3‐D seismic interpretation and reserve estimation of Ossu Field in OML 124, onshore Niger Delta Basin, Nigeria

2010 ◽  
Author(s):  
Uzonna Anyiam ◽  
Victor Nduka ◽  
Alex Opara
Keyword(s):  
Niger Delta ◽  
Seismic Interpretation ◽  
Reserve Estimation ◽  
Niger Delta Basin

Reservoir Geometry Determination and Volumetric Reserve Estimation of an Offshore, Niger Delta Basin Nigeria

2019 ◽  
pp. 1-15
Author(s):  
K. O. Ukuedojor ◽  
G. E. Maju-Oyovwikowhe
Keyword(s):  
Continental Slope ◽  
Water Depth ◽  
Niger Delta ◽  
Gamma Ray ◽  
Well Logs ◽  
Reserve Estimation ◽  
Yield Production ◽  
Reservoir Geometry ◽  
Tertiary Recovery ◽  
Niger Delta Basin

Volumetric reserve estimation had been carried out as well as deducing the reservoir geometry of Idje field. Idje field is an 8.4 km2 area between latitudes 4°31’49”N and 4°33’23” N and longitudes 4°34’43”E and 4°36'17"E offshore Niger Delta in a water depth of approximately 1000 m on the continental slope. Well logs suites from ten wells comprising gamma-ray, resistivity, neutron and density were obtained and analyzed. From the result, it was observed that the reservoir was a sedimentary dome possibly resulting from an underlying shale diaper. The volumetric reserve estimate for the D-3 reservoir shows that it contains 15.8 million barrels of oil and 32 billion cubic feet of gas. If the field is produced at the rate of 10,000 barrels per day, it would yield production for approximately 4 years before subsequent secondary and tertiary recovery measures would be employed.

Seismic interpretation, structural analysis, and fractal study of the Greater Ughelli Depobelt, Niger Delta Basin, Nigeria

2011 ◽  
Vol 30 (6) ◽  
pp. 640-648 ◽  
Author(s):  
D. K. Amogu ◽  
J. Filbrandt ◽  
K. O. Ladipo ◽  
C. Anowai ◽  
K. Onuoha
Keyword(s):  
Structural Analysis ◽  
Niger Delta ◽  
Seismic Interpretation ◽  
Niger Delta Basin

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.

The Characteristics and Distribution Pattern of Seafloor Sinuous Pockmark Train in the Niger Delta Basin, West Africa

2016 ◽  
Vol 90 (3) ◽  
pp. 1057-1058 ◽  
Author(s):  
JIANG Li ◽  
WU Shenghe ◽  
HU Guangyi ◽  
ZHANG Jiajia
Keyword(s):  
West Africa ◽  
Distribution Pattern ◽  
Niger Delta ◽  
Niger Delta Basin

scholarly journals Seismic interpretation and petrophysical analysis for hydrocarbon resource evaluation of ‘Pennay’ field, Niger Delta

2018 ◽  
Vol 9 (2) ◽  
pp. 1025-1040 ◽  
Author(s):  
Akindeji Opeyemi Fajana ◽  
Michael Ayuk Ayuk ◽  
Pius Adekunle Enikanselu ◽  
Ajibola Rasidat Oyebamiji
Keyword(s):  
Niger Delta ◽  
Seismic Interpretation ◽  
Resource Evaluation ◽  
Petrophysical Analysis ◽  
Hydrocarbon Resource

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.

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