ABIMBOLA A DUROGBITAN

The University of Manchester, Basin Studies & Petroleum Geoscience Group, PhD Graduate 2009

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Dr. Durogbitan is the General Manager Geosciences at Amni International Petroleum Development Company (Amni) Limited where he champions integrated subsurface assessments including asset evaluation, exploration, well drilling, development and production activities across the company. He is a high energy and very passionate professional with over 25 years global oil and gas industry experience working in senior technical and management positions with integrated independents and Oil service companies. A Certified Project Management Professional (PMP) with Project Management Institute (PMI), a fellow of the African Scientific Institute (ASI) and a member of the ASI fellow think tank.
Abimbola is an aluminous of the University of Ilorin with an MSc Petroleum Geology and Sedimentology degree from the University of Ibadan (UI) and PhD Petroleum Geosciences University of Manchester. He won the best poster award twice at the NAPE International Conference and Exhibition. Prior to joining Amni, he spent six (6) years with Petrofac Integrated Energy Services where he held different senior technical positions and interfaced with several E&P companies including Oil majors and independents. Due to his outstanding contribution to the organization, he was awarded the Petrofac Group Eve Award. The award celebrates Petrofac`s best employees (individual) in their area of work. Before Petrofac-IES, Abimbola was in PetroVision Energy UK for two (2) years as an Associate Senior Geoscientist.
Dr. Durogbitan is NAPE UK/Europe Chapter Coordinator, the first and only NAPE Chapter in diaspora. He is one of the pioneers of the Chapter and the first NAPE UK/Europe Chapter Coordinator. He has facilitated strategic partnerships for NAPE with different UK and European Companies, associations and institutions. He also acts as a liaison and representative of the Association in the United Kingdom.
Phone: +2349062848112
Address: PLOT 1377, TIAMIYU SAVAGE STREET, VI, LAGOS

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Application of Basin to Prospect Maturation A Case Study

by ABIMBOLA A DUROGBITAN and SIMON EYOGWE

NAPE Bulletin, V.31 No. 2 (November2022)P. 64-69 , 2022

Basin and petroleum systems modeling is used to gain insight into a petroleum system. It has prov... more Basin and petroleum systems modeling is used to gain insight into a petroleum system. It has proven to be an effective tool for discovering hydrocarbon in green basins. This is done by representing all the necessary parameters and geological processes that must be simultaneously present and persist till present day to support hydrocarbon generation, accumulation and preservation. When a structure that is likely to hold hydrocarbon is identified through seismic interpretation, and its seismic attributes show reservoir presence, it is termed a "prospect". This prospect can then be matured through petroleum systems analysis. This analysis involves a comprehensive understanding of the origin of present-day subsurface structures that support hydrocarbon accumulation and the likelihood that a basin is expected to contain hydrocarbon. The weakness in this approach is that the petroleum systems elements are analyzed independent of the geodynamics accompanying the generation and accumulation ofhydrocarbon. Basin modeling is a technique that goes a step further to simulate these processes to provide a better understanding and interpretation of the geologic elements and processes that control and favor hydrocarbon accumulation in geologic space and time. This reduces E&P risks associated with maturing an identified prospect. This paper shows how lD and 3D basin modeling techniques were used to predict the presence of charge in identified prospects within an asset in Niger Delta and predict the hydrocarbon type ( oil or gas) present. An integrated approach utilizing data analytical inputs from different disciplines was adopted. Inputs to the model included basement maps, basement lithology, stratigraphic profiles from well and seismic data, global sea level curve data and results from compaction trend analysis. The resulting model was calibrated using temperature data while the hydrocarbon type in the prospect was calibrated using known reservoirs. Several sensitivities were run to capture different scenarios. The results of the thermal model showed that the optimal hydrocarbon accumulation window (60°C -120°C) ranged from 7000 ft to 16,000 ft for the field-the identified prospect was within this depth range. The Eocene to Recent source rock maturity ranged from 1.3 -2 % Ro in the southern portion of the study area to 0.7 - 1.3 % Ro in the northern portion. Hydrocarbon charge commenced at 8Ma to present day (0Ma). Traps were in place before hydrocarbon generation and migration occurred for the prospects. However, the seal integrity of the northern prospects was compromised as hydrocarbons were observed to have re-migrated up dip and outside the field. From the model, deeper prospects to the south appeared to be the most prospective and the hydrocarbon type was identified as oil

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