Browsing by Author "Fagbemigun, T.S."

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    DIGITISATIZATION OF WELL CORELLATION AND PETROPHYSICAL ANALYSIS OF “OKPELLA” FIELD, NIGER DELTA
    (Zibeline International Publishing, 2024) Oyanameh, O.E.; Ayuk, M.A.; Fagbemigun, T.S.; Osisanya, W.O.; Onoghoro, B.B.
    The oil and gas industry is continuously evolving, with a growing emphasis on digital transformation to enhance exploration and production processes. This paper presents a detailed study on the digitization of well correlation and petrophysical analysis in the "Okpella" Field, located in the prolific Niger Delta basin. The Okpella Field represents a significant hydrocarbon reservoir with complex geological and petrophysical characteristics, making it an ideal case study for the implementation of advanced digitization techniques. This research presents the results of log suit analysis from the “OKPELLA” field, Niger Delta. The study aimed at locating the hydrocarbon potential of lithological units encountered during the drilling of the “OKPELLA” field. The primary objectives of this research are to improve well correlation accuracy, optimize reservoir characterization, and enhance reservoir management in the Okpella Field. To achieve the general objective, suites of wire-line logs from the “OKPELLA” field were used for the research. Based on wire-line logs, two types of lithology were identified, which include sand and shale. Five sand bodies are marked as reservoirs, and they are denoted as R1, R2, R3, R4, and R5. The sand bodies were identified with their tops and bases at a depth interval of 4880 m to 6050 m. Computed petrophysical parameters for the five reservoir zones gave an average total porosity of 8% to 28%, with low permeability in the range of 0.56 D to 0.95 D. The high permeability indicates that the reservoir sand bodies are permeable. The fluid type defined in the reservoir zones is hydrocarbon, with a high saturation greater than 75%, which indicates that the proportion of void space occupied by hydrocarbon is high, consequently low water saturation and production. Summarily, the good porosity, high permeability, and low water saturation obtained via petrophysical analysis of the “OKPELLA” field indicate that the quality of hydrocarbon within the five (5) reservoirs found in the field of study is prolific and of commercial use.
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    Petrophysical Analysis And Structural Mapping To Characterize Reservoir Of "Femtop Field", Niger Delta
    (Scholarlink Resource Centre, 2020) Oyanameh, O.E.; Ako, B.D.; Ibitoye, A.T.; Fagbemigun, T.S.; Osisanya, O.W.
    Unveiling the lithological and reservoir mapping, well correlation, petrophysical analysis and structural mapping of ʺFEMTOP FIELDʺ offshore Niger Delta,the data used includes;FieldBase Map, Four wells with Spontaneous Potential (SP), GR Log, Density Logs, Resistivity, andSeismic data in SEG-Y format. The Petrophysical analysis, Structural interpretation of „„Femtop field‟‟was carried out to identify the reservoirs and map faults from the 3-D seismic volume using Schlumberger (PETRELTM) software (i.e. Well data input, Delineation of lithology and Seismic to well tie). Time and depth structure maps in combination with well logs were used to map four reservoirs (A, B, C,and D), and four horizons (H1 to H4).Calculated petrophysical values of the reservoirs in each of the wells show that each formation has varying degree of petrophysical parameters. The average water saturation in these reservoirs is low, ranging from 27% to 45% with a corresponding hydrocarbon saturation ranging from 56% to 72%. Two major growth faults (F3 and F5), three antithetic faults (F1, F2 and F4) also were mapped. Therefore, structural closures identified as rollover anticlines, are displayed on the time/depth structure maps, suggest probable hydrocarbon accumulation at the downthrown side of the fault F3 attesting to the structural characteristics ofidentified reservoirs within the subsurface of study area. Hence, the integration of well logs with seismic data has largely enhanced the success of the petrophysical analysis and structural mapping in identifying theprobable growth faults and other structural closures responsible for hydrocarbon accumulation within the study area.
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    Petrophysical Parameters Analysis and Reservoir Evaluation of ‘ATINUK’ Field, Offshore Niger Delta Basin
    (Umharu Musa Yar'adua University, Katsina, 2024-06) Fagbemigun, T.S.; Fajana, A.O.; Odebunmi, O.D.; Oyanameh, O.E.; Tsado, j.; Osisanya, W.O.
    A suite of geophysical wire-line logs from an oilfield in the Niger Delta have been examined and analyzed with the aim of evaluating the petrophysical properties and determining the reservoir correlation of the ‘ATINUK’ field. Gamma-ray logs, sonic logs, and resistivity logs were used for the correlation analysis of four wells. Three major sand lithologies (Sand A, Sand B, and Sand C) were correlated. For this study, we used Schlumberger PETREL software in combination with well logs to map three (3) reservoirs (A, B, and C), considering parameters such as porosity, permeability, water saturation, hydrocarbon saturation, and volume of shale. The reservoirs' petrophysical parameters revealed water saturation ranging from 0.063 to 0.090, 0.036 to 0.055, and 0.030 to 0.109, respectively; hydrocarbon saturation also ranges from 0.910 to 0.937 in reservoir A, 0.639 to 0.964 in reservoir B, and 0.891 to 0.970 in reservoir C. The reservoir's porosity and hydrocarbon pore volume values within the field proved to be quite productive, with porosity ranging from 0.44 – 0.60 in Reservoir A, 0.40 – 0.45 in Reservoir B, and 0.38 – 0.48 in Reservoir C. reservoir A stands out among the wells due to its high porosity values, low water saturation, high hydrocarbon saturation, and hydrocarbon pore volume.