Composite Sand Bodies Architecture of Deep-Water Turbidite Channels in the Niger Delta Basin

2014 ◽  
Vol 88 (6) ◽  
pp. 1822-1834 ◽  
Author(s):  
Yu LIN ◽  
Shenghe WU ◽  
Xing WANG ◽  
Yun LING ◽  
Yao LU ◽  
...  
Keyword(s):  
Deep Water ◽  
Niger Delta ◽  
Niger Delta Basin ◽  
Sand Bodies

scholarly journals Petrophysical evaluation of reservoir sand bodies in Kwe Field Onshore Eastern Niger Delta

2016 ◽  
Vol 20 (2) ◽  
pp. 383-393
Author(s):  
T.M. Asubiojo ◽  
S.E. Okunuwadje
Keyword(s):  
Niger Delta ◽  
Depositional Environment ◽  
Gamma Ray ◽  
Petrophysical Properties ◽  
System Quality ◽  
Flow Units ◽  
Wireline Logs ◽  
And Performance ◽  
Niger Delta Basin ◽  
Sand Bodies

Reservoir sand bodies in Kwe Field, coastal swamp depobelt, onshore eastern Niger Delta Basin were evaluated from a composite log suite comprising gamma ray, resistivity, density and neutron logs of five (5) wells with core photographs of one (1) reservoir of one well. The aim of the study was to evaluate the petrophysical properties of the reservoirs while the objectives were to identify the depositional environment and predict the reservoir system quality and performance. The study identified three reservoir sand bodies in the field on the basis of their petrophysical properties and architecture. Reservoir A has an average NTG (61.4 %), Ø (27.50 %), K (203.99 md), Sw (31.9 %) and Sh (68.1 %); Reservoir B has an average NTG (65.6 %), Ø (26.0 %), K (95.90 md), Sw (28.87 %) and Sh (71.13 %) while Reservoir C has an average NTG (70.4 %), Ø (26.1 %), K (91.4 md), Sw (25.0 %) and Sh (75.03 %) and therefore show that the field has good quality sandstone reservoirs saturated in hydrocarbon. However, the presence of marine shales (or mudstones) interbedding with these sandstones may likely form permeability baffles to vertical flow and compartmentalize the reservoirs. These reservoirs may therefore have different flow units. Integrating wireline logs and core data, the reservoir sand bodies were interpreted as deposited in an estuarineshoreface setting thus indicating that the Kwe Field lies within the marginal marine mega depositional environment.Keywords: Estuarine, Shoreface, Reservoir, Sand, Kwe, field

scholarly journals Evaluation of Petrophysical Parameters of Reservoir Sand Wells in Uzot-Field, Onshore Niger Delta Basin, Nigeria

2021 ◽  
Vol 25 (2) ◽  
pp. 157-171
Author(s):  
UC Omoja ◽  
T.N. Obiekezie
Keyword(s):  
Niger Delta ◽  
Gamma Ray ◽  
Depth Range ◽  
High Hydrocarbon ◽  
Hydrocarbon Production ◽  
Petrophysical Parameters ◽  
Resistivity Logs ◽  
Hydrocarbon Saturation ◽  
Niger Delta Basin ◽  
Sand Bodies

Evaluation of the petrophysical parameters in Uzot-field was carried out using Well log data. The target for this study was the D3100 reservoir sand of wells Uz 004, Uz 005, U008 and Uz 011 with depth range of 5540ft to 5800ft across the four wells. Resistivity logs were used to identify hydrocarbon or water-bearing zones and hence indicate permeable zones while the various sand bodies were then identified using the gamma ray logs. The results showed the delineated reservoir units having porosity ranging from 21.40% to 33.80% indicating a suitable reservoir quality; permeability values from 1314md to 18089md attributed to the well sorted nature of the sands and hydrocarbon saturation range from 12.00% to 85.79% implying high hydrocarbon production. These results suggest a reservoir system whose performance is considered satisfactory for hydrocarbon production. Keywords: Petrophysical parameters, porosity, permeability, hydrocarbon saturation, Niger Delta Basin

scholarly journals Digital Rock Approaches to Estimate the Impact of Early Quartz Cementation in Miocene Deepwater Sands Niger Delta Basin, Nigeria

