Integrated Sensor Diagnostics (ISD)

Well and fracture spacing are two subsurface challenges that have the largest impact on net present value in large-scale field development of unconventional wells. Pinnacle's integrated sensor diagnostics service overcomes these challenges and more using customized sensors and engineering strategies. Our service delivers subsurface insight to help you make financially important decisions relating to well spacing, fracture spacing and stimulation design, based on characteristics of the reservoir and your needs.

Purpose-driven sensor acquisition drives engineering value to drastically reduce the learning curve surrounding pad and asset optimization. The far-field monitoring sensors that comprise the integrated sensor diagnostics suite include FracTrac ® downhole microseismic, surface microseismic imaging and FracNetSM microdeformation monitoring, while the near-wellbore sensors consist of FiberWatch ® distributed optical sensing and pressure gauges.

Pinnacle's unique approach combines subsurface insight from far-field and near-wellbore sensors collected throughout the life of a pad, from completion to stimulation to production. This knowledge is then integrated with proven fracture and reservoir engineering techniques to address the challenges.

Understanding the Asset

Unconventional resources present complex challenges that require comprehensive solutions and experience. In order to optimize asset delivery, proper tools must be used, including those that provide subsurface insight and aid in the knowledge of fracture development and reservoir characterization. Our industry-leading integrated sensor diagnostics service provides recommendations to improve well performance and develop overall asset deliverability. The goal is to discover the unknowns of the unconventional reservoir and make qualitative improvements for field development. As an industry leader in this space, our service provides well, pad and full field development using proven value-added tools and diagnostic approaches.

Solution: Pinnacle's integrated sensor diagnostics service encompasses monitoring the entire well lifecycle.

Real-Time Stimulation Monitoring

Real-Time Stimulation Monitoring

Monitoring and evaluating the effectiveness of a stimulation is particularly important to understanding and interpreting downhole conditions and pinpointing which controllable characteristics may be impacting well productivity the most. Fiber-optic technologies determine fluid distribution and cluster efficiency near the wellbore, as well as define fluid movement in real time. ControlFrac℠ service allows for real-time fluid diversion to improve cluster efficiency in real-time based on the fiber optic results. This data, combined with far-field fracture geometry derived from microseismic and microdeformation monitoring, can provide vital information regarding stimulated reservoir coverage and possible methods for the improvement of future stage and well design, both of which are critical to improving reservoir drainage and minimizing missed pay zone. This information is critical to the integrated sensor diagnostic service as it provides several of the sensor inputs needed for fracture and reservoir modeling techniques.

Calibrated Fracture Modeling

Calibrated Fracture Modeling

Fiber-optic monitoring is used to provide valuable particulars on perforation-cluster efficiency and fluid distribution per stage. These data, when combined with stimulated reservoir volume (SRV) and stimulated reservoir area (SRA) derived from microseismic and microdeformation monitoring, to better understand how fluid placement and volume affected the created far-field geometry of a particular stimulation. All the sensor information is only a portion of what our integrated sensor diagnostic service represents. The key benefit is tying this information into fracture modeling done by our experts to better characterize the fracturing process and its impact on the reservoir. The fracture model is the key step to understand proppant placement within the fractures.

Production Analysis

Production Analysis

A permanently installed fiber-optic system has the ability to monitor production at any time during the life of a well. Such data can be gathered at your discretion or it can be collected continuously on location with a dedicated interrogator, which is capable of monitoring several wells at once. All of this data can be visualized and interpreted using FiberView™ software. In tandem with fracture geometry measurements and far-field data from microseismic mapping, this information can be used for production profiling and to identify the impact fractures have along the wellbore on production.

Calibrated Reservoir Modeling

Calibrated Reservoir Modeling

Once all the data is collected for stimulation, fracture modeling and production phases, the last significant data gathering step in our process is to constrain the final reservoir model. In order to accurately and confidently constrain the reservoir model, the appropriate sensors and data analysis must happen as the precursor. This helps to close the loop on the integrated sensor diagnostic service with the end result being recommendations on well completion and pad design to improve overall asset deliverability.

Asset Optimization

Success in complex shale systems requires a precisely orchestrated effort that applies a unique set of techniques. No single approach defines the path to shale optimization.

Instead, success in each asset depends on understanding the shale and the nature of its hydrocarbon content to determine such fundamentals as where to drill, where to perforate and how to stimulate production.

Answers to these and a host of critical questions depend on variable shale characteristics. Challenges range from defining the reservoir volumetrically to predicting formation brittleness and ductility. Integrated sensor diagnostics provides a solution throughout the well lifecycle in order to understand well and pad performance. These learnings can then be applied to optimize field development.

Solution: Pinnacle offers stage-to-field optimization.

