RESERVOIR MODELLING AND VOLUMETRICS

voLuMEtriC AND riSk ASSESSEMENt

GPCI provides hydrocarbon in-place volumetrics evaluations not only for segments of leads, prospects or discoveries, but also the assessment of the remaining potential of producing reservoirs or fields.

The risk assessment of individual segments or aggregated opportunities is usually performed in line with the risk matrix of the client. However, if required by the client, gpci can use also its own consistent risking approach. GPCI has also developed a robust workflow for consolidation of individual prospecti ve segments into leads and prospects and isable to define the combined chance factor of the evaluated opportunity for different hydrocarbon phases. This probabilistic approach considers relations between the different chance factors and volumes of the individual segments. the result can be directly associated with the client’s field development plans (LOFs) and economic evaluati ons, and will support the portfolio ranking.

StAtiC 3D MoDELLiNg

Static 3D modelling is important when developing new or mature field, or even when considering the re-development of an abandoned field or an under-developed reservoir. GPCI provides static reservoir modelling by integrating seismic, logs, core, porosity and permeability data, sedimentological analysis, well tests and production data. This will create the sedimentological model of your reservoir, highlight the reservoir properties distribution (NtG, porosity, permeability, saturation, etc.) and reveal flow units. Static models are performed on different workstation platforms depending on clients’ preferences (SKUA, petrel).
Results are directly used for hydrocarbon in-place evaluation and dynamic simulation (outputs suitable for dynamic platforms like Eclipse).

NETWORK MODELING OF MULTIP HASE FLUID FLOW IN POROUS MEDIA AT PORE SCALE

Pore-scale modeling is used to support experimental measurements and go beyond the sole laboratory capabilities. Our approach is based on open source, robust code developed at the London Imperial College for two-phase fluid flow.

The goal is to apply predictive pore-scale network modelling where experimental data are not available or difficult to obtain. Available experimental data are used to anchor the model to a specific core condition. Admittedly, these conditions may vary considerably in the reservoir. Network modelling is used to assess the impact these variations have on relative permeability.

  • Definition of realistic geometric properties of the network such as topology and pore size distribution, pore-scale physics, and wettability characterization
  • Tuning network properties to MICP/SCAL experimental data in order to predict flow properties
  • Generation of capillary pressure curves and prediction of permeability

DYNAMIC RESERVOIR SIMULATIONS

In addition to pore-scale simulations GPCI also provides various types of assistance on reservoir-scale simulations, from the QC of data deck files to full-field production profiles.

  • Quality control of the data deck: the keywords and assumptions made in the data deck are checked and challenged by ensuring that the different inputs are in line with the understanding of the reservoir
  • Data deck construction from scratch to pre-processing
  • Sector or phenomenologic models to study specific challenges, e.g. checking the recovery from the matrix in a fractured reservoir context
  • Running simulations: history matching and predictions taking into consideration different scenarios
  • Beyond the usual services related to reservoir simulations, GPCI has a strong experience in dual-porosity reservoir simulations. This knowledge integrates the key skills in Petrophysics, SCAL and pore-scale simulations