Regional Hydrocarbon Source Rock and Thermal Maturity Evaluation of Ogaden Basin, Ethiopia: ABSTRACT

AAPG Bulletin ◽  
1979 ◽  
Vol 63 ◽  
Author(s):  
P. W. Cayce, Byrl D. Carey, Jr.
Keyword(s):  
Source Rock ◽  
Thermal Maturity ◽  
Hydrocarbon Source Rock ◽  
Maturity Evaluation

scholarly journals Organic geochemical and palynological studies of the Maastrichtian source rock intervals in Bida Basin, Nigeria: implications for hydrocarbon prospectivity

2020 ◽  
Vol 10 (8) ◽  
pp. 3191-3206
Author(s):  
Olusola J. Ojo ◽  
Ayoola Y. Jimoh ◽  
Juliet C. Umelo ◽  
Samuel O. Akande
Keyword(s):  
Organic Matter ◽  
Source Rock ◽  
Vitrinite Reflectance ◽  
Source Rocks ◽  
High Yield ◽  
Thermal Maturity ◽  
Hydrocarbon Source Rock ◽  
Moderate Amount ◽  
Oxic Condition ◽  
Freshwater Swamp

Abstract The Patti Formation which consists of sandstone and shale offers the best potential source beds in the Bida Basin. This inland basin is one of the basins currently being tested for hydrocarbon prospectivity in Nigeria. Fresh samples of shale from Agbaja borehole, Ahoko quarry and Geheku road cut were analysed using organic geochemical and palynological techniques to unravel their age, paleoecology, palynofacies and source bed hydrocarbon potential. Palynological data suggest Maastrichtian age for the sediments based on the abundance of microfloral assemblage; Retidiporites magdalenensis, Echitriporites trianguliformis and Buttinia andreevi. Dinocysts belonging to the Spiniferites, Deflandrea and Dinogymnium genera from some of the analysed intervals are indicative of freshwater swamp and normal sea conditions. Palynological evidence further suggests mangrove paleovegetation and humid climate. Relatively high total organic carbon TOC (0.77–8.95 wt%) was obtained for the shales which implies substantial concentration of organic matter in the source beds. Hydrocarbon source rock potential ranges from 0.19 to 0.70 mgHC/g.rock except for a certain source rock interval in the Agbaja borehole with high yield of 25.18 mgHC/g.rock. This interval also presents exceptionally high HI of 274 mgHC/g.TOC and moderate amount of amorphous organic matter. The data suggests that in spite of the favourable organic matter quantity, the thermal maturity is low as indicated by vitrinite reflectance and Tmax (0.46 to 0.48 Ro% and 413 to 475 °C, respectively). The hydrocarbon extracts show abundance of odd number alkanes C27–C33, low sterane/hopane ratio and Pr/Ph > 2. We conclude that the source rocks were terrestrially derived under oxic condition and dominated by type III kerogen. Type II organic matter with oil and gas potential is a possibility in Agbaja area of Bida Basin. Thermal maturity is low and little, or no hydrocarbon has been generated from the source rocks.

scholarly journals Project 'Nordolie': hydrocarbon source rock investigations in central North Greenland

1985 ◽  
Vol 125 ◽  
pp. 17-21
Author(s):  
F.G Christiansen ◽  
F Rolle
Keyword(s):  
Source Rock ◽  
Research Programme ◽  
Source Rocks ◽  
Petroleum Geology ◽  
General Knowledge ◽  
Thermal Maturity ◽  
Reservoir Properties ◽  
Hydrocarbon Source Rock ◽  
Lower Priority ◽  
North Greenland

The project 'Nordolie' was initiated under the Danish Ministry of Energy's Research Programme 1983. The aim of the project is to obtain general knowledge about the source rock geology of central North Greenland. Similar investigations have previously been carried out in eastern North Greenland (Rolle, 1981; Rolle & Wrang, 1981). The main purpose of the project is to study the presence and distribution of potential hydrocarbon source rocks in the region and to evaluate the thermal maturity pattern. Studies of reservoir properties, trapping possibilities, and other aspects of petroleum geology will accordingly have a much lower priority.

scholarly journals The Silurian shales of central and western North Greenland: evaluation of hydrocarbon source rock potential

1989 ◽  
Vol 143 ◽  
pp. 47-71
Author(s):  
F.G Christiansen ◽  
H Nøhr-Hansen
Keyword(s):  
Organic Matter ◽  
Source Rock ◽  
Black Shales ◽  
Drainage Area ◽  
Source Rocks ◽  
Thermal Maturity ◽  
Hydrocarbon Source Rock ◽  
Potential Source ◽  
Drastic Increase ◽  
North Greenland

The Silurian shales of central and western North Greenland form a more than 400 m thick succession which contains some potential hydrocarbon source rock intervals. Deposition of these organic-rich units was restricted in both time and space and potential source rocks only formed when and where black shales covered wide areas of sballow-water carbonates. Such deposition started in the middle Llandovery in Washington Land and continued tboughout the region in the late Llandovery. Neither the Wenlock nor the Ludlow shales contain sufficient organic matter to be considered as potential source rocks. The potential source rocks are dominated by oil-prone organic matter (large amorphous kerogen particles, mainly type Il) and typically show TOC values between 2% and 6%. The generative potential of immature to early mature samples is high with values up to 30 mg Hag rock. A drastic increase in thermal maturity of surface rocks is observed from south to north and most of the potential drainage area is thermally mature to postmature. This leaves only few chances of finding trapped hydrocarbons sourced by Silurian shales in North Greenland.

scholarly journals The Cambrian Henson Gletscher Formation: a mature to postmature hydrocarbon source rock sequence from North Greenland

1987 ◽  
Vol 133 ◽  
pp. 141-157
Author(s):  
F.G Christiansen ◽  
H Nøhr-Hansen ◽  
O Nykjær
Keyword(s):  
Source Rock ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Hydrocarbon Source Rock ◽  
Reservoir Rocks ◽  
Potential Source ◽  
Potential Reservoir ◽  
Field Season ◽  
North Greenland

During the 1985 field season the Cambrian Henson Gletscher Formation in central North Greenland was studied in detail with the aim of evaluating its potential as a hydrocarbon source rock. The formation contains organic rich shale and carbonate mudstone which are considered to be potential source rocks. These are sedimentologically coupled with a sequence of sandstones and coarse carbonates which might be potential reservoir rocks or migration conduits. Most of the rocks exposed on the surface are, however, thermally mature to postrnature with respect to hydrocarbon generation, leaving only few chances of finding trapped oil in the subsurface of the area studied in detail.

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