fluids catalog

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2006 Systems, Products and Services Catalog

FLUIDS

Table of Contents

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About M-I SWACO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4

F L U I D S T E C H N O L O G Y

Drilling-Fluid Systems

APHRON ICS Invasion-Control System . . . . . 8

DRILPLEX . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10

GLYDRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12

NOVA Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14

PARALAND . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16

RHELIANT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18

SAGDRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20

SILDRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22

ULTRADRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24

WARP Advanced Fluids Technology . . . . . . . 26

DURATHERM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28

ECOGREEN . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29

ENVIROTHERM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29

ENVIROVERT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30

K-MAG . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31

NOVATEC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31

PARADRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32

PARATHERM/VERSATHERM . . . . . . . . . . . . . . . . . . . 32

POLY-PLUS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33

TRUDRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33

VERSACLEAN/VERSADRIL . . . . . . . . . . . . . . . . . . . . . . 34

Reservoir Drill-In Fluid Systems

DIPRO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36

FAZEPRO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38

FLOPRO NT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40

FLOPRO SF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42

FLOTHRU. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 44

FORMIX Technology. . . . . . . . . . . . . . . . . . . . . . . . . . . 46

NOVAPRO/VERSAPRO/PARAPRO . . . . . . . . . . . . . 48

VERSAPRO LS/SF. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50

Drilling-Fluid and RDF Products

Drilling-Fluid and RDF Products Listing . . . . . . . . . . . . . . . . . . . . . . . . . 52

Workover and Completion Fluid Systems

FLODENSE AP. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 58

FLOPRO CT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 60

ISOTHERM. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 62

SAFETHERM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 64

SEAL-N-PEEL. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66

Workover and Completion Fluid Systems Listing. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66

Workover and Completion Fluid Products

SAFE-LINK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 67

FILTER FLOC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68

SAFE-BREAK CBF. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68

SAFE-LUBE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68

SAFE-T-PICKLE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68

Workover and Completion Fluid Products Listing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 69

F L U I D S E N G I N E E R I N G

OPTIBRIDGE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 70

PRESSPRO RT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72

VIRTUAL CF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 74

VIRTUAL HYDRAULICS NAVIGATOR . . . . . . . . . . 75

F L U I D S S O L U T I O N S

Barite Sag . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76

Deepwater. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 77

Lost Circulation. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78

Wellbore Stability . . . . . . . . . . . . . . . . . . . . . . . . . . . . 79

I N T E G R A T E D F L U I D SE N G I N E E R I N G ( I F E )

INTEGRATED FLUIDS ENGINEERING . . . . . . . . . . 80

D I S P L A C E M E N T A N D C L E A N U P

SPEEDWELL Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 82

Drilling FluidsM-I SWACO* provides a com-plete offering of oil-, water- andsynthetic-base drilling fluidsand additives.

Reservoir Drill-In and Completion Fluids (RDF)Our complete line of reservoirdrill-in, completion and workoverfluids and additives help make oiland gas wells more productive.We also offer fluid-reclamationand -filtration services as a com-plement to this segment.

Drilling Waste ManagementIn order to provide customers witha truly integrated suite of services,M-I SWACO is continuously expand-ing and strengthening its drillingwaste management capabilities.This gives drilling contractors andoperators the ideal combination ofequipment and services for drillingin environmentally sensitive areasand/or in zero-discharge conditions.

Solids-control equipment.

M-I SWACO manufactures, sellsand rents a complete line of shaleshakers, desanders, desilters, hydro-cyclones, mud cleaners, centrifugesand oilfield screens.

Pressure-control equipment.

Chokes and operating consoles,degassers and mud/gas separatorsgive drilling contractors and opera-tors the ability to drill safely andeconomically in sour-gas and high-pressure zones. M-I SWACO tech-nological innovations such as theECHOKE* and SUPER AUTOCHOKE*are helping our customers drill forextended intervals under extremewell conditions.

Waste management. This cate-gory covers a range of waste-minimization and treatmentservices, including:

• AUTOMATIC TANK CLEANING (ATC)

• Bioremediation/landfarming

• Cuttings drying (VERTI-G*)

• Cuttings slurrification andRe-Injection (CRI)

• Dewatering

• The ENVIROCENTER* process

• Filtration

• Fixation and stabilization

• Pneumatic cuttings transport(CLEANCUT*)

• PRESSURE & FLUID

MANAGEMENT SYSTEM*

• Produced-water treatment

• Production waste management

• Rig and boat cleaning

• Thermal desorption technologies

• Vacuum collection

Advanced fluid-recovery and drill-cuttings processing services makeM-I SWACO uniquely capable ofmeeting today’s cuttings collectionand treatment needs. Our special-ists make recommendations anddevelop remediation strategies thatdefine the most effective methodsfor each application.

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M-I SWACO is an international company that offers a broad range of productsand services to the oil and gas industry. Our offerings include drilling, reservoirdrill-in and completion fluids and services, solids-control equipment, anddrilling waste management equipment and services for the petroleumindustry. M-I SWACO also provides separation and screening productsand services for the municipal and industrial markets. The followingoverview of our company gives you an idea of the scope of services we offer.

INTEGRATED FLUIDSENGINEERING* (IFE*)brings together all the capabilitiesM-I SWACO has to offer. IFE providesa level of integration and coopera-tion among fluids-related disciplinesthat delivers quantifiable value.

M-I SWACO AffiliatesM-I PRODUCTION CHEMICALS* isa leading provider of corrosioninhibitors, demulsifiers and waterclarifiers, scale inhibitors and dis-solvers, bactericides, defoamers,wax and asphaltene inhibitors,H2S scavengers, hydrate inhibitors,water-injection chemicals, com-modity chemicals, and mainte-nance and utility chemicals.

ALPINE MUD PRODUCTS* providesspecialty drilling-fluid additives forlubrication and hole stability, fea-turing liquid dispersed Gilsonite^and co-polymer drill beads.

M-I HDD MINING & WATERWELL*

markets drilling-fluid productsand additives to the waterwell,mining and trenchless-technology(Horizontal Directional Drilling orHDD) industries.

FEDERAL* Industrial Products spe-cializes in marketing drilling-fluidproducts and chemicals to generalindustrial, geotechnical, construc-tion and foundry industries.

FEDERAL Wholesale provides whole-sale drilling-fluid products to othermud companies that require prod-ucts without engineering services.

SWECO* is a leading manufacturerof customized industrial separationequipment and has also becomethe primary manufacturer ofM-I SWACO oilfield equipment.

5^Gilsonite is a mark of American Gilsonite Company.

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UNITED WIRE* and SOUTHWESTERN

WIRE CLOTH* are the worldwideleaders in oilfield and industrialscreen technology, manufacturingand marketing screens for all makesof oilfield shakers, providing wirecloth and screening products for abroad range of industrial markets,and supplying sand screens for thepetroleum-production industry.

SULFATREAT* specializes in tech-nologies and products that removehydrogen sulfide from gasesand liquids.

Quality, Health, Safety and EnvironmentEvery aspect of M-I SWACO andits activities is permeated with astrong sense of caring for the healthand safety of the people and theenvironment where they work.Our people not only look out foreach other but for those aroundthem — customers, suppliers, com-petitors and community members.

We train our people to worksafely within our facilities andoffices as well as at our customers’sites and on their rigs. All of ourregions and many of our largerdistricts have dedicated QHSEmanagers to ensure safe workingpractices and environmental

compliance. M-I SWACO has spe-cialists assigned to oversee occu-pational health standards, practicesand issues. Safe driving practices,safe working conditions and contin-ual safety training are hallmarks ofM-I SWACO people and workplaces,because respect for the individualdrives the company and everythingit does.

Training and Career DevelopmentTo be sure our personnel arethe best trained in the industry,M-I SWACO has a dedicatedTraining and Career-DevelopmentDepartment and fosters a culturewhere our people continuallyimprove and increase their skillsand expertise. Through training,we strive to create value on everyone of our clients’ projects.

Internal training for M-I SWACOpersonnel ranges from teaching

basic skill sets for entry-levelemployees to advanced trainingfor experienced people. In additionto basic mud school, M-I SWACOprovides formalized training indrilling waste management,INTEGRATED FLUIDS ENGINEERING

(IFE) and Cuttings Re-Injection (CRI).To ensure consistent quality in ourpeople, we have standardized ourtraining worldwide, so our customerscan count on our people to solve theirproblems anywhere in the world.

We provide continuing educationthroughout a person’s professionallife with the company, and for fast-tracking promising individuals wholook for challenges, our ProACT pro-gram accomplishes in a few yearswhat once required decades ofexperience. Our planned career-development and mentoring pro-grams ensure that M-I SWACOpeople have every opportunity tosucceed for themselves, for thecompany and for our customers.

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Customer-Focused, Solutions-DrivenEvery day, M-I SWACO people areengaged in the critical activitiesthat give our customers the assur-ance that they can rely on us forsolutions to their problems:

Engineering — M-I SWACO onsiteengineers and project engineersquickly respond to changing situ-ations backed by the extensiveresources at our labs and officesaround the globe.

Technical support — Our Researchand Engineering Center in Houstonand technical centers in Stavangerand Aberdeen provide 24-hr assis-tance for operations anywhere inthe world.

Technology development — Insolving problems for our customers,we’ve developed new systems andunique ways of using them. Wehave people and processes in placethat represent every activity, fromthe laboratory to the field, neededto create problem-solving technol-ogies and promote best practicesthroughout the company.

Environmental support — We opti-mize the “environmental equation”by making environmental concernsa part of every job, from productdevelopment to disposal. Throughour ENVIROCENTER* facilities, bulkcuttings-transport systems, thermaldesorption technology and otherinnovations, M-I SWACO is theindustry leader in managingdrilling wastes.

Continual training — Changingcustomer needs, more sophisticatedwell programs and rapid techno-logical advances are making knowl-edge of our industry a movingtarget. Continuous training forourselves and our customers isthe answer.

Mining, manufacturing and dis-

tribution — The best way to ensureabsolute consistency and perform-ance in our products is to controlthem from manufacturing throughdelivery. At every step in the proc-ess, we make sure that raw materi-als and finished products meet thehighest standards. Through onlineinventory and delivery systems, wekeep our customers supplied withthe products they need when theyneed them, giving them a betterreturn on their investment.

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APHRON ICS Invasion-Control System

� A P P L I C A T I O N S

Wells being drilled in depleted reser-voirs or any geology characterizedby porous sands or laminatedsequences of sand and shale. Also,some applications where under-balanced drilling is the only option.

� P R O B L E M S

When drilling sand and sand/shalesequences, operators must often useextra casing strings or costly under-balanced-drilling techniques.

� S O L U T I O N S

The water-base APHRON ICS* sys-tem uses microbubble (“aphron”)technology to stabilize problemzones. When a low-pressure zoneis encountered, the tough aphronsenter the formation and expand toequalize formation pressure.

� E C O N O M I C S

The APHRON ICS system gives oper-ators a way to access reserves eco-nomically in depleted reservoirs. Byreducing lost circulation and stuck-pipe incidents, the system furtherreduces drilling costs.

� E N V I R O N M E N T A L

Its water-base formulation makesthe APHRON ICS system acceptablein most drilling areas. The organic,biodegradable polymers and non-caustic pH materials provide a bal-ance between operational efficiencyand environmental acceptability.

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Technology that closes the door on formation invasion and opens the door to a range of drilling applications

The APHRON ICS (Invasion-ControlSystem) system is an engineereddrilling-fluid system that controlslosses in depleted, high-porositysands while stabilizing pressuredshales. This means you can useconventional drilling equipmentto successfully complete manyreservoirs that previously wouldhave been candidates only forunderbalanced drilling.

The APHRON ICS design software,which tailors the system to yourwell, and the fluid’s ability to con-trol losses significantly decreasethe potential for differential stickingand other fluid-related problems.The outstanding performance ofthis system makes it a soundeconomic option for:

• Underbalanced drilling

• Areas where lost-circulationmaterial has proven ineffectivein controlling drilling-fluid lossesor in providing desired bridging

• High-angle/horizontal wells

• Depleted formations coexistingwith normally pressuredformations

Pressure Analysis of APHRON ICS Performance4,800 (1,463) Depth: ft (m)

4,900 (1,494)

5,000 (1,524)

5,100 (1,554)

5,200 (1,585)

2 (0.24)

4 (0.48)

6 (0.72)

8 (0.96)

10 (1.20)

lb/gal (kg/L)

MDT equivalent formation pressureSurface fluid weightAnnular ECD

Although this interval had a severe dropin pore pressure (from 7 to 3 lb/gal [0.84to 0.36 kg/L] equivalent), the APHRON ICSsystem controlled losses to the formation.A 9-lb/gal (1.08-kg/L) APHRON ICS fluid,exhibiting an 8-lb/gal (0.96-kg/L) surfacedensity, was being used.

Features • Tough, stable microbubbles

• High LSRV

• Reduces the effects of high-pressure differentials

• Good cuttings transport

• Can be used in low-pressureenvironments

• Customized design andselection software

Benefits• Improves drilling efficiency

• Easier drilling in high-angleand horizontal wells

• Reduces lost circulation andrisk of stuck pipe

• UBD alternative

• Improves field economics

• Environmentally acceptable

• Significantly reduces cleanuptimes and costs

Cleanup40 Days

30

20

10

0

Gel/polymer APHRON ICS

The APHRON ICS system has proved itselfin the field, resulting in wells that showgreatly reduced cleanup times and costs.

The excellent condition of thefinal borehole significantly improvesthe acquisition and quality of dataobtained with electronic logs, andpromotes optimum results fromMWD tools.

Lower drilling costs indepleted reservoirsThe APHRON ICS system’s Low-Shear-Rate Viscosity (LSRV), com-bined with its stable microbubbles,helps you control losses when drill-ing through depleted reservoirs. Inaddition, the flexible microbubblesenable operators to economicallyaccess reserves where depletion hasaltered the mechanics of the field,

forcing the use of additional casingstrings or costly underbalanced-drilling techniques.

A microenvironmentcompatible with the macro-environmentThe organic, biodegradable poly-mers and non-caustic pH materialsthat make up the APHRON ICS sys-tem provide a healthy balancebetween operational efficiencyand environmental acceptability.The system meets or exceeds regu-latory statutes, such as those forthe Gulf of Mexico, Canada andthe North Sea.

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How the system protects sensitive formations

The water-base APHRON ICS invasion-control system uses stable, energized microbubbles of air (“aphrons”) to control losses to trouble-some formations. When a low-pressure zone is drilled, the aphrons enter the formation where they expand to equalize formationpressure, effectively protecting the formation from fluid invasion. Standard rig equipment and mixing-hopper turbulence are theonly requirements for creating the aphrons. This system should not be confused with foam drilling; it requires no external air source.

Formation

Lower-pressure zone

Microenvironment

∆p

Annulus

Higher-pressure zone

APHRON ICS bridging mechanism

A

A. Aphrons have an affinity forone another, causing them toform a bubble system in theformation openings.

B. Laplace pressure is exertedagainst the formation openingsas the aphrons expand in thelower-pressure openings.

B

DRILPLEX


Drilling lost-circulation zones, casing-milling operations, stabilizingunconsolidated formations, coiled-tubing operations, environmentallysensitive areas, and high-angle andhorizontal wells.

� P R O B L E M S

Many drilling operations require afluid system that is cost-effectiveand environmentally acceptablein addition to having exceptionalhole-cleaning ability, good screen-ability at high flow rates and theability to control losses in hardrock as well as unconsolidatedsedimentary formations.


The DRILPLEX* system is the latestgeneration of Mixed-Metal Oxide(MMO) products, a water-basedrilling-fluid system with unequaledsolids suspension, but one that stillscreens easily, even at high flowrates — the ideal system for an arrayof applications.


The system’s water-base chemistryreduces costs and environmentalproblems, minimizes torque anddrag, and limits the chance of holeerosion because the DRILPLEX systemprovides flow that is low to zeroacross the wellbore.


The basic DRILPLEX system containsessentially no components that canharm the environment. The systemand all its components are virtuallynon-toxic, with a low concentrationof organic material. The primaryfluid-loss-control additive is astarch derivative for minimalenvironmental impact.

Ordinary bentonite, extraordinary resultsSimply combining the DRILPLEX

viscosifier with pre-screened,high-quality bentonite producesa highly shear-thinning fluid witha high yield point, low plastic vis-cosity and high, flat gel strengths.The result is a fluid system withunequaled solids suspension,but one that still screens easily,even at high flow rates.

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The versatile water-base system with exceptional rheological properties designed tolower costs in a wide range of wells

The bentonite/MMO associates into long ribbon-like structuresthat can bridge openings withdiameters measured in 10sof microns.

Rheogram Showing UniqueRheological PropertiesThe data was obtained on a Fann 35A viscometer.Both fluids were unweighted.

80 Dial reading

70

60

50

40

30

20

10

0

0

Rheometer speed

100 200 300 400 500 600

XC polymerPV 12 YP 48Gels 28/40n 0.263 K 11.6

DRILPLEX systemPV 4 YP 40Gels 17/19n 0.126 K 20.1

A straightforward system for the most complex applicationsYou might think that a systemwith the versatility and applicationrange DRILPLEX has demonstratedwould involve intricate and difficult-to-engineer chemical compositions.On the contrary, the proprietaryFLOPLEX* primary fluid-loss-controladditive and the DRILPLEX viscosifierare the only components developedspecifically for the DRILPLEX system.The remaining chemicals are rela-tively common and well understood.

A diverse, worldwide track recordChallenging horizontal wells in theGulf of Mexico. The establishmentof milling records in the North Seaand elsewhere. Drilling in nearly9,000 ft (2,743 m) of water in theCampos Basin with zero losses. InWest Africa, the successful drillingof a depleted reservoir and uncon-solidated formation with a maxi-mum angle of 102° F (38.8° C).

The success stories go on and on.

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Features • Latest-generation Mixed-

Metal Oxide (MMO) system

• Highly shear-thinning

• Excellent QHSE profile

• Temperature-stable to 250° F (121° C)

• Exceptional hole cleaningand suspension

• Excellent ability to seal thehigh-permeability formationsfound in deepwater drilling

Benefits• Ideal for lost-circulation

zones, unconsolidatedformations, milling situations, and high-angleand horizontal wells

• Minimizes losses

• Reduces environmentalimpact

• High rates of penetration

• Well-suited for coiled-tubing drilling

• Cost-effective

The ability to stabilize goes with the flow

Excellent cuttings

transport

Stationary, gelled layer

of fluid

• Zero shear stress at wall• Minimal dynamic fluid loss• Protects poorly consolidated or fractured formations• Helps prevent seepage losses• No erosion of wellbore

The flow profile of the fluid in the annulusaffords DRILPLEX the ability to stabilizemechanically weak and poorly consolidatedformations. The high viscosity of the fluidat low shear rates results in a stationarylayer of fluid on the sides of the wellbore.This protective layer shields weak rock for-mations from erosion caused by the flow.The capacity of the fluid to stabilize theseweak and unconsolidated formationsis further enhanced by the lower pumprates used with the DRILPLEX system. Thistendency may also explain the lowerseepage losses that occurred in several wellsin which the formations were fractured.

The unique mechanism driving DRILPLEXBentonite platelet Bentonite/MMO complex

1 micron

MMO crystals

The mixed-metal oxide comprisingthe core of the system has anelectron-deficient lattice, andwhen added to water, the DRILPLEXparticles bond to the cationexchange sites on bentonite,forming a strong complex, whichin turn structures the fluid andprovides viscosity and gels.

When the MMO crystals areadded to a suspension of bentoniteplatelets, the cationic crystalsdisplace the naturally “resident”sodium or other cations and formstrong associations with theanionic sites on the faces of theclay platelets. What results is anew complex or adduct with

characteristics that are funda-mentally different from thoseof a virgin bentonite platelet.

The entire mechanism appearsto be electrostatic in nature, whichmakes it somewhat unusual andaccounts for the unique character-istics of the fluid system. Forexample, an electrostatic-field-based mechanism could explainthe elastic or deformable-solidbehavior observed in the absenceof shear and could also explainboth the dramatic and instan-taneous onset of the solid-to-liquidtransition and the reversibility ofthe process.

GLYDRIL


Offshore and onshore wellswhere a high-performance systemis required along with the envi-ronmental benefits and drillingcharacteristics of a water-base sys-tem. This includes large-diameterwellbores, ERD, deepwater andsubsalt applications.

� P R O B L E M S

Many high-performance systems,especially those designed for highperformance and inhibition, are oil-base products with characteristicsthat are not sanctioned by environ-mental regulations or that posecleanup and disposal problems.


The GLYDRIL* system uses anenhanced-polymer, water-basechemistry that employs polyglycoltechnology to deliver a high degreeof shale inhibition; wellbore sta-bility; High-Temperature, High-Pressure (HTHP) fluid-loss control;and lubricity.


The GLYDRIL system delivers lowerdilution rates, higher Rate ofPenetration (ROP) and lubricity, and lower disposal and environ-mental costs.


Offshore: relatively low marine toxi-city and fast biodegradation rates,minimal cuttings piles, and benthicimpact. Onshore: shale inhibitionwithout the use of salts, no aromaticor cyclic hydrocarbon compounds.

Proven by the M-I SWACO team inhundreds of wells worldwide, theGLYDRIL system uses an enhanced-polymer, water-base chemistry thatemploys polyglycol technology.Thanks to that technology, opera-tors can count on the GLYDRIL sys-tem to deliver a high degree of shaleinhibition; wellbore stability; HTHPfluid-loss control and lubricity.Because no two wells are alike,M-I SWACO offers a range of glycolsto meet all drilling needs.

Customization makes GLYDRIL the right choice for a variety of applicationsIn fact, the system’s broad range ofglycols makes it a preferred systemwhere environmental guidelinesdictate a water-base fluid. TheGLYDRIL system can be customizedto meet a variety of drilling chal-lenges — large-diameter wellbores,extended-reach drilling, deepwaterand subsalt applications, and par-ticularly reactive shales. The systemalso is ideal for drilling high-anglewells in reactive shale formations— where wellbore stability, torqueand drag are major concerns. Inaddition, the glycols in the GLYDRIL

system enhance the thermal stabil-ity of both FLO-VIS*/DUO-VIS* andPolyanionic Cellulose (PAC)/starchsystems, and also enhance thelow-shear rheological behavior ofFLO-VIS polymers at temperaturesabove 248° F (120° C).

GLYDRIL and ROPenhancementLike most water-base systems, theGLYDRIL system’s performance canbenefit from the addition of an ROPenhancer in certain applications.Please contact your M-I SWACOrepresentative to derive maximumbenefit from the GLYDRIL system andany performance-boosting additives.

12

The proven glycol system for high-performance, environmentally advanced drilling

Shale-Recovery Comparisons100% Cuttings recovery

90

80

70

60

50

40

30

20

10

0

Gel PHPA KCl PHPA Glydr il OBM

Wet cuttings Dry cuttings

Fluid-Loss Comparisons14 cc Fluid loss

12

10

8

6

4

2

0

KCl/PHPA GLYDRIL

API HTHP (200° F [93° C])

Compare performance, then save with GLYDRILLower dilution rates. Higher ROPand lubricity. Lower total costs.The GLYDRIL system is one moreexample of the M-I SWACO pledgeto provide customers the mostappropriate, cost-effective drillingfluids and systems.

Engineering experience comeswith every ounce of GLYDRILHaving the right drilling fluid is onlyone part of the story. M-I SWACOalso has the experience to help oper-ators apply products to control rhe-ology, fluid loss and density. In thecase of the GLYDRIL system, thatexperience helps determine theproper concentration and choice ofglycol additive. We can even helpyou monitor glycol concentrationsthrough the use of optical refractiontechniques. Wherever you operate,M-I SWACO has the experience thatcan make your operations run moresmoothly and cost effectively.

GLYDRIL is the right choicefor the environment, tooThe products that make up theGLYDRIL system are formulated toaddress environmental concernsworldwide, both offshore and onland. For offshore operations, thesystem displays relatively lowmarine toxicity, provides relativelyfast biodegradation rates, and mini-mizes cuttings piles and benthicimpacts. Onshore, the GLYDRIL sys-tem can be engineered to provideshale inhibition without the useof salts and contains no aromaticor cyclic hydrocarbon compounds,making cuttings ideally suitedfor landfarming.

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Soluble

polyglycol

enters

shale pores.

As temperature increases

and chemical environment

changes, polyglycol clouds out.

By plugging shale pores, the GLYDRIL system provides a barrier against water migration,thereby reducing wellbore instability caused by fluid influx.

Features• Low-toxicity, water-base system

• Relatively fast biodegradation

• Shale inhibition

• Pore-plugging, ThermallyActivated Mud Emulsion (TAME)properties

• Improved filter-cake quality

• Pipe-wetting capabilities

Benefits• In-gauge wellbores

• Lower fluid losses andleak-off values

• Lower potential for differentialsticking

• Less torque, drag and bit balling

• Lower dilution rates

• Slicker, firmer filter cake

• Greater wellbore stability

NOVA Systems

The NOVA* line has proven itself insome of the stickiest applications.

• Where increased rates of penetra-tion are required to reduce totaltime spent drilling the well,reducing overall well costs

• Drilling through highly reactiveshales where aqueous fluids pro-duce wellbore instability andviscosity problems associatedwith hydration and dispersionof the formation

• High-angle wells, includingextended-reach and horizontalwells where maximum lubricityis a high priority

• Controlling the stability and gaugeof the wellbore while drillingthrough massive salt sections

• Depleted reservoirs where highdifferential pressures requirelow fluid loss, as well as thebest available filter cake andlubricity to reduce the potentialfor differential-pressure sticking

• Production zones that may be sen-sitive to formation damage whendrilled with water-base fluids

• High-pressure, high-temperature(>350° F or >177° C) wells wherecontinuous phase temperaturestability is critical

• While drilling wells with potentialformation-related problems: bitballing, gumbo heaving and blind-ing of shale shaker screens

The NOVA line has what you’relooking for to replace yourconventional system• Compared to water-base sys-

tems, NOVA systems deliver

significantly improved drillingrates and improved lubricity

• The choice of low synthetic-to-water ratios to reduce formulationcosts and environmental impact

• The ability to discharge cuttings

• Excellent wellbore, temperatureand contamination stability

• Superior return permeabilityresults, ensuring minimalformation damage

• Increased hole cleaning, evenin high-angle wellbores

• Improved health and safetycompared to oil-base systems

• The choice of rheological profileto suit drilling requirements

• Available in a wide range ofdrilling-fluid propertiesand densities

NOVA systems deliver superiordrilling performanceAlthough the cost per barrel of aNOVA system is higher than tradi-tional, water-base systems, itsimproved performance significantlyoutweighs the initial investment.M-I SWACO customers report thatNOVA systems have reduced theiroverall drilling costs by up to 55%.And rigs running NOVA systemsprograms have set world-recordpenetration rates, representingimprovements of up to 70% com-pared to other mud systems.

