MicroSeismic Webcasts

Upcoming Webcasts

Technology in the Permian Basin: Microseismic-based Reservoir Simulation

Presenter: Carl Neuhaus, VP Engineering

Date: March 21, 2017

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Summary: With a variety of fracture diagnostics technologies available, it is important to validate interpretations and recommendations independently. Understanding how the reservoir reacts to a particular combination of treatment parameters and optimizing the design based on those observations has been key.

In this month’s webcast, a lookback study is reviewed for a three-well pad in the Midland Basin using historic production data, well logs, PVT, and core data, as well as other available offset well data. Initial project goals included determining optimum vertical and lateral wellbore spacing as well as evaluating the completion design in terms of cluster spacing and stage length for wells landed in the Middle Spraberry, the Lower Spraberry, and the Wolfcamp A shales.

Previous Webcasts

Market Trends Shaping The Oil & Gas Industry

Presenter: Carl Neuhaus, VP Engineering

Date: March 21, 2017

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Summary: In this month’s webcast, we will provide a concise overview and highlights of the E&P business economics to date, the driving factors that we’ve seen over the last two years, capital expenditures, a brief overview of the M&A market, and what bankruptcies have meant for the industry. We will also take a look at international shale, in particular, Argentina, and long- term forecasts by the EIA. Finally, we will discuss MicroSeismic’s reaction and response.

Assess Your Stress – Get Mohr From Your Microseismic

Presenter: Orlando Teran, PhD, Structural Geologist

Date: January 17, 2017

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Summary: Focal mechanisms, when computed for an entire microseismic catalogue, permit a rapid assessment of the stress conditions throughout the entire stimulated reservoir. In this talk we will present a new geomechanical workflow using focal mechanisms to accurately and unambiguously estimate SHmax. We will demonstrate the importance of SHmax in achieving more precise frac design modeling results, as well as how the microseismic data permits us to evaluate the stratigraphic variations in SHmax. Additionally, by simply using the microseismic fracture orientations and this new workflow, we will show how we can identify fracture populations likely to control fluid flow, those that required different stimulation pressures in order to contribute to flow, and the mechanical conditions that favored out-of-zone growth and reactivation of geohazards. We will further show how by integrating stimulation data, such as net wellbore pressure measurements, and geophysical logs, can better constrain our geomechanical model as well as understand the adaptive controls affecting the overall stimulated rock volume.

Designing More Efficient and Effective Treatment Plans Using Full Moment Tensor Analysis of Microseismic Data

Presenter: Sudhendu Kashikar, VP Completions Evaluation

Date: September 20, 2016

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Summary: Moment tensors are valuable tools for interpreting microseismic data from hydraulic fracturing as they describe the dynamic geomechanical response of the earth to the hydraulic treatment. The moment tensors and the focal mechanisms derived from them are becoming increasingly more sought after as a means to help integrate microseismic data with fracture modeling, reservoir engineering, and completions optimization.

Automatic calculation of moment tensors offers a distinct advantage in that it enables fast and efficient evaluation of numerous microseismic events and their possible source mechanisms with little need for analyst intervention. This facilitates a more detailed and accurate picture of stress and resultant fracture network both spatially and temporally. Such detailed moment tensor analysis makes it possible for the completion engineer to plug microseismic data into their fracture modeling in a more deterministic way so they can customize specific details of the treatment schedules and parameters. The most direct application of this type of analysis is identifying the net pressure required for activating various natural fractures and induced fractures in the rock. Being able to determine temporal changes in the stress fields offers a look into how the treatment is changing the stress field and provides a pathway to modify and alter the treatment to generate the desired near wellbore complexity and more effective fracturing.

PSET® Downhole: The Power of Imaging Downhole Microseismic Data

Presenter: Geraldine Haas, Senior Geophysicist & Downhole Team Lead

Date: May 17, 2016

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Summary: Microseismic, Inc. (MSI) has developed and is currently using advanced tools to enable downhole data processing and imaging. Using the proprietary and widely-used PSET® algorithm (also used in surface processing) and moving away from p&s picking, MSI provides a more accurate and reliable downhole solution to operators. In this webcast we will cover the PSET Downhole workflow that includes receiver orientation, velocity model calibration, and microseismic event location computation, along with a brief case history.

