scholarly journals Analysis of shaly sand reservoir rocks in the eastern Niger Delta Basin using geophysical well logs

2019 ◽  
Vol 10 (1) ◽  
pp. 1-13
Author(s):  
K. F. Fozao ◽  
Lordon A. E. Djieto ◽  
E. A. A. Ali ◽  
C. M. Agying ◽  
D. M. Ndeh ◽  
...  
Keyword(s):  
Niger Delta ◽  
Well Logs ◽  
Reservoir Rocks ◽  
Shaly Sand ◽  
Geophysical Well Logs ◽  
Niger Delta Basin

Prediction Of Abnormal Pressures In The Niger Delta Basin Using Well Logs

1990 ◽  
Author(s):  
Olubunmi O. Owolabi ◽  
Godwin A. Okpobiri ◽  
Iyalia A. Obomanu
Keyword(s):  
Niger Delta ◽  
Well Logs ◽  
Niger Delta Basin

scholarly journals Delineation of Stratigraphic Units in Xyz Field of Niger Delta Using Geophysical Logs

2019 ◽  
Vol 3 (1) ◽  
pp. 38-49
Author(s):  
Charles C. Ekeh ◽  
Etim D. Uko ◽  
Ejiro F. Eleluwor ◽  
Friday B. Sigalo
Keyword(s):  
Niger Delta ◽  
Well Logs ◽  
Surface Porosity ◽  
Depositional Sequences ◽  
Petrophysical Parameters ◽  
Geophysical Logs ◽  
Net To Gross ◽  
Geophysical Well Logs ◽  
System Tracts ◽  
Optimum Recovery

AbstractGeophysical well logs were used to delineate the stratigraphic units and system tracks in the XYZ Field of the Niger Delta. The gross percentages for sand levels range from 93-96% in the shallow levels to 60-66% in the deeper levels. Porosity values ranged between 27% at shallower sections and 9% at deeper depths. Six depositional sequences were identified and categorized into their associated system tracts. Porosity decreases with depth in normal compacted formation for both sandstone and shale units. Surface porosity for sandstone is 42%, and for shale it is 38.7% from extrapolation of sub-surface porosity values to the surface. The depth to the base of Benin Formation is highly variable ranging between 1300 and 2600m. This study reveals the possibility to correlate sand levels over long distances which enables inferring porosity values laterally. The knowledge of the existent stratigraphic units, the Benin, Agbada and Akata Formations and their petrophysical parameters such as porosity, lateral continuity of the sands and shales, the variation of the net-to-gross of sands with depth, enables the reservoir engineer to develop a plan for the number and location of the wells to be drilled into the reservoir, the rates of production that can be sustained for optimum recovery. The reservoir engineer can also estimate the productivity and ultimate recovery (reserves) using the results on this work.

scholarly journals Foraminiferal analysis of AE-1 well, Agbada formation Onshore, Western Niger Delta Basin: Implication for biozonation and age dating

2020 ◽  
Vol 26 (2) ◽  
pp. 107-118
Author(s):  
Florence O. Amiewalan ◽  
Frankie .O. Balogun
Keyword(s):  
Niger Delta ◽  
Age Dating ◽  
Early Miocene ◽  
Total Count ◽  
Early Oligocene ◽  
Sandy Clay ◽  
Sandy Shale ◽  
Shaly Sand ◽  
Stratigraphic Ranges ◽  
Niger Delta Basin

Foraminiferal and sedimentological analysis was carried out using ditch cutting samples from intervals 2700 ft. - 10,185 ft. in AE-1 well. The samples were composited at 60 ft. into ninety four (94) ditch cutting samples. The standard micropaleontological sample procedures to recover the foraminiferal biofacies assemblages was utilized, followed by analysis and interpretation of the obtained results. The sedimentological analysis reveals five lithofacies - sandstone, sandy shale, shaly sand, mudstone and sandy clay which constitute part of the Agbada Formation of the Niger Delta. The foraminiferal fauna recovered from the samples studied comprised of twenty four species grouped into nineteen genera from niniteen families and nineteen subfamilies. A few number of miscellaneous microfossils such as Ostracoda, Holothuroidea and Echinoderm remains were recovered. The total count of foraminiferal defined from this well is four hundred and nineteen (419). The planktic foraminiferal count was two hundred and forty two (242) (57.8 % of the total count) while the benthics foraminiferal count was one hundred and seventy seven (177) (42.2 % of the total count). Among the benthic forms, the calcareous consists of one hundred and forty nine forms (149) (33.4 % of the total benthic count) while the agglutinating benthic forms were thirty seven (37) (8.8 % of the total benthic count). One (1) planktic (Chiloguembelinacubensis) and three (3) benthic (Eponidesberthelotianus, Hanzawaiastratonii and Nonionellaauris) informal foraminiferal zones were established in the well. The age of the AE-1 well sediments has been interpreted to belong to Early Oligocene - Early Miocene in comparism with foraminiferal markers species whose stratigraphic ranges are well established in the Niger Delta and globally. This inferred the presence of the Rupelian - Burdigalian sediments in the Niger Delta. Keywords: Foraminiferal, Biozone, Age, Rupelian, Burdigalian.

