English Russian
 
 

Events

Technical Sessions - North America Series - Part 2

June 16 - July 30, 2020
11:30 AM CDT (unless otherwise noted)
EMR_Tech-Series_N-America_Hubspot_v02-(002).jpg


Our current environment has been profoundly changed, forcing all of us to work from home and connect differently, while facing growing challenges in the oil and gas industry.

In light of these circumstances, Emerson is introducing a series of online Technical Sessions covering the breadth of geoscience domains; from seismic depth imaging to reservoir modeling. We hope you will use this time to sharpen skills, learn new methods to help you improve efficiency, and connect with a geoscience subject matter expert who will answer your questions during each live session. 

We invite you to register for any or all of the lectures. 

Date

Title

Register

Tuesday, June 16
11:30 AM CT

Presented by: 
Elive Menyoli

Seismic-driven Fracture Analysis from Full-azimuth Subsurface Angle Domain Data: A South Texas Case Study
Featured technologies:  QSI, EarthStudy 360™

High density full-azimuth seismic acquisition may record data revealing information about subsurface fracture and stress orientation and intensity. This information is useful for prospecting tight reservoirs.

This session will show a methodology for extracting fractures from a South Texas dataset. In two formations with seismic-scale fracture system (Austin Chalk and Olmos Formations), the vertical fractures appear to be associated with the major tectonic faulting that occurred in this area. Identifying those local areas within a play with higher probability of natural fracture corridors can be vital for asset portfolio management and horizontal well placement.

The entire fracture characterization process is carried out in the Local Angle Domain (LAD), a domain that describes subsurface image points by two polar angle systems that capture full-azimuth reflectivity and full-azimuth directivity. The data parameters are measured in situ over all reflection angles and azimuths, making data more relevant for fracture analysis.

What you will learn about in this lecture:

  1. Fracture analysis methods
  2. Seismic velocity variation with azimuth
  3. Seismic imaging in the Local Angle Domain
watch_the_video_blue-(17).png
Thursday, June 18
11:30 AM CT

Presented by: 
Zahary Vera

Improving your Structural and Stratigraphic Interpretation using Seismic Attributes
Featured technologies:  SeisEarth™, Seismic Attributes

Recent advances in seismic acquisition, processing and visualization enable us to extract more value from seismic data than ever before. Physical attributes may be used as direct hydrocarbon or lithologic indicators, while geometric attributes facilitate the definition of both the structural and stratigraphic framework of the seismic interpretation. Fast on-the-fly computation, multi-volume visualization, image processing through advanced merge and voxel opacity, are some of the techniques that enable the efficient use of seismic attributes.

In this workflow-based presentation, we will show how geoscientists can use Emerson’s latest technologies to provide details of the structural, stratigraphic, and fluid framework not readily visible in normal seismic amplitude image,s to derive new insights into the subsurface.

In this lecture, you will learn about:

  1. Extracting geological information not readily visible in regular seismic data
  2. Visualization techniques for the efficient use of seismic attributes
  3. The Principal Component Analysis workflow
watch_the_video_blue-(18).png
Tuesday, June 23
11:30 AM CT

Presented by: 
Bruno de Ribet

Enhanced Seismic Interpretation from Diffraction Energy​
Featured technologies: EarthStudy 360™ + Epos™-based seismic interpretation software

Although diffracted energy is recorded during data acquisition, it is suppressed by conventional processing and standard imaging algorithms, where summations and averaging processes are applied, resulting in the loss of high-resolution structural information.  Current processing workflows rightly focus on high specular amplitudes to enhance the continuity of seismic reflection events, thus improving the structural mapping of the subsurface.  Consequently, in a traditional seismic interpretation workflow, some derived discontinuity attributes (e.g. coherence, curvature or fault likelihood) may carry only partial information.

This presentation will describe the decomposition of the full wavefield, and the benefits of separating reflection and diffraction energy fields through various case studies, to provide geoscientists with high-resolution subsurface images containing different types and scales of discontinuous geometrical objects. The objective is to leverage the traditional seismic interpretation workflow by integrating information relative to diffraction energy like any another poststack attribute to be interpreted.

