No abstract

With the maturity of the Niger Delta region, having been producing hydrocarbons for the past fifty years, exploration has to look deeper to find any economic accumulations. Some of the consequences of looking deeper include the onset of overpressures and velocity anisotropy. One of the measures to counter these challenges in Onshore Niger Delta is the introduction of anisotropic prestack depth migration for all newly acquired long offset 3D seismic data.The need to properly image the deep leads to acquisition of long offset data as in Okubotin 3D survey. The consequence is that Pre-Stack Depth Migration (PSDM) based on isotropic velocity model assumptions, though effective in imaging conventional reservoirs at shallower levels, is no longer adequate. The introduction of the long offset acquisition brings about a new challenge to derive an accurate velocity model to correct for the socalled 'hockey stick' effect at long offsets. Resolution of the velocity challenge helps in the better imaging of steep dips and corrects for non-hyperbolic moveout on Common Mid Point (CMP) gathers to give better image for the deep exploration plays in the field. This paper presents a workflow for the use of anisotropic velocity model building in Okubotin area. It discusses the possible causes of anisotropy and the impact of anisotropic Pre-Stack Depth Migration processing of seismic data in Onshore Niger Delta. Results showed a much-improved imaging of the subsurface revealing new play potentials that were hitherto unknown in the area.The successful imaging of the deep as in Okubotin 3D has enabled the development of a standardized workflow for this process, successfully unlocked the deep play in the Onshore Niger Delta by revealing impressive leads, explained the influence of anisotropy in the region and SPDC is now able to gain full dollar value of the legacy acquired long-cable seismic data.

No abstract

The Niger Delta Deep Offshore Basin has been the latest frontier within the Niger Delta for hydrocarbon exploration and production activities. Until the onset of drilling activities in the early nineteen nineties, little was known about the biostratigraphy of this frontier setting. Thus, uncertainties existed in the ages ascribed to the various stratigraphic sequences. Presently, several wells have been drilled in the Deep Offshore Niger Delta and a three-pronged biostratigraphic data and some sequence stratigraphic interpretations have become available. We integrated biostratigraphic data comprising palynological, foraminiferal, and calcareous nannoplankton zonation and biofacies, wireline log information and regional-3D seismic data, with simple basic sequence stratigraphic analysis for a detailed well correlation, regional mapping of hydrocarbon-bearing intervals, and evaluation of the thicknesses of promising stratigraphic intervals. Results show a significant effect on not only the earlier conceptualized age of the deepest prospective reservoirs, but also the ages of possible source rocks in the Paleogene of the Niger Delta Offshore sequence. This finding will help in the realistic assumptions of source rock characterization, charge modeling/prediction, and the stratigraphic thicknesses of the offshore sequences and their reservoirs. This paper examines the specific derivable age interpretations from the integration of at least six wells, biostratigraphic data with seismic and the implications of these interpretations for hydrocarbon prospectivity of the Paleogene sequences. Furthermore, this paper documents the biostratigraphy work done in the area, in all the structural belts where drilling has occurred including the deepest well drilled in the Deep Offshore Niger Delta, Bosi-006. The results of this study have a critical impact on the current regional geological understanding of the Deep Offshore Niger Delta.