URTeC 2017

Where is my production coming from??

ESG will be exhibiting and presenting at the 2017 Unconventional Resources Technology Conference (URTeC) in Austin, Texas from July 24-26, 2017.  Stop by Booth #619 to hear from a number of experts on how integrated microsiesmic, engineering and geomechanics solutions can improve well economics for operators by answering the question "where is my production coming from?"

Presentation Schedule (Booth #619)

Monday July 24, 2017

Exhibition 10:00am - 7:00pm

10:15  Geomechanical Modeling for Fracture Prediction and Optimization 
Uno Mutlu, Rockfield Global Technologies
10:45Characterizing Fracture Connectivity - Where is my Production Coming From?
Ted Urbancic, ESG Solutions
3:10Effective Constraint of RTA Models Using Microseismicity 
David Anderson, Anderson Thompson Reservoir Strategies
3:40Assessing Stress and Deformation with Microseismic Geomechanics
Doug Angus, ESG Solutions
5:15Understanding Effective Fracture Lengths - Differentiating Between Wet and Dry Fractures 
Adam Baig, ESG Solutions
5:45Estimating Producing SRV from Surface Microseismicity – Where is my Proppant?
Brad Birkelo, Spectraseis Inc.

Tuesday July 25, 2017

Exhibition 9:00am - 6:00pm

10:15  Effective Constraint of RTA Models Using Microseismicity 
David Anderson, Anderson Thompson Reservoir Strategies
10:45Estimating Producing SRV from Surface Microseismicity – Where is my Proppant?
Brad Birkelo, Spectraseis Inc.
3:10Geomechanical Modeling for Fracture Prediction and Optimization 
Uno Mutlu, Rockfield Global Technologies
3:40Understanding Effective Fracture Lengths - Differentiating Between Wet and Dry Fractures 
Adam Baig, ESG Solutions
5:15Characterizing Fracture Connectivity - Where is my Production Coming From?
Ted Urbancic, ESG Solutions
5:45Assessing Stress and Deformation with Microseismic Geomechanics
Doug Angus, ESG Solutions

Wednesday July 26, 2017

Exhibition 9:00am - 1:00pm

10:15  Estimating Producing SRV from Surface Microseismicity – Where is my Proppant?
Brad Birkelo, Spectraseis Inc.
10:45Understanding Effective Fracture Lengths - Differentiating Between Wet and Dry Fractures 
Adam Baig, ESG Solutions
11:40Oral Paper: Ballroom E
Effective Constraint of RTA Models Utilizing Microseismicity Derived Flow Attributes
1:50Oral Paper: Room 16AB
Characterizing Reservoir Behavior With Cluster-based Microseismic Analysis

Presentation Abstracts

Effective Constraint of RTA Models Using Microseismicity 

Common approaches to constraining RTA models using microseismic event locations have historically been unsuccessful.  Using a new approach incorporating the collective statistical behavior of seismicity along with production data, a workflow has been developed which reduces the uncertainty of possible reservoir descriptions for model-based production forecasting and improves the understanding of non-uniform fracture lengths along horizontal wells.  A case study for a multi-well program in the Duvernay formation is presented which provides improved descriptions of stimulated reservoir volume (SRV) which corroborates observed well performance behavior, namely well interference effects and relative performance differences between wells.

Geomechanical Modeling for Fracture Prediction and Optimization

Recent advances in computational geomechanics and rock constitutive models offer predictive models for complex natural and induced fracture network modeling. This talk will build on Rockfield’s core geomechanical technology areas and cover several modeling applications with implications to fracture initiation and propagation. These applications -and processes they represent- include natural fracture evolution, near wellbore and reservoir scale hydraulic fracture propagation, natural-hydraulic fracture interaction(s), fracture height growth in thinly laminated rocks, hydraulic fracturing between tightly spaced horizontals and the link between geomechanics-microseismic interpretation for cross validation. Advanced geomechanical models provide insight into these key processes/applications and can help optimize stimulation in the field.

Estimating Producing SRV from Surface Microseismicity – Where is my Proppant?