NOVA systems have also reducedcosts by minimizing wellborestability problems associatedwith hydratable clays. The sub-stantial improvement in holegauge obtained by using NOVA

fluids delivers in-gauge wellbores.This means better logging andcasing runs, reduced bit-balling,fewer stuck-pipe and downtimeincidents, and a substantialreduction of waste volumes andcement consumption.

Along with record-breaking drill-ing rates, NOVA systems providesuperior hole cleaning and lubricityfor drilling “designer,” high-angle,extended reach wells. The filter cakecharacteristics of a NOVA systemprovide excellent lubricity equalto or better than that provided byoil-base systems.

Lubricity, combined with effec-tive cuttings removal, results insignificant reductions in torqueand drag.

The NOVA line satisfiesvirtually every country’senvironmental regulationsOne of the main reasons for devel-oping a synthetic-base system wasenvironmental considerations. NOVA

systems not only have proven lessdamaging (environmentally) thandiesel-base and mineral-oil-basesystems, but they also generate lesswaste than water-base systems.

Among the many stringent envi-ronmental tests conducted on NOVA

systems are those for the North Seaand the Gulf of Mexico.

The North Sea area requires that,for approval for use/discharge off-shore, all drilling chemicals and flu-ids pass a series of tests for toxicityto specific aquatic organisms andthat biodegradation/degradationtesting be conducted under marineconditions. Each sector within the

14

The environmentally sound alternative to traditional drilling fluids

North Sea area then assesses thedata for discharge approval. Thisenvironmental test data for theNOVA systems has resulted in themobtaining the most environmentallyacceptable classifications for use/discharge in the North Sea. It shouldbe noted that they have been usedin all North Sea sectors.

In 2001, the EPA established newregulations for the use of Synthetic-Base Drilling Fluid (SBF) for use in theGulf of Mexico. These regulationsincluded stock limitations and dis-charge limitations in a two-partapproach to control SBF-cuttingsdischarges. The first part was basedon product substitution throughuse of stock limitations (e.g., sedi-ment toxicity, biodegradation, PAHcontent, metals content) and dis-charge limitations (e.g., sedimenttoxicity, limit on the retention ofSBF on SBF-cuttings).

The NOVA system is designed tomeet both the stock limitations andthe discharge limit of sediment toxi-city. It is also design to biodegrade inthe most difficult of environments:those without oxygen. Detailed doc-umentation is developed to insurethe compliance of the NOVA system.The EPA has viewed the use of a prod-uct like the NOVA system, in combi-nation with the VERTI-G technology,as a pollution-prevention technology.

M-I SWACO formulated NOVA sys-tems with the health and safety ofrig crews in mind. In addition to pro-tecting the environment, NOVA sys-tem fluids go a long way in makinglife easier for the people who handleand work with them. Extensive test-ing has been carried out on the basicingredient in the NOVA system, thebase fluid.

Details of, and results from, thetesting procedures for eye and skinirritation are available upon request.

A significant safety benefit pro-vided by the NOVA products are highflash points. This is confirmed bythe results of a study to detect andanalyze the vapors emitted by thebase fluids at different tempera-tures. The reduction in vapors hasimproved the work environment,especially in enclosed areas aroundshale shakers and mud pits.

M-I SWACO supports theNOVA line with completeenvironmental testing andanalytical servicesM-I SWACO confirms the environ-mental acceptability and regulatorycompliance of its products. Wemaintain an environmental divi-sion within our R&D departmentsin Houston and Aberdeen and havethe ability to run all tests for U.S.protocols within our own facilities.An in-house analytical departmentcan supply further tests, includinggas chromatograph/mass spectrom-eter for evaluating fluid samples forearly signs of contamination.

Extensive screening and analysisof synthetic-base fluids has madeM-I SWACO a leader in understand-ing environmental issues, a func-tion of developing technologies thatoptimizes drilling performance andminimizes environmental impact.Among the environmental serviceswith which we support our NOVA

line are: coordinating researchsamples, conducting seabed impactstudies, developing appropriateprotocols, interfacing with gov-ernment officials and providingonsite monitoring.

Skilled engineers and full com-puter support ensure high produc-tivity on your well. It takes highlytrained drilling-fluid engineers tosupport the exceptional NOVA line.In addition to the extensive trainingin drilling fluids and our advancedprograms, our engineers receivein-depth training in running NOVA

systems, including the environmen-tal and QHSE aspects of the systems.

We support our rigsite engineerswith local, area technical servicessupervisors and a technical servicesgroup working at our R&D facilities.This critical well support group offield and staff engineers has at itsdisposal some of the most advancedsoftware available.

MUDVOL* is a program used on adaily basis to track any losses ofNOVA system fluids while drillingand to provide information aboutthe volume of fluid discharged intothe sea. By analyzing the resultsfrom MUDVOL, M-I SWACO engi-neers can detect areas where fluidloses can be reduced, saving money.

VIRTUAL HYDRAULICS* is propri-etary software that provides cal-culations for dynamic downholeconditions involving temperatureand pressure specifically for NOVA

systems. Our engineers use it todetermine pressure drops, equiva-lent circulating densities, stand-pipe pressures and more. Thisinformation is extremely valuablewhen planning well hydraulics tominimize losses in areas of lowfracture gradients.

Supporting our field engineersis the most extensive drilling-fluidsplant and warehouse network inthe industry. This distribution net-work ensures that M-I SWACO cus-tomers have access to the NOVA lineof fluids 24/7.

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PARALAND

The issues with conventionalinvert-emulsion fluidsExternal phase. Typically diesel ormineral oils, these materials onlypartially and slowly degrade, leavingbehind toxic, degradation-resistantwaste that can pose a long-termliability for disposal.

Emulsifiers. Typically thesematerials only partially and slowlydegrade leaving behind toxic,degradation-resistant waste.

Internal phase. Typically calciumchloride, which provides high levelsof conductivity to any waste andinhibits plant growth.

Weight material. Typically barite,non-toxic in itself, which can besubstituted with an improvedweight material that can promotesite recovery.

Other components. Typically lime,organoclays and filtration-controladditives, the latter materials canbe slow to degrade leaving behindtoxic, degradation-resistant waste.

An entire system engineeredto reduce environmentalliabilityThe PARALAND system design incor-porates ready biodegradability andlow terrestrial toxicity into all ofits organic components. In addition,the inorganic components aredesigned to minimize conductivityand enhance plant growth. All ofthis is accomplished while maintain-ing the high-performance character-istics of an invert-emulsion fluid.

16

The non-aqueous system designed to deliver outstanding performance coupled with unsurpassed environmental excellence


Extended-reach and complex wellsboth on land and offshore wheremaximum environmental protec-tion is desired.

� P R O B L E M S

Conventional invert-emulsion fluidsexhibit both slow and incompletebiodegradation, as well as compo-nent toxicity, requiring expensiveand lengthy treatments to permitthe disposal of contaminated drillcuttings onshore.


The PARALAND system has beendesigned with environmental pro-tection in mind. The system com-ponents are biodegradable and oflow toxicity, with an internal phasewhich provides nutrients for plantgrowth. Coupled with a designedtreatment method, the systemminimizes environmental risk.


With its unique environmentallyacceptable design, the PARALAND

system not only improves drillingefficiency as a high-performance,invert-emulsion fluid, but alsoreduces the cost and footprint fordisposal of contaminated cuttings.


The PARALAND system, designedspecifically for environmental excel-lence, minimizes risk and cost byproviding various options for rapidand complete treatment to meetsafe-disposal standards. The systemtreatment can be designed to con-vert drill cuttings into an agricultur-ally acceptable byproduct, resultingin a unique zero-waste treatment.

Product Concentration

PARALAND* B 45 – 85%

SUREMUL* 6 – 8 lb/bbl

SUREWET* 1 – 3 lb/bbl

Lime 3 – 6 lb/bbl

VG-PLUS* 5 – 8 lb/bbl

Water 5 – 30%

K-52* 5 – 45 lb/bbl

Hematite As needed

Typical Formulations

Multiple treatment optionsensure minimal environmental riskA wide range of efficient techniquescan be used to treat the PARALAND

system to either meet local disposalregulations or to convert drill cut-tings into a useful byproduct whichcan be utilized as a topsoil or a fer-tilizer, in a true beneficial-reuse,zero-waste environmental scenario.Landfarming, biopiling, compost-ing, bioreacting and vermicultureare all suitable treatment tech-niques for PARALAND drill cuttings.With efficient composting andvermiculture, these cuttings canbe beneficially reused as a soil-enhancing additive.

The use of PARALAND allows fastertreatments with less dilution addi-tives than conventional invert flu-ids, resulting in lower treatmentcosts and less environmental risk.

Field results deliverperformance promises from laboratoryIn the field, PARALAND has con-sistently exceeded performanceexpectations with high rates ofpenetration, low dilution rates andhigh levels of contamination toler-ance. Mud weights from 7.5 lb/gal(0.9 kg/L) to 16 lb/gal (1.92 kg/L)have been easily achieved withideal rheological and filtrationproperties. The system is easily

and economically maintained withactual total fluid-cost reductions ofas much as 30% below estimate.

The PARALAND system has beenused in various zero-waste opera-tions. In New Zealand, PARALAND cut-tings were used as a food source forworms in a local vermiculture farm,converting the cuttings into vermi-cast fertilizer. In Colorado, PARALAND

cuttings were co-composted withstraw, bark and sand to provide atopsoil for reseeding the drillsite.

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Features• High-performance,

invert-emulsion system

• Readily engineered andmaintained

• Biodegradable organiccomponents

• All components lowterrestrial toxicity

• Variety of compatibletreatment options

Benefits• Optimized drilling performance

• Low dilution rates

• Minimum environmentalexposure

• Lower well costs

• Beneficial reuse of cuttings

• Zero-waste option

RHELIANT


Deepwater, extended-reach andother technically demanding wells.

� P R O B L E M S

Adjusting the rheological propertiesof conventional synthetic-base drill-ing fluids to deal with changingtemperatures and other well condi-tions can lead to poor hole cleaning,excessive Equivalent CirculatingDensities (ECDs), barite sag andlost circulation.


The constant rheology of theuniquely engineered RHELIANT*system opens the door for moreefficient, trouble-free and cost-effective drilling by improving holecleaning and minimizing barite sag,pressure spikes, high gel strengthsand other problems that resultwhen balancing ECD values.


With its flat rheological profile, theRHELIANT system is unsurpassed inreducing fluid losses in challengingdownhole environments. The result-ant higher drilling efficiency andminimized formation damage fur-ther help to reduce total well costs.


The RHELIANT system requires lessdilution, further optimizing its envi-ronmental advantages. The system isa flat-rheology invert that can be for-mulated as a synthetic-base systemfor offshore-discharge compliance.

18

The non-aqueous system with the flat rheology you can trust to reduce expensive mud losses and protect your AFE

ECD Problem A: In deepwater, thesurface rheology must be reducedwhen encountering cold tempera-tures to offset negative ECD effects.

ECD Problem B: Adjusting the rhe-ology upwards to compensate forhigher downhole temperatures andpressure can lead to excessive ECDvalues and gel strengths.

The RHELIANT Solution: With its flatrheology, this new-generation sys-tem maintains consistent fluidproperties that are independent oftemperature and pressure. It main-tains constant 150° F (65.5° C) prop-erties even when confrontingtemperatures as low as 40° F (4.4° C).You can drill with ECDs lower than,or equal to, conventional invert sys-tems while encountering fewerdrilling problems and successfullyavoiding the loss of whole mud.

RHELIANT System vs Conventional SBM35 YP (lb/100 ft2)

30

25

20

15

50° 70° 90° 110° 130° 150° 170°

10

Temperature (° F)

Conventional SBM RHELIANT system

The practical side of a flat rheological profile

An entire system engineeredto reduce dilution and costsThe RHELIANT system’s lower claycontent, fit-for-purpose viscosifiers,newly developed emulsifiers, rheol-ogy modifiers and adaptability todifferent base fluids yield a high-performance system that is cost-effective yet easy to maintain.

Field results that deliver onthe promise of the laboratoryIn the field, the RHELIANT systemhas shown performance character-istics far superior to those of anyconventional synthetic-base andother invert drilling fluids in deep-water applications.

• ROP as much as 20 ft/hr (6.1 m/hr)faster than typical synthetic-base systems

• On-bottom drilling time reducedby as much as 24 hrs per interval

• Reduced mud losses, less dilutionand improved displacementcharacteristics

• Balanced yield point delivershigher penetration rates, vastlyimproved cuttings-transportand considerable savings inhole-conditioning time

RHELIANT technology builds on the NOVAPLUSsystem’s successNo name is more synonymouswith synthetic-base drilling fluidsthan the widely accepted NOVAPLUS*system. Long the system of choicefor the deepwater and similarlychallenging environments, thisaward-winning system set thestandard for balancing cost-effective performance withenvironmental efficiency.

While just as robust as its fore-runner, the RHELIANT system’seasier-on-the-AFE formulationallows it to deliver value-addedperformance that no conventionalsynthetic-base or other invertdrilling fluids can match.

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Minimized Pressure Surges1400 Pump output (gpm) ECD (lb/gal) 11.5

11.4

11.3

11.25

1200

1000

800

600

400

200

4:07:41 4:10:34 4:13:26 4:16:19 4:19:12 4:24:584:22:05

0

Time

Flow rate ECD

11.45

11.35

12,800

13,800

14,800

15,800

16,800

17,800

18,800

19,800

20,800

21,800

14,000

15,000

16,000

17,000

18,000

19,000

20,000

21,00012.3 12.7 13.1 13.5 13.9 14.3 12.5 13 13.5 14

0.5 lb/gal

728 gpm

0.4 lb/gal

770 gpm

SBM 12∏-in. PWD (lb/gal)

RHELIANT 11∑-in. PWD (lb/gal)

PWD MW (in.)

RHELIANT Field Data Well B:PWD Comparison with Direct Offset

RHELIANT System vs Conventional SBMBarite Sag Performance12.9 Sag flow loop test, NOVAPLUS and RHELIANT systems

12.8

12.7

12.6

0 50 100 150 200 250

12.5

Time, min

NOVAPLUS system RHELIANT system

Now, manage ECD without sacrificing hole cleaning or promoting barite sag

The RHELIANT system also has demon-strated its capacity to eliminate pressurespikes on connections. During the staticperiod, the high gel strengths that candevelop in conventional systems, espe-cially at low temperatures, can causeexcessive pressures to develop when thepumps are restarted, creating the potentialfor a formation breakdown.

The RHELIANT system’s low clay contentand flat rheology profile ensure minimumbuildup of gels, effectively eliminatingthese pressure surges seen with otherinvert drilling fluids.

The RHELIANT system’s superior cuttings transportation properties translate into smootherECD profiles, reduced incidents of barite sag and dramatically improved hole cleaning. And,since the rate of removal keeps pace with the cuttings generated, the drill solids will not accu-mulate in the annulus and increase the ECD values. The system’s constant yield point ensuresefficient hole cleaning and fewer packoffs.

Not only is the RHELIANT system ideal for the challenging deepwater environment, it hasalso yielded tremendous benefits in any application where superior ECD management isneeded to reduce the risk of lost circulation.

SAGDRIL


Wells drilling in the Athabasca tarsands and in any area where SteamAssisted Gravity Drainage (SAGD) isused to drill for, and produce, crudeoil from bitumen deposits.

� P R O B L E M S

The sticky bitumen clings to bits,BHAs, drill pipe and shaker screens,and the wellbore can erode easilyif the drilling fluid is too hot or con-tains critical amounts of solvents.


The water-base SAGDRIL* drilling-fluid system resists bitumen accre-tion and screen blinding whilekeeping the wellbore clean andintact for tight build radii andextended-reach horizontal sections.


The SAGDRIL system significantlyreduces drilling time and expenseby promoting faster, cleaner drilling;by maintaining wellbore integrityand by significantly reducingcleanup costs.


The water-base SAGDRIL systemreduces both solid and liquid drillingwaste streams, and we can employthe SAGDRIL tar-sand cuttingscleaner to strip tar from drilledsolids for mix-bury-cover onsite.

20

The drilling-fluid system that keeps you moving ahead, even in sticky tar sand

Features• INTEGRATED FLUIDS ENGINEERING

(IFE) combined with latest-generation SAGD drilling fluid

• Minimizes fluid impact onbitumen and cleans cuttingsat surface

• Dual tar control through TARLIFT*and TARSURF*

• Excellent hole cleaning andsuspension

• Separates and cleans differentwaste streams

Benefits• New approach for drilling and

drilling waste management

• Mud cooler not needed (flowlinetemperature >35° C [95° F] mayrequire cooling)

• Minimizes hole washout %

• Minimizes waste generation

• Liner run without incidents

• Easy to engineer

• No cuttings beds formed

• Maximizes ROP, savesdrilling time

Gra

ph

ic c

ourt

esy

of S

ton

ehen

ge P

rod

uct

ion

s, In

c.

A great deal of a Steam AssistedGravity Drainage (SAGD) program’ssuccess depends upon finding ahighly specialized drilling fluid thatwill keep the hole clean, withoutwellbore erosion, for tight-buildradii and extended-reach, horizon-tal sections; that will keep the bitand drillstring clean to minimizebitumen-accretion problems; andthat will prevent screen blindingat the shale shakers. Add to thatthe need for an environmentallycompatible formulation that alsoreduces the amount of drillingwaste, and the challenge to findthe right drilling-fluid system iseven greater.

The SAGDRIL system givesyou exactly what you need for this demanding workM-I SWACO developed the SAGDRIL

system to address the specific prob-lems unique to drilling high build-angles and long-reach horizontalsections through the tar sands. Thesystem incorporates a combinationof surfactants and solvents, eachwith a specific function. Extensivelaboratory testing of several solventand surfactant products resultedin the selection of two products,TARLIFT and TARSURF, for accretioncontrol. These products, working

in conjunction with water-wettingsurfactants effectively control well-bore erosion by forming a stableemulsion of the solvents so theirinteraction with the wellbore canbe reduced.

The result of M-I SWACO research,development and field testing is aproven system that delivers the fea-tures which help you get more pro-duction from the tar sands at alower cost:

• A water-base drilling fluid thatrelies on a strong water-wettingagent to minimize accretion ofthe sticky tar sands on the bit anddrillstring while it minimizesshaker-screen blinding

• Oil-wetting surfactants to encap-sulate tarry cuttings and promotetheir effective removal by theshakers and other solids-controlequipment such as centrifuges

• A rheological profile optimizedfor minimal wellbore erosion

• Rheology that ensures optimumhole conditions while drillingand running casing and pro-duction liners

• Onsite fluids engineers whomonitor the system’s Low-Shear-Rate Viscosity (LSRV) witha Brookfield viscometer

The SAGDRIL system’s stable wellbore helps youbeyond just drillingAnother area where the SAGDRIL

system helps your operation runmore smoothly is in running casingand liners. High operating temper-atures, thermal expansion andhigh stress levels in the casingand cement sheath are facts of lifein SAGD drilling. Add to that theabsolute requirement that an excel-lent pipe/cement and cement/formation bond be accomplishedthroughout the intermediate cas-ing, and you have quite a challengefor any drilling fluid. And that’s pre-cisely why the SAGDRIL system isn’tjust any drilling fluid. It helps youachieve your running and cement-ing goals by ensuring maximumlubricity while running the inter-mediate casing, and it aids increating a better cement bond bydelivering an in-gauge wellbore.

An aid to responsible drillingwaste management practicesM-I SWACO has formulated theSAGD system to address the specificproblem areas of accretion, shaker-screen blinding and wellbore ero-sion. A reduction in accretionand shaker-screen blinding haveresulted in a significant increasein shaker-screen life and a sharpdecrease in both fluid dilution anddrilling waste disposal costs. Bycontrolling wellbore erosion, thesystem further reduces the amountof drilling waste generated.

SAGDRIL wells have realized sig-nificant savings in disposal costs ofboth solid and liquid drilling waste.They have also seen a significantreduction in solids-control costs andoverall project costs.

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In a laboratory test to simulate hole ero-sion in various drilling fluids, techniciansrotated calibrated tar-sand cores at con-trolled temperatures and rotating speedsin solvent/xanthan gum formulations orSAGDRIL fluid. Periodically, the techniciansmeasured the cores to check for erosion.The solvent/xanthan gum formulationswere more aggressive, causing higher ero-sion, while the SAGDRIL fluid proved to bethe least aggressive.

0.5 Reduction in diameter (mm)

0

–0.5

–1

–1.5

–2

–2.5

–3

0 20 40 60 80 100 120 140 160 180 200

Time, min

Differential Rotor Decay

SAGDRIL fluidSolvent-base System ASolvent-base System BSolvent-base System C

Compared to wells drilled with traditionalsolvent-base systems, SAGDRIL wells haverealized significant savings in disposal costsof both solid and liquid drilling waste. Theyhave also seen a significant reduction insolids-control costs and overall project costs.

400 tonnes

350

300

250

200

150

100

50

0

Drilling Waste

Solvent/xanthan gum systemSAGDRIL system

SILDRIL


Onshore and offshore wells, includ-ing vertical and high-angle, drillingthrough highly reactive formationswhere an invert system would berequired but where environmentalrestrictions preclude the use of oil-base systems.

� P R O B L E M S

Many onshore, offshore and deep-water wells require highly inhibitivedrilling-fluid systems but are locatedin areas subject to strict environ-mental regulations.


The SILDRIL* system uses silicatetechnology to inhibit reactive clayswhile offering the environmentalbenefits of a water-base formulation.


This one, versatile system deliversoptimum inhibition characteris-tics, high penetration rates,decreased trouble time, superiorwellbore integrity and superbsolids-removal performance.


In the field, the SILDRIL system hasproven itself with low dilution rates,a full complement of non-toxic prod-ucts and safe-handling characteristics.

SILDRIL: The one system foroptimum shale inhibition andenvironmental complianceThis uniquely formulated systemcapitalizes on the very latest insilicate technology to give youperformance approaching thatof oil-base mud but with the envi-ronmental acceptability of a water-base fluid. This one system deliversoptimum inhibition characteristics,high penetration rates, decreasedtrouble time, superior wellboreintegrity and superb solids-removalperformance — all with minimalenvironmental impact.

It’s hard to match the shale inhibition of the SILDRIL systemThe SILDRIL system achieves itssuperior inhibition through athreefold approach:

• Direct chemical bonding of thesilicate polymers to drill cuttingsand formation surfaces

• Precipitation of the silicate withdivalent ions

• Silicate polymerization thatresults in complex, inorganicpolymer structures that reactwith the shale surfacesThe system generates highly

competent, inhibited cuttings thatcontribute to optimum perform-ance of the solids-control equip-ment and greatly enhancedformation evaluation. By dramati-cally reducing solids contamination,the SILDRIL system reduces dilutionrates and the costs associated withdrilling waste management. Fieldexperience has shown the solids-control efficiency of the systemcan compare very favorably tothat achieved with typical invert-emulsion fluids.

22

The adaptable silicate fluid system with the proven inhibition of an invert-emulsion fluid

After treatment: In the same formation,SILDRIL produces a high degree of cuttingsintegrity.

Before SILDRIL treatment: Cuttings froma reactive formation drilled with aconventional KCl polymer fluid.

Fewer components give you more flexibilityThe relatively small number ofcomponents that comprise thenon-dispersed SILDRIL systemprovide a great deal of flexibilityin matching the system to theparticular application. Fewerproducts also mean ease of main-tenance, simpler logistics andlower total fluid costs. The versa-tile SILDRIL system is compatiblewith a variety of inorganic saltsthat can be added to enhanceinhibition and help meet specificenvironmental regulations.

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Features• Outstanding inhibition

• Low toxicity

• Applicable for deepwater

• Minimum number ofcomponents

• Highly flexible fluidparameters

Benefits• High penetration rates

• Optimum solids removal

• Low dilution rates and superbdrilling waste control

• Excellent cuttings integrityand stable wellbores

• In-gauge holes

200 400 600 800 1,000 1,200 1,400100

Swellmeter Test35 Swelling (%)

30

25

20

15

10

5

0

–5

Time (min)

Low pH dispersed

SILDRIL

DI water/XC

KCl/glycol

Shale Recovery100 Shale recovery (%)

90

80

70

60

50

40

30

20

10

0

FW/polymer

NaCl/PHPA

KCl/glycol/PHPA

SILDRIL Oil-basemud

Si

Si

O

OH

H

Clay platelets

Non-clay particles

Filter-cake deposition

Physical and chemicalbarrier toinvasion

For systems formulated with SILDRIL, primary inhibition is achieved with the addition of aunique 2:6-ratio silicate. Polymerization of the higher-ratio silicate monomer effectivelyprovides a physical and chemical barrier to filtrate and particle invasion.

ULTRADRIL


Deepwater and other offshore andonshore projects in environmentallysensitive areas characterized byhighly reactive shales.

� P R O B L E M S

Drilling in highly reactive shalescalls for a high-performance fluidwith excellent inhibition charac-teristics. Reducing drilling wastemanagement costs, as well ascomplying with environmentalregulations, virtually dictate theuse of a water-base fluid.


The water-base ULTRADRIL* systeminhibits highly reactive shales andstabilizes wellbores while promot-ing hole cleaning and reducing clay/gumbo accretion and bit balling.


The system’s ability to promotewellbore stability and high Ratesof Penetration (ROP) saves valuablerig time. Its lower dilution require-ments, lower waste volumes andrecyclability, even after drilling longintervals of highly reactive forma-tions, significantly reduce drillingwaste management and fluid costs.


The excellent drilling waste man-agement characteristics of the sys-tem — less dilution, lower wastevolumes and excellent recyclability— as well as its water-base formula-tion, make the system environmen-tally acceptable in virtually anydrilling area.

24

The water-base system that helps you achieve your drilling and environmental goals through an exclusive, triple-inhibition approach

Features• High chemical stabilization

• Low dilution, low toxicity

• Viable alternative toOBM/SBM performance

• Easy to build and maintain

• Anti-accretion agent

Benefits• Optimizes inhibition


• Deepwater alternative

• Reduces costs

• Increases drilling rates

Comparative Inhibition: GOM Shales100 Moisture and recovery (%)

90

80

70

60

50

40

30

20

10

0

Moisture Recovery

20% NaCl/PHPA ULTRADRIL

(20% NaCl)Synthetic OBM

Reactive-Clay Hydration120 Hydration (%)

100

80

60

40

20

0

Gel/LignosulphonateKCl/PHPACaCl2/PolymerSeawater/glycol/PHPAKCl/glycol/PHPA

ULTRADRIL (Seawater only)ULTRADRIL (20% NaCl)ULTRADRIL (KCl)Invert OBM

–20

In the field, the ULTRADRIL system delivers results comparable to oil-base systems

The results of a 16-hr test of various drillingfluids on samples of reactive clay. Three for-mulations of ULTRADRIL all had lower clayhydration than that of conventional water-base drilling fluids. Through highly reac-tive intervals, ROPs have averaged up to150 ft/hr (45.7 m/hr), delivering cuttingsthat exhibited the excellent integrityexpected if drilling with an oil-base system.

