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DDG     (Drilling Dynamics Geomechanics)


We developed DDG to maximize ultimate recovery and minimize risks of wellbore integrity, casing deformation, induced seismicity, and environmental hazards. To ensure safe and cost-effective drilling and hydraulic fracturing operations, knowledge of the subsurface geomechanical characteristics is essential. The currently available methodologies for geomechanical modeling are heavily dependent on well logs which are not always available at the quantity and quality required for geomechanics.

The Drillbit is the first logging tool to touch the rock formation generating a large volume of rich dataset. Using robust interpretation schemes, these data can be used to evaluate the geomechanical characteristics of the formations. TEVERRA’s Drilling Dynamics Geomechanics (DDG) technology solves this problem. Its architecture processes complex drilling dynamics data and extracts valuable geomechanical characteristics It enables high-resolution geomechanical modeling and wellbore stability analysis for entire well length without requiring any logs. DDG has been successfully tested in several onshore and offshore locations around the world.



Over the past two decades, there has been a significant advances in sensing technologies and data acquisition systems. These datasets require swift, automated and affordable interpretation and storage to enable both real-time decision-making and post-analysis. However, the conventional data analysis and interpretation mechanisms are often rudimentary, requiring significant time to transmit the high-resolution data to the cloud, and the processing needs significant human intervention.

Monitoring, Verification, and Accounting (MVA) to confirm permanent storage of CO2 in geological formations is a significant cost component of any carbon storage campaign and indeed, necessary for its success. Automated and low-cost MVA solutions can advance Carbon Capture and Storage (CCS) towards commercialization by providing a reliable and real-time control option over the reservoir as well as reducing the associated costs. Such solutions should address the data management bottlenecks available today including insufficient bandwidth, inadequate storage, and limited connectivity. A key solution to overcome these challenges is to reduce the volume of the recorded data streamed on site with CompressDeck.

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CarbonWatch is a newly developed technology that can monitor the spatial distribution of injected CO2 in a near real-time manner from geophysical field measurement data. It provides critical information for agile decision making, to mitigate the risks like CO2 leakage and fault reactivation, as well as to improve the storage utilization efficiency. This is achieved by integrating rock physics modeling and advanced machine learning algorithms. The workflow built within CarbonWatchTM has broad applicability for subsurface monitoring of pore fluid evolution associated with physical relationships and rock properties. Similar to CCS and plume migration, we predict our workflow, with minor updating, will have the ability to successfully identify evolution of the fluid pathway during geothermal production. This information can help optimize heat sweep efficiency, thereby maximizing operation economics.



OurGeoDeck software  eliminates or minimizes the rigorous setup, the time and cost, and the complexity faced when visualizing geologic subsurface data . GeoDeck makes the visualization process more productive, scalable, and accessible to a wider range of audiences. The software is designed and customized for people who do not necessarily have the time or skill to use conventional software. It extracts insights from physics-based analytical workflows which are notoriously time-consuming and complicated. To offer maximum simplicity and accessibility, GeoDeck uses the web, i.e., it is available as a regular website that users can load in their browsers.

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Application Programming Interface (API) exposed in the browser environments is employed to create a fast and seamless user experience on the web with modern graphics. Moreover, since subsurface data are often too large to be handled by browsers (or even user’s machines), GeoDeck intelligently and dynamically loads the current data to be viewed. We believe that style and simplicity matter. GeoDeck lets users seamlessly perform uncertainty studies on static and dynamic subsurface properties under different operational or computational scenarios through its smart sampling mechanism. Users are usually one click away from generating the graphs needed such as heat maps, iso-surfaces, scatterplots, statistics, etc., for presentations and reports.

Finally, GeoDeck has a long term vision for data visualization made through ever-increasing virtual reality (VR) and augmented reality (AR) technologies such as Oculus, Google VR, and other popular AR/VR headsets. At TEVERRA, we believe the ultimate immersive experience is only possible through VR and AR, and our software is designed to accommodate future extended reality (XR) integration on the web.



ConvertDeck analyzes the geothermal production for both electricity and direct-use (heating/cooling) opportunities while also examining the local utilization market potential. The tool can be used in two ways. It can identify wells that will achieve pre-determined financial requirements given the input data, or it can identify potential use case scenarios and then estimate the economic value of the different scenarios. This decreases evaluation time by combining expert analysis from multiple disciplines into one intuitive platform. Decreasing evaluation time produces faster and more cost-effective analysis.

ConvertDeck Benefits:

  • Reduces the hydrocarbon-to-geothermal well conversion evaluation study time 

  • Increases well conversion profitability by increasing the understanding of the opportunity 

  • Contains over 100 unique parameters to calculate an accurate estimate of the geothermal economic potential

  • De-risks conversion project by identifying the most profitable projects

  • Designed for quick repeat screening to analyze multiple end use scenarios

  • Prevents overly conservative valuations

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The subsurface can be heated and used as a medium for thermal energy storage. Synthetic Geothermal Reservoirs (SGR) use the subsurface as a medium for the storage of heat collected in concentrated solar collectors or energy from wind turbines to reliably produce on-demand electrical power using the recovered heat.

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Synthetic Geothermal Reservoir    (SGR)  




The evolution of fractures in reservoirs determines the efficacy of an enhanced geothermal system (EGS). Monitoring changes in fracture network characteristics aid assessment of reservoir performance. The real-time EGS assessments provide valuable information to optimize stimulation schemes and maximize heat production.. Our AI-based system would characterize differences in various aspects of geology/reservoir, regulation/permitting, and available data between the old and new fields. The value of this project includes:

  • Monitoring the evolution of fractures under different operational conditions

  • Assessing, improving, and predicting EGS performance from prior learning

  • Developing a site specific EGS design from knowledge of natural fractures in heat production



TEVERRA is developing an innovative downhole system for direct measurement of in-situ stresses. It will have huge impacts on improving accuracy and validity of the designs and models used for subsurface operations including drilling, completions, stimulation, injection, and reservoir management. The lack of sufficiently reliable knowledge of in-situ stresses costs the energy industry billions of dollars every year. These losses are associated with non-productive time during drilling caused by stress-related problems; poor well design including trajectory, casing, and mud designs; failure of hydraulic fracturing treatments due to incorrect estimation of the pressure required to breakdown zones; erroneous prediction of fracture dimensions/direction; poor evaluation of the shear strength/conductivity of natural fractures; flawed placement of parent and child wells; well integrity issues, and lack of understanding of the risks during production.

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