In this lecture, you will learn how to:

  • Decompose the full wavefield and the benefits of separating reflection and diffraction energy fields.
  • Leverage the diffraction energy recorded at data acquisition to improve seismic interpretation.
  • Obtain high-resolution subsurface images.
watch_the_video_blue-(20).png
Friday, June 26
11:30 AM CT

Presented by: 
Elive Menyoli

Deep Learning for Automatic Geological Feature Detection and Classification
Featured technologies:  EarthStudy 360™, SeisEarth™

Modern 3D data-rich surface acquisitions sample an equally rich set of subsurface information, resulting in different wavefields associated with different subsurface features and conditions. These wavefields carry signatures related to fractures, faults, edges, points, and other structural discontinuities, features not always easy to resolve because of size and low illumination energies. When isolated, these wavefields can be used to produce feature-targeted images of unprecedented resolution and clarity.

To capture all these wavefields, a full-azimuth prestack depth imaging procedure is used that maps data into a multi-dimensional prestack directional angle gather consisting of thousands of traces (directions) illuminating each subsurface point from a rich spectrum of angles. When combined with Principle Component Analysis (PCA), deep learning filters can be applied to these directional gathers to extract subsurface features (e.g. faults, stratigraphic edges, karsts) that are often lost or heavily attenuated with standard seismic processing and imaging methods. 

In this lecture, you will learn about:

  1. Resolving low energy faults and edges
  2. Applying Principal Component Analysis (PCA) to decompose seismic data
  3. Applying deep learning to classify and extract geologic features such as reflectors, edges, faults, and organized noise from multi-dimensional seismic data 
watch_the_video_blue-(19).png
Tuesday, June 30
11:30 AM CT

Presented by: 
Andrey Klimushin

Integrated Production Management, from Subsurface Studies to Daily Production
Featured technologies:  RMS™, Tempest™, METTE™ 

METTE™ provides flow assurance and production optimization services to the upstream oil and gas industry. Ensuring successful and economical flow of the 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 simulation 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 the phasing of pressure boosting equipment, identify bottlenecks, evaluate new tie-backs, get expected variations in mass and energy balances.

Optimize well flow.  Investigate different production strategies, see the implications on operating conditions as well as recovery, and make safe decisions. Understanding what the well can deliver ensures a proper match of production string design and lifting performance.

In this lecture, you will learn how to:

  1. Optimize well flow
  2. Investigate different production strategies and see the implications on operating conditions as well as recovery, and take safe decisions.
  3. Understand what the well can deliver, to ensure a proper match of production string design and lifting performance.
watch_the_video_blue-(21).png
Thursday, July 2
11:30 AM CT

Presented by:
Zahary Vera
 

A Flexible and Robust Time-Depth Conversion Workflow Using Various Velocity Sources
Featured technologies:  Explorer™

Velocity modeling is a critical step in accurate time-to-depth conversion and hydrocarbon volume estimation. Consequently, a comprehensive and intuitive solution fully integrated into the main interpretation platform is crucial for workflow productivity.

The time-depth conversion process is required in several steps of typical G&G workflows, such as structural mapping and volumetric calculations, QSI activities, well log data domain conversion, and well planning.  To support these multiple objectives, a single, shared window implementation is required to build velocity models consistently, combining different velocity sources in a more straightforward way. 

In this presentation, we will show how the Global Velocity Model can enable velocity workflows that use many kinds of velocity information, spanning simple to complex geology, in cases where there are few or no wells to many wells, and from a single seismic survey to multi-survey cases.

In this lecture, you will learn how to:

  • Create velocity models through an easy-to-use, one-window interface.
  • Define and QC a velocity model using various velocity sources
  • Adjust your velociy model to Checkshots
watch_the_video_blue-(22).png
Tuesday, July 7
11:30 AM CT

Presented by:
Pat Stirling

Advanced Tips and Tricks for Petrophysicists, Geoscientists and Technicians for Quick Data Management, Manipulation and Visualization
Featured technologies:  Geolog™

This presentation will focus on various methods of data searching, data querying and data manipulation in Geolog. Most of the topics presented are the result of common ‘How to’ questions from clients like you, which resulted in a ‘customized’ solution leveraging the major strengths of Geolog.

In this session, we will look at:

  • Using the new query tool to create new sets of data
  • Converting continuously sampled facies logs to tops interpolated and vice versa
  • Creating quick look lithology logs
  • Highlighting tips and tricks
register_blue-(8).png
Friday, July 10
11:30 AM CT

Presented by:
Dennis Ellison

Enhancing Reservoir Prediction by Strengthening Seismic Attribute Analysis with a Waveform Classification Workflow​  
Featured technologies:  SeisEarth™

The waveform analysis and classification technique is useful for extending attribute analysis to determine geologic similarity and variability from seismic data. Attribute analysis assumes that the attributes used are descriptive reservoir changes. While true generally, it alone can lead to false positives through insufficient risk reduction in exploration and development; and false negatives, making potential prospects become overlooked. Waveform classification takes a different approach, as it analyzes the attribute waveform throughout the interval before reducing it to one value. The results provide a richer understanding of reservoir rock properties and spatial delineation. 

