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Halliburton Artificial Lift - ESP
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
DJ Fakelman – Account Representative Denver, CO.
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Presentation Overview
§ Halliburton Ar-ficial Li1 § Divide County case study § Mountrail County case study § Advantages to using ESP’s in the Bakken/Three Forks § Addressing the Program Bullet Points § Conclusion
Halliburton Artificial Lift
2008 2012 § Global Ar-ficial Li1 formed in 2008 § 2009 -‐ Service centers opened in Texas and Oklahoma § 2010 -‐ New Manufacturing facility opened in Oklahoma City § 2011-‐ Service centers opened in Casper, WY and Minot, ND § 2012 – Halliburton Energy Services acquires Global § 2013 – Forma-on of new PSL, Halliburton Ar-ficial Li1
Tomlinson 3-‐2HN § U-lizing a Halliburton ESP unit
beginning October of 2012 § 300th Day Oil Produc-on – 63,276 BO § Lower intake pressure, lower fluid level
© 2011 HALLIBURTON. ALL RIGHTS RESERVED. 4
Divide County Case Study: SM Energy
Tomlinson 3-‐1HS § U-lizing a Rotoflex™ unit beginning
March of 2012 § 300th Day Oil Produc-on – 57,765 BO § Higher intake pressure, higher fluid level
v Both wells were completed using the same techniques v ESP has significantly increased produc-on over the last 11 months
v Opportunity has been created for con-nued u-liza-on of Halliburton ESP’s in this area
© 2011 HALLIBURTON. ALL RIGHTS RESERVED. 5
Mountrail County Case Study: Slawson Exploration Cannonball Federal 2-‐27-‐34H
§ Compe-tor ESP installed in April 2012 § ESP pulled in November 2012 § GLR ranging from 500-‐800 § Gas locking issues between 700-‐1000psi
PIP § NPT caused by excessive down -me § Produced 104,332 BO during run life of
ESP
Cannonball Federal 3-‐27-‐34H § Halliburton ESP installed in March 2012 § ESP pulled in April 2013 § GLR ranging from 500-‐800 § No gas locking, PIP consistently
between 400-‐500psi § No NPT caused by excessive down -me § Produced 244,823 BO during run life of
ESP
v Both wells were completed using the same techniques v Halliburton ESP not only had longer run life but produced 68,070 BO more in same -me
period ( 8 months ) as compe-tor unit v Opportunity has been created for con-nued u-liza-on of Halliburton ESP’s in this area
§ Crea-on of “second” decline curve – Achieve rates reached during flow back
© 2011 HALLIBURTON. ALL RIGHTS RESERVED. 6
Advantages to Using ESP’s in the Bakken / Three Forks
§ Pump wells down to lower PIP’s and fluid levels – Maximize the amount of hydrocarbon produc-on
§ Large opera-ng range – Less interven-ons and NPT to accommodate well decline
§ Ability to gather and trend large amounts of data – Down hole sensor is u-lized alongside monitoring program
§ No problems caused by rod wear, rod stretch, rod pounding, or tubing wear – Deeper PSD’s and rod pounding caused by gas interference are common problems
§ Minimal maintenance required and small footprint – Less for field hands to worry about, weather has ligle effect on opera-on
§ Today’s technology allows the use of ESP’s in high GLR, high BHT condi-ons
© 2011 HALLIBURTON. ALL RIGHTS RESERVED. 7
Addressing the Program Bullet Points § Evaluating whether aggressive preliminary ESP production raises the decline curve enough
to justify initial outlay – In our experience the answer is yes. The pump must be properly designed for the applica-on
and coopera-on between the service company and the operator is key.
§ Deciphering the lowest production rate at which ESPs can run without failing to determine the point at which it can't be used
– There are ESP’s that can pump volumes as low as 75bpd. The ques-on is when is an ESP no longer the economical solu-on. The answer to that is situa-on and operator specific.
§ Assessing the failure rate of ESPs being used in the Bakken to define the total run life that can be expected
– The run life of an ESP is as much determined by the environment in which it is operated in as it is by the design and manufacturing of the unit.
– Failure rates can be directly correlated to how the well bore is treated and what is put into place to protect the ESP prior to installa-on.
§ Examining the effectiveness of using ESPs for moving additional fluid to clean the well up before running rod pump
– ESP’s should not be considered the vacuum cleaner that is run in order to clean the well up for other forms of li1.
– If designed properly, an ESP can be the preferred method of ar-ficial li1 for a large por-on of the life of the well.