The inhibitive capability of the ULTRADRIL

system surpasses that of a conventionalwater-base system and nearly matchesthat of a invert-emulsion drilling fluid. Thesystem’s low moisture content results indrier, firmer drilled cuttings. Withdensities up to 11.3 lb/gal (1.4 kg/L),ULTRADRIL systems have successfullydrilled long sections of highly reactivegumbo shales and graded out very high interms of stability, inhibition, screenabilityand maintenance. In sections typicallydrilled with CaCl2 or 20% NaCl/PHPAwater-base fluids, the high-performanceULTRADRIL system eliminated the shaker-screen binding, rapid encapsulator deple-tion and high-dilution rates that hadseverely impacted wells drilled withits more traditional counterparts.

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Triple inhibition is your key to faster drilling and better drilling waste management

Inhibition Action #1: Superior Clay Inhibition

Inhibition Action #3: Protected Metal Surfaces

Conventional water-basesystems do not have the highlyinhibitive quality of the ULTRADRIL

system, so shales are prone tosloughing and swelling that cancause stuck pipe, and washouts.

The first feature of the ULTRADRIL

system’s triple-inhibitionapproach is its ability to inhibitthe most reactive shales and pro-vide superb wellbore stability,even in the most reactive clays.

Inhibition Action #2: Cuttings Encapsulation

Conventional fluids allowgumbo buildup and bit ballingto occur, slowing down theentire drilling process.

The third feature of the system’striple-inhibition approach is itsability to coat the bit, BHA anddrill pipe with an accretion-inhibitive coating. The cuttingstructure stays clean and effec-tive, resulting in less bit ballingand higher ROP.

With conventional systems,drilling is slower, the cuttingsare smaller, and there is not thesame, high level of inhibitionas we have with the ULTRADRIL

system. Many of the cuttingsbreak apart and disperse, creat-ing fines that not only requiredilution of the system but thatsettle in the hole and can pack-off the bit. Other particulatesswell and agglomerate intolarge masses that adhere to thebit, drill pipe and BottomholeAssembly (BHA).

The second feature of theULTRADRIL system’s triple-inhibition approach is the wayit encapsulates cuttings witha thin polymer coating thatvirtually eliminates shale dis-persion. This, in turn, reducesthe need for dilution and thedisposal of large fluid volumes.Because it is a high-performancesystem, the well can be drilledat higher ROP, producing largercuttings which reach the shakerfirm and intact.

The high-performance,water-base system that’seasy to build and maintainFor all of the capabilities it provides,the ULTRADRIL system is easy tobuild and maintain on location.The base fluid can be anythingfrom freshwater to potassium chlo-ride, to sodium chloride and, insome instances, seawater. The fluidis extremely clean, it does not use

any bentonite in its makeup, andits inhibitive character means a verylow colloidal content. Its propertiescan be easily maintained, even inthe presence of contaminants suchas cement and common drilling-fluid additives. And the ULTRADRIL

system provides its high degreeof inhibition without the use ofperformance-limiting salts suchas calcium chloride.

To ensure top performance inthe field, the ULTRADRIL system canbe tested for proper concentrations,using simple, common tests to con-firm product-volume percentage.The basic system consists of threemain components: ULTRAHIB*,ULTRACAP* and ULTRAFREE*.

WARP Advanced Fluids Technology


Onshore and offshore wells wheretight control must be maintainedover fluid weights, rheologies, ECDsand barite sag.

� P R O B L E M S

Extended-reach, HTHP andsmall-bore drilling with narrowmud-weight windows, requiresufficiently high viscosity to sus-pend barite, but not so high thatECD management is compromised.For high-density completion andworkover fluids, the choices havebeen either conventionally weightedfluids with potential settling prob-lems or high-density, very costly,solids-free brines.


The micron-size particles used inWARP* Advanced Fluids Technologyfrom M-I SWACO can be used inmany water-base and invert drill-ing and completion-fluid systemsto increase density without com-promising rheology or promotingparticle settlement.


For faster drilling, WARP FluidsTechnology reduces torque, dragand particle settlement. For com-pletions and workovers, WARP

Advanced Fluids Technology ismore cost-effective than somehigh-density brine systems.


Finer shaker screens can be used,improving solids-removal efficiencyand reducing overall dilution anddischarge volumes. Completionfluids formulated with WARP FluidsTechnology are cost-effective andenvironmentally more acceptablethan many high-density, clear-brine systems.

Every manual on drilling-fluidengineering tells us that micron-size particles are detrimental todrilling fluids. With too many finesin the fluid, the rheology increases,often with detrimental effects. Thetechnology behind WARP FluidsTechnology lies in grinding theweighting material to extremelyfine particle sizes — from 0.1 to 10microns, with the majority measur-ing 1 micron. By pre-treating theseextremely fine particles, there is norheology increase.

Now imagine what WARP FluidsTechnology micro-particles cando for your water- and oil-basedrilling, reservoir drill-in andcompletion fluids:

• Low-rheology, high-density fluids

• Weight materials that do not set-tle, even with very low rheologies

• Better management of ECDs

• Ability to use ultra-fine shakerscreens that improve solids-removal efficiency withoutsacrificing valuable products

• Fluids that reduce environmentalimpact

• The ability to formulate oil-basecompletion fluids

26

The specially treated microparticles are your assurance of higher mud weights with lower rheologies for critical applications

Features• Micron-size weighting agent

• Lower fluid viscosities

• Reduces sag

• Improves filtration properties

• Excellent solids-separationefficiency

• Greater hole cleaning

• Reduces torque and drag


• Reduces oil on cuttings

Benefits• Ideal for extended-reach and

horizontal drilling, through-tubing drilling, coiled-tubingdrilling and HTHP wells

• Excellent for high-density com-pletion and workover fluids, killfluids, logging and testing fluids,packer fluids, and high-densityreservoir drill-in fluids

• Safer, more secure well control

• Less dilution and reduceddischarge to the environment

• Non-damaging to formation

• Finer-mesh shaker screenscan be used

The micron-size weighting materialsdeveloped for WARP Fluids Technologyare much smaller than standard APIbarite, allowing them to flow easilythrough 300-mesh shaker screens, sothat virtually 100% of drilled cuttingscan be removed on the first pass. Theirultra-small size, combined with theirproprietary treatment, ensures thatfluids formulated with WARP FluidsTechnology do not settle or sag.

API barite 75 µm max size

WARP particle < 1µm

API barite

d50 ~25 µm

When the stakes are high,WARP Fluids Technologykeeps rheologies — and problems — downThe low rheological profile of afluid enhanced with WARP FluidsTechnology actually improves holecleaning by effectively removingany cuttings buildup on the lowerside of the hole.

In addition, the low rheologiesof WARP Fluids Technology clearthe way for better control and man-agement of equivalent circulatingdensity, which is especially criticalwhen a very narrow margin existsbetween the pore and fracture pres-sure. In fact, ECDs are actuallyreduced and pump pressures arelower with WARP Fluids Technology,which also reduce swab and surgepressures while tripping andrunning casing.

These and other advantagesmake WARP Fluids Technologythe ultimate choice for a widearray of critical drilling applica-tions, including:

• Horizontal and extended-reach wells

• Coiled-tubing drilling

• Reservoir drill-in fluids

• Wells with narrow operating windows

• HTHP wells

• Inhibitive fluids

• Wells with risk of barite sag

• Drilling waste management

For completion fluids, WARP Fluids Technology wins out over conventionalweighting agentsAbove 13 lb/gal (1.6 kg/L), solids-free completion and workover fluidsare limited to mixed calcium chlo-ride, calcium bromide and zincbromide, or mixed potassium andcesium formate brines. The onlyother alternatives are speciallyformulated barite- or calcium-carbonate-weighted fluids thatare prone to sag and settlement.

Now there is WARP AdvancedFluids Technology from M-I SWACOin which the ultra-fine particlesbehave similar to solids-free fluidswith no settlement, minimal reser-voir damage and complete flow-back through gravel pack andsand-screen completions — all withno environmental or disposal haz-ards. In addition, you now have theoption of high-density, oil-basecompletion fluids for a complete oil-base drilling and completion-fluidstrain, minimizing spacers and thepotential for emulsion blocks.

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The Clear Advantages of WARP Advanced Fluids Technology Over Conventional Weighting Materials

Conventional Weighting Materials

API Barite

• Higher rheologies to control baritesettlement and sag

• Problematic ECD management in sec-tions with narrow pressure windows

• Horsepower limitations in extreme,horizontal wells

WARP Advanced Fluids Technology

• Near-zero sag and settlement ininclined and horizontal sections

• Fluid rheology may be low andindependent of sag

• Better management of ECD and controlof losses. No mud weight variation.

• Lower drillstring torque deliveringsuperior bit horsepower

• All-in-one drilling and completion fluid

• Lower dilution factors and lowerwell costs

• Reduced discharge volumes andenvironmental impact

Dri

llin

g Fl

uid

s

Graded Calcium Carbonate

• Mud weights limited at higherdensities

• Limited ECD management andrheology control at higher densities

• Lower rheologies for the same density

• Better management of ECD andcontrol of losses

• Complete flowback throughsand screens

Res

ervo

ir

Dri

ll-I

n F

luid

s

Solids Free Calcium and Zinc Bromide or Cesium Formate brines

• High costs

• Personnel safety and handling concerns

• Disposal issues

• Environmental concerns

• No heavy metals

• No environmental concerns

• No particle settlement or sag

• No personnel safety or handling issues

• Easy cleanup and disposal

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uid

s

DURATHERM

The DURATHERM* system is a low-colloid, contaminant-resistantwater-base fluid designed for high-temperature drilling. It providesgood inhibition, minimizes claymigration and swelling, and isstable to >500° F (260° C) ambient,with densities from 9 to 20 lb/gal(1.1 to 2.4 kg/L), and at depths from5,000 to 25,000 ft (1,524 to 7,620 m).High ROPs, improved solids-removalcapability and minimal formationdamage help reduce drilling costs,while its aqueous-base chemistrygives it environmental advantagesover oil-base systems. The systemis especially useful when there areconcerns about formation evalua-tion, kick detection or lost circula-tion. It may be formulated withfreshwater or seawater, and non-flocculating salts may be incorpo-rated for inhibition.

Because the DURATHERM systemevolved from formulations used aspacker fluids, where long-term rhe-ological stability is necessary, thislow-colloid system remains stablein the presence of acid gases, salts,and drill solids. The system’s sta-bility can be maintained by mini-mizing the concentration of activesolids, and using polymeric materi-als for viscosity requirements. Thisreduces gelation caused by the floc-culation of active clays at high tem-perature, as well as the viscosityincrease resulting from saltwaterflows, acid gases, or salt.

Generally, treatments with lig-nosulfonate (SPERSENE*) should bediscontinued at bottomhole tem-peratures above 325° F (163° C).Solids-control equipment — shakers,hydroclones and centrifuges — mustbe operated as efficiently as possibleto minimize maintenance costs.

System productsXP-20* potassium chrome lignitematerial is used as a viscosity-stabilizing agent and to controlfluid loss in the DURATHERM system.

This product continues to functionas designed in fluids that encounterformation temperatures greater than500° F (260° C). It is the primarytreating agent in the DURATHERM

system, and it provides potassiumions for shale inhibition.

RESINEX* resin polymer is usedfor HTHP fluid-loss reduction bydecreasing filter-cake permeability,and it contributes to fluid stabiliza-tion. Field results have demon-strated the utility of RESINEX inminimizing formation damage.RESINEX is used in conjunction withXP-20 to control these properties inthe DURATHERM system.

TANNATHIN* is a lignitic materialthat works with RESINEX to reduceHTHP fluid-loss values and stabilizerheological properties in theDURATHERM system.

Polymers contribute viscosityand API fluid-loss control to theDURATHERM system. Minimizingbentonite concentrations requiresthe use of polymeric materials asviscosifiers. Cellulosic polymersand xanthan gum provide theviscosity required to suspendweigh material and drill solids,and lower API fluid-loss values inthe DURATHERM system.

M-I GEL* may be used for fluid-losscontrol and viscosity in wells withbottomhole temperatures below250° F (121° C). For bottomholetemperatures above 250° F (121° C),M-I GEL must be maintained atlow levels. The primary function ofM-I GEL at these reduced concentra-tions is to help form a thin, dense,low-permeability filter cake.

M-I BAR* and/or FER-OX* are high-density materials with specificgravities of 4.2 and 5.0, respectively.They provide fluid density in theDURATHERM system.

Caustic, lime and gypsum are usedto balance alkalinities and controlthe effects of carbonates/bicarbon-ates on rheological properties. The

basic environment provided byhydroxyl ions aids in tubular corro-sion control and in hydrolyzing mudproducts added at the surface.

Corrosion control and lubrication.

The DURATHERM system is com-patible with selected corrosioncontrol-chemicals and lubricants.The low-solids feature of theDURATHERM system, in conjunctionwith lubricants such as LUBE-167*and EP LUBE*, will reduce bit balling,torque, and drag.

The DURATHERM system as a packer fluidThe DURATHERM system has beenrecognized as a drilling fluid appli-cable in areas of high temperatureand pressure. Due to its physicalcharacteristics it also may be usedas a packer fluid.

The characteristics that make theDURATHERM system an ideal packerfluid are:

• Thermal stability to temperaturesin excess of 500° F (260° C)

• Minimal liquid separationor breakout

• Ability to suspend barite andsolids without settling

• Non-corrosive (when freshwater isused as a base)

• Low static shear strengths

• Quick reversion to fluid stateupon agitationFor corrosion protection,

M-I SWACO recommends that afilming amine corrosion inhibitorsuch as CONQOR* 101 be added tothe packer fluid. One barrel ofCONQOR 101 per 100 bbl of mudusually results in an adequate con-centration of inhibitor. Additionsof 0.2 to 0.5 lb/bbl (0.1 to 0.2 kg/bbl)BACBAN III preservative (bacteri-cide) will prevent the growth ofsulfate-reducing bacteria andfermentation of the mud.

28

ENVIROTHERM

ECOGREEN

The ENVIROTHERM* system is achrome-free, environmentallyadvanced fluid designed for high-temperature drilling. Its low-toxicity,high-temperature stability and min-imal reactive-solids content makeit ideal for high-temperature opera-tions. This environmentally accept-able drilling-fluid system providesgood filtration control and reducestrouble time.

The ENVIROTHERM system isused primarily in the WesternHemisphere and is similar to achrome-free DURATHERM usingTANNATHIN* and SPERSENE CF forrheology control, and RESINEX forfluid-loss control. Freshly preparedmuds have low viscosity, yieldpoints and gels.

These fresh muds should betreated with additional POLYPAC* R

(or DUO-VIS*) to increase the vis-cosity in the pits to prevent baritesettling.

Once drilling begins, the drillsolids accumulate and give thefluid enough rheology to supportweight material.

Other options include polymers forsynthetic viscosity fluid-loss control.

Ester-base chemistry for optimum drilling performance in the mostfragile environmentsWhen you prefer an ester-base sys-tem in order to meet local dischargerequirements without sacrificingthe economic benefits of a high-performance fluid, the ECOGREEN*system is the logical choice.

The true value of the ECOGREEN

system lies in its versatility. It iseasily formulated to address a widerange of drilling requirements,including Extended-Reach Drilling(ERD) and horizontal drilling, anddrill-in fluid applications. The sys-tem produces the penetration ratesconsistent with oil-base muds,while eliminating or dramaticallyreducing the instances of stuck pipe,out-of-gauge holes and unstable

wellbores normally associated withwater-base systems. Its low-lubricitycoefficients dramatically reducetorque and drag, making it particu-larly beneficial in deviated and high-angle wellbores.

From an environmental stand-point, the ECOGREEN system is asynthesized material, and the fatty-acid ester comprising its base fluidcontains no “priority pollutants”and is biodegradable. The system

has passed some of the most rigor-ous toxicity, biodegradation andvapor tests in the industry andhas been approved for dischargein some of the world’s mostrestricted environments.

The ECOGREEN system is alsocompletely reusable after only min-imal treatment, significantly reduc-ing your mud consumption costs.

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Features• Biodegradable

• Synthetic system

• Non-aqueous-fluid system

• Ester chemistry

Benefits• Wellbore stability

• Increases ROP

• Cuttings integrity

• Lubricity

• Hole cleaning

• Permission to discharge

ENVIROVERT

30

The invert drilling-fluid systemthat reduces drilling,completion and disposal costsWith the ENVIROVERT* system, oper-ators now have all the performanceadvantages of a conventionalinvert-emulsion drilling fluid, withthe added benefit of reduced dis-posal costs. The system contains nochlorides, but rather a proprietarycalcium nitrate salt that not onlyinhibits reactive shales, but alsoprovides nitrogen that acceleratesbiodegradation.

The ENVIROVERT system hasbeen shown to significantly reducetorque and drag, making it an idealoption for drilling high-angle orhorizontal wellbores. Its high-temperature stability gives youa dependable system for drillingdeep, hot holes. What’s more, thishighly versatile system has demon-strated its effectiveness as a perfo-rating, completion, spotting andcasing-pack fluid.

ENVIROVERT reducesyour environmental costsand concernsFor a landfarming operation to suc-ceed in its biodegradation activity,one or more supplemental applica-tions of a fertilizer high in nitrogenis necessary. The ENVIROVERT sys-tem gives you a head start by pro-viding the nitrogen required forhydrocarbon-degrading micro-organisms to perform effectivelyin landfarming operations. TheENVIROVERT calcium nitrate salt notonly eliminates the trouble andcosts associated with chlorides, italso facilitates faster biodegrada-tion. In addition, ENVIROVERT meetsNMX-L-162-1996-SCFI specifications.

Features• Invert drilling-fluid system for

water-sensitive formations

• Uses calcium nitrate in placeof calcium chloride

• Excellent torque anddrag reduction

• Prevents lost circulation inlow-pressure zones

Benefits• Eliminates typical chloride

disposal problem

• Promotes faster biodegradation

• Reduces unexpected events

• Also works as a spotting, packerand casing-pack fluid

• Reduces drilling, completionand disposal costs

Water Activity of the ENVIROVERT System1.00 Water activity

0.95

0.90

0.85

0.80

0.75

0.70

0.65

0.60

0.55

Water-phase salinity (% by weight) ENVIROFLOC*

15 20 25 30 35 40 45 50 55 60 65 7010

NOVATEC

K-MAG

Used primarily in the Gulf ofMexico, the K-MAG* system is aninhibitive water-base system thatprovides shale inhibition and well-bore stability while it minimizesbit balling. System benefits includereduced dispersion of drill cuttingsfor easier removal, near-gauge well-bores for better cement jobs, even inwater-sensitive shales, and reducedswelling for wellbore stability.

The K-MAG system is designedto perform most efficiently in fresh-water to seawater-salinity envi-ronments, but the salinity can beincreased to improve shale stabilityand gas-hydrate inhibition whennecessary. The use of a powerfuldispersant, such as lignosulfonate,is usually kept as low as possiblein order to minimize excessive

dispersion of drill solids andwellbore washout.

The system’s popularity hasincreased as the use of synthetic-base fluids in offshore drilling hasbecome more challenging due tomore stringent environmental reg-ulations, biodegradation restric-tions and other environmentalissues. In addition, low fracture gra-dients and narrow ECD windowsoften encountered in deepwateroperations greatly increase the riskof lost circulation, which can drasti-cally increase the cost of the opera-tion. More economical water-basefluids, such as the K-MAG system,with good shale inhibition andeffective ROP enhancement arenow competing with syntheticsin deepwater applications.

NOVATEC PThe NOVATEC* P fatty acid is formu-lated as the primary emulsifier inthe NOVATEC system. NOVATEC Pemulsifier can be used alone toform tight water emulsions in mostsynthetic-fluid systems but is par-ticularly effective when used in con-junction with NOVATEC S additive, asecondary emulsifier and wettingagent for this system.

The NOVATEC P agent contributesto HTHP filtration control, tempera-ture stability and contaminationtolerance of the NOVATEC system byforming a tight, stable emulsion.

NOVATEC SNOVATEC S polyamide is the second-ary emulsifier and wetting additivein the NOVATEC LAO-base system.NOVATEC S emulsifier can be usedalone to form tight water emul-sions in olefin fluids, but is par-ticularly effective when used tocompliment NOVATEC P additive.The product is designed for use inthe NOVATEC system to providetight emulsion stability, HTHPfluid-loss control and strongorganic wetting capability.

When used in combination,NOVATEC S and NOVATEC P emulsifiersreact to form a tight emulsion andimprove the fluid’s resistance to con-tamination and water-wet solids.

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Features and BenefitsNOVATEC P

• Improves emulsion stability

• Functions as secondarywetting agent

• Provides filtration control

• Helps maintain HTHP filtratein a water-free condition

• Improves thermal stabilityand contamination resistanceof the NOVATEC system

NOVATEC S

• Improves oil-wetting andprevents water-wet solids

• Maintains stable invertemulsion and helps preventwater in filtrate

• Improves thermal stabilityand contamination resistanceof the NOVATEC system

• Improves emulsion stability

Features and Benefits• Flexible system can be

formulated to suit drillingenvironment

• Excellent shale inhibitionand wellbore stability

• Minimizes bit balling,improves ROP

• Preserves drill cuttingsfor easier removal

• Tolerates salinity fromfreshwater to seawater levels

• Substitutes for somesynthetics where environ-mental issues are a concern

PARADRIL

PARATHERM/VERSATHERM

32

The PARADRIL* invert-emulsion sys-tem was designed specifically asan alternative to conventional ormineral-oil-base drilling-fluid sys-tems, balancing high performancewith environmental compliance.

The heart of the system isthe paraffinic component which,depending on the application, dis-charge requirements and availabil-ity, can range from synthetic LinearParaffins (LP) to mixed blends ofrefined paraffins. All of the prod-ucts comprising the PARADRIL sys-tem have been formulated to meetlocal discharge requirements.

The true value of the PARADRIL sys-tem lies in its flexibility. Weights canrange from unweighted to 18 lb/gal(2.2 kg/L). The paraffin/water ratioscan range from as low as 50:50 toas high as 95:5, depending on mudweight and solids loading. The sys-tem is formulated as an emulsionin which the paraffinic liquidforms the continuous phase,while a brine solution serves asthe dispersed phase. It is easily for-mulated to address a wide range ofrequirements, including extended-reach, horizontal and reservoirdrill-in applications.

Hydrocarbon monitoring. All toooften, the inability to accuratelymonitor the presence of crude oilin mud returning from the produc-tion zone restricts the use of oil-base drilling fluids. With thePARADRIL system’s linear-paraffinbase fluid, that concern has beeneliminated. The unique chemistryof the PARADRIL SB base fluid gener-ates a very identifiable fingerprint,and GC/MS work has shown thateven in concentrations as low as0.5%, crude oil is still detectablein the system.

The PARATHERM* and VERSATHERM*systems are invert-emulsion systemswith one significant difference intheir formulations. PARATHERM

uses a linear-paraffin base oil,while VERSATHERM employs a low-toxicity mineral oil. Both wereoriginally designed for use in High-Temperature, High-Pressure (HTHP)applications, but can be engineeredfor use in low-temperature wells.It was developed to meet the tech-nical challenges associated withdrilling wells with narrow hydraulicwindows and extended-reach pro-files. The system was designed withthe specific goal of delivering thefollowing qualities:

• Stability at high temperatures

• Reduced high-shear-rate viscosity

• Stable low-shear-rate viscosity

• Reduction in EquivalentCirculating Density (ECD)

• Reduced sag potential

ApplicationsThe PARATHERM system is suit-able for applications with narrowhydraulic windows, regardless of

the expected Bottomhole StaticTemperature (BHST). The first fieldapplication of the PARATHERM

system was in a low-temperature(1,670° F [910° C]), narrow-hydraulic-window well. The well was success-ful due in large part to the lowerrheological properties and associ-ated reduction in ECD obtainablewith the PARATHERM system. Thisapplication confirmed the ability ofthe PARATHERM system to provide afluid with reduced high-shear-rateviscosity compared to conventional

systems, providing a direct benefit inreduced total system pressure loss.

The PARATHERM system hasalso been used successfully todrill Extended-Reach Drilling(ERD) wells.

The VERSATHERM system has beensuccessfully used in HTHP applica-tions. The maximum bottomholestatic temperature the system hasbeen used to drill is slightly above3,560° F (1,960° C). The system hasexhibited very stable properties andlow, non-progressive gel strengths.

Additive Material Function

Linear Paraffin Base fluid Continuous phase

Low-Toxicity Mineral Oil (LTMO) Base fluid Continuous phase

EMI-783 Organophilic clay Viscosifier

Bentone 38 Organophilic clay Viscosifier

VG-SUPREME* Organophilic clay Viscosifier

Lime Calcium hydroxide Alkalinity

SUREMUL* Polyamide Primary emulsifier

SUREWET* Fatty acid Secondary emulsifier

Freshwater Freshwater Internal phase

CaCl2 Calcium chloride Salinity

VERSATROL* Gilsonite Fluid loss

VERSATROL HT Gilsonite Fluid loss

Barite Barium sulfate Density

Typical System Components

POLY-PLUS

TRUDRIL

The POLY-PLUS* system employshigh-molecular-weight polymersand anionic liquid to provide cut-tings encapsulation and shale stabi-lization. It also acts as a viscosifier,friction reducer and flocculantwhile providing some fluid-losscontrol. POLY-PLUS additive canbe used in mud systems rangingfrom low-solids to weighted,utilizing makeup waters fromfresh to saltwater.

• POLY-PLUS additive mud systems.

POLY-PLUS provides excellent cut-tings encapsulation and improvedwellbore stability.

• Clear-water fluids. POLY-PLUS

agent may be used in clear-water,solids-free drilling fluids. POLY-PLUS

polymer increases viscosity andenhances solids removal by floccu-lating the undesired solids. It alsoprovides cuttings encapsulationand improved wellbore stability.

• Low-Solids, Non-Dispersed(LSND) muds. POLY-PLUS

agent is well suited to LSNDsystems. In reduced-bentonitemuds, POLY-PLUS serves as abentonite extender to increaseviscosity, flocculates drill solidsfor more efficient removal,encapsulates cuttings andimproves wellbore stability.

• Weighted muds. POLY-PLUS canbe used in weighted muds forcuttings encapsulation, improvedwellbore stability, secondaryviscosity and to improve filtercake integrity.

• POLY-PLUS sweeps. ViscousPOLY-PLUS sweeps are effectivefor periodic hole cleaning.

The TRUDRIL* system differs from otheroil muds in that it is formulated with-out an internal brine phase. A high-performance organoclay is used togenerate superior rheology and sus-pending properties. Efficient filtrationcontrol is achieved through use of par-ticulates and/or synthetic polymers.The inevitability of incorporationof small quantities of water from thedrilling operation and surface han-dling operations is addressed throughuse of limited treatments with emulsi-fiers and oil-wetting agents, but unlikeconventional invert-emulsion fluids,water content is minimized and istreated as a contaminant rather thana system component.

Experience has shown that over5% by volume of water can be incorpo-rated without any evidence of negativeinteraction with drilled formation orcuttings. At higher water fractions, it isexpedient to address balanced-activityissues and to salt up as appropriate,

treating the fluid as a conventionalinvert. There is no real break-overprocedure to be dealt with, andconversion to an invert is straight-forward. All system componentsare efficient elements of invert-emulsion formulations.

