Seismic stratigraphic and structural interpretation is often hampered by seismic resolution and, sometimes, human's inability to identify a subtle feature on the seismic. These factors have frequently led to the poor seismic interpretation of geologic features. Thus, an integral approach to studying the structural patterns and hydrocarbon bearing zones using seismic attributes were carried out on the Tomboy field using 3D seismic data covering approximately 56 km 2 of the western belt of the Niger Delta. The seismic volume underwent post-stack processing, which enhanced seismic discontinuities. A deep steering volume was first created, and several dip filters were applied to enhance faults in the study area. After that, curvature and similarity attributes were calculated on the dip-steered and fault-enhanced volume. These calculations show detailed geometry of the faults and zones of subtle lineaments. Six faults (F1, F2, F3, F4, F5, and F6) were identified and mapped. These faults range from antithetic to crestal growth faults. Two major growth faults (F5 and F6) were revealed to dip in the NE-SW directions. A near-extensive crestal fault (F4) appeared beneath the major faults. Although several minor fractures were displayed in the southern and central portion of the seismic data, the SW dipping crestal fault (F4) and growth fault F6 are responsible for holding the hydrocarbon found within the identified closures. Using attributes on the seismic data increased confidence in the mapping and interpreting structural features. Furthermore, Energy attributes were used as Direct Hydrocarbon Indicator (DHI) to visualize viable areas within the study and permits a more robust interpretation. Time slices were taken at regions of flat and bright spots. Spectral decomposition attribute was run on these slices to display areas of high amplitude reflection typical of hydrocarbon-bearing regions, which are trapped mainly by regional to sub-regional growth faults. The surface attribute calculated on the generated surface shows that the field is dominantly controlled by faults serving as traps for hydrocarbon.

Seismic attribute analysis is important in subsurface data interpretation, such as seismic interpretation, which could involve seismic stratigraphic and structural interpretation. This interpretation is often hampered by seismic resolution and, sometimes, human inability to identify a subtle feature on the seismic. These factors have frequently led to the poor seismic interpretation of geologic features. Thus, an integral approach to studying structural patterns and hydrocarbon bearing zones using seismic attributes was carried out on the Tomboy field using 3D seismic data covering approximately 56 km2 of the western belt of the Niger Delta. The seismic volume underwent post-stack processing, which enhanced seismic discontinuities. A deep steering volume was first created, and several dip filters were applied to enhance faults in the study area. After that, curvature and similarity attributes were calculated on the dip-steered and fault-enhanced volume. These calculations show detailed geometry of the faults and zones of subtle lineaments. Six faults (F1, F2, F3, F4, F5 and F6) were identified and mapped. These faults range from antithetic to crest growth faults. Two major growth faults (F5 and F6) were revealed to dip in the northeast to southwest directions. A near-extensive crest fault (F4) appeared beneath the major faults. Although several minor fractures were displayed in the southern and central portions of the crest fault of the dipping seismic data, the southwest (F4) and growth fault, F6, are responsible for holding the hydrocarbon found within the identified closures. Using attributes on the seismic data increased confidence in mapping and interpreting structural features. Furthermore, energy attributes were used as Direct Hydrocarbon Indicators (DHI) to visualize viable areas within the study, which allows a more robust interpretation. Time slices were taken in regions of flat and bright spots. The spectral decomposition attribute was run on these slices to display areas of high amplitude reflection typical of hydrocarbon-bearing regions trapped mainly by regional to sub-regional growth faults. The surface attribute calculated on the generated surface shows that the field is predominantly controlled by faults serving as traps for hydrocarbon.