In this lecture, you will learn how to:

•    Reveal more geology from seismic data
•    Expand seismic investigation toolkit
•    Improve confidence in reservoir prediction and delineation


register_blue-(9).png
Tuesday, July 14
11:30 AM CT

Presented by:
Elive Menyoli

Seismic Depth Imaging in the Presence of Azimuthal Anisotropy
Featured technologies:  EarthStudy 360™

Orthorhombic velocity modeling and imaging provide key alternative technologies for recovering natural fractures. However, the determination of orthorhombic parameters is challenging and requires special methods to obtain in-situ azimuths with rich sampling. Additionally, proper orthorhombic imaging in the depth migration domains, rather than time migration domain, requires interval parameters instead of simple effective parameters.

In this session, we present a methodology where the entire orthorhombic imaging process is carried out in the Local Angle Domain (LAD), a domain that describes subsurface image points by two polar angle systems that capture full-azimuth reflectivity and directivity.

In order to build an orthorhombic velocity model for imaging and fracture characterization, other workflow steps are needed to ensure a more stable and reliable outcome. These include shallow velocity modeling, surface noise attenuation, and data regularization for low fold acquisitions. This session will also cover other processing steps that are pre-requisite for a successful outcome. 

In this lecture, you will learn about::

  • Image quality uplift post-orthorhombic imaging
  • Advantages of seismic imaging in the local angle domain 
register_blue-(10).png
Thursday, July 16
11:30 AM CT

Presented by:
Kim McLean

Optimizing Petrophysics to Solve Mineralogical Complexity in Conventional Reservoirs​
Featured technologies:  Geolog™

Petrophysical analysis provides vital input to most, if not all, geoscience workflows. While a deterministic approach to formation evaluation will provide values for shale volume, porosity and saturation, taking into account mineral and fluid volume complexity can offer more insight into the distribution of your petrophysical properties.

In this session we will look at:

  • The theory behind the Multimin optimized petrophysical method in Geolog™
  • Utilizing the Monte Carlo method as part of the Multimin workflow
  • Probabilistic model switching
register_blue-(1).png
Tuesday, July 21
11:30 AM CT

Presented by:
Sasan Ghanbari

Virtual Metering as a Cost-effective Production Monitoring Solution 
Featured technologies:  METTE™

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.

In this lecture, you will learn how to:

  1. Interpret available measured data for production allocation 
  2. Validate flow models with reference data
  3. Combine with reservoir models for forecasting
  4. Optimize production
register_blue-(11).png
Thursday, July 23
11:30 AM CT

Presented by:
Kim McLean

Get More from Your Image Logs : Borehole Image Processing and Interpretation 
Featured technologies:  Geolog™

Borehole image logs provide very high resolution images of the borehole. We often use this data to interpret structural dip of bedding, fractures, breakouts, etc. Beyond looking at the structural geology, borehole image data can also give us a better understanding of rock texture that can lead to deeper insight of the depositional environment of the reservoir.

In this session, we will look at:

  1. The borehole image processing workflow
  2. Image upscaling for statistical and facies analysis
  3. Textural analysis using 2DSOM and MRGC
register_blue-(12).png
Tuesday, July 28
11:30 AM CT

Presented by:
Dennis Ellison

Well-to-Seismic Calibration: How to Get the Most from your Seismic Data
Featured technologies:  SeisEarth™ 
 
Well-to-seismic calibration is a critical step for appropriately mapping logs, markers, and the well trajectory to seismic data. It’s a means of understanding the seismic waveform relation to the subsurface geology and selecting meaningful seismic events to pick horizons.

A synthetic seismic trace (synthetic seismogram) is calculated from elastic property logs (velocity, density and time-depth) and a wavelet, then converted from depth to time. The synthetic seismogram is correlated and compared with seismic traces to determine a goodness-of-fit at the well location. You then calibrate (stretch & squeeze) the synthetic seismogram to improve the match with the seismic data.

