Emerson Process Management has launched Roxar Tempest 7.2, the latest version of its integrated reservoir engineering software suite that can be applied in a wide variety of scenarios such as field appraisal, field optimization, and brownfield development.
Tempest 7.2 has an updated history matching and uncertainty analysis module, Tempest ENABLE, that will help oil and gas operators generate production estimates, quantify uncertainty, and minimize financial risk.
New features within Tempest 7.2 include the ‘Roxar App Connector’ that allows users to set up a multi-application description of their reservoir which can be used in ensemble-based workflows - a set of runs of linked programs that can predict how an oil reservoir may respond and provide statistics on field performance.
To take into account the natural but unknown variations in the geological representation of a reservoir, Emerson has now augmented/expanded its proxy with a stochastic component. As a result, assessment of the underlying uncertainty in the production estimates is more realistic, and greater collaboration between reservoir engineers and geologists is encouraged. While users may not know the precise geology of their reservoir, they will now have access through Tempest 7.2 to a range of reasonable possibilities and can calculate the effect of this range on oil production.
Tempest 7.2 also updates its Tempest MORE and Tempest VIEW modules. New Tempest MORE features include more stable well controls, modeling threshold and breakthrough pressures and handling branched well fractures, improved facilities for sector modeling, and the splitting of models for improved history matching speed. Users of Tempest VIEW will also be able to conduct more flexible history matching analysis on a wide range of results including water breakthrough.
Roxar Tempest 7.2, operating alongside Emerson’s reservoir modeling solution, Roxar RMS, consists of five modules: Tempest VIEW, Tempest MORE, Tempest ENABLE, Tempest PVTx, a fluid analysis tool, and Tempest VENTURE, an economic evaluation tool that provides cash flow analysis derived from simulation results. The five modules can be deployed as an integrated unit with a common interface or individually to enhance existing workflows.
“With Tempest 7.2, we have delivered another stage towards our vision of the integrated, ensemble-based, Big Loop solution where innovative uncertainty quantification and greater geological realism can be applied, and risk quantified across the reservoir management lifecycle,” said Kjetil Fagervik, managing director of Emerson’s Roxar Software Solutions. “The result will be an integrated seismic to production workflow, improved field development decisions, and better investment returns.”
Tempest 7.2 is the latest commercial output from the Total Uncertainty Management Program developed with Statoil and also builds on the long-term collaboration on algorithm development with the University of Durham in the UK.
Image: Pairs Plot within Tempest 7.2/Emerson Process Management
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