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Optimizing productivity in oil rims: simulation studies on water and gas injection patterns

Authors
  • Oluwasanmi, Olabode1
  • Pastor, Alonge-Niyi1
  • Charles, Onuh1
  • Christopher, Nwozor1
  • Seyi, Orisamika2
  • 1 Covenant University, Ota, Ogun State, Nigeria , Ota (Nigeria)
  • 2 University of Ibadan, Ibadan, Oyo State, Nigeria , Ibadan (Nigeria)
Type
Published Article
Journal
Arabian Journal of Geosciences
Publisher
Springer-Verlag
Publication Date
Mar 22, 2021
Volume
14
Issue
7
Identifiers
DOI: 10.1007/s12517-021-06945-3
Source
Springer Nature
Keywords
License
Yellow

Abstract

Thin oil rim are reservoirs with hydrocarbon pay zone not more than 100 ft. Production challenges mainly water, and gas coning arises due to this trait and presence of a larger gas cap and aquifer. To safely exploit from oil rim reservoirs, the right production choices and optimization of production parameters need to be implemented before the commencement of any recovery scheme. A case study reservoir of an oil rim in the Niger-delta producing region is placed on a concurrent production via 8 horizontal producer wells after history matching and optimization of production parameters using a black oil simulator (Eclipse). Six different pattern scenarios of water and gas injection at 3 rates are considered: optimized oil recovery estimates of 5.43%, 4.51%, 5.41%, 4.93%, 5.89%, and 5.82% for inverted direct line water injection, inverted staggered water injection, inverted 4 spot injection, 5 spot water injection, inverted 7 spot water injection, and inverted 9 spot water injection respectively. The incremental oil recovery over the base case (no injection) recorded in like manner are 1.43%, 0.51%, 1.41%, 0.93%, 1.89%, and 1.82%. The results show that pattern water injection at 1000 stb/day is more suitable for optimum oil recovery for oil rims under concurrent production.

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