N-SOLATE®
HIGH PERFORMANCE Insulating Packer Fluid
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
customer
CHALLENGE
Preventing unwanted
heat loss during
production
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2
Challenge 1:
production rate
Production rates slow
down with:
 Heat loss
 Paraffin and asphalt
buildup
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
3
Challenge 1:
production rate
Production rates slow
down with:
 Heat loss
 Paraffin and asphalt
buildup
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
4
Challenge 2:
wellbore integrity
Pressure buildup
can compromise
casing integrity.
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
5
convection
Without proper heat insulation, heat transfer is uncontrolled
Well producing in a steady
state prior to production
 Threatens wellbore integrity
 Reduces production
flow rates
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
6
Before N-SOLATE® Packer Fluid
ONLY LOW
ONLY OIL
VACUUM
TEMPERATURE
INSULATORS
BASED
INSULATORS
TUBING
INSULATORS
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
7
Baroid’s
SOLUTION
®
N-SOLATE
High Performance
Insulating Packer Fluid
can effectively control
unwanted heat loss by
reducing both conduction
and convection for the life
of the well.
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
8
Applications
N-SOLATE Applications:
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9

DEEPWATER

HP/HT

STEAM INJECTION

PERMAFROST
®
N-SOLATE Packer Fluid Applications
Oil Based
Water Based
N-SOLATE
N-SOLATE
N-SOLATE
N-SOLATE
175
275
400
600
 DEEPWATER
 DEEPWATER
 DEEPWATER
 DEEPWATER
 CONTINENTAL
SHELF
 CONTINENTAL
SHELF
 HP/HT
 HEAVY-OIL
 GEOTHERMAL
 GEOTHERMAL
 PERMAFROST
 STEAM
INJECTION
N-SOLATE® packer fluids have low-thermal conductivity components.
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
10
®
N-SOLATE Packer Fluid Specifications
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.

Thermal stability – from 90°F to 600°F

Density range from 8.5 lb/gal to 15.0 ppg

Pumpable viscosity

Hydrate inhibitive to >8,500 psi @ 40°F
(can be engineered to higher pressure
with density limitations)

Green – Oil and grease content <8 mg/L
and LC-50 >100,000
11
®
N-SOLATE Insulating Packer Fluids
BEFORE
AFTER
crosslinker
crosslinker
Day 1
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
Day 14
N-SOLATE® systems are
engineered to activate to a robust,
insulating gel at a prescribed
temperature
and time.
Example of
N-SOLATE® 275 Fluid
Day 28
12
________ Testing with N-SOLATE 275
Upper
Middle
1.05 in
0.70 in
0.35 in
79
123
170
82
129
Example of effective
insulating packer fluid.
Demonstrates high
thermal gradient and
convection currents are
eliminated.
177
 Flow Temp: 280 oF
Lower
91
147
Zone 3
Zone 2
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
196
Zone 1
13
 Density: 10.0 lb/gal
customer
BENEFITS
 Lower cost as opposed to traditional methods such as
vacuum insulating tubing (VIT)
 Higher production potential
Increase production rates, while reducing the costly
risks associated with uncontrolled heat loss.
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
14
HIGH PERFROMANCE
®
N-SOLATE Insulating Packer Fluids
 Can prevent annular
pressure buildup for the life
of the well
 Control and prevent heat
loss for the well’s life
 Maintains wellbore integrity
 Compatible with most
wellbore fluids
 Environmentally friendly, with
low GOM toxicity and low oil
and grease
 Tailored per well for
maximum production
can eliminate
heat loss by
more
than
when compared
to basic
insulation methods.
90
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
%
15
TM
WELLCAT Casing Design Software
Accurately models the thermal insulating effectiveness of N-SOLATE fluids.
Wellbore Temperatures - Deepwater Gas Production (32mmscf/day)
Wellbore Temperatures - Deepwater Gas Production (32mmscf/day)
3000
4000
5000
6000
7000
5000
6000
7000
8000
8000
9000
9000
10000
Tubing Fluid
Tubing
Tubing Annulus
Casing1
Casing1 Annulus
Casing2
Casing2 Annulus
Casing3
Casing3 Annulus
Undisturbed
4000
MD (ft)
MD (ft)
3000
Tubing Fluid
Tubing
Tubing Annulus
Casing1
Casing1 Annulus
Casing2
Casing2 Annulus
Casing3
Casing3 Annulus
Undisturbed
10000
11000
11000
12000
12000
13000
13000
14000
14000
15000
15000
16000
16000
17000
17000
35
60
85
110
135
160
Temperature (°F)
185
210
235
260
35
UNCONTROLLED HEAT
LOSS WITH BRINE
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
60
85
110
135
160
Temperature (°F)
185
210
CONTROLLED HEAT LOSS
WITH N-SOLATE FLUID
16
235
260
EACH RESERVOIR IS UNIQUE.
TAILORED PER WELL FOR
MAXIMUM
PRODUCTION
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
17
HIGH PERFROMANCE
®
N-SOLATE Insulating Packer Fluids
Saved
Operators
2MM
$
(vs. vacuum insulated tubing)
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
18
CASE STUDY: Insulating Packer Fluid Offers Cost
Effective Alternative in Deepwater Operations
Location: Offshore Louisiana
CHALLENGE


