Reservoir characterization of the Hibernia formation, Jeanne d'Arc Basin, Grand Banks, Newfoundland

Fidan, Erkan (1996) Reservoir characterization of the Hibernia formation, Jeanne d'Arc Basin, Grand Banks, Newfoundland. Masters thesis, Memorial University of Newfoundland.

[English] PDF (Migrated (PDF/A Conversion) from original format: (application/pdf)) - Accepted Version Available under License - The author retains copyright ownership and moral rights in this thesis. Neither the thesis nor substantial extracts from it may be printed or otherwise reproduced without the author's permission. Download (18MB) [English] PDF - Accepted Version Available under License - The author retains copyright ownership and moral rights in this thesis. Neither the thesis nor substantial extracts from it may be printed or otherwise reproduced without the author's permission. (Original Version)

Abstract

The offshore Hibernia oil field, discovered in 1979, 315 km (195 mi) southeast of St John's, Newfoundland, has estimated recoverable oil of 83 million m³ (525 million bbl) Sediments of the Hibernia oil field occur within the northeast trending Jeanne d'Arc rift basin (JDB), which records two rift phases, each followed by a period of post-rift thermal subsidence. Reservoir sands in the Hibernia oil field were deposited during the second intense episode of rifting between Callovian and Early Aptian times. -- The Hibernia Formation is Berriasian to Valanginian age and accommodates 85% of the recoverable oil in the Hibernia oil field. The formation is encountered within the average depth interval of 3,400 and 4,200 m. Sandstones of the Hibernia Formation were deposited in a fluvially-dominated deltaic complex and are composed of very fine- to coarse-grained, partially argillaceous quartzarenites and sublitharenites. Porosities (Φ) range between 4% and 24.2% and permeabilities (k) between 0.01 mD to 9860 mD. -- This study, of petrographic lithofacies, log character and response, and engineering data, evaluates Core Lab statistical analysis of porosity and permeability to define "hydraulic flow units" and Canadian Hunter's methodology of petrographic analysis to relate to flow units. Development of drainage character is a crucial process for maximizing hydrocarbon production. Permeability is a crucial parameter which defines the rate of fluid flow, and separate flow units in a reservoir. Permeability is highly variable as a complex function of petrophysical and depositional properties which must be identified on the scale of microscopic lithofacies and macroscopic facies associations. "Hydraulic flow units" of the Hibernia Formation reflect highly variable plug permeabilitv data Definition of flow units by means of k-Φ cross plots distinguish broad variations. -- Three general k-Φ clusters can be defined using k-Φ cross plots. A concept of "Enhanced Textural Maturity Index (ETMI)" relating sorting and roundness is developed. The ETMI shows strong correlation with permeability. "Reservoir Quality Zones (RQZ)" are defined based on facies analysis, SEM/EDS, thin section petrography, and k-Φ attributes. Anomalies contributing to a scattered data pattern are addressed. It is shown that facies architecture of the reservoir (i.e., the "mix" of lithofacies) is critical to effective interpretation. Integrated log suites and RQZ permit estimation of average horizontal permeability ranges in uncored sections when the availability of drill cuttings is restricted or non-existent. By using RQZ as a template in the Hibernia Formation a multi-parameter reservoir modelling and cell characterization in the model can be achieved. -- Individual depositional models have inherent k-Φ relationships. The assemblage models in the stratigraphic package and overprinting of diagenetic effects serve notice that neither geological nor engineering data can be left out of the equation if accurate characterization is to be expected.

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