Understanding the Reservoir Stress Field From Microseismic Focal Mechanisms

Presenter: Dr. Orlando Teran – Structural Geologist

Date: March 22, 2016

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Summary: MicroSeismic’s new AutoMTI tool calculates a discrete focal mechanism, the orientation of a fracture plane and the direction of movement, for every event, thus providing an adequate distribution of fracture plane orientations and slip vectors to perform statistically reliable stress field inversions. In this webcast, we will present our workflow on how we derive the fracture plane solutions, SHmax direction and magnitude, and how this can be used to understand the variations in the stress field throughout the reservoir during stimulation.

Rapid and Accurate Diagnosis of Well Performance Through Integrated Microseismic

Presenter: Sudhendu Kashikar, VP Completions Evaluation

Date: Feburary 8, 2016

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Summary: In this webcast, we will look at several case studies that demonstrate how microseismic data offers the opportunity to make early, well specific, in situ observations of the permeability through stimulation. These observations can then be turned into a more timely and robust well appraisal, significantly reducing the need for 6 to 12 months of production data before appraising the well and diagnosing performance issues.

Seeking Real Value From Microseismic Monitoring | Early Appraisal of Unconventional Well Performance Using Microseismic Data

Presenter: Peter M. Duncan, Ph.D. – Founder & CoChairman, MicroSeismic, Inc.

Date: January 19, 2016

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Summary: At every stage in the life of a well, estimates of what that well will recover and how much that might be worth are of primary importance. Before the well is drilled, the subsurface team uses the best G&G data available to forecast the value of the well and justify it being drilled. As the well is being drilled we anxiously watch the logs and cuttings to get hints on whether our predictions will bear out. After completion, we watch the IP as the well unloads hoping to see numbers that validate the prediction. In reality, all these are weak and highly uncertain indicators. We have to wait for 6 to 12 months of production history to really know how the well is going to perform over its life. In the meantime, we continue to drill more wells in an area that perhaps should be downgraded, we continue to complete wells with perhaps a less than optimal design and we continue to space wells based on a drainage model that may not be correct.

Microseismic data, that is the location of the microseismic events generated as the stimulation proceeds, have been used by the completion engineers to “watch” what is happening at the reservoir and confirm that the completion is going as planned. Various methods of mapping the extent of the microseismic cloud have been used to estimate the volume of stimulated rock (SRV) as a predictor of how the well will perform. Unfortunately SRV or the propped fraction of it alone are not reliable predictors of production since the amount of permeability enhancement within the SRV and its distribution are key to effective drainage of the hydrocarbons present.

Recent work has shown that microseismic data can also provide an insitu, real-time estimate of the permeability enhancement resulting from the treatment and its distribution over the SRV. This allows for an improved appraisal of the well within days of it being completed, without waiting months for production data. The workflow has been validated with long-term history matching to production.

The workflow and its output are the subject of this webcast.

Using Depletion-Zone Microseismicity to Understand Producing Volumes | Part 2

Presenter: Jon McKenna, Completions Evaluation Team Leader

Date: November 17, 2015

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Summary: In Part 2, the methodology for separating microseismic events into different populations is further defined. This yields insight into an observed proppant distribution associated with offset producing wells, an observed fluid and proppant-laden gel distribution on stimulated wells, and depleted zones associated with offset producing wells.

In addition, the proppant-filled discrete fracture network model is validated by demonstrating that the modeled proppant distributions are very similar to the observed proppant-distributions on both the offset producing wells and the stimulated wells.

Using Depletion-Zone Microseismicity to Understand Producing Volumes | Part 1

Presenter: Jon McKenna, Completions Evaluation Team Leader

Date: October 20, 2015

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Summary: Microseismicity is typically used to describe the region around the wellbore directly affected by the hydraulic stimulation. However, when wellbores are treated near offset producing wells, microseismicity can illuminate areas that have already been stimulated and can reveal important details about how the offset wells were treated, where production has occurred, and where hydrocarbons may have been left behind.

In this webcast, we will explain how to use microseismicity occurring on offset producing wells to understand and describe the region around the wellbore that was propped and where production has occurred. Using this information to test calibrated proppant filled fracture models, along with fracture velocities, helps evaluate the enhanced permeability around the wellbore from stimulation.

Geomechanics of Refracturing – Part 2: An Engineering Approach to Refracturing

Presenter: Alireza Agharazi, Petroleum Engineer

Date: August 18, 2015

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Summary: As discussed in Part 1 of this webcast series, microseismic observations and geomechanical analysis of refracturing indicate that diverters are not effective in regulating the flow along lateral during the treatment.

