scholarly journals Distribution of Some Diamondoids in Crude Oils from Niger Delta Basin

2019 ◽  
Vol 2 (2) ◽  
Keyword(s):  
Niger Delta ◽  
Oil Fields ◽  
Crude Oils ◽  
Good For ◽  
Niger Delta Basin

Some Niger Delta oils were studied for the presence of diamondoids in the oils. Oils were obtained from a well each from their respective oil fields. The objectives of the study include identification of diamondoids in the oils, use of parametric ratios to delineate biodegradation and maturity of the oils. The m/z 136 show the presence of Adamantane and the m/z135 showed the presence of 1-Methyladamantane, 2–Methyladamantane, 1–Ethyladamantane and 2-Ethyladamantanein the oils. The nC17/Pr and nC17+nC18/(Pr+Ph) showed good biodegradation trend for the oils. 1MA/nC11 and nC17+nC18/(Pr+Ph plot did not show a good biodegradation gradient though of similar trend. 1MA/ nC11 showed a restricted spread. The plot 1MA/nC11 and 1MA+2MA/A showed a better spread for 1MA+2MA/A. The1MA/1MA+2MA (Methyladamantane index) showed a better maturity gradient and is good for the Nigerian oils but the 1EA/1EA+2EA (Ethyladamantane index) showed restricted spread for a good maturity gradient and may be better for higher matured oils than the Niger delta Oils.

Geochemical investigation of trace elements in crude oils from two different depobelts in the Niger Delta basin, Nigeria

2017 ◽  
Vol 36 (2) ◽  
pp. 130-135 ◽  
Author(s):  
Oluwabamise L. Faboya ◽  
Abiodun A. Ojo ◽  
Hafsat Bello ◽  
Ilesanmi Osasona
Keyword(s):  
Trace Elements ◽  
Niger Delta ◽  
Crude Oils ◽  
Geochemical Investigation ◽  
Niger Delta Basin

scholarly journals Determination of Geothermal Gradient from Bore Hole Temperature data in Some Parts of the Eastern Niger Delta Basin

2021 ◽  
pp. 39-46
Author(s):  
E. D. Uko ◽  
M. A. Alabraba ◽  
I. Tamunoberetonari ◽  
A. O. Oki
Keyword(s):  
Niger Delta ◽  
Good Reason ◽  
Geothermal Gradient ◽  
Temperature Data ◽  
Oil Fields ◽  
Basin Evolution ◽  
Geothermal Gradients ◽  
Oil Hydrocarbons ◽  
Niger Delta Basin

An analysis of Geothermal Gradients in the Eastern Niger Delta basin was done using Bore Hole Temperature (BHT) data from three (3) adjacent oil fields. BHT data was converted to static formation temperature by using the conventional method of increasing measured BHT data by 10% and Geothermal Gradient computed using its simple linear relationship with depth, surface temperature and static temperature at depth. Projections were then made for change in Geothermal gradients at 1km intervals to a depth of 4 km. Results obtained showed significant variations across Idama, Inda and Robertkiri fields with average geothermal gradients of 17.3⁰C/Km, 22.6⁰C/Km and 23.1⁰C/Km respectively. Variation in the geothermal gradients in the area is attributed to lithological control and differential rates of sedimentation during basin evolution. Also, results showed that the Geothermal Gradient in the area are generally moderate and could be a good reason for the occurrence of more oil hydrocarbons than gas in the area.

Lithofacies Analysis and Qualitative Minerology of the Sediments of #3 Well in the Greater Ughelli Depobelt, Niger Delta Basin

2021 ◽  
Vol 13 (2) ◽  
pp. 601-610
Author(s):  
K. Itiowe ◽  
R. Oghonyon ◽  
B. K. Kurah
Keyword(s):  
Physical Properties ◽  
Clay Minerals ◽  
Niger Delta ◽  
Reservoir Quality ◽  
X Ray Diffraction ◽  
X Ray ◽  
Sandy Shale ◽  
Heterogeneous Nature ◽  
Niger Delta Basin ◽  
Shaly Sandstone

The sediment of #3 Well of the Greater Ughelli Depobelt are represented by sand and shale intercalation. In this study, lithofacies analysis and X-ray diffraction technique were used to characterize the sediments from the well. The lithofacies analysis was based on the physical properties of the sediments encountered from the ditch cuttings.  Five lithofacies types of mainly sandstone, clayey sandstone, shaly sandstone, sandy shale and shale and 53 lithofacies zones were identified from 15 ft to 11295 ft. The result of the X-ray diffraction analysis identified that the following clay minerals – kaolinite, illite/muscovite, sepiolite, chlorite, calcite, dolomite; with kaolinite in greater percentage. The non-clay minerals include quartz, pyrite, anatase, gypsum, plagioclase, microcline, jarosite, barite and fluorite; with quartz having the highest percentage. Therefore, due to the high percentage of kaolinite in #3 well, the pore filing kaolinite may have more effect on the reservoir quality than illite/muscovite, chlorite and sepiolite. By considering the physical properties, homogenous and heterogeneous nature of the #3 Well, it would be concluded that #3 Well has some prospect for petroleum and gas exploration.

Sedimentary facies and petrographic analyses of Miocene nearshore deposits, Central Swamp Depobelt, onshore Niger Delta Basin: implications for reservoir quality

2021 ◽  
Author(s):  
Joseph Nanaoweikule Eradiri ◽  
Ehimare Erhire Odafen ◽  
Ikenna Christopher Okwara ◽  
Ayonma Wilfred Mode ◽  
Okwudiri Aloysius Anyiam ◽  
...  
Keyword(s):  
Niger Delta ◽  
Sedimentary Facies ◽  
Reservoir Quality ◽  
Petrographic Analyses ◽  
Niger Delta Basin

Evaluation of Reservoir’s Petrophysical Parameters, Niger Delta, Nigeria

2017 ◽  
Vol 5 (1) ◽  
pp. 19
Author(s):  
Ubong Essien ◽  
Akaninyene Akankpo ◽  
Okechukwu Agbasi
Keyword(s):  
Niger Delta ◽  
Gamma Ray ◽  
Water Saturation ◽  
Petrophysical Parameters ◽  
Niger Delta Region ◽  
Average Porosity ◽  
Irreducible Water Saturation ◽  
Open Hole ◽  
Bulk Volume ◽  
Niger Delta Basin

Petrophysical analysis was performed in two wells in the Niger Delta Region, Nigeria. This study is aimed at making available petrophysical data, basically water saturation calculation using cementation values of 2.0 for the reservoir formations of two wells in the Niger delta basin. A suite of geophysical open hole logs namely Gamma ray; Resistivity, Sonic, Caliper and Density were used to determine petrophysical parameters. The parameters determined are; volume of shale, porosity, water saturation, irreducible water saturation and bulk volume of water. The thickness of the reservoir varies between 127ft and 1620ft. Average porosity values vary between 0.061 and 0.600; generally decreasing with depth. The mean average computed values for the Petrophysical parameters for the reservoirs are: Bulk Volume of Water, 0.070 to 0.175; Apparent Water Resistivity, 0.239 to 7.969; Water Saturation, 0.229 to 0.749; Irreducible Water Saturation, 0.229 to 0.882 and Volume of Shale, 0.045 to 0.355. The findings will also enhance the proper characterization of the reservoir sands.

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