Direct estimation of Hydrocarbon in place of JAKS Offshore Field, Niger Delta using empirical formulae Technique


Authors : Osaki, L.J; Itiowe, K, Mgbeojedo; T.I, Agoha, C.C; Onwubuariri, C.N; Okoro, E.M

Volume/Issue : Volume 6 - 2021, Issue 10 - October

Google Scholar : http://bitly.ws/gu88

Scribd : https://bit.ly/2ZCuY9O

The 3D seismic intėrpretation and petrophysical assessment of thė JAKS oil field in the Niger Dėlta was successfully carried out by performing a comprehensive structural analysis, reservoir delineation and volumetric assessment of the field using seismic data, drilling logs and empirical formulas. The work was carried out in two stages; seismic data interpretation and petrophysical data analysis. These phases are combined to evaluate the hydrocarbon reserves of the reservoir using the empirical formula approach. The methodology includes the delineation of lithology from the gamma ray log, the identification of reservoir fluid types from the resistivity and the neutron / density combination log, borehole correlation, horizon and fault mapping from seismic data, determination of petrophysical parameters from empirical equations. The reservoirs' original hydrocarbon stocks were also assessed based on the weighted averages of porosity, water saturation, gross rock volume and net to gross ratio. The research shows a deep structure map with massive, NNW running anticline, with four associated fold-related synthetic and antithetical normal faults (F1, F2, F3, F4); understand that they were folded and faulted by localized overburden stresses resulting from a combination of differential loading on the deep-seated overpressureductile beneath compacted marine Akata shale and the gravitational collapse of the Niger Delta continental slope due to the inflow of sediments. The petrophysical analyzes have shown that the mean porosity value of the deposit sand units is in the range of 25, -31%, the mean permeability values of the deposit sand units are in the range of 61-1452 mD, the mean slate volume in the range of 20.5-38.6% lies. The water saturation and hydrocarbon content of the reservoirs ranged from 15 to 41% and 59 to 85%, respectively. The results of the study show that the field has good structural and petrophysical parameters for hydrocarbon potential and enables hydrocarbon production. The average Original Oil in Place (OOIP), which is calculated using the empirical formula method with the petrophysical parameter, is 29 bbls / STB, while the Stock Tank Oil In Place (STOIP), the oil volume after production, is 22 bbls / STB . The primary extraction reserve is 20,381,028.23 barrels, which can be extracted with a primary extraction factor of 10%. The Empirical forecast approach for hydrocarbon in place is a substitute and reliable remedial method pending a qualitative 3D geostatic model technique.

Keywords : Empirical formulae technique, Porosity, Permeability, Hydrogen Saturation, Primary Recovery.

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