Stage-to-Well Optimization

Stage-to-Well Optimization

Through our comprehensive and advanced suite of diagnostic technologies, real-time monitoring of near-wellbore and far-field stimulation behavior can be directly applied to the optimization of subsequent stage completions. This can include modifying the perforation strategy, based on the observed cluster efficiency, or the fracture design, for greater fracture extension and reservoir coverage. The ability to optimize a completion from stage-to-well gives you incredible control over your assets, enabling you to experiment with various aspects of the completion and receive immediate feedback on the effects of these changes.

Well-to-Pad Optimization

Well-to-Pad Optimization

Not only can you improve and refine your completion designs between wells, but the same data, knowledge and experience, derived from the results of our diagnostic tools and services, can now be applied from well-to-pad. The analyzed data from a previously completed and monitored well can be invaluable toward the optimization of future area projects. Attributes, such as the number of perforation clusters, stage and cluster spacing, fracture design, and well spacing can be modified and adjusted based on the lessons learned from previous completions.

Pad-to-Field Optimization

Pad-to-Field Optimization

In addition to stage-to-well and well-to-pad completion design and strategy modification, improvement and refinement, pad-to-field optimization is also possible with our dynamic diagnostic technologies. Permanently installed fiber-optic tools can be used to monitor and assess actual production, over time, and this data correlated to a specific completion strategy and/or previous stimulation results, for the optimization of the next pad operation. Calibrated fracture and reservoir modeling, which utilizes this data as input, can determine the ideal lateral spacing for a given field development, maximizing acreage, capital and overall reserve recovery.

Our Experts

Doug Walser
Doug has extensive (35+ years) Permian Basin, Mid-continent, Appalachia, Rockies, and South Texas experience with Halliburton, Dowell Schlumberger, The Western Company of North America, and BJ Services.  He has specialized in the calibration of three-dimensional fracture modeling via a number of methods, including historical production transient analysis and calibration by fracture mapping measurements.  He has taught many seminars, workshops and short courses on subjects related to his fields of interest.  Most recently, he has focused on the application of integrated sensor diagnostics and the associated reservoir engineering of unconventional plays with high liquid hydrocarbon content. He developed and applied the concept of dramatically reducing the cost of the conventional trial-and-error learning curve by replacing it with an Engineered Learning Curve based on Integrated Sensor Diagnostics and a rigorous Design of Experiments.  He has authored numerous papers & articles, and holds several patents in his areas of interest.  He received a B.S. in Natural Gas Engineering from Texas A&I University, and has worked for Pinnacle Technologies and Halliburton since 2005.

 

Neil Stegent 
Neil is a Technology Manager at Pinnacle, a Halliburton service in Houston, Texas and is a registered professional engineer (P.E.). In his Halliburton career starting in 1980, he has held various roles including engineering, customer sales, management, and marketing. He has a vast amount of field experience implementing fracture theory into practice. Fracture evaluation, pre-frac and post-frac diagnostics, fracture production evaluation, and completion optimization are his expertise. He has worked in numerous basins across North America, and has worked globally to provide solutions and commercialize new technologies. Neil has taught various courses in completion optimization and has worked most of his career focused on Fracture Stimulation and Completions of low permeability reservoirs. He has written many technical papers and holds multiple patents.

 

Henry Bland
Henry came to Pinnacle after having run two microseismic and instrumentation consulting companies. Henry worked many years at the University of Calgary’s “Consortium for Research in Elastic Wave Exploration” (CREWES). While working there he performed a diverse range of research in the field of multicomponent seismology. Although Henry’s education is in Electrical Engineering, the bulk of his experience comes from over 20 years of work in geophysics. Henry’s enthusiasm for new technologies has involved him in instrumentation design, seismic sensor testing, seismic processing, seismic acquisition, real-time monitoring and algorithm design. With Pinnacle, Henry has developed new hardware and software to assist in velocity model calibration and continues to develop new methodologies for geophone-orientation calibration. Henry also conducts work evaluating fiberoptic based sensing technologies and works with Canadian clients to integrate Pinnacle’s technologies into their daily monitoring. Henry is active in the geophysical community and is currently leading a group that plans to standardize the exchange of microseismic data. Outside of work hours, Henry plays trombone in a community-run concert band and studies the guitar.

 

Eric Davis
Eric leads the development of Pinnacle’s unique tilt, GPS and InSAR diagnostics, which are used for fracture mapping, reservoir monitoring and geotechnical monitoring. He oversees the instrument designs, develops analysis methods and implements relevant new technologies that can improve the technique of using ground deformation to visualize far field fluid movement. The equipment and methods have garnered numerous awards, from both inside and outside of the oil and gas industry.

 

Mikko Jaaskelainen
Technology professional developing monitoring solutions used primarily in the Oil & Gas industry for applications ranging from down-hole sensing, pipe-line leak detection, power cable monitoring, sub-sea systems optimization to towed, seabed and down-hole seismic sensing. It all started with a 3 month project assignment in Houston 1996.

