RMS™ Flow Simulation is a fully integrated black-oil flow simulator within the RMS environment. A graphical user interface links RMS with the reservoir simulator Tempest™ MORE, which then can be executed as part of any workflow within RMS. Access to dynamic simulations offers the option to investigate dynamic uncertainty, perform forecasting, or rank models as part of an integrated study within RMS.
Flow Simulation Features
- Fully integrated, three-phase black oil flow simulator
- Improves cross-disciplinary integration in the asset team
- Offers easy and keyword-free access to a reservoir simulator
- Additional access to all simulator keywords through a keyword editor
- Extensive range of well and group controls
- Visualization of static and dynamic data in the same powerful viewer
- Post-processing of dynamic data
Integrated Static and Dynamic Modelling
The RMS Flow Simulation module is designed for geologists and reservoir engineers operating in an asset team environment. Sharing a single data model within the team leads to productivity gains and improved understanding of the reservoir management tasks at each point in the modeling process. By including dynamic data (production profiles, well tests and pressure measurements) earlier in the modeling process, the geologist will be able to hand over upscaled simulation models that are better suited to history matching by the user’s preferred in-house full field simulator.
The Flow Simulation tool uses the RMS GUI and data management conventions. This permits a Flow Simulation job to be easily copied within or across zones to encourage sensitivity analysis. The job can be placed in the Workflow Manager and executed across realizations.
RMS Flow Simulation has access to all RMS grid parameter data within the zone. The index parameters can be used to set up sub-regions of the grid, where different rock and fluid properties can be set. These are also used for defining reporting regions. The results of the simulation can be displayed in the same 3D window as the original geological model. Time-dependent well and group profiles can be plotted in the Data Analysis Window of the multiviewer. The output from multiple simulations created from different jobs or realizations can be compared.
Traditionally RMS has been used to create, edit and manage the static data required for reservoir simulations. RMS Flow Simulation extends the data model to include automatic calculations of well connection factors and time-dependent well controls.
Grid: The simulation grid can be a sector of a geological model or an upscaled model. An index parameter can be used to set regions inactive.
Grid Properties: A Flow Simulation job uses the output from an existing Transmissibility job. This contains the effects of all fault multipliers and can easily be modified to test the effect of sealing faults. Porosity and net-to-gross properties are selected from pre-calculated parameters or as grid-wide constants.
Fluid & Rock Properties: Property tables can be generated from industry standard correlations or imported from a full field simulation model. Graphical plots of this data allow it to be quality controlled before starting a job.
Wells: Wells are loaded upstream in RMS. The set of wells and any group hierarchy can be selected in RMS Flow Simulation. The wells are manipulated in real world coordinates. The perforated sections can be set in TVD or measured depth intervals, or according to well log properties. For example, it is possible to perforate only the grid blocks corresponding to the channel sands of a defined facies.
Events: The well, group controls and any economic limits are supplied as event tables. These time- dependent tables start and end at specified dates. The engineer need not supply these in time order, as required by conventional keyword simulators. RMS Flow Simulation automatically threads through the complete set of events and selects them in the correct order.
RMS Flow Simulation contains a comprehensive reservoir simulator that uses robust, fully implicit solver techniques to handle demanding reservoir engineering problems. It models multi-phase flow using the standard black oil model description. Automatic intelligent coarsening algorithms can be used to dramatically reduce the number of cells while retaining the dynamic response of the reservoir. It offers extensive well and group control modes, including economic limit conditions on wells, group and field level quantities.
3D solution arrays - pressure, absolute and mobile saturations - and their variations over time are reported. Well production and injection profiles of fluid rates, cumulative pressures and regional averages are available by default.