PowerPoint Template

Report
Baroid® High Pressure/High
Temperature Drilling Solutions
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Customer Challenge
Fluid Design
Operational

HP/HT viscosity and rheology

Pressure management

HP/HT fluid loss control

Weighting material sag

HP/HT stability of additives

Fluid testing and monitoring

Weighting material choice

HSE

Resistance to contamination

Drilling Efficiency

ECD control

Increased Trip Time

Environmental Regulations

Lost Circulation
Risks can lead to higher costs, environmental and safety issues,
and non-productive time.
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Baroid’s Solution
As temperatures and pressures continue to increase,
engineered solutions are critical to successful drilling.

High-Performance Invert Emulsion Fluids (HPIEF)

HP/HT Water-Based Fluids

Insulating Packer Fluids

Lost Circulation Materials

Digital Solutions
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
High-Performance Invert Emulsion Fluids
INNOVERT®, ENCORE®, INTEGRADE® Systems
Solution Features

Enhanced low-end rheological
properties
10.2+ Conventional IEF’s
Conventional IEF’s
12.6+ Baroid HP IEF’s
Baroid HP IEF’s

Superior hole cleaning

Fragile gel strengths

Low plastic viscosity (PV)

Stable in high temperatures

No organophillic clays

Increased pressure control in narrow
margin drilling operations
Increased wellbore stability, significant reductions in whole fluid
losses, and excellent return permeability
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Water-Based Fluids for HP/HT
THERMA-DRIL™ System
THERMA-DRIL™ Fluid Performance
16 lb/gal
Solution Features

Stable rheology in high temperature

Thixotropic rheological properties
70
Low fluid loss in high temperature

Exceptional fluid suspension at high
downhole temperatures
40
Excellent thinning properties
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
56
60


64
Plastic Viscosity
cP @ 120°F
50
Yield Point
lb/100
ft
HPHT sq
filtrate
20
30
10
Contaminant tolerant
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6
Fluid Loss gel
(mL)
10-second
lb/100 sq ft
20
8
12
5
6
10-minute gel
lb/100 sq ft
0

HPHT
350°F350°F
@ 16
hour hot roll
Improved lubricity
HPHT
400°F
400°F
@ 16
hour hot roll
Maximum wellbore stability, enhanced drilling efficiencies and
improved hole cleaning in HP/HT environments
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Insulating Packer Fluids
N-SOLATE® System
N-SOLATE Performance
Solution Features






Thermal Conductivity (k) – 0.123 to
0.177 BTU/(hr*ft*°F)
Thermal stability – from 90°F to
600°F
Density range from 8.5 lb/gal to
15.0 lb/gal
Hydrate inhibitive to >8,500 psi @
40°F
Prevents annular pressure buildup
for the life of the well
Control and prevent heat loss for
the life of the well
UNCONTROLLED
CONTROLLED
HEATHEAT
LOSS
LOSS
WITH BRINE
WITH
N-SOLATE
FLUID
Higher production potential, can lower costs over traditional
methods, and helps maintain wellbore stability
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Lost Circulation Solutions
WellSET®, STEELSEAL®, STOPPIT®, DUO-SQUEEZE® H, HYDRO-PLUG®,
DIAMOND SEAL® Additives
Solution Features

Preventative and Remedial solutions

STEELSEAL Resiliency Comparison
Highly resilient materials (>75%)

PSD and fracture modeling simulations

“Engineered, Composite Solutions

Multi-modal particle size
distributions

Increased material toughness

Hydratable, swelling polymer
technology

Resistant to downhole pressure
fluctuations
Helps reduce costs through superior fracture-sealing performance,
effective solutions in HP/HT environments
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Digital Software Solutions
DFG™, DFG-RT™, CFG, AFO, RTDV Software and Services
Solution Features


Baroid Essential Services

DrillAhead® Hydraulics simulations

Hydraulics & ECD modeling

3D Cuttings Load Simulations

WellSET® - LCM Modeling

Surge & swab computations

Animated Sweep Designs
Applied Fluids Optimization

Real-time fluids monitoring

Remote monitoring of real-time data
Improved HSE, helps reduce drilling time, and optimized hole
cleaning and ROP
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Baroid HP/HT Solutions
Customized to provide
increased fluids efficiency,
cost savings, decreased nonproductive time, and
improved HSE in the most
challenging downhole
conditions.
Save Time and Money
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Consistent Quality: Technical and Operational Process
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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:







