Deepwater Drilling Solutions
Baroid Fluid and Waste Management
Deepwater Drilling Solutions
Why Baroid?
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
1925
Filed patent for first barite-based
drilling fluid
1930
First mud school
1932
First mud-testing procedures and kit
1939
First mud-logging service
1940s
Pioneers service by air and sea
1950s
Invents foam drilling technology
1960s
Invents oil-based fluid, INVERMUL® system
1970s
Develops new fluids for hostile geology
1980s
Develops mud loop testing, improves
waste management
1990s
Pioneers biodegradable invert
drilling fluids
2000s
Rolls out first families of clay-free synthetic
and high performance water-based fluids;
Roll out of Baroid Surface Solutions
2010s
Introduces automated mud monitoring
equipment to industry
2
Today’s Deepwater Market
 Leading market for the
last 10 years
― reserves added per well
― total volume of
hydrocarbons recovered
― value per BOE developed
 Significantly increased
water depth
― 1982: 500 meters
― 2012: 1500 meters
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
Deepwater and Ultra-Deepwater developments are expanding
beyond the Golden Triangle of the Gulf of Mexico, Brazil, and
offshore Africa.
3
Today’s Deepwater Market
Average Per Well Drilling Fluids & Solids Control/Waste Management Expenditures
$2,867,469
$3,000,000
$2,500,000
$2,000,000
$1,500,000
$1,000,000
$536,423
$348,676
$313,767
$537,539
$500,000
$Land
Offshore Shelf
Offshore
Deepwater
North America
International
*Welling & Company 2014
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
4
Customer Challenge
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
5

High rig costs

Complex subsurface
conditions

Remote locations and
transportation logistics

Environmental and safety
concerns
Customer Challenge
Deepwater wells increase in complexity as operators
are drilling further and deeper.
Deepwater drilling fluids challenges:
 Strict
environmental
regulations
 Transportation
logistics
 ECD control
 Gas hydrates
 Barite sag
 Reactive shale
 Lost circulation
 Shallow hazards
when riserless
drilling
 High temperature
 Waste
management
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
 Salt formations
 Low mudline
temperature
6
Customer Challenge
Risks can lead to environmental
and safety issues, higher costs,
and non-productive time.
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Baroid’s Solution
As deepwater drilling gets more complex, engineered
solutions are more important than ever.

High-Performance Invert Emulsion Fluids (HPIEF)

High-Performance Water-Based Fluids (HPWBF)

Lost Circulation Materials (LCM)

Reservoir Drill-In Fluids

Insulating Packer Fluids

Completion Fluids

Digital Solutions

Solids Control & Waste Management Solutions
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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High-Performance Invert Emulsion Fluids
ACCOLADE®, ENCORE®, INNOVERT®, INTEGRADE®, BaraECD™ Systems
BaraECD™ Fluid Performance
Solution Features

Enhanced low-end rheological properties

Superior hole cleaning

Fragile gel strengths

Low plastic viscosity (PV)

Stable in high temperatures

No organophillic clays
ra
r
radi
.2+ Co
io a I ’s
Co
io a I ’s
2.6+ Baroid H I ’s
Baroid H I ’s
d
i
or

r ss r
Increased pressure control in narrow
margin drilling operations
i a
d
i
s a
Increased wellbore stability, significant reductions in
whole fluid losses, and excellent return permeability
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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High-Performance Water-Based Fluids
HYDRO-GUARD®, PERFORMADRIL® Systems
HYDRO-GUARD® Fluid Performance
Solution Features

Highly inhibitive, non-dispersed

Clay-free

Improved lubricity

Thixotropic rheological properties

Excellent fluid suspension at high
downhole temperatures

Stable rheology in high
temperature
Maximum wellbore stability, improved hole cleaning,
and helps lower ancillary rig costs
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Lost Circulation Solutions
WellSET®, STEELSEAL®, STOPPIT®, DUO-SQUEEZE® H, HYDRO-PLUG®,
DIAMOND SEAL ® Additives
Solution Features