TRUDRIL fluids have been usedin a wide variety of conditionsand environments:

• Base fluids have ranged from crudeand diesel to ultra-low-aromaticmineral oils

• Densities have varied fromunweighted (basically thedensity of the base fluid) toover 18 lb/gal (2.2 kg/L)

• Application is documented at tem-peratures up to ~400° F (204° C)

• Drilling environments have variedfrom critical-angle deepwater wellsto shallow horizontals

The composition of the fluid deliv-ers certain desirable characteristics

and properties, (as compared toinverts) including:

• High YP/PV ratio and superiorsuspending performance

• Lower ECDs

• Efficient hole cleaning

• Reduced gas-hydrate sensitivity

• Lower densities than achievable withinverts. Low-density inverts tend tohave a high aqueous fraction whichfurther limits the ability to achievelow densities

• Reduced concern over water-phasecomposition

• More environmentally competentdischarges i.e., no salt added

• Lower maintenance costs

• Low surfactant content with possiblereservoir implications

• Minimum number of productsmaking engineering simple

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Features and Benefits• Provides excellent cuttings

encapsulation and limitscuttings dispersion

• Provides improvedshale stabilization

• Enhances the removalof drill solids

• Liquid product for easy mixingand rapid yield

• Aids in preventing balling onthe bit, stabilizers and BHA bycoating and lubricating solids

• Improves the lubricity ofmost mud systems, particularlynondispersed muds, when usedin combination with a lubricant

• Can be used to viscosify clear-water and low-solids drilling fluids

VERSACLEAN/VERSADRIL

34

The VERSACLEAN* and VERSADRIL*systems are oil-base fluids formu-lated and engineered to meet anydrilling-fluid requirement. The onlydifference between the two sys-tems is that the VERSACLEAN systemuses a highly refined mineral oilwhile the VERSADRIL system is for-mulated with No. 2 diesel oil as thecontinuous external phase.

Both systems deliver excellentthermal stability for drilling deep,hot holes. Their formulation pro-vides inherent protection againstacid gases, such as CO2 and H2S,as well as corrosion due to thepresence of lime (used as an alka-linity control reagent) in the con-tinuous oil phase. VERSACLEAN andVERSADRIL systems can drill water-soluble formations (anhydrite, gyp-sum, salts and complex salts) withminimum or no hole-washout prob-lems. They provide improved lubric-ity for drilling deviated holes andfor significantly reducing occur-rences of stuck pipe. VERSACLEAN

and VERSADRIL systems minimizedamage to producing formationsthrough the prevention of waterintrusion, thereby eliminating clayswelling which can cause reducedpermeability of the pay zone. Theyalso provide increased rates of pen-etration and ability to drill thick,water-sensitive shale sections withrelative ease, thus providing forgauge hole drilling.

In many cases, oil muds arenot considered, although the drill-ing conditions warrant their use,because of their initial makeupcosts. However, if the overall drillingcosts are considered, the costs

accompanying the use of an oilmud are usually comparable with,or less than, those of a water-basefluid, particularly when most drill-ing problems are eliminated, result-ing in substantial time savings.In addition, both VERSACLEAN

and VERSADRIL oil muds can besalvaged and reused following thedrilling operation.

Features• Low coefficient of friction

• High-temperature stability

• Chemically stable

• Excellent filtration control

Benefits• Maximizes production

• Reduces torque and drag

• In-gauge wellbores

• Optimized ROP

• Stable wellbores

System Base Oil

VERSACLEAN* Mineral oil

VERSADRIL* Diesel

Through-tubing rotary drillingA 972-m (3,189-ft), 149-mm (57⁄8-in.) TTRDsection, inclined at 78° was drilled in one bitrun with a rotary steerable system, PWD andMWD to 5,069 m (16,631 ft) with a 1.6-kg/L(13.2-lb/gal) invert oil-base system incorporatingWARP Fluids Technology.� No mud-weight variations

were measured� ROP were 10% higher than planned� Using 250-mesh shaker screens,

dilution was 50% lower than offsetwells, reducing discharge volumes

� Fluid costs were 18% lowerthan planned

HTHP drillingA 311-mm (121⁄4-in.) section of a high-temperature,high-pressure well was drilled at 60° inclination to5,121 m (16,800 ft), using a 1.8-kg/L (15-lb/gal)invert oil-base system incorporating WARP technology.� The fluid system proved stable to 166° C (331° F)� Improved ECD management resulted in

no losses while drilling or running casing� No mud-weight variations or fill observed

after 82 hr non-circulation� Torque was reduced by 25%� Dilution factors were three times less

than the North Sea average, reducing environmental impact

In extended-reach, HTHP and small-bore drillingwith narrow mud-weight windows, operators

must maintain viscosity high enough tosuspend barite, but not so high as to com-promise ECD management.The micron-size, treated par-ticles in WARP* AdvancedFluids Technology fromM-I SWACO* can be used

in all water- and oil-basedrilling and completion fluid

systems to increase densitywithout compromising rheology

or promoting particle settlement.

High environmental performance as wellFor North Sea drilling operationsusing WARP microparticles as theweighting agent, shakers can bedressed with finer screens, improv-ing drill-solids-removal efficiencyand reducing overall dilutionvolumes. For completions, the

elimination of particle settlement gives WARP FluidsTechnology the advantage as a more cost-effectiveand environmentally acceptable alternative to manyhigh-density, clear-brine systems.

Weight up for success nowJust call your local M-I SWACO representative andask for information and success stories about ourWARP Advanced Fluids Technology. Your next projectcould reap the benefits.

©2005 M-I L.L.C. All rights reserved. *Mark of M-I L.L.C.

The specially treated microparticles are your assurance of higher mudweights with lower rheologies in critical applications

WARP particle (right) compared

to bariteparticle (left)

With WARP Fluids Technology,critical downhole conditions

don’t become critical situations.

WARP SUCCESS STORIES

www.miswaco.com

WWAARRPPAADDVVAANNCCEEDD FFLLUUIIDDSS TTEECCHHNNOOLLOOGGYY

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DIPRO


Onshore and offshore projectsthat will use divalent brines as thecompletion fluid and/or applica-tions where a low-solids, high-density Reservoir Drill-In Fluid(RDF) is required.

� P R O B L E M S

Divalent brines’ incompatibilitywith biopolymers create RDFs thatare less than optimal for hole clean-ing and minimizing EquivalentCirculating Density (ECD). In addi-tion, it has been difficult to removethe filter cake formed by divalent-brine/biopolymer systems, increas-ing cleanup time and costs.


The DIPRO* system can use a varietyof divalent brines for its base fluidand achieves high density withoutloading the system with solids.It creates a thin, impermeablefilter cake and builds Low-Shear-Rate Viscosity (LSRV), withoutproducing high ECDs.


The DIPRO system’s low ECDsreduce costly fluid losses and for-mation damage. The system ishighly compatible with variouscompletion fluids and methods;it can be reused; and its thin filtercake protects the reservoir andcan be produced through virtuallyany completion equipment.


All DIPRO system components areaccepted for use in both the U.S.and North Sea when utilizing anapproved base brine.

36

The system that transforms high-density divalent brines into premium, biopolymer-free reservoir drill-in fluids

The DIPRO system gives you high density, low solids,minimal formation damageand easy cleanup in divalent brines For its base fluids, the DIPRO systemuses the divalent-cation brines andbrine blends — CaCl2, CaBr2, CaCl2/CaBr2, CaBr2/ZnBr2 and CaCl2/CaBr2/ZnBr2 — in the 11.5 to 17.5-lb/gal(1.4 to 2.1-kg/L) density range. Withany of these base brines, the systemuses a unique viscosifier/filtration-control additive in conjunction withproperly sized calcium carbonatebridging agents to build a fluid thatgenerates low filtration rates andproduces a thin filter cake to protectthe reservoir.

The system’s low ECDs help pre-vent excessive invasion of wholemud, especially in formations hav-ing low fracture gradients, such asthose found in deepwater.

Because we can engineer thesystem so precisely, and becauseof its flexible chemistry, DIPRO

can be formulated in densitiesranging from 11.5 to 17.5 lb/gal(1.4 to 2.1 kg/L) for any of severalcompletion methods:

• Open-hole gravel packs

• Standalone screens

• Slotted/perforated liners

• Barefoot

The key components of the DIPRO systemThe DIPRO system achieves highdensity without loading the systemwith solids; the only significantsolids are the carefully selected,calcium carbonate bridging agent.In addition to creating a thin,impermeable filter cake, theDI-TROL* and DI-BALANCE* com-ponents work together to buildLSRV without producing high ECDs.

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Features• Biopolymer-free

• Divalent-brine base

• Precisely controlled particle-sizedistribution of bridging agent

• Customized formulations

• Low ECDs

• Excellent shale stability

• Compatible with complexcompletions, including open-holegravel packs


• High production rates sooner

• Filter cake is easily removed

• Cost-effective, high-density fluids

• Minimal formation damage

• Minimal fluid loss with durablefilter cake

• Reduces remediation anddisposal costs

• High performance in deepwaterapplications

Completion

Formation damage. The system’sunique viscosifier/filtration-controladditive results in low filtration ratesand protects the reservoir with atough, thin filter cake.

Completion compatibility. The systemforms a durable filter cake that remainsintact during completion operations,such as high-rate water packing, butmay also be flowed back through virtu-ally any completion during production.

Displacement. Because of the base-brine composition, the DIPRO systemis compatible with completion fluidsand displaces easily.

Cleanup. The DIPRO system filter cakecan be produced through a completion,or be easily destroyed with a variety ofchemical breakers.

Long-term stability. The DIPRO system’sdivalent-brine base fluid allows the fluidto remain in the well for long periods oftime without significant degradation.

Recoverability. The base brine from theDIPRO system can be easily reclaimedfor use as a completion fluid or forformulating another DIPRO system.

Drilling

Density requirements. The DIPROsystem functions optimally in the11.5 to 17.5-lb/gal (1.4 to 2.1-kg/L)range and its density can be adjustedwithin this range without increasingthe solids in the system.

Rheological properties. Typically,the DIPRO system has a shear-thinningrheological profile, low plastic viscosity,high yield point and relatively high LSRV.

Contaminant tolerance. The systemtolerates the contaminants commonlyfound in drilling: cement, drilled solids,reactive shales and oil.

Torque and drag. While the DIPROsystem produces torque and dragthat is slightly higher than syntheticor oil-base systems, its lubricity isgood for water-base reservoir drill-influid systems. If needed, the system’slubricity can be enhanced with acompatible lubricant.

Wellbore stability. The base brinesused to formulate the system producean excellent level of shale inhibition.

Engineering ease. Because the DIPROsystem consists of only a few com-ponents, it is easy to mix on the rigand maintain.

The DIPRO System has the Characteristics You’ve Come to Expect from M-I SWACO

The M-I SWACO SAFE-CARB bridging agentis high-purity ground marble which is

selected using our OPTIBRIDGE* software toobtain the optimal blend. In these photos,

the disc on top is coated with a typicalfilter cake as it would be deposited by the

DIPRO system. The middle photo shows theeven “pinholing” effect obtained by back-producing the well, when this is possible.

The bottom photo represents instanceswhere back-producing is not a viable

option; the filter cake is almostcompletely dissolved after only a

three-hour soak with 5% HCl acid.

PRODUCTION SCREEN TESTER (PST). Thecorrect design and maintenance of areservoir drill-in fluid is critical whereopen-hole completions are planned.The particle-size distribution of solids inthe open hole must be carefully chosen,primarily to bridge across the exposedformation, but it may also permit flow-back through the openings in the com-pletion assembly. Initial fluid designand testing must be done in the labora-tory, but once drilling has started in thereservoir, any flowback testing on fieldsamples normally requires urgent ship-ping to shore, resulting in delays ofdays between sampling and test results.M-I SWACO has designed the PRODUCTION

SCREEN TESTER to perform onsite testingof fluid flowback at the rigsite. The unitallows field fluid to be tested in real-time on samples of identical completionscreen. This test also assists in determin-ing the optimum cleanup chemistrysuch as the M-I SWACO BREAKFREE* orBREAKOVER* treatments.

FAZEPRO


Offshore and onshore wells thatrequire the drilling performanceand inhibition of an invert-emulsion system along withthe easy cleanup characteristicsof a water-base system.

� P R O B L E M S

Conventional invert emulsions canmake drilling easier but can makecertain sand-control completionsdifficult, and their filter cakes canbe extremely time-consuming toclean up. In contrast, water-basesystems’ filter cakes are easier toclean up, but the systems may notinhibit certain formations.


The FAZEPRO* system is the indus-try’s only reversible, invert-emulsionreservoir drill-in fluid system, deliv-ering the drilling performance of aninvert emulsion with the filter-cake-removal efficiency, non-damagingcharacteristics and overall comple-tion simplicity of a water-base fluid.


Faster drilling through reactiveshales, easier cleanup and comple-tion efficiency all add up to signifi-cant time and money savings.

FAZEPRO gives you fasterdrilling and easier cleanup in one systemUntil now, drilling and completingcertain types of reservoirs presentedoperators with a dilemma. On oneside of the problem, technical, geo-logical and economic considerationsrequired an oil- or synthetic-basereservoir drill-in fluid, but oil-wetfilter cakes can be extremely costlyand time-consuming to clean upthoroughly. On the other side ofthe problem, while a water-basesystem makes it much easier toclean up the filter cake, it maybe incapable of inhibiting water-reactive shales and clays, com-promising drilling efficiency.

The FAZEPRO system eliminatesthis quandary. It is the industry’sonly reversible, invert-emulsionreservoir drill-in fluid system, deliv-ering the drilling performance of aninvert emulsion with the filter-cake-removal efficiency, non-damagingcharacteristics and overall comple-tion simplicity of a water-base fluid.

Now filter-cake removal is a simple matter of good chemistryWhile drilling the reservoir, theFAZEPRO system generates the highperformance you expect from aninvert-emulsion system. With theoil- or synthetic-base fluid servingas the continuous phase, the systemdelivers the excellent inhibition

and lubricity inherent in these sys-tems, resulting in a high-qualitywellbore and cost-effective ratesof penetration.

Once you reach the completionphase, the uniqueness of the FAZEPRO

system really becomes apparent.By simply adjusting the pH of

either the breaker solution or thecompletion brine, the wettability ofthe filter cake is transformed froman oil-wet state to water-wet. Oncethe filter cake is water-wet, it can beremoved easily and entirely withstandard water-base breaker treat-ments, even through gravel packswhich, by their very nature, nor-mally restrict lift-off. The result isminimal formation damage andoptimized production rates.

38

Sometimes you need a reservoir drill-in fluid system that can do two things at once

Features• Oil-base drilling performance

• Water-base cleanup

• Oil-wetting easily reversedwith pH change

• Stable chemical package

• Water-wet surfaces afterpH change

• Good shale inhibition

Benefits• Faster drilling, stable wellbore

• Easier to clean up

• Reduces waste generation

• Better production rates

• Can clean up throughopen-hole gravel packs

• Less costly remedialtreatments

Flexible components designedfor invert-emulsion drilling inthe reservoirOne of the key advantages of theFAZEPRO system lies in its flexibility.With the exception of the emulsi-fiers, the principal components ofthe FAZEPRO system are comparableto those in a conventional invertemulsion. They include the brine-base internal phase, organophilicclay and lime as the alkalinity agent.

Neither the base fluid nor brinerequires any special makeup. And,FAZEPRO technology can be incor-porated into a variety of invert-emulsion base fluids, includingsynthetics, diesel, mineral oils,

paraffins and olefins. In otherwords, any base fluid you woulduse in a conventional invert systemworks with the FAZEPRO system.Likewise, you can use organophilicclays for viscosity just as you wouldin a conventional invert emulsion.

The emulsifier package’sunique chemistry is the key to a water-wet filter cakeEarlier designs of conventional oiland synthetic-base reservoir drill-influids relied on strong emulsifiersand wetting agents. Powerful sur-factants and solvents were usedprior to production in an attemptto remove or break down theseconventional-fluid filter cakes. Suchmethods had only limited success.

The FAZEPRO system changes allthat. The uniquely engineeredemulsifier package developedspecifically for the FAZEPRO systemallows for a single-stage cleanupthat is easier to perform and farmore efficient than is possible withtypical invert-emulsion fluids. First,there’s FAZE-MUL*, the industry’sonly emulsifier capable of beingreversed from an oil to a water con-tinuous phase. Complementing the

emulsifier is FAZE-WET*, a speciallydesigned wetting agent.

M-I SWACO designed this pack-age so that alkalinity conditionsslightly below neutral (pH 7) willchange the emulsifier into asurfactant. Once that happens, thedeposited filter cake, includingsolids and residual fluids, thenbecomes water-wet. And, water-wet solids usually translate into amore efficient cleanup, resultingin optimized production rates.

When the unique FAZE-MUL

emulsifier package is reversed towater-wet, the FAZE-WET oil-wettingagent is removed at the same time.Once the downhole conditionsrevert to water-wet, cleanup as apart of the completion becomesmuch simpler. What’s more, you areno longer faced with the additionalexpense and risks associated withcomplicated, time-consumingcleanup procedures involving multi-stage stimulation treatments ofacid-blend packages, mutualsolvents and non-emulsifiers.

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Pressure-Drop Comparison350 Screen pressure drop (psi)

300

250

200

150

100

50

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100 5 15 20 25 30

Time, min

SBMFAZEPRO

Oil

Oil

Acid

Base

Water

Water

By changing the pH of the breaker or com-pletion brine, the filter cake deposited by theFAZEPRO system is converted from a water-in-oil emulsion to a direct oil-in-water emul-sion, resulting in easy and complete cleanup.

Initial Pressure Final Pressure Initial Pressure Final PressureDrop Across Drop Across Drop Across Drop Across

Core (psi) Core (psi) Screen (psi) Screen (psi)

Conventionalsynthetic-basefluid 2.30 2.77 0.1 >300

FAZEPRO* 2.34 2.85 0.1 0.3

Simulator Results of Pressure-Drop Comparison

As shown in the table, both drilling fluids yield similar core return permeability (82 to 83%)values. However, the table and graph reveal that the filter cake deposited by the SBM pluggedthe screen, whereas the FAZEPRO filter cake did not damage the screen. These data can beexplained by the fact that the FAZEPRO system’s components were well-dispersed or dissolvedby the acid treatment, so there was no coherent filter cake left to plug the screen.

FLOPRO NT


Onshore and offshore wells thatrequire a flexible, non-damagingreservoir drill-in fluid for a varietyof completion methods: • Open-hole gravel-pack or

non-gravel-pack completions • Barefoot, slotted or perforated

liner completions • Cased-hole completions where

hole cleaning or minimal fluidinvasion is critical

• Expandable sand-screencompletions

• High-temperature applications

� P R O B L E M S

Many drilling and reservoir drill-influids can harm producing forma-tions with high solids content,persistent filter cakes and highECDs that can cause fracturingand lost circulation.


The FLOPRO NT system is a provensolution with non-damaging charac-teristics, minimal drawdown pres-sure, an extremely low frictionfactor for low pump pressures andhigh ROP, an extremely high capac-ity for cuttings transport, water-base formulation and globalenvironmental compliance.


Because it is specifically engi-neered for high production rates,the FLOPRO NT system increaseshole-cleaning efficiency and pro-tects fragile formations. Its water-base formulation saves disposalcosts and its precisely controlledbridging agent particle-size distri-bution allows completion equip-ment to function properly, andspeeds up cleanup.


The water-base FLOPRO NT systemhas been approved for all majordrilling areas of the world.

Start preparing your reservoirfor higher production ratesright from the startIn response to the industry’sdemands for greater drilling effi-ciencies and higher productionrates, M-I SWACO developed thisnew-generation reservoir drill-influid — FLOPRO NT. The systembegins with your production-ratetarget and completion design thenworks back to the drill-in operation,optimizing all the factors that willaffect your success. You get a systemwhich provides strong benefits as ahigh-performance, non-damagingdrill-in fluid that optimizes pro-duction rates across a wide rangeof completion methods. See“Applications” in first column.

As the well is being drilled andcompleted, your M-I SWACO fluidsengineer ensures that the system iscapable of delivering what it prom-ises — maximum reservoir produc-tivity, lower total well costs andminimal environmental risk.

For production and reservoir engineers: wells that are productive soonerBecause the design of a FLOPRO NTsystem is based upon the way you’llcomplete your well, the completionprocess itself is greatly simplified.Every system component is solublein some type of treatment chemicalto make chemical breaking andcleanup relatively simple andstraightforward. Because the filtercakes are designed to lift-off withthe minimum possible drawdown,FLOPRO NT wells can, in many cases,begin production without chemicalcleanup treatments.

Because of the system’s flexibility,your M-I SWACO engineer can builda FLOPRO NT system from a numberof base fluids, including freshwater,seawater, potassium chloride,sodium chloride, calcium chloride,sodium bromide and FORMIX*TECHNOLOGY, which includessodium formate, potassiumformate and cesium formate.

40

The reservoir drill-in fluid that takes you to the new level of technology for minimizing formation damage and optimizing production

Features• Customized formulations

• Non-damaging

• Low lift-off

• Engineered for easy cleanup

• High return permeability

• Ultra-low-permeability filter cake

• Precisely controlled particle-sizedistribution of bridging agent

• Extremely low friction factor

• Promotes low skin values


• Rheologically engineered forelevated LSRV


• Reduces remediation costs

• Higher production rates sooner

• Minimal lift-off required,faster cleanup

• Minimizes solids and fluidinvasion to the formation

• Reduces pump pressures

• Maximizes ROP, savesdrilling time

• Excellent hole-cleaning profile

• Reduces cleanup anddisposal costs

• Compatible with anycompletion assembly

For drilling engineers:maximum ROP and reduced drilling costsDuring drill-in operations, theFLOPRO NT system exhibits excel-lent drag reduction inside the drill-string and can lower string pressureloss by as much as 40% comparedto conventional water- or oil-basedrilling fluids. The system preventsclay hydration and dispersion, whileits gel-like structure traps and sus-pends cuttings, producing a cleanerhole, and because the viscosity ofFLOPRO NT fluids is such that cut-tings beds are virtually eliminated,the system greatly reduces torque,drag and differential sticking.

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Lift-Off Pressure40 Pressure (psi)

35

30

25

20

15

10

5

0

FLOPRO NT Single-sack product

Because the FLOPRO NT system can becustom-tailored to the well conditions athand, it consistently outperforms single-sack reservoir drill-in-fluid products inboth return permeability and cleanup —two major factors in increasing productionand reducing costs.

Return-Permeability Profile350 Permeability (md)

300

250

200

150

100

50

0

Return (%) 100

90

80

70

60

50

40

30

20

10

0

0 20 40 60 80 100 120 140 160 180

Time, min

InitialReturn

The High-Temperature, High-Pressure (HTHP) return permeameter measures the permeabil-ity of formations to oil, brine, and gas under high-temperature and high-pressure conditions.The apparatus can also be used to measure formation damage on core samples, test fluidscontaining lost-circulation materials and large bridging particles, and run acid cleanup testsin high temperatures and pressures.

Return-Permeability Tests100 Return permeability (%)

90

80

70

60

50

40

30

20

10

0

FLOPRO NT Single-sack product

M-I SWACO uses the petrographic microscope to analyze thin sections of reservoir rockmaterials. Through analysis of pore size and other mineralogical characteristics, we cantailor fluid formulations to specific reservoirs.

FLOPRO SF


A variety of wells that do nottolerate a high percentage ofsolids, where bridging agentsare not required or where acidis not an acceptable breaker.Coiled-tubing and heavy-oilwells are prime applications.

� P R O B L E M S

Many reservoirs and completionmethods will not reach pre-wellgoals if solids, such as bridgingagents and lost-circulation materi-als, are introduced into the reservoirdrill-in fluid.


The FLOPRO* SF system controls fluidinvasion into the formation withviscosity. It is formulated with ahigher LSRV than a conventionalFLOPRO system.


The system reduces and even pre-vents formation damage to increaseproduction. Its lack of solids allowscompletion equipment to functionproperly, and its formulation speedsup cleanup.

The FLOPRO SF (Solids-Free) systemis a water-base Reservoir Drill-InFluid (RDF) which has proven itselfas a successful “rheologically engi-neered” system that relies on vis-cosity to control fluid invasion intothe formation. It is formulatedwith a higher Low-Shear-RateViscosity (LSRV) than a conven-tional FLOPRO NT system.

The reservoir and yourproduction come first when we design a FLOPRO SF systemM-I SWACO engineers designFLOPRO SF systems with respectto the reservoir properties andthe completion method to beused. Factors taken into consid-eration include:

• Formation permeability orpore size

• Formation temperature• Presence of reservoir gases• Formation sensitivity to

particular ions• Clay content• Type of hydrocarbon(s)

to be produced

Reducing fluid invasion without solidsFLOPRO SF systems can be usedwhere bridging agents are notrequired or acid is not a desiredbreaker. Heavy-oil formations,where formation viscosity con-fronts drilling-fluid viscosity to fur-ther reduce leak-off invasion depth,are also excellent candidates for

the system. And FLOPRO SF fluidswork well where overbalance pres-sure is kept to a minimum to reduceinvasion depth into dolomite, lime-stone, and consolidated or uncon-solidated sands.

The applications for FLOPRO SFcan include:

• Coiled-tubing applications

• Ultra-low-permeabilityformations

• Formations that containhigh-viscosity oil

• As pills for running completionassemblies after having drilledwith FLOPRO NT

• Barefoot, slotted-liner, open-hole-gravel-pack or non-gravel-packcompletions

• Cased-hole completions wherehole cleaning or minimizingfluid invasion is critical

42

The solids-free system for wells that require special handling

Flexible formulation makes the system a practical solutionvirtually anywhereFLOPRO SF systems can be designedwith a number of base fluids,including:

• Freshwater• Seawater• Potassium, calcium or

sodium chloride• Sodium bromide• Sodium, potassium or

cesium formate

Start protecting your future investments todayJust call your M-I SWACO represen-tative and ask to see case historiesof the FLOPRO SF system at work.Then put it to work for you.

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Features• Does not rely on starch or

sized bridging agents

• Circulates at low pumppressures

• Low friction factor

• Breaks easily with oxidizer

• Temperature-stable to 300° F(176° C)

Benefits• Reduces and prevents

formation damage

• Increases production

• Simplifies cleanup

• Ideal for coiled-tubing drilling

• Well-suited for high-temperature applications

FLOTHRU


Open-hole gravel packs, expandablescreens, stand-alone completionsor any open-hole application wherechemical breakers are normallyapplied, including oil- or condensate-production wells.

� P R O B L E M S

Once the gravel pack is completeor the screen expanded, the filtercake is trapped between the forma-tion and the completion assembly,making it difficult to access witha chemical breaker. In the case ofstand-alone completions, prema-ture breakthrough or other com-plications sometimes preventsthe breaker from fully contactingthe filter cake.


The FLOTHRU* system’s oil-permeablefilter cake requires lower flow-initiation pressures, permittingoil to readily pass through.