Ineffective diverters and the pressure drop along the lateral, results in localized stimulation of reservoir at the heel area, leaving a major part of the well un-stimulated.

In part 2, we introduce an alternative method to address ineffective diverters and to improve the effectiveness of refracturing. This methodology is based on the stimulation of naturally fractured reservoirs by a pore pressure-driven mechanism. Proper handling of injection pressure and flow rates is a key factor in this methodology. Numerical simulations indicate the effectiveness of the method in creating a uniformly stimulated rock volume along the lateral.

Geomechanics of Refracturing | Part 1: Diverters Effectiveness

Presenter: Alireza Agharazi, Petroleum Engineer

Date: July 21, 2015

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Summary: Operators are always searching for the best way to target as much of the productive zone as possible, while expending the least amount of resources.

This webcast covers MicroSeismic Inc.’s industry-leading methods for using rapid reservoir simulation, production history matching, and production forecasting to accurately forecast future production and plan optimal wellbore spacing for future developments. Learn to avoid wasting resources on areas of low return or sub-optimal field developments. Also, hear how an independent operator is successfully using these techniques to accurately forecast future production and optimize wellbore spacing for developments in the Eagle Ford shale.

Improving Production Forecasting for Shale reservoirs

Presenter: Sudhendu Kashikar, VP Completions Evaluation

Date: June 16, 2015

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Summary: An independent operator in the Eagle Ford was looking at ways to rapidly and accurately forecast future production and determine optimal wellbore spacing. Microseismic Inc developed a unique methodology to quantify permeability enhancement resulting from hydraulic fracturing to enable rapid reservoir simulation, production history matching and production forecasting. This case study will highlight the how workflow and results enabled the operator to understand future production and determine optimal wellbore spacing for future development.

AlertArray™: Cost Effective Seismicity Monitoring to Mitigate Risk

Presenter: Ganesh Murdeshwar | Vice President, MicroSeismic Canada

Date: May 21, 2015

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Summary: In this month’s webcast, we will discuss how the new AlertArray system works and how it is used to mitigate risk for monitoring seismicity during hydraulic fracturing and fluid injection operations.

Geohazard Avoidance: Optimizing Completions in Real-time

Presenter: Karl Harris, Petroleum Engineer

Date: April 21, 2015

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Summary: An independent operator in the Eagle Ford believed there was a possibility that faults existed in the region and hired MicroSeismic, Inc. to help monitor during their hydraulic fracturing program. This case study will highlight how real-time microseismic analysis provided geohazard detectability, which helped the operator reduce completions costs and optimize production.

Refrac’ing: How microseismic can help improve results

Presenter: Sudhendu Kashikar - VP Completions Evaluation, MicroSeismic, Inc.

Date: March 17, 2015

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Summary: In this webcast, Mr. Kashikar will discuss how microseismic monitoring can help during refrac’ing in order to increase production from old wells at a significantly lower investment compared drilling a new well and to increase recovery from old wells – by stimulating and accessing new reservoir from new fractures created during refracing.

PSET® Downhole

Presenter: Dr. Peter Duncan | Founder & Co-Chairman, MicroSeismic, Inc

Date: February 17, 2015

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Summary: Dr. Peter Duncan will address the pros and cons of downhole P&S picking and downhole imaging, and how each method works. He will also highlight the benefits and differentiators of PSET® Downhole and how the downhole imaging technique was successfully used in the Permian.

MicroSeismic: When Every Penny Counts

Presenter: Dr. Peter Duncan | Founder & Co-Chairman, MicroSeismic, Inc

Date: January 20, 2015

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Summary: Founder Peter Duncan will present his views on how microseismic monitoring can help reduce costs in this environment of low commodity prices where every penny counts.

The Case for Seismicity Monitoring

Presenter: Ganesh Murdeshwar | Vice President , MicroSeismic Canada

Date: November 18, 2014

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Summary: The Business Case for Seismicity Monitoring - A Decision Framework


Introducing PermIndex™ – Reservoir Permeability Calculation

Presenter: Asal Rahimi Zeynal, Petroleum Engineer

Date: October 21, 2014

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Summary: A crucial piece of information a reservoir engineers always want to know about a reservoir is the permeability, because this controls how fast the gas and/or oil will flow to the well. This month’s webcast will highlight MicroSeismic’s most recent Completions Evaluation Service – PermIndex, which calculates seismicity-based reservoir permeability coupled with effective drainage volume determination in order to provide operators with a stage-by-stage indication of production potential given early estimates of each stage’s productivity. This information can then provide operators with information they need in order to improve production forecasting and estimated ultimate recovery (EUR).