The size of effective stimulated reservoir volume (eSRV) is considered a critical factor in assessing the effectiveness of a fracture treatment, however attempts to quantify SRV using microseismicity has historically over-estimated this volume.  Here we present a case study using surface microseismic data for hydraulic fracture stimulation of two wells in the Eagle Ford.  Using event locations and origin times of microseismic events along with pumping data, events were classified into “fracture wing” and “proppant placement” events, where the subset of proppant placement events is considered an indirect indicator of where proppant banks have been placed in the formation and can be used to estimate the minimum extent of eSRV.  Microseismic-derived estimates of eSRV show approximately 30% difference between the two wells, which is consistent with initial production rates observed for the two wells.

Assessing Stress and Deformation with Microseismic Geomechanics

Here we present a new workflow integrating geomechanical modeling with passive seismic source mechanisms as well as fracture models, in order to assess reservoir deformation and stress changes. The approach is based on semi-analytical formulations that allow fast and approximate evaluation of the geomechanical response enabling a near real-time tool. A case study is presented using data from a multi-well and multi-stage hydraulic fracturing treatment in the Marcellus formation. We compare geomechanical model results with ESG Solutions enhanced microseismic attributes that demonstrates correlation between geomechanical and seismic response.

Understanding Effective Fracture Lengths - Differentiating Between Wet and Dry Fractures 

Microseismic monitoring is increasingly used to describe the extent of hydraulic fracture stimulations, namely measuring fracture geometries (half lengths, heights etc.) to inform optimal well spacing.  However, traditional analysis of microseismicity based on event locations alone treats all events as equal with respect to production potential, which we have come to understand is an over-simplification of the dynamic reservoir processes occurring during stimulation.  Using a new statistical approach to microseismic analysis, it is possible to further define seismicity as fluid induced (i.e. wet fractures) and stress-induced (i.e. dry fractures) which has implications for improved estimates of producing volume.  

Characterizing Fracture Connectivity - Where is my Production Coming From?

Analysis of microseismic data for hydraulic fracture stimulations contains a wealth of information besides typical event locations and magnitudes.  Using advanced methods such as seismic moment tensor inversion (SMTI) or focal mechanism solutions (FMS) it is possible to reconstruct a discrete fracture network (DFN) providing insight on fracture orientations, failure mechanisms and rupture characteristics.  Using new approaches to describe network complexity and connectivity, volumetric network complexity can be developed to identify zones of enhanced production.  Interestingly, the derived DFN and its growth characteristics appear to be related to the ability to stimulate bedding-parallel fractures.  We examine a case study from a North American shale play focusing on containment and production from the perspective of generated fracture connectivity in order to answer the question, where is my production coming from?

 

Presenter Biographies

Ted Urbancic, CTO ESG Solutions

Dr. Ted Urbancic, a founder and current Chief Technology Officer at ESG Solutions, has over 30 years of experience examining and interpreting seismicity associated with mining and petroleum applications. He is a pioneer in the development of passive seismic monitoring in industrial applications, authoring over 150 publications ranging from understanding the fundamental aspects of seismicity to characterizing rock and reservoir behavior by integrating passive seismic data with numerical modeling, engineering and geomechanical data, and has received top 10 paper recognition on multiple occasions from the AAPG. Over the past 15 years, Ted has been integral in building ESG’s passive seismic hydraulic fracture monitoring capabilities and in promoting passive seismic tools for enhanced reservoir characterization. Currently, Ted oversees work by ESG’s Innovation and Technology Group, which spearheads all R&D related to passive seismic analysis, integration of new technologies, enhancement of geomechanical and reservoir/mine management systems in the mining and oil & gas sectors.  Ted holds a Ph.D. in Seismology from Queen’s University, Kingston Canada and currently also holds an Adjunct Professorship in the Department of Geological Sciences. He is a member of numerous professional societies, including AAPG, AGU, CSEG, EAGE,  SEG, SPE, SSA, and on the organizing committees for the 2014, 2016, and 2018 EAGE Passive Seismic Workshops. 

Brad Birkelo, EVP Spectraseis Inc.

