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Led by Senior Reservoir Engineer Simulacrum
Reservoir characterisation and monitoring from rock and fluid properties through petrophysical evaluation, material balance, decline curves, pressure transient analysis, EOR, and the surveillance methods that track reservoir behaviour throughout field life.
Led by Senior Reservoir Engineer Simulacrum
The question
What can a reservoir hold, and how will it flow? Porosity defines storage capacity. Permeability — governed by the Darcy equation and shaped by wettability — defines flow capacity. Water saturation, estimated through the Archie equation and the capillary pressure profile, determines how much of the pore space contains oil. PVT properties describe how the fluids behave as pressure declines during production. The module closes with the five reservoir drive mechanisms and their comparative recovery efficiency — the first diagnostic for interpreting any production history.
Outcome
The student can define porosity, permeability, and water saturation, explain how each is measured and what governs their uncertainty, describe the relative permeability concept and why wettability controls its shape, and name the five drive mechanisms and their relative recovery efficiency. (Rock and fluid properties — the measurement foundations)
Sub-units
Led by Senior Reservoir Engineer Simulacrum
The question
How does the reservoir engineer move from well data to a quantitative model of what lies between the wells? This module works through the full characterisation sequence: core analysis and the core-to-log calibration, well log interpretation for lithology, porosity, and saturation, rock typing using the flow zone indicator, geological modelling from seismic and geostatistics, and the transition from static geological model to dynamic simulation model through upscaling and history matching.
Outcome
The student can describe the core analysis workflow, identify the primary log inputs at each step of the petrophysical evaluation, explain rock typing using FZI, and describe the distinction between the static and dynamic model and what the history match achieves. (Reservoir characterisation — the data-to-model workflow)
Sub-units
Led by Senior Reservoir Engineer Simulacrum
The question
Production data and pressure data are the reservoir's continuous signal — but only if the engineer knows how to read them. This module develops the four analytical instruments: material balance for STOIIP estimation and drive mechanism identification, Arps decline curves for production forecasting, pressure transient analysis for permeability and skin measurement using the Horner plot and the Bourdet derivative, and reservoir simulation as the integrating tool for full-field development planning.
Outcome
The student can apply the Havlena-Odeh straight-line method to identify drive mechanism and estimate STOIIP, fit Arps decline curves and calculate EUR, extract kh and skin from a Horner plot, and identify the key flow regimes on a Bourdet derivative plot. (Reservoir performance analysis — the diagnostic toolkit)
Sub-units
Led by Senior Reservoir Engineer Simulacrum
The question
Natural depletion recovers a fraction of the oil in place — EOR and waterflooding aim to close the gap. This module covers the three EOR mechanism categories and which recovery efficiency each addresses, waterflood design using the Buckley-Leverett analysis and mobility ratio, and the surveillance tools for tracking whether the injection is working as planned — the Hall plot, production logging, pulsed neutron saturation monitoring, tracer testing, and 4D seismic.
Outcome
The student can describe the three EOR categories and the efficiency term each addresses, calculate VRR and interpret a Hall plot, name four surveillance methods for tracking fluid movement, and explain the 4D seismic principle and the Gassmann equation's role in it. (EOR, surveillance, and production data integration)
Sub-units
Led by Senior Reservoir Engineer Simulacrum
The question
Every reservoir model is wrong — the question is whether it is wrong in ways that affect the decisions it is being used to make. This module develops the uncertainty management framework: tornado charts, Monte Carlo simulation, P10/P50/P90 forecasts, decision trees and value of information. It then covers SPE-PRMS resource classification, the mature field management toolkit — pressure maintenance, infill drilling, recompletions, production optimisation — and the economic limit that governs the abandonment decision.
Outcome
The student can describe the main sources of reservoir uncertainty and how Monte Carlo simulation propagates them to an EUR distribution, apply the P10/P50/P90 framework, classify volumes using SPE-PRMS, name five mature field management interventions, and explain the economic limit and gas lift optimisation by slope equalisation. (Reservoir management — uncertainty, maturity, and asset strategy)
Sub-units