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SPE ATCE 2020 Virtual

October 27 - 29, 2020
Virtual Event


Welcome to this year’s virtual SPE ATCE.  We have compiled multiple presentations covering a wide variety of topics of interest to the SPE community. These topics are organized into three categories below; the presentations focus on workflow optimization for cost-effective reservoir management. 

Emerson continues to build upon its 30+ years of developing and delivering exceptional, production-ready solutions that can be applied to your assets through flexible software licenses and services. 

We look forward to your participation in our program and the virtual SPE ATCE.

Efficient Field Development

Break Through Uncertainties and Design an Optimal Field Development Plan
Presenter: Camille Cosson

This presentation outlines the benefits of Big Loop, an automation and integration solution designed to support strategic field management decisions. We present an integrated reservoir modeling case study, following these steps: Workflow automation, assisted history match, and risk assessment; finally, we will design not only a good enough, but an optimal field development plan, using all available information.

The solution has been implemented for several fields and benefits have been quantified: reduced costs and increased production. Looking back, asset teams using Big Loop have leveraged its technology capabilities to change their approach to reservoir modeling and adopt new collaboration behaviors that result in increased productivity.
Solutions covered in this session: Big Loop™

Integrated Production Management, from Subsurface Studies to Daily Production
Presenter: Andrey Klimushin

METTE provides flow assurance and production optimization services to the upstream oil and gas industry. Ensuring the successful and economical flow of a hydrocarbon stream from the reservoir to the surface is crucial, and both risk mitigation and optimal design are needed to reach a profitable target. Gain a deep understanding of the network with our solution of life-of-field simulations networks from reservoir to production facilities. Our module takes into account user-defined production constraints, employing a powerful built-in event module. It automatically determines the need for choking, artificial lift and pressure boosting. Quantify the effect of artificial lift, determine phasing of pressure boosting equipment, identify bottlenecks, evaluate new tie-backs, and obtain expected variations in mass and energy balances.
Solutions covered in this session:  RMS™, Tempest™, METTE™

Optimizing Field Development with Emerson SKUA-GOCAD Automation Solutions and Data Science Workflows
Presenter: Jeremy Rihet

Enhanced Oil Recovery (EOR) strategies are becoming increasingly common in the Middle East, used primarily for optimizing mature fields. Choosing the right location to implement the EOR scheme is critical to the success of the Field Development Plan. One approach for a given field is to subdivide a 3D geo-cellular model into different sectors and perform a statistical analysis of the 3D model’s properties in each individual sector. This task is usually performed manually and can be resource intensive and time-consuming. In particular, in the case of large mature fields, the scale and data volume involved make the workflow impractical to implement.

Advanced automation methods, developed to rapidly generate EOR sectors and perform the statistical analysis of 3D model properties, are therefore necessary. This work presents a new workflow for extracting and analyzing model properties at a scale relevant to EOR planning.
Solutions covered in this session: SKUA-GOCAD™

Reduce Unnecessary Spending on Equipment by Optimized Geosteering and Well Planning
Presenter:  Andrey Klumishin

One of the key objectives when building a reservoir model is to identify potential well targets and plan the wells and well trajectory. This presentation will show how RMS enables multidisciplinary teams to quickly and efficiently design targets and optimize well paths to reduce drilling costs. The RMS Geosteering module helps to prevent problems associated with the geological structure of the reservoir being drilled. RMS enables asset teams to view the 3D model together with the new well, link it with a dynamic model and choose the right top well equipment in advance after an entire simulation loop.
Solutions covered in this session: RMS™

Saving Costs in Heavy Oil and Unconventional Fields : Facies Modeling and SAGD Volume Calculations Using RMS
Presenter: Sasan Ghanbari

This presentation shows how facies modeling and SAGD volume calculations have helped major and independent oil operators to reduce costs by optimizing pads and well placements and ensure the best production results. This involves incorporating all data types and identifying geological trends that will impact the rock property distribution in the model. You will learn how RMS helps to Identify sufficient quality and thickness for the SAGD process to be both effective and economical with an understanding of risk and uncertainty.
Solutions covered in this session: RMS™

SpeedWise Reservoir Opportunity (SRO) - Streamlined Opportunity Identification and Ranking
Presenter:  Hamed Darabi, QRI