FracRx™ – Stage-by-Stage Completions Optimization

Presenter: Jon McKenna, PhD - Completions Evaluation Team Lead

Date: September 16, 2014

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Summary: Find out what’s really happening when you frac your well with FracRx, MicroSeismic’s latest technology to help operators optimize production on every well in real-time. By evaluating and optimizing the performance and the treatment of each well, FracRx will help operators increase asset value, maximize well spacing, and improve ultimate recovery. Learn how it works and what it means for you by watching this month’s webcast!

Next Generation Real-time

Presenter: Mike Mueller, VP Technology & Development

Date: August 19, 2014

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Summary: MicroSeismic continues to push the boundaries of real-time passive seismic services. The industry leading real-time provider, MicroSeismic now offers this service with enhanced, advanced anisotropic velocity calibration to improve event locations, automated moment tensor inversions or source mechanism determination to provide real-time rock failure and stress state characterization and advanced event editing to allow only true positives into your microseismic pointset. These features mean you are able to use your microseismic results at the time of completion for advanced completions evaluation with confidence.

Completions Evaluation: Optimizing Completions & Recovery – A Case Study

Presenter: Kash Kashikar, VP Completions Evaluation

Date: July 22, 2014

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Summary: Don’t miss the opportunity to find out how to optimize your recovery and completions! Watch this month’s webcast to understand how MicroSeismic was able to help a client evaluate vertical extent, determine optimum wellbore spacing and stage spacing, calibrate earth models, compare completions options and much more!

Completions Evaluation in the Eagle Ford Shale – A Case Study

Presenter: Carl Neuhaus, Completions Evaluation Team Leader

Date: June 17, 2014

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Summary: Microseismic monitoring provides important information to characterize the reservoir and drive field development, wellbore completion, and treatment design strategies. This month’s webcast will discuss how MicroSeismic, Inc.’s Completions Evaluation Services played an essential role in determining sophisticated wellbore spacing in the Eagle Ford shale.

Comparison of Fracture Planes in the Utica and Marcellus Shales

Presenter: Mary Ellison, Geologiest III, MicroSeismic, Inc.

Date: May 20, 2014

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Summary: Operators seeking to produce oil, natural gas or condensates in the various shale plays need to understand their natural and induced fracture patterns in order to optimize production. “Comparison of Fracture Failure Planes in the Utica and Marcellus Shales” compiles data from our work in the Appalachian basin and provides insight into completion strategies. The webcast covers fracture orientations derived from focal mechanisms and the regional stress regime.

Microseismic Correlation to Production

Presenter: Asal Zeynal, Petroleum Engineer & Mike Mueller, VP Development

Date: April 22, 2014 at 10AM CDT

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Summary: The application of microseismic-based hydraulic fracture monitoring over the past decade of shale oil and gas development has reached the point where thousands of wells and tens of thousands of stages have been monitored. With this microseismic monitoring of a large number of wells, and sufficient time since initial production for many of the monitored wells, it is now possible to compare the microseismic results to multi-year production data across all of the active shale oil and gas trends. The correlations are based on using the stimulated rock volumes computed from microseismic pointsets and production data available from common reporting agencies. Overall these correlations are very promising with coefficients above 0.8 for all the prominent North American shale trends.

Downhole Monitoring with EventPick™

Presenter: Julia Kurpan, Sr. Geophysicist & Mike Mueller, VP Development, MicroSeismic, Inc.

Date: March 18, 2014 at 10AM CDT

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Summary: EventPick technology provides an independent evalution of well stimulation results in areas less suitable for surface-based microseismic acquisition. Final results determined using the proprietary EventPick processing technology provides operators with the fracture geometry and azimuth, discrete fracture network characterization, estimations of stimulated reservoir volume, and recommendations for completions optimization. An in depth look at EventPick will give insight on how operators can determine well spacing, improve fluid and proppant selection, alter pressure pumping schedules, avoid geohazards, and delineate reservoir boundaries.