 

Jeff Bush
Jeff came to Pinnacle in 2013 through the acquisition of Optiphase, Inc., a company he founded with a 23 year record of championing advanced instrumentation solutions for fiber optic sensing markets worldwide.  His entire professional career, starting in 1978, has been devoted to fiber sensing technology evolution where he holds 12 patents and has attained numerous business wins.  At Pinnacle Jeff continues such roles by managing the technical elements and agendas for Distributed Acoustic Sensing.

 

Eric Holley
Eric Holley started as a stimulation field engineer for Halliburton in the US in 2006 before moving over to Pinnacle, a Halliburton Service in Calgary in 2009. At Pinnacle Eric lead the fiber optics product globally. Currently Eric is the Product Line Manager for Production Enhancement focused on well productivity. He holds a Bachelor of Science degree in Aeronautical Engineering from Purdue University and has authored several publications on the topic of fracture diagnostics through the use of microseismic mapping and fiber optics.

 

Neha Sahdev
Neha Sahdev started as completions engineer in oilfield in2006, in India after completing her B. Tech in Chemical Engineering from Indian Institute of Technology, Madras, India. Throughout her career so far, she has had diverse experience in terms of geography (Asia, Middle-East, Offshore Canada, North America), and worked in different field development types (EOR/Unconventional/Mature fields). She joined Pinnacle, Halliburton in Nov 2015, working for the Rockies region- deeply involved in all phases of fiber optics projects. She then moved to Houston, leading the fiber optics analytics development team, developing new applications for fiber optics analyses.

 

Erik Lee
Erik started his career at NASA’s Marshall Space Flight Center working on fluid dynamics and acoustics for propulsion systems.  After transitioning to the Oil and Gas industry in 2012 he held numerous positions within Baker Hughes’ global technology division supporting sensor development, large scale data analysis and reservoir/wellbore modeling.  Erik currently works as a Senior Product Champion within Pinnacle.  He holds a Master of Science in Mechanical Engineering from Georgia Institute of Technology and has authored various publications and patents in the oil/gas and aerospace/defense industries.

 

Sean Machovoe
Sean Machovoe is a technical advisor and microseismic subject matter expert at Halliburton, Houston, where he has dedicated 17 years to mapping hydraulic fracture treatments via passive microseismic arrays deployed in downhole environments. Prior to joining Pinnacle in 2001, he spent three years in conventional land and marine seismic processing. Sean’s extensive exposure to microseismic has permitted him to analyze data from all major oil and gas basins throughout the world where hydraulic fracturing is occurring. Since Pinnacle’s acquisition by Halliburton in 2008, he has been a leader in managing and developing the microseismic service. Sean holds a master’s degree in geology from Indiana University.

 

Natalia Verkhovtseva
Natalia joined Pinnacle in 2007 as a microseismic analyst. She then became a senior analyst after she completed many successful projects in Canada and US. Currently she is one of Pinnacle’s Principal Geophysicists at a position of Subject Matter Expert for Microseismic Processing as well as leading a team of MSM analysts. Her role includes providing in depth quality control for all microseismic projects Halliburton has, participating in writing HMS procedures and providing guidance for microseismic geophysicists. Prior to joining Pinnacle she worked as a research assistant in the Institute of Geology, Russia where she obtained her PhD in geology and mineralogy.

Integrated Sensor Diagnostics (ISD)

Filter By  
Количество записей на странице Show     results per page
  TitleНазвание  DateДата
Summary Summary Integrated Sensor Diagnostics
Integrated Sensor Diagnostics delivers subsurface insight to help you make financially important decisions relating to well spacing, fracture spacing and stimulation design, based on characteristics of the reservoir and your needs.
Summary Summary Integrated Sensor Diagnostics Brochure
Every shale formation is different, to some degree. Optimizing the asset can be a complex undertaking that involves understanding and integrating a vast scope of data to form a unified picture of the asset, from early planning through exploration and development to long-term production.
Summary Summary Diagnostics Reveal Stimulation Effects
Diagnostics Reveal Stimulation Effects American Oil and Gas Reporter July 2018 Edition
Summary Summary Integrated Sensor Diagnostics (ISD) – Subsurface Insight for Unconventional Reservoirs
ISD enables real-time adjustments and improvements during fracture treatments and pad completions.
Summary Summary Integrating Microseismic, Fracture Diagnostics Data Improves Stimulation Analysis
Microseismic is an indispensable technology that provides critical information on hydraulic fracturing parameters, but it cannot provide all the precise information to enable a full understanding of stimulation behavior in unconventional reservoirs. Obtaining a complete picture of the fracturing process requires integrating microseismic with advanced diagnostic solutions such as surface tiltmeters, downhole tiltmeters, and fiber optic distributed temperature and acoustic sensing, as well as more conventional diagnostic tools, including tracers, flow tests, fracture modeling, diagnostic injection tests, and production data analysis.
Summary Summary Integrated Sensor Diagnostics (ISD)
Integrated Sensor Diagnostics delivers subsurface insight to help you make financially important decisions relating to well spacing, fracture spacing and stimulation design, based on characteristics of the reservoir and your needs.
Related Information

Related Information Дополнительная информация