Fluids Catalog

2006 Systems, Products and Services Catalog

FLUIDS

F L U I D S

T E C H N O L O G Y ,

E N G I N E E R I N G

A N D

S O L U T I O N S

TABLE

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F L U I D S

T E C H N O L O G Y

Drilling-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

OPTIBRIDGE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 70 PRESSPRO RT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72 VIRTUAL CF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 74 VIRTUAL HYDRAULICS NAVIGATOR . . . . . . . . . . 75 S O L U T I O N S

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

CONTENTS

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

OF

Barite Sag . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76 Deepwater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 77 Lost Circulation. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78 Wellbore Stability . . . . . . . . . . . . . . . . . . . . . . . . . . . . 79

TABLE

F L U I D S

CONTENTS

E N G I N E E R I N G

OF

F L U I D S

TABLE

SAFE-LINK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 67 FILTER FLOC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68 SAFE-BREAK CBF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68 SAFE-LUBE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68 SAFE-T-PICKLE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68 Workover and Completion Fluid Products Listing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 69

CONTENTS

DIPRO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36 FAZEPRO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38 FLOPRO NT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 FLOPRO SF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42 FLOTHRU . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 44 FORMIX Technology . . . . . . . . . . . . . . . . . . . . . . . . . . . 46 NOVAPRO/VERSAPRO/PARAPRO . . . . . . . . . . . . . 48 VERSAPRO LS/SF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50

Workover and Completion Fluid Systems

OF

Reservoir Drill-In Fluid Systems

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

TABLE

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

Drilling-Fluid and RDF Products

CONTENTS

About M-I SWACO

OF

Table of Contents

SPEEDWELL Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 82 TABLE OF CONTENTS

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

Drilling Waste Management In order to provide customers with a truly integrated suite of services, M-I SWACO is continuously expanding and strengthening its drilling waste management capabilities. This gives drilling contractors and operators the ideal combination of equipment and services for drilling in environmentally sensitive areas and/or in zero-discharge conditions.

Drilling Fluids M-I SWACO* provides a complete offering of oil-, water- and synthetic-base drilling fluids and additives.

Reservoir Drill-In and Completion Fluids (RDF) Our complete line of reservoir drill-in, completion and workover fluids and additives help make oil and gas wells more productive. We also offer fluid-reclamation and -filtration services as a complement to this segment.

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Solids-control equipment. M-I SWACO manufactures, sells and rents a complete line of shale shakers, desanders, desilters, hydrocyclones, mud cleaners, centrifuges and oilfield screens. Pressure-control equipment. Chokes and operating consoles, degassers and mud/gas separators give drilling contractors and operators the ability to drill safely and economically in sour-gas and highpressure zones. M-I SWACO technological innovations such as the ECHOKE* and SUPER AUTOCHOKE* are helping our customers drill for extended intervals under extreme well conditions.

Waste management. This category covers a range of wasteminimization and treatment services, including: • AUTOMATIC TANK CLEANING (ATC) • Bioremediation/landfarming • Cuttings drying (VERTI-G*) • Cuttings slurrification and Re-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 drillcuttings processing services make M-I SWACO uniquely capable of meeting today’s cuttings collection and treatment needs. Our specialists make recommendations and develop remediation strategies that define the most effective methods for each application.

ABOUT – –

M-I SWACO ABOUT

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M-I SWACO

INTEGRATED FLUIDS ENGINEERING* (IFE*)

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SWACO ABOUT

SWECO* is a leading manufacturer of customized industrial separation equipment and has also become the primary manufacturer of M-I SWACO oilfield equipment.

M-I

FEDERAL* Industrial Products specializes in marketing drilling-fluid products and chemicals to general industrial, geotechnical, construction and foundry industries.

FEDERAL Wholesale provides wholesale drilling-fluid products to other mud companies that require products without engineering services.

ABOUT

M-I HDD MINING & WATERWELL* markets drilling-fluid products and additives to the waterwell, mining and trenchless-technology (Horizontal Directional Drilling or HDD) industries.

SWACO

M-I PRODUCTION CHEMICALS* is a leading provider of corrosion inhibitors, demulsifiers and water clarifiers, scale inhibitors and dissolvers, bactericides, defoamers, wax and asphaltene inhibitors, H2S scavengers, hydrate inhibitors, water-injection chemicals, commodity chemicals, and maintenance and utility chemicals.

ALPINE MUD PRODUCTS* provides specialty drilling-fluid additives for lubrication and hole stability, featuring liquid dispersed Gilsonite^ and co-polymer drill beads.

M-I

M-I SWACO Affiliates

ABOUT

brings together all the capabilities M-I SWACO has to offer. IFE provides a level of integration and cooperation among fluids-related disciplines that delivers quantifiable value.

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M-I SWACO ABOUT

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M-I SWACO

^Gilsonite is a mark of American Gilsonite Company.

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compliance. M-I SWACO has specialists assigned to oversee occupational health standards, practices and issues. Safe driving practices, safe working conditions and continual safety training are hallmarks of M-I SWACO people and workplaces, because respect for the individual drives the company and everything it does. UNITED WIRE* and SOUTHWESTERN WIRE CLOTH* are the worldwide leaders in oilfield and industrial screen technology, manufacturing and marketing screens for all makes of oilfield shakers, providing wire cloth and screening products for a broad range of industrial markets, and supplying sand screens for the petroleum-production industry. SULFATREAT* specializes in technologies and products that remove hydrogen sulfide from gases and liquids.

Quality, Health, Safety and Environment Every aspect of M-I SWACO and its activities is permeated with a strong sense of caring for the health and safety of the people and the environment where they work. Our people not only look out for each other but for those around them — customers, suppliers, competitors and community members. We train our people to work safely within our facilities and offices as well as at our customers’ sites and on their rigs. All of our regions and many of our larger districts have dedicated QHSE managers to ensure safe working practices and environmental

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Training and Career Development To be sure our personnel are the best trained in the industry, M-I SWACO has a dedicated Training and Career-Development Department and fosters a culture where our people continually improve and increase their skills and expertise. Through training, we strive to create value on every one of our clients’ projects. Internal training for M-I SWACO personnel ranges from teaching

basic skill sets for entry-level employees to advanced training for experienced people. In addition to basic mud school, M-I SWACO provides formalized training in drilling waste management, INTEGRATED FLUIDS ENGINEERING (IFE) and Cuttings Re-Injection (CRI). To ensure consistent quality in our people, we have standardized our training worldwide, so our customers can count on our people to solve their problems anywhere in the world. We provide continuing education throughout a person’s professional life with the company, and for fasttracking promising individuals who look for challenges, our ProACT program accomplishes in a few years what once required decades of experience. Our planned careerdevelopment and mentoring programs ensure that M-I SWACO people have every opportunity to succeed for themselves, for the company and for our customers.

ABOUT – –

M-I

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M-I SWACO ABOUT

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M-I SWACO ABOUT

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M-I SWACO ABOUT M-I

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Continual training — Changing customer needs, more sophisticated well programs and rapid technological advances are making knowledge of our industry a moving target. Continuous training for ourselves and our customers is the answer.

Mining, manufacturing and distribution — The best way to ensure absolute consistency and performance in our products is to control them from manufacturing through delivery. At every step in the process, we make sure that raw materials and finished products meet the highest standards. Through online inventory and delivery systems, we keep our customers supplied with the products they need when they need them, giving them a better return on their investment.

ABOUT

Environmental support — We optimize the “environmental equation” by making environmental concerns a part of every job, from product development to disposal. Through our ENVIROCENTER* facilities, bulk cuttings-transport systems, thermal desorption technology and other innovations, M-I SWACO is the industry leader in managing drilling wastes.

SWACO

Technical support — Our Research and Engineering Center in Houston and technical centers in Stavanger and Aberdeen provide 24-hr assistance for operations anywhere in the world.

M-I

Engineering — M-I SWACO onsite engineers and project engineers quickly respond to changing situations backed by the extensive resources at our labs and offices around the globe.

Technology development — In solving problems for our customers, we’ve developed new systems and unique ways of using them. We have people and processes in place that represent every activity, from the laboratory to the field, needed to create problem-solving technologies and promote best practices throughout the company.

ABOUT

Every day, M-I SWACO people are engaged in the critical activities that give our customers the assurance that they can rely on us for solutions to their problems:

SWACO

Customer-Focused, Solutions-Driven

SWACO

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APHRON ICS Invasion-Control System Technology that closes the door on formation invasion and opens the door to a range of drilling applications


APPLICATIONS

Wells being drilled in depleted reservoirs or any geology characterized by porous sands or laminated sequences of sand and shale. Also, some applications where underbalanced drilling is the only option.


PROBLEMS

When drilling sand and sand/shale sequences, operators must often use extra casing strings or costly underbalanced-drilling techniques.


SOLUTIONS

The water-base APHRON ICS* system uses microbubble (“aphron”) technology to stabilize problem zones. When a low-pressure zone is encountered, the tough aphrons enter the formation and expand to equalize formation pressure.




E C O N O M I C S

The APHRON ICS system gives operators a way to access reserves economically in depleted reservoirs. By reducing lost circulation and stuckpipe incidents, the system further reduces drilling costs.


ENVIRONMENTAL

The APHRON ICS (Invasion-Control System) system is an engineered drilling-fluid system that controls losses in depleted, high-porosity sands while stabilizing pressured shales. This means you can use conventional drilling equipment to successfully complete many reservoirs that previously would have been candidates only for underbalanced drilling. The APHRON ICS design software, which tailors the system to your well, and the fluid’s ability to control losses significantly decrease the potential for differential sticking and other fluid-related problems. The outstanding performance of this system makes it a sound economic option for: • Underbalanced drilling • Areas where lost-circulation material has proven ineffective in controlling drilling-fluid losses or in providing desired bridging

Pressure Analysis of APHRON ICS Performance 4,800 (1,463) Depth: ft (m)

4,900 (1,494)

5,000 (1,524)

5,100 (1,554)

5,200 (1,585) 2 (0.24)

6 (0.72)

Although this interval had a severe drop in pore pressure (from 7 to 3 lb/gal [0.84 to 0.36 kg/L] equivalent), the APHRON ICS system 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) surface density, was being used.

Cleanup 40 Days

• Depleted formations coexisting with normally pressured formations

30

20

10

0

Features

Benefits

• Tough, stable microbubbles • High LSRV • Reduces the effects of highpressure differentials • Good cuttings transport • Can be used in low-pressure environments • Customized design and selection software

• Improves drilling efficiency • Easier drilling in high-angle and horizontal wells • Reduces lost circulation and risk of stuck pipe • UBD alternative • Improves field economics • Environmentally acceptable • Significantly reduces cleanup times and costs

10 (1.20)

lb/gal (kg/L)

Gel/polymer

8

8 (0.96)

MDT equivalent formation pressure Surface fluid weight Annular ECD

• High-angle/horizontal wells

Its water-base formulation makes the APHRON ICS system acceptable in most drilling areas. The organic, biodegradable polymers and noncaustic pH materials provide a balance between operational efficiency and environmental acceptability.

4 (0.48)

APHRON ICS

The APHRON ICS system has proved itself in the field, resulting in wells that show greatly reduced cleanup times and costs.

Annulus Higher-pressure zone

Microenvironment ∆p

Formation Lower-pressure zone

The excellent condition of the final borehole significantly improves the acquisition and quality of data obtained with electronic logs, and promotes optimum results from MWD tools.

Lower drilling costs in depleted reservoirs

APHRON ICS bridging mechanism

A microenvironment compatible with the macro-environment The organic, biodegradable polymers and non-caustic pH materials that make up the APHRON ICS system provide a healthy balance between operational efficiency and environmental acceptability. The system meets or exceeds regulatory statutes, such as those for the Gulf of Mexico, Canada and the North Sea.

A

B A. Aphrons have an affinity for one another, causing them to form a bubble system in the formation openings. B. Laplace pressure is exerted against the formation openings as the aphrons expand in the lower-pressure openings.

DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

The APHRON ICS system’s LowShear-Rate Viscosity (LSRV), combined with its stable microbubbles, helps you control losses when drilling through depleted reservoirs. In addition, the flexible microbubbles enable operators to economically access reserves where depletion has altered the mechanics of the field,

forcing the use of additional casing strings or costly underbalanceddrilling techniques.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

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

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

How the system protects sensitive formations

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


APPLICATIONS

Drilling lost-circulation zones, casingmilling operations, stabilizing unconsolidated formations, coiledtubing operations, environmentally sensitive areas, and high-angle and horizontal wells.


PROBLEMS

Many drilling operations require a fluid system that is cost-effective and environmentally acceptable in addition to having exceptional hole-cleaning ability, good screenability at high flow rates and the ability to control losses in hard rock as well as unconsolidated sedimentary formations.

Ordinary bentonite, extraordinary results Simply combining the DRILPLEX viscosifier with pre-screened, high-quality bentonite produces a highly shear-thinning fluid with a high yield point, low plastic viscosity and high, flat gel strengths. The result is a fluid system with unequaled solids suspension, but one that still screens easily, even at high flow rates.

The bentonite/MMO associates into long ribbon-like structures that can bridge openings with diameters measured in 10s of microns.


SOLUTIONS

The DRILPLEX* system is the latest generation of Mixed-Metal Oxide (MMO) products, a water-base drilling-fluid system with unequaled solids suspension, but one that still screens easily, even at high flow rates — the ideal system for an array of applications.


ECONOMICS

The system’s water-base chemistry reduces costs and environmental problems, minimizes torque and drag, and limits the chance of hole erosion because the DRILPLEX system provides flow that is low to zero across the wellbore.


ENVIRONMENTAL

The basic DRILPLEX system contains essentially no components that can harm the environment. The system and all its components are virtually non-toxic, with a low concentration of organic material. The primary fluid-loss-control additive is a starch derivative for minimal environmental impact.

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Rheogram Showing Unique Rheological Properties The data was obtained on a Fann 35A viscometer. Both fluids were unweighted. 80 Dial reading 70 60 50 40 XC polymer PV 12 YP 48 Gels 28/40 n 0.263 K 11.6

30 20 10 0 0

100

200

300

400

Rheometer speed

500

600

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

You might think that a system with the versatility and application range DRILPLEX has demonstrated would involve intricate and difficultto-engineer chemical compositions. On the contrary, the proprietary FLOPLEX* primary fluid-loss-control additive and the DRILPLEX viscosifier are the only components developed specifically for the DRILPLEX system. The remaining chemicals are relatively common and well understood.

A diverse, worldwide track record

Stationary, gelled layer of fluid

Excellent cuttings transport

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

The unique mechanism driving DRILPLEX Bentonite platelet

MMO crystals

Features

Benefits • Ideal for lost-circulation zones, unconsolidated formations, milling situations, and high-angle and horizontal wells • Minimizes losses • Reduces environmental impact • High rates of penetration • Well-suited for coiledtubing drilling • Cost-effective

Bentonite/MMO complex

1 micron

The mixed-metal oxide comprising the core of the system has an electron-deficient lattice, and when added to water, the DRILPLEX particles bond to the cation exchange sites on bentonite, forming a strong complex, which in turn structures the fluid and provides viscosity and gels. When the MMO crystals are added to a suspension of bentonite platelets, the cationic crystals displace the naturally “resident” sodium or other cations and form strong associations with the anionic sites on the faces of the clay platelets. What results is a new complex or adduct with

characteristics that are fundamentally different from those of a virgin bentonite platelet. The entire mechanism appears to be electrostatic in nature, which makes it somewhat unusual and accounts for the unique characteristics of the fluid system. For example, an electrostatic-fieldbased mechanism could explain the elastic or deformable-solid behavior observed in the absence of shear and could also explain both the dramatic and instantaneous onset of the solid-to-liquid transition and the reversibility of the process.

DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

• Latest-generation MixedMetal Oxide (MMO) system • Highly shear-thinning • Excellent QHSE profile • Temperature-stable to 250° F (121° C) • Exceptional hole cleaning and suspension • Excellent ability to seal the high-permeability formations found in deepwater drilling

The flow profile of the fluid in the annulus affords DRILPLEX the ability to stabilize mechanically weak and poorly consolidated formations. The high viscosity of the fluid at low shear rates results in a stationary layer of fluid on the sides of the wellbore. This protective layer shields weak rock formations from erosion caused by the flow. The capacity of the fluid to stabilize these weak and unconsolidated formations is further enhanced by the lower pump rates used with the DRILPLEX system. This tendency may also explain the lower seepage losses that occurred in several wells in which the formations were fractured.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Challenging horizontal wells in the Gulf of Mexico. The establishment of milling records in the North Sea and elsewhere. Drilling in nearly 9,000 ft (2,743 m) of water in the Campos Basin with zero losses. In West Africa, the successful drilling of a depleted reservoir and unconsolidated formation with a maximum angle of 102° F (38.8° C). The success stories go on and on.