Next Generation Discrete Fracture Network

Presenter: Jonathan McKenna, Completions Evaluation Team Lead, MicroSeismic, Inc.

Date: February 18, 2014 at 10AM CDT

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Summary: Effective propped fracture half-lengths during hydraulic fracturing are difficult to quantify, new modeling techniques must be developed to understand the spatial extent of proppant-filled fractures and improve estimates of proppant distribution within a formation. In this webcast, we will show you how the distribution of propped and unpropped fractures can be statistically analyzed to determine the Productive Stimulated Rock Volume (Productive-SRVTM) and constrain key field development parameters such as wellbore and stage spacing as well as vertical containment of proppant placement.

Hydrocarbon Production and Microseismic Monitoring – Treatment Optimization in the Marcellus Shale

Presenter: Carl Neuhaus, Completions Evaluation Team Lead, MicroSeismic, Inc.

Date:January 21, 2014 at 10AM CDT

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Summary: This month's webcast features an integrated analysis of hydraulic fracturing treatments in the Marcellus Shale. The analysis was conducted to investigate the relationship between reservoir geology, wellbore completion, stimulation design, and microseismic data. Carl Neuhaus will discuss how the findings were used to evaluate the correlation between hydrocarbon production and microseismic results and how the initial production related to engineering parameters and/or reservoir properties.

The Variable Nature of Shale Plays & How Monitoring Can Help

Presenter: Cherie Telker, Geologist & Mike Mueller, VP Technology Development - MicroSeismic, Inc.

Date: November 19, 2013 at 10AM CDT

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Summary: In comparison to conventional reservoirs, shale plays are highly variable in nature resulting in uncertainty around profitability. In this webcast, we discuss shale variability and show how using a near-surface BuriedArray™ for frac monitoring provides the necessary information for operators to optimize production. We discuss ideal well spacing, number of stages needed, production prediction and more. Monitoring every frac means turning the unconventional into the conventional.

The Illumination of Natural Fractures and Faults of the Muskwa Shale Play in Northeastern British Columbia

Presenter: Jane Ling, Geophysicist, MicroSeismic, Inc.

Date: October 22, 2013 at 10AM CDT

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Summary: In this month's webcast, we will present a case study presenting the natural fracture and faulting characteristics of the Muskwa Shale play in Northeastern British Columbia. The microseismic data for this study was recorded by a surface array during the hydraulic fracturing for 9 horizontal wells, 8 of them located within the Muskwa formation. Specific wells in this pad will be discussed illustrating different geologic characteristics, stimulated fracture geometry, and the performance of the completion including focal mechanism and b-values analysis.

PSET 5.0: High Definition Surface Microseismic

Presenter: Mike Thornton, Ph.D. - Chief Technology Officer, MicroSeismic, Inc.

Date: September 17, 2013 at 10AM CDT

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Summary:
Microseismic’s CTO, Mike Thornton, discusses the latest release of PSET 5.0. The latest release allows for high definition z-resolution across the wellbore and controlled amplitude processing to allow for improved magnitudes and well to well, basin to basin comparisons.

Tune in to learn what’s new and how it can help your company increase production and reduce costs.

Advanced Microseismic Analysis for Enhanced Reservoir Characterization

Presenter: Peter M. Duncan, Ph.D. - Founder and CEO, MicroSeismic, Inc.

Date: August 20, 2013 at 10AM CDT

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Summary:
The analysis of microseismic monitoring data can make a contribution to reservoir management that extends well beyond the design of the best completion procedures.

Sound intriguing? Tune in as Peter Duncan, Ph.D. shares new insights on how an old technology is being re-engineered to provide insights on structure, stress and reservoir dynamics.

Using Microseismicity to Understand Subsurface Fracture Systems and Increase the Effectiveness of Completions: Eagle Ford Shale, TX

Presenter: John Detring, Geophysicist, MicroSeismic, Inc.

Date: July 23, 2013 at 10AM CDT

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Summary:
This month's webcast focuses on utilizing microseismicity to ascertain an understanding of the subsurface fracture networks and how this information can increase the effectiveness of completions. This presentation is a case study from within the Eagle Ford formation.

 

Productive-SRV: Proppant Placement and Production Estimation from Microseismic Data

Presenter: Carl Neuhaus, Petroleum Engineer at MicroSeismic, Inc..