Successful reservoir management requires an up-to-date backlog of opportunities that an asset team can pursue to meet expected production targets. Finding the optimal set of opportunities requires combining geological knowledge, reservoir behavior, production history, completion information, and multi-disciplinary expertise. The process of gathering and analyzing data, identifying opportunities, and then vetting each of them, is labor-intensive and generally takes several months. It rarely considers the latest set of acquired data and requires the use of multiple software applications, making information sharing and comprehensive data analysis difficult, often leading to a sub-optimal set of candidates. The process also makes it complicated to look at alternative scenarios by considering different hypotheses; and leaves little time to rigorously validate multiple candidates. SRO, developed in collaboration between Emerson and QRI, is a fully automated, collaborative cloud-native solution that applies advanced computational algorithms, AI, and data mining techniques to multi-disciplinary data to deliver a catalog of ranked opportunities. SRO provides a platform for the asset team to bring together all relevant information and collaboratively review recompletion or new drill opportunities identified from the data.
Solutions covered in this session: SRO™​

Quantifying Petrophysical Uncertainty
Presenter:  Rick Aldred

No petrophysical interpretation is complete without quantified uncertainty included in the results. Petrophysical results play a critical role in the assessment of hydrocarbons in place in a reservoir. However, when the value of a prospect is determined it is not the best technical interpretation which is used, but a pessimistic version of that interpretation, the difference being the quantified uncertainty. It is therefore essential that petrophysicists understand the nature and impact of their uncertainties and are involved in calculating the pessimistic and optimistic cases to be used in the reservoir models. The most thorough methods of quantifying petrophysical uncertainty are a combination of Monte Carlo processing and scenario modelling. Geolog™ has the industry’s leading application of Monte Carlo processing for quantifying petrophysical uncertainty and this lecture will illustrate how the processes should be run and the pitfalls of running Monte Carlo processing incorrectly.


Wellbore Stability Analysis to Reduce Drilling Risk
Presenter:  Anish Tkrishnapillai

The study of geomechanics is important for understanding regional stress orientations and magnitudes, and how these may impact rock properties in the formations around a wellbore. The comprehensive pore pressure prediction and geomechanics workflow in Geolog enables users to assess regional stress regimes and the mechanical conditions around the wellbore, thereby reducing drilling risks while maximizing well and reservoir productivity. This session showcases the pore pressure prediction and geomechanics capabilities in the latest version of Geolog.
Solutions covered in this session: Geolog™​

Virtual Metering as a Cost-effective Production Monitoring Solution
 Sasan Ghanbari
Virtual metering is a very cost-effective solution for monitoring and interpreting operational data to find well phase flows, requiring only a computer linked to a production database for retrieval of measured source data. Based on multiple boundary conditions dictated by measured sensor data, estimate in-situ well production rates. Use it to tune or validate flow models with reference data. Use well flow rates to tune reservoir models. Get answers to determine what is flowing anywhere in your system, and what is needed to optimize the flow of these materials from the reservoir to the sales outlet.
Solutions covered in this session: METTE™


Integration, Automation and Analytics

High-performance Workflow Automation with Big Loop on AWS
 Taha Taha and Srinivas Tadepalli [AWS]
Future digital evolution of reservoir development and management will come from the full automation of multidisciplinary subsurface workflows. The output of these are reservoir models used for forecasting reservoir behavior that are systematically and automatically updated by incorporating the latest petrophysical, geophysical, geological, and production data. The incorporation of all these data provide an evolving view of the asset, and critically, of forecast uncertainty.

This presentation will show a history matching study using an ensemble-based workflow that tightly integrates the static and dynamic domains. Subsurface uncertainties captured at every stage of the interpretative, modeling and predictive processes, are used as inputs within an automated repeatable workflow. By adjusting these inputs, an ensemble of models is created, and their likelihoods constrained by observations within an iterative loop. The result is multiple calibrated models that are consistent with the underlying geology and the observed production data. It is effectively a digital twin of the reservoir with an improved predictive ability that provides a realistic assessment of uncertainty associated with production forecasts.

We illustrate this workflow with data from Volve, a North Sea oil field on the Norwegian continental shelf. The study is conducted in an AWS cloud-hosted environment. ​ The impact of the AWS cloud is profound; overall project time is reduced from weeks to days without typical limitations on the number of simultaneous runs. Results are available within hours instead of days, allowing same-day evaluation​ for faster decisions and improved operational efficiency​. Moreover, enhanced stochastic analyses are now possible for those without high-performance on-premise clusters​.
Solutions covered in this session: Big Loop™

Increase Confidence in Decision-Making through the Efficient Handling, Visualization and Analysis of Ensemble-Based Simulations
Presenter:  Aurore Plougoulen

Ensemble-based methods are recognized as efficient reservoir simulation techniques for uncertainty analysis and high-quality history matching. These methods provide an ensemble of equiprobable models carrying highly valuable statistics and representing uncertainty in the model and its dynamic response. However, most post-processing simulation solutions on the market have not been designed to handle ensembles, so that reservoir engineers often struggle to deal with a high number of simulations, manipulate them as a coherent ensemble, and use the statistics resulting from the models.

