advanced bha modeling and drilling & evaluation … · shale gas typical drilling challenges...
TRANSCRIPT
Advanced BHA Modeling and
Drilling & Evaluation Technology
to Improve Efficiency in Shale Gas
Horizontal Drilling
© 2011 Baker Hughes Incorporated. All Rights Reserved.
Shale Gas Typical Drilling Challenges
Challenge /Objective
• Performance Optimization
• Wellbore Placement
• Bit & Motor Durability
• Excessive Sliding
• Extended Reach
• Borehole Quality
• PDC Bit Vibrations
• High Stick-Slip, Torque
• Staying in Zone (Lateral)
• Hole Cleaning, Balling
• Pack Offs, Stuck
• Faulted/NF, Abrasive Format.
Impact
• Reduced ROP, Days on Well
• Production Optimization
• Bit Trips – NPT
• Reduced ROP, Days on Well
• Production Optimization
• Problems Run CSG, Red. ROP
• Reduced ROP, Days on Well
• Reduced ROP, Days on Well
• Production Optimization
• Reduced ROP, Days on Well
• Increased Days on Well
• Reduced ROP, Days on Well
Major Shale Gas Drilling Challenges:
• The formations are difficult – maximize the trip time• Optimize drilling to increase ROP• How to steer to the right place in the formation
The Value of Bit and BHA Stability
Drilling system stability has a significant influence on overall reliability (i.e. lessvibration = less bit, BHA, and drill string damage)
– Equipment failure is the largest source of non-productive time
– Drilling tool failures specifically cited as a top source for NPT
14%
5%6%
8%
9%
10%
10%
11%
16%
18%
18%
25%
0% 10% 20% 30%
EQUIPMENT FAILURE (IN GENERAL)
WEATHER DELAYS
DOWNHOLE WELLBORE INSTABILITY
RIG FAILURE
INEXPERIENCED PERSONNEL
STUCK PIPE
DRILLING TOOL FAILURES
EQUIPMENT AVAILABILITY
LOST CIRCULATION
CASING OR WELLHEAD FAILURE
MANAGEMENT INDECISION/ DISAGREEMENTS
ALL OTHER (12 ISSUES)
Source: Welling & Company
Survey Question: What is your greatest source of NPT?
Drilling Engineering / Optimization
• Internal education and certification program for DrillingApplication Engineers
• AKS - Application Knowledge Store
• Advantage Engineering Package
Torque & Drag, Hydraulics
• BHASysPro Analysis Software
gravity
bending moment maxima
Bending Moment Color ScaleBending Moment Color Scale
MinimumMinimum MaximumMaximum
gravitygravity
bending moment maxima
Bending Moment Color ScaleBending Moment Color Scale
MinimumMinimum MaximumMaximum
Reducing Days on Well by Drilling Optimization
5
Downhole Tools,Analytical Tools and
Modeling
Structured Processes& Engineering
Training
Offset Well and DullBit Analysis
RPM change
Stabilizer in thissectionat RPM change
RPM nearcriticalspeed,
then BHAenters hardformation
Appears to resultfrom stabilizers
hanging on ledges
and allowing bit toside cut
Fri
ab
leF
orm
ati
on
Fri
ab
leF
orm
ati
on
BHA Modeling
Torque, Drag, Hydraulics Modeling
AXIAL LATERAL TORSIONAL
Downhole dynamics measurement
DF Designs & ECD
BHASysPro - Fit for Purpose BHA
Advantage Software for Hydraulic Optimization
•From basic hydraulic optimisation•To detailed split flow analysis
•To guarantee flawless deployments
Going farther faster – Drilling Optimization (BarnettShale example)
• Premature Damage to PDC Bits• Low ROP, More Bits Required• High Cost Per Foot• High Torque and Drag• Excessive Slide Drilling (Oriented) in
Lateral Interval• Damaging Drill String Vibrations• Low Reliability/Performance of Downhole
Tools
Drilling Challenges
Closer to Bit - Minimum Vibration
Away from Bit - High Vibration
Buckling Load Analysis/ BHA Re-design
Critical Speed Analysis – OptimizeDrilling Parameters
Drilling Optimization (Barnett Shale Example)
6 Wells Drilled Prior to Optimization @ 32 ft/hr8 Wells Drilled After Optimization @ 57 ft/hr
80% Increase inAverage ROP for
Spud to TD
5+ DAYS SAVED
