Sustainable management and characterization of groundwater resource in coastal aquifer of Niger delta basin Nigeria

2021 ◽  
Vol 7 (4) ◽  
Author(s):  
Moses Oghenenyoreme Eyankware ◽  
Obinna Chigoziem Akakuru ◽  
Ruth Oghenerukevwe Eyankware Ulakpa ◽  
Oghenegare Emmanuel Eyankware
Keyword(s):  
Coastal Aquifer ◽  
Niger Delta ◽  
Sustainable Management ◽  
Groundwater Resource ◽  
Niger Delta Basin

scholarly journals Characterization of reservoir sands using 3D seismic attributes in the coastal swamp area of Niger Delta Basin

2021 ◽  
Author(s):  
Oluwatoyin Khadijat Olaleye ◽  
Pius Adekunle Enikanselu ◽  
Michael Ayuk Ayuk
Keyword(s):  
Seismic Data ◽  
Niger Delta ◽  
Seismic Attributes ◽  
Effective Porosity ◽  
High Porosity ◽  
Hydrocarbon Accumulation ◽  
3D Seismic ◽  
Seismic Attribute ◽  
Niger Delta Basin

AbstractHydrocarbon accumulation and production within the Niger Delta Basin are controlled by varieties of geologic features guided by the depositional environment and tectonic history across the basin. In this study, multiple seismic attribute transforms were applied to three-dimensional (3D) seismic data obtained from “Reigh” Field, Onshore Niger Delta to delineate and characterize geologic features capable of harboring hydrocarbon and identifying hydrocarbon productivity areas within the field. Two (2) sand units were delineated from borehole log data and their corresponding horizons were mapped on seismic data, using appropriate check-shot data of the boreholes. Petrophysical summary of the sand units revealed that the area is characterized by high sand/shale ratio, effective porosity ranged from 16 to 36% and hydrocarbon saturation between 72 and 92%. By extracting attribute maps of coherence, instantaneous frequency, instantaneous amplitude and RMS amplitude, characterization of the sand units in terms of reservoir geomorphological features, facies distribution and hydrocarbon potential was achieved. Seismic attribute results revealed (1) characteristic patterns of varying frequency and amplitude areas, (2) major control of hydrocarbon accumulation being structural, in terms of fault, (3) prospective stratigraphic pinch-out, lenticular thick hydrocarbon sand, mounded sand deposit and barrier bar deposit. Seismic Attributes analysis together with seismic structural interpretation revealed prospective structurally high zones with high sand percentage, moderate thickness and high porosity anomaly at the center of the field. The integration of different seismic attribute transforms and results from the study has improved our understanding of mapped sand units and enhanced the delineation of drillable locations which are not recognized on conventional seismic interpretations.

scholarly journals Characterization of reservoirs and depositional study of J-P Field, shallow offshore of Niger Delta Basin, Nigeria

2021 ◽  
pp. e01064
Author(s):  
Theophilus Aanuoluwa Adagunodo ◽  
Oyelowo Gabriel Bayowa ◽  
Oluwaseun Emmanuel Alatise ◽  
Adeola Opeyemi Oshonaiye ◽  
Olusegun Oladotun Adewoyin ◽  
...  
Keyword(s):  
Niger Delta ◽  
Niger Delta Basin

scholarly journals Source Rocks Characterization Of Agbada And Akata Formations In The Niger Delta, Nigeria

2020 ◽  
Vol 1 (4) ◽  
Author(s):  
Koffi Eugene Kouadio ◽  
Selegha Abrakasa ◽  
Sunday S. Ikiensikimama ◽  
Takyi Botwe
Keyword(s):  
Organic Matter ◽  
Niger Delta ◽  
Early Stage ◽  
Source Rocks ◽  
Thermal Maturity ◽  
Petroleum Generation ◽  
Niger Delta Basin ◽  
Rock Eval ◽  
Organic Matter Abundance

The geochemical analysis was performed on twelve (12) core samples from 6 wells of different formations (Akata, Agbada, and Akata/Agbada) of the onshore  Niger Delta Basin. The study was essentially based on the results of the Rock-Eval 6 Pyrolysis to evaluate organic matter abundance, quality, and thermal maturity. The Total Organic Carbon (TOC) varies between 0.6 and 3.06 wt% and the Hydrogen Index (IH) of the studied samples ranges from 38 to 202 mgHC/g TOC, indicating predominantly Type III (gas prone) and mixed type II/III (gas and oil-prone) kerogen. This suggests terrigenous and a mixture of marine and terrigenous organic matter deposited in a paralic marine setting. The organic matter is immature to early mature according to the thermal maturity parameter (414<Tmax<432). The well Isan 9 from Agbada (6760 ft) and Agbada/Akata (8680 ft) shows petroleum generation potential of fair (2,5 < S2 < 5 mg HC/g rock) to good (5 < S2 < 10 mgHC/g rock) and poor for the  other wells. The maturation of the kerogen indicates a very early stage of maturation (Tmax= 432°C). The results indicate that the shales from Agbada and the transition zone between the upper and lower parts of the Akata Shales are more shaly and perhaps the more mature part of the Agbada formation can be the potential source rocks of Niger Delta Basin.

scholarly journals Geochemical Characterization of Some Biodegraded Oils from the Niger Delta Basin, Nigeria

2020 ◽  
Vol 7 (4) ◽  
pp. 127-133
Author(s):  
Omonigho Khalin Egbo ◽  
Olubunmi C. Adeigbe ◽  
Onoriode Esegbue
Keyword(s):  
Niger Delta ◽  
Complex Mixture ◽  
Low Molecular Weight ◽  
Geochemical Characterization ◽  
Biodegraded Oils ◽  
Fluid Properties ◽  
Compositional Changes ◽  
Niger Delta Basin

This study aimed to examine the compositional changes resulting from biodegradation, fathom the extent of degradation, and provide clues for interpreting the evolution and the overall effects on the quality of the oils. Ten oil samples from onshore-offshore fields were analyzed using gas chromatography (GC) and GC-mass spectrometry (GC-MS) methods. GC results indicate variable loss of low molecular weight (LMW) alkanes, besides the presence of unresolved complex mixture (UCM). Saturated, aromatic, resins, and asphaltenes (SARA) compositions and low saturate/aromatic ratio confirmed evidence of biodegradation. Biodegradation levels of the considered oils range from light to moderate, based on Peters and Moldowan scale. This influenced shifts in the ‘primary compositions’ of oils probably from paraffinic or paraffinic-naphthenic oils to aromatic-naphthenic oils. Total ion chromatograms of well 1 and 2 from Northern depobelt, show presence of LMW alkanes, co-existing side by side with UCM, suggesting multiple charges. However, biomarker fingerprints of the oils lack evidence of in-reservoir mixing of biodegraded and non-biodegraded oils. Nevertheless, the possibility of oil mixing cannot be excluded, because biodegradation is progressive and is ongoing. This study, shows the process has dramatically impacted the fluid properties, commercial worth, and economic producibility of the investigated oil accumulations in the basin.

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