Browsing by Author "Oyanameh, O.E."

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    Application of One Dimensional Geophysical Investigation on Proposed Dam Project, Iyah Gbede, Kogi State, Nigeria
    (International Organization of Scientific Research, 2021) Olabode, O.O.; Oyanameh, O.E.; Idowu, D.O.; Osisanya, O.W.; Korede, A.I.
    Foundation designs planning is very critical in engineering works, therefore geophysical investigation was carried out for foundation design of a proposed Dam at IyahGbede, Ijumu Local Government Area of Kogi State with a view to deduce and enhance the knowledge of the near subsurface integrity of the area for engineering structures.Electrical Resistivity method was adopted to conduct the survey for detail and distinct result. The aim of the exercise was to determine the soil properties of the subsoil layers that constitute the foundation soils and their competence as foundation soils for a dam site establishment. Traverse lines were established along E-W direction and six (6) Vertical Electrical Sounding points (VES) which is one dimensional in prospect, werelaid which to reveal the subsurface property of the area.The VES curves types are AA,AH, HA and KH,which depicts that the investigated site is competent for the proposed dam project.
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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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    Hydrocarbon Play Assessment of “Oswil” Field, Onshore Niger Delta Region.
    (The Bilingual Publishing Group, 2021-01) Osisanya, W.O.; Alile, O.M.; Eze, S.U.; Ibitoye, T.A.; Oyanameh, O.E.
    Hydrocarbon play assessment of any field involves the evaluation of the production capacity of hydrocarbon reservoir unit in the field. This involves detail study of the reservoir petrophysical properties and geological interpretation of structures suitable for hydrocarbon accumulation in the field as observed from seismic reflection images. This study details the assessment of hydrocarbon play in OSWIL field onshore in Niger Delta, with the intent of appraising its productivity using a combination of seismic, well logs, petrophysical parameters and volumetric estimation using proven tech niques which involves an integrated methodology. Two reservoir windows “R1” and “R2” were defined from five wells OSWIL-02, 04, 06, 07 and 12. The top and base of each reservoir window was delineated from the wells. Structural interpretation for inline 6975 revealed two horizons (X and Y) and eight faults labelled (F1, F2, F6, F8, F10, F16, F17 and F18). Five faults (F1, F6, F10, F17 and F18) were identified as synthetic faults and dip basin wards while three faults (F2, F8 and F16) were identified as antithetic faults and dips landwards. Time-depth structural map at top of reservoirs R1 and R2 revealed structural highs and closures. These observations are characteristics of growth structures (faults) which depicts the tectonic style of the Niger Delta. Results of petrophysical evaluation for reservoirs “R1” and “R2” across the five wells were analysed. For reservoir “R1” effective porosity values of 27%, 26%, 23%, 20% and 22% were obtained for wells OSWIL-04, 12, 07, 06 and 02 respectively with an average of 23.6%, while for reservoir “R2” effective porosity values of 26%, 22%, 21%, 24% and 23% for wells OSWIL-04, 12, 07, 06 and 02 were obtained respectively with an average of 23.2%. This porosity values correspond with the already established porosity range of 28-32% within the Agbada formation of the Niger Delta. Permeability index of the order (K > 100mD) were obtained for both reservoirs across the five wells and is rated very good. Hydrocar bon saturation (Shc) across the five wells averages at 61.6% for reservoir “R1” and 67.4% for reservoir “R2”. Result of petrophysical model for porosity, permeability and water saturation reveal that the reservoir system in R1 and R2 is fault assisted and fluid flow within both reservoirs is aided by presence of effective porosity and faulting. Volumetric estimation for both reservoirs showed that reservoir R1 contains an estimate of 455 × 106 STB of hydrocarbon in place, while reservoir R2 contains an estimate of 683 × 106 STB of hydrocarbon in place. These findings impact positively on hydrocarbon production in the field and affirm that the two reservoirs R1 and R2 are highly prospective.
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    Hydrocarbon Reservoir Mapping and 3d Seismic Interpretation of “Deejay” Field, Onshore Niger Delta
    (RSIS International, 2021) Alabi, A.O.; Oyanameh, O.E.; Agbalagba, E.O.; Korode, A.I.; Osisanya, O.W.
    The 3-D seismic data interpretation and reservoir mapping of ‘‘Deejay field’’ have been carried out with the use of Schlumberger (PETRELTM) software. This research work is aimed at delineating the subsurface structure and deducing the trapping system of the study area that may aid hydrocarbon accumulation. The research methodology involved horizon and fault interpretation to produce subsurface structural maps. Available Wireline log signatures were employed to identify hydrocarbon bearing sands and compute reservoir petrophysical parameters for hydrocarbon pore volume determination. Two faults F_01 and F_02 (synthetic) were mapped using seismic structural attribute (variance) with fault polygon generated on the surface. Structural interpretation for inline 5533 revealed two horizons (1&2) were taken into consideration with their time and depth maps generated for the purpose of this study. The structural maps revealed fault assisted closures at the centre of the field which correspond to the crest of rollover anticlines and possibly served as the trapping medium. Three hydrocarbon bearing reservoirs - S1, S2 and S3 were delineated from three wells and the top and base of each reservoir window were mapped from the wells. Reservoirs S1, S2 and S3 have average porosity values of 30.7%, 29.8% and 29.3% respectively. All the porosity values obtained are in agreement with the established porosity values of Agbada formation of Niger Delta as it ranges from 28-32%. The obtained permeability index for the three reservoirs are rated very good. Hydrocarbon saturation values for the three wells have an average of 72.3% for S1, 83.7% for S2 and 76.7% for S3. The Petrophysical parameters from the wells show that most of the reservoirs are good targets in hydrocarbon prospecting. The result shows that the three reservoirs in the field have high hydrocarbon potential and good trapping mechanism for its productivity.
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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.