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Emerson Launches Latest Reservoir Engineering Software Enhancements


Published Mar 29, 2016
Emerson Process Management Roxar Tempest™ 7.2
Pairs Plot within Tempest 7.2 that show the correlation between uncertain simulation input parameters and history match quality (illustration: Emerson Process Management)

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 optimisation, and brownfield development.

Tempest 7.2 comes with significant enhancements to its history matching and uncertainty analysis module Tempest ENABLE that will help oil and gas operators generate accurate production estimates, quantify uncertainty, and minimise financial risk. 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.

“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,” says 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.”

New features within Tempest 7.2 include the “Roxar App Connector” that allows users to set up a complex, 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 accurate 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, a more realistic assessment of the underlying uncertainty in the production estimates is achieved as well as encouraging greater collaboration between reservoir engineers and geologists. 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. The result is improved and more detailed uncertainty analysis.

Tags: Emerson Process Management




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