Brad Birkelo is currently the Executive Vice President of Surface and Seismicity Monitoring for Spectraseis Inc.  Brad joined Spectraseis in 2009 and was a key technical leader in the company's transition from low frequency passive seismic monitoring for exploration, to surface-based microseismic monitoring for hydraulic fracturing and seismicity monitoring.  Upon the acquisition of Spectraseis Inc. by ESG Solutions in 2015, Brad has spearheaded much of the integration initiatives of the two companies and has led the company's growth in seismicity monitoring for waste-water injection and HFM.  Brad earned his M.Sc. in Geophysics from the University of Kansas and is a member of the SEG.

 

 

David Anderson, Director Anderson Thompson Reservoir Strategies

David Anderson (B.Sc., P.Eng.) is the Director of Anderson Thompson Reservoir Strategies, a business unit of NCS Multistage. David was previously a managing partner at Fekete Associates, and was one of the original designers of Fekete’s Rate Transient Analysis software, which is now an industry standard for well performance analysis. David has 20 years industry experience, and is a recognized expert in the area of well performance analysis. He has authored numerous papers on the subject, and has won several awards from various industry societies. David is also an SPE Distinguished Lecturer (2014-2015).

 

 

Uno Mutlu, COO Rockfield Global Technologies

Uno Mutlu is Chief Operating Officer for Rockfield Americas, overseeing operations in US, Canada and Latin America regions. Prior to this position, Uno managed geomechanics R&D teams in Weatherford with implications to conventional, unconventional and computational geomechanics.  Before he joined to Weatherford, Uno Mutlu worked as a Research Specialist within Structural Dynamics & Geomechanics group at ExxonMobil Upstream Research. Upon completion of his academic studies, Uno held a research scientist position at Stanford University Structural Geology and Geomechanics group.  Uno has over 40 publications related to geomechanics and several patent applications in natural fracture/damage prediction, wellbore stability/strengthening, rock strength characterization, alternative fracturing techniques, stress inversion from image logs, hydraulic fracture optimization, diverting agent design and stress anisotropy. 

Uno obtained his BSc degree in Civil Engineering from Middle East Technical University (METU), MSc in Construction Eng. & Management (with a focus on Geotechnical Engineering) and PhD in Civil Engineering (specializing in Geomechanics/Fracture Mechanics) both from Purdue University. During his stay at Purdue, he also held a position at the Department of Mathematics as an instructor.

Adam Baig, Manager Advanced Analytics ESG Solutions

Dr Adam Baig is a seismologist with ESG, managing research and development for their Innovation and Technology Group.  In that role, he has lead efforts to understand the dynamics of hydraulic fracturing, other injection processes, and mining-induced microseismicity through the seismicity associate with these treatments: from moment tensor inversion of signals to reveal underlying fracture sets and the dynamic stress/strain conditions in situ; addressing questions on how to best instrument the areas around these treatments to obtain unbiased interpretations of event source parameters; to numerous other techniques driven towards using microseismicity to understand the state of stress and the fracture state in the rock.  Adam obtained his B. Sc. and M. Sc. in Geophysics at the University of Alberta in 1997 and 1999 respectively, and went on to pursue his Ph. D. in Geosciences at Princeton, studying diffraction and scattering effects on seismic wave propagation, and graduating from there in 2003.  After completing post-docs at UBC in Vancouver, Canada and Université Joseph Fourier in Grenoble, France, studying various aspects of crustal seismology, he began working at ESG in 2008.  Adam is a member of a number professional societies, including the EAGE, SEG, SPE, SSA, and AGU.

Doug Angus, Advisor Geomechanics ESG Solutions

Dr. Doug Angus is currently the Advisor, ITG Geomechanics at ESG, and has over 10 years of experience developing and applying new technology in the field of seismic geo-mechanics to address reservoir production and injection challenges, specifically to improve reservoir characterization and monitoring. He has pioneered practical approaches to integrate microseismicity, time-lapse seismology, rock physics, surface deformation, and coupled fluid-flow and geo-mechanical modelling. He has published up to 50 journal papers and up to 40 conference abstracts on a diverse range of problems, spanning theoretical, exploration and engineering seismology as well as hydrocarbon, carbon storage and engineering scale problems. He has been heavily involved in R&D efforts that are heavily multi-disciplinary, involving the integration of seismology, rock and petro physics, hydro-mechanics and geodesy. He was previously Associate Professor of Seismic Geomechanics at the University of Leeds, UK.

 

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