10.57647/j.ijes.2025.1701.02

Reservoir characterization and hydrocarbon volume estimation of “Lamba” reservoir in Central Swamp depobelt, Niger Delta, Nigeria

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  • Ngwaka Chibuzor Alexis*1,
  • Anyiam Okwudiri Aloysius1,
  • Okeugo Gabriel Chukwudike1,
  • Okeugo Gabriel Chukwudike1,
  • Ibemesi Onyedikachi Peter1,
  1. Department of Geology, University of Nigeria, Nsukka, Enugu State Nigeria
Reservoir characterization and hydrocarbon volume estimation of “Lamba” reservoir in Central Swamp depobelt, Niger Delta, Nigeria

Received: 2024-03-15

Revised: 2024-08-17

Accepted: 2024-11-11

Published 2025-01-10

Copyright (c) 2025 Ngwaka Chibuzor Alexis, Anyiam Okwudiri Aloysius, Okeugo Gabriel Chukwudike, Okeugo Gabriel Chukwudike, Ibemesi Onyedikachi Peter (Author)

Creative Commons License

This work is licensed under a Creative Commons Attribution 4.0 International License.

How to Cite

Chibuzor Alexis, N., Okwudiri Aloysius, A., Gabriel Chukwudike, O., Gabriel Chukwudike, O., & Onyedikachi Peter, I. (2025). Reservoir characterization and hydrocarbon volume estimation of “Lamba” reservoir in Central Swamp depobelt, Niger Delta, Nigeria. Iranian Journal of Earth Sciences, 17(1), 1-11. https://doi.org/10.57647/j.ijes.2025.1701.02
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Abstract

The reservoir quality assessment and the associated risks of the “Lamba” reservoir in the Central Swamp depobelt of the Niger Delta were carried out. These were achieved using integrated exploration techniques of well log sequence stratigraphic correlation, 3-D Seismic interpretation, formation evaluation, play risk assessment (PRA), volumetrics, and risk volume assessment (RVA). Sequence stratigraphic correlation along strike direction indicates a lateral continuity of the reservoir and vertical facies changes down dip. Structural interpretation reveals the presence of back-to-back structures, growth faults, synthetic and antithetic configurations, the major hydrocarbon migration pathway, and the trapping mechanism. Formation evaluation showed that the “Lamba” reservoir possess a net-to-gross value of 0.857; evidence of good sand development, average effective porosity (Øe) value of 0.134 v/v, and hydrocarbon saturation of 0.977 v/v. Analysis of play risk assessment reveals that the delineated prospect (Zircon) is located in the low-risk part of the study area. Volumetric estimation showed that hydrocarbon initial in place (HCIIP) was 6.6 Bscf of gas. Risk volume assessment showed that the reservoir has a probability of success (POS) of 0.228 and a risk volume of 1.5Bscf which suggests a decent hydrocarbon potential for the field.

Keywords

  • Reservoir characterization,
  • Volume estimation,
  • Common risk segment,
  • Probability of success,
  • Hydrocarbon
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