The FLOTHRU system eliminatesthe time and costs associatedwith chemical breakers and per-mits higher early hydrocarbonproduction rates that often offsetwater production.


The FLOTHRU system’s water-baseformulation minimizes environ-mental concerns, and its flexibilityallows it to be engineered with com-ponents that meet most environ-mental criteria worldwide.

During an open-hole completionwhere the filter cake is confined,as in open-hole gravel packs orexpandable-screen completions,the cake must remain intact toprevent losses and prematurescreenout. Once the completionoperation has finished, however,the filter cake is usually removedwith a chemical breaker to aidwell productivity and avoid piecesof the cake plugging the screenduring production.

The catch is that it can be difficultto access the confined filter cakewith a chemical breaker. The cakecan fail prematurely during breakerapplication, causing the breaker tobypass, or fail to contact, portions ofthe cake. This results in inadequatefilter-cake dissolution.

One way to address this problemis to include a chemical breaker dur-ing the gravel-packing operation,but that approach can be problem-atic. If the chemical breaker is tooaggressive and/or applied too early,premature filter-cake breakthrough

can occur and prevent the well frombeing completely gravel-packed.

The FLOTHRU system offers asolution that eliminates the needfor a chemical breaker.

How the FLOTHRUsystem worksThe FLOTHRU system is a water-base Reservoir Drill-In Fluid (RDF)designed with enhanced flowbackcapabilities that eliminate the needfor a chemical cleanup treatment,while providing higher return per-meability and lower flow-initiationpressures. The primary applicationfor a FLOTHRU system is in open-hole completions where the filtercake is trapped between the forma-tion and the completion assembly.In open-hole completions wherethe filter cake is not confined, theFLOTHRU system still provides amajor benefit: lower flow-initiationpressures at comparable return-permeability values.

In the FLOTHRU system, a pro-prietary hydrophobic-carbonate

44

This water-base filter cake won’t come between you and your oil

Features• Higher return permeability

through Open-Hole GravelPacks (OHGP)

• Lower flow-initiation pressuresfor OHGP and stand-alonecompletions

• Higher tolerance to drilled-solidscontamination

• Creates channels for steadyoil flow

• Requires no chemical breakers

Benefits• Increases production rates,

from heel to toe

• Removes cleanup risk/cost

• Cuts completion time and costs

• Allows oil to preferentiallyproduce

• Eliminates remedialcompletion operations

• Gradual filter-cakecleanup removes screen-plugging potential

component combines with ahydrophobic starch to controlfluid loss. These materials createorganophilic (oil-preferential) chan-nels through the FLOTHRU filtercake. Their filter-cake-buildingcharacteristics provide a low-permeability barrier to water andprevent high infiltration. Thesesame organophilic channels avoidthe cohesive nature of conventionalwater-base RDF filter cakes and pro-vide increased transmissibilityof hydrocarbons, eliminating theneed for chemical breakers.

The low-solids system withsuperior drilling characteristicsThe rheological properties of aFLOTHRU system are created with avariety of biopolymers, includingFLO-VIS* PLUS and FLO-VIS NT. Therheological profile of a FLOTHRU

system exhibits an elevated low-shear-rate rheology while main-taining minimal high-shear-raterheology — in particular, mini-mal plastic viscosity. This typeof rheological profile has consis-tently demonstrated low pumppressures, rate-of-penetrationenhancement and excellenthole-cleaning capabilities.

To engineer a highly inhibi-tive system, the chemistry ofthe FLOTHRU system can beadjusted with salts or hydrationsuppressants such as KLA-STOP* orKLA-GARD*. These materials utilizecation exchange to suppress clayhydration. They are also compatibleand work together with the sys-tem’s polymers, a viscosifier anda fluid-loss-control agent, to impede

the absorption of water by shalesand/or formation clays.

Due to the low solids and thepolymeric nature, FLOTHRU systemsgenerally have a very low coefficientof friction — typically 0.2 to 0.25.This assists in rotary and orienteddrilling operations. Lubricants havebeen found to further decrease thecoefficient of friction in FLOTHRU

systems to about 0.15.

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Description• Water-base monovalent salts

• Organophilic cake components– Carbonate — very fine– Starch

• Biopolymer viscosifier

• Properly sized bridging agents

The FLOTHRU filter cake resists water invasion of the formation while allowing hydrocarbons to flow at low flow-initiation pressures.

Inside wellbore

Hydrocarbons

Hydrocarbons flowing through the filter cake

FLOTHRU filter cake

THRUCARB

Associations of THRUTROL starch

THRUTROL starch

Formation sand where filtrate has displaced back the hydrocarbons

Hydrocarbons

Return Permeability and Flow-Initiation PressureAll 40/60 Gravel Packs withNo Chemical Cleanup100% Return permeability

90

80

70

60

50

40

30

20

10

0

Flow-initiation 25

20

15

10

5

0

pressure (psi)

Conventional RDF FLOTHRU psi

Clean fluidsFLOTHRU formulations

Contaminated fluids

A B

Return Permeability and Flow-Initiation PressureClean Fluids, No Chemical Cleanup100% Return permeability

90

80

70

60

50

40

30

20

10

0

Flow-initiation 30

25

20

15

10

5

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pressure (psi)

FLOTHRU

formulationsA B

Gravel-packed completions

Stand-alone tests

Conventional RDF FLOTHRU psi

FORMIX TECHNOLOGY


Onshore and offshore (includingdeepwater) wells that require high-density, low-solids water-base orinvert-emulsion drilling fluidsand/or Reservoir Drill-In Fluids(RDF) for highly reactive shales,high-temperature holes, low weight-material sag and low EquivalentCirculating Density (ECD).

� P R O B L E M S

Environmental regulations mandatethe use of halide-free, aqueous-basedrilling fluids, and most conven-tional high-density fluids include asignificant volume of weight mate-rial that can reduce ROP, increaseECD, and cause weight-materialsag and completion impairment.


FORMIX TECHNOLOGY is the processfor designing a drilling-fluid or RDFsystem around a formate salt. Thiscan include either invert-emulsion orwater-base systems with densitiesas high as 14.2 or 19.1 lb/gal (1.7 or2.29 SG), respectively, with no solids.


FORMIX TECHNOLOGY systems opti-mize drilling efficiency and dramati-cally minimize the risk of reservoirdamage and completion impair-ment. The low-solids content of thesystems paves the way for reuse onsubsequent wells.


These formate systems contain nochlorides or bromides, have greaterenvironmental acceptability thanother water-base or invert-emulsionfluids, and eliminate the need fortoxic biocides.

FORMIX TECHNOLOGYstarts with a new look at some familiar compoundsFormates are relatively new to thepetroleum industry. They are salts,not unlike the halide family of chlo-rides and bromides used in the oil-field for years. Monovalent formatesalts are extremely soluble in waterand form high-density, solids-freebrines, reducing the need forweighting agents.

M-I SWACO has a long history ofengineering formate-base brine sys-tems for various global applications.Today, three monovalent organic for-mate salts — sodium formate, potas-sium formate and cesium formate —provide the basis for our latest break-through in fluids engineering.

FORMIX TECHNOLOGY has beensuccessfully incorporated into theM-I SWACO FLOPRO NT reservoirdrill-in fluid system to drill andcomplete wells in particularly chal-lenging environments: high tem-peratures, damage-prone reservoirs,wells with narrow ECD windowsand wells in environmentally sen-sitive areas. FORMIX TECHNOLOGY

has also been utilized with ourVERSAPRO* LS low-solids invert-emulsion system to produce fluidswith densities higher than thoseachievable with a conventionalhalide brine internal phase.

Formates bring versatility and environmental strengths to both invert and water-base fluidsUsing FORMIX TECHNOLOGY in water-base RDFs results in increased pro-ductivity due to lower solidsconcentration; a thin, impermeablefilter cake and compatible base-fluid chemistry. Being monovalent,they reduce scaling potential andare compatible with most reservoirminerals and fluids. Formates arealso highly compatible with RDFpolymers, viscosifiers and fluid-loss-control agents.

In conventional drilling applica-tions, FORMIX TECHNOLOGY providesfluid stability for drilling throughsensitive shale sections, or when

46

The ideal foundation for building high-performing, low-solids drilling and reservoir drill-in fluid systems

Features• High densities with

minimal solids

• Minimal formation damage

• Excellent QHSE profiles

• Compatible with reservoir fluidsand polymers

• Completion compatible

• High shale and gas hydrateinhibition

• Thermally stable to >350° F(177° C)

• Low corrosion rates

Benefits• Increases production

• Reduces project costs


• Enhances solids-control efficiency

• Fewer completion problems

• Increases ROP

• Ideal for HTHP drilling

• Reduces weight-material sag

Economics and Reclamation250 Daily treatment cost (U.S. $)

200

150

100

50

0

CaCO3 polymer mud Formates

XY1

XY2

XY3

XY4

XY5

XY6

XY7

XY8

XY9

XY10

XY11

drilling in environmentally sensi-tive areas. For either RDF or conven-tional drilling, formates providestability at high temperatures. Likeother salts, formates can be blendedtogether to create an assortment ofdensities and crystallization points.

For high-density, invert-emulsion-fluid applications,FORMIX TECHNOLOGY providesdensity with minimal solids. Thehigh-density, monovalent-brineinternal phase is highly compatiblewith VERSAPRO LS emulsifiers, pro-viding excellent emulsion stabilityat oil/brine ratios down to 50:50.

The systems that bring wide-ranging benefits to awide range of applicationsThe more we utilize FORMIX

TECHNOLOGY, the wider the rangeof applications grows for the sys-tems based on it. Here are justsome of the advantages beingdiscovered and proven:

• The inhibitive water-base natureof these formate systems makesthem ideal for drilling highlyreactive shales

• Using natural polymers, they areinherently thermally stable, keep-ing the rheological and fluid-losscontrol properties stable in theface of downhole temperaturesin excess of 350° F (177° C)

• They have the capacity to elimi-nate the problems associated withweight-material sag, as well as thecompressibility and ensuing highECDs of invert-emulsion fluids,making FORMIX TECHNOLOGY sys-tems well suited for both HTHPand deepwater drilling

• All of the above tendencies alsoopen the door for the systems’use as thermal stabilizers inconventional water-base fluidformulations

• Since these FORMIX TECHNOLOGY-base systems are engineeredto deliver minimal circulating-pressure losses and maximizepower transmission to both thebit and mud motor, they are viablechoices for extended-reach andhorizontal wells

Our FLOPRO NT reservoir drill-influid system, based on FORMIX

TECHNOLOGY, is an excellent candi-date for high-density, slim-holedrilling applications. The shear-thinning and drag-reducing proper-ties are extremely compatible withthe small-diameter tubulars andnarrow annuli in both slim-holeand coiled-tubing wells.

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Progress vs Drilling Days2,500 Depth drilled (ft)

2,700

2,900

3,100

3,300

3,500

0 5 10 15 20 25 30

Section days

Planned Actual

Properties of Formate-Base FLOPRO NT vs. OBM40

30

20

10

0

FORMIX OBM

Solids(0%)

PV(cP)

Gel10 sec

lb/100 ft2

Gel10 min

lb/100 ft2

Gel30 min

lb/100 ft2

Formate DensitiesChemical Maximum Density Maximum Salt

Formate Symbol @ 68° F (20° C) Concentration

Sodium formate NaCOOH 11.2 lb/gal (1.34 SG) 45%

Potassium formate KCOOH 13.3 lb/gal (1.60 SG) 76%

Cesium formate CsCOOH 19.7 lb/gal (2.37 SG) 83%

NOVAPRO/VERSAPRO/PARAPRO


Onshore and offshore develop-mental wells designed for bothcased- and open-hole completions.

� P R O B L E M S

Many conventional drilling-fluidsystems “specialize” in one or twocharacteristics. In the case of devel-opmental wells, however, a combi-nation of desirable characteristicsare required to achieve a balanceamong good drilling, good comple-tions and high production rates.


The NOVAPRO*, VERSAPRO* andPARAPRO* systems are non-damaging, invert-emulsion fluidsdesigned to minimize formationdamage problems such as oil wet-ting, emulsion blocking, and solidsplugging, yet retain the perform-ance advantages of invert-emulsionfluids, including high Rates ofPenetration (ROP), lubricity andwellbore stability.


The systems’ fast-drilling character-istics and non-damaging formula-tions save time and money whiledrilling and completing the well,and they result in higher returnssooner when producing the well.

NOVAPRO* (synthetic), VERSAPRO*(diesel or mineral oil) and PARAPRO*(paraffin) Reservoir Drill-In Fluid(RDF) systems are non-damaging,invert-emulsion fluids used for drill-ing developmental wells designedfor both cased- and open-hole com-pletions. These systems aredesigned to minimize formationdamage problems such as oil wet-ting, emulsion blocking, and solidsplugging, yet retain the perform-ance advantages of invert-emulsionfluids, including high Rates ofPenetration (ROP), lubricity andwellbore stability.

Owing to the higher priority ofminimizing formation damageand compatibility with completionassemblies, these fluids differ fromconventional invert-emulsion flu-ids in their design and application.The emulsifier/wetting agent pack-age, the type and size of bridgingmaterial and, indeed, all compo-nents required are reviewed forthe best combination of drillingand completion characteristics. TheNOVAPRO/VERSAPRO systems areversatile, providing tremendousflexibility for numerous applica-tions. The key concepts to keep inmind when planning and usinga NOVAPRO/ VERSAPRO/PARAPRO

system are:

• Minimizing formation damage

• Providing completioncompatibility

• Maximizing productivity

ApplicationsNOVAPRO/VERSAPRO/PARAPRO invert-emulsion reservoir drill-in fluids aredesigned with flexibility in the for-mulation that makes them suitablefor a variety of applications:

• Open-hole gravel packs orstand-alone screens

• Cased-hole completions

• High-temperature applications

• Barefoot or slotted linercompletions

System componentsThe NOVAPRO system is built usingsynthetic-base fluid; the VERSAPRO

system uses either diesel or min-eral-base fluid while the PARAPRO

system uses paraffin-base oil.All systems exhibit all of the drill-ing advantages of conventionalinvert-emulsion fluids. In somecases, a conventional NOVAPLUS*,VERSACLEAN*, VERSADRIL* or PARADRIL*drilling-fluid system can be con-verted to a NOVAPRO, VERSAPRO

or PARAPRO system. This mayinvolve adjusting the size and/orconcentration of the bridging/weighting agent and/or modifyingthe emulsion package.

48

Features• Flexible formulation

• Non-damaging characteristics

• Invert-emulsion drilling-fluid properties

• Employs proprietary software andPRODUCTION SCREEN TESTER* (PST*)

Benefits• Ideal for a variety of applications

• Maximizes production

• High ROP, lubricity andwellbore stability

• Assures proper bridging,flowback tendencies

Solving several problems atonce on the U.S. West CoastFor drilling a 1,000-ft (305-m) reser-voir section, a West Coast operatorplanned to drill a horizontal wellutilizing an open-hole gravel-packcompletion. Excellent drilling char-acteristics, and the ability to enhanceproduction flowback without a chem-ical cleanup treatment, made theFLOTHRU system the natural choice.� Drilling proceeded with no

lost circulation or seepages� The completion and gravel pack

went as planned � Once online, the well had none

of the emulsion, mud, mud-filtrateor solids problems observed inprevious wells

� Production was 33% above theanticipated oil rate, with lower-than-expected water cuts — an averageof 50% below normal

Breaking the filter cake in an open-hole gravel-packor expandable-screen completion can be tricky.Break it too soon during the completion and youdon’t get a good pack or expansion. If you leave thecake in place and try to break it chemically after thegravel pack is complete or the screen is expanded,you could damage the formation or plug the screen.

The solution: The FLOTHRUoil-permeable filter cakeThe FLOTHRU* system is a water-base ReservoirDrill-In Fluid (RDF) designed with enhanced flow-back characteristics that eliminate the need for achemical cleanup treatment. A combination of pro-prietary materials form the basis for a filter cake thatprovides a low-permeability barrier to water and pre-vents high infiltration. The cake forms organophilicchannels that promote the transmission of hydrocar-bons and eliminate the need for chemical breakers.

Bottom line: water stays out of the formation;more oil flows into the wellbore.

Easy to run, environmentally sensible A typical FLOTHRU system incorporates very fewbase products, making it easy to engineer andmaintain while keeping logistics considerationsto a minimum. The highly inhibitive system exhibitsa low coefficient of friction, high LSRV and a minimalplastic viscosity. With its water-base formulation,the FLOTHRU system meets most environmentalregulations worldwide.

Contact your M-I SWACO* representative todiscover how the FLOTHRU system can help youropen-hole gravel-pack and stand-alone completions.

©2006 M-I L.L.C. All rights reserved.*Mark of M-I L.L.C.

This water-base filter cakewon’t come betweenyou and your oil

www.miswaco.com

TECHNOLOGY

FLOTHRU

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VERSAPRO LS/SF


Wells that require an oil-baseor reservoir drill-in-fluid systemfor either open-hole or cased-hole completions; a low-solidsperforation pill; a solids-freepreproduction pill for open-holecompletions.

� P R O B L E M S

While most conventional oil-basedrilling-fluid systems impart mini-mal formation damage, their highsolids content often impairs thecompletion and restricts production.Solids may also impact production-facility efficiency.


The density of the internal phaseof the VERSAPRO LS/SF systems ismaximized, and solids are incorpo-rated only to aid emulsion stabilityand bridge the formation. With alow-to-no level of solids, the chancesfor completion and tool plugginggreatly decrease.


Typically, wells drilled with theVERSAPRO LS system are character-ized by less completion pluggingand higher production rates thanwells in the same area drilled withconventional invert systems. Solids-free pills have helped eliminateproduction-facility upsets.

The system that lets you place formation protection where you need itAs a reservoir drill-in or completionfluid, or as a displacement or perfor-ating pill, the VERSAPRO LS systemhas proven to be one of the mostversatile on the market:

• In both cased-hole and open-holecompletions where oil-base fluidis required for drilling

• As a cased-hole perforationpill, it minimizes the threat ofsolids plugging the perforationtunnels, while preventing lossesto the reservoir

• In open-hole completions, it isideal as a low-solids fluid-loss-control pill to be left in the pro-ductive section prior to runningthe completion assembly. Bridgingagents can be eliminated inVERSAPRO SF pills used wherethere is a pre-existing solids-ladenfilter cake. The pill can be usedas a screen-running pill or pre-production pill.

• As a temporary-abandonmentfluid to minimize the risk ofsolids settling prior to the initia-tion of production

50

The versatile, low-solids, oil-base-fluid system that helps maximize your field’s productivity

Here’s an idea of what this low-solids, oil-base system can do for your bottom line• A 400% increase in one well’s pro-

ductivity index as compared toprevious perforated, horizontallycompleted wells in the same field

• A VERSAPRO LS pill remained verystable under downhole conditionsand, unlike previous wells in thearea, did not plug the completionassembly, so the operator couldreach expected production levels

• As a workover fluid, the systemenabled another operator to com-plete workover operations andreturn a group of wells to produc-tion rates at or above expectationswhile eliminating scale problemsexperienced with water-baseworkover fluids VERSAPRO SF pills have displaced

VERSAPRO drilling fluids in multi-lateral wells during completion

and prior to production. This hasallowed flowback through produc-tion facilities without facility upset.

These are only a few examplesof why operators the world over areturning to the VERSAPRO LS systemto get the most their reservoirshave to offer.

To learn more about howVERSAPRO LS is helping operatorsworldwide maximize production,contact your local M-I SWACOrepresentative.

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Features• Low to no solids loading

• High-density-brine internal phase

• Oil continuous phase

• Thermally stable

• Bridging agents optimizedfor specific formations

Benefits• Maximized production

• Reduced screen plugging

• High return-flow efficiency

• Greatly reduced sag or settling

• Low fluid loss

• Reduced gelation

• Reduced production-facilityupsets

Gel Strength ComparisonOver 12-day Period120 lb/100 ft2

(58.59 kg/10 m2)

100(48.83)

80(39.06)

60(29.30)

40(19.53)

20(9.77)

0

VERSAPRO LS Field Mud

Filter-Cake Lift-Off Pressure250 Millibars

200

150

100

50

0

VERSAPRO LS OBM

The high-density internal phase of the system reduces the potential for solids plugging andsettling. In addition, long-term gelation potential is significantly reduced due to the low-solidsnature of VERSAPRO LS, resulting in better flowback with minimal flow-initiation pressure.


52

Product Primary SecondaryTrade Name Description Type Function Function

ACTIGUARD* Shale and clay inhibitor for the APHRON ICS system Water Shale inhibitor —

ACTIVATOR* I Thermal stabilizer for the APHRON ICS system Water Thermal extender —

ACTIVATOR* II Thermal stabilizer for the APHRON ICS system Water Thermal extender —

ASPHASOL* Sulfonated organic-resin blend Water Shale inhibitor Filtration

ASPHASOL* D Sulfonated organic blend Water Shale inhibitor Filtration

ASPHASOL* Sulfonated asphalt Water Shale inhibitor FiltrationSUPREME

BLUE STREAK* Mud conditioner and air micro-encapsulator Water Surfactant Viscosifierfor the APHRON ICS system Filtration

BUBBLE BUSTER* Low-toxicity defoamer Water Defoamer —

CAUSTILIG* Caustilized lignite Water Thinner Thermal stability Filtration Emulsifier

CLEAN UP* Detergent for general rig cleaning when using Water Surfactant Emulsifieroil- and synthetic-base fluids Oil

Synthetic

CONQOR* 101 Filming amine Water Corrosion inhibitor —

CONQOR* 202 B Persistent filming amine Water Corrosion inhibitor —

CONQOR* 303 A Amine corrosion inhibitor for clear brines Water Corrosion inhibitor —

CONQOR* 404 General-use, phosphorus-base inhibitor Water Corrosion inhibitor —

C-SEAL* Coke FLCA Water, Lost circulation —Oil,

Synthetic

C-SEAL* F Coke FLCA (fine grind) Water Lost circulation —Oil

Synthetic

D-D* Drilling detergent Water Surfactant Emulsifier Shale control

DEFOAM-A* Alcohol-base defoamer Water Defoamer —

DEFOAM-X* All-purpose liquid defoamer Water Defoamer —

DI-ANTIFOAM* Antifoaming agent for the DIPRO system Water Defoamer —

DI-BALANCE* Viscosifier for the DIPRO system Water Viscosifier pH control

DI-BOOST* Secondary viscosifier for the DIPRO system Water Viscosifier —

DI-INHIB* Shale inhibitor for the DIPRO system Water Shale inhibitor —

DI-TROL* Filtration control agent for the DIPRO system Water Filtration —

DOWFROST MI* Low-temperature product Water Antifreeze —

DRIL-FREE* High-performance lubricant, anti-sticking agent Water Lubricant Surfactant

DRIL-KLEEN* Concentrated, mild drilling detergent Water Surfactant Emulsifier with low toxicity Shale control

DRIL-KLEEN* II Anti-bit balling agent Water Surfactant Emulsifier, Lubricant

DRILPLEX* Viscosifier for the DRILPLEX MMO system Water Viscosifier Shale inhibitor

DRILZONE* ROP enhancer Water Surfactant —

DRILZONE* L Low-cost anticrete Water Surfactant —

D-SOLVER* Chelant filter-cake remover for water-, oil- or synthetic-base Water Breaker —drilling fluids

D-SOLVER* PLUS Chelant plus acid filter-cake remover for water-, oil- or Water Breaker —synthetic-base drilling fluids

D-SPERSE* Surfactant Water Surfactant —

DUAL-FLO* Fluid-loss reducer for the FLOPRO NT system Water Filtration —

DUAL-FLO* HT Fluid-loss reducer for high-temperature applications Water Filtration —

DUO-TEC* Xanthan gum Water Viscosifier —

DUO-VIS* Xanthan gum Water Viscosifier —

DUO-VIS* L Liquified xanthan gum, non-clarified — Viscosifier —

DUO-VIS* PLUS Xanthan gum Water Viscosifier —

DURALON* High-temperature filtration-control polymer Water Filtration Thermal stability

DUROGEL* Sepiolite clay Water Viscosifier —

ECOGREEN* B Ester base fluid Synthetic Thinner Lubricant

ECOGREEN* M Low-end rheology modifier Synthetic Viscosifier —

ECOGREEN* P Primary emulsifier for the ECOGREEN system Synthetic Emulsifier Surfactant

ECOGREEN* S Secondary emulsifier for the ECOGREEN system Synthetic Emulsifier Surfactant

ECOKLEEN* Anticrete for tar applications Water Surfactant —

ECOTROL* RD Readily dispersible filtration control additive Oil Filtration — Synthetic

EMUL HT* HTHP emulsifier Oil Emulsifier —Synthetic

ENVIROBLEND* Salt for ENVIROVERT system Water Shale inhibitor —

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FAZE-MUL* Emulsifier for FAZEPRO system Oil Emulsifier —Synthetic

FAZE-WET* Wetting agent for the FAZEPRO system Oil Surfactant —Synthetic

FER-OX* Hematite Water Density —Oil

Synthetic

FLO-PLEX* Fluid-loss additive for the DRILPLEX system Water Filtration —

FLO-TROL* Starch derivative Water Filtration Viscosifier

FLO-VIS* L Non-dispersible, clarified xanthan gum Water Viscosifier —

FLO-VIS* NT Non-dispersible, non-clarified xanthan gum Water Viscosifier —

FLO-VIS* PLUS Premium-grade, clarified xanthan gum Water Viscosifier —

FLO-WATE* Sized-salt material Water Density Filtration

FLOXIT* Clay flocculant Water Flocculant Shale inhibition

FORM-A-PLUG* II Acid-soluble plug formulated with a finely ground borate Water Lost circulation FiltrationOil

Synthetic

FORM-A-PLUG* Accelerator for the FORM-A-PLUG pill Water Lost circulation —ACC Oil

Synthetic

FORM-A-PLUG* Retarder for the FORM-A-PLUG pill Water Lost circulation —RET Oil

Synthetic

FORM-A-SET* Cross-linked polymer plug Water Lost circulation —

FORM-A-SET* Accelerator for the FORM-A-SET pill Water Lost circulation —ACC Oil

Synthetic

FORM-A-SET* AK Polymeric lost-circulation material Water Lost circulation —Oil

Synthetic

FORM-A-SET* Variant of FORM-A-SET AK for water shut off Water Lost circulation —AKX Oil

Synthetic

FORM-A-SET* RET Retarder for the FORM-A-SET pill Water Lost circulation —Oil

Synthetic

FORM-A-SET* XL Cross-linker for the FORM-A-SET pill Water Lost circulation —Oil

Synthetic

G-SEAL* Sized graphite bridging agent Water Lubricant FiltrationOil

Synthetic

GELEX* Bentonite extender Water Flocculant Viscosifier —

GELPLEX* Viscosifier for the DRILPLEX system Water Viscosifier —

GLYDRIL* DG Water-miscible glycol-hydrate inhibitor Water Thermal stability Surfactant

GLYDRIL* GP Broad-cloud-point, general-purpose polyglycol Water Shale control Lubricityfor low-salinity fluids and low temperatures Filtration

