Well Logging Analysis in Niger Delta Basin

2021 ◽  
Author(s):  
Aniekeme Edet Sunday
Keyword(s):  
Niger Delta ◽  
Oil And Gas ◽  
Well Logging ◽  
Hydrocarbon Exploration ◽  
Seismic Survey ◽  
Monitoring And Control ◽  
Principal Characteristics ◽  
Formation Evaluation ◽  
Niger Delta Basin ◽  
Mud Logging

Abstract A hydrocarbon exploration begins with the geological recognition of probable hydrocarbon accumulation areas, which are confirmed by seismic survey and, to ensure certainty, it is necessary to drill a well. On those exploration wells measurements are made down the hole for the formation evaluation. The evaluation of water, oil and gas saturations are attained by geological and petrophysical characteristics. To obtain such information it is necessary to use a combination of several sources, namely mud logging, coring, well logging and occasionally down the hole tests. Due to the high risks associated with drilling activities, such as safety problems and environmental impacts, it is extremely important to have a very well designed and established drilling program. Therefore, the activities monitoring and control and a good knowledge of what types of formations will be affected, and its principal characteristics, are priorities to take into consideration. Bearing in mind the sources for the formation evaluation, the present work aims to focus on wireline logs and the major challenge that is faced here which is data acquisition and petrophysical evaluation. The case study is a Niger Delta basin (Nigeria).

Structure and Assessment of the Oil Potential of Carbonaceous Carbonate-Siliceous Domanik Deposits in the Volga–Ural Oil and Gas Province

2021 ◽  
Vol 62 (08) ◽  
pp. 929-946
Author(s):  
N.K. Fortunatova ◽  
A.I. Varlamov ◽  
A.S. Kanev ◽  
V.I. Poroskun ◽  
A.V. Baranova ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Oil Production ◽  
Well Logging ◽  
Seismic Survey ◽  
Oil Resources ◽  
Materials Used ◽  
Stratigraphic Interval

Abstract —The paper considers the regularities in the structure and conditions of formation of Domanik carbonaceous carbonate-siliceous productive deposits. They are shown to occur in the stratigraphic interval from middle Frasnian to upper Famennian. The highly persistent structure of their sections for many kilometers within specific sedimentation zones and the drastic changes in the structure at the boundaries of the zones are justified. Lithological classification of rocks is considered. Methods and results of combined paleontological, lithological, geochemical, and petrophysical core studies are presented, as well as interpretation of well logging data and seismic-survey materials used in the assessment of oil resources and identification of oil- and gas-promising zones and areas. The conducted studies have proved significant oil resources in the Domanik productive sequence; their extraction might compensate for the decline in oil production from conventional pools.

Tailored acquisition and processing providing an enhanced subsurface image of the basin architecture, Exmouth Sub-basin, North West Shelf, Australia

2019 ◽  
Vol 59 (2) ◽  
pp. 886
Author(s):  
Alexander Karvelas ◽  
Bee Jik Lim ◽  
Lianping Zhang ◽  
Haryo Trihutomo ◽  
Oliver Schenk ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Model Building ◽  
Waveform Inversion ◽  
Hydrocarbon Exploration ◽  
Surface Velocity ◽  
Seismic Survey ◽  
Image Point ◽  
Surface Model ◽  
Near Surface ◽  
North West

Hydrocarbon exploration has resulted in the discovery of a variety of oil and gas accumulations mainly in Upper Jurassic and Lower Cretaceous intervals. However, the distribution of the different petroleum system elements including Jurassic and Triassic intervals is poorly determined, but required for improved understanding of the complex charge history, as indicated by the variety of hydrocarbon types encountered in the basin. The new WesternGeco multiclient 3D seismic survey extends to the edges of the basin to give a comprehensive picture. Raw hydrophone data were delivered from the vessel as acquisition progressed to begin the near-surface model building. The model building consisted of two major stages: first, using full waveform inversion (FWI) to derive the near-surface velocity field; and, second, common image point (CIP) tomography to update the deeper section beyond the FWI illumination zone. As illustrated herein, various stages of processing and imaging provided a cleaner and crisper dataset across the record length, allowing (1) detailed picking of the events within the entire Mesozoic (Cretaceous–Triassic) section allowing key events to be interpreted and correlated across the area and (2) accurate investigation of the complexity of different aged fault networks and their relationships across the full Exmouth Sub-basin for the first time. In summary, this survey provides a detailed insight into the deeper basin architecture of the Exmouth Sub-basin. The seamless volume imaged to depth allows accurate mapping which is critical to unravel the complex evolutionary history in a basin with proven and significant remaining hydrocarbon potential.