Date: June 17, 2013 at 10AM CDT

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Summary:
This month’s webcast focuses on how using microseismic data allows users to build an event magnitude calibrated DFN, taking into account the seismic energy of the events, rock properties, and the pumped treatment. Evaluating proppant placement in the calibrated DFN allows you to discern between the part of the SRV that contributes to production in the long term, and the part of the reservoir that was affected by the treatment but may not be hydraulically connected over a longer period of time. Then obtaining reservoir characteristics from microseismic data gives you an idea of permeability that was created with the stimulation in order to evaluate drainage volume from where you are producing. From here you are able to estimate production, as well as refine field development in terms of wellbore spacing. Considering other treatment data, such as pressure and rate, we show how you can make additional recommendations on stage spacing and how to optimize your fluid system based on the signature of a proprietary treatment analysis plot.

 

Next Generation Downhole Microseismic Monitoring with EventPick Technology

Presenter: Indy Chakrabarti, VP of Strategic Development, MicroSeismic, Inc.

Date: May 21, 2013 at 10:00 AM CST

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Summary:
This short webinar is an introduction and overview of microseismic acquisition and processing techniques and considerations, with a special focus on the new EventPick first arrival picking technology. The session will review optimal scenarios for surface and downhole microseismic solutions in hydraulic fracture mapping, reservoir monitoring and seismicity detection scenarios. In addition, a brief description of the differing microseismic results and uses from each of these techniques will be discussed, including source mechanism characterization and discrete fracture network generation.

 

Coupled Fluid Flow and Geomechanical Modeling of Unconventional Hydraulic Stimulation: Processing Affecting Recovery

Presenter: Mark McClure, Assistant Professor of Petroleum & Geosystems Engineering at University of Texas at Austin

Date: April 23, 2013 at 10:00 AM CST

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Summary:
During hydraulic stimulation in unconventional oil and gas, newly forming and preexisting fractures interact to generate complex fracture networks. We developed a computational model, CFRAC, that couples fluid flow and the stresses induced by fracture deformation in large, complex discrete fracture networks. Modeling these processes with discrete fracture networks is useful because the stresses induced by fracture propagation and deformation are specially heterogeneous and depend on the relative locations and orientations of neighboring fractures. The model also has the capability to describe friction evolution on fractures, allowing it to directly describe the processes giving rise to microseismicity. In this talk, applications to practical problems will be given. Different mechanisms that encourage or inhibit development of productive fracture networks will be summarized. The relationship between microseismicity and deformation will also be discussed.

 

Uncertainties in Surface and Downhole Microseismic

Presenter: Michael Thornton, CTO MicroSeismic, Inc.

Date: March 26, 2013 at 10AM CST CST

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Summary:
This month's webcast focuses on the presumption that the two competing microseismic imaging techniques in use today appear at first to be very dissimilar. Downhole microseismic locations are determined from P & S wave travel-time matching, much like traditional earthquake seismology, while surface microseismic imaging is more like pre-stack depth migration of reflection seismic. However, if one considers both techniques as maximum likelihood estimators (MLE), it is possible to show that the two are in fact quite similar. Moreover, the MLE framework provides a basis to compare the two methods in terms of the uncertainties in location estimates and sensitivity to velocity uncertainty.

 

Improving Event Location Accuracy with Anisotropic Velocity Models

Presenter: Carl Neuhaus, Petroleum Engineer, MicroSeismic, Inc.

Date: February 19, 2013 at 10:00AM CST

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Summary:
This month’s webcast focuses on the application of an anisotropic velocity model in determining microseismic event locations from surface-acquired passive seismic data. The Thomsen parameters ε and δ were determined to accurately locate calibration shots to their known location. Hydraulic fracture events where then imaged and compared to their locations derived from processing incorporating an isotropic velocity model. When compared directly to calibration shot locations derived with an isotropic velocity model, we will show that the absolute average error in calibration shot positioning in all directions was improved by almost 30% and hypocenter events from the hydraulic fracturing treatment depicted a more dense and confined zone of microseismic activity.

 

Microseismic Monitoring: Methods and Interpretation

Presenter: Mike Mueller, VP Technology Development, MicroSeismic, Inc.