GLYDRIL* HC Polyglycol for high-salinity fluids and Water Shale control Lubricityhigh temperatures Filtration

GLYDRIL* LC Low-cloud-point polyglycol for low-salinity Water Shale control Lubricityfluids and low temperatures Filtration

GLYDRIL* MC Medium-cloud-point polyglycol for Water Shale control Lubricitymoderate-salinity fluids and high temperatures Filtration

GO DEVIL* II Provides LSRV for APHRON ICS system Water Viscosifier Filtration

HIBTROL* Modified metal-cellulose polymer Water Filtration Shale inhibition

HIBTROL* HV Modified metal-cellulose polymer that also Water Filtration Shale inhibitionprovides viscosity Viscosifier

HIBTROL* ULV Fluid-loss additive and secondary shale inhibitor with Water Filtration Shale controlultra-low viscosity

HRP* Liquid viscosifier for oil fluids Oil Viscosifier Thermal stability

HYDRABLOK* Deepwater hydrate inhibitor Water Surfactant —

IDCAP* D Polymeric shale inhibitor Water Shale inhibition —

IDLUBE* XL Extreme-pressure lubricant Water Lubricant —

IDSPERSE* XT High-temperature polymeric dispersant Water Thinner —

INHIBYCON Wide-molecular-weight glycol Water Shale control LubricityFiltration

K-17* Potassium lignite Water Filtration Emulsifier Thinner Shale control

K-52* Potassium supplement Water Shale control —

KLA-CURE* Hydration suppressant Water Shale control —

KLA-CURE* II Hydration suppressant plus detergent Water Shale control —

KLAFLOC* I Low-cost shale inhibitor for floc water drilling Water Filtration —


54


KLAFLOC* II Cationic flocculant for floc water drilling Water Filtration —

KLA-GARD* Shale stabilizer and inhibitor Water Shale control Filtration

KLA-GARD* B Salt-free KLA-GARD Water Shale inhibitor —

KLA-STOP* Shale inhibitor Water Shale control —

LO-WATE* Ground calcium carbonate weight material Water Density Filtration Oil Lost circulation

Synthetic

LUBE-100* Low-toxicity lubricant Water Lubricant —

LUBE-167* Low-toxicity lubricant blend Water Lubricant —

LUBE-776* Lubricant Water Lubricant —

LUBE XLS* Extreme-pressure lubricant Water Lubricant —

M-I 157* Supplemental emulsifier Oil Emulsifier FiltrationSynthetic Surfactant

M-I BAR* Barite, meets API specifications Water Density —Oil

Synthetic

M-I CEDAR FIBER* Shredded cedar fiber Water Lost circulation —

M-I CIDE* Biocide – Not available in the U.S.A. Water Biocide —

M-I GEL* Bentonite, meets API specifications Water Filtration —Viscosifier

M-IGEL* SUPREME Non-treated bentonite, meets API specifications Water Viscosifier Filtration

M-IGEL* WYOMING API-spec bentonite sourced only from Wyoming Water Viscosifier Filtration

M-I LUBE* General-purpose lubricant Water Lubricant —

M-I PAC* R PAC polymer, tech grade Water Filtration ViscosifierShale inhibitor

M-I PAC* SR High-viscosity PAC, semi-pure grade Water Filtration ViscosifierShale inhibitor

M-I PAC* SUL Low-viscosity PAC, semi-pure grade Water Filtration Shale inhibitor

M-I PAC* UL PAC polymer, low-viscosity, tech grade Water Filtration Shale inhibitor

M-I SEAL* LCM for fractured or vugular formations Water Lost circulation FiltrationOil

Synthetic

M-I-X* II Ground cellulose Water Lost circulation FiltrationOil

Synthetic

MUD WASH* Rig wash Rig wash Rig wash —

MUL HTP* Primary emulsifier for negative-alkalinity system Oil Emulsifier FiltrationSynthetic

MY-LO-JEL* Pregelatinized starch Water Filtration —

NOVAMOD* Rheology modifier, LSRV Synthetic Viscosifier —

NOVAMUL* Basic emulsifier package Synthetic Emulsifier Surfactant Filtration

Thermal stability Viscosifier

NOVATEC* B LAO base fluid Synthetic Thinner Lubricant

NOVATEC* M Low-end rheology modifier for the Synthetic Viscosifier —NOVATEC system

NOVATEC* P Primary emulsifier for the NOVATEC system Synthetic Emulsifier Filtration

NOVATEC* S Secondary emulsifier for the NOVATEC system Synthetic Emulsifier Filtration

NOVATHIN* Deflocculant Synthetic Thinner Surfactant

NOVAWET* Wetting agent Synthetic Surfactant Emulsifier Thinner

Thermal stability

NUT PLUG* Ground nut shells Water Lost circulation —Oil

Synthetic

OILFAZE* Sacked oil-base concentrate Oil Emulsifier FiltrationViscosifier

OS-1L* Sulfite-base oxygen scavenger Water Corrosion inhibitor Thermal stability

PARADRIL* B Base fluid for the PARADRIL system Synthetic Thinner —

PARALAND* B Base fluid C11-17 linear paraffin for the PARALAND system Synthetic Thinner —

PARAMIX* A Salt for the PARALAND system Synthetic Shale inhibitor —

PARAMIX* N Salt for the PARALAND system Synthetic Shale inhibitor —

PARATROL* HT High-temperature Gilsonite Synthetic Filtration —

PASSIVATOR* I Defoamer for the APHRON ICS system Water Defoamer —

PIPE-LAX* Oil-base, stuck-pipe-freeing surfactant Water Free pipe —Oil

PIPE-LAX* ENV Low-toxicity, stuck-pipe spotting fluid Water Free pipe Lubricant

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PIPE-LAX* W Liquid, one-drum, stuck-pipe spotting fluid Water Free pipe —EXPORT Oil

POLYPAC* ELV Extra-low-viscosity PAC Water Filtration Shale inhibitor

POLYPAC* R Polyanionic cellulose Water Filtration Shale controlViscosifier

POLYPAC* Premium-grade polyanionic cellulose Water Filtration Shale controlSUPREME R Viscosifier

POLYPAC* PAC, premium-grade, ultra-low viscosity Water Filtration Shale inhibitorSUPREME UL Viscosifier

POLYPAC* UL Polyanionic cellulose Water Filtration Shale control

POLY-PLUS* Liquid PHPA Water Shale control Viscosifier Flocculant

POLY-PLUS* Dry Dry PHPA polymer Water Shale inhibitor FiltrationFlocculant

POLY-PLUS* LV Low-viscosity PHPA Water Shale control Filtration, Flocculant

POLY-PLUS* RD Readily dispersible PHPA powder Water Shale control Viscosifier Flocculant

POLY-SAL* Preserved modified starch Water Filtration Viscosifier

POLY-SAL* T Non-fermenting tapioca starch derivative Water Filtration Viscosifier

PTS-200* Polymeric temperature stabilizer Water Thermal stability —

RESINEX* Resinated lignite complex Water Filtration Thermal stability Thinner

RESINEX* II Resinated lignite, tech grade Water Filtration Thermal stabilityThinner

RHEBUILD* Viscosifier for RHELIANT system Synthetic Viscosifier —Oil

RHEDUCE* Thinner for RHELIANT system Synthetic Thinner —Oil

RHEFLAT* Rheological modifier for RHELIANT system Synthetic Viscosifier —Oil

RHETHIK* Rheological modifier for RHELIANT system Synthetic Viscosifier —Oil

RHEOSPERSE* Polymeric high-temperature deflocculant Water Thinner —

SAFE-CARB* Ground marble (calcium carbonate) Water Density FiltrationOil

Synthetic

SAFE-SOLV* E Pipe dope pickle solvent Water Surfactant —

SALT GEL* Attapulgite clay Water Viscosifier —

SCREENKLEEN* Organic blend to control screen blinding Water Surfactant —while drilling heavy oil/tar formations

SHALE CHEK* Shale-control and gumbo additive Water Shale control FiltrationSurfactant

Thermal stability

SI-1000* Scale inhibitor Water Corrosion inhibitor —

SILDRIL* D Dry sodium silicate Water Shale inhibitor —

SILDRIL* EPL Extreme-pressure lubricant for the SILDRIL system Water Lubricant —

SILDRIL* K Potassium silicate Water Shale inhibitor —

SILDRIL* L Liquid sodium silicate Water Shale inhibitor —

SIL-LUBE* Lubricant for the SILDRIL system Water Lubricant —

SP-101* Sodium polyacrylate Water Filtration Shale control Thermal stability

SPERSENE* Chrome lignosulfonate Water Thinner Emulsifier Filtration

Thermal stability

SPERSENE* CFI Iron lignosulfonate Water Thinner —

SPERSENE* I Ferrochrome lignosulfonate Water Thinner Thermal stabilityFiltration

STARGLIDE* Lubricant and ROP enhancer Water Lubricant Surfactant

STEEL LUBE* EP Extreme-pressure lubricant Water Lubricant —

SULFATREAT* DFS H2S scavenger Water Corrosion inhibitor —

SULFATREAT* XLP Extended-life H2S scavenger Water Corrosion inhibitor —

SUPRA-VIS* High-performance biopolymer viscosifier Water Viscosifier —

SUREMOD* Viscosifier, gelling agent for invert-emulsion systems Synthetic Viscosifier —Oil

SUREMUL* Primary emulsifier for invert-emulsion systems Synthetic Emulsifier SurfactantOil

SURETHIK* Rheological modifier Synthetic Viscosifier —

SURETHIN* Thinner for invert-emulsion systems Synthetic Thinner SurfactantOil


56


SUREWET* Wetting agent for for invert-emulsion systems Synthetic Surfactant EmulsifierOil

SV-120* Organic H2S scavenger Water Corrosion inhibitor —

SWA* EH Oil-base wetting agent for Oil Surfactant Emulsifierhigh-brine-content systems

TACKLE* Liquid, low-molecular-weight polyacrylate Water Thinner Filtration(dry available) Thermal stability

TACKLE* DRY Powdered low-molecular-weight polyacrylate Water Thinner —

TANNATHIN* Ground lignite Water Filtration EmulsifierThinner Thermal stability

TARCLEAN* Anticrete agent for heavy oil to thin asphaltenes Water Shale control —

TARLIFT* Solvent for the SAGDRIL* system Water Surfactant —

TARSURF* Water-wetter for the SAGDRIL system Water Surfactant —

TARVIS* Liquid viscosifier for the SAGDRIL system Water Viscosifier —

THINSMART* Thinner for water-base drilling fluids Water Thinner —

THRUCARB* Carbonate for the FLOTHRU* system Water Density Filtration

THRUTROL* Organic starch for the FLOTHRU system Water Filtration —

TRUVIS* Viscosifier for the TRUDRIL system Oil Viscosifier Filtration

ULTRACAP* Encapsulator for the ULTRADRIL system Water Shale inhibitor —

ULTRAFREE* ROP enhancer for the ULTRADRIL system Water Surfactant —

ULTRAFREE* L Low-cost anticrete Water Surfactant Lubricant

ULTRAFREE* NH Non-hydrocarbon version of ULTRAFREE ROP enhancer Water Surfactant Lubricant

ULTRAHIB* Shale inhibitor for the ULTRADRIL system Water Shale inhibitor —

UNITROL* Modified polysaccharide Water Filtration —

VERSACLEAN* B Base fluid for the VERSACLEAN system Oil Thinner Lubricant

VERSACOAT* Emulsifier and wetting agent Oil Surfactant Emulsifier Thermal stability

VERSACOAT* NA High flash-point emulsifier for oil-base fluids Oil Emulsifier SurfactantThermal stability

VERSADRIL* B Base fluid for the VERSADRIL system Oil Thinner Lubricant

VERSAGEL* HT Hectorite Oil Viscosifier Filtration

VERSALIG* Amine-treated lignite Oil Filtration Lost circulation

VERSALUBE* Oil-soluble lubricant Oil Lubricant —

VERSAMOD* Rheology modifier, LSRV Oil Viscosifier —

VERSAMUL* Basic emulsifier package Oil Emulsifier Surfactant Filtration

Thermal stability Viscosifier

VERSAPAC* Thermally activated, organic thixotrope Oil Viscosifier Lost circulationSynthetic

VERSAPRO* P/S Primary emulsifier Oil Emulsifier —

VERSATHIN* Thinner and conditioner for oil-base fluids Oil Thinner —

VERSATROL* Asphaltic resin Oil Filtration Lost circulation Viscosifier

VERSATROL* HT High-temperature Gilsonite Oil Filtration —Synthetic

VERSAVERT* B Base fluid for VERSAVERT system Oil Thinner Lubricant

VERSAVERT* BT Thin version of worker-friendly base oil Oil Thinner Lubricant

VERSAWET* Wetting agent for oil-base fluids Oil Surfactant Emulsifier Thinner

Thermal stability

VG-69* Organophilic clay Oil Viscosifier Filtration

VG-PLUS* Organophilic clay Oil Viscosifier Filtration Synthetic

VG-SUPREME* Organophilic clay for the NOVA systems Synthetic Viscosifier Filtration

VINSEAL* Filtration control and electrical stability agent Water Filtration —Oil

Synthetic

WELLZYME* A Enzyme breaker for water-base reservoir drill-in fluid Water Breaker —

WELLZYME* NS Enzyme breaker without biocide for reservoir drill-in fluids Water Breaker —

XP-20K* Potassium chrome lignite Water Thermal stability Emulsifier Filtration Thinner

XP-20* N Chrome lignite, sodium hydroxide, neutralized Water Thermal stability ThinnerFiltration

Simultaneous drilling,cleaning save time on 3-year, P&A well

Re-entering and cleaning this wellthat had been abandoned for 3 yearswent quickly and smoothly becauseof the close integration of M-I SWACOtools and fluids.

� Running a tricone bit made up tothe SPEEDWELL PUP* scraper, brushand magnet tool along with thePUP Finger Basket saved at leastone entire trip

� M-I SWACO displacement chemicalsand filtered completion brineaugmented with the SPEEDWELL

tools ensured a clean downholeenvironment

� Operator had a perfect packerset in the clean, junk-free hole

Now. Everything you need for a trouble-free displacement.One source. Truly integrated.

You have a lot riding on your dis-placement procedure, because it occupies that crucial positionbetween drilling your well andcompleting it. That’s why we’vecreated the INTEGRATED WELLBORE

CLEANING SOLUTIONS* (IWCS*)program from M-I SWACO*.

Much more than just a rigidsuite of services and products,the IWCS service lets us workwith you to develop a custom displacementprogram, using exactly what you need from:

• The SPEEDWELL* line of downhole cleaning tools

• M-I SWACO displacement chemistry andadditives, completion fluids, filtration services,and proprietary VIRTUAL CF* software

• Single-responsibility M-I SWACO displace-ment engineering that makes it all workin a truly integrated fashion for yourmaximum productivity

Upgrade to easier, better displacementsJust call your M-I SWACO representative todiscover how easy and clean an effectivelyrun displacement can be with our INTEGRATED

WELLBORE CLEANING SOLUTIONS. Call today and getthe most from everything you put into your well.

INTEGRATEDINTEGRATED WELLBORE CLEANING SOLUTIONS

Drilling

Displacement

CompletionDrilling

Displacement

Completion

www.miswaco.com

Because it’s all connected


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FLODENSE AP

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The uncontrolled release of pres-sure from a sealed casing stringpresents a serious safety and envi-ronmental hazard that reportedlyaffects nearly half of the wellsin the Gulf of Mexico. The U.S.Minerals Management Service(MMS) estimates that the problem,known as Sustained CasingPressure (SCP), affects some11,000 casing strings in approxi-mately 8,000 wells in the Gulf.

According to the MMS, some 30% ofthe affected wells require specialdeparture waivers to maintain pro-duction, while all of them requirecontinuous investment in eitherremediation or monitoring. Whilehalf of these incidents are reportedto occur in the production casing,SCP may arise in any of the annuliwithin a well. This problem is notunique to the Gulf and is prevalentin a number of fields worldwide.

Top-down casing-pressure remediation: the methodical approach to managing sustained casing pressure

Gas bubble

Gas formation

Mud or fluid

Cement


Wells in the Gulf of Mexico and else-where that experience SustainedCasing Pressure (SCP) — recurringpressure in casing strings that willnot bleed to zero psi (bar) after thewell reaches a steady state of flow.

� P R O B L E M S

SCP presents an ongoing, serioussafety and environmental hazard.Due to the nature of the gas-bearingformations, it cannot be prevented,but it can be controlled.


As part of our all-inclusive Top-DownCasing-Pressure-Remediation Process,the nucleus of the M-I SWACOapproach is to increase hydrostaticpressure by pumping our speciallyformulated FLODENSE* AP well-intervention fluid into the annulus.


By controlling casing pressure,FLODENSE AP fluid helps operatorsavoid costly blowouts as well asthe constant repair of productionequipment and tubulars.


The M-I SWACO Top-Down Casing-Pressure-Remediation Process canprevent the adverse environmentalimpact of a blowout.

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Basically, SCP refers to anyamount of recurring pressurein casing strings that will not bleedto zero psi after the well reaches asteady state of flow. Any number offailures, including leaks in tubing,casing, packers, wellhead packoffsand poor or failed cement jobs, caninitiate sustained casing pressure.

Recognizing the critical safety,environmental and economicconsequences of SCP, M-I SWACOhas taken the lead in developinga systematic line of attack toreduce or control these annularpressures. While the nucleus ofour approach is to increase hydro-static pressure by pumping ourspecially formulated FLODENSE* APwell-intervention fluid intothe annulus, our all-inclusiveTop-Down Casing-Pressure-Remediation Process entails somuch more. We study the circum-stances and parameters of eachwell to determine the best methodfor inserting a fluid-delivery sys-tem through an existing wellheadand into a constricted, pressurizedannulus. Our specialists carefullyexamine corresponding data toestablish how to best deliver thefluid downhole to achieve thenecessary hydrostatic column forhydrostatic enhancement. The endresult is the delivery of a fluid thatwill establish hydraulic control.

Designing a remediationproject begins with givingyour well the third degreeBefore we ever attempt to designa pressure-remediation plan foryour particular situation, we lookat every facet of your well. We

examine all the casing strings in thewell geometry, the well survey, pro-duction data and the types and den-sities of the fluids in all annuli. Weevaluate the bottomhole, flowingand shut-in pressures; the flowingtemperatures; and the sustainedpressures on the various annuli.We then review drilling records totrack the mud weights used andcompare those densities to the tripand background gases. We identifythe drilling breaks and track thecementing records.

Armed with this mountain ofdata, we attempt to diagnose thecause of SCP on your well by firstdetermining if the pressure is beingreleased from the producing forma-tion or another farther up the hole.Pulling all these pieces together iscritical to designing the ideal solu-tion for your individual situation.

FLODENSE AP helps put the brakes on uncontrolled casing pressureComplementing our Top-DownCasing-Pressure-RemediationProcess is our high-densityFLODENSE AP well-interventionfluid. The FLODENSE AP systemcontains a range of fluids thatcan be formulated for differentapplications with average densitiesranging between 17.5 to 18 lb/gal(2.1 to 2.16 kg/L). If an applicationspecifies, FLODENSE AP fluids canbe formulated at densities up to20.5 lb/gal (2.46 kg/L).

The FLODENSE AP system can beused as a viscous, lubricious andsolids-free fluid that is engineeredto fall through the annulus withminimal dispersion.

The FLODENSE AP well-interventionfluid also can be engineered withmicron-sized particles that allowthe fluid to pass in snakelike fash-ion through very narrow apertures.Densities as high as 20.5 lb/gal(2.46 kg/L) of the neat slurry permitit to fall through most existingannular fluids.

Owing to its micron-sized par-ticles, the FLODENSE AP systemexhibits reduced sag and settle-ment compared to competing sys-tems. In fact, the settling rate ofthe fluid is 1,000 times less thanthat of API barite, while smallerFLODENSE AP particles have asettling rate 10,000 times lessthan barite.

Both of these systems are designedto provide hydrostatic control.

FLODENSE AP fluid falling through CaCl2.

FLOPRO CT

The FLOPRO CT system is a water-base, solids-free intervention fluidthat meets the requirementsof coiled-tubing drilling withspecialized features:

• Promotes extended coil life

• Optimizes hydraulics

• Lower pump pressures andEquivalent Circulating Densities (ECD)

• Reduces mechanical drag, helixing and buckling

• Higher flow rates

• Applicable for all coil diameters and lengthsWith the FLOPRO CT system at

work, removing debris from thewellbore and clearing the way forthe insertion of production toolshas never been easier or more effi-cient. As an added bonus, the holetypically can be cleaned thoroughlyin one trip.

The system that givesoperators a wider range of possibilities for difficult applicationsThe versatility of the FLOPRO CTsystem has dramatically extendedthe range of applications for coiled-tubing interventions:

• High-strength and tapered coil

• Well depths of more than 27,000 ft(8,230 m) reached with nearly29,000-ft (8,839-m) spools

• Underbalanced environments ofup to 4,500 psi (31,050 kPa)

• Wellbores with bottomholetemperatures of more than300° F (149° C)

• Extended-reach wells exceeding30,000 ft (9,144 m)

60


Wells that require coiled-tubingdrilling under a wide range of con-ditions, including high temperatures,extended-reach and deep drilling,underbalanced environments,and rigs using high-strength andtapered-coil tubing.

� P R O B L E M S

Conventional fluid systems lack thecombination of characteristics thatthe FLOPRO* CT system uses to over-come tubing damage, extended slid-ing distances, high temperatures,hole-cleaning inefficiencies andnarrow pressure gradients.


The FLOPRO CT system has been spe-cially engineered to solve the uniquecombination of challenges found incoiled-tubing applications.


Because it is specifically engineeredfor coiled-tubing applications, thesystem saves time as well as wearand tear on the rig and tubing;increases hole-cleaning efficiency;and protects fragile formations.Its water-base formulation savesdisposal costs.


The water-base FLOPRO CT systemhas been approved for all majordrilling areas of the world.

The rheologically engineered fluid that puts the squeeze on pressure losses while delivering a clean wellbore

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The FLOPRO CT system is idealfor a wide range of workover opera-tions, including removing sand anddebris from a well. The rheologicallyengineered system poses minimalrisk of formation damage in per-forated intervals, with a solidscontent that is routinely less than1% by volume and elevated Low-Shear-Rate Viscosity (LSRV) thatcontrols invasion.

Engineered to optimize your drilling efficiency andmaximize your productionFor flexibility, the FLOPRO CT systemcan be built with a wide variety ofbase fluids:

• Freshwater

• Seawater

• Potassium, calcium orsodium chloride

• Sodium bromide

• Cesium, potassium orsodium formateCompared to conventional fluids

in similar situations, the FLOPRO CTsystem has exhibited vastly improvedsliding with reduced coil helixing andbuckling. Its combination of rheologymodifiers and interfacial tension anddrag reducers has allowed for highflow rates at minimum pressure.

FLO-VIS L premium-grade, clari-fied xanthan gum gives the systemits elevated LSRV. This high-yieldingbiopolymer is also dispersible andimparts the LSRV without adverselyaffecting the overall gross viscosityof the system.

Discover for yourself how theFLOPRO CT system is helping opera-tors optimize their coiled-tubingoperations. Contact your localM-I SWACO representative today.

Features• Low coefficient of friction

• Shear-thinning rheologicalprofile with high LSRV

• Zero or minimal solids

• Inhibitive fluid

• Provides drag reduction

• Wide density range

Benefits• Reduces mechanical friction

and coil wear

• Promotes hole cleaningand solids suspension

• Minimizes pressure lossand coil wear

• Minimal reservoir damage

• Enables entering higher-angle deeper wells notpreviously attainable

• Simplifies cleanup

The FLOPRO CT system delivers high LSRVs,which are measured using a Brookfieldrheometer. Where extremely high LSRVsare required, a vane spindle is used.

ISOTHERM


Deep and ultra-deepwater wellsthat require thermal protection forproduced liquids, threaded connec-tions and cement-bond integrity.

� P R O B L E M S

Subsea temperatures can cool,and change the properties of, pro-duced fluids. Temperature cyclingcan loosen threaded connectionsand compromise the integrity ofcement jobs.


ISOTHERM* fluid and the M-I SWACOproprietary TPRO ST* computermodeling software offer maximumprotection against low-temperature-related production problems.


In addition to preventing production-related and production-string-integrity problems, the fluid canbe mixed on the rig, eliminatingthe cost of a pumping boat.

The ISOTHERM system is atemperature-stable, solids-freeinsulating system based on oil-soluble components. Oil-baseinsulating fluids generally outper-form water-base or water-misciblefluids in many applications dueto their inherently lowerthermal conductivity.

The absence of solids meansthat density will not segregateover time nor will solids settle on-bottom. The absence of phase sep-aration (“top-oil” separation) canmean the difference between con-vective heat loss and no convectiveheat loss. The thermally stable rhe-ology produces a fluid that providesinsulation from the bottom to thetop of the well.

The ISOTHERM system’s low ther-mal conductivity is a function ofits oil base, versus water, brine orwater-miscible solvents. For exam-ple, the ISOTHERM systems havethermal-conductivity values 80%less than water and 40% less thanthe “best” water-miscible solventsystem (kwater = 0.35 BTU/hr/ft/°F;kwms = 0.12 BTU/hr/ft/°F; koil = 0.07BTU/hr/ft/°F).

Because the base fluid is inher-ently non-corrosive, the ISOTHERM

system is compatible with pro-duction tubulars, especiallyCRA materials.

In another application, the systemhas been used to prevent casing col-lapse in subsea wells. Casing collapseand sustained casing pressure inunvented annuli have not beenadequately prevented by the useof vacuum-insulating tubing.Therefore, additional measuresare necessary, and insulatingfluids are a critical componentof these measures.

M-I SWACO has developed acomprehensive, project-specificapproach designed to keep wellsflowing at optimum rates, evenafter they have been shut in forextended periods. Through ourflow-assurance program, we nowprovide a line of high-performance,oil-base, insulating packer fluidsand a proprietary computer model,TPRO ST, to remove many of theuncertainties and problems sur-rounding convective heat loss inthe annulus.

62

The ISOTHERM fluid offers maximum protection against low-temperature-related production problems

Features• Excellent insulating properties

• Solids-free formulationeliminates settling anduneven insulation

• Protects well from topto bottom

• Compatible with productiontubulars, especially CRAmaterials

• Can be used to preventcasing collapse

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Physical Properties Needed in an Insulating Annular Fluid

• h = the heat transfer film coefficient

• k = thermal conductivity

• ν = kinematic viscosity

• CP • ρ = volumetric heat capacity

• β = thermal expansion coefficient

Hot

Fluid

h = 0.129 k 2/31/3

{ (g • β • ∆T • CP • ρ ) }ν

SAFETHERM

In the deepwater environment, ini-tiating production, testing or shut-ting in for well intervention carrydistinctive flow-assurance risks thatcould threaten your investment.

The combination of cold temper-ature and high pressure can leadto temperature cycling in the well-bore, salt precipitation, or the for-mation of production-blockinghydrates, paraffin and asphaltene— any of which can seriouslyjeopardize your entire project.