The ability to stabilize goes with the flow

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

A straightforward system for the most complex applications

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


APPLICATIONS

Offshore and onshore wells where a high-performance system is required along with the environmental benefits and drilling characteristics of a water-base system. This includes large-diameter wellbores, ERD, deepwater and subsalt applications.


PROBLEMS

Many high-performance systems, especially those designed for high performance and inhibition, are oilbase products with characteristics that are not sanctioned by environmental regulations or that pose cleanup and disposal problems.


SOLUTIONS

The GLYDRIL* system uses an enhanced-polymer, water-base chemistry that employs polyglycol technology to deliver a high degree of shale inhibition; wellbore stability; High-Temperature, HighPressure (HTHP) fluid-loss control; and lubricity.


ECONOMICS

The GLYDRIL system delivers lower dilution rates, higher Rate of Penetration (ROP) and lubricity, and lower disposal and environmental costs.




E N V I R O N M E N T A L

Offshore: relatively low marine toxicity and fast biodegradation rates, minimal cuttings piles, and benthic impact. Onshore: shale inhibition without the use of salts, no aromatic or cyclic hydrocarbon compounds.

Proven by the M-I SWACO team in hundreds of wells worldwide, the GLYDRIL system uses an enhancedpolymer, water-base chemistry that employs polyglycol technology. Thanks to that technology, operators can count on the GLYDRIL system to deliver a high degree of shale inhibition; wellbore stability; HTHP fluid-loss control and lubricity. Because no two wells are alike, M-I SWACO offers a range of glycols to meet all drilling needs.

GLYDRIL and ROP enhancement Like most water-base systems, the GLYDRIL system’s performance can benefit from the addition of an ROP enhancer in certain applications. Please contact your M-I SWACO representative to derive maximum benefit from the GLYDRIL system and any performance-boosting additives.

Shale-Recovery Comparisons

Customization makes GLYDRIL the right choice for a variety of applications

100% Cuttings recovery

In fact, the system’s broad range of glycols makes it a preferred system where environmental guidelines dictate a water-base fluid. The GLYDRIL system can be customized to meet a variety of drilling challenges — large-diameter wellbores, extended-reach drilling, deepwater and subsalt applications, and particularly reactive shales. The system also is ideal for drilling high-angle wells in reactive shale formations — where wellbore stability, torque and drag are major concerns. In addition, the glycols in the GLYDRIL system enhance the thermal stability of both FLO-VIS*/DUO-VIS* and Polyanionic Cellulose (PAC)/starch systems, and also enhance the low-shear rheological behavior of FLO-VIS polymers at temperatures above 248° F (120° C).

60

90 80 70

50 40 30 20 10 0 Gel PHPA

KCl PHPA

Wet cuttings

Glydr il

Dry cuttings

Fluid-Loss Comparisons 14 cc Fluid loss

12

10

8

6

4

2

0 KCl/PHPA

API

12

GLYDRIL

HTHP (200° F [93° C])

OBM

Lower dilution rates. Higher ROP and lubricity. Lower total costs. The GLYDRIL system is one more example of the M-I SWACO pledge to provide customers the most appropriate, cost-effective drilling fluids and systems.

As temperature increases and chemical environment changes, polyglycol clouds out. Soluble polyglycol enters shale pores.

Engineering experience comes with every ounce of GLYDRIL

GLYDRIL is the right choice for the environment, too

Features

Benefits

• Low-toxicity, water-base system • Relatively fast biodegradation • Shale inhibition • Pore-plugging, Thermally Activated Mud Emulsion (TAME) properties • Improved filter-cake quality • Pipe-wetting capabilities

• In-gauge wellbores • Lower fluid losses and leak-off values • Lower potential for differential sticking • Less torque, drag and bit balling • Lower dilution rates • Slicker, firmer filter cake • Greater wellbore stability

DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

The products that make up the GLYDRIL system are formulated to address environmental concerns worldwide, both offshore and on land. For offshore operations, the system displays relatively low marine toxicity, provides relatively fast biodegradation rates, and minimizes cuttings piles and benthic impacts. Onshore, the GLYDRIL system can be engineered to provide shale inhibition without the use of salts and contains no aromatic or cyclic hydrocarbon compounds, making cuttings ideally suited for landfarming.

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

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Having the right drilling fluid is only one part of the story. M-I SWACO also has the experience to help operators apply products to control rheology, fluid loss and density. In the case of the GLYDRIL system, that experience helps determine the proper concentration and choice of glycol additive. We can even help you monitor glycol concentrations through the use of optical refraction techniques. Wherever you operate, M-I SWACO has the experience that can make your operations run more smoothly and cost effectively.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Compare performance, then save with GLYDRIL

13

NOVA Systems The environmentally sound alternative to traditional drilling fluids The NOVA* line has proven itself in some of the stickiest applications.

significantly improved drilling rates and improved lubricity

• Where increased rates of penetration are required to reduce total time spent drilling the well, reducing overall well costs

• The choice of low synthetic-towater ratios to reduce formulation costs and environmental impact

• Drilling through highly reactive shales where aqueous fluids produce wellbore instability and viscosity problems associated with hydration and dispersion of the formation

• Excellent wellbore, temperature and contamination stability

• High-angle wells, including extended-reach and horizontal wells where maximum lubricity is a high priority • Controlling the stability and gauge of the wellbore while drilling through massive salt sections • Depleted reservoirs where high differential pressures require low fluid loss, as well as the best available filter cake and lubricity to reduce the potential for differential-pressure sticking • Production zones that may be sensitive to formation damage when drilled with water-base fluids • High-pressure, high-temperature (>350° F or >177° C) wells where continuous phase temperature stability is critical • While drilling wells with potential formation-related problems: bit balling, gumbo heaving and blinding of shale shaker screens

The NOVA line has what you’re looking for to replace your conventional system • Compared to water-base systems, NOVA systems deliver

14

• The ability to discharge cuttings

• Superior return permeability results, ensuring minimal formation damage • Increased hole cleaning, even in high-angle wellbores • Improved health and safety compared to oil-base systems • The choice of rheological profile to suit drilling requirements • Available in a wide range of drilling-fluid properties and densities

NOVA systems deliver superior drilling performance Although the cost per barrel of a NOVA system is higher than traditional, water-base systems, its improved performance significantly outweighs the initial investment. M-I SWACO customers report that NOVA systems have reduced their overall drilling costs by up to 55%. And rigs running NOVA systems programs have set world-record penetration rates, representing improvements of up to 70% compared to other mud systems. NOVA systems have also reduced costs by minimizing wellbore stability problems associated with hydratable clays. The substantial improvement in hole gauge obtained by using NOVA

fluids delivers in-gauge wellbores. This means better logging and casing runs, reduced bit-balling, fewer stuck-pipe and downtime incidents, and a substantial reduction of waste volumes and cement consumption. Along with record-breaking drilling rates, NOVA systems provide superior hole cleaning and lubricity for drilling “designer,” high-angle, extended reach wells. The filter cake characteristics of a NOVA system provide excellent lubricity equal to or better than that provided by oil-base systems. Lubricity, combined with effective cuttings removal, results in significant reductions in torque and drag.

The NOVA line satisfies virtually every country’s environmental regulations One of the main reasons for developing a synthetic-base system was environmental considerations. NOVA systems not only have proven less damaging (environmentally) than diesel-base and mineral-oil-base systems, but they also generate less waste than water-base systems. Among the many stringent environmental tests conducted on NOVA systems are those for the North Sea and the Gulf of Mexico. The North Sea area requires that, for approval for use/discharge offshore, all drilling chemicals and fluids pass a series of tests for toxicity to specific aquatic organisms and that biodegradation/degradation testing be conducted under marine conditions. Each sector within the

Details of, and results from, the testing procedures for eye and skin irritation are available upon request. A significant safety benefit provided by the NOVA products are high flash points. This is confirmed by the results of a study to detect and analyze the vapors emitted by the base fluids at different temperatures. The reduction in vapors has improved the work environment, especially in enclosed areas around shale shakers and mud pits.

M-I SWACO supports the NOVA line with complete environmental testing and analytical services

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

M-I SWACO confirms the environmental acceptability and regulatory compliance of its products. We maintain an environmental division within our R&D departments in Houston and Aberdeen and have the ability to run all tests for U.S. protocols within our own facilities. An in-house analytical department can supply further tests, including gas chromatograph/mass spectrometer for evaluating fluid samples for early signs of contamination. Extensive screening and analysis of synthetic-base fluids has made M-I SWACO a leader in understanding environmental issues, a function of developing technologies that optimizes drilling performance and minimizes environmental impact. Among the environmental services with which we support our NOVA line are: coordinating research samples, conducting seabed impact studies, developing appropriate protocols, interfacing with government officials and providing onsite monitoring.

Skilled engineers and full computer support ensure high productivity on your well. It takes highly trained drilling-fluid engineers to support the exceptional NOVA line. In addition to the extensive training in drilling fluids and our advanced programs, our engineers receive in-depth training in running NOVA systems, including the environmental and QHSE aspects of the systems. We support our rigsite engineers with local, area technical services supervisors and a technical services group working at our R&D facilities. This critical well support group of field and staff engineers has at its disposal some of the most advanced software available. MUDVOL* is a program used on a daily basis to track any losses of NOVA system fluids while drilling and to provide information about the volume of fluid discharged into the sea. By analyzing the results from MUDVOL, M-I SWACO engineers can detect areas where fluid loses can be reduced, saving money. VIRTUAL HYDRAULICS* is proprietary software that provides calculations for dynamic downhole conditions involving temperature and pressure specifically for NOVA systems. Our engineers use it to determine pressure drops, equivalent circulating densities, standpipe pressures and more. This information is extremely valuable when planning well hydraulics to minimize losses in areas of low fracture gradients. Supporting our field engineers is the most extensive drilling-fluids plant and warehouse network in the industry. This distribution network ensures that M-I SWACO customers have access to the NOVA line of fluids 24/7.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

North Sea area then assesses the data for discharge approval. This environmental test data for the NOVA systems has resulted in them obtaining the most environmentally acceptable classifications for use/ discharge in the North Sea. It should be noted that they have been used in all North Sea sectors. In 2001, the EPA established new regulations for the use of SyntheticBase Drilling Fluid (SBF) for use in the Gulf of Mexico. These regulations included stock limitations and discharge limitations in a two-part approach to control SBF-cuttings discharges. The first part was based on product substitution through use of stock limitations (e.g., sediment toxicity, biodegradation, PAH content, metals content) and discharge limitations (e.g., sediment toxicity, limit on the retention of SBF on SBF-cuttings). The NOVA system is designed to meet both the stock limitations and the discharge limit of sediment toxicity. It is also design to biodegrade in the most difficult of environments: those without oxygen. Detailed documentation is developed to insure the compliance of the NOVA system. The EPA has viewed the use of a product like the NOVA system, in combination with the VERTI-G technology, as a pollution-prevention technology. M-I SWACO formulated NOVA systems with the health and safety of rig crews in mind. In addition to protecting the environment, NOVA system fluids go a long way in making life easier for the people who handle and work with them. Extensive testing has been carried out on the basic ingredient in the NOVA system, the base fluid.

15

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


APPLICATIONS

Extended-reach and complex wells both on land and offshore where maximum environmental protection is desired.


PROBLEMS

Conventional invert-emulsion fluids exhibit both slow and incomplete biodegradation, as well as component toxicity, requiring expensive and lengthy treatments to permit the disposal of contaminated drill cuttings onshore.


SOLUTIONS

The PARALAND system has been designed with environmental protection in mind. The system components are biodegradable and of low toxicity, with an internal phase which provides nutrients for plant growth. Coupled with a designed treatment method, the system minimizes environmental risk.


ECONOMICS

With its unique environmentally acceptable design, the PARALAND system not only improves drilling efficiency as a high-performance, invert-emulsion fluid, but also reduces the cost and footprint for disposal of contaminated cuttings.


ENVIRONMENTAL

The PARALAND system, designed specifically for environmental excellence, minimizes risk and cost by providing various options for rapid and complete treatment to meet safe-disposal standards. The system treatment can be designed to convert drill cuttings into an agriculturally acceptable byproduct, resulting in a unique zero-waste treatment.

16

The issues with conventional invert-emulsion fluids External phase. Typically diesel or mineral oils, these materials only partially and slowly degrade, leaving behind toxic, degradation-resistant waste that can pose a long-term liability for disposal. Emulsifiers. Typically these materials only partially and slowly degrade leaving behind toxic, degradation-resistant waste. Internal phase. Typically calcium chloride, which provides high levels of conductivity to any waste and inhibits plant growth. Weight material. Typically barite, non-toxic in itself, which can be substituted with an improved weight material that can promote site recovery. Other components. Typically lime, organoclays and filtration-control additives, the latter materials can be slow to degrade leaving behind toxic, degradation-resistant waste.

An entire system engineered to reduce environmental liability The PARALAND system design incorporates ready biodegradability and low terrestrial toxicity into all of its organic components. In addition, the inorganic components are designed to minimize conductivity and enhance plant growth. All of this is accomplished while maintaining the high-performance characteristics of an invert-emulsion fluid.

Typical Formulations Product PARALAND* B SUREMUL* SUREWET* Lime VG-PLUS* Water K-52* Hematite

Concentration 45 – 85% 6 – 8 lb/bbl 1 – 3 lb/bbl 3 – 6 lb/bbl 5 – 8 lb/bbl 5 – 30% 5 – 45 lb/bbl As needed

Field results deliver performance promises from laboratory

A wide range of efficient techniques can be used to treat the PARALAND system to either meet local disposal regulations or to convert drill cuttings into a useful byproduct which can be utilized as a topsoil or a fertilizer, in a true beneficial-reuse, zero-waste environmental scenario. Landfarming, biopiling, composting, bioreacting and vermiculture are all suitable treatment techniques for PARALAND drill cuttings. With efficient composting and vermiculture, these cuttings can be beneficially reused as a soilenhancing additive. The use of PARALAND allows faster treatments with less dilution additives than conventional invert fluids, resulting in lower treatment costs and less environmental risk.

In the field, PARALAND has consistently exceeded performance expectations with high rates of penetration, low dilution rates and high levels of contamination tolerance. Mud weights from 7.5 lb/gal (0.9 kg/L) to 16 lb/gal (1.92 kg/L) have been easily achieved with ideal rheological and filtration properties. The system is easily

and economically maintained with actual total fluid-cost reductions of as much as 30% below estimate. The PARALAND system has been used in various zero-waste operations. In New Zealand, PARALAND cuttings were used as a food source for worms in a local vermiculture farm, converting the cuttings into vermicast fertilizer. In Colorado, PARALAND cuttings were co-composted with straw, bark and sand to provide a topsoil for reseeding the drillsite.

Benefits

• High-performance, invert-emulsion system • Readily engineered and maintained • Biodegradable organic components • All components low terrestrial toxicity • Variety of compatible treatment options

• Optimized drilling performance • Low dilution rates • Minimum environmental exposure • Lower well costs • Beneficial reuse of cuttings • Zero-waste option

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Features

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Multiple treatment options ensure minimal environmental risk

DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

17

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


APPLICATIONS

The practical side of a flat rheological profile

Deepwater, extended-reach and other technically demanding wells.


PROBLEMS

Adjusting the rheological properties of conventional synthetic-base drilling fluids to deal with changing temperatures and other well conditions can lead to poor hole cleaning, excessive Equivalent Circulating Densities (ECDs), barite sag and lost circulation.


SOLUTIONS

The constant rheology of the uniquely engineered RHELIANT* system opens the door for more efficient, trouble-free and costeffective drilling by improving hole cleaning and minimizing barite sag, pressure spikes, high gel strengths and other problems that result when balancing ECD values.




E C O N O M I C S

With its flat rheological profile, the RHELIANT system is unsurpassed in reducing fluid losses in challenging downhole environments. The resultant higher drilling efficiency and minimized formation damage further help to reduce total well costs.


ENVIRONMENTAL

The RHELIANT system requires less dilution, further optimizing its environmental advantages. The system is a flat-rheology invert that can be formulated as a synthetic-base system for offshore-discharge compliance.

