. The area is a part of the Zagros Fold and Thrust Belt, and is locally situated within the High Folded Zone. Typically, the Baluti Formation is composed of gray and green shale calcareous dolomite with intercalations of thinly bedded dolomites, dolomitic limestones, and silicified limestones which in places are brecciated. The geochemical indicators obtained from Rock-Eval pyrolysis of Baluti samples gave Total Organic Carbon content (TOC wt. %) average values of 0.15 and 0.18 wt. % and potential hydrocarbon content (S2) average values of 0.78 mg HC/g rock and 0.58 mg HC/g rock for Bekhme-1 and Gulak-1 respectively, suggesting a source rock of poor potential. The type of organic matter is of mixed type II-III and III kerogens with an average Tmax value of 440 °C for both boreholes, exhibiting early to peak stage of thermal maturity. Considering the results of this study, it is concluded that Baluti Formation in the studied area can not be regarded as a potential source rock for hydrocarbon generation.

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