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Investigation and prediction of pore type system by integrating velocity deviation log, petrographic data and mercury injection capillary pressure curves in the Fahliyan Formation, the Persian Gulf Basin

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Abstract

Detecting and understanding the pore types and pore geometries as two crucial attributes of the porous media based on geophysical logs is an essential step in reservoir properties mapping. The Fahliyan Formation is considered as one of the prolific carbonate reservoir3s in the Persian Gulf. In this study, the velocity deviation log and the capillary pressure curves were employed as an efficient way for the quantitative estimation of pore system properties of the Fahliyan Formation. Based on the petrographic studies and velocity log calculations, the Fahliyan Formation is characterized by negative velocity deviations (interconnected pores & vugs), zero deviations (intercrystalline and micropores) and positive velocity deviations (isolated or moldic pores). Integration of petrographic data with velocity deviation log led to the identification of five pore facies (PFs) or hydraulic flow units (HFU), with reservoir quality being increased from PF1 to PF5. Finally, 3D model of pore types and pore facies distribution was prepared by quantifying the well log-derived pore types and their validation with the core data. The results indicate that the reservoir quality of the Fahliyan Formation was affected by the sedimentary and diagenetic processes, but in general, diagenesis has a more significant contribution in developing complex pore types and determining reservoir quality. The best rock types are about the touching vugs and interparticle pores. Based on the velocity deviation log and petrographic analyses, the Fahliyan Formation is divided into the best reservoir unit (equivalent to Manifa), the main reservoir unit (equivalent to middle Yamama), and the low reservoir quality unit (equivalent to upper Yamama).

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Data availability

All data used to carry out this research will be shared upon reasonable request.

Abbreviations

FZI:

Flow zone indicator

\(H\) :

Height above free water level

HFU:

Hydraulic flow units

Kh:

Cumulative flow capacity

MICP:

Mercury injection capillary pressure

\(P_{c}\) :

Capillary pressure

\(Pc_{ob}\) :

Oil–brine capillary pressure

\(Pc_{aHg}\) :

Air–mercury capillary pressure

PF:

Pore facies

PMR:

Normalized porosity

PRTs:

Petrophysical rock types

PTSD:

Pore throat size distribution

PTS:

Pore throat sorting

\(\varphi h\) :

Cumulative storage capacity

RRTs:

Reservoir rock types

RQI:

Reservoir quality Indicator

SGS:

Sequential Gaussian Simulation

SIS:

Sequential Indicator Simulation

SMLP:

Stratigraphic Modified Lorenz Plot

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Acknowledgements

Iranian Offshore Oil Company (IOOC) is acknowledged for data preparation and their cooperation in conducting this research.

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Authors and Affiliations

  1. School of Geology, College of Science, University of Tehran, Tehran, Iran

    Mohammad Derafshi & Hossain Rahimpour-Bonab

  2. Earth Sciences Department, Faculty of Natural Sciences, University of Tabriz, Tabriz, Iran

    Ali Kadkhodaie & Rahim Kadkhodaie-Ilkhchi

  3. Petrophysics Department, Iranian Offshore Oil Company (IOOC), Tehran, Iran

    Hamid Moslman-Nejad & Amir Ahmadi

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  1. Mohammad Derafshi
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  2. Ali Kadkhodaie
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  3. Hossain Rahimpour-Bonab
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Derafshi, M., Kadkhodaie, A., Rahimpour-Bonab, H. et al. Investigation and prediction of pore type system by integrating velocity deviation log, petrographic data and mercury injection capillary pressure curves in the Fahliyan Formation, the Persian Gulf Basin. Carbonates Evaporites 38, 22 (2023). https://doi.org/10.1007/s13146-022-00837-7

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