© 2014 HALLIBURTON. ALL RIGHTS RESERVED. Baroid® High Pressure/High Temperature Drilling Solutions

© 2014 HALLIBURTON. ALL RIGHTS RESERVED.

Baroid® High Pressure/High Temperature Drilling Solutions

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Customer Challenge

Pressure management Weighting material sag Fluid testing and monitoring HSE Drilling Efficiency Increased Trip Time Lost Circulation

HP/HT viscosity and rheology HP/HT fluid loss control HP/HT stability of additives Weighting material choice Resistance to contamination ECD control Environmental Regulations

Fluid Design Operational

Risks can lead to higher costs, environmental and safety issues, and non-productive time.

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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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High-Performance Invert Emulsion FluidsINNOVERT®, ENCORE®, INTEGRADE® Systems

Increased wellbore stability, significant reductions in whole fluid losses, and excellent return permeability

Solution Features

10.2+ Conventional IEF’s12.6+ Baroid HP IEF’sBaroid HP IEF’s

Conventional IEF’s

Enhanced low-end rheological properties

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

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HPHT 350°F HPHT 400°F0

10

20

30

40

50

60

70

20 20HPHT filtrateFluid Loss (mL)

350°F @ 16 hour hot roll

400°F @ 16 hour hot roll

0

10

20

30

40

50

60

70 64

56

14 126 5

8 6

Plastic ViscositycP @ 120°F

Yield Pointlb/100 sq ft

10-second gellb/100 sq ft

10-minute gellb/100 sq ft

Water-Based Fluids for HP/HTTHERMA-DRIL™ System

THERMA-DRIL™ Fluid Performance16 lb/gal

Maximum wellbore stability, enhanced drilling efficiencies and improved hole cleaning in HP/HT environments

Solution Features Stable rheology in high temperature

Thixotropic rheological properties

Low fluid loss in high temperature

Exceptional fluid suspension at high downhole temperatures

Excellent thinning properties

Contaminant tolerant

Improved lubricity

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Insulating Packer FluidsN-SOLATE® System

Higher production potential, can lower costs over traditional methods, and helps maintain wellbore stability

UNCONTROLLED HEAT LOSS WITH BRINE

CONTROLLED HEAT LOSS WITH N-SOLATE FLUID

Solution Features N-SOLATE Performance

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

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Lost Circulation SolutionsWellSET®, STEELSEAL®, STOPPIT®, DUO-SQUEEZE® H, HYDRO-PLUG®, DIAMOND SEAL® Additives

Preventative and Remedial solutions 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

Solution FeaturesSTEELSEAL Resiliency Comparison

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Digital Software SolutionsDFG™, DFG-RT™, CFG, AFO, RTDV Software and Services

Improved HSE, helps reduce drilling time, and optimized hole cleaning and ROP

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

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Baroid HP/HT Solutions

Customized to provide increased fluids efficiency, cost savings, decreased non-productive time, and improved HSE in the most challenging downhole conditions.

Save Time and Money

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Consistent Quality: Technical and Operational Process

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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.

Analytical technical support Bioassay technical support Reservoir fluids technical services Drilling fluids technical services Industrial drilling products lab Quality assurance Research and development

Baroid’s Laboratory Services include:

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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 History – Clay-Free INNOVERT® High-Performance Invert Emulsion system introduced into Norwegian market, offering an environmental HP/HT drilling fluid solutionLocation: North Sea

CASE STUDY

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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 low-shear 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 History – Baroid Delivers Repeated High-Temperature Success in the Gulf of ThailandLocation: Gulf of Thailand

CASE STUDY

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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 History – Innovative use of N-SOLATE® Packer Fluid in Gulf of MexicoLocation: Gulf of Mexico

CASE STUDY

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CHALLENGE: Reduce rig time while drilling and running the casing/liner in a high-

pressure/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 History – Drilling Fluids Graphics (DFG™) Software allows Operator to save rig time and successfully drill challenging HP/HT well in Western CanadaLocation: Western Canada

CASE STUDY

DFG™ with DrillAhead® Hydraulics Software provides comprehensive simulations of well and fluid characteristics.

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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

http://www.halliburton.com/en-US/ps/baroid/project-experience.page?DocListingBundle=33C0C2EF&node-id=hg4zbji0

http://www.halliburton.com/en-US/ps/baroid/fluid-services/drilling-fluids-solutions/invert-emulsion-drilling-fluid-systems.page?node-id=hgyyxpgp

http://www.halliburton.com/en-US/ps/baroid/fluid-services/drilling-fluids-solutions/invert-emulsion-drilling-fluid-systems.page?node-id=hgyyxpgp

http://www.halliburton.com/en-US/ps/baroid/fluid-services/drilling-fluids-solutions/water-based-drilling-fluid-systems.page?node-id=hgyyxphg

http://www.halliburton.com/en-US/ps/baroid/fluid-services/drilling-fluids-solutions/water-based-drilling-fluid-systems.page?node-id=hgyyxphg

http://www.halliburton.com/en-US/ps/baroid/fluid-services/fluid-additives/lost-circulation-materials/default.page?node-id=hgyyxpgw

http://www.halliburton.com/en-US/ps/baroid/fluid-services/reservoir-fluids-solutions/drill-in-fluid-systems/default.page?node-id=hgyyxpg3

http://www.halliburton.com/en-US/ps/baroid/fluid-services/reservoir-fluids-solutions/packer-fluids/default.page?node-id=hgyyxpj8

http://www.halliburton.com/en-US/ps/baroid/fluid-services/reservoir-fluids-solutions/completion-fluids/default.page?node-id=hgyyxpfs

http://www.halliburton.com/en-US/ps/baroid/operational-support/engineering-software/default.page?node-id=hg4zbjhn


Back-up

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How Halliburton defines HP/HT

> 10K psi69 MPa

Temperature > 400°F> 200°C

> 350°F> 175°C

> 300°F> 150°C

> 15K psi103 MPa

> 20K psi138 MPa

Pre

ssu

re

Standard

HP/HT

Extreme HP/HT

Ultra HP/HT