scholarly journals Geological Evaluation of Hydrocarbon Prospect of FOB-field, Coastal Swamp Depobelt, Onshore, Niger Delta Basin, Nigeria

2019 ◽  
pp. 1-12
Author(s):  
Frankie O. Balogun ◽  
Franklin A. Lucas ◽  
Osarodion Ebomwonyi
Keyword(s):  
Late Miocene ◽  
Niger Delta ◽  
Seismic Facies ◽  
Well Logs ◽  
Environment Model ◽  
Multidisciplinary Data ◽  
Sedimentary Succession ◽  
Sequence Boundaries ◽  
Niger Delta Basin ◽  
Geological Position

Well logs, biostratigraphic data, seismic data and semblance map which together form a multidisciplinary data approach, were utilized in the geological evaluation of hydrocarbon prospect FOB-Field, onshore Coastal Swamp Depobelt in the Niger Delta Basin. Structural interpretation of faults, correlation of wells and 3D seismic interpretation were carried out using Schlumberger’s window based petrel software integrated with various lines of evidence such as sequence boundaries and maximum flooding surfaces. The penetrated sedimentary succession was established to constrain the alternation of sand packages from proximal to distal. The studied wells were dated mid to late Miocene based on the geological position of the sequence boundary (10.35Ma) and geological ages of the Mfs (9.5MaMfs) and (10.4MaMfs) respectively corresponding to the Coastal Swamp Depobelt of the Niger Delta Basin. Integration of well logs, seismic, semblance, paleobathymetric and biostratigraphic data indicated mid to late Miocene and neritic to bathyal paleoenvironment of deposition. Integration of fault integrity, seismic, well logs and key stratigraphic markers were utilized to build a seismic facies model and a gross depositional environment model for the FOB-Field.

Prediction Of Abnormal Pressures In The Niger Delta Basin Using Well Logs

10.2118/90-75 ◽  
1990 ◽  
Author(s):  
O.O. Owolabt ◽  
G.A. Okpobiri ◽  
L.A. Obamanu
Keyword(s):  
Niger Delta ◽  
Well Logs ◽  
Niger Delta Basin

scholarly journals Depositional Environments and Reservoir Evaluation of Otuma Oil Field, Niger - Delta basin, Nigeria

2021 ◽  
Vol 2 (6) ◽  
pp. 53-57
Author(s):  
Godwin O. Aigbadon ◽  
Goriola O. Babatunde ◽  
Mu’awiya B. Aminu ◽  
Changde A. Nanfa ◽  
Simon D. Christopher
Keyword(s):  
Niger Delta ◽  
Water Saturation ◽  
Depositional Environments ◽  
Oil Field ◽  
Well Logs ◽  
Depth Range ◽  
Motif Model ◽  
Reservoir Evaluation ◽  
Study Interval ◽  
Niger Delta Basin

This study was carried out by using well logs to evaluate the depositional environments and hydrocarbon reservoirs in the Otuma oil field, Niger Delta basin. The gamma motif/model within- study interval in the drilled well shows blocky, symmetrical, and serrated shapes which suggest a deltaic front with mouth bar to a regressive - transgressive shoreface delta respectively. A correlation was done on the well logs across the wells and the ten well logs were used to evaluate the petrophysical characteristics of the reservoirs. The reservoirs showed highly porous and permeable channels where the wells were used for the characterization. The ten reservoirs were mapped at a depth range of 2395 m to 2919 m with thicknesses varying from 4m to 135m. The petrophysical results of the field showed that the porosity of the reservoirs ranges between 0.10 to 0.30, and permeability from 48 md to 290 md; the water saturation ranges from 0.39 to 0.52, and hydrocarbon saturation from the field 0.48 to 0.61. The By-passed hydrocarbons identified in low resistivity pay sands D4 and D3 at depth 2649 m to 2919 m, respectively were also evaluated and will be put to production in the field.

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