To give you the upper hand,M-I SWACO has developed acomprehensive, project-specificapproach designed to keep yourwell flowing at optimum rates,even after it has been shut in forextended periods. Through ourflow-assurance program, we nowprovide a line of high-performance,water-base, insulating packer fluidsand a proprietary computer modelto remove many of the uncertain-ties and problems surroundingconvective heat loss in the annulus.

Stop production-robbingproblems where they startSAFETHERM insulating packer fluidfrom M-I SWACO helps overcometemperature-related problemsthat can reduce, or even stop,production:

• Heat transfer away from pro-duced fluids, resulting in a prod-uct that is incompatible withthe available surface processingequipment

• Multiple casing strings wherethe transfer of heat intounvented annuli can increasetemperature and pressure inthe sealed space, posing a veryserious risk of a casing collapse

• Well shut-ins for short-termsuspensions and interventionoperations, causing thermalexpansion and contractionof the tubular goods, inducingexcessive stress in the metalthat can disrupt casing/cement bonding

SAFETHERM keeps the heat where it belongsSpecially engineered for deep-water, permafrost and other cold-temperature environments,SAFETHERM provides thermalprotection for your produced oil:

• Aqueous-base or water-misciblefluid designed to minimize theconduction of heat away fromthe production string

• Suppresses convective heat lossin the annulus

• Compatible with a broad spec-trum of fluids, elastomers andother components in a widerange of wells

• Brings production to the surfacewithin the temperature criteriaof processing equipment

• Remains thermally stable overa wide range of temperatures andpressures for extended periodsof time

• Eliminates convection for minimalstress on tubing, casing, seals andcement bonds

• Reduced pressure cycling andthermal expansion means lessloosening of makeup torqueand threaded connections


Deepwater and ultra-deepwaterwells that require thermal pro-tection for produced liquids,threaded connections andcement-bond integrity.

� P R O B L E M S

Subsea temperatures can cool,and change the properties of, pro-duced fluids. Temperature cyclingcan loosen threaded connectionsand compromise the integrity ofcement jobs.


SAFETHERM* fluid and our propri-etary TPRO ST* computer modelingsoftware offer maximum protectionagainst low-temperature-relatedproduction problems.


In addition to preventing production-related and production-string-integrity problems, the fluid canbe mixed on the rig, eliminatingthe cost of a pumping boat.


This water-base system containsno free oil and produces no sheen.

64

For maximum supplemental fluid-loss protectionwith easy cleanup in sand-control completions

Features• Minimizes heat conduction and

convective heat loss

• Easily mixed and pumped onthe rig

• Environmentally acceptablecomponents

• Proprietary heat-transfercomputer model

• pH-buffered and corrosion-inhibitive

• Thermally stable

Benefits• Prevents production-line

blockage and casing-string collapse

• Compatible with a wide rangeof elastomers and fluids

• Production compatiblewith available surfaceprocessing equipment

• Controls heat regression duringproduction and shut-in

• Reduces costs

• Helps maximize production

Components speciallyengineered to protect your production• Base fluid resists thermal

conduction, contains nosuspended solids

• Can be formulated for densitiesranging from 8.33 to 12.5 lb/gal(1 to 1.5 kg/L)

• pH-buffered and inhibited tominimize corrosion

• Hydraulically optimized to yieldlow plastic viscosity with elevatedlow-shear-rate viscosities andyield stress

• Flat rheological profile over a widetemperature range

• Thermally stable over extendedtime periods

• Can be mixed and pumped onthe rig

• Can be pumped at high ratesthrough small tubing and orificevalves, with minimal frictionalpressure loss

SAFETHERM makes environmental sense too The components of the SAFETHERM

system were specially selected tohave minimal environmentalimpact, thereby mitigating theeffects of spills or other unforeseenevents. The packer fluid containsno free oil and produces no sheen.

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Temperature profile of well with SAFETHERM 118 in the “A” Annulus (1,500 bopd).

66

Workover and Completion Fluid Systems

SEAL-N-PEEL

SEAL-N-PEEL is a uniquely engi-neered fluid-loss-control pill,designed specifically as a contin-gency for all sand-control comple-tions. SEAL-N-PEEL provides superbsupplemental fluid-loss controlwhen mechanical devices either failor are unavailable. It deposits animpenetrable filter cake against theinside surface of the screen assem-bly. When the well is ready to go onstream, the cake simply peels away,using production pressure and flowas the lift-off mechanisms.

With the SEAL-N-PEEL pill, thecarbonate particles are speciallysized for each sand-control screen,and the stable rheological profile

ensures that these particles reachthe screen surface intact. This pro-motes the immediate depositionof a thin, tough filter cake on theinside surface of the gravel-packscreen with very little matrix inva-sion. When it’s time to produce thewell, surface-tension-reducing andreleasing agents lower the adhesiveforces that bind the filter cake tothe screen, allowing it to be com-pletely removed with very littledifferential pressure.

There’s no invasion into the for-mation, no damage from remedialcleanup measures, no unstable rhe-ological properties and no impedi-ment to optimized production.

Density RangeSystem Trade Name Description lb/gal kg/L

BREAKDOWN* Enzyme-chelant-base system 8.3 – 12 1 – 1.4

BREAKFREE* Enzyme-base system 8.3 – 12 1 – 1.4

BREAKLOOSE* Oxidizer-base system No density range available

Calcium Bromide Single-salt inorganic brine 8.4 – 15.1 1 – 1.8

Calcium Bromide/ Two-salt inorganic brine 11.7 – 15.1 1.4 – 1.8Calcium Chloride

Calcium Chloride Single-salt inorganic brine 8.4 – 11.6 1 – 1.4

ISOTHERM Oil-base packer fluid custom-designed and blended for specific DW and permafrost applications 7.5 0.9

Potassium Chloride Single-salt inorganic brine 8.4 – 19.7 1 – 2.4

Potassium Formate Single-salt organic brine 8.4 – 13 1 – 1.6

SAFE-LINK* 110 Completion fluid pill using 11 lb/gal (1.3 kg/L) CaCl2 8.4 – 11 1 – 1.3

SAFE-LINK 140 Completion fluid pill using 14 lb/gal (1.7 kg/L) CaCl2 8.4 – 14 1 – 1.7

SAFE-LINK 160 Completion fluid pill 8.4 – 16 1 – 1.9

SAFE-PLUG* Completion fluid pill 8.3 – 15.1 1 – 1.8

SAFE-PLUG* Z Completion fluid pill 15.1 – 19.2 1.8 – 2.3

SAFETHERM* Water-base or water-miscible packer fluid custom-designed and blended 9 – 12 1.1 – 1.4for specific deepwater and permafrost applications

SEAL-N-PEEL* Uniquely engineered fluid-loss-control pill, designed specifically as a 8.4 – 17.5 1 – 2.1contingency for all high-rate gravel-pack or water-pack completions whenmechanical devices either fail or are unavailable

Sodium Bromide Single-salt inorganic brine 8.4 – 12.5 1 – 1.5

Sodium Bromide/ Two-salt inorganic brine 10 – 12.7 1.2 – 1.5Sodium Chloride

Sodium Chloride Single-salt inorganic brine 8.4 – 10 1 – 1.2

Sodium Formate Single-salt organic brine 8.4 – 11 1 – 1.3

Zinc Bromide/Calcium Bromide Two-salt inorganic brine 14.2 – 19.2 1.7 – 2.3

Zinc Bromide/Calcium Bromide/ Three-salt inorganic brine 15.2 – 19.2 1.8 – 2.3Calcium Chloride

Features and Benefits• Acts as supplement to

mechanical fluid-loss-control devices

• Particles sized specificallyfor each screen

• Specially engineered additivereduces adhesive tendency

• Contains minimal solids

• Minimally invasive pill

• Superb capacity to peelfrom the screen

• Requires no remedial washes

• Non-damaging tothe formation

SAFE-LINK

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SAFE-LINK* fluid-loss-control productcomprises a chemically modified,cross-linked cellulose polymer usedprimarily to control loss of clearbrine fluid to the formation duringcompletion or workover operations.It controls fluid loss by applying avery viscous material across theformation face, virtually stoppingthe flow of brine into the formation.SAFE-LINK additive functions througha cross-linked polymer network thatis held in place on the formationface. The effectiveness of this prod-uct is not dependent on bridgingsolids or on viscous drag within theformation matrix.

ApplicationsSAFE-LINK additive is designed towork in non-zinc, halide brinessuch as CaCl2, CaBr2, NaCl, seawater,NaBr, and KCl, ranging from 8.6 to15.1 lb/gal (1 to 1.8 kg/L) to controlwholesale loss of brine to the for-mation. Generally, SAFE-LINK fluid-loss-control additive is stable to250° F (121° C) for at least 48 hrsof exposure. Due to the SAFE-LINK

additive’s cross-linking mechanism,differential pressure greater than2,000 psi (137.9 bar) is not advisable.

Based on recommended treat-ment levels and recommended use,the fluid loss to moderately perme-able formations (100 to 1,000 mD)can be reduced to <2 bbl/day per30-ft (9.1-m) interval.

Features and Benefits• Premixed liquid

• No special mixing equipmentrequirements

• Good to 250° F (121° C)

• Can be used at differentialpressures up to 2,000 psi(137.9 bar)

• Clean up with dilute acid

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SAFE-BREAK CBF emulsion preventeris a specialty solvent/surfactantblend that acts to prevent theformation of a stable emulsionbetween clear-brine completionfluids and reservoir crude oil.

SAFE-BREAK CBF preventer is for-mulated to penetrate the formationwith minimal adsorption and toprovide oil/brine separation atthe leading edge of invading fluid.It is soluble in all non-zinc-bromideor non-formate-base completionfluids. It will not “gunk out” of

solution at typical bottomholetemperatures. This combination ofproperties makes SAFE-BREAK CBFeffective at the lowest possibleconcentration and maximizesthe possibility for full reclamationof the completion fluid.

SAFE-BREAK CBF

SAFE-LUBE* additive is a patent-pending, water-soluble brine lubri-cant. The chemistry demonstratesan exceptional reduction in metal-to-metal friction when added to

brine-base completion fluids atextremely low concentrations.SAFE-LUBE lubricant is designed toreduce the coefficient of friction inseawater, sodium chloride, sodiumbromide, calcium chloride and cal-cium bromide completion fluids.

Torque and drag in completionfluids in high-angle, extended-reachwells has become a major concernto completion operations. SAFE-LUBE

lubricant has reduced torque anddrag up to 50% at extremely lowconcentrations in field applications.

SAFE-LUBE

SAFE-T-PICKLE* additive is a highlyeffective, non-aromatic, high-flashpoint pipe-dope solvent thatcontains no recognized carcinogens.It is effective in cleaning commonly

used copper- and zinc-base com-pounds. A fast-acting solvent thatrequires minimum contact time,SAFE-T-PICKLE solvent is effectiveover a wide temperature range andis ideal for deepwater applications.It removes excess pipe dope that

is used to lubricate pipe threadsduring tripping operations.

Removal efficiency is a function offlow rate and contact time. A mini-mum of five minutes’ contact at aflow rate of 120 ft/min (36.6 m/min)is recommended.

SAFE-T-PICKLE

FILTER FLOC* polymer is a suspensiondesigned to flocculate residual dis-placement solids in a manner thatfacilitates removal from a brine-base completion fluid. By floccu-lating the residual displacement

solids, the contaminant can beeasily transported to the surfaceand removed through the brinefiltration process.

For completion fluid applications,FILTER FLOC polymer is applied as aspacer in the displacement train.FILTER FLOC additive is intended for

use in freshwater, seawater, mono-valent, and calcium brine fluids.FILTER FLOC additive can also be uti-lized in the reclamation of comple-tion fluid brines. For reclamationapplications, optimum FILTER FLOC

polymer additions are determinedthrough pilot testing.

FILTER FLOC

Workover and Completion Fluid Products

Product Primary SecondaryTrade Name Description Function Function

Ammonium Chloride Dry, crystalline inorganic salt for mixing clear brines Shale control —(dry) (typically at 3 – 6 wt %)

Calcium Bromide Dry, crystalline inorganic salt for mixing clear brines Brine density —(dry) (8.4 – 15.3 lb/gal [1 – 1.8 kg/L]) adjustment

Calcium Bromide 14.2 lb/gal (1.7 kg/L) clear brine Brine density Shale control(liquid) adjustment

Calcium Chloride Dry, crystalline inorganic salt for mixing clear brines Brine density Shale control(dry) (8.4 – 11.8 lb/gal [1 – 1.4 kg/L]) adjustment

Calcium Chloride 11.6 lb/gal (1.4 kg/L) clear brine Brine density Shale control(liquid) adjustment

DUO-VIS* Xanthan gum Viscosifier —

FILTER FLOC* Blend of surfactants and solvents designed to suspend OBM, pipe Flocculant Filtrationdope and mineral-scale solids and transport them from the well

FLO-TROL* Starch derivative Filtration Viscosifier

FLO-VIS* L Clarified xanthan gum in a liquid medium Viscosifier Viscosifier

FLO-VIS* PLUS Premium-grade, clarified xanthan gum Viscosifier Fluid-loss control

KLA-GARD* Shale stabilizer and inhibitor Shale control —

KLA-STOP* Shale inhibitor Shale control —

Potassium Chloride Dry, crystalline inorganic salt for mixing clear brines Shale control Brine preparation(dry) (8.4 – 9.7 lb/gal [1 – 1.2 kg/L])

Potassium Formate Dry, crystalline organic salt for mixing clear brines Brine density —(dry) (8.4 – 13.3 lb/gal [1 – 1.6 kg/L]) adjustment

SAFE-BREAK* 611 Non-emulsifier Polymer breaker —

SAFE-BREAK* CBF Non-emulsifier for non-zinc-base clear brine Non-emulsifier —

SAFE-BREAK* L Breaker for brine viscosifiers Polymer breaker —

SAFE-BREAK* S Breaker for brine viscosifiers Polymer breaker —

SAFE-BREAK* ZINC Non-emulsifier for zinc-base clear brine Non-emulsifier —

SAFE-CARB* Sized ground marble Fluid-loss control —

SAFE-CIDE* Biocide – Not available in the U.S.A. Biocide —

SAFE-COR* Corrosion inhibitor for clear brines Corrosion inhibitor —

SAFE-COR* 220X Brine corrosion inhibitor Corrosion inhibitor —

SAFE-COR* C Concentrated corrosion inhibitor for clear brines Corrosion inhibitor —

SAFE-COR* E Corrosion inhibitor for clear brines Corrosion inhibitor —

SAFE-COR* HT High-temperature corrosion inhibitor for clear brines Corrosion inhibitor —

SAFE-COR* Z PLUS Amine-base corrosion inhibitor Corrosion inhibitor —

SAFE-DFOAM* Defoamer for clear brines Foam control —

SAFE-FLOC* I Blend of surfactants, flocculants and solvents designed to Flocculant Filtrationflocculate and suspend iron solids

SAFE-LUBE* Water-soluble brine lubricant Lubricant —

SAFE-PEEL* Filter-cake releasing agent Fluid-loss control —

SAFE-SCAV* CA Oxygen scavenger for calcium-base clear brines Corrosion control —

SAFE-SCAV* HS Hydrogen sulfide scavenger for clear brines Corrosion control —

SAFE-SCAV* NA Oxygen scavenger for monovalent clear brines Corrosion control —

SAFE-SCAVITE* Scale inhibitor for clear brine Scale inhibitor —

SAFE-SOLV* E Pipe-dope pickle solvent Surfactant —

SAFE-SOLV* OM Dispersible solvent for O/SBM Solvent —

SAFE-SURF* E Nonionic wellbore cleaning agent for oil- and water-base fluids Surfactant —

SAFE-SURF* O Displacement surfactant/detergent chemical for Surfactant/detergent —oil/synthetic-base fluids

SAFE-SURF* W Displacement surfactant/detergent chemical for water-base fluids Surfactant/detergent —

SAFE-SURF* WE Displacement surfactant/detergent chemical for water-base fluids Surfactant/detergent —

SAFE-SURF* WN Displacement wash chemical for water-base fluids Surfactant —

SAFE-T-PICKLE* Pipe dope removal Solvent —SAFE-VIS* Hydroxyethylcellulose (HEC) powder Viscosifier Fluid-loss control

SAFE-VIS* E Liquid HEC viscosifier for clear brines Viscosifier Fluid-loss control

SAFE-VIS* HDE Liquid HEC viscosifier for high-density clear brines Viscosifier Fluid-loss control

SAFE-VIS* LE Liquid viscosifier in a highly purified mineral oil carrier Viscosifier Fluid-loss control

SAFE-VIS* OGS Specially formulated liquid HEC Viscosifier Fluid-loss control

Sodium Bromide 12.5-lb/gal (1.5-kg/L) brine Brine density —(liquid) adjustment

Sodium Chloride Dry, crystalline inorganic salt for mixing clear brines Brine density —(dry) (8.4 – 10 lb/gal [1 – 1.2 kg/L]) adjustment

Sodium Formate Dry, crystalline organic salt for mixing clear brines Brine density —(dry) (8.4 – 11 lb/gal [1 – 1.3 kg/L]) adjustment

Zinc Bromide/ 19.2-lb/gal (2.3-kg/L) clear brine Brine density —Calcium Bromide adjustment

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OPTIBRIDGE

Any fluid entering your reservoiraffects production. Whether it’s akill pill, a reservoir drill-in fluid orone designed for lost circulation orperforation sealing, it must be for-mulated precisely to block invasionand, ultimately, prevent formationdamage. The first step in designinga non-damaging fluid is to deter-mine the ideal particle-size distribu-tion for the bridging material.

Our proprietary OPTIBRIDGE* soft-ware gives the M-I SWACO engineera tool for precisely and quicklyselecting correctly sized bridgingagents. With the OPTIBRIDGE pro-gram, the M-I SWACO engineerinputs formation data as well asinformation about locally availableproducts. Then the software calcu-lates the “best-fit” mixture of locallyproduced bridging particles for effec-tively sealing the formation face.

The OPTIBRIDGE tool is anotherexample of our commitment toensure the integrity and long-timeproductivity of your reservoir.

OPTIBRIDGE software makessure no void is left unsealedThe OPTIBRIDGE program improveson the popular Ideal PackingTheory, which takes a graphicalapproach to determine the opti-mum sizing of bridging material forspecific formation characteristics.Basically, this theory examines allthe voids in a given formation andconsiders the full range of particle-size distribution that will be requiredto fill them effectively.

OPTIBRIDGE software takes thattheory a major step further. It gen-erates a mathematical model basedon the largest pore size, also knownas the D∑ rule.

Using the software, the M-I SWACOengineer examines data from the tar-geted formation, including maximumpore-size opening, permeabilityand/or screen sizes, and combinesthat input with the bridging-particleinformation. From that model, theOPTIBRIDGE program automaticallygenerates a target line of the opti-mum blend of particles that willeffectively minimize solids and fil-trate invasion. Once the optimumblend is known, the ratio of bridgingmaterials can be perfectly matchedto the formation characteristics.

Because the OPTIBRIDGE programconsiders characteristics of yourspecific formation and matchesthem with bridging particles avail-able in your area, there is no con-cern about having to wait or bearthe burden of extraordinary deliv-ery costs. What’s more, this power-ful software package ensures thedesired solids are maintained in thefluid system, allowing you to maxi-mize your solids-control programwhile still maintaining the preciseparticle-size distribution of thebridging agent.

OPTIBRIDGE software: Onemore weapon in the battleagainst reservoir damageThe OPTIBRIDGE program clearlyillustrates the ingenuity andlengths that M-I SWACO will under-take to develop systems and tools tominimize formation damage andmaximize your production. To findout more about how the OPTIBRIDGE

program is performing for our cus-tomers worldwide, contact yourlocal M-I SWACO representative.

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Versatile software that takes the guesswork out of designing non-damaging reservoir fluids

Features• Accurately matches local

bridging agents with forma-tion characteristics

• Applicable for reservoirdrill-in fluids, lost-circulationtreatments, kill pills, fracturesealing and perforationsealing

• Prevents fluid invasion

• Uses actual formation andbridging-agent informationthat will provide an optimumfilter cake

Benefits• Reduces formation damage

• Takes the guesswork out ofselecting bridging material

• Lowers material costs

• Optimizes production

OPTIBRIDGE software generates a targetline that defines the ideal blend of locallyproduced bridging materials that wouldbest fit the targeted formation character-istics. Available anywhere in the world,the OPTIBRIDGE service is an ideal tool forformulating a non-damaging reservoirdrill-in fluid. It also can be used to designfracture-sealing and lost-circulationtreatments, and to formulate kill andperforation-sealing pills for workoverand completion operations.

VIRTUAL RDFVIRTUAL RDF* (Reservoir Drill-InFluids) software package is avail-able to M-I SWACO operationalpersonnel. VIRTUAL RDF consists ofa suite of programs used in theselection, design, and optimiza-tion of reservoir drilling fluids.The suite includes OPTIBRIDGE,FINV*, RDFX*, BREAKER ADVISOR*and RDF FORMULATOR*. In additionthe standard M-I SWACO refer-ence modules, CONV and Tablesare included.

• OPTIBRIDGE optimizes bridgingparticle-size distribution basedon reservoir characteristicssuch as pore size (preferred)or permeability.

• FINV indicates potentialfiltrate invasion depth basedon exposure time and filtrationproperties.

• RDFx is a reservoir drilling-fluid selector program thatassists the project engineer inchoosing an appropriate RDFfor a specific project.

• RDF FORMULATOR is a reser-voir drilling-fluid formulationprogram. It is capable of for-mulating water and invert-emulsion based reservoirdrilling fluids and can formulateall M-I SWACO RDF systems.

• BREAKER ADVISOR is a programto assist the completion/projectengineer in selecting an appro-priate breaker for a given proj-ect. The program uses reservoir,drilling, completion and produc-tion information to assist it theselection process.

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PRODUCTION SCREEN TESTER (PST). Thecorrect design and maintenance of areservoir drill-in fluid is critical whereopen-hole completions are planned.The particle-size distribution of solids inthe open hole must be carefully chosen,primarily to bridge across the exposedformation, but it may also permit flow-back through the openings in the com-pletion assembly. Initial fluid designand testing must be done in the labora-tory, but once drilling has started in thereservoir, any flowback testing on fieldsamples normally requires urgent ship-ping to shore, resulting in delays ofdays between sampling and test results.M-I SWACO has designed the PRODUCTION

SCREEN TESTER to perform onsite testingof fluid flowback at the rigsite. The unitallows field fluid to be tested in real-time on samples of identical completionscreen. This test also assists in determin-ing the optimum cleanup chemistrysuch as the M-I SWACO BREAKFREE orBREAKOVER treatments.

PRESSPRO RT

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The PRESSPRO RT service fromM-I SWACO provides unprecedentedwellsite engineering support with aunique, specifically designed suiteof software. Proprietary programsuse surface measurements to cal-culate real-time downhole pressureand corresponding fluid propertiesduring drilling and tripping. Thisunique technology not only providesup-to-the-second Equivalent StaticDensities (ESDs) and EquivalentCirculating Densities (ECDs) at anypoint in the wellbore during drilling,but also delivers surge and swabpressure measurements, EquivalentDynamic Density (EDD) while trip-ping drill pipe or setting casing.

A manned computer systemfor ECD management calculatesdownhole hydraulics using surface-measured drilling and trippingdata. And the real-time VIRTUAL

HYDRAULICS* package leveragesthe proven technology, updatingand displaying current data viathe VIRTUAL HYDRAULICS

SNAPSHOT* graph.

The virtual sensor package pro-vides ESD, ECD, and other key val-ues for display at the driller’s stationas if they were measured values.

Using the PRESSPRO RT packageis like running the VIRTUAL

HYDRAULICS package in real time.

VIRTUAL HYDRAULICS provides a “snapshot.” PRESSPRO RTgives you the “movie.”Now, the industry has access to animmediate processing technologythat expands on the field-provenM-I SWACO VIRTUAL HYDRAULICS

and VIRTUAL RHEOLOGY* platformsto consistently and accurately cal-culate ECDs and pump pressureas they occur. You get the informa-tion you need to mitigate, and eveneliminate, critical drilling problemsand events that can jeopardize theefficiency and economics of high-cost drilling programs.

Because the system works inreal time, you can make changeson the fly and impact operationsthat are ongoing.

Real-time engineering answers for technically challenging wells with narrow operating windows


Deepwater, high-temperature,extended-reach wells and wellswith very narrow pressure windows.

� P R O B L E M S

Drilling-fluid properties mustbe monitored and adjusted con-stantly to handle rapidly changingwellbore conditions and to avoidlosing expensive, premium fluidsthat could violate environmentalregulations and damageproducing formations.


The proprietary programs of thePRESSPRO* RT package use surfacemeasurements to calculate real-time downhole pressure and corre-sponding fluid properties duringdrilling and tripping so problemscan be managed as they arise.Onshore drilling centers (OCs)provide reliable control fromremote sites.


The PRESSPRO RT service can miti-gate and even eliminate drillingproblems that can jeopardize theefficiency and economics of high-cost drilling programs. Onshorecenters maximize efficiency byoptimizing workflow and reducingthe number of personnel requiredat the drillsite.


By allowing greater control of ECDand allowing surge/swab pressuresto be monitored during tripping, thePRESSPRO RT service safeguards theenvironment and the fragile per-meability of producing formations.Onshore centers contribute to envi-ronmental safety by removingpersonnel from the work site andplacing them in an offsite facility.

The PRESSPRO RT package includes a computer that connects to the data-source company’scomputer to receive and send data. The real-time data, in turn, is either sent back to thedata-acquisition company or to another third party responsible for the rig-floor display.

Data-sourcecompany

system

MWD/LWDprovider

Real-time downhole data

Rig-floor display

Remote computer

M-I SWACOPRESSPRO RT

system

Office computer connected toPRESSPRO RT computer — using

Reachout with TCP/IP

Measured real-time surfacedata from data source

PRESSPRO RT calculated variables send back to

data sourceReal-time data —measured and

calculated

And the PRESSPRO RT systemis a real wellsite service. ThePRESSPRO RT system and dedi-cated computer aboard the rigare maintained by an M-I SWACOcritical-well analyst, an experiencedfluids engineer specially trainedin all aspects of drilling the mostdemanding deepwater, HTHP,extended-reach, and multilateralwells. If additional assistance isnecessary, the M-I SWACO analystis connected to additional supportpersonnel outside the immediatedrilling area.

Offsite centers cut cost, not serviceThe PRESSPRO RT system can also bemonitored from an offsite center.Real-time OCs can perform certaincritical and routine functions tradi-tionally performed at the wellsiteand all input from experts whohave a “virtual presence” at multi-ple wellsites. OCs can provide reli-able, inexpensive transmission ofdrilling data to and from remotesites with minimal delay.

Simulation computers can beinstalled in the OC to facilitate effi-cient deployment and provideinstant, remote access to real-timedrilling and other operational data.Results can be compared immedi-ately to WD and can be mergedseamlessly with the real-time datastream simultaneously accessibleby the OC and at the rigsite.

