drilling fluids
TRANSCRIPT
DRILLING FLUID SYSTEMS
&
FUNCTIONS
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All-oil muds Invert emulsion
Oil-based Muds(diesel, mineral, synthetic)
non-damaging
Polymer muds
dispersed non-dispersed
Clay (gel) muds
Water-based Muds
Drilling Muds
inhibitive
Drilling Mud Classification
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Primary Functions of a Drilling Fluid
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Some Water-based Muds
• Freshwater bentonite (gel)• Seawater bentonite• Extended bentonite• Attapulgite (salt water gel)• Gypsum• Lime• Potassium/Lime
• Polymer• KCl/polymer• KCl/Polymer/PHPA• KCl/glycol• Mixed Metal Hydroxide• Silicate• Low invasion• Cationic
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Bentonite-based WBM
• Bentonite used for viscosity and fluid loss control
• Polymer (eg CMC) often used for additional fluid loss control• Thinner (dispersant) added to improve rheology, fluid loss
control & thermal stability (eg lignosulphonate, lignite, synthetic polymer)
• Bentonite must be pre-hydrated• Muds sensitive to calcium & magnesium contamination• Unless properly treated, muds undergo irreversible thermal
gelation
• Poor level of shale inhibition• Bentonite can cause high levels of formation damage
• Cheap
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Polymer-based WBM
• Polymers used for viscosity and fluid loss control
• Many polymers tolerant of contamination by salts
• Can formulate to high salinities (eg. sat’d NaCl, formates etc)
• Moderate thermal stability, depending on composition
• Shale inhibition provided by salts, polymers & glycols
• Less formation damaging than bentonite muds
• More expensive than bentonite muds
• More lubricating than bentonite muds
• Flexible systems - properties adjusted via polymer selection
• Lower solids content than bentonite muds - can increase ROP
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Functions of Common WBM Additives
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Functions of Common WBM Additives (II)
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Functions of Common WBM Additives (III)
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Oil-based Muds
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Oil-based Muds
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Some Measured Mud Properties
• Funnel viscosity (Marsh Funnel) (seconds/quart)• Yield point (lb/100 ft sq)• Plastic viscosity (cPoise)• 6 and 3 rpm Fann viscometer readings• Gel strengths (10 second & 10 minute) (lb/100 ft sq)• API fluid loss (WBM) (ambient temperature, 100 - 150 psi)
• HTHP fluid loss (OBM and WBM) (250’F, 500 psi)• pH (WBM)• Oil:water ratio (OBM)• Density (pcf, ppg or sg)• High gravity & low gravity solids content (HGS / LGS) (from density & retort)
• Salt content - usually as chlorides (WBM & OBM)• Emulsion stability (OBM)• Inhibitor concentrations - K+, PHPA, glycol etc (WBM)
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Comparative Drilling Fluid Performance
Formation damage avoidance
Wellbore stability
Lubricity
Tolerance tocontaminants
Environmental acceptability
Overall drilling performance
Corrosivity
Thermalstability
Mineral OBM
Ester
Glycol WBM
KCl / PHPA
SBM
Bentonite WBM
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