Date: January 22, 2013 at 10 AM CST

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Summary:
The optimal horizontal wellbore orientation is generally orthogonal to the direction of hydraulic fracture propagation. There is a very little publically available data concerning the direction of maximum horizontal stress and natural fracture orientations in the Eagle Ford. In this webinar, the speaker will discuss how source mechanism analysis from surface-based microseismic results shows that the azimuth of hydraulic fractures in the Eagle Ford varies, depending on location. The optimal wellbore orientations varies as well. A range of wellbore orientation in the Eagle Ford Play is estimated using microseismic source mechanism analysis.

Integrated Microseismic Monitoring for Field Optimization in the Marcellus Shale

Presenter: Carl Neuhaus, Petroleum Engineer, MicroSeismic, Inc.

Date: October 23, 2012 at 10 AM CST

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Summary:
This webcast focuses on an integrative analysis of hydraulic fracture treatments conducted in the Marcellus Shale. The presentation determines how various factors related to the specific reservoir geology in the Marcellus and to what extent the variability of hydraulic fracture treatments impacted the microseismic results. It analyzes stress changes in the reservoir indicated by focal mechanisms to help explain the asymmetry of the microseismicity about the wellbore. Finally, the initial production results are compared to reservoir and engineering parameters to determine if the variability in the microseismic results is due to engineering differences or to spatially-varying reservoir properties.

Understanding Microseismic Positional Uncertainty

Presenter: Mike Mueller, VP Technology Development

Date: September 25, 2012 at 10AM CDT

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Summary:
Microseismic event location or position resolution and uncertainty remains one of the most critical aspects of passive seismic for the user community. Understanding the inherent capabilities, limitations and drivers for event locations from downhole, surface and near-surface microseismic acquisition geometries is required to have confidence with ‘beyond the dots’ microseismic applications such as hydrofracture length, height and stimulated rock volume calculations. In this webinar, these capabilities, limitations and drivers are reviewed for both the downhole and the surface acquisition methods.

Geological Interpretations of Microseismic Events to Better Constrain Fracture Models

Presenter: Jon McKenna, Geophysicist, MicroSeismic, Inc.

Date: August 21, 2012 at 10AM CDT

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Summary:
In addition to locating microseismic events, MicroSeismic, Inc.’s surface and shallow buried array passive seismic technology is used to define the geometry and orientations of the fracture networks that are stimulated or induced by hydro-frac treatments. Additional rock mechanics parameters can be combined with additional information contained in the microseismic data to better understand in-situ subsurface stress and failure conditions.

In this webinar, the speaker will discuss focal mechanisms, stress inversion techniques, discrete fracture models constrained by microseismic events, and stimulated rock volume calculations. Additional analysis to be discussed include fractal geometries of event clusters, and event energy analyses can be used to optimize the stimulation treatment.

Understanding the Impact of Natural Fracture Reactivation and Implications for Well Drainage

Presenter: Dr. Sherilyn Williams-Stroud, Chief Geologist, MicroSeismic, Inc.

Date: July 24, 2012 10:00am CDT

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Summary:
Microseismic data obtained from surface or shallow buried array contains a wealth of information that allows interpretation of rock failure mechanisms, fracture plane orientations, and reservoir stress. Analyses of this information in microseismicity from the Marcellus Shale stimulations show reactivation of the regionally persistent joint sets that allows identification of how the reservoir stress state changes during the treatment.

Using b-Value Analysis to Avoid Faults During Fracture Jobs Using Microseismic Monitoring

Presenter: Michael Kratz, Geophysicist, MicroSeismic, Inc.

Date: June 19, 2012, 10:00 am CDT

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Summary:
In order to gain more insights from microseismic monitoring, organizations are using b-value analysis, a method to estimate stress in the subsurface, to avoid geohazards such as faults in their reservoirs.

Register now to receive a link to this pre-recorded webcast available on microseismic.com on June 19th. MicroSeismic, Inc. geophysicist Michael Kratz will present a Barnett Shale case study, expanding on his EAGE/SPE Unconventional Resources Vienna conference talk.

Advanced Microseismic Analysis for Enhanced Reservoir Characterization

Presenter: Peter M. Duncan Ph.D., Founder and Executive Chairman of MicroSeismic, Inc.

Date: May 11, 2012, 10:00 am CDT

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Summary:
The analysis of microseismic monitoring data can make a contribution to reservoir management that extends well beyond the design of the best completion procedures.

Sound intriguing? Tune in as Peter Duncan, Ph.D. shares new insights on how an old technology is being re-engineered to provide insights on structure, stress and reservoir dynamics.

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