Preventative and mitigating LCM solutions

PSD and fracture modeling simulations

“En ineered, compo i e” materials

Multi-modal particle size distributions

Highly resilient materials (120%)

Increased material toughness

Hydratable, swelling polymer
technology

Resistance to downhole pressure
fluctuations
STEELSEAL Resiliency Comparison
Helps reduce costs, effective solutions in HP/HT
environments, and superior fracture-sealing
performance
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Reservoir Drill-In Fluids
BARADRIL-N®, BRINEDRIL-N®, COREDRIL-N™ Systems
Solution Features





Acid soluble
Exhibits excellent fluid loss control
Stable rheology
Uniquely high, low shear rate
viscosities and shear-thinning
capabilities
Bridging particle sizes can be
op imized wi h DFG™ mode in
software to help prevent deep
invasion by solids and fluids into
the reservoir
Non-damaging to the reservoir, increased wellbore
stability, and high penetration rates
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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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
he we ’ i e
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
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Completion Fluids
Brines, Corrosion Control Additives, Non-Emulsifiers
Solution Features
Corrosion Control Additives:
 Scavengers, inhibitors, and biocide
additives to protect steels in a
range of brine and temperature
environments
 Monovalent and divalent brine
compatibility
 High temperature protection up to
450°F / 230°C
NO-BLOK NON-EMULSIFIERS
Untreated brine
Brine treated with NOBLOK non-emulsifier
Non-Emulsifiers:
 Suitable for all brines
 Effective at low concentrations
Higher production potential, can lower costs over
traditional methods, and helps maintain wellbore
stability
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Digital Software Solutions
DFG™, DFG-RT™, CFG™, AFO, RTDV Software and Services
Solution Features

DrillAhead® Hydraulics simulations

Hydraulics & ECD modeling

Cuttings Load Simulations

WellSET® - LCM Modeling

Surge & swab computations

3D Animated Sweep Designs

Real-time fluids monitoring

Remote monitoring of real-time data

Simulations of deepwater displacements
Improved HSE, helps reduce drilling time, and
optimized hole cleaning and ROP
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Solids Control
Shakers & Centrifuges
Solution Features


High volume shakers
High volume centrifuges
DP
™ VE™ wi h Sc pin Deck
DE-7200
Maximum fluid recovery, helps lower disposal
volumes, reduced transportation costs, and increased
operational efficiency
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Waste Management - Cuttings Dryers
Thermomechanical Cuttings Cleaner, Vertical Cuttings Dryers (VCD)
Solution Features


Friction-kinetic heat generation to process oil contaminated drilling waste
(TCC)
Reduced oil-on-cuttings (VCD)
Baroid’s V-133 Vertical Cuttings Dryer
Thermomechanical Cuttings Cleaner (TCC)
Maximum fluid recovery, treat rig waste at origin, helps lower
disposal volumes, reduced transportation costs, and increased
operational efficiency
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Waste Management - Storage and Transport
Honey Comb Base (HCB™) Tanks, SupaVac™ System
Solution Features

Totally pneumatic cuttings transport and storage
Honey Comb Base Tank
SupaVac SV-400
Totally Pneumatic cuttings transport and storage
system reduces storage & transportation costs,
minimizes HSE and increased operational efficiency
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Fluids Treatment: Shearing Unit, Hi-Flow Filtration, Mix-on-the-Fly, Slop Unit
Shear Unit
Hi-Flow Filtration
Mix-on-the-Fly
DAF Slop Unit
Reduce deepwater rig time, reduced transportation costs,
and increased operational efficiency.
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Baroid Deepwater Solutions
Baroid’s deepwater solutions
are customized to provide
increased fluids efficiency,
cost savings, decreased nonproductive time, and improved
HSE.
Save Time and Money
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Consistent Quality: Technical and Operational Process
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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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 La ora ory S r i







© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
si
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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d :
CASE STUDY: Sag Resistant Fluid Solution for
Narrow Margin, Slim Hole, High Angle Wellbore
Location: Gulf of Mexico
CHALLENGE



Drilling high angle (64°) deep-water well in Gulf of Mexico
Narrow drilling margin (surface mud weight=13.7 lb/gal,. fracture gradient=14.8 lb/gal)
Operator was experiencing stuck production liners, lost returns, and well control issues
SOLUTION



Months of development and collaboration led to development of enhanced fluid package that could meet
extreme wellbore conditions
BaraECD™ hi h per orm nce uid y em’ unique rheo o ic pro i e provide ow, con ro ed ECD nd ow
viscosity, while also maintaining adequate suspension properties to resist sag and combat stuck pipe at high
angles
Fluid was pre-condi ioned u in H i ur on’ unique hi h-shear plant mixing system to simulate down hole
conditions prior to use
RESULTS

Drilling continued to operate within narrow drill window with no indication of barite sage or stuck pipe

Well was delivered under specified AFE days, as zero HSE incidents and zero NPT were attributed to
fluid services
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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CASE STUDY: 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
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 N-SOLATE
fluid

Less stress on the wellbore throughout the entire operation

Major reduction in drilling time and reduction of fluid costs
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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CASE STUDY: Applied Fluids Optimization (AFO)
Service Helps to Avoid Costly NPT in Deviated
GOM Deepwater Well
Location: Gulf of Mexico
CHALLENGE

Maintain ECD below Leak-Off Test value and avoid Non-Productive Time

Wellbore contained a 56-degree hole angle, typically more difficult to clean, and had reached a depth of 12,969 ft
Surface fluid density at the time of the event was 13.65 lb/gal. Bottom-hole circulating temperature was 127°F at
a pressure of 8,400 psi.
SOLUTION

Applied Fluids Optimization (AFO) services allowed AFO specialists to use real time DFG RT™ software to
interpret the situation in real time, enabling the operators to respond quickly and appropriately.

AFO specialists observed that an increase in the ROP from +/-100 ft/hr to +/-140 ft/hr with a steady flow rate of
890 gal/min could lead to a cuttings load increase from 3.08% to 8.23% and a corresponding ECD increase of
almost 0.3 lb/gal. The LOT at the last casing show was 13.37 lb/gal.

Since DFG-RT simulations had predicted significant increases to the cuttings load and ECD, the AFO specialist
declared a level yellow intervention* and sent notifications as per the job communication plan. The rig operators
reduced the ROP to +/-100 ft/hr, and the threat was avoided.
RESULTS

Reduction in ROP reduced the cuttings load in the wellbore, helping to avoid a potential pack-off, stuck
pipe, and/or lost returns.

Events could have resulted in problems ranging from a few hours of lost drilling time to the loss of the well
interval and having to sidetrack the well.
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Related Documents
Deepwater Case Histories
High-Performance Invert Emulsion
Fluids
High-Performance Water-Based Fluids
Lost Circulation Materials
Reservoir Drill-In Fluids
Insulating Packer Fluids
Completion Fluids
Digital Solutions
Solids Control & Waste Management
Solutions
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Baroid Drilling Fluid Solutions





Water Based Fluids
Invert Emulsion Systems
Wellbore Stability
Lost Circulation Materials
Wellbore Clean-Up and
Displacement Packages
 Breaker Systems for
Polymer and Solids Removal
 Lost Circulation in Pay
Zones Solutions
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Baroid Digital Solutions
 Well Planning Software
 Hydraulics Simulation
Software
 Completions Fluids
Simulation Software
 Real Time Wellbore
Monitoring Software
 Real Time Fluids Monitoring
 Automated Mud Monitoring
Equipment
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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Discover B roid’ Ecosystem
Click on image above to launch ecosystem,
then click on Launch Interactive ►
Where people, processes, and
technology are brought together to
build customized solutions,
optimize performance and deliver
distinctive service quality.
www.halliburton.com/baroid
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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