reducing days on location and time to first productionlp.hartenergy.com/rs/433-odk-889/images/1.15...
TRANSCRIPT
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© 2020 Halliburton. All rights reserved.
Reducing Days on Location and Time to First Production
Simul-Frac OperationsCasey MaxwellHalliburton Vice President – Permian Basin
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2© 2020 Halliburton. All rights reserved.
Eliminating Idle White Space
ZIPPER SIMUL-FRACWells Pumping at a Time 1 2
Rate per Well (bpm) 100 160/2 = 80 per well
Wellhead Pressure (psi) 9,500 9,000
Pump Time Per Stage (hrs) 1.27 1.58Pumping Hours/Day 16.3 16.3
Pumping Hours/Month 456 456
Stages/Month 359 577Completed Lateral Ft/Month 53,850 86,500
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3© 2020 Halliburton. All rights reserved.
Achieving Peak Performance
ExpressSand™ Delivery SystemContainerized sand delivery for maximum efficiency and reduced HSE exposure
XHD Q10™ PumpRuggedized pump designedfor shale fracturing, with Tier 4 emissions
IntelliScan™ Monitoring SystemReal-time pump health monitoring
ExpressKinect® WCUSingle-line rig-up to wellhead for maximum efficiency and safety
ExpressKinect® ManifoldSingle-pump connection for maximum efficiency and safety
ACHIEVE THE EFFICIENCY OF2 ZIPPER FRACS WITH ONLY 1SIMUL-FRAC CREW
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4© 2020 Halliburton. All rights reserved.
QEP Highlights
§ First wells 40% increase in stages completed
§ Steadily improved our efficiencies and reducing completion costs per lateral foot
§ Simulfracing wells at >80 bpm per well
§ Completed over 560 stages in a month
§ Pumped over 180M lbs of sand
§ Completed over 5,000 ft in 24-hour period
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5© 2020 Halliburton. All rights reserved.
Diamondback Highlights
§ 25% savings compared to using 2 zipper crews
§ Completed 24 stages/day
§ Pumped average of +18.5 hrs pumping per day over a five month span
§ Achieved increase of 50 to 100% in efficiency gains
§ Recent test:» Completion of 4 wells » 11 days» Translated into ~4,000 lateral ft per day
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6© 2020 Halliburton. All rights reserved.
Intelligent Fracturing
It is possible to engineer the high cost and complexity out of fiber with a scalable solution
for routine fracture monitoringHalliburton has: Resulting in:
Simplified complex fiber design $600,000 eliminated from the full installation
Reduced fiber installation times Reduction of six months down to two weeks
Reengineered downhole equipment Eliminated undesired wellbore changes, such as requiring a larger hole
Removed need for additional runs Eliminated cost and risk with an additional mapping run
Developed intelligent fracturing 15,000 stages across North America with up to 20% production uplift
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7© 2020 Halliburton. All rights reserved.
A Cognitive FleetAdapt and Respond to
Reservoir Measurements
INTELLIGENT AUTOMATION
CONTROL While Pumping Real-time Decisioning
and Fracture Commands
REAL-TIME CONTROL
LIVEVISUALIZATION
3D Virtual InterfaceLive Fracture Monitoring
and Performance Projections
Intelligent Fracturing System
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8© 2020 Halliburton. All rights reserved.
PERMIAN BASIN
Averaging
160BPM
Stimulating
3,600FT / DAY
Pumping
450HRS/ MONTH
Completing
50% MORE STAGES / MONTH
BY THE NUMBERSSIMULTANEOUS FRACTURING
Complete More Stages in Less Time
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9© 2020 Halliburton. All rights reserved.