18

ECD Problem B: Adjusting the rheology upwards to compensate for higher downhole temperatures and pressure can lead to excessive ECD values and gel strengths.

RHELIANT System vs Conventional SBM 35 YP (lb/100 ft2)

30

25

20

15

10 50°

70°

90°

110°

130°

150°

170°

Temperature (° F) Conventional SBM

RHELIANT system

ECD Problem A: In deepwater, the surface rheology must be reduced when encountering cold temperatures to offset negative ECD effects.

An entire system engineered to reduce dilution and costs The RHELIANT system’s lower clay content, fit-for-purpose viscosifiers, newly developed emulsifiers, rheology modifiers and adaptability to different base fluids yield a highperformance system that is costeffective yet easy to maintain.

The RHELIANT Solution: With its flat rheology, this new-generation system maintains consistent fluid properties that are independent of temperature and pressure. It maintains constant 150° F (65.5° C) properties even when confronting temperatures as low as 40° F (4.4° C). You can drill with ECDs lower than, or equal to, conventional invert systems while encountering fewer drilling problems and successfully avoiding the loss of whole mud.

In the field, the RHELIANT system has shown performance characteristics far superior to those of any conventional synthetic-base and other invert drilling fluids in deepwater applications.

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

14,000

12,800 13,800

15,800

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

19,800

16,000

16,800 17,800 18,800

0.5 lb/gal

17,000

728 gpm

18,000

770 gpm

12.8

12.7

12.6

20,000

21,800

21,000 12.3 12.7 13.1 13.5 13.9 14.3

SBM 12∏-in. PWD (lb/gal)

12.5

13

13.5

14

RHELIANT 11∑-in. PWD (lb/gal)

12.5 0

50

100

150

200

250

Time, min NOVAPLUS system

PWD

RHELIANT system

MW (in.)

The RHELIANT system’s superior cuttings transportation properties translate into smoother ECD 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 accumulate in the annulus and increase the ECD values. The system’s constant yield point ensures efficient hole cleaning and fewer packoffs. Not only is the RHELIANT system ideal for the challenging deepwater environment, it has also yielded tremendous benefits in any application where superior ECD management is needed to reduce the risk of lost circulation.

Minimized Pressure Surges 1400 Pump output (gpm)

ECD (lb/gal) 11.5

1200 11.45 1000 11.4

800 600

11.35

400 11.3 200 11.25

0

4:07:41 4:10:34 4:13:26 4:16:19 4:19:12 4:22:05 4:24:58 Time Flow rate

ECD

The RHELIANT system also has demonstrated its capacity to eliminate pressure spikes on connections. During the static period, the high gel strengths that can develop in conventional systems, especially at low temperatures, can cause excessive pressures to develop when the pumps are restarted, creating the potential for a formation breakdown. The RHELIANT system’s low clay content and flat rheology profile ensure minimum buildup of gels, effectively eliminating these pressure surges seen with other invert drilling fluids.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

No name is more synonymous with synthetic-base drilling fluids than the widely accepted NOVAPLUS* system. Long the system of choice for the deepwater and similarly challenging environments, this award-winning system set the standard for balancing costeffective performance with environmental efficiency. While just as robust as its forerunner, the RHELIANT system’s easier-on-the-AFE formulation allows it to deliver value-added performance that no conventional synthetic-base or other invert drilling fluids can match.

0.4 lb/gal

19,000

20,800

• Reduced mud losses, less dilution and improved displacement characteristics

RHELIANT technology builds on the NOVAPLUS system’s success

12.9 Sag flow loop test, NOVAPLUS and RHELIANT systems

15,000

14,800

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

• Balanced yield point delivers higher penetration rates, vastly improved cuttings-transport and considerable savings in hole-conditioning time

RHELIANT System vs Conventional SBM Barite Sag Performance

RHELIANT Field Data Well B: PWD Comparison with Direct Offset

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Field results that deliver on the promise of the laboratory

19

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


APPLICATIONS

Wells drilling in the Athabasca tar sands and in any area where Steam Assisted Gravity Drainage (SAGD) is used to drill for, and produce, crude oil from bitumen deposits.


PROBLEMS

The sticky bitumen clings to bits, BHAs, drill pipe and shaker screens, and the wellbore can erode easily if the drilling fluid is too hot or contains critical amounts of solvents. Graphic courtesy of Stonehenge Productions, Inc.


SOLUTIONS

The water-base SAGDRIL* drillingfluid system resists bitumen accretion and screen blinding while keeping the wellbore clean and intact for tight build radii and extended-reach horizontal sections.


ECONOMICS

The SAGDRIL system significantly reduces drilling time and expense by promoting faster, cleaner drilling; by maintaining wellbore integrity and by significantly reducing cleanup costs.


ENVIRONMENTAL

The water-base SAGDRIL system reduces both solid and liquid drilling waste streams, and we can employ the SAGDRIL tar-sand cuttings cleaner to strip tar from drilled solids for mix-bury-cover onsite.

20

Features

Benefits

• INTEGRATED FLUIDS ENGINEERING (IFE) combined with latestgeneration SAGD drilling fluid • Minimizes fluid impact on bitumen and cleans cuttings at surface • Dual tar control through TARLIFT* and TARSURF* • Excellent hole cleaning and suspension • Separates and cleans different waste streams

• New approach for drilling and drilling waste management • Mud cooler not needed (flowline temperature >35° C [95° F] may require cooling) • Minimizes hole washout % • Minimizes waste generation • Liner run without incidents • Easy to engineer • No cuttings beds formed • Maximizes ROP, saves drilling time

400 tonnes

Differential Rotor Decay 0.5 Reduction in diameter (mm)

350

0

300

–0.5

• Onsite fluids engineers who monitor the system’s Low-ShearRate Viscosity (LSRV) with a Brookfield viscometer

250 –1

The SAGDRIL system’s stable wellbore helps you beyond just drilling

200 –1.5

150

–2

100 50

–2.5

0

–3 0 Solvent/xanthan gum system SAGDRIL system

Compared to wells drilled with traditional solvent-base systems, SAGDRIL wells have realized significant savings in disposal costs of both solid and liquid drilling waste. They have also seen a significant reduction in solids-control costs and overall project costs.

M-I SWACO developed the SAGDRIL system to address the specific problems unique to drilling high buildangles and long-reach horizontal sections through the tar sands. The system incorporates a combination of surfactants and solvents, each with a specific function. Extensive laboratory testing of several solvent and surfactant products resulted in the selection of two products, TARLIFT and TARSURF, for accretion control. These products, working

60

80

100 120 140 160 180 200

Time, min SAGDRIL fluid Solvent-base System A Solvent-base System B Solvent-base System C

In a laboratory test to simulate hole erosion in various drilling fluids, technicians rotated calibrated tar-sand cores at controlled temperatures and rotating speeds in solvent/xanthan gum formulations or SAGDRIL fluid. Periodically, the technicians measured the cores to check for erosion. The solvent/xanthan gum formulations were more aggressive, causing higher erosion, while the SAGDRIL fluid proved to be the least aggressive.

in conjunction with water-wetting surfactants effectively control wellbore erosion by forming a stable emulsion of the solvents so their interaction with the wellbore can be reduced. The result of M-I SWACO research, development and field testing is a proven system that delivers the features which help you get more production from the tar sands at a lower cost: • A water-base drilling fluid that relies on a strong water-wetting agent to minimize accretion of the sticky tar sands on the bit and drillstring while it minimizes shaker-screen blinding • Oil-wetting surfactants to encapsulate tarry cuttings and promote their effective removal by the shakers and other solids-control equipment such as centrifuges • A rheological profile optimized for minimal wellbore erosion • Rheology that ensures optimum hole conditions while drilling and running casing and production liners

Another area where the SAGDRIL system helps your operation run more smoothly is in running casing and liners. High operating temperatures, thermal expansion and high stress levels in the casing and cement sheath are facts of life in SAGD drilling. Add to that the absolute requirement that an excellent pipe/cement and cement/ formation bond be accomplished throughout the intermediate casing, and you have quite a challenge for any drilling fluid. And that’s precisely why the SAGDRIL system isn’t just any drilling fluid. It helps you achieve your running and cementing goals by ensuring maximum lubricity while running the intermediate casing, and it aids in creating a better cement bond by delivering an in-gauge wellbore. An aid to responsible drilling waste management practices M-I SWACO has formulated the SAGD system to address the specific problem areas of accretion, shakerscreen blinding and wellbore erosion. A reduction in accretion and shaker-screen blinding have resulted in a significant increase in shaker-screen life and a sharp decrease in both fluid dilution and drilling waste disposal costs. By controlling wellbore erosion, the system further reduces the amount of drilling waste generated. SAGDRIL wells have realized significant savings in disposal costs of both solid and liquid drilling waste. They have also seen a significant reduction in solids-control costs and overall project costs.

DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

The SAGDRIL system gives you exactly what you need for this demanding work

40

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

A great deal of a Steam Assisted Gravity Drainage (SAGD) program’s success depends upon finding a highly specialized drilling fluid that will keep the hole clean, without wellbore erosion, for tight-build radii and extended-reach, horizontal sections; that will keep the bit and drillstring clean to minimize bitumen-accretion problems; and that will prevent screen blinding at the shale shakers. Add to that the need for an environmentally compatible formulation that also reduces the amount of drilling waste, and the challenge to find the right drilling-fluid system is even greater.

20

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Drilling Waste

21

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


APPLICATIONS

Onshore and offshore wells, including vertical and high-angle, drilling through highly reactive formations where an invert system would be required but where environmental restrictions preclude the use of oilbase systems.


PROBLEMS

Many onshore, offshore and deepwater wells require highly inhibitive drilling-fluid systems but are located in areas subject to strict environmental regulations.


SOLUTIONS

The SILDRIL* system uses silicate technology to inhibit reactive clays while offering the environmental benefits of a water-base formulation.


ECONOMICS

This one, versatile system delivers optimum inhibition characteristics, high penetration rates, decreased trouble time, superior wellbore integrity and superb solids-removal performance.

SILDRIL: The one system for optimum shale inhibition and environmental compliance This uniquely formulated system capitalizes on the very latest in silicate technology to give you performance approaching that of oil-base mud but with the environmental acceptability of a waterbase fluid. This one system delivers optimum inhibition characteristics, high penetration rates, decreased trouble time, superior wellbore integrity and superb solids-removal performance — all with minimal environmental impact.

It’s hard to match the shale inhibition of the SILDRIL system The SILDRIL system achieves its superior inhibition through a threefold approach:

• Direct chemical bonding of the silicate polymers to drill cuttings and formation surfaces • Precipitation of the silicate with divalent ions • Silicate polymerization that results in complex, inorganic polymer structures that react with the shale surfaces The system generates highly competent, inhibited cuttings that contribute to optimum performance of the solids-control equipment and greatly enhanced formation evaluation. By dramatically reducing solids contamination, the SILDRIL system reduces dilution rates and the costs associated with drilling waste management. Field experience has shown the solidscontrol efficiency of the system can compare very favorably to that achieved with typical invertemulsion fluids.


ENVIRONMENTAL

In the field, the SILDRIL system has proven itself with low dilution rates, a full complement of non-toxic products and safe-handling characteristics.

Before SILDRIL treatment: Cuttings from a reactive formation drilled with a conventional KCl polymer fluid.

22

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

The relatively small number of components that comprise the non-dispersed SILDRIL system provide a great deal of flexibility in matching the system to the particular application. Fewer products also mean ease of maintenance, simpler logistics and lower total fluid costs. The versatile SILDRIL system is compatible with a variety of inorganic salts that can be added to enhance inhibition and help meet specific environmental regulations.

Shale Recovery

Swellmeter Test

100 Shale recovery (%)

35 Swelling (%)

90

30

80 25 70 60

20

50

15

40

10

30 5 20 0

10 0

–5 FW/ polymer

NaCl/ PHPA

KCl/ glycol/ PHPA

SILDRIL

Oil-base mud

100

200

400

600

800

1,000

1,200

Time (min) DI water/XC

Low pH dispersed

KCl/glycol

SILDRIL

Features Filter-cake deposition

Si Physical and chemical barrier to invasion

O

H Si

Benefits • High penetration rates • Optimum solids removal • Low dilution rates and superb drilling waste control • Excellent cuttings integrity and stable wellbores • In-gauge holes

H

O

Clay platelets Non-clay particles

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

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

• Outstanding inhibition • Low toxicity • Applicable for deepwater • Minimum number of components • Highly flexible fluid parameters

1,400

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Fewer components give you more flexibility

DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

23

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


APPLICATIONS

Deepwater and other offshore and onshore projects in environmentally sensitive areas characterized by highly reactive shales.


PROBLEMS

Drilling in highly reactive shales calls for a high-performance fluid with excellent inhibition characteristics. Reducing drilling waste management costs, as well as complying with environmental regulations, virtually dictate the use of a water-base fluid.

In the field, the ULTRADRIL system delivers results comparable to oil-base systems Comparative Inhibition: GOM Shales 100 Moisture and recovery (%) 90 80 70 60 50 40 30 20




S O L U T I O N S

The water-base ULTRADRIL* system inhibits highly reactive shales and stabilizes wellbores while promoting hole cleaning and reducing clay/ gumbo accretion and bit balling.


ECONOMICS

The system’s ability to promote wellbore stability and high Rates of Penetration (ROP) saves valuable rig time. Its lower dilution requirements, lower waste volumes and recyclability, even after drilling long intervals of highly reactive formations, significantly reduce drilling waste management and fluid costs.


ENVIRONMENTAL

The excellent drilling waste management characteristics of the system — less dilution, lower waste volumes and excellent recyclability — as well as its water-base formulation, make the system environmentally acceptable in virtually any drilling area.

24

10 0 20% NaCl/PHPA

ULTRADRIL (20% NaCl)

Moisture

Synthetic OBM

Recovery

The inhibitive capability of the ULTRADRIL system surpasses that of a conventional water-base system and nearly matches that of a invert-emulsion drilling fluid. The system’s low moisture content results in drier, firmer drilled cuttings. With densities up to 11.3 lb/gal (1.4 kg/L), ULTRADRIL systems have successfully drilled long sections of highly reactive gumbo shales and graded out very high in terms of stability, inhibition, screenability and maintenance. In sections typically drilled with CaCl2 or 20% NaCl/PHPA water-base fluids, the high-performance ULTRADRIL system eliminated the shakerscreen binding, rapid encapsulator depletion and high-dilution rates that had severely impacted wells drilled with its more traditional counterparts.

Reactive-Clay Hydration 120 Hydration (%)

The results of a 16-hr test of various drilling fluids on samples of reactive clay. Three formulations of ULTRADRIL all had lower clay hydration than that of conventional waterbase drilling fluids. Through highly reactive intervals, ROPs have averaged up to 150 ft/hr (45.7 m/hr), delivering cuttings that exhibited the excellent integrity expected if drilling with an oil-base system.

100

80

60

40

20

0 –20 Gel/Lignosulphonate KCl/PHPA CaCl2/Polymer Seawater/glycol/PHPA KCl/glycol/PHPA

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

Features

Benefits

• High chemical stabilization • Low dilution, low toxicity • Viable alternative to OBM/SBM performance • Easy to build and maintain • Anti-accretion agent

• Optimizes inhibition • Environmentally acceptable • Deepwater alternative • Reduces costs • Increases drilling rates

Inhibition Action #2: Cuttings Encapsulation

Conventional water-base systems do not have the highly inhibitive quality of the ULTRADRIL system, so shales are prone to sloughing and swelling that can cause stuck pipe, and washouts.

With conventional systems, drilling is slower, the cuttings are smaller, and there is not the same, high level of inhibition as we have with the ULTRADRIL system. Many of the cuttings break apart and disperse, creating fines that not only require dilution of the system but that settle in the hole and can packoff the bit. Other particulates swell and agglomerate into large masses that adhere to the bit, drill pipe and Bottomhole Assembly (BHA).

The first feature of the ULTRADRIL system’s triple-inhibition approach is its ability to inhibit the most reactive shales and provide superb wellbore stability, even in the most reactive clays.

Inhibition Action #3: Protected Metal Surfaces

Conventional fluids allow gumbo buildup and bit balling to occur, slowing down the entire drilling process.