This presentation demonstrates an interactive workflow based on powerful data analytics using Tempest, allowing users to visualize, analyze and easily highlight the value of an ensemble. This approach is flow simulator agnostic and can be used in combination with various ensemble methods, enabling efficient peer and partner reviews that lead to a better understanding of the risks, and enlightened decisions. The featured application is a comprehensive solution for ensemble-based simulation post-processing aimed at any asset team eager to make the most of its data.
Solutions covered in this session: Tempest™ VIEW

Turn your Models into Democratic Knowledge with Agile Analytics for Enlightened Decisions
 Melanie Morin and Camille Cosson
The use of Data Analytics is one of the key trends emerging in the upstream and downstream industry. With the increase in the amount of data and related knowledge at various scales, it becomes crucial to adopt a collaborative, interactive and efficient approach to get the most out of complex 3D models built by expert geoscientists, and maximize the understanding of plays with no additional work. Although our industry uses massive amounts of data, we still face challenges, mainly due to a lack of openness and agility in traditional tools. Better insight into models is key for streamlining the expert review of 3D models and for supporting efficient, objective and enlightened decisions.

This presentation will demonstrate how the openness, flexibility and automation capabilities of the Emerson modeling suite enable an efficient and fit-for-purpose analysis to review key models’ characteristics, from regional to field compartment scale. As an example, we will demonstrate the power of the plugin Emerson modeling solution and TIBCO Spotfire data visualization and analytics software.
Solutions covered in this session: Emerson modeling solutions and TIBCO Spotfire® data visualization and analytics software


Understanding Reservoir Behavior

An Efficient Workflow for Saturation Height Modeling
 Brijesh Singh
This session will present a workflow which contains a comprehensive suite of algorithms for interpreting and integrating routine and special core analysis data, allowing effective correlation with conventional log data. It features a highly interactive graphical workflow for rapidly loading, correcting, and analyzing special core analysis data for saturation height modeling, enabling seamless integration of this data with other petrophysical measurements, for more accurate reservoir characterization. Specifically, we will look at: saturation height modeling using core data and log-based saturation height modeling.
Solutions covered in this session: Geolog™

Early Fluid Identification with Geolog Gas Ratio Analysis
 Edwin Wong
Gas chromatography data is often acquired during well drilling operations, and this valuable information is usually underrated. Geolog 19 offers a new Mud Gas Analysis module that helps identify possible hydrocarbons early on, using a gas ratio analysis method. With the combination of different approaches, e.g. Pixler ratio method, Haworth model and oil indicator model, this provides valuable fluid characterization of the potential reservoir.  This helps the operator make accurate decisions about perforation jobs, leading to potential cost savings.
Solutions covered in this session: Geolog™

Introducing Geolog 20
Presenter:  Richard Pelling

Geolog 20 is the latest incarnation of Emerson’s industry-leading formation evaluation product suite. This release offers a wealth of improvements in a number of key areas, such as functionality and usability. These include a revised graphical user interface with remodeled launcher, improved icons and menus throughout the application, and several changes aimed at giving users faster access to the functionality they need. Geolog 20 also delivers enhancements and new developments to many of its primary petrophysical modules, such as Determin, Multimin, Image Processing, Facimage and NMR, while continuing to streamline workflows. This release also provides increased connectivity options, both within the Emerson portfolio and to the industry at large.
Solutions covered in this session: Geolog™


Powerful and Intuitive Data Interrogation for the Efficient Post-processing of Flow Simulations with Tempest VIEW
Presenter:  Aurore Plougoulen

Data visualization and interrogation are key to understanding flow simulation results. When handling multiple simulations consisting of millions of cells and thousands of wells, this task can be very tedious for reservoir engineers.

Tempest VIEW is a fast and memory-efficient system than can reliably process a high number of simulations. It provides reservoir engineers with the tools needed to accelerate the decision-making process through unparalleled analysis of simulation results.

This presentation features Tempest VIEW functionalities that make data interrogation intuitive and powerful, and provide efficient simulation post-processing to a wide range of third-party simulators.
Solutions covered in this session: Tempest™ VIEW


Unleash the Potential of Your Microseismic Data with SKUA-GOCAD
Presenter: Sasan Ghanbari

Microseismic is a costly data source that is typically not leveraged as much as it could be. With this session, you will see how SKUA-GOCAD can help you go deep into your microseismic data, QC, validate and analyze them, and create compelling visualization products and data tables that can be used as input to feed predictive models and correlate fracture parameters with historical production data.
Solutions covered in this session: SKUA-GOCAD™


For additional information, please contact Carmen Comis.