Journal of
Petroleum and Gas Engineering

  • Abbreviation: J. Petroleum Gas Eng.
  • Language: English
  • ISSN: 2141-2677
  • DOI: 10.5897/JPGE
  • Start Year: 2010
  • Published Articles: 107

Full Length Research Paper

Optimization of Gas Recovery using Co-production technique in Water Drive Reservoir

Maselugbo A. O.
  • Maselugbo A. O.
  • Department of Chemical Engineering, University of Lagos, Lagos, Nigeria.
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Onolemhemhen R. U.
  • Onolemhemhen R. U.
  • Department of Chemical Engineering, University of Lagos, Lagos, Nigeria.
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Denloye A. O.
  • Denloye A. O.
  • Department of Chemical Engineering, University of Lagos, Lagos, Nigeria.
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Salufu S. O.
  • Salufu S. O.
  • Department of Petroleum Engineering, University of Ibadan, Ibadan, Nigeria.
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Isehunwa S. O.
  • Isehunwa S. O.
  • Department of Petroleum Engineering, University of Ibadan, Ibadan, Nigeria.
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  •  Received: 17 May 2017
  •  Accepted: 27 June 2017
  •  Published: 31 August 2017

Abstract

Recovery factor for gas reservoirs are highly dependent on factors such as initial reservoir pressure, abandonment pressure and the type of reservoir drive mechanism. Producing gas reservoirs with active water drive mechanism possess a lot of challenge to the field operator since optimum production of gas is dependent on reduced pressure. Material balance model was used to derive basic reservoir and production parameters thereafter Excel was used to simulate the parameters for both conventional and co-production scenarios using a field data from the Niger Delta Basin. The reservoir contains three producing wells with conventional technique, while co-production has three wells, producing gas from the up-dip and one well producing water from the down-dip. The simulated results show that gas production rate from the three wells changed with respect to the production strategies. Under conventional, gas production rate from the three wells was at a constant rate of 19MMSCF/D for a long period of time. However, under co-production technique, gas production rate was at a constant rate of 38MMSCF/D for a short period of time. Under conventional method, 231.85BCF of gas was recovered from 356.713BCF of gas initially-in-place with recovery factor of 65% until water cut set-in at an abandonment pressure of 2000 psia. However, under co-production technique, the simulated result shows that there was an optimum recovery of gas of up to 92% recovery which is 27% above the conventional technique and the reservoir pressure was depleted to 1000 psia before water cut set-in.

 

Key words: Co-production, Niger Delta Basin, gas production, material balance model, gas reservoir.