In this lecture, you will learn how to:

  1. Avoid common pitfalls
  2. Incorporate a more rigorous approach to well-ties
  3. Improve results from workflows that rely on integrating well and seismic data
register_blue-(13).png
Thursday, July 30
11:30 AM CT

Presented by:
Bruno de Ribet

Well Bore Analysis, Geomodeling and Seismic Attributes for Enhanced Fracture Detection
Featured technologies:  Geolog™, SKUA-GOCAD™, Epos™

Maximizing hydrocarbon recovery in fractured reservoirs requires a deep understanding of the subsurface, fracture network connectivity, and the interaction between the matrix and fracture networks, whether fractures are naturally occurring or induced.This presentation addresses challenges, objectives, and responses from seismic, well and modeling by illustrating an effective cross-domain technology-based workflow for fractured reservoir imaging. Structural attributes paired with automatic fault extraction and RMO(z)-AVA(z) or diffraction energy detailed interpretation set the main framework, while wellbore fracture characterization sets the vertical resolution for the subsurface model to image the stimulated and natural fracture networks, support fracture and SRV analysis, and derive a realistic mechanical model.

In this lecture, you will learn how to:

  1. Define which seismic attributes are used to detect and characterize fractures
  2. Understand the geomechanical conditions (stress and strain) affecting oil and gas reservoirs
  3. Evaluate the impact of fractures for optimizing well placement and production
register_blue-(14).png


Biographies

Bruno2_sm_crop-(1).jpgDr. Bruno de Ribet is Technical Global Director, Strategic Projects, at Emerson E&P Software. Dr. de Ribet advises on developing interpretation and reservoir characterization workflows that increase efficiency and take full advantage of the Emerson E&P Software suite of geophysical and geological innovations. Dr. de Ribet holds a Ph.D. in Geophysics from the Institute du Physique du Globe, Paris University. He has over 25 years of experience in the upstream oil and gas industry.

Elive_Menyoli_sm-jpgDr. Elive Menyoli has over 15 years of experience in the oil and gas industry. Prior to joining Emerson, he worked at Marathon Oil and Total E&P USA, in deep water projects. Dr. Menyoli holds a MSc degree in Physics from the University of Goettingen, Germany and a PhD in Geophysics from the University of Hamburg, Germany.  He has authored numerous publications in seismic imaging and interpretation, with a recent emphasis on shale resource plays.

Andrey_Limushin_sm.jpgAndrey Klimushin has over 14 years of experience in subsurface modeling, business development and project execution. He spent eight years working in Moscow in geological modeling and subsurface studies for national (CGE, Gazprom-neft) and international companies (AGR petroleum, Roxar).




Zahary_Vera_sm-(1).jpgZahary Vera is a Technical Advisor at Emerson in North America.  She has been with Emerson for over 15 years, serving in a number of roles that provide support for emerson E&P seismic interpretation and reservoir characterization workflows.  Zahary holds a BS Degree in Geophysical Engineering from Simon Bolivar University, Venezuela.


Sasan-Ghanbari_crop_sm-(1).jpgSasan Ghanbari is currently principal geoscientist at Emerson. Sasan has extensive experience in offshore exploration and in the Canadian Oil Sands. He has also worked on various field studies and geostastical subsurface modeling in North America, South America, and the Middle East.  This work includes analyzing relevant data such as regional studies and uncertainty analysis to build realistic geological, geostatistical and reservoir simulation models. Sasan has been working with Emerson since 2004. He earned a degree in Petroleum Engineering from the University of Alberta and is a Professional Engineer.

Pat-Stirling-(1).jpgPat Stirling has over 18 years of experience in the oil and gas industry. He currently handles North American technical sales and support for Emerson's advanced Formation Evaluation solution; Geolog. Before joining Emerson in 2013, he worked at Schlumberger in Formation Evaluation acquisition, processing, interpretation and sales. Pat holds a BSc in Geology from the University of Saskatchewan, Canada.


Dennis-Ellison_sm-(1).jpgDennis Ellison works as Technical Advisor – Geophysics for Emerson EPS North America, where he helps oil operators reduce costs and leverage their data with next-generation technology. His career started in depth imaging of geologically complex land data and transitioned into reservoir characterization and Quantitative Interpretation, focusing on unconventional reservoir property prediction. Dennis holds a Master’s degree in Geology and Geophysics from the University of Calgary in Canada. He is a member of CSEG, SEG, SPE, EAGE, and APEGA.


Kim-McLean1_sm_crop.jpgKim McLean received her Bachelors of Science degree from the University of New Orleans before continuing to Central Washington University, where she studied the structural geology of the Tien Shan in Kyrgystan for her Master’s thesis. After receiving her MSc, Kim entered the energy industry, and now has over 15 years of experience. She worked at Halliburton and Paradigm before spending two years as the petrophysicist for the Pike Asset team with BP in Calgary.  At Emerson E&P Software, Kim applies her practical petrophysical experience to the work she does with the Geolog Formation Evaluation application.