Analytical technical support
Bioassay technical support
Reservoir fluids technical services
Drilling fluids technical services
Industrial drilling products lab
Quality assurance
Research and development
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Case History – Clay-Free INNOVERT® High-Performance Invert Emulsion
system introduced into Norwegian market, offering an environmental HP/HT
drilling fluid solution
Location: North Sea
CHALLENGE:
 Expanded environmental regulations in Norway have increased demand for drilling
fluid systems that can meet drilling challenges while remaining environmentally
acceptable.
 A vertical exploratory well similar to the main offset well offered a high degree of
comparison to measure the fluid’s effectiveness
SOLUTION:
 Baroid’s clay-free INNOVERT® system was formulated with XP-07™ base oil to
provide improved ECD control in narrow margins and superior hole cleaning
compared to conventional oil-based systems
 BDF-568™ additive was used in place of RHEMOD L™ suspension agent to
produce the same rheological properties and unique gel structure while meeting
environmental standards
RESULT:
 While drilling with INNOVERT® system, the Operator experienced low and
consistent Equivalent Circulating Density (ECD) in both the 16” and 12 ¼” sections
 ECD was reported throughout at 0.02sg-0.04sg above mud weight in both sections,
an improvement from the 0.02sg-0.1sg reported in the main offset well using a
conventional organophilic clay-based system
 INNOVERT® system reduced fluid losses by 23% compared to previous wells,
representing cost savings of $104,477 USD (598,246 NOK)
 No alternative fluids were needed for the 8 ½” section, resulting in further savings of
$372,717 USD (2,732,462 NOK)
CASE STUDY
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Case History – Baroid Delivers Repeated High-Temperature
Success in the Gulf of Thailand
Location: Gulf of Thailand
CHALLENGE:
 Directional slim-hole drilling, fast rates of penetration, steep thermal gradients, acid
gases and limited solids control efficiency all combined to stress non-aqueous drilling
fluid (NAF) left in the wellbore, working against effective triple combo runs and later
logs.
 Our High-Temperature (HT) fluid solution for these projects requires a thin efficient
filter cake and an advanced stable emulsion which could walk the fine line between
barite sag and excessive gelation.
SOLUTION:
 PERFORMUL HT™ emulsifier replaced other products which could not tolerate
swings in alkalinity. This non-ionic surfactant was teamed up with EZ MUL® NT
emulsifier to produce an invert fluid with minimal gelation over several days at
extreme heat. A careful balance was made with the viscosifier additives to build lowshear rheological properties and reduce the risk of barite sag.
 DURATONE® HT filtration control agent, formed part of the filtration control package
with BDF™-513 copolymer making up the rest to achieve filtrate values as low as 8.0
cc at 425°F.
RESULT:
 Over the past three months we successfully drilled and logged five wells over 400°F
using this fluid solution
 The trials provided evidence of our engineered fluid design and allowed for some key
lessons learned in implementing it.
CASE STUDY
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Case History – Innovative use of N-SOLATE® Packer Fluid
in Gulf of Mexico
Location: 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
RESULT:
 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 N-SOLATE fluid
 Less stress on the wellbore throughout the entire operation
 Major reduction in drilling time and reduction of fluid costs
CASE STUDY
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Case History – Drilling Fluids Graphics (DFG™) Software allows
Operator to save rig time and successfully drill challenging HP/HT well in
Western Canada
Location: Western Canada
CHALLENGE:
 Reduce rig time while drilling and running the casing/liner in a highpressure/high-temperature formation
 Bottomhole Static Temperature (BHST) was up to 170°C
 Narrow pore pressure and fracture gradient window
 Previous vertical well in the area experienced high fluid losses while running
and circulating the production casing
SOLUTION:
 Drilling Fluids Graphics (DFG™) with DrillAhead® Hydraulics Modeling
Software was utilized during planning and execution of the well
 Baroid personnel accurately modeled multiple characteristics for four
different sections of the well
RESULT:
 Modeling of surge pressures prior to running the 7 5/8” casing gave Operator
confidence to increase running speed from 5 m/min to 10 m/min inside the
intermediate casing
 Total casing running time was reduced by 6 hours, with an estimated cost
savings of $18,500.
CASE STUDY
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
DFG™ with DrillAhead® Hydraulics Software
provides comprehensive simulations of well and
fluid characteristics.
Related Documents
HP/HT Case Histories
Invert Emulsion Fluids
Water-Based Fluids
Lost Circulation Materials
Reservoir Drill-In Fluids
Insulating Packer Fluids
Completion Fluids
Digital Solutions
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Back-up
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
How Halliburton defines HP/HT
Ultra HP/HT
> 20K psi
138 MPa
Extreme HP/HT
> 15K psi
103 MPa
HP/HT
> 10K psi
69 MPa
Pressure
Standard
Temperature
> 300°F
> 150°C
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© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
> 350°F
> 175°C
> 400°F
> 200°C

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