The second feature of the ULTRADRIL system’s tripleinhibition approach is the way it encapsulates cuttings with a thin polymer coating that virtually eliminates shale dispersion. This, in turn, reduces the need for dilution and the disposal of large fluid volumes. Because it is a high-performance system, the well can be drilled at higher ROP, producing larger cuttings which reach the shaker firm and intact.

The third feature of the system’s triple-inhibition approach is its ability to coat the bit, BHA and drill pipe with an accretioninhibitive coating. The cutting structure stays clean and effective, resulting in less bit balling and higher ROP.

For all of the capabilities it provides, the ULTRADRIL system is easy to build and maintain on location. The base fluid can be anything from freshwater to potassium chloride, to sodium chloride and, in some instances, seawater. The fluid is extremely clean, it does not use

any bentonite in its makeup, and its inhibitive character means a very low colloidal content. Its properties can be easily maintained, even in the presence of contaminants such as cement and common drillingfluid additives. And the ULTRADRIL system provides its high degree of inhibition without the use of performance-limiting salts such as calcium chloride.

To ensure top performance in the field, the ULTRADRIL system can be tested for proper concentrations, using simple, common tests to confirm product-volume percentage. The basic system consists of three main components: ULTRAHIB*, ULTRACAP* and ULTRAFREE*.

DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

The high-performance, water-base system that’s easy to build and maintain

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Inhibition Action #1: Superior Clay Inhibition

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

25

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


APPLICATIONS

Onshore and offshore wells where tight control must be maintained over fluid weights, rheologies, ECDs and barite sag.


PROBLEMS

Extended-reach, HTHP and small-bore drilling with narrow mud-weight windows, require sufficiently high viscosity to suspend barite, but not so high that ECD management is compromised. For high-density completion and workover fluids, the choices have been either conventionally weighted fluids with potential settling problems or high-density, very costly, solids-free brines.


SOLUTIONS

The micron-size particles used in WARP* Advanced Fluids Technology from M-I SWACO can be used in many water-base and invert drilling and completion-fluid systems to increase density without compromising rheology or promoting particle settlement.


ECONOMICS

For faster drilling, WARP Fluids Technology reduces torque, drag and particle settlement. For completions and workovers, WARP Advanced Fluids Technology is more cost-effective than some high-density brine systems.


ENVIRONMENTAL

Finer shaker screens can be used, improving solids-removal efficiency and reducing overall dilution and discharge volumes. Completion fluids formulated with WARP Fluids Technology are cost-effective and environmentally more acceptable than many high-density, clearbrine systems.

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Every manual on drilling-fluid engineering tells us that micronsize particles are detrimental to drilling fluids. With too many fines in the fluid, the rheology increases, often with detrimental effects. The technology behind WARP Fluids Technology lies in grinding the weighting material to extremely fine particle sizes — from 0.1 to 10 microns, with the majority measuring 1 micron. By pre-treating these extremely fine particles, there is no rheology increase. Now imagine what WARP Fluids Technology micro-particles can do for your water- and oil-base drilling, reservoir drill-in and completion fluids: • Low-rheology, high-density fluids • Weight materials that do not settle, even with very low rheologies • Better management of ECDs • Ability to use ultra-fine shaker screens that improve solidsremoval efficiency without sacrificing valuable products

• Fluids that reduce environmental impact • The ability to formulate oil-base completion fluids

API barite 75 µm max size

API barite d50 ~25 µm

WARP particle < 1µm The micron-size weighting materials developed for WARP Fluids Technology are much smaller than standard API barite, allowing them to flow easily through 300-mesh shaker screens, so that virtually 100% of drilled cuttings can be removed on the first pass. Their ultra-small size, combined with their proprietary treatment, ensures that fluids formulated with WARP Fluids Technology do not settle or sag.

Features

Benefits

• Micron-size weighting agent • Lower fluid viscosities • Reduces sag • Improves filtration properties • Excellent solids-separation efficiency • Greater hole cleaning • Reduces torque and drag • Environmentally acceptable • Reduces oil on cuttings

• Ideal for extended-reach and horizontal drilling, throughtubing drilling, coiled-tubing drilling and HTHP wells • Excellent for high-density completion and workover fluids, kill fluids, logging and testing fluids, packer fluids, and high-density reservoir drill-in fluids • Safer, more secure well control • Less dilution and reduced discharge to the environment • Non-damaging to formation • Finer-mesh shaker screens can be used

• 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

• Lower rheologies for the same density • Better management of ECD and control of losses • Complete flowback through sand screens

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

Drilling Fluids Reservoir Drill-In Fluids

Graded Calcium Carbonate • Mud weights limited at higher densities • Limited ECD management and rheology control at higher densities

Completion and Workover Fluids

WARP Advanced Fluids Technology • Near-zero sag and settlement in inclined and horizontal sections • Fluid rheology may be low and independent of sag • Better management of ECD and control of losses. No mud weight variation. • Lower drillstring torque delivering superior bit horsepower • All-in-one drilling and completion fluid • Lower dilution factors and lower well costs • Reduced discharge volumes and environmental impact

For completion fluids, WARP Fluids Technology wins out over conventional weighting agents Above 13 lb/gal (1.6 kg/L), solidsfree completion and workover fluids are limited to mixed calcium chloride, calcium bromide and zinc bromide, or mixed potassium and cesium formate brines. The only other alternatives are specially formulated barite- or calciumcarbonate-weighted fluids that are prone to sag and settlement.

Now there is WARP Advanced Fluids Technology from M-I SWACO in which the ultra-fine particles behave similar to solids-free fluids with no settlement, minimal reservoir damage and complete flowback through gravel pack and sand-screen completions — all with no environmental or disposal hazards. In addition, you now have the option of high-density, oil-base completion fluids for a complete oilbase drilling and completion-fluids train, minimizing spacers and the potential for emulsion blocks.

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• Drilling waste management

Conventional Weighting Materials API Barite • Higher rheologies to control barite settlement and sag • Problematic ECD management in sections with narrow pressure windows • Horsepower limitations in extreme, horizontal wells

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

The low rheological profile of a fluid enhanced with WARP Fluids Technology actually improves hole cleaning by effectively removing any cuttings buildup on the lower side of the hole. In addition, the low rheologies of WARP Fluids Technology clear the way for better control and management of equivalent circulating density, which is especially critical when a very narrow margin exists between the pore and fracture pressure. In fact, ECDs are actually reduced and pump pressures are lower with WARP Fluids Technology, which also reduce swab and surge pressures while tripping and running casing. These and other advantages make WARP Fluids Technology the ultimate choice for a wide array of critical drilling applications, including:

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

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When the stakes are high, WARP Fluids Technology keeps rheologies — and problems — down

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DURATHERM The DURATHERM* system is a lowcolloid, contaminant-resistant water-base fluid designed for hightemperature drilling. It provides good inhibition, minimizes clay migration and swelling, and is stable to >500° F (260° C) ambient, with densities from 9 to 20 lb/gal (1.1 to 2.4 kg/L), and at depths from 5,000 to 25,000 ft (1,524 to 7,620 m). High ROPs, improved solids-removal capability and minimal formation damage help reduce drilling costs, while its aqueous-base chemistry gives it environmental advantages over oil-base systems. The system is especially useful when there are concerns about formation evaluation, kick detection or lost circulation. It may be formulated with freshwater or seawater, and nonflocculating salts may be incorporated for inhibition. Because the DURATHERM system evolved from formulations used as packer fluids, where long-term rheological stability is necessary, this low-colloid system remains stable in the presence of acid gases, salts, and drill solids. The system’s stability can be maintained by minimizing the concentration of active solids, and using polymeric materials for viscosity requirements. This reduces gelation caused by the flocculation of active clays at high temperature, as well as the viscosity increase resulting from saltwater flows, acid gases, or salt. Generally, treatments with lignosulfonate (SPERSENE*) should be discontinued at bottomhole temperatures above 325° F (163° C). Solids-control equipment — shakers, hydroclones and centrifuges — must be operated as efficiently as possible to minimize maintenance costs.

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This product continues to function as designed in fluids that encounter formation temperatures greater than 500° F (260° C). It is the primary treating agent in the DURATHERM system, and it provides potassium ions for shale inhibition. RESINEX* resin polymer is used for HTHP fluid-loss reduction by decreasing filter-cake permeability, and it contributes to fluid stabilization. Field results have demonstrated the utility of RESINEX in minimizing formation damage. RESINEX is used in conjunction with XP-20 to control these properties in the DURATHERM system. TANNATHIN* is a lignitic material that works with RESINEX to reduce HTHP fluid-loss values and stabilize rheological properties in the DURATHERM system. Polymers contribute viscosity and API fluid-loss control to the DURATHERM system. Minimizing bentonite concentrations requires the use of polymeric materials as viscosifiers. Cellulosic polymers and xanthan gum provide the viscosity required to suspend weigh material and drill solids, and lower API fluid-loss values in the DURATHERM system. M-I GEL* may be used for fluid-loss control and viscosity in wells with bottomhole temperatures below 250° F (121° C). For bottomhole temperatures above 250° F (121° C), M-I GEL must be maintained at low levels. The primary function of M-I GEL at these reduced concentrations is to help form a thin, dense, low-permeability filter cake.

System products

M-I BAR* and/or FER-OX* are highdensity materials with specific gravities of 4.2 and 5.0, respectively. They provide fluid density in the DURATHERM system.

XP-20* potassium chrome lignite material is used as a viscositystabilizing agent and to control fluid loss in the DURATHERM system.

Caustic, lime and gypsum are used to balance alkalinities and control the effects of carbonates/bicarbonates on rheological properties. The

basic environment provided by hydroxyl ions aids in tubular corrosion control and in hydrolyzing mud products added at the surface. Corrosion control and lubrication. The DURATHERM system is compatible with selected corrosion control-chemicals and lubricants. The low-solids feature of the DURATHERM system, in conjunction with lubricants such as LUBE-167* and EP LUBE*, will reduce bit balling, torque, and drag.

The DURATHERM system as a packer fluid The DURATHERM system has been recognized as a drilling fluid applicable in areas of high temperature and pressure. Due to its physical characteristics it also may be used as a packer fluid. The characteristics that make the DURATHERM system an ideal packer fluid are: • Thermal stability to temperatures in excess of 500° F (260° C) • Minimal liquid separation or breakout • Ability to suspend barite and solids without settling • Non-corrosive (when freshwater is used as a base) • Low static shear strengths • Quick reversion to fluid state upon agitation For corrosion protection, M-I SWACO recommends that a filming amine corrosion inhibitor such as CONQOR* 101 be added to the packer fluid. One barrel of CONQOR 101 per 100 bbl of mud usually results in an adequate concentration of inhibitor. Additions of 0.2 to 0.5 lb/bbl (0.1 to 0.2 kg/bbl) BACBAN III preservative (bactericide) will prevent the growth of sulfate-reducing bacteria and fermentation of the mud.

Ester-base chemistry for optimum drilling performance in the most fragile environments When you prefer an ester-base system in order to meet local discharge requirements without sacrificing the economic benefits of a highperformance fluid, the ECOGREEN* system is the logical choice. The true value of the ECOGREEN system lies in its versatility. It is easily formulated to address a wide range of drilling requirements, including Extended-Reach Drilling (ERD) and horizontal drilling, and drill-in fluid applications. The system produces the penetration rates consistent with oil-base muds, while eliminating or dramatically reducing the instances of stuck pipe, out-of-gauge holes and unstable

Features

Benefits

• Biodegradable • Synthetic system • Non-aqueous-fluid system • Ester chemistry

• Wellbore stability • Increases ROP • Cuttings integrity • Lubricity • Hole cleaning • Permission to discharge

The ENVIROTHERM system is used primarily in the Western Hemisphere and is similar to a chrome-free DURATHERM using TANNATHIN* and SPERSENE CF for rheology control, and RESINEX for fluid-loss control. Freshly prepared muds have low viscosity, yield points and gels. These fresh muds should be treated with additional POLYPAC* R

(or DUO-VIS*) to increase the viscosity in the pits to prevent barite settling. Once drilling begins, the drill solids accumulate and give the fluid enough rheology to support weight material. Other options include polymers for synthetic viscosity fluid-loss control.

ENVIROTHERM The ENVIROTHERM* system is a chrome-free, environmentally advanced fluid designed for hightemperature drilling. Its low-toxicity, high-temperature stability and minimal reactive-solids content make it ideal for high-temperature operations. This environmentally acceptable drilling-fluid system provides good filtration control and reduces trouble time.

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has passed some of the most rigorous toxicity, biodegradation and vapor tests in the industry and has been approved for discharge in some of the world’s most restricted environments. The ECOGREEN system is also completely reusable after only minimal treatment, significantly reducing your mud consumption costs.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

wellbores normally associated with water-base systems. Its low-lubricity coefficients dramatically reduce torque and drag, making it particularly beneficial in deviated and highangle wellbores. From an environmental standpoint, the ECOGREEN system is a synthesized material, and the fattyacid ester comprising its base fluid contains no “priority pollutants” and is biodegradable. The system

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

ECOGREEN

29

ENVIROVERT The invert drilling-fluid system that reduces drilling, completion and disposal costs With the ENVIROVERT* system, operators now have all the performance advantages of a conventional invert-emulsion drilling fluid, with the added benefit of reduced disposal costs. The system contains no chlorides, but rather a proprietary calcium nitrate salt that not only inhibits reactive shales, but also provides nitrogen that accelerates biodegradation. The ENVIROVERT system has been shown to significantly reduce torque and drag, making it an ideal option for drilling high-angle or horizontal wellbores. Its hightemperature stability gives you a dependable system for drilling deep, hot holes. What’s more, this highly versatile system has demonstrated its effectiveness as a perforating, completion, spotting and casing-pack fluid.

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Features

Benefits

• Invert drilling-fluid system for water-sensitive formations • Uses calcium nitrate in place of calcium chloride • Excellent torque and drag reduction • Prevents lost circulation in low-pressure zones

• Eliminates typical chloride disposal problem • Promotes faster biodegradation • Reduces unexpected events • Also works as a spotting, packer and casing-pack fluid • Reduces drilling, completion and disposal costs

ENVIROVERT reduces your environmental costs and concerns For a landfarming operation to succeed in its biodegradation activity, one or more supplemental applications of a fertilizer high in nitrogen is necessary. The ENVIROVERT system gives you a head start by providing the nitrogen required for hydrocarbon-degrading microorganisms to perform effectively in landfarming operations. The ENVIROVERT calcium nitrate salt not only eliminates the trouble and costs associated with chlorides, it also facilitates faster biodegradation. In addition, ENVIROVERT meets NMX-L-162-1996-SCFI specifications.

Water Activity of the ENVIROVERT System 1.00 Water activity 0.95 0.90 0.85 0.80 0.75 0.70 0.65 0.60 0.55 10

15

20

25

30

35

40

45

50

55

60

Water-phase salinity (% by weight) ENVIROFLOC*

65

70

Used primarily in the Gulf of Mexico, the K-MAG* system is an inhibitive water-base system that provides shale inhibition and wellbore stability while it minimizes bit balling. System benefits include reduced dispersion of drill cuttings for easier removal, near-gauge wellbores for better cement jobs, even in water-sensitive shales, and reduced swelling for wellbore stability. The K-MAG system is designed to perform most efficiently in freshwater to seawater-salinity environments, but the salinity can be increased to improve shale stability and gas-hydrate inhibition when necessary. The use of a powerful dispersant, such as lignosulfonate, is usually kept as low as possible in order to minimize excessive

dispersion of drill solids and wellbore washout. The system’s popularity has increased as the use of syntheticbase fluids in offshore drilling has become more challenging due to more stringent environmental regulations, biodegradation restrictions and other environmental issues. In addition, low fracture gradients and narrow ECD windows often encountered in deepwater operations greatly increase the risk of lost circulation, which can drastically increase the cost of the operation. More economical water-base fluids, such as the K-MAG system, with good shale inhibition and effective ROP enhancement are now competing with synthetics in deepwater applications.