Rock Compressive Strength: A Correlation from Formation Evaluation Data for the Niger Delta

2016 ◽  
Author(s):  
Babatunde Salawu ◽  
Reza Sanaee ◽  
Olumayowa Onabanjo
Keyword(s):  
Compressive Strength ◽  
Niger Delta ◽  
Sample Collection ◽  
Delta Region ◽  
Evaluation Data ◽  
Formation Evaluation ◽  
Core Samples ◽  
Niger Delta Region ◽  
Different Depths ◽  
Niger Delta Basin

ABSTRACT The purpose of this paper is to study the strength of rocks by determining their Unconfined Compressive Strength (UCS), correlate the determined strength to physical properties of rocks that can be measured from formation evaluation data and derive an equation that can be used to derive rock strength from formation evaluation measurements. The scope of this work is limited to the Niger delta basin from which core samples were taken. The method used for this research was to collect data of existing core samples at different depths and in various fields in the Niger Delta, then determine the strength of each sample by unconfined compressive tests. The derived strength was then analyzed with corresponding formation evaluation data utilizing regression analysis. Then, comparisons were drawn between the correlations derived and other existing correlations in the industry to check whether any of the existing correlations fits the Niger Delta region. The result is a model that takes formation evaluation data (Slowness, Young's Modulus and Poisson's ratio) as input in order to provide rock compressive strength for the Niger-Delta region. It was also observed that correlations built for other regions of the world do not yield accurate results when used for the Niger Delta region due to factors such as formation characteristics type of regression method, various sample collection conditions and so on.

scholarly journals Curie depth and heat flow analysis of Ikot Ekpene and environs, Eastern Niger Delta Basin, using airborne magnetic data

2020 ◽  
Vol 8 (2) ◽  
pp. 263
Author(s):  
Uche Iduma ◽  
Stephen Stephen Onyejiuwaka ◽  
Nwokeabia Charity Nkiru
Keyword(s):  
Heat Flow ◽  
Spatial Data ◽  
Niger Delta ◽  
Average Power ◽  
Hydrocarbon Exploration ◽  
Computational Method ◽  
Magnetic Data ◽  
Geothermal Gradients ◽  
Curie Depth ◽  
Niger Delta Basin

Aeromagnetic dataset over Ikot Ekpene and environs, Eastern Niger Delta Basin, was processed to compute the basement depth, Curie isotherm depth, geothermal gradient and heat flow within the area in order to investigate the depth to magnetic sources, geothermal prospect and the hydrocarbon potential of the place. The adopted computational method transformed the spatial data into frequency domain and provided a relationship between radially average power spectrum of the magnetic anomalies and the depths to respective sources.  The results of the analysis showed that the depths to centroids and top boundaries range from 7.84 to 13.38 km and 0.233 to 0.459 km respectively. Curie depths within the basin undulate and vary between 15.42 and 26.49 km. The geothermal gradients range between 20.758 and 35.649 ⁰C/km while the corresponding heat flow is about 51.896 mWm⁻² within east of Ikono, north of Mbak and west of Abak Areas and 89.124 mWm⁻² within Amawum, Ndoro, Isiala, Ogbuebule and east of Uyo Areas. Based on the computed sedimentary thicknesses, high geothermal gradients and delineated major faults and fractures which could serve as migratory pathway for hydrocarbon or hydrothermal fluid, some parts of the study area have been demarcated for geothermal prospect and detail hydrocarbon exploration.  

scholarly journals Geochemical Analysis of Sediments from Sahaiawei-1 Well of the Northern Delta Depobelt in the Niger Delta Basin, Nigeria

2021 ◽  
Vol 13 (1) ◽  
pp. 125-135
Author(s):  
K. Itiowe ◽  
F. A. Lucas ◽  
E. O. Avwenagha
Keyword(s):  
Niger Delta ◽  
Depositional Environment ◽  
Tectonic Setting ◽  
Fluorescence Analysis ◽  
Hydrocarbon Exploration ◽  
Geochemical Analysis ◽  
X Ray ◽  
Sedimentary Provenance ◽  
Niger Delta Basin

Geochemical analysis of sediments from Sahaiawei-1 Well of the Northern Delta Depobelt in the Niger Delta Basin was carried out to classify the sediments, determine the provenance, tectonic setting and depositional environment. Twenty (20) ditch cutting samples between 1500 and 10730 ft. were subjected to X-ray fluorescence analysis to determine the elemental composition.  The result for the classification of the sediments shows that the sediments were classified as Fe-shale and Fe-sand. The discriminant function diagrams for provenance signature and tectonic setting show that the sediments were plotted within the quartzose sedimentary provenance and passive continental margin tectonic setting fields respectively. The depositional environment using inorganic geochemistry shows that the sediments were deposited with in the continental, transitional and marine environments. This research has provided up to date information on the geochemistry of the Northern Delta Depobelt which would help in hydrocarbon exploration in the area.