Earth's surface configuration is in constant change due to geomorphic processes in operation. These processes are responsible for initiating several features such as channels, drainage basins, incised valleys, and submarine canyons. The understanding of these features is paramount for an accurate assessment of biological, environmental and geologic activities on land and in the sea. This article is a review of submarine canyons with overview of their geomorphic processes which discusses the origin, types and processes within canyons. Working with a compiled highly published materials of the world's most famous submarine canyons, this paper documents the historical evolution of the canyons over time and the different processes acting in the development of these canyons. From this study, the major factor controlling canyon creation is the seal level change. Turbiditic flow, and tectonics (faults and folds) favours canyon development. Canyon geometry can be both U-shaped, V-shaped or both depending on the tectonic or erosional influence. Although several works have been done on submarine canyon, the issue of submarine canyon evolution through time is minimal and accurate fluvial to canyon head connections are still a challenge. More focus on the stratigraphic and source to sink study of canyon systems can help give clue on the ages of canyons and the type of facies contained in it. This could be of benefit to the oil and gas industry in reservoir explorations.

There is a growing interest in the Niger Delta hydrocarbon field exploration and exploitation. With growing interest in proven field prospects and confirmed reservoir facies, there is a need for improved basin and field scale reservoir identification, analysis, and assessment. The Agbada Formation of the middle Miocene age across Vim Field, in the western part of the coastal swamp depobelt was studied using wire-line logs, 3D seismic and biostratigraphic data. This contribution evaluated stratigraphic configuration, structural style, facies geometry, hydrocarbon leads, and distribution. The method adopted involves delineating lithologies from the gamma-ray log, identifying reservoirs from the resistivity and gamma ray logs, well top correlation using gamma ray logs, horizon and fault mapping, time to depth conversion of maps using velocity model, attribute analysis, and sequence stratigraphic analysis. Bounding surfaces were mapped on the seismic section, and well correlations were conducted and integrated with a paleobathymetry chart to highlight the depositional environments. Eight major stratigraphic bounding surfaces (four sequence boundaries and four maximum flooding surfaces) were identified. Erosional bounding surfaces were mapped as interest surface horizons. Analysis of the vertical succession of depositional facies revealed five 3rd order depositional sequences of Mid-Miocene age-bound SB and MFS chronologically. Three strata stacking patterns (progradational, retrogradation, and aggradational) were delineated and interpreted as lowstand systems tract (LST), highstand systems tract (HST), and transgressive systems tract (TST). The alternation of the reservoir sands of the HST and TST and the shale units of the TST offers good traps for hydrocarbon. Fault analysis revealed regional growth faults, counter-regional growth faults, synthetic and antithetic faults that show foot walls and hanging walls dominating the mainly extensional zone. These faults play a major role in hydrocarbon trapping within the area. The depositional environment spans from shelf to slope margin, with sediments deposited within the Inner neritic through the middle neritic to the outer neritic settings. Interpretative observation shows that thin-bedded shale facies complexly intercalate the reservoir facies of the TST. Thus careful evaluation of such reservoirs is recommended before making exploitation decisions.

An accurate definition of environment of sediment deposition is a sine qua non for characterizing and providing measures for enhancing hydrocarbon reservoirs. Consequently, this study is aimed at determining the sub-environment of deposition and architecture of two reservoirs: S1000 and S2000 reservoirs, in 'SABALO' field, deep offshore Niger Delta. In addition, the study is imperative in order to assess reservoir properties such as: geometry, connectivity and continuity, which are important for exploration and reservoir management. In this study, we integrated well logs from six (6) wells and 3D-seismic data (near and far angle stack) for seismic stratigraphic studies. Four major seismic sequences with their corresponding facies units were recognized by analysis of reflection terminations, seismic parameters and external geometry. The reservoirs of interest are within the seismic sequence one containing facies units: SF1A and SF1B. Both reservoirs were delineated to be structurally and stratigraphically controlled. This implies a combinational trapping system at the reservoir level. Also, hydrocarbons in the reservoir were confirmed to be down to reservoir base. Integrated study of the seismic and well logs shows that the two identified reservoirs, S1000 and S2000, were defined to be weakly confined channel complex with an area of 50 km 2 and 78 km 2 , respectively. Their connectivity was defined to be loosely amalgamated and highly amalgamated, respectively. The results of this paper are essential to develop the reservoirs by utilizing the information of their geometry, connectivity and continuity.