Westside WEBINAR Option: Unconventional Asset Development Workflow in the Eagle Ford Shale

Speaker Hunter Watkins, Completions Advisor, BHP Billiton
Hunter Watkins has 38 years industry experience, 35 years with Halliburton and Pinnacle and one year with The Western Company of North America, primarily focused on tight gas and unconventional plays.  For the past 2.5 years he has served as Completions Advisor for BHP Billiton, focusing on the Eagle Ford ...

Hunter Watkins has 38 years industry experience, 35 years with Halliburton and Pinnacle and one year with The Western Company of North America, primarily focused on tight gas and unconventional plays.  For the past 2.5 years he has served as Completions Advisor for BHP Billiton, focusing on the Eagle Ford shale.  He is a Professional Engineer in Texas and a graduate of the University of Texas at Austin.  

Full Description

The Eagle Ford shale is recognized as the largest oil and gas development in the world, based on capital investment (Wood Mackenzie, 2013).  Development typically consists of horizontal wells stimulated with multiple hydraulic fracture stages.  Almost $30 billion was spent developing the play in 2013, and optimizing the completion designs and spacing of these wells can result in large rewards for the companies involved.  This paper presents a pragmatic integrated workflow that was used to optimize the development and to guide critical decisions in the Black Hawk field, Eagle Ford shale.  Geoscientists, reservoir and completion engineers worked collaboratively to identify the optimal completion designs and well spacings for the development’s focus areas.  Multiple simplistic simulation models were history-matched to existing producing wells.  The resulting calibrated reservoir scenarios formed the basis of optimization studies for development drilling and down-spacing. Completion design parameters, including fracture stage length, perforation clusters per stage, and landing point for the laterals, were evaluated in hydraulic fracture models.  The resulting fracture geometries were simulated and the optimum completion design and well spacing determined for each area.  The optimal development was shown to vary by region, due to changing reservoir, fluid and geomechanical properties.  The use of multiple subsurface realizations, spanning an appropriate range of uncertainty, was critical to the success of this study.  Economic analysis across a range of potential outcomes enabled robust development decisions to be made.

Organizer Danica Hurd

Contact info:  danica.hurd@bakerhughes.com 


Please note that webinar option is dependent on the data transfer speed at the venue and therefore possible delays and breaks in communication may occur. 

When?

Wed, Jan. 21, 2015
noon - 1 p.m. US/Central

How Much?

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Where?

At your desk
United States

WEBINAR ONLY

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