Deterministic Fluid Modelling
We use deterministic fluid modelling to integrate all the geological elements and processes that are fundamental to the evaluation of a petroleum system. The same methodology is currently being applied to study the formation of organic H2 in deep sedimentary basins.
Deterministic fluid modelling uses digital data of one or more petroleum systems to reconstruct the evolution of all elements involved as a function of geologic time. It provides a record of the generation, migration, accumulation and loss of petroleum during basin evolution. Calibration to available natural data constrains the model, while sensitivity studies are used to assess the scope of possible alternatives leading to the same results.
Models can be performed in 1, 2 or 3D. We use the suite of Trinity T3 and Genesis (Zetaware), as well as Petromod®(SLB) basin modelling software.
1D modelling: Burial history of a single well location
This quick-look technique provides the burial history of a well, reconstructs the evolution of physical properties of individual sedimentary units as functions of depth or time, and calculates the speed with which kerogen breaks down under thermal stress to generate petroleum as a function of time and depth.
The output can be used to calibrate map-based and 3D petroleum system models, to study the evolution of reservoir properties, the timing of hydrocarbon generation and the evolution of cap rock properties. Flow modelling is not performed at this stage.
Burial history diagram. Colours show porosity evolution of the assigned lithologies.
Changes in maturity (vitrinite reflectance, shown in black) and transformation ratio (red) as a function of geologic time.
Burial history diagram showing the evolution of reservoir temperature and source rock maturity in a North Sea chalk field. The 80 °C isotherm is highlighted to evaluate the risk of biodegradation for an early petroleum charge. The established hydrocarbon generation modelling workflows can be applied to other energy resources or any other burial and temperature dependent process, for example the generation of natural hydrogen from organic matter.
1D burial history model of a Chinese onshore basin well comparing CH4 to H2 generation from organic matter in a coal source rock.
2D modelling: Geologic evolution of a basin transect
This technique provides the burial history along a basin transect, reconstructs the evolution of physical properties of individual sedimentary units as functions of depth or time, and calculates the speed with which kerogen breaks down under thermal stress to generate petroleum as a function of time and depth. In addition to the 1D outputs, prospect and kitchen areas can be modelled and rough phase and compositional predictions can be made.
2D profile showing source rock transformation (red mature blue immature) and migration vectors of oil (green arrows) and gas (red arrows).
2D model profiles showing migration into a North Sea chalk field and leakage through the top seal at 16 Ma and present-day.
3D modelling: Geologic evolution of a basin volume
This technique represents the state of-the-art in sophisticated numerical modelling software and can be completed in either PetroMod® or Trinity 3D. In addition to providing insights into hydrocarbon generation and migration in time and space, migration routes are mappable, and fill-spill scenarios can be tested. Volumes generated are furnished, as are phase, GOR, compositional and quality predictions (PVT).
We use deterministic fluid modelling to predict fluid compositions and properties in undrilled prospects. This is described under PhaseKinetics.
3D view into a basin model showing source rock transformation (