Features and Benefits • Flexible system can be formulated to suit drilling environment • Excellent shale inhibition and wellbore stability • Minimizes bit balling, improves ROP • Preserves drill cuttings for easier removal • Tolerates salinity from freshwater to seawater levels • Substitutes for some synthetics where environmental issues are a concern

NOVATEC P

Features and Benefits NOVATEC P • Improves emulsion stability • Functions as secondary wetting agent • Provides filtration control • Helps maintain HTHP filtrate in a water-free condition • Improves thermal stability and contamination resistance of the NOVATEC system

NOVATEC S • Improves oil-wetting and prevents water-wet solids • Maintains stable invert emulsion and helps prevent water in filtrate • Improves thermal stability and contamination resistance of the NOVATEC system • Improves emulsion stability

NOVATEC S NOVATEC S polyamide is the secondary emulsifier and wetting additive in the NOVATEC LAO-base system. NOVATEC S emulsifier can be used alone to form tight water emulsions in olefin fluids, but is particularly effective when used to compliment NOVATEC P additive. The product is designed for use in the NOVATEC system to provide tight emulsion stability, HTHP fluid-loss control and strong organic wetting capability. When used in combination, NOVATEC S and NOVATEC P emulsifiers react to form a tight emulsion and improve the fluid’s resistance to contamination and water-wet solids.

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The NOVATEC* P fatty acid is formulated as the primary emulsifier in the NOVATEC system. NOVATEC P emulsifier can be used alone to form tight water emulsions in most synthetic-fluid systems but is particularly effective when used in conjunction with NOVATEC S additive, a secondary emulsifier and wetting agent for this system. The NOVATEC P agent contributes to HTHP filtration control, temperature stability and contamination tolerance of the NOVATEC system by forming a tight, stable emulsion.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

NOVATEC

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K-MAG

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PARADRIL The PARADRIL* invert-emulsion system was designed specifically as an alternative to conventional or mineral-oil-base drilling-fluid systems, balancing high performance with environmental compliance. The heart of the system is the paraffinic component which, depending on the application, discharge requirements and availability, can range from synthetic Linear Paraffins (LP) to mixed blends of refined paraffins. All of the products comprising the PARADRIL system have been formulated to meet local discharge requirements.

The true value of the PARADRIL system lies in its flexibility. Weights can range from unweighted to 18 lb/gal (2.2 kg/L). The paraffin/water ratios can range from as low as 50:50 to as high as 95:5, depending on mud weight and solids loading. The system is formulated as an emulsion in which the paraffinic liquid forms the continuous phase, while a brine solution serves as the dispersed phase. It is easily formulated to address a wide range of requirements, including extendedreach, horizontal and reservoir drill-in applications.

Hydrocarbon monitoring. All too often, the inability to accurately monitor the presence of crude oil in mud returning from the production zone restricts the use of oilbase drilling fluids. With the PARADRIL system’s linear-paraffin base fluid, that concern has been eliminated. The unique chemistry of the PARADRIL SB base fluid generates a very identifiable fingerprint, and GC/MS work has shown that even in concentrations as low as 0.5%, crude oil is still detectable in the system.

PARATHERM/VERSATHERM The PARATHERM* and VERSATHERM* systems are invert-emulsion systems with one significant difference in their formulations. PARATHERM uses a linear-paraffin base oil, while VERSATHERM employs a lowtoxicity mineral oil. Both were originally designed for use in HighTemperature, High-Pressure (HTHP) applications, but can be engineered for use in low-temperature wells. It was developed to meet the technical challenges associated with drilling wells with narrow hydraulic windows and extended-reach profiles. The system was designed with the specific goal of delivering the following qualities: • Stability at high temperatures • Reduced high-shear-rate viscosity • Stable low-shear-rate viscosity • Reduction in Equivalent Circulating Density (ECD) • Reduced sag potential

Applications The PARATHERM system is suitable for applications with narrow hydraulic windows, regardless of 32

Typical System Components Additive Linear Paraffin Low-Toxicity Mineral Oil (LTMO) EMI-783

Material Base fluid

Function Continuous phase

Base fluid Organophilic clay

Continuous phase Viscosifier

Bentone 38 VG-SUPREME* Lime SUREMUL* SUREWET* Freshwater CaCl2 VERSATROL* VERSATROL HT Barite

Organophilic clay Organophilic clay

Viscosifier Viscosifier

Calcium hydroxide Polyamide Fatty acid

Alkalinity Primary emulsifier Secondary emulsifier

Freshwater Calcium chloride Gilsonite Gilsonite Barium sulfate

Internal phase Salinity Fluid loss Fluid loss Density

the expected Bottomhole Static Temperature (BHST). The first field application of the PARATHERM system was in a low-temperature (1,670° F [910° C]), narrow-hydraulicwindow well. The well was successful due in large part to the lower rheological properties and associated reduction in ECD obtainable with the PARATHERM system. This application confirmed the ability of the PARATHERM system to provide a fluid with reduced high-shear-rate viscosity compared to conventional

systems, providing a direct benefit in reduced total system pressure loss. The PARATHERM system has also been used successfully to drill Extended-Reach Drilling (ERD) wells. The VERSATHERM system has been successfully used in HTHP applications. The maximum bottomhole static temperature the system has been used to drill is slightly above 3,560° F (1,960° C). The system has exhibited very stable properties and low, non-progressive gel strengths.

The POLY-PLUS* system employs high-molecular-weight polymers and anionic liquid to provide cuttings encapsulation and shale stabilization. It also acts as a viscosifier, friction reducer and flocculant while providing some fluid-loss control. POLY-PLUS additive can be used in mud systems ranging from low-solids to weighted, utilizing makeup waters from fresh to saltwater. • POLY-PLUS additive mud systems. POLY-PLUS provides excellent cuttings encapsulation and improved wellbore stability. • Clear-water fluids. POLY-PLUS agent may be used in clear-water, solids-free drilling fluids. POLY-PLUS polymer increases viscosity and enhances solids removal by flocculating the undesired solids. It also provides cuttings encapsulation and improved wellbore stability.

Features and Benefits • Provides excellent cuttings encapsulation and limits cuttings dispersion • Provides improved shale stabilization • Enhances the removal of drill solids • Liquid product for easy mixing and rapid yield

• Aids in preventing balling on the bit, stabilizers and BHA by coating and lubricating solids • Improves the lubricity of most mud systems, particularly nondispersed muds, when used in combination with a lubricant • Can be used to viscosify clearwater and low-solids drilling fluids

treating the fluid as a conventional invert. There is no real break-over procedure to be dealt with, and conversion to an invert is straightforward. All system components are efficient elements of invertemulsion formulations. TRUDRIL fluids have been used in a wide variety of conditions and environments:

and properties, (as compared to inverts) including:

• POLY-PLUS sweeps. Viscous POLY-PLUS sweeps are effective for periodic hole cleaning.

TRUDRIL The TRUDRIL* system differs from other oil muds in that it is formulated without an internal brine phase. A highperformance organoclay is used to generate superior rheology and suspending properties. Efficient filtration control is achieved through use of particulates and/or synthetic polymers. The inevitability of incorporation of small quantities of water from the drilling operation and surface handling operations is addressed through use of limited treatments with emulsifiers and oil-wetting agents, but unlike conventional invert-emulsion fluids, water content is minimized and is treated as a contaminant rather than a system component. Experience has shown that over 5% by volume of water can be incorporated without any evidence of negative interaction with drilled formation or cuttings. At higher water fractions, it is expedient to address balanced-activity issues and to salt up as appropriate,

• Base fluids have ranged from crude and diesel to ultra-low-aromatic mineral oils

• High YP/PV ratio and superior suspending performance • Lower ECDs • Efficient hole cleaning • Reduced gas-hydrate sensitivity • Lower densities than achievable with inverts. Low-density inverts tend to have a high aqueous fraction which further limits the ability to achieve low densities

• Densities have varied from unweighted (basically the density of the base fluid) to over 18 lb/gal (2.2 kg/L)

• Reduced concern over water-phase composition

• Application is documented at temperatures up to ~400° F (204° C)

• Lower maintenance costs

• Drilling environments have varied from critical-angle deepwater wells to shallow horizontals The composition of the fluid delivers certain desirable characteristics

• Minimum number of products making engineering simple

• More environmentally competent discharges i.e., no salt added • Low surfactant content with possible reservoir implications

DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

• Weighted muds. POLY-PLUS can be used in weighted muds for cuttings encapsulation, improved wellbore stability, secondary viscosity and to improve filter cake integrity.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

• Low-Solids, Non-Dispersed (LSND) muds. POLY-PLUS agent is well suited to LSND systems. In reduced-bentonite muds, POLY-PLUS serves as a bentonite extender to increase viscosity, flocculates drill solids for more efficient removal, encapsulates cuttings and improves wellbore stability.

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POLY-PLUS

33

VERSACLEAN/VERSADRIL The VERSACLEAN* and VERSADRIL* systems are oil-base fluids formulated and engineered to meet any drilling-fluid requirement. The only difference between the two systems is that the VERSACLEAN system uses a highly refined mineral oil while the VERSADRIL system is formulated with No. 2 diesel oil as the continuous external phase. Both systems deliver excellent thermal stability for drilling deep, hot holes. Their formulation provides inherent protection against acid gases, such as CO2 and H2S, as well as corrosion due to the presence of lime (used as an alkalinity control reagent) in the continuous oil phase. VERSACLEAN and VERSADRIL systems can drill watersoluble formations (anhydrite, gypsum, salts and complex salts) with minimum or no hole-washout problems. They provide improved lubricity for drilling deviated holes and for significantly reducing occurrences of stuck pipe. VERSACLEAN

34

Features

Benefits

• Low coefficient of friction • High-temperature stability • Chemically stable • Excellent filtration control

• Maximizes production • Reduces torque and drag • In-gauge wellbores • Optimized ROP • Stable wellbores

and VERSADRIL systems minimize damage to producing formations through the prevention of water intrusion, thereby eliminating clay swelling which can cause reduced permeability of the pay zone. They also provide increased rates of penetration and ability to drill thick, water-sensitive shale sections with relative ease, thus providing for gauge hole drilling. In many cases, oil muds are not considered, although the drilling conditions warrant their use, because of their initial makeup costs. However, if the overall drilling costs are considered, the costs

accompanying the use of an oil mud are usually comparable with, or less than, those of a water-base fluid, particularly when most drilling problems are eliminated, resulting in substantial time savings. In addition, both VERSACLEAN and VERSADRIL oil muds can be salvaged and reused following the drilling operation.

System VERSACLEAN* VERSADRIL*

Base Oil Mineral oil Diesel

ADVANCED FLUIDS TECHNOLO GY

In extended-reach, HTHP and small-bore drilling with narrow mud-weight windows, operators must maintain viscosity high enough to suspend barite, but not so high as to compromise ECD management. The micron-size, treated particles in WARP* Advanced Fluids Technology from M-I SWACO* can be used in all water- and oil-base drilling and completion fluid systems to increase density without compromising rheology or promoting particle settlement.

High environmental performance as well

WARP SUCCESS STORIES Through-tubing rotary drilling A 972-m (3,189-ft), 149-mm (5 7⁄ 8-in.) TTRD section, inclined at 78° was drilled in one bit run with a rotary steerable system, PWD and MWD to 5,069 m (16,631 ft) with a 1.6-kg/L (13.2-lb/gal) invert oil-base system incorporating WARP Fluids Technology.  No mud-weight variations were measured  ROP were 10% higher than planned  Using 250-mesh shaker screens, dilution was 50% lower than offset wells, reducing discharge volumes  Fluid costs were 18% lower than planned

With WARP Fluids Technology, critical downhole conditions don’t become critical situations.

Weight up for success now Just call your local M-I SWACO representative and ask for information and success stories about our WARP Advanced Fluids Technology. Your next project could reap the benefits.

HTHP drilling

www.miswaco.com

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

DISPLACEMENT AND CLEANUP W O R K O V E R A N D C O M P L E T I O N F L UI D P R O D U C T S

A 311-mm (121⁄4-in.) section of a high-temperature, high-pressure well was drilled at 60° inclination to 5,121 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

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

For North Sea drilling operations using WARP microparticles as the weighting agent, shakers can be dressed with finer screens, improvWARP particle (right) compared ing drill-solids-removal efficiency to barite and reducing overall dilution particle (left) volumes. For completions, the elimination of particle settlement gives WARP Fluids Technology the advantage as a more cost-effective and environmentally acceptable alternative to many high-density, clear-brine systems.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

WARP

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

35

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


APPLICATIONS

Onshore and offshore projects that will use divalent brines as the completion fluid and/or applications where a low-solids, highdensity Reservoir Drill-In Fluid (RDF) is required.


PROBLEMS

Divalent brines’ incompatibility with biopolymers create RDFs that are less than optimal for hole cleaning and minimizing Equivalent Circulating Density (ECD). In addition, it has been difficult to remove the filter cake formed by divalentbrine/biopolymer systems, increasing cleanup time and costs.


SOLUTIONS

The DIPRO* system can use a variety of divalent brines for its base fluid and achieves high density without loading the system with solids. It creates a thin, impermeable filter cake and builds Low-ShearRate Viscosity (LSRV), without producing high ECDs.


ECONOMICS

The DIPRO system’s low ECDs reduce costly fluid losses and formation damage. The system is highly compatible with various completion fluids and methods; it can be reused; and its thin filter cake protects the reservoir and can be produced through virtually any completion equipment.


ENVIRONMENTAL All DIPRO system components are accepted for use in both the U.S. and North Sea when utilizing an approved base brine.

36

The DIPRO system gives you high density, low solids, minimal formation damage and easy cleanup in divalent brines For its base fluids, the DIPRO system uses the divalent-cation brines and brine 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. With any of these base brines, the system uses a unique viscosifier/filtrationcontrol additive in conjunction with properly sized calcium carbonate bridging agents to build a fluid that generates low filtration rates and produces a thin filter cake to protect the reservoir.

The system’s low ECDs help prevent excessive invasion of whole mud, especially in formations having low fracture gradients, such as those found in deepwater. Because we can engineer the system so precisely, and because of its flexible chemistry, DIPRO can be formulated in densities ranging from 11.5 to 17.5 lb/gal (1.4 to 2.1 kg/L) for any of several completion methods: • Open-hole gravel packs • Standalone screens • Slotted/perforated liners • Barefoot

The key components of the DIPRO system The DIPRO system achieves high density without loading the system with solids; the only significant solids are the carefully selected, calcium carbonate bridging agent. In addition to creating a thin, impermeable filter cake, the DI-TROL* and DI-BALANCE* components work together to build LSRV without producing high ECDs.

The M-I SWACO SAFE-CARB bridging agent is high-purity ground marble which is selected using our OPTIBRIDGE* software to obtain the optimal blend. In these photos, the disc on top is coated with a typical filter cake as it would be deposited by the DIPRO system. The middle photo shows the even “pinholing” effect obtained by backproducing the well, when this is possible. The bottom photo represents instances where back-producing is not a viable option; the filter cake is almost completely dissolved after only a three-hour soak with 5% HCl acid.

Benefits

• Biopolymer-free • Divalent-brine base • Precisely controlled particle-size distribution of bridging agent • Customized formulations • Low ECDs • Excellent shale stability • Compatible with complex completions, including open-hole gravel packs

• Maximizes production • High production rates sooner • Filter cake is easily removed • Cost-effective, high-density fluids • Minimal formation damage • Minimal fluid loss with durable filter cake • Reduces remediation and disposal costs • High performance in deepwater applications

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

Features

Drilling Density requirements. The DIPRO system functions optimally in the 11.5 to 17.5-lb/gal (1.4 to 2.1-kg/L) range and its density can be adjusted within this range without increasing the solids in the system. Rheological properties. Typically, the DIPRO system has a shear-thinning rheological profile, low plastic viscosity, high yield point and relatively high LSRV. Contaminant tolerance. The system tolerates the contaminants commonly found in drilling: cement, drilled solids, reactive shales and oil. Torque and drag. While the DIPRO system produces torque and drag that is slightly higher than synthetic or oil-base systems, its lubricity is good for water-base reservoir drill-in fluid systems. If needed, the system’s lubricity can be enhanced with a compatible lubricant. Wellbore stability. The base brines used to formulate the system produce an excellent level of shale inhibition. Engineering ease. Because the DIPRO system consists of only a few components, it is easy to mix on the rig and maintain.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

PRODUCTION SCREEN TESTER (PST). The correct design and maintenance of a reservoir drill-in fluid is critical where open-hole completions are planned. The particle-size distribution of solids in the open hole must be carefully chosen, primarily to bridge across the exposed formation, but it may also permit flowback through the openings in the completion assembly. Initial fluid design and testing must be done in the laboratory, but once drilling has started in the reservoir, any flowback testing on field samples normally requires urgent shipping to shore, resulting in delays of days between sampling and test results. M-I SWACO has designed the PRODUCTION SCREEN TESTER to perform onsite testing of fluid flowback at the rigsite. The unit allows field fluid to be tested in realtime on samples of identical completion screen. This test also assists in determining the optimum cleanup chemistry such as the M-I SWACO BREAKFREE* or BREAKOVER* treatments.

