Petrophysical, geomechanical and depositional environment characterization of the Triassic TAGI reservoir from the Hassi Berkine South field, Berkine Basin, Southeastern Algeria

• Published in: Journal of natural gas science and engineering 2021-08, Vol.92, p.104002, Article 104002
• Main Authors: Baouche, Rafik, Sen, Souvik, Ganguli, Shib Sankar, Feriel, Hadj Arab
• Format: Article
• Language: English
• Subjects: Berkine basin; Depositional system; In-situ stress; Petrophysical characterization; Reservoir geomechanics; TAGI Sandstone
• ISSN: 1875-5100
• DOI: 10.1016/j.jngse.2021.104002

An integrated knowledge of the sedimentological data, petrophysical and geomechanical characteristics significantly enhances the understanding of the reservoir properties, leading to a reliable subsurface modeling. This work presents a comprehensive reservoir assessment of the prolific Triassic Argilo-Gréseux Inférieur (TAGI) sandstones of the Hassi Berkine South (HBNS) field, Southeastern Algeria. The Lower Triassic producer appears to be laid down on the Late Devonian erosional surface (Hercynian unconformity) in a fluvial depositional system. Based on the sedimentary structures, a fluvial depositional environment is deciphered from cores. Lateral and vertical disposition of the channel and floodplain deposits from regional well log correlation infers a shift of depositional regime from braided in the SW to meandering in the NE direction. Two distinct reservoir rock types (RRT) are interpreted from core-based petrophysical assessment. RRT1 is composed of macro-megaporous medium to very coarse grained amalgamated channel sandstones and yields the best reservoir attributes, while the mesoporous fine grained RRT2 translates to impervious to poor reservoir quality. RRT1 channel sands are found to be laterally continuous, while the fine grained crevasse splay sands corresponding to RRT2 are laterally discontinuous, thus making them difficult to correlate field wide. Rock-mechanical property-based in-situ stress estimates suggested a normal to strike-slip transitional (Sv ≥ SHMax > Shmin) stress state in the TAGI Formation. Direct measurements indicate that the TAGI reservoir had an initial pore pressure gradient of 11.08 MPa/km and is presently depleted by 2.1–2.5 MPa. A stable depletion stress path value of 0.57 is inferred considering a pore pressure-minimum horizontal stress coupling. At the present-day depletion rate, normal faulting is unlikely to have happened at the TAGI reservoir level and it can be depleted by another 25 MPa before inducing any production-induced reservoir instabilities. •Sedimentary structures interpreted from the cores reveal a fluvial depositional environment responsible for TAGI Formation.•Petrophysical rock typing infers that the medium to coarse grained, laterally extensive, amalgamated channel sandstones (RRT1) yield the best reservoir attributes.•TAGI has a normal to strike-slip transitional (Sv ≥ SHMax > Shmin) stress state.•Reservoir stress path and available depletion window are implied to avoid production-induced normal f