Notwithstanding the fact that commercial oil discovery has been fifty-plus years in Nigeria; the Nigerian natural gas industry is known to be a developing industry. Thus, understanding the huge potential this industry presents to its economy, the Nigerian government has sought to implement policies that will bring about development in this industry. The paper seeks to examine the policies and the legal framework (if any), in order to ascertain to what extent the policies have been able to develop the industry and if not, why? In addition, the paper examines the adequacy or otherwise of the present legal framework. The paper finds that the successful and sustainable development of the natural gas industry hinges on the existence of adequate legal framework, as policies can only serve as aspirations and sought-after-goals without the backing of sufficient legal framework to support their implementation. The paper finds that in light of shale gas development in Nigeria's investors cum market geography, time is fast running for Nigeria as there is the urgent need to address the situation as Nigeria is gradually losing not just investors but her natural gas market as well.
Ogbuli, Andrew (Shell Petroleum Development Company of Nigeria Limited) | Kakayor, Omagbemi (Shell Petroleum Development Company of Nigeria Limited) | Bahry, Alia (Shell Petroleum Development Company of Nigeria Limited) | Adepoju, Yaqub (Shell Petroleum Development Company of Nigeria Limited) | Awa, Chukwunweike (Shell Petroleum Development Company of Nigeria Limited) | Balogun, Olalekan (Shell Petroleum Development Company of Nigeria Limited)
The management of uncertainties associated with ‘green fields' remains a challenge due to data paucity. In the context of rising development costs for oil and gas projects, integration of data from all available sources becomes imperative. This integration has been demonstrated to reduce identified subsurface uncertainties and risks.
Biostratigraphic data which comprises use of forams and fauna from ditch cuttings picked in several reservoirs in the field has been evaluated and is used to delineate the sequence stratigraphic boundaries which have been shown to be useful for building the framework for field correlation, thus the building of realistic static models.
The CAMOY Gas field located onshore Niger Delta basin was discovered in 1961 by CAMO-1 well. To date, a total of six wells have been drilled in the field. The field is split into two fault blocks by CAMO fault (an East-west trending fault) in the south. The minor block is penetrated by just one well, with the remaining five wells in the main block. A total of nine hydrocarbon-bearing reservoirs have been penetrated occurring between the depths of 6500 ftss and 11000 ftss.
Key subsurface uncertainties that impact on the development plan of the B4 gas reservoir have been identified, and they are associated with structure and stratigraphy. A range of static volumes were computed initially based on the original understanding of the underlying structural and stratigraphic uncertainties. However, by integrating biostratigraphic data in the reservoir correlation, the uncertainty associated with stratigraphy is reduced, leading to a more realistic range of volumes.
Following the building of a realistic 3D model and volume ranges, two wells have been proposed to be drilled to develop the reservoir. The placement of one of the wells closer to the CAMO fault has been optimized post application of biostratigraphic data in B4 gas reservoir correlation.
Background: The quest for oil and gas has necessitated personnel movement into remote locations including offshore. Typical challenges for medical emergency response in remote locations are: adverse weather conditions and logistical problems. Employees of ExxonMobil Upstream Affiliates in Nigeria stepped into the future of medicine with the deployment of innovative telemedicine technology by the Medicine and Occupational Health (MOH) Department in Nigeria. This Upstream Nigeria Telemedicine Pilot Program became a reality in March 2010 with commencement of teleconsultations by the specialists across our locations. Thus, they became the first ExxonMobil affiliate to successfully deploy such a Pilot Program.