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. 2 © 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 3 © 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 4 © 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 20 56 60 64 Plastic Viscosity cP @ 120°F 50 Yield Point lb/100 ft HPHT sq filtrate 20 30 10 Contaminant tolerant 14 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 5 © 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 6 © 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 7 © 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 8 © 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 9 © 2014 HALLIBURTON. ALL RIGHTS RESERVED. Consistent Quality: Technical and Operational Process 10 © 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 11 © 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 12 © 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 13 © 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 14 © 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 15 © 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 16 © 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 18 © 2014 HALLIBURTON. ALL RIGHTS RESERVED. > 350°F > 175°C > 400°F > 200°C
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