C&P/DESG SPECIAL EVENT: Data Management Challenges of Distributed Measurements in Unconventional Wells

Speaker Kyle Friehauf, PhD, ConocoPhillips
Kyle Friehauf, PhD is a Senior Well Stimulation Engineer in ConocoPhillips' Completion Technology group, located in Houston. His current research projects include monitoring and characterization technology of hydraulic fracture treatments.   He has authored several SPE papers on hydraulic fracturing and serves on the technical committee for the SPE Distributed Fiber-Optic Monitoring for ...

Kyle Friehauf, PhD is a Senior Well Stimulation Engineer in ConocoPhillips' Completion Technology group, located in Houston. His current research projects include monitoring and characterization technology of hydraulic fracture treatments.   He has authored several SPE papers on hydraulic fracturing and serves on the technical committee for the SPE Distributed Fiber-Optic Monitoring for Well, Reservoir and Field Management Workshop.  He also holds a BS in Chemical Engineering from the Colorado School of Mines and a PhD in Chemical Engineering from The University of Texas.


Most wells do not include lateral monitoring, leaving the engineer uncertain of the fluid distribution in both the completion and production phase. Distributed well monitoring is ideally suited for these well types because it is capable of monitoring the entire lateral, giving engineers the ability to discriminate between sections of the well. The most common distributed measurement is the fiber-optic based technology, DTS (Distributed Temperature Sensors); however, other distributed measurement technologies are expected to grow in the future.


There are several challenges associated with collecting and managing distributed data. Most notable is the differentiation of the data to be used both statically, like a log, and dynamically, like a point gauge. This requires software and data communication protocols that are not anticipated in normal operations. The author has taken note of the process and results of a handful of DTS applications. He would like to share the unique challenges and lessons learned when applying distributed measurements to these well types.

Full Description

The Completions/Production and Digital Energy Study Groups Present a Unique Joint Event and Dinner Presentation

Data Management Challenges of Distributed Measurements in Unconventional Wells

Typical North American shale gas wells are characterized by long horizontals and multiple stages of hydraulic fracturing. Economic success relies on effectively and efficiently stimulating the entire reservoir along the horizontal well. Most wells do not include lateral monitoring at all, leaving the engineer uncertain of the fluid distribution in both the completion and production phase. Distributed well monitoring is ideally suited for this well types because they are capable of monitoring the entire lateral at one time, giving engineers the ability to discriminate between sections of the well. The most common distributed measurement is the fiber-optic based technology DTS (Distributed Temperature Sensors). However, other distributed measurements are expected to grow in the future.

There are several challenges associated with collecting and managing distributed data. Most notable is the differentiator of the data to be used both statically, like a log, and dynamically, like a point gauge. This requires software and data communication requirements that are not normally anticipated in normal operations. The author has taken note of the process and results of a handful of DTS applications. He would like to share the challenges and gives lessons learned when applying distributed measurements to these well types.


Organizer Digital Energy Study Group & Productions/Completions Study Group

When?

Wed, Apr. 24, 2013
5:30 p.m. - 8 p.m. US/Central

How Much?

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Where?

Norris Conference Centers - Houston/Westchase
9990 Richmond Ave.
Houston, TX 77042
USA

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