CASE HISTORY
| bakerhughes.com
Baker Hughes Integrated Services Empowered Customer
to Drill More than 1 Mile of Lateral in 24 Hours
Location: Marshall County, West Virginia
Results
nnIncreased
drilling performance while
maintaining wellbore stability
nnDelivered
high ROP (up to 224 ft/hr
[68.3 m/hr] in lateral section)
nnMaintained
high environmental
compliance standards
nnReduced
drilling time and drilling
fluid costs
nnDoubled
foot per day average when
compared to similar field wells
nnMaximized
operator’s return
on investment
An operator petitioned Baker Hughes to drill
a lateral footage section of more than 1 mile
in a single day. To achieve this, Baker Hughes
needed to present the operator with solutions
to improve drilling performance by reducing
days on well and cost per foot.
The operator had several challenges, including
maximizing on-bottom rates of penetration
(ROP) and improving cuttings removal and
flow rates while maintaining good wellbore
placement and hole stability.
The need for high flow rate also had to
be balanced with the need to control
pressures and maintain a high level of
environmental compliance.
Baker Hughes was able to address the operator’s
challenges by combining its NEXT-DRILL™ invert
emulsion drilling fluid system, its AutoTrak™
Curve high build-up rate rotary steerable system
(RSS), and the Talon™ polycrystalline diamond
compact (PDC) drill bit, which is designed
specifically for use with the AutoTrak Curve RSS.
One of the keys to the performance Baker
Hughes provided is the NEXT-DRILL fluid’s
design, which enabled it to optimize pressure
management by converting wasted pressure
back to flow rate.
The fluid complimented the drill bit’s
StaySharp™ cutter technology and optimized
the bit’s hydraulic and mechanical efficiencies.
By using the AutoTrak Curve RSS’ on-bottom
downlink capability, as well as expertise
from Baker Hughes Reservoir Navigation
Services (RNS), high ROP and optimized
wellbore placement were achieved without
compromising directional control.
The compact, single-piece design of the
AutoTrak Curve RSS enabled better directional
control through real-time monitoring of near bit
inclination (5.9 ft [1.8 m] behind the bit) and
bulk gamma ray (11.5 ft. [3.5 m] behind the bit).
This impressive level of control resulted in 100%
placement of the wells in the target zone.
Challenges
nnIncrease
lateral footage and ROP
nnImprove
flow rates and boost bit
and tool performance
nnEnhance
hole cleaning
nnIncrease
flow rate and controlled
pressures without inducing
downhole losses
nnMaintain
fluid properties with
increasing ROP
Baker Hughes solution
nnAutoTrak
Curve RSS
nnNEXT-DRILL
nnTalon
drilling fluid system
PDC drill bit
nnReservoir
Navigation Services
CASE HISTORY
Overall Operator Drilling Performance
300,000
180
Total Footage
140
200,000
120
100
150,000
80
100,000
60
ROP (on bottom)
160
250,000
40
50,000
20
0
0
Q2 2013
Q3 2013
Q4 2013
Q1 2014
Q2 2014
Q3 2014
Q4 2014
The integrated technologies from
Baker Hughes worked together to
surpass competitor performance while
also maximizing wellbore stability and
extending bit life.
Baker Hughes and the operator’s drilling
and rig crews also worked together to
provide the highest standards of safety,
resulting in no health, safety, or
environmental incidents.
This high-performance Baker Hughes
package saved the operator more than
one drilling day in the lateral sections of
the wells and delivered cost savings of
approximately USD100,000 per
lateral section.
This project is a great example of how
Baker Hughes’ development efforts and
integrated performance have kept the
focus on safety while improving drilling
performance for operators.
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© 2016 Baker Hughes Incorporated. All rights reserved. 42831 08/2016