2017 ◽  
Vol 6 (2) ◽  
pp. 138
Author(s):  
Ibukunoluwa S. Adeola ◽  
Jim Buckman ◽  
Gary Couples ◽  
Adewole John Adeola
Keyword(s):  
Deep Water ◽  
Niger Delta ◽  
Scattered Electron ◽  
Two Phase ◽  
Flow Models ◽  
Porosity And Permeability ◽  
Final Porosity ◽  
Quartz Cement ◽  
Niger Delta Basin ◽  
The Impact

Quartz cement forming as syntaxial overgrowths is one of the most abundant cement type in sandstones. The rim and occluding cements develop around the surfaces of frame work grains and fill up pore spaces with no preferred orientation with grain surfaces. Imaging the various forms of quartz cement generation and development in 3D as it increases through time will help in further evaluation and better understanding of a reservoir in deep water sands in Niger Delta Basin.Petrographic analysis was performed on 10 Samples with micron resolutions of 0.675 and 0.337 per pixel. Scanning Electron Microscopy (SEM) using the Cathoduluminiscence (CL) and Back Scattered Electron (BSE) was employed in delineating the detrital quartz from the syntaxial quartz cements. Image J Software and Scandium Software were employed in binarizing the BSE image samples and study the iteration porosity, final porosity and permeability. 3DSlicer software was employed to produce 3D images for better understanding of the impact of early cement in the deep water sands. Two Phase Flow Models was also generated for each samples to outlines the effect of cementation.Quartz cement reduces porosity and peremability significantly at early stages of quartz cementation. Small local quartz overgrowths do join and link together with increasing cement precipitation hence gradually impeding porosity and drastically reducing permeability. Modelled results showed similar trends and this is an indication that when analysing a top reservoir unit, once the cementation is more than 6% the possibility of it being a good reservoir is relatively low.

scholarly journals Lithological attributes of hd-001 well, shallow offshore, Niger delta basin, Nigeria

2020 ◽  
Vol 9 (1) ◽  
pp. 5
Author(s):  
Olubusayo A. Olatunji ◽  
Edward A. Okosun ◽  
Usman S. Onoduku ◽  
Yahya B. Alkali
Keyword(s):  
Grain Size ◽  
Niger Delta ◽  
Entire Interval ◽  
Accessory Minerals ◽  
Log Data ◽  
Shallow Marine ◽  
Wireline Logs ◽  
Niger Delta Basin ◽  
Shoreline Progradation ◽  
Sand Bodies

Lithological analysis was carried out on 96 ditch cuttings samples from HD-001 well located within the shallow offshore Niger delta basin, Nigeria. Three lithofacies sequences were delineated by the integration of wireline logs textural/lithologic attritudes and the distribution of index accessory minerals. They are transitional paralic, paralic and marine paralic sequences. The lithologic, textural and wireline log data indicate that the entire interval studied in the HD-001 well belongs to the Agbada Formation. The Formation is made up of alternating sand and shale units which suggests rapid shoreline progradation. The grain size increases from essentially fine to medium-grained at the basal part of the well to dominantly coarser grain at the upper part. The index accessories recognize shallow marine to coastal deltaic settings environment of deposition. Sand bodies which represent sub-environments within those settings are deposited in sequences. Each sequence begins with a transgressive phase followed by significant regressions.   

Reservoir quality variations within a sinuous deep water channel system in the Niger Delta Basin, offshore West Africa

2015 ◽  
Vol 63 ◽  
pp. 166-188 ◽  
Author(s):  
Jiajia Zhang ◽  
Shenghe Wu ◽  
Xing Wang ◽  
Yu Lin ◽  
Hongjun Fan ◽  
...  
Keyword(s):  
West Africa ◽  
Deep Water ◽  
Niger Delta ◽  
Water Channel ◽  
Reservoir Quality ◽  
Channel System ◽  
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
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