Completion Formation damage. The system’s unique viscosifier/filtration-control additive results in low filtration rates and protects the reservoir with a tough, thin filter cake. Completion compatibility. The system forms a durable filter cake that remains intact during completion operations, such as high-rate water packing, but may also be flowed back through virtually any completion during production. Displacement. Because of the basebrine composition, the DIPRO system is compatible with completion fluids and displaces easily. Cleanup. The DIPRO system filter cake can be produced through a completion, or be easily destroyed with a variety of chemical breakers. Long-term stability. The DIPRO system’s divalent-brine base fluid allows the fluid to remain in the well for long periods of time without significant degradation. Recoverability. The base brine from the DIPRO system can be easily reclaimed for use as a completion fluid or for formulating another DIPRO system.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

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

37

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


APPLICATIONS

Offshore and onshore wells that require the drilling performance and inhibition of an invertemulsion system along with the easy cleanup characteristics of a water-base system.


PROBLEMS

Conventional invert emulsions can make drilling easier but can make certain sand-control completions difficult, and their filter cakes can be extremely time-consuming to clean up. In contrast, water-base systems’ filter cakes are easier to clean up, but the systems may not inhibit certain formations.


SOLUTIONS

The FAZEPRO* system is the industry’s only reversible, invert-emulsion reservoir drill-in fluid system, delivering the drilling performance of an invert emulsion with the filter-cakeremoval efficiency, non-damaging characteristics and overall completion simplicity of a water-base fluid.


ECONOMICS

Faster drilling through reactive shales, easier cleanup and completion efficiency all add up to significant time and money savings.

FAZEPRO gives you faster drilling and easier cleanup in one system Until now, drilling and completing certain types of reservoirs presented operators with a dilemma. On one side of the problem, technical, geological and economic considerations required an oil- or synthetic-base reservoir drill-in fluid, but oil-wet filter cakes can be extremely costly and time-consuming to clean up thoroughly. On the other side of the problem, while a water-base system makes it much easier to clean up the filter cake, it may be incapable of inhibiting waterreactive shales and clays, compromising drilling efficiency. The FAZEPRO system eliminates this quandary. It is the industry’s only reversible, invert-emulsion reservoir drill-in fluid system, delivering the drilling performance of an invert emulsion with the filter-cakeremoval efficiency, non-damaging characteristics and overall completion simplicity of a water-base fluid.

Now filter-cake removal is a simple matter of good chemistry While drilling the reservoir, the FAZEPRO system generates the high performance you expect from an invert-emulsion system. With the oil- or synthetic-base fluid serving as the continuous phase, the system delivers the excellent inhibition

38

and lubricity inherent in these systems, resulting in a high-quality wellbore and cost-effective rates of penetration. Once you reach the completion phase, the uniqueness of the FAZEPRO system really becomes apparent. By simply adjusting the pH of either the breaker solution or the completion brine, the wettability of the filter cake is transformed from an oil-wet state to water-wet. Once the filter cake is water-wet, it can be removed easily and entirely with standard water-base breaker treatments, even through gravel packs which, by their very nature, normally restrict lift-off. The result is minimal formation damage and optimized production rates.

Features • Oil-base drilling performance • Water-base cleanup • Oil-wetting easily reversed with pH change • Stable chemical package • Water-wet surfaces after pH change • Good shale inhibition

Benefits • Faster drilling, stable wellbore • Easier to clean up • Reduces waste generation • Better production rates • Can clean up through open-hole gravel packs • Less costly remedial treatments

Water Acid

Water

Oil Base

Pressure-Drop Comparison 350 Screen pressure drop (psi)

300

250

200

By changing the pH of the breaker or completion brine, the filter cake deposited by the FAZEPRO system is converted from a waterin-oil emulsion to a direct oil-in-water emulsion, resulting in easy and complete cleanup.

Flexible components designed for invert-emulsion drilling in the reservoir

Earlier designs of conventional oil and synthetic-base reservoir drill-in fluids relied on strong emulsifiers and wetting agents. Powerful surfactants and solvents were used prior to production in an attempt to remove or break down these conventional-fluid filter cakes. Such methods had only limited success. The FAZEPRO system changes all that. The uniquely engineered emulsifier package developed specifically for the FAZEPRO system allows for a single-stage cleanup that is easier to perform and far more efficient than is possible with typical invert-emulsion fluids. First, there’s FAZE-MUL*, the industry’s only emulsifier capable of being reversed from an oil to a water continuous phase. Complementing the

Simulator Results of Pressure-Drop Comparison Final Pressure Drop Across Core (psi)

Initial Pressure Drop Across Screen (psi)

Final Pressure Drop Across Screen (psi)

2.30 2.34

2.77 2.85

0.1 0.1

>300 0.3

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 plugged the screen, whereas the FAZEPRO filter cake did not damage the screen. These data can be explained by the fact that the FAZEPRO system’s components were well-dispersed or dissolved by the acid treatment, so there was no coherent filter cake left to plug the screen.

100

50

0 0

5

10

15

20

25

30

Time, min SBM FAZEPRO

emulsifier is FAZE-WET*, a specially designed wetting agent. M-I SWACO designed this package so that alkalinity conditions slightly below neutral (pH 7) will change the emulsifier into a surfactant. Once that happens, the deposited filter cake, including solids and residual fluids, then becomes water-wet. And, waterwet solids usually translate into a more efficient cleanup, resulting in optimized production rates. When the unique FAZE-MUL emulsifier package is reversed to water-wet, the FAZE-WET oil-wetting agent is removed at the same time. Once the downhole conditions revert to water-wet, cleanup as a part of the completion becomes much simpler. What’s more, you are no longer faced with the additional expense and risks associated with complicated, time-consuming cleanup procedures involving multistage stimulation treatments of acid-blend packages, mutual solvents and non-emulsifiers.

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

Conventional synthetic-base fluid FAZEPRO*

Initial Pressure Drop Across Core (psi)

150

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

One of the key advantages of the FAZEPRO system lies in its flexibility. With the exception of the emulsifiers, the principal components of the FAZEPRO system are comparable to those in a conventional invert emulsion. They include the brinebase internal phase, organophilic clay and lime as the alkalinity agent. Neither the base fluid nor brine requires any special makeup. And, FAZEPRO technology can be incorporated into a variety of invertemulsion base fluids, including synthetics, diesel, mineral oils,

The emulsifier package’s unique chemistry is the key to a water-wet filter cake

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Oil

paraffins and olefins. In other words, any base fluid you would use in a conventional invert system works with the FAZEPRO system. Likewise, you can use organophilic clays for viscosity just as you would in a conventional invert emulsion.

39

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


APPLICATIONS

Onshore and offshore wells that require a flexible, non-damaging reservoir drill-in fluid for a variety of 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 fluid invasion is critical • Expandable sand-screen completions • High-temperature applications


PROBLEMS

Many drilling and reservoir drill-in fluids can harm producing formations with high solids content, persistent filter cakes and high ECDs that can cause fracturing and lost circulation.


SOLUTIONS

The FLOPRO NT system is a proven solution with non-damaging characteristics, minimal drawdown pressure, an extremely low friction factor for low pump pressures and high ROP, an extremely high capacity for cuttings transport, waterbase formulation and global environmental compliance.




E C O N O M I C S

Because it is specifically engineered for high production rates, the FLOPRO NT system increases hole-cleaning efficiency and protects fragile formations. Its waterbase formulation saves disposal costs and its precisely controlled bridging agent particle-size distribution allows completion equipment to function properly, and speeds up cleanup.


ENVIRONMENTAL The water-base FLOPRO NT system has been approved for all major drilling areas of the world.

40

Start preparing your reservoir for higher production rates right from the start

For production and reservoir engineers: wells that are productive sooner

In response to the industry’s demands for greater drilling efficiencies and higher production rates, M-I SWACO developed this new-generation reservoir drill-in fluid — FLOPRO NT. The system begins with your production-rate target and completion design then works back to the drill-in operation, optimizing all the factors that will affect your success. You get a system which provides strong benefits as a high-performance, non-damaging drill-in fluid that optimizes production rates across a wide range of completion methods. See “Applications” in first column. As the well is being drilled and completed, your M-I SWACO fluids engineer ensures that the system is capable of delivering what it promises — maximum reservoir productivity, lower total well costs and minimal environmental risk.

Because the design of a FLOPRO NT system is based upon the way you’ll complete your well, the completion process itself is greatly simplified. Every system component is soluble in some type of treatment chemical to make chemical breaking and cleanup relatively simple and straightforward. Because the filter cakes are designed to lift-off with the minimum possible drawdown, FLOPRO NT wells can, in many cases, begin production without chemical cleanup treatments. Because of the system’s flexibility, your M-I SWACO engineer can build a FLOPRO NT system from a number of base fluids, including freshwater, seawater, potassium chloride, sodium chloride, calcium chloride, sodium bromide and FORMIX* TECHNOLOGY, which includes sodium formate, potassium formate and cesium formate.

Features

Benefits

• Customized formulations • Non-damaging • Low lift-off • Engineered for easy cleanup • High return permeability • Ultra-low-permeability filter cake • Precisely controlled particle-size distribution of bridging agent • Extremely low friction factor • Promotes low skin values • Environmentally acceptable • Rheologically engineered for elevated LSRV

• Maximizes production • Reduces remediation costs • Higher production rates sooner • Minimal lift-off required, faster cleanup • Minimizes solids and fluid invasion to the formation • Reduces pump pressures • Maximizes ROP, saves drilling time • Excellent hole-cleaning profile • Reduces cleanup and disposal costs • Compatible with any completion assembly

Return-Permeability Profile

40 Pressure (psi)

350 Permeability (md)

Return-Permeability Tests Return (%) 100 90

300

35

100 Return permeability (%) 90

80 250

70

80

200

60

70

30

50

25

150

20

40 30

100

20

50

15

10

0 10

0 0

20

40

60

80

100

120

140

160

180

60 50 40 30 20

Time, min

5

10 Initial Return

0 FLOPRO NT

Single-sack product

Because the FLOPRO NT system can be custom-tailored to the well conditions at hand, it consistently outperforms singlesack reservoir drill-in-fluid products in both return permeability and cleanup — two major factors in increasing production and reducing costs.

0 FLOPRO NT

Single-sack product

The High-Temperature, High-Pressure (HTHP) return permeameter measures the permeability 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 fluids containing lost-circulation materials and large bridging particles, and run acid cleanup tests in high temperatures and pressures.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

For drilling engineers: maximum ROP and reduced drilling costs

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

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

During drill-in operations, the FLOPRO NT system exhibits excellent drag reduction inside the drillstring and can lower string pressure loss by as much as 40% compared to conventional water- or oil-base drilling fluids. The system prevents clay hydration and dispersion, while its gel-like structure traps and suspends cuttings, producing a cleaner hole, and because the viscosity of FLOPRO NT fluids is such that cuttings beds are virtually eliminated, the system greatly reduces torque, drag and differential sticking.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Lift-Off Pressure

41

FLOPRO SF The solids-free system for wells that require special handling


APPLICATIONS A variety of wells that do not tolerate a high percentage of solids, where bridging agents are not required or where acid is not an acceptable breaker. Coiled-tubing and heavy-oil wells are prime applications.


PROBLEMS

Many reservoirs and completion methods will not reach pre-well goals if solids, such as bridging agents and lost-circulation materials, are introduced into the reservoir drill-in fluid.


SOLUTIONS

The FLOPRO* SF system controls fluid invasion into the formation with viscosity. It is formulated with a higher LSRV than a conventional FLOPRO system.


ECONOMICS

The system reduces and even prevents formation damage to increase production. Its lack of solids allows completion equipment to function properly, and its formulation speeds up cleanup.

42

The FLOPRO SF (Solids-Free) system is a water-base Reservoir Drill-In Fluid (RDF) which has proven itself as a successful “rheologically engineered” system that relies on viscosity to control fluid invasion into the formation. It is formulated with a higher Low-Shear-Rate Viscosity (LSRV) than a conventional FLOPRO NT system.

The reservoir and your production come first when we design a FLOPRO SF system M-I SWACO engineers design FLOPRO SF systems with respect to the reservoir properties and the completion method to be used. Factors taken into consideration include: • Formation permeability or pore size • Formation temperature • Presence of reservoir gases • Formation sensitivity to particular ions • Clay content • Type of hydrocarbon(s) to be produced

the system. And FLOPRO SF fluids work well where overbalance pressure is kept to a minimum to reduce invasion depth into dolomite, limestone, and consolidated or unconsolidated sands. The applications for FLOPRO SF can include: • Coiled-tubing applications • Ultra-low-permeability formations • Formations that contain high-viscosity oil

Reducing fluid invasion without solids

• As pills for running completion assemblies after having drilled with FLOPRO NT

FLOPRO SF systems can be used where bridging agents are not required or acid is not a desired breaker. Heavy-oil formations, where formation viscosity confronts drilling-fluid viscosity to further reduce leak-off invasion depth, are also excellent candidates for

• Barefoot, slotted-liner, open-holegravel-pack or non-gravel-pack completions • Cased-hole completions where hole cleaning or minimizing fluid invasion is critical

FLOPRO SF systems can be designed with 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 today Just call your M-I SWACO representative and ask to see case histories of the FLOPRO SF system at work. Then put it to work for you.

Features • Does not rely on starch or sized bridging agents • Circulates at low pump pressures • 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 hightemperature applications

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Flexible formulation makes the system a practical solution virtually anywhere

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

43

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


APPLICATIONS

Open-hole gravel packs, expandable screens, stand-alone completions or any open-hole application where chemical breakers are normally applied, including oil- or condensateproduction wells.


PROBLEMS

Once the gravel pack is complete or the screen expanded, the filter cake is trapped between the formation and the completion assembly, making it difficult to access with a chemical breaker. In the case of stand-alone completions, premature breakthrough or other complications sometimes prevents the breaker from fully contacting the filter cake.


SOLUTIONS

The FLOTHRU* system’s oil-permeable filter cake requires lower flowinitiation pressures, permitting oil to readily pass through.


ECONOMICS

The FLOTHRU system eliminates the time and costs associated with chemical breakers and permits higher early hydrocarbon production rates that often offset water production.


ENVIRONMENTAL The FLOTHRU system’s water-base formulation minimizes environmental concerns, and its flexibility allows it to be engineered with components that meet most environmental criteria worldwide.

44

During an open-hole completion where the filter cake is confined, as in open-hole gravel packs or expandable-screen completions, the cake must remain intact to prevent losses and premature screenout. Once the completion operation has finished, however, the filter cake is usually removed with a chemical breaker to aid well productivity and avoid pieces of the cake plugging the screen during production. The catch is that it can be difficult to access the confined filter cake with a chemical breaker. The cake can fail prematurely during breaker application, causing the breaker to bypass, or fail to contact, portions of the cake. This results in inadequate filter-cake dissolution. One way to address this problem is to include a chemical breaker during the gravel-packing operation, but that approach can be problematic. If the chemical breaker is too aggressive and/or applied too early, premature filter-cake breakthrough

can occur and prevent the well from being completely gravel-packed. The FLOTHRU system offers a solution that eliminates the need for a chemical breaker.

How the FLOTHRU system works The FLOTHRU system is a waterbase Reservoir Drill-In Fluid (RDF) designed with enhanced flowback capabilities that eliminate the need for a chemical cleanup treatment, while providing higher return permeability and lower flow-initiation pressures. The primary application for a FLOTHRU system is in openhole completions where the filter cake is trapped between the formation and the completion assembly. In open-hole completions where the filter cake is not confined, the FLOTHRU system still provides a major benefit: lower flow-initiation pressures at comparable returnpermeability values. In the FLOTHRU system, a proprietary hydrophobic-carbonate

Features

Benefits

• Higher return permeability through Open-Hole Gravel Packs (OHGP) • Lower flow-initiation pressures for OHGP and stand-alone completions • Higher tolerance to drilled-solids contamination • Creates channels for steady oil flow • Requires no chemical breakers

• Increases production rates, from heel to toe • Removes cleanup risk/cost • Cuts completion time and costs • Allows oil to preferentially produce • Eliminates remedial completion operations • Gradual filter-cake cleanup removes screenplugging potential

The low-solids system with superior drilling characteristics

the absorption of water by shales and/or formation clays. Due to the low solids and the polymeric nature, FLOTHRU systems generally have a very low coefficient of friction — typically 0.2 to 0.25. This assists in rotary and oriented drilling operations. Lubricants have been found to further decrease the coefficient of friction in FLOTHRU systems to about 0.15.