Preventing well failure caused by annular pressure buildup in Gulf of Mexico deepwater wells.
Find a less-expensive and efficient insulation system that would prevent heat transfer and allow for increased
flow rates.
SOLUTION


N-SOLATE® packer fluid was custom-engineered specific to well conditions, formulated for a delayed crosslinking until placed in the wellbore; at which point full gelation of the system occurred
In each well, 10 lb/gal packer fluid was blended on the rig site and pumped into the production annuli. Maximum
flow-production temperatures for the wells were 210º F (99º C). The cross-linking occurred before reaching this
temperature, activating the insulating gel structure.
RESULTS

Using the high performance packer fluid, It took 12 hours less rig time at a depth of nearly 22,000 ft than it would
have to achieve a lesser depth of 10,000 ft with vacuum insulated tubing

Nearly $2 million in cost savings were realized over using the traditional vacuum insulated tubing
system
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
19
CASE STUDY: Innovative Use of N-SOLATE®
Packer Fluid in Gulf of Mexico
CHALLENGE

Lost circulation

High ECD

Because of extremely cold sea floor temperatures, the synthetic-based fluid was becoming excessively thick
when cooling off in the riser, requiring greater pump pressure to move
SOLUTION

N-SOLATE 600 packer fluid was used in the riser wall annulus to keep the heat from the synthetic-based mud
(SBM) in the main annulus from being lost to cold sea floor temperatures
RESULTS

Once the N-SOLATE 600 packer fluid was in place, further lost circulation was not experienced

Equivalent circulating density (ECD) was drastically reduced

Higher circulation rate and faster drilling rates achieved

Drilling fluid returned to surface 20 degrees warmer compared to wells without the insulating effects of NSOLATE fluid

Less stress on the wellbore throughout the entire operation

Major reduction in drilling time and reduction of fluid costs
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
20
related
DOCUMENTS
Sales Data Sheet
Technical Papers
Case Studies
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
21
BAROID Laboratory Support
Baroid scientists and engineers work with state of the art
equipment and an extensive global database in order to perform
comprehensive testing analysis on a global scale.
Baroid’s Laboratory Services include:







© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
Analytical technical support
Bioassay technical support
Reservoir fluids technical services
Drilling fluids technical services
Industrial drilling products lab
Quality assurance
Research and development
22
BAROID
RESERVOIR FLUID SOLUTIONS




Reservoir Drilling Fluids
Breaker Systems
Completion Fluids
Wellbore Clean-Up and
Displacement Packages
 Breaker Systems for
Polymer and Solids Removal
 Lost Circulation in Pay
Zones Solutions
© 2012 HALLIBURTON. ALL RIGHTS RESERVED.
23
discover
BAROID ecosystem
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Where people, processes, and
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distinctive service quality.
www.halliburton.com/baroid
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