Baroid Deepwater Solutions Customer Presentation

Report
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.
7
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.
8
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.
9
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.
10
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.
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 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.
23
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.
25
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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