Return Permeability and Flow-Initiation Pressure All 40/60 Gravel Packs with No Chemical Cleanup

Return Permeability and Flow-Initiation Pressure Clean Fluids, No Chemical Cleanup

100% Return permeability

Flow-initiation 25 pressure (psi)

100% Return permeability

Flow-initiation 30 pressure (psi)

90

90 20

80

25

80 70

70 15

60

20

60 15

50

50 10

40

40 10

30

30 5

20

20

5

10

10 0

0 Clean fluids

Conventional RDF

Contaminated fluids FLOTHRU formulations A B FLOTHRU

psi

0

0 Stand-alone tests FLOTHRU formulations A B Conventional RDF

Description

Gravel-packed completions

FLOTHRU

psi

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

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

• Water-base monovalent salts • Organophilic cake components – Carbonate — very fine – Starch • Biopolymer viscosifier • Properly sized bridging agents

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

The rheological properties of a FLOTHRU system are created with a variety of biopolymers, including FLO-VIS* PLUS and FLO-VIS NT. The rheological profile of a FLOTHRU system exhibits an elevated lowshear-rate rheology while maintaining minimal high-shear-rate rheology — in particular, minimal plastic viscosity. This type of rheological profile has consistently demonstrated low pump pressures, rate-of-penetration enhancement and excellent hole-cleaning capabilities.

To engineer a highly inhibitive system, the chemistry of the FLOTHRU system can be adjusted with salts or hydration suppressants such as KLA-STOP* or KLA-GARD*. These materials utilize cation exchange to suppress clay hydration. They are also compatible and work together with the system’s polymers, a viscosifier and a fluid-loss-control agent, to impede

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

component combines with a hydrophobic starch to control fluid loss. These materials create organophilic (oil-preferential) channels through the FLOTHRU filter cake. Their filter-cake-building characteristics provide a lowpermeability barrier to water and prevent high infiltration. These same organophilic channels avoid the cohesive nature of conventional water-base RDF filter cakes and provide increased transmissibility of hydrocarbons, eliminating the need for chemical breakers.

45

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


APPLICATIONS

Onshore and offshore (including deepwater) wells that require highdensity, low-solids water-base or invert-emulsion drilling fluids and/or Reservoir Drill-In Fluids (RDF) for highly reactive shales, high-temperature holes, low weightmaterial sag and low Equivalent Circulating Density (ECD).


PROBLEMS

Environmental regulations mandate the use of halide-free, aqueous-base drilling fluids, and most conventional high-density fluids include a significant volume of weight material that can reduce ROP, increase ECD, and cause weight-material sag and completion impairment.


SOLUTIONS

FORMIX TECHNOLOGY is the process for designing a drilling-fluid or RDF system around a formate salt. This can include either invert-emulsion or water-base systems with densities as high as 14.2 or 19.1 lb/gal (1.7 or 2.29 SG), respectively, with no solids.


ECONOMICS

FORMIX TECHNOLOGY systems optimize drilling efficiency and dramatically minimize the risk of reservoir damage and completion impairment. The low-solids content of the systems paves the way for reuse on subsequent wells.


ENVIRONMENTAL

These formate systems contain no chlorides or bromides, have greater environmental acceptability than other water-base or invert-emulsion fluids, and eliminate the need for toxic biocides.

46

FORMIX TECHNOLOGY starts with a new look at some familiar compounds Formates are relatively new to the petroleum industry. They are salts, not unlike the halide family of chlorides and bromides used in the oilfield for years. Monovalent formate salts are extremely soluble in water and form high-density, solids-free brines, reducing the need for weighting agents. M-I SWACO has a long history of engineering formate-base brine systems for various global applications. Today, three monovalent organic formate salts — sodium formate, potassium formate and cesium formate — provide the basis for our latest breakthrough in fluids engineering. FORMIX TECHNOLOGY has been successfully incorporated into the M-I SWACO FLOPRO NT reservoir drill-in fluid system to drill and complete wells in particularly challenging environments: high temperatures, damage-prone reservoirs, wells with narrow ECD windows and wells in environmentally sensitive areas. FORMIX TECHNOLOGY has also been utilized with our VERSAPRO* LS low-solids invertemulsion system to produce fluids with densities higher than those achievable with a conventional halide brine internal phase.

Economics and Reclamation 250 Daily treatment cost (U.S. $)

200

150

100

50

0 XY 1

XY 2

XY 3

XY 4

XY 5

XY 6

CaCO3 polymer mud

XY 7

XY 8

XY 9

XY 10

XY 11

Formates

Formates bring versatility and environmental strengths to both invert and water-base fluids Using FORMIX TECHNOLOGY in waterbase RDFs results in increased productivity due to lower solids concentration; a thin, impermeable filter cake and compatible basefluid chemistry. Being monovalent, they reduce scaling potential and are compatible with most reservoir minerals and fluids. Formates are also highly compatible with RDF polymers, viscosifiers and fluid-losscontrol agents. In conventional drilling applications, FORMIX TECHNOLOGY provides fluid stability for drilling through sensitive shale sections, or when

Features

Benefits

• High densities with minimal solids • Minimal formation damage • Excellent QHSE profiles • Compatible with reservoir fluids and polymers • Completion compatible • High shale and gas hydrate inhibition • Thermally stable to >350° F (177° C) • Low corrosion rates

• Increases production • Reduces project costs • Environmentally acceptable • Enhances solidscontrol efficiency • Fewer completion problems • Increases ROP • Ideal for HTHP drilling • Reduces weight-material sag

The systems that bring wide-ranging benefits to a wide range of applications

• The inhibitive water-base nature of these formate systems makes them ideal for drilling highly reactive shales

Properties of Formate-Base FLOPRO NT vs. OBM 40

30

20

0 Solids (0%)

PV (cP)

Gel Gel Gel 10 sec 10 min 30 min lb/100 ft2 lb/100 ft2 lb/100 ft2 FORMIX

OBM

• All of the above tendencies also open the door for the systems’ use as thermal stabilizers in conventional water-base fluid formulations • Since these FORMIX TECHNOLOGYbase systems are engineered to deliver minimal circulatingpressure losses and maximize power transmission to both the bit and mud motor, they are viable choices for extended-reach and horizontal wells

2,500 Depth drilled (ft)

2,700

2,900

3,100

3,300

3,500 0

5

10

15

20

25

Planned

Actual

Our FLOPRO NT reservoir drill-in fluid system, based on FORMIX TECHNOLOGY, is an excellent candidate for high-density, slim-hole drilling applications. The shearthinning and drag-reducing properties are extremely compatible with the small-diameter tubulars and narrow annuli in both slim-hole and coiled-tubing wells.

Formate Densities Formate Sodium formate Potassium formate Cesium formate

Chemical Symbol NaCOOH KCOOH CsCOOH

30

Section days

Maximum Density @ 68° F (20° C) 11.2 lb/gal (1.34 SG) 13.3 lb/gal (1.60 SG) 19.7 lb/gal (2.37 SG)

Maximum Salt Concentration 45% 76% 83%

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

10

• They have the capacity to eliminate the problems associated with weight-material sag, as well as the compressibility and ensuing high ECDs of invert-emulsion fluids, making FORMIX TECHNOLOGY systems well suited for both HTHP and deepwater drilling

Progress vs Drilling Days

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

The more we utilize FORMIX TECHNOLOGY, the wider the range of applications grows for the systems based on it. Here are just some of the advantages being discovered and proven:

• Using natural polymers, they are inherently thermally stable, keeping the rheological and fluid-loss control properties stable in the face of downhole temperatures in excess of 350° F (177° C)

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

drilling in environmentally sensitive areas. For either RDF or conventional drilling, formates provide stability at high temperatures. Like other salts, formates can be blended together to create an assortment of densities and crystallization points. For high-density, invertemulsion-fluid applications, FORMIX TECHNOLOGY provides density with minimal solids. The high-density, monovalent-brine internal phase is highly compatible with VERSAPRO LS emulsifiers, providing excellent emulsion stability at oil/brine ratios down to 50:50.

47

NOVAPRO/VERSAPRO/PARAPRO
APPLICATIONS

Onshore and offshore developmental wells designed for both cased- and open-hole completions.


PROBLEMS

Many conventional drilling-fluid systems “specialize” in one or two characteristics. In the case of developmental wells, however, a combination of desirable characteristics are required to achieve a balance among good drilling, good completions and high production rates.


SOLUTIONS

The NOVAPRO*, VERSAPRO* and PARAPRO* systems are nondamaging, invert-emulsion fluids designed to minimize formation damage problems such as oil wetting, emulsion blocking, and solids plugging, yet retain the performance advantages of invert-emulsion fluids, including high Rates of Penetration (ROP), lubricity and wellbore stability.


ECONOMICS

The systems’ fast-drilling characteristics and non-damaging formulations save time and money while drilling and completing the well, and they result in higher returns sooner 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 drilling developmental wells designed for both cased- and open-hole completions. These systems are designed to minimize formation damage problems such as oil wetting, emulsion blocking, and solids plugging, yet retain the performance advantages of invert-emulsion fluids, including high Rates of Penetration (ROP), lubricity and wellbore stability. Owing to the higher priority of minimizing formation damage and compatibility with completion assemblies, these fluids differ from conventional invert-emulsion fluids in their design and application. The emulsifier/wetting agent package, the type and size of bridging material and, indeed, all components required are reviewed for the best combination of drilling and completion characteristics. The NOVAPRO/VERSAPRO systems are versatile, providing tremendous flexibility for numerous applications. The key concepts to keep in mind when planning and using a NOVAPRO/ VERSAPRO/PARAPRO system are: • Minimizing formation damage

48

• Providing completion compatibility • Maximizing productivity

Applications NOVAPRO/VERSAPRO/PARAPRO invertemulsion reservoir drill-in fluids are designed with flexibility in the formulation that makes them suitable for a variety of applications: • Open-hole gravel packs or stand-alone screens • Cased-hole completions • High-temperature applications • Barefoot or slotted liner completions

System components The NOVAPRO system is built using synthetic-base fluid; the VERSAPRO system uses either diesel or mineral-base fluid while the PARAPRO system uses paraffin-base oil. All systems exhibit all of the drilling advantages of conventional invert-emulsion fluids. In some cases, a conventional NOVAPLUS*, VERSACLEAN*, VERSADRIL* or PARADRIL* drilling-fluid system can be converted to a NOVAPRO, VERSAPRO or PARAPRO system. This may involve adjusting the size and/or concentration of the bridging/ weighting agent and/or modifying the emulsion package.

Features

Benefits

• Flexible formulation • Non-damaging characteristics • Invert-emulsion drillingfluid properties • Employs proprietary software and PRODUCTION SCREEN TESTER* (PST*)

• Ideal for a variety of applications • Maximizes production • High ROP, lubricity and wellbore stability • Assures proper bridging, flowback tendencies

This water-base filter cake won’t come between you and your oil Breaking the filter cake in an open-hole gravel-pack or expandable-screen completion can be tricky. Break it too soon during the completion and you don’t get a good pack or expansion. If you leave the cake in place and try to break it chemically after the gravel pack is complete or the screen is expanded, you could damage the formation or plug the screen.

The solution: The FLOTHRU oil-permeable filter cake

Easy to run, environmentally sensible Solving several problems at once on the U.S. West Coast

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

www.miswaco.com

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

For drilling a 1,000-ft (305-m) reservoir section, a West Coast operator planned to drill a horizontal well utilizing an open-hole gravel-pack completion. Excellent drilling characteristics, and the ability to enhance production flowback without a chemical cleanup treatment, made the FLOTHRU 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-filtrate or solids problems observed in previous wells  Production was 33% above the anticipated oil rate, with lower-thanexpected water cuts — an average of 50% below normal

A typical FLOTHRU system incorporates very few base products, making it easy to engineer and maintain while keeping logistics considerations to a minimum. The highly inhibitive system exhibits a low coefficient of friction, high LSRV and a minimal plastic viscosity. With its water-base formulation, the FLOTHRU system meets most environmental regulations worldwide. Contact your M-I SWACO* representative to discover how the FLOTHRU system can help your open-hole gravel-pack and stand-alone completions.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

TECHNOLOGY

The FLOTHRU* system is a water-base Reservoir Drill-In Fluid (RDF) designed with enhanced flowback characteristics that eliminate the need for a chemical cleanup treatment. A combination of proprietary materials form the basis for a filter cake that provides a low-permeability barrier to water and prevents high infiltration. The cake forms organophilic channels that promote the transmission of hydrocarbons and eliminate the need for chemical breakers. Bottom line: water stays out of the formation; more oil flows into the wellbore.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

FLOTHRU

49

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


APPLICATIONS

Wells that require an oil-base or reservoir drill-in-fluid system for either open-hole or casedhole completions; a low-solids perforation pill; a solids-free preproduction pill for open-hole completions.


PROBLEMS

While most conventional oil-base drilling-fluid systems impart minimal formation damage, their high solids content often impairs the completion and restricts production. Solids may also impact productionfacility efficiency.


SOLUTIONS

The density of the internal phase of the VERSAPRO LS/SF systems is maximized, and solids are incorporated only to aid emulsion stability and bridge the formation. With a low-to-no level of solids, the chances for completion and tool plugging greatly decrease.


ECONOMICS

Typically, wells drilled with the VERSAPRO LS system are characterized by less completion plugging and higher production rates than wells in the same area drilled with conventional invert systems. Solidsfree pills have helped eliminate production-facility upsets.

The system that lets you place formation protection where you need it As a reservoir drill-in or completion fluid, or as a displacement or perforating pill, the VERSAPRO LS system has proven to be one of the most versatile on the market: • In both cased-hole and open-hole completions where oil-base fluid is required for drilling • As a cased-hole perforation pill, it minimizes the threat of solids plugging the perforation tunnels, while preventing losses to the reservoir

50

• In open-hole completions, it is ideal as a low-solids fluid-losscontrol pill to be left in the productive section prior to running the completion assembly. Bridging agents can be eliminated in VERSAPRO SF pills used where there is a pre-existing solids-laden filter cake. The pill can be used as a screen-running pill or preproduction pill. • As a temporary-abandonment fluid to minimize the risk of solids settling prior to the initiation of production

Filter-Cake Lift-Off Pressure

120 lb/100 ft2 (58.59 kg/10 m2)

250 Millibars

100 (48.83)

200

80 (39.06)

150

60 (29.30) 100 40 (19.53) 50

20 (9.77) 0

0 VERSAPRO LS

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 productivity index as compared to previous perforated, horizontally completed wells in the same field

• As a workover fluid, the system enabled another operator to complete workover operations and return a group of wells to production rates at or above expectations while eliminating scale problems experienced with water-base workover fluids VERSAPRO SF pills have displaced VERSAPRO drilling fluids in multilateral wells during completion

VERSAPRO LS

OBM

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

Features

Benefits

• Low to no solids loading • High-density-brine internal phase • Oil continuous phase • Thermally stable • Bridging agents optimized for specific formations

• Maximized production • Reduced screen plugging • High return-flow efficiency • Greatly reduced sag or settling • Low fluid loss • Reduced gelation • Reduced production-facility upsets

and prior to production. This has allowed flowback through production facilities without facility upset. These are only a few examples of why operators the world over are turning to the VERSAPRO LS system to get the most their reservoirs have to offer.

