Download - © 2014 HALLIBURTON. ALL RIGHTS RESERVED. Baroid® High Pressure/High Temperature Drilling Solutions
2
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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.
3
© 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
4
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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
5
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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
6
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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
7
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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
8
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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
9
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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
11
© 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.
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:
12
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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
13
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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
14
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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
15
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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.
16
© 2014 HALLIBURTON. ALL RIGHTS RESERVED.
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