Optimization• Modified PDC Bits• Model Re-design BHA- torque, drag, hydraulics
• Optimized Parameters -WOB, Rotation
• Critical Speed Analysisto reduce vibration
• Result - increase ROP
Barnett Shale – Drilling Performance
Average days per wellreduced from
31.2 to 15.5 days
Average rotating hours per wellreduced from
330 to 181 hours
Decrease risk and reduce time on well utilizingRotary Steerable Tools – Shale Gas Laterals
• Decrease risk
– Improved borehole qualityallows for casing runningoperations to be completedwith less risk for extendedreach laterals
• Reduce time on well
– Eliminating orient and slidetime associated withsteerable motor drillingimproves overall effectivepenetration rate
Rotary Steerable
Steerable Motor
Rotate
Slide
12
Well Details• Well Details• Location: Webb County• Shale Play: Eagle Ford• Hole Size: 8 ¾” Curve and Lateral
Challenges• Low ROP’s• Several Bits Required• Inconsistent BUR’s in Curve• Trips to change BHA’s• Reduced Drilling Efficiency• High Cost per foot• Difficulties staying in Zone
Eagle Ford - Webb County – AutoTrak G3 / OnTrak
Solution• 8 ¾” HCC Bit (DP505X PDC Bit)• 6 ¾” AutoTrak G3 RSS• 6 ¾” OnTrak LWD
Project Results• Drill Curve from 23 deg inclination and land the curve• Continue Drilling Entire Lateral of 3,748 ft to TD• Total Footage: 5,113 ft• Rotating Hrs : 97.75 hrs• Average ROP: 52.3’/hr• Eliminated Reaming• Smoothly Ran Liner to Bottom• Consistent BUR’s• Stayed in Desired Zone
© 2009 Baker Hughes Incorporated. All Rights Reserved.
Woodford Shale – Rotary Steerable
Rotary Steerable Improved ROP by 15%
19.2
16.8
15.5
16
16.5
17
17.5
18
18.5
19
19.5
Lateral BHA 1:
AutoTrak eXpress
Lateral BHA 2:
Conventional
RO
P(f
t/hr)
Rotary steerable Reduced Cost/ Foot by 7%
$166
$179
$155
$160
$165
$170
$175
$180
Lateral BHA 1:
AutoTrak eXpress
Lateral BHA 2:
Conventional
Co
st/
foo
t($
)
Tru
eV
ert
ical
Dep
th(f
t)
Planned WellpathActual Wellpath
SteeringUnit
Power &Telemetry
MWD ProbeAssembly/NMCSDP
FlexStabilize
r
NMStab
AutoTrak Express®
Saved 4 Days of Rig Time
12.400
13.400
14.400
15.400
16.400
17.400
325 425 525 625 725 825
Drilling Hours
De
pth
(ft)
Offset drilled withConventional Assembly
AutoTrak Express® Well
AutoTrak®
eXpress In
AutoTrak®
eXpress Out
Woodford Shale – Rotary Steerable
Rotary Steerable Improves ROP by 115%
23.2
46.4
21.518.8
0
10
20
30
40
50
Conventional
BHA Run 1
AutoTrak BHA
Run 1
Conventional
BHA Run 2
AutoTrak BHA
Run 2
RO
P(f
t/h
r)
Rotary Steerable Reduces Cost/ft by 34%
$137
$94
$143$150
$-
$20
$40
$60
$80
$100
$120
$140
$160
Conventional
BHA Run 1
AutoTrak BHA
Run 1
Conventional
BHA Run 2
AutoTrak BHA
Run 2C
ost/
foo
t($
)
SteeringUnit
Power &Telemetry
MWD ProbeAssembly/NMCSDP
FlexStabilize
r
NMStab
Maximizing production by optimizingwellbore placement –Shale Gas
• Reservoir Navigation
– Full suite of formationevaluation tools andservices to steer to thereservoir “sweet spot”
Reservoir Navigation – Woodford Shale
Project Results Well was maintained in target zone Reservoir Navigation Services Multiple Propagation Resistivity Azimuthal Gamma Ray Gamma Ray Imaging Annular and Bore hole pressure
Fig.1: RNS CROSS SECTION – Well A
Fig.3: RNS CROSS SECTION – Well B
Fig. 2: Gamma Image of Well A
Fig. 4: Gamma Image of Well B
LWD Image in Shale Gas
17
Breakouts
RockStrength
Gamma
LWD Can be used to identify:
• Fracture
• Lithoface good for fracturing
• Optimization of perforating interval
• Optimization of packer placement
• Fracturing length
Integrated fracturing design
@ 2009 Baker Hughes Incorporated. All Rights Reserved
Forestburg Carbonate
© Baker Hughes Incorporated. All Rights Reserved.
Faults and Fractures in Barnett Shale Horizontal Well
Barnett Shale Forestburg Carbonate
Barnett Shale
Fault Undetectable on 3D seismic