Estimating smectite content from seismic data

2019 ◽  
Vol 59 (2) ◽  
pp. 851
Author(s):  
Roman Beloborodov ◽  
Marina Pervukhina ◽  
Valeriya Shulakova ◽  
Dimitri Chagalov ◽  
Matthew Josh ◽  
...  
Keyword(s):  
Seismic Data ◽  
Oil And Gas ◽  
Clay Mineralogy ◽  
Mineralogical Composition ◽  
Hydrocarbon Exploration ◽  
Seismic Survey ◽  
Maximum Deviation ◽  
North West ◽  
Northern Carnarvon Basin ◽  
Carnarvon Basin

Predicting the mineralogical composition of shales is crucial for drilling operations related to hydrocarbon exploration/production as well as for the assessment of their sealing capacity as hydrocarbon or CO2 barriers. For example, hydrocarbon exploration in the Northern Carnarvon Basin, North-West Shelf, Australia is hindered by the presence of a thick (up to 1 km) smectite-rich shale seal that spreads regionally. Complex structures of the channelised oil and gas fields in the area make it necessary to drill deviated wells through that seal. The maximum deviation angle at which successful drilling is possible depends strongly on the clay mineralogy and, in particular, on the smectite content in the shale. Here, we introduce a novel workflow combining seismic data, well logs and laboratory measurements to infer shale composition at the reservoir scale. It is applied to the Duyfken 3D seismic survey in the central part of the Northern Carnarvon Basin. Interpretation results are verified against the laboratory X-ray diffraction measurements from the test well that was not used for the interpretation. The results match the test data well within the determined uncertainty bounds.

scholarly journals Sequence stratigraphic approach to hydrocarbon exploration: a case study of Chiadu field at eastern onshore Niger Delta Basin, Nigeria

2017 ◽  
Vol 8 (2) ◽  
pp. 399-415
Author(s):  
Victor C. Nwaezeapu ◽  
Anthony U. Okoro ◽  
Elesius O. Akpunonu ◽  
Norbert E. Ajaegwu ◽  
Kingsley C. Ezenwaka ◽  
...  
Keyword(s):  
Niger Delta ◽  
Hydrocarbon Exploration ◽  
Sequence Stratigraphic ◽  
Niger Delta Basin

Sequence Stratigraphic, Structural and Reservoir Analyses: An Integrated Approach to Exploration and Development of the Eastern Coastal Swamp Cluster, Niger Delta Basin

2016 ◽  
Author(s):  
C. I. Dim ◽  
K. Mosto Onuoha ◽  
C. Gabriel Okeugo
Keyword(s):  
Niger Delta ◽  
Evaluation Studies ◽  
Hanging Wall ◽  
Hydrocarbon Exploration ◽  
Foot Wall ◽  
Stratigraphic Correlation ◽  
Sequence Stratigraphic ◽  
Hydrocarbon Reservoir ◽  
Niger Delta Basin ◽  
System Tract

ABSTRACT Sequence stratigraphic, structural and reservoir analytical tools have been employed in interpreting the geology of the eastern Coastal Swamp Depo-belt of the Niger Delta Basin. The aim was to understand the stratigraphic framework, structural styles and hydrocarbon reservoir distribution for improved regional hydrocarbon exploration across the onshore Niger Delta basin. This interpretative study made use of well logs, biostratigraphic (biofacies and bio-zonation) and petrophysical data obtained from twenty wellbores, integrated with recently merged and reprocessed 3D Pre-Stack Time Migrated regional seismic volume spanning across eight fields (over 960 km2). Results reveal the occurrence of nine key chronostratigraphic surfaces (five maximum flooding surfaces and four sequence boundaries) that were tied to well-established pollen and foram bio-zones for high resolution sequence stratigraphic interpretation. The sediment stacking patterns recognized from gamma ray log signatures were used in delineating the lowstand system tract (LST), transgressive system tract (TST) and highstand system tract (HST) genetic units. Well log sequence stratigraphic correlation reveals that stratal packages within the area were segmented into three depositional sequences occurring from middle to late Miocene age. Furthermore, there is thickening of stratal packages with corresponding decrease in net-to-gross thickness from north to south (basinwards). This is due possibly to the influence of syn-depositional structures on stratigraphy. The combination of reservoir sands (of LST and HST), source and seal shales (of TST and HST) and fault structures allows for good hydrocarbon accumulation and should be targeted during exploration. Reservoir evaluation studies using petrophysical parameters indicates the presence of good quality reservoir intervals, which are laterally continuous and partly compartmentalized. Structural top maps of reservoirs show good amplitude response that are stratigraphically and structurally controlled. Structural analysis revealed the occurrence of back-to-back faulting, collapsed crest structures, simple/faulted rollovers, regional foot wall and hanging wall closures and sub-detachment structures. These structural styles constitute the major hydrocarbon entrapment mechanism in the area. Overall, the study has unraveled the existence of undrilled hydrocarbon leads at deeper depths that should be further revalidated for development and production.

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