To learn more about how VERSAPRO LS is helping operators worldwide maximize production, contact your local M-I SWACO representative.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

• A VERSAPRO LS pill remained very stable under downhole conditions and, unlike previous wells in the area, did not plug the completion assembly, so the operator could reach expected production levels

Field Mud

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Gel Strength Comparison Over 12-day Period

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

51

Drilling-Fluid and RDF Products Product Trade Name

ACTIGUARD* ACTIVATOR* I ACTIVATOR* II ASPHASOL* ASPHASOL* D ASPHASOL* SUPREME BLUE STREAK* BUBBLE BUSTER* CAUSTILIG*

Primary Function

Secondary Function

Shale and clay inhibitor for the APHRON ICS system Thermal stabilizer for the APHRON ICS system Thermal stabilizer for the APHRON ICS system Sulfonated organic-resin blend Sulfonated organic blend Sulfonated asphalt

Water Water Water Water Water Water

Shale inhibitor Thermal extender Thermal extender Shale inhibitor Shale inhibitor Shale inhibitor

— — — Filtration Filtration Filtration

Mud conditioner and air micro-encapsulator for the APHRON ICS system Low-toxicity defoamer Caustilized lignite

Water

Surfactant

Water Water

Defoamer Thinner Filtration Surfactant

Viscosifier Filtration — Thermal stability Emulsifier Emulsifier

Corrosion inhibitor Corrosion inhibitor Corrosion inhibitor Corrosion inhibitor Lost circulation

— — — — —

Lost circulation

—

Surfactant

CLEAN UP*

Detergent for general rig cleaning when using oil- and synthetic-base fluids

CONQOR* 101 CONQOR* 202 B CONQOR* 303 A CONQOR* 404 C-SEAL*

Filming amine Persistent filming amine Amine corrosion inhibitor for clear brines General-use, phosphorus-base inhibitor Coke FLCA

C-SEAL* F

Coke FLCA (fine grind)

D-D*

Drilling detergent

DEFOAM-A* DEFOAM-X* DI-ANTIFOAM* DI-BALANCE* DI-BOOST* DI-INHIB* DI-TROL* DOWFROST MI* DRIL-FREE* DRIL-KLEEN*

D-SPERSE* DUAL-FLO* DUAL-FLO* HT DUO-TEC* DUO-VIS* DUO-VIS* L DUO-VIS* PLUS DURALON* DUROGEL* ECOGREEN* B ECOGREEN* M ECOGREEN* P ECOGREEN* S ECOKLEEN* ECOTROL* RD

Alcohol-base defoamer All-purpose liquid defoamer Antifoaming agent for the DIPRO system Viscosifier for the DIPRO system Secondary viscosifier for the DIPRO system Shale inhibitor for the DIPRO system Filtration control agent for the DIPRO system Low-temperature product High-performance lubricant, anti-sticking agent Concentrated, mild drilling detergent with low toxicity Anti-bit balling agent Viscosifier for the DRILPLEX MMO system ROP enhancer Low-cost anticrete Chelant filter-cake remover for water-, oil- or synthetic-base drilling fluids Chelant plus acid filter-cake remover for water-, oil- or synthetic-base drilling fluids Surfactant Fluid-loss reducer for the FLOPRO NT system Fluid-loss reducer for high-temperature applications Xanthan gum Xanthan gum Liquified xanthan gum, non-clarified Xanthan gum High-temperature filtration-control polymer Sepiolite clay Ester base fluid Low-end rheology modifier Primary emulsifier for the ECOGREEN system Secondary emulsifier for the ECOGREEN system Anticrete for tar applications Readily dispersible filtration control additive

EMUL HT*

HTHP emulsifier

ENVIROBLEND*

Salt for ENVIROVERT system

DRIL-KLEEN* II DRILPLEX* DRILZONE* DRILZONE* L D-SOLVER* D-SOLVER* PLUS

52

Type

Description

Water Oil Synthetic Water Water Water Water Water, Oil, Synthetic Water Oil Synthetic Water Water Water Water Water Water Water Water Water Water Water

Defoamer Defoamer Defoamer Viscosifier Viscosifier Shale inhibitor Filtration Antifreeze Lubricant Surfactant

Water Water Water Water Water

Surfactant Viscosifier Surfactant Surfactant Breaker

Emulsifier Shale control — — — pH control — — — — Surfactant Emulsifier Shale control Emulsifier, Lubricant Shale inhibitor — — —

Water

Breaker

—

Water Water Water Water Water — Water Water Water Synthetic Synthetic Synthetic Synthetic Water Oil Synthetic Oil Synthetic Water

Surfactant Filtration Filtration Viscosifier Viscosifier Viscosifier Viscosifier Filtration Viscosifier Thinner Viscosifier Emulsifier Emulsifier Surfactant Filtration

— — — — — — — Thermal stability — Lubricant — Surfactant Surfactant — —

Emulsifier

—

Shale inhibitor

—

Emulsifier for FAZEPRO system

FAZE-WET*

Wetting agent for the FAZEPRO system

FER-OX*

Hematite

FLO-PLEX* FLO-TROL* FLO-VIS * L FLO-VIS * NT FLO-VIS * PLUS FLO-WATE* FLOXIT * FORM-A-PLUG* II

Fluid-loss additive for the DRILPLEX system Starch derivative Non-dispersible, clarified xanthan gum Non-dispersible, non-clarified xanthan gum Premium-grade, clarified xanthan gum Sized-salt material Clay flocculant Acid-soluble plug formulated with a finely ground borate

FORM-A-PLUG* ACC

Accelerator for the FORM-A-PLUG pill

FORM-A-PLUG* RET

Retarder for the FORM-A-PLUG pill

FORM-A-SET * FORM-A-SET * ACC

Cross-linked polymer plug Accelerator for the FORM-A-SET pill

FORM-A-SET * AK

Polymeric lost-circulation material

FORM-A-SET * AKX

Variant of FORM-A-SET AK for water shut off

FORM-A-SET * RET

Retarder for the FORM-A-SET pill

FORM-A-SET * XL

Cross-linker for the FORM-A-SET pill

G-SEAL*

Sized graphite bridging agent

GELEX*

Bentonite extender

GELPLEX* GLYDRIL* DG GLYDRIL* GP

HRP* HYDRABLOK* IDCAP * D IDLUBE* XL IDSPERSE* XT INHIBYCON

Viscosifier for the DRILPLEX system Water-miscible glycol-hydrate inhibitor Broad-cloud-point, general-purpose polyglycol for low-salinity fluids and low temperatures Polyglycol for high-salinity fluids and high temperatures Low-cloud-point polyglycol for low-salinity fluids and low temperatures Medium-cloud-point polyglycol for moderate-salinity fluids and high temperatures Provides LSRV for APHRON ICS system Modified metal-cellulose polymer Modified metal-cellulose polymer that also provides viscosity Fluid-loss additive and secondary shale inhibitor with ultra-low viscosity Liquid viscosifier for oil fluids Deepwater hydrate inhibitor Polymeric shale inhibitor Extreme-pressure lubricant High-temperature polymeric dispersant Wide-molecular-weight glycol

K-17* K-52* KLA-CURE * KLA-CURE * II KLAFLOC* I

GLYDRIL* HC GLYDRIL* LC GLYDRIL* MC GO DEVIL* II HIBTROL* HIBTROL* HV HIBTROL* ULV

Oil Synthetic Oil Synthetic Water Oil Synthetic Water Water Water Water Water Water Water Water Oil Synthetic Water Oil Synthetic Water Oil Synthetic Water Water Oil Synthetic Water Oil Synthetic Water Oil Synthetic Water Oil Synthetic Water Oil Synthetic Water Oil Synthetic Water

Primary Function

Secondary Function

Emulsifier

—

Surfactant

—

Density

—

Filtration Filtration Viscosifier Viscosifier Viscosifier Density Flocculant Lost circulation

— Viscosifier — — — Filtration Shale inhibition Filtration

Lost circulation

—

Lost circulation

—

Lost circulation Lost circulation

— —

Lost circulation

—

Lost circulation

—

Lost circulation

—

Lost circulation

—

Lubricant

Filtration

Water Water Water

Flocculant Viscosifier Viscosifier Thermal stability Shale control Filtration Shale control Filtration Shale control Filtration Shale control Filtration Viscosifier Filtration Filtration

Water

Filtration

Oil Water Water Water Water Water

Viscosifier Surfactant Shale inhibition Lubricant Thinner Shale control

Potassium lignite

Water

Potassium supplement Hydration suppressant Hydration suppressant plus detergent Low-cost shale inhibitor for floc water drilling

Water Water Water Water

Filtration Thinner Shale control Shale control Shale control Filtration

Water Water Water Water Water Water

— — Surfactant Lubricity Lubricity Lubricity Lubricity Filtration Shale inhibition Shale inhibition Viscosifier Shale control Thermal stability — — — — Lubricity Filtration Emulsifier Shale control — — — —

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

FAZE-MUL*

Type

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Description

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Product Trade Name

53

Drilling-Fluid and RDF Products

54

Product Trade Name

Description

KLAFLOC* II KLA-GARD * KLA-GARD * B KLA-STOP* LO-WATE*

Cationic flocculant for floc water drilling Shale stabilizer and inhibitor Salt-free KLA-GARD Shale inhibitor Ground calcium carbonate weight material

LUBE-100 * LUBE-167* LUBE-776* LUBE XLS* M-I 157*

Low-toxicity lubricant Low-toxicity lubricant blend Lubricant Extreme-pressure lubricant Supplemental emulsifier

M-I BAR *

Barite, meets API specifications

M-I CEDAR FIBER* M-I CIDE* M-I GEL*

Shredded cedar fiber Biocide – Not available in the U.S.A. Bentonite, meets API specifications

M-IGEL* SUPREME M-IGEL* WYOMING M-I LUBE* M-I PAC* R

Non-treated bentonite, meets API specifications API-spec bentonite sourced only from Wyoming General-purpose lubricant PAC polymer, tech grade

Water Water Water Water

Lost circulation Biocide Filtration Viscosifier Viscosifier Viscosifier Lubricant Filtration

M-I PAC* SR

High-viscosity PAC, semi-pure grade

Water

Filtration

M-I PAC* SUL M-I PAC* UL M-I SEAL*

Low-viscosity PAC, semi-pure grade PAC polymer, low-viscosity, tech grade LCM for fractured or vugular formations

Filtration Filtration Lost circulation

M-I-X* II

Ground cellulose

Lost circulation

Filtration

MUD WASH* MUL HTP*

Rig wash Primary emulsifier for negative-alkalinity system

Rig wash Emulsifier

— Filtration

MY-LO-JEL* NOVAMOD* NOVAMUL*

Pregelatinized starch Rheology modifier, LSRV Basic emulsifier package

Water Water Water Oil Synthetic Water Oil Synthetic Rig wash Oil Synthetic Water Synthetic Synthetic

Filtration Filtration — Viscosifier Shale inhibitor Viscosifier Shale inhibitor Shale inhibitor Shale inhibitor Filtration

Filtration Viscosifier Emulsifier

NOVATEC * B NOVATEC * M

Synthetic Synthetic

Thinner Viscosifier

NOVATEC * P NOVATEC * S NOVATHIN* NOVAWET*

LAO base fluid Low-end rheology modifier for the NOVATEC system Primary emulsifier for the NOVATEC system Secondary emulsifier for the NOVATEC system Deflocculant Wetting agent

— — Surfactant Filtration Thermal stability Viscosifier Lubricant —

Synthetic Synthetic Synthetic Synthetic

Emulsifier Emulsifier Thinner Surfactant

NUT PLUG *

Ground nut shells

Lost circulation

OILFAZE *

Sacked oil-base concentrate

Water Oil Synthetic Oil

OS-1L* PARADRIL* B PARALAND* B PARAMIX* A PARAMIX* N PARATROL* HT PASSIVATOR* I PIPE-LAX*

Sulfite-base oxygen scavenger Base fluid for the PARADRIL system Base fluid C11-17 linear paraffin for the PARALAND system Salt for the PARALAND system Salt for the PARALAND system High-temperature Gilsonite Defoamer for the APHRON ICS system Oil-base, stuck-pipe-freeing surfactant

Corrosion inhibitor Thinner Thinner Shale inhibitor Shale inhibitor Filtration Defoamer Free pipe

PIPE-LAX* ENV

Low-toxicity, stuck-pipe spotting fluid

Water Synthetic Synthetic Synthetic Synthetic Synthetic Water Water Oil Water

Filtration Viscosifier Thermal stability — — — — — — —

Free pipe

Lubricant

Type

Water Water Water Water Water Oil Synthetic Water Water Water Water Oil Synthetic Water Oil Synthetic Water Water Water

Primary Function

Secondary Function

Filtration Shale control Shale inhibitor Shale control Density

— Filtration — — Filtration Lost circulation

Lubricant Lubricant Lubricant Lubricant Emulsifier

— — — — Filtration Surfactant —

Density

Emulsifier

— — —

Filtration Filtration Surfactant Emulsifier Thinner Thermal stability —

Description

PIPE-LAX* W EXPORT POLYPAC * ELV POLYPAC * R

Liquid, one-drum, stuck-pipe spotting fluid

POLYPAC * SUPREME R POLYPAC* SUPREME UL POLYPAC * UL POLY-PLUS *

Type

Primary Function

Secondary Function

Filtration Filtration

Premium-grade polyanionic cellulose

Water

Filtration

PAC, premium-grade, ultra-low viscosity

Water

Filtration

Polyanionic cellulose Liquid PHPA

Water Water

Filtration Shale control

POLY-PLUS * Dry

Dry PHPA polymer

Water

Shale inhibitor

POLY-PLUS * LV POLY-PLUS * RD

Low-viscosity PHPA Readily dispersible PHPA powder

Water Water

Shale control Shale control

POLY-SAL* POLY-SAL* T PTS-200* RESINEX*

Preserved modified starch Non-fermenting tapioca starch derivative Polymeric temperature stabilizer Resinated lignite complex

Water Water Water Water

Filtration Filtration Thermal stability Filtration

RESINEX* II

Resinated lignite, tech grade

Water

Filtration

RHEBUILD*

Viscosifier for RHELIANT system

Viscosifier

RHEDUCE*

Thinner for RHELIANT system

Thinner

—

RHEFLAT*

Rheological modifier for RHELIANT system

Viscosifier

—

RHETHIK*

Rheological modifier for RHELIANT system

Viscosifier

—

RHEOSPERSE* SAFE-CARB *

Polymeric high-temperature deflocculant Ground marble (calcium carbonate)

Thinner Density

— Filtration

SAFE-SOLV* E SALT GEL* SCREENKLEEN*

Surfactant Viscosifier Surfactant

— — —

SHALE CHEK *

Pipe dope pickle solvent Attapulgite clay Organic blend to control screen blinding while drilling heavy oil/tar formations Shale-control and gumbo additive

Synthetic Oil Synthetic Oil Synthetic Oil Synthetic Oil Water Water Oil Synthetic Water Water Water

Shale inhibitor Shale control Viscosifier Shale control Viscosifier Shale inhibitor Viscosifier Shale control Viscosifier Flocculant Filtration Flocculant Filtration, Flocculant Viscosifier Flocculant Viscosifier Viscosifier — Thermal stability Thinner Thermal stability Thinner —

Water

Shale control

SI-1000* SILDRIL* D SILDRIL* EPL SILDRIL* K SILDRIL* L SIL-LUBE* SP-101*

Scale inhibitor Dry sodium silicate Extreme-pressure lubricant for the SILDRIL system Potassium silicate Liquid sodium silicate Lubricant for the SILDRIL system Sodium polyacrylate

Water Water Water Water Water Water Water

Corrosion inhibitor Shale inhibitor Lubricant Shale inhibitor Shale inhibitor Lubricant Filtration

SPERSENE*

Chrome lignosulfonate

Water

Thinner

SPERSENE* CFI SPERSENE* I

Iron lignosulfonate Ferrochrome lignosulfonate

Water Water

Thinner Thinner

STARGLIDE* STEEL LUBE* EP SULFATREAT * DFS SULFATREAT * XLP SUPRA-VIS* SUREMOD*

Lubricant and ROP enhancer Extreme-pressure lubricant H2S scavenger Extended-life H2S scavenger High-performance biopolymer viscosifier Viscosifier, gelling agent for invert-emulsion systems

Lubricant Lubricant Corrosion inhibitor Corrosion inhibitor Viscosifier Viscosifier

SUREMUL*

Primary emulsifier for invert-emulsion systems

Emulsifier

Surfactant

SURETHIK* SURETHIN*

Rheological modifier Thinner for invert-emulsion systems

Water Water Water Water Water Synthetic Oil Synthetic Oil Synthetic Synthetic Oil

Filtration Surfactant Thermal stability — — — — — — Shale control Thermal stability Emulsifier Filtration Thermal stability — Thermal stability Filtration Surfactant — — — — —

Viscosifier Thinner

— Surfactant

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

—

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Free pipe

Extra-low-viscosity PAC Polyanionic cellulose

Water Oil Water Water

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Product Trade Name

55

Drilling-Fluid and RDF Products Product Trade Name

Description

SUREWET*

Wetting agent for for invert-emulsion systems

SV-120* SWA* EH

TACKLE * DRY TANNATHIN *

Organic H2S scavenger Oil-base wetