Janchik R Lost Circulation Solutions for Lime Stones and Induced Fractures
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Transcript of Janchik R Lost Circulation Solutions for Lime Stones and Induced Fractures
© 2011 BAKER HUGHES INCORPORATED. ALL RIGHTS RESERVED. TERMS AND CONDITIONS OF USE: BY ACCEPTING THIS DOCUMENT, THE RECIPIENT AGREES THAT THE DOCUMENT TOGETHER WITH ALL INFORMATION
INCLUDED THEREIN IS THE CONFIDENTIAL AND PROPRIETARY PROPERTY OF BAKER HUGHES INCORPORATED AND INCLUDES VALUABLE TRADE SECRETS AND/OR PROPRIETARY INFORMATION OF BAKER HUGHES
(COLLECTIVELY "INFORMATION"). BAKER HUGHES RETAINS ALL RIGHTS UNDER COPYRIGHT LAWS AND TRADE SECRET LAWS OF THE UNITED STATES OF AMERICA AND OTHER COUNTRIES. THE RECIPIENT FURTHER
AGREES THAT THE DOCUMENT MAY NOT BE DISTRIBUTED, TRANSMITTED, COPIED OR REPRODUCED IN WHOLE OR IN PART BY ANY MEANS, ELECTRONIC, MECHANICAL, OR OTHERWISE, WITHOUT THE EXPRESS PRIOR
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Lost Circulation Solutions for
Limestones and Induced Fractures
(or any rock type)
Alex Wienzek Product Line Manager
Richard Jachnik Technical Sales Manager
History
• Lost circulation of Drilling Fluids have been experienced
ever since Drilling Fluids were introduced-especially when
drilling porous/fractured and vuggy formations.
• Many types of Lost Circulation Material (LCM) have been
proposed, tried (with little science) and many are still in
use.
• Many technical papers have been written on the subject
and if those concerned with minimising formation damage
through bridging are also considered the list is extensive
indeed
• So what is new regarding both our understanding and
ability to seal natural fractures/vugs in limestones or
induced fractures in various rock types?
© 2011 Baker Hughes Incorporated. All Rights Reserved. 2
Efficiency...Data accuracy...People-oriented service
Examples of Fractured Chalks
1 f
t
Tectonic Healed Stylolite-assoc. Discontinuous
f
f
f f
f
f
f
f
Quantification of Losses
• Seepage Loss (<4m3/hr)
• Partial Loss (4 -80 m3/hr)
• Severe Loss (>80 m3 /hr)
• These numbers vary according to author and rounding up from bbl to
m3 ! (In mud man parlance loosing >60 m3 per hour is ~2 pits per
hour! – sufficient!). In 8 ½” hole pumping at 2 m3 per min means
returns at 50% or less.
• Seepage loss is normally loss to porous formations or small
discontinuous fractures – which may be natural or induced
• This type of loss can be cured either with small doses of effective
LCM (possibly using the application of bridging theory with
particulates)
© 2011 Baker Hughes Incorporated. All Rights Reserved. 4
SPE 18022
This seminal paper by Sandia Natl
Labs contains some very useful
information.
Converting to mm - if we look at the
width of the fracture opening (b) at
0.12 in (3.05mm) we see that even
if the particle size diameter is 2mm
the fracture will never plug.
(Multiple particle bridges do not
form with the same material or can
sustain the applied pressure)
For half the fracture width the same
size particle can plug – at only 5
ppb (14.3 kg/m3)
They also showed that when the
particle size was shifted to a larger
size distribution they achieved
better bridging (next slide)
© 2011 Baker Hughes Incorporated. All Rights Reserved. 5
Jamming
• When flakes were mixed with the particulate (rubber) Sandia
achieved even greater effectiveness – this is due to the
morphology of flakes and the ability to randomly orient and jam.
• The use of LC Lube (more elongated morphology than ground
marble) at concentrations of 57 kg/m3 in OBM allowed Brent
sands to be drilled significantly overbalance with pressures
between 3000 and 5400 psi.
• The material has been used successfully at concentrations as
low as 2.85 kg/m3, more often at 15-20 kg/m3 with 100 kg/hr
additions while drilling 8 ½” holes.
• The resiliency of the synthetic graphite is much higher than
solid particulates – this provides an increase in Frac pressure
(wellbore strengthening) and can be used injunction with
marble to lower cost
© 2011 Baker Hughes Incorporated. All Rights Reserved. 7
LC Lube – synthetic graphite
Issues – Larger is better than finer!
• D50 of LC Lube is around 320 microns or 48 mesh
• Initial drilling requires 84/52 mesh screens
• 145/120 mesh can be used once the mud is warm
and fully sheared
• Some losses at the shakers are inevitable
• Finer product is less effective at plugging induced
fractures in Brent sands
25 x25 x
Particle Size Distribution
Mesh Size Micron % Retained
40 425 µm 27
50 300 µm 22
60 250 µm 12
80 180 µm 19
Seepage loss materials
• These by their very nature
of smaller particle size will
not plug large fractures but
can be effective for
seepage loss into porous
formations or into short
drilling/ECD induced
fractures
• So at what fracture width
will they fail?
Fine Mica
Chek-Loss (cellulose
fibre)
Max-Bridge Slot Failure
• Max-Bridge is a
combination formulation of
Soltex or Sulphatrol, Max-
Shield (latex polymer ~1
micron), LC Lube and LC
lube fine designed for
Saudi drilling
• Tested on 200 micron slots
it functioned, but failed on
300 micron (next slide)
Particle Size Distribution
0
10
20
30
40
50
60
70
80
90
100
0 100 200 300 400 500 600 700
Micron
Perc
en
tag
e
LC Lube Fine
LC Lube
Aquadrill Mud + Max-Bridge + LCM
• Note the addition of various LCM used for seepage loss
and the results!
Increasing the pressure to 900 psi and at 150 F doubled the spurt result for test 4
and 8.
RDIF Mud + Sized marbles
• Note that the addition of extra calcarb particulates failed to
bridge effectively 100 micron slots
TFL= Total Fluid Loss
No Surprise!
• Multiple particle bridges will not form when none of the
particulates has at least a D90 >than the fracture width!
© 2011 Baker Hughes Incorporated. All Rights Reserved. 13
0
10
20
30
40
50
60
70
80
90
100
1 10 100 1000
Cu
mu
lati
ve
%
Diameter (microns)
PSD of Fordacal Grades - 2005 data from supplier
Fordacal 10
Fordacal 30
Fordacal 45
Fordacal 300
Fordacal 200
Fordacal 100
Fordacal 60
Fordacal 25
Fordacal 36
Fordacal 16 max
Fordacal 16 max
but flakes are another story!
Baker-Squeez
This is a recent product introduction
based on a fibrous pill formulation
for loss circulation problems. (See
SPE papers 139817 & 149120).
It is a formulated one sack additive
that can be weighted to 18 ppg
(2.16 sg) and seals both porous
sands, gravels and fractures
The fracture limitation?
From our testing ~1300-1400
micron as it failed at 1500 micron in
WBM and at 1000 micron in OBM
though bridged 800 micron
Useful for overburden drilling.
Convenient and avoids issues of
how much LCM to add, which LCM
to add and in what combination.
Also simplifies rig inventory.
Comparative testing on 1500 micron slots
© 2011 Baker Hughes Incorporated. All Rights Reserved. 15
• Only Formulations C & D bridged but with high fluid loss.
Note E failed with more Nut Plug (the surmise is greater
sphericity in the mix).
So while formulations C & D would have sealed smaller fractures as well as
Baker-Squeez , the formulations are more complex to engineer and liable to
failure.
Solu-Squeez
© 2011 Baker Hughes Incorporated. All Rights Reserved. 16
This material was designed where a degree of solubility in 15% HCl was
desired (>90%) and seals up to ~700 micron slots – although this could be
extended with Soluflake
What can bridge above 3000 micron? 10 mm?
We can successfully bridge in the
laboratory apertures up to 8 mm
wide with Soluflake and calcarb
blends. Holes appear slightly easier
to bridge than these apertures.
The concentration of additives is
now such coupled with the large
size of the coarse materials that
these slurries cannot be pumped
through tools or small nozzles and
are best displaced/squeezed open
ended.
The point is approached where
either losses are lived with, or a
lower fluid density is used such as
air drilling if this is possible.
Alternative techniques such as
pressured mud cap drilling or
variants can also be used in some
circumstances.
© 2011 Baker Hughes Incorporated. All Rights Reserved. 17
Sufficient material to Jam
• While not optimised for coarse material
dose Table 4 data shows that even a
high concentration of flaked and
particulate materials can fail to bridge.
• This and other data goes someway to
explain the cases where LCM pills have
failed. They just do not have sufficient
coarse flaky or fibrous material to enable
multiple bridges to form.
• Bridges will form on 8 mm apertures with
150 ppb material blend (428 kg/m3)
• Largest particulate size can be < than
actual aperture width provided there are
enough other large flakes/smaller
particulates to help bridge
© 2011 Baker Hughes Incorporated. All Rights Reserved. 18
Solu-Flake D
This is a recent addition to our
flaked Calcium carbonate line. The
difference to Soluflake is the slightly
lower acid solubility >80% vs~95%
and a slightly harder more brittle
flake.
It was introduced due to the large
demand for Soluflake in Saudi and
supply line issues.
Picture of experimental Extra Coarse Soluflake
Intellibore
• Drilling Fluids have recently introduced a methodology
that allows detailed design of drilling fluids for wellbore
strengthening in areas of weak fracture pressure or low
operating margins between mud weight and fracture
initiation pressure. It is aimed at expensive offshore wells
where the cost of the analysis and the time savings for
successful implementation warrant it’s use.
• The methodology requires a variety of geomechanical
inputs (15) into the Borewise model.
© 2011 Baker Hughes Incorporated. All Rights Reserved. 20
Geomechanics Model Input IntelliBore™ - Wellbore Strengthening
© 2010 Baker Hughes Incorporated. All Rights Reserved. 21
Formation Properties
• Young’s modulus
• Poisson’s ratio
• Biot’s constant
• Tensile strength
• UCS
• Internal friction angle
• Linear thermal coefficient
Formation Stresses
• Pore pressure
• Overburden
• Sh min
• SHmax
• Smax azimuth
Fracture Parameters
• Height
• Length
• Toughness
Geomechanics analysis requires fifteen input parameters
Borewise Model – example output IntelliBore™ - Wellbore Strengthening
© 2010 Baker Hughes Incorporated. All Rights Reserved. 22
Functions / Capabilities
• Temperature effects on Formation Breakdown Pressure
• Formation properties data base
• Single point / batch analysis
• Range options – sensitivity analysis
– Inclination
– Azimuth
– Young’s modulus
– Pore pressure
IntelliBore Integrated Solution Process IntelliBore™ - Wellbore Strengthening
© 2010 Baker Hughes Incorporated. All Rights Reserved. 23
Well Data
• Customer
• E-Log
• Pore Pressure
• Offset wells
• Mud System
BoreWise - Geomechanics Model
• Fracture Characterization: Depth & Width
• Single Point Analysis - Fracture Pressures
• Inclination / Azimuth changes
• Drilling Window Analysis
BridgeWise – Bridging
• PSD Optimization
• Drill-In Fluid Design
• Wellbore Strengthening
• Fracture Closure Pressure
Dynamic Temperature Modeling
• Circulating Temperature Profile
• Tripping Schedule
• ECD Spike
Advantage® Engineering
• Hydraulics
• Hole Cleaning
• ECD/ESD
• Bit Optimization
• Swab / Surge
Laboratory
• Formulation
• Optimization
• Return Perm
GeoWise
Drilling Fluid Formulation
Happiness is a plugged fracture!
Questions?
© 2011 Baker Hughes Incorporated. All Rights Reserved. 24