If it impacts drilling ortripping, the PRESSPRO RTservice has you coveredSpecially designed PRESSPRO RTmodules provide valuable informa-tion about all the properties of thefluids in the wellbore.

• DRILLPRO* RT targets criticalparameters that must be considerwhen drilling a well. For the veryfirst time, ECD values are calcu-lated and displayed every second

while both drilling and makingconnections.

• TRIPPRO* RT calculates and dis-plays real-time fluid parameterswhile tripping drill pipe and run-ning casing — situations wherewellbore conditions can changevery quickly

• SNAPSHOT* RT provides a con-tinuous graphical display ofdownhole profiles

• VISUAL HYDRAULICS* provides avisual representation of down-hole metrics using an easy-to-understand color scale.

PRESSPRO RT and PWD: a perfect matchThe PRESSPRO RT package is anintegral part of ECD management.It does not replace the popularPressure While Drilling (PWD) tool.Instead, it complements PWD data,comparing the “what are” measure-ments of PWD with a “what shouldbe” scenario for early detection ofimpending problems. While PWDprovides a single-point profile at thebit, the PRESSPRO RT package calcu-lates complete profiles of downholehydraulics and mud behavior, sub-stituting PWD when the data is notavailable, a situation that occurswhen running casing or when PWDtools break or cannot be usedbecause of high-temperature/high-pressure conditions.

PRESSPRO RT and VIRTUALHYDRAULICS packages area winning combinationNow a vital element in many opera-tors’ onshore real-time drilling cen-ters, the PRESSPRO RT package is theonly technology that provides in-time equivalent static and equiva-lent circulating densities at anypoint in the wellbore during drill-ing. VIRTUAL HYDRAULICS software,long an integral component of theM-I SWACO PRESSPRO RT wellsiteengineering service, uses surface

measurements to calculate down-hole pressure and correspondingfluid properties during drilling andtripping. The PRESSPRO RT serviceperfectly complements the PWDby filling in the gaps in that tech-nology and substituting for PWDwhen data is unavailable.

The PRESSPRO RT system is onemore example of why M-I SWACO isthe industry leader when it comesto developing solutions to the mostdemanding applications.

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Features• Managed by a specially

trained, onsite, critical-well analyst

• Can be operated from remoteOperation Centers

• Monitors drilling andtripping parameters

• A dedicated computer canbe interfaced to an existingdata acquisition system withthe data-acquisition sourceon the rig

• Pre-defined screens fortargeted drilling/trippingcomponents

• Downhole profiles calculatedand updated every second anddisplayed as virtual sensors

Benefits• Prevents/minimizes down-

hole fluid losses due tolost circulation

• Early detection of impendingproblems by providing “whatshould be” data to comparewith “what is”

• Minimizes mud-relatednon-productive time

• Helps reduce drilling costs

• Provides real-time monitoringfor immediate response

• Complements PWD whenavailable and substitutesfor PWD when the data isnot available

VIRTUAL CF

When displacing drilling fluid with acompletion or reservoir drill-in fluid,neglecting critical variables can leadto a world of headaches down theroad. Excessive rig time. Damagedreservoirs. Added cleanup and filtra-tion costs. Lower production.

Our proprietary VIRTUAL CF* soft-ware package considers all theparameters, taking the uncertaintyout of wellbore displacements. Thissophisticated, integrated suite ofcomputer programs targets thehydraulics modeling and displace-ment profiles of high-density brinesand other completion fluids toenhance wellbore cleanup and ulti-mately the productivity of your well.

Armed with this powerful soft-ware package, the M-I SWACO engi-neer can, with an unequaled degreeof accuracy:

• Minimize rig time for displace-ments by calculating all criticalvariables in the wellbore, includingspacer volume, rheologies, fluidregime, velocity, contact time,pump strokes, pump pressure anddifferential pressures

• Design a displacement thatmeets equipment limitationsby inputting exact wellboregeometry, including angle, andcalculating such parameters ashydraulic horsepower, pill volume,flow rate, choke pressures andback pressures — all based onactual wellbore geometry

• Ensure safety and well control byproviding back-pressure schedulesfor those cases where differentialor bottomhole pressures mustbe maintained

• Provide flexible operating parame-ters for critical wells by simulatingdisplacement in either direction,tracking all fluids in the displace-ment as a function of volume orpump strokes, and displaying posi-tion, pressure, rate and other dataat any point in the wellbore

• Optimize completion fluid eco-nomics by predicting equivalentstatic and local brine densityat any point in the wellbore,accounting for varying temper-atures from surface to bottom,which is especially beneficial inthe cold, deepwater environments

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Powerful software for designing and optimizing wellbore displacements

Engineered Displacement*

VIRTUAL HYDRAULICS NAVIGATOR

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The true value of the VIRTUAL

HYDRAULICS software suite is trulyappreciated in deepwater wellswhere uncontrolled EquivalentCirculating Densities (ECDs) canquickly exceed the boundariesof narrow operating windows, inextended-reach and horizontalwells, in HTHP applications andother technically demanding wells.Proven on thousands of projects,both critical and more routineapplications, this powerful com-putational tool literally givesM-I SWACO engineers a virtualsnapshot of downhole fluid behav-ior — before drilling begins andwhile the well is in progress. Thisaccurate prediction of downholehydraulics has a proven, positiveeffect on overall well performance.

Now, M-I SWACO has raised thebar to an entirely new level withthe release of VIRTUAL HYDRAULICS

Version 3.0. Now you have every-thing you have come to rely on fromthis unparalleled hydraulics moni-toring package, and much more:

• The innovative VIRTUAL

HYDRAULICS NAVIGATOR* 3-Dvisualization system was devel-oped by M-I SWACO to create avirtual window into downholehydraulics and related issues. Theconcept is the ideal combinationof advanced drilling technologyand 3-D computer graphics. TheVH NAVIGATOR module makesit possible to navigate interac-tively through a virtual well andcritically examine and analyzedownhole hydraulics calculatedby VRDH (snapshot case) andVH RHECON* (transient case) ona standard-issue laptop or PCusing a gamepad or keyboard.Invaluable as an analysis tool, theVIRTUAL HYDRAULICS NAVIGATOR

module is also a great training toolfor office-based and field person-nel, as well as non-drillers.

• The VH RHECON provides dynamicreconnaissance simulations to

optimize hydraulics ahead ofthe bit, using predefined drillingparameters

• The OPTIPRO* bit hydraulicsoptimization package in whichrheological properties are resultsof the optimization process

• Improved models and parametricanalyses for hole cleaning, ECDmanagement, 3-D velocity pro-files, downhole temperatures,and pressures and more

• New graphics to address keyhydraulics-related issues

• A totally redesigned, state-of-the-art software system

The wide range of modulesin VIRTUAL HYDRAULICS 3.0covers all the issues inhydraulics modelingWith VIRTUAL HYDRAULICS 3.0,we kept some of the classics thatyou had come to depend on, buthave added a host of newly engi-neered modules that considersevery aspect of hydraulics analysis.Complementing our new VIRTUAL

HYDRAULICS NAVIGATOR, that allowsour engineers to get up close andpersonal with your wellbore, wehave added or enhanced a widerange of modules designed to con-sider every downhole condition.

• VIRTUAL ROTARY DRILLING

HYDRAULICS*, or VRDH, uses down-hole ECD and pressure-loss calcu-lations to generate a veritable“SnapShot” of downhole profiles

• VIRTUAL HYDRAULICS RHECON pro-vides reconnaissance simulations(pseudo real-time analysis) oftransient drilling, tripping andcirculation, and effect on ECDsand hole-cleaning

• The widely used TRIPPRO*, orTRIPPING PROFILES* module pro-vides optimum running speedbased on transient surge and swabmodels combined with variable

downhole fluid properties, andincludes a host of liner surge-reduction tools

• The VIRTUAL HYDRAULICS PLAN*, orVH PLAN*, performs hydraulic opti-mizations based on surface equip-ment limits and downhole ECDand hole-cleaning requirements

• OPTIPRO, or OPTIMUM PROFILES,optimizes fluid rheology andhydraulics based on surface equip-ment limits and downhole ECDand hole-cleaning requirements

• The TPRO* TEMPERATURE PROFILES

generates downhole transient-temperature profiles duringcirculation or shut-in

• DENSITY PROFILES, or DPRO*, pro-vides downhole ESD calculationsbased on PVT characteristics ofbase-fluid and drilling-fluidcomposition

• VOLPRO*, or VOLUME PROFILES cal-culates changes in fluid volumeand trapped pressure in annuli,based on temperature and pres-sure changes in HTHP and LTenvironments

• LEAK-OFF* test module generatesvolume requirements and leak-off pressure and equivalent den-sity calculations accounting fortemperature- and pressure-dependent fluid density

• GEOM* (WELL GEOMETRY) moduleconsiders standard and complexwell geometries, including bypasssubs, subsea BOPs, pilot holes andcoil-tubing, among others

• DIRPRO* (DIRECTIONAL PROFILES)generates both 2-D and 3-Ddirectional profilesAs its predecessor did in the

past, the new-generation VIRTUAL

HYDRAULICS 3.0 promises to delivermore information rather than meredata — information you can useto make educated decisions abouthow to safely, efficiently and cost-effectively drill your well.

VIRTUAL HYDRAULICS Version 3.0 gives you an even clearer view of your fluids’ behavior downhole

Barite Sag

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Sag is defined as a significant variation in mud density, both higher and lower thanthe nominal mud weight, while circulating bottoms-up after a trip or a logging/casingrun. This phenomenon occurs in deviated wells and is most severe in extended-reachwells. Sag can lead to a multitude of well-related problems among which are lostcirculation, loss of well control, stuck pipe and poor cement jobs.

Fundamentals• Occurs on directional wells

with weighted muds

• Primarily a dynamic settlingproblem

• Severity is usually dependent onthe length of the static period(trip, logging/casing run)

• Can lead to a variety ofdrilling/completion problems

Sag indicators• Light mud followed by heavy mud

when circulating bottoms-up

• Abnormal standpipe pressures —U-tube effect due to heavy mud inannulus

• High ECDs, mud losses — BHArotation in a slug with slumpingbarite

• High torque and drag —pipe/barite bed contact

• Unexpected kicks due to the lightmud column

Boycott settling mechanism

Barite sag is the result of dynamicsettling, static settling, and slump-ing. Local settling at top and low-sideof hole during low-rate circulationand static periods create a pressureimbalance which forces lighter mudupwards and accelerates baritesettling (Boycott effect). Mostdifficult well conditions occurwhen barite beds “slump” towardsthe bottom of the hole, causingdensity variation.

Sag-related problems• Lost circulation

• Stuck pipe

• Poor cement jobs

• Loss of well control

• Loss of well

Wells with high risk• High-angle and ERD wells

• Any wells with angle >30° andMW >12 lb/gal (1.44 kg/L) at risk

• ERD wells are most critical —long deviated section

• HTHP wells — mud thinningand product degradation

Factors influencing sagLow-Shear Conditions

• Running casing — creates low-shear annular flow; can beaggravated by excessive thinning

• Tripping/Logging — drillstring/logging tools can break gels andgenerate low-shear flow

• Pumping slowly

• ECD restrictions

• Well-control situations

• Fracture breathing (ballooning) —mud returning from fracturescreates low-shear flow

• Boat ride — rocking motion canbreak gel structure and promotesettling, if not agitated

Drillstring Rotation

• Rotation moves sag beds intoflow stream

• Sliding increases beds buildup

Mass of Weighting Particles

• Finer and lighter particles willsag less

• Adverse effects: higher PVresulting in higher ECD

Time

• Sag severity increases with staticor low-shear time

• Time for running casing/logging should account forsag minimization

Well Design

• Hole angle — wells >30° withMW >12 lb/gal (1.44 kg/L) areprone to sag; <75° may experi-ence slumping

• Pressure and temperature —temperature may induce mudthinning and degradation

• Well and casing design — maypromote sag in low annularvelocity sections

• Hydraulics design — optimizepump rate (minimum ECD withleast sag), annular geometry

Mud Formulation and Properties

• Low-shear rheology —controls dynamic sag

• Gel strengths — mainlycontrol static settling

• Emulsifier and wetting agent —type and concentration

• Low-gravity solids — typeand concentration

• Base-oil selection — affectssag tendency in OBM/SBM

• Oil viscosity

• Interaction with viscosifiersand surfactants

Light Fluid

Suspension Zone

Sag Bed

Slump

Static Dynamic

Deepwater

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While there’s no such thing as easy deepwater projects, there’s one way to makethem less challenging — call M-I SWACO. We’ve helped operators drill more than50% of the world’s deepwater and ultra-deepwater wells, and we’ve learned lessonsthat only experience can teach.

Challenges and solutionsTwo of the major challenges indeepwater are the difficultyand expense involved. Narrowoperating windows, shallowhazards, cold temperatures, well-control problems, logistics andsupply difficulties contribute tothe challenge of operating indeepwater. The expenses comein the form of remote locations;expensive rigs; large volumes ofconsumables, including drilling,reservoir drill-in and completionfluids; and the necessity of usingpremium fluids.

Experience has taughtM-I SWACO a lot about the behav-ior of fluids in the deepwaterenvironment. Solutions to

deepwater challenges are bestovercome through:

• Understanding the technicallimits of equipment andmaterials

• A full range of products andsystems, engineering software,and technical services

• Insistence on the use of thebest available technologyand practices

• A strong commitment to, andinsistence upon, a completemanagement system for deal-ing with the quality, health,safety and environmentalaspects of deepwater drilling

Cold-water temperaturesManaging the drilling-fluid systemto ensure proper fluid behavior atdownhole and riser temperaturescan pose a difficult challengein deepwater drilling. Rigsiterheology testing should be

performed at low temperatures,using a chiller as well as the stan-dard API test temperatures. Thedata should be incorporated intoVIRTUAL HYDRAULICS modeling.

Gas hydratesGas hydrates are ice-likecrystals that form when freewater, hydrocarbon gas, coldtemperatures and high pres-sure are present, i.e., underthe conditions encountered indeepwater drilling. Hydrateplugs can form and preventcirculation of the drilling fluid.Hydrate remediation is a costlyand danger-ous process,so everypossibleprecautionshould betaken toprevent hydrates fromforming in the first place.M-I SWACO recommends thesebest practices at the minimum:

• Target full thermodynamic inhibition

• Primary inhibitor — NaCl

• Secondary inhibitor — glycol

• Utilize WHyP and SWIFTfor modeling

• The M-I SWACO testingfacilities in Houston andStavanger can run hydrate-inhibition tests onspecific fluids

• Contingency for glycol/brine in BOP and choke-and-kill lines

• Consider using invert-emulsion systems as soonas the riser is attached

• Kinetic hydrate inhibitor —EMI-571*

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14

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HYDRAULICS

50 75 100 125 15020

Annulus

Formation

Drillstring

Causes and potential lost-circulation zonesLost circulation occurs by one of the two following mechanisms.

• Natural losses — invasion occurs in, or whole fluidis lost to, formations that are highly permeable,unconsolidated, fractured, cavernous or vugular

• Induced losses — the fluid is lost due to excessiveinduced pressure hydraulically fracturing the formation

Locating the thief zoneLosses are normally “on-bottom” if:

• They first occur while drilling ahead

• The loss is accompanied by a notable change in ROP,torque or drilling roughness

• Induced fractures on-bottom can be caused by aballed-up BHA or bit restricting the annulus

• The loss is due obviously to natural fractures, faults,caverns, vugs or high-permeability sands and gravels.Wellsite geologist — drilling break with an increase intorque and the kelly free falls while drilling, coupledwith an instant loss in circulation.

Losses are normally “off-bottom” if:

• They first occur while tripping, drilling quickly orincreasing drilling-fluid weight

• They are obviously the result of an induced fracture

• They are the result of shutting the well in and killing it

• The annular loading is such that it increases the returnapparent mud weight higher than last casing shoefracture gradient

Designing and managing bridging agents — Particle-Size Distribution (PSD) • Ideal Packing Theory (IPT) can be defined as the full

range of particle-size distribution required to effec-tively seal all voids including those created by bridgingagents. A good rule of thumb is having D90 equal to theopening sizes of the fractures.

• M-I SWACO proprietary software for PSD optimizationis called OPTIBRIDGE. The program enables the user todetermine the optimum blend of bridging materialsby inputting either maximum pore size or, if available,permeability.

Lost Circulation

78

Perhaps no downhole problem has a more profound and widespread economicimpact on drilling operations than lost circulation. In fact, it has been reportedthat the complications associated with lost returns cost the industry hundreds ofmillions of dollars a year.

DefinitionLost circulation or lost returns are the partial or totalloss of whole drilling fluid to subsurface formations.Lost circulation occurs when the openings in theformation allow the passage of whole fluid into theformation, resulting in losses ranging from 1 bbl/hrto complete loss of returns.

ProblemsEconomics is the biggest problem associated with lostreturns. When circulation is lost, the drilling-fluid costsrise appreciably, along with the expenses associatedwith rig and equipment delays.

Smaller particles fill any remaining gaps Large blocking particles

providing initial bridging

Wellbore Stability

Regardless of the chemical composi-tion of the fluid and other factors,the weight of the mud must bewithin the necessary range to bal-ance the mechanical forces actingon the wellbore (formation pres-sure, wellbore stresses related toorientation and tectonics). Wellboreinstability is most often identifiedby a sloughing formation, whichcauses tight hole conditions, bridgesand fill on trips. This often makesit necessary to ream back to theoriginal depth. (Keep in mind thesesame symptoms also indicate hole-cleaning problems in high-angleand difficult-to-clean wells.)

Wellbore stability is greatestwhen the hole maintains its originalsize and cylindrical shape. Once thehole is eroded or enlarged in anyway, it becomes weaker and moredifficult to stabilize. Hole enlarge-ment leads to a host of problems,including low annular velocity,poor hole cleaning, increasedsolids loading, fill, increased treat-ing costs, poor formation evalua-tion, higher cementing costs andinadequate cementing.

Hole enlargement through sandand sandstone formations is due

largely to mechanical actions, witherosion most often being causedby hydraulic forces and excessivebit nozzle velocities. Hole enlarge-ment through sand sections maybe reduced significantly by follow-ing a more conservative hydraulicsprogram, particularly with regardto impact force and nozzle velocity.Sands that are poorly consolidatedand weak require a slight over-balance to limit wellbore enlarge-ment and a good-quality filtercake containing bentonite to limitwellbore enlargement.

In shales, if the mud weight issufficient to balance formationstresses, wells are usually stable —at first. With water-base muds,chemical differences cause inter-actions between the drilling fluidand shale, and these can lead (overtime) to swelling or softening. Thiscauses other problems, such assloughing and tight hole condi-tions. Highly fractured, dry, brittleshales, with high dip angles, canbe extremely unstable when drilled.The failure of these dry, brittle for-mations is mostly mechanical andnot normally related to water orchemical forces.

Various chemical inhibitors oradditives can be added to helpcontrol mud/shale interactions.Systems with high levels of cal-cium, potassium or other chemicalinhibitors are best for drilling intowater-sensitive formations. Salts,polymers, asphaltic materials, gly-cols, oils, surfactants and othershale inhibitors can be used inwater-base drilling fluids to inhibitshale swelling and prevent slough-ing. Shale exhibits such a widerange of composition and sensi-tivity that no single additive isuniversally applicable.

Oil- or synthetic-base drillingfluids are often used to drill themost water-sensitive shales inareas with difficult drilling condi-tions. These fluids provide bettershale inhibition than water-basedrilling fluids. Clays and shales donot hydrate or swell in the continu-ous phase, and additional inhibitionis provided by the emulsified brinephase (usually calcium chloride) ofthese fluids. The emulsified brinereduces the water activity and cre-ates osmotic forces that preventadsorption of water by the shales.

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Wellbore stability is a complex balance of mechanical (pressure and stress) andchemical factors. The chemical composition and mud properties must combineto provide a stable wellbore until casing can be run and cemented.

INTEGRATED FLUIDS ENGINEERING

What is IFE?The INTEGRATED FLUIDS ENGINEERING

(IFE) approach is a totally differentmethod of drilling and completing awell. It is a results-driven and com-prehensive fluids solution whichoptimizes the design, deliveryand management of wellsite fluidsand fluids-related services. TheIFE program utilizes all M-I SWACOproducts, equipment and tech-nology engineered by highlytrained personnel.

INTEGRATED FLUIDSENGINEERING was created for challenges• High day rates and shrinking

budgets demand that operatorsreach TD quickly and that pro-ducing formations yield the mostoil and gas possible

• The use of expensive, sophisticatedequipment requires logistics andoperations to be carried out seam-lessly, with no gaps or overlaps

• Increasingly stringent regulationsare putting a bigger burden onoperators to improve health andsafety conditions, and eitherreduce the amount of drillingwaste or bear the costs of dealingwith it

The bottom line — get the mostproductivity from every person,service, instrument, tool and prod-uct used in drilling and completingyour wells.

The IFE approach optimizes your drilling wastemanagement programIn planning your well, M-I SWACOengineers look at the whole picture,including the generation and man-agement of drilling waste. We willalways strive to manage wastesat the highest possible (widest)level of the pyramid, and thenmove down the priorities ascircumstances dictate.

Making the most of valuable informationOne of the tools we use in ourimprovement process is our pro-prietary software. As various situ-ations and needs have arisen,M-I SWACO has authored fit-for-purpose computer programs tosupport the IFE mission. Thispowerful, industry-acceptedsoftware suite is another reasonthat only M-I SWACO can pro-vide true INTEGRATED FLUIDS

ENGINEERING solutions. OurIFE-related software includes:

• ONEPLAN/ONE-TRAX*• PRESSPRO RT• OPTIBRIDGE

• VIRTUAL HYDRAULICS

• VIRTUAL COMPLETION FLUIDS*• WASTE MANAGEMENT ADVISOR*

80

Reducing your drilling time, lowering your drilling costs, increasing production and meeting your environmental objectives. More than 1,600 wells have proven it.


Any well, whether complex or rela-tively simple, where there is roomfor improvement in drilling time,production rates, environmentalissues and overall costs.

� P R O B L E M S

Traditional bundled services oftenpresent problems of gaps, overlapsand even conflicts among theservice companies. This resultsin lost time and money as wellas increased risks to health, safetyand the environment.


The M-I SWACO IFE approachensures that all fluids-related serv-ices and equipment work in concertwith each other to shorten drillingtime, increase production, meetenvironmental regulations andlower overall costs.


With all the well’s aspects plannedfar in advance, and a true integra-tion of personnel, services andequipment, IFE will reduce overalldrilling and completion costs.


During well planning, certifiedM-I SWACO IFE personnel coordinateall the factors that influence theenvironmental performance of thewell, including fluids, drilling wastemanagement methods and equip-ment, and post-well operations.

Waste minimization: prioritized strategy

Wasteminimization

Reduce

Reuse

Recycle

Recover

Residue

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Drilling and Reservoir Drill-In Fluids• Hole cleaning

• Barite sag

• Bit balling/accretion

• ECD margins

• Lost circulation

• Bottomhole temperature

• Pressure control/UBD

• Stuck pipe

• Depleted zones

• Contaminants

• Rate of Penetration (ROP)

• Drilling salt/subsalt

• Formation damage

• Hydrates

• Formation evaluation

Drilling Waste Management• Solids-removal efficiency

• Screen life and performance

• Mud Retention On Cuttings (ROC)

• Liquid-drilling-waste volume

• Solid-drilling-waste volume

• Long-term liability

Completion Fluids• Formation damage

• Displacements

• Wellbore cleanup

• Precipitates

• Asphaltenes

• Solids plugging

• Water block

• Fines migration

SPEEDWELL* Tools• Risk of connection failure

• Trips after drilling cement

• Expensive downhole equipment

Mixing Technologies• Chemical/polymer consumption

• Mixing pad mud for riserless drilling

• Additional mixing capacity

General (all products and services)• Cost

• Logistics

• Downtime/non-productive time

• Quality, Health, Safety and Environmental (QHSE)

By integrating key M-I SWACO products and services, IFE gives you real value, positively affecting factors that determine your success

SPEEDWELL Tools

You can trust the SPEEDWELL* prod-uct line to perform even in theharsh conditions that treacherousdownhole environments can throwat an operation with no warning.We have been an integral part offishing and milling operations, dis-placements, solids removal, debrisretrieval, and perforation cleanup

in every major drilling area ofthe world.

M-I SWACO has established anintegrated, time-saving approach tothe wellbore cleanup and displace-ment operation. The M-I SWACODisplacement Tool Box includes ourSAFE* Series cleanup and displace-ment chemicals, filtration, ourVIRTUAL HYDRAULICS program, the

torque-reduction program and,of course, the SPEEDWELL line. Thisgives our customers the most inte-grated, comprehensive approachto dealing with the most challeng-ing wells anywhere in the world.This is just a sample of the overallspud-to-production approachthat M-I SWACO will bring toyour operation.

82

The modular tool design eliminates the need for a pup joint rental while providing brush and scraper carriers, as well as additional items, all on one tool

One-piece mandrel isconstructed of high-yield steel,is designed for drilling cement and has no external fasteners.

One tool carries everything:

scrapers, brushes, magnets, gaugerings and handling features inaddition to providing excellentannular bypass so solids can exitthe cased hole.

Double-crimped,

stainless steel

brushes stand up toharsh operating condi-tions and do not rotate.They outperform carbonsteel, straight-wire brushesthat become brittle and break fromchemical exposure and move-ment. Wear values have beenestablished to ensure continuousbrush contact throughout the run.

Centralizers rotate

independently

of the workstring toreduce wear on casingand liner. SPEEDWELL

can eliminate the need for a gaugering by placing a centralizer at drifton your PUP tool.

Larger-bore mandrels allowthe fluid to do its work, promotingbetter circulation and reversecirculation for solids removal.

Non-rotating magnets can berun on the same mandrelwith scraper and brushcarriers, eliminating theneed for additional toolson your next project.

Junk basket carriers canbe placed on the PUP

mandrel, just likebrushes, scrapers andmagnets. The basketshave an unrestricted,360° opening at the top.

Two styles of non-rotating

scraper blades:

Knurled-face-style foraggressive cleaning andsmooth-face-style forspecial requests. Wearvalues have been estab-

lished to ensure continuous bladecontact throughout the run.

SPEEDWELL modular tool design

allows you to run the toolwith a regular box downto eliminate a bit sub.We can also furnish bitor mill, already made upon the tool.

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The flexible, SPEEDWELL approach gives you maximum effectiveness on any well

Liner-top testing and cleanup

Riser cleaningand jetting

Cased-hole cleanup anddebris removal

Perforation-debriscleanup

P.O. Box 42842Houston, Texas 77242-2842

Tel: 281·561·1300Fax: 281·561·1441

www.miswaco.comE-mail: [email protected]


FMC.0600.0604.R1 (E) 500 Litho in U.S.A.

This information is supplied solely for informational purposes and M-I SWACO makes noguarantees or warranties, either expressed or implied, with respect to the accuracy and useof this data. All product warranties and guarantees shall be governed by the Standard Termsof Sale. Nothing in this document is legal advice or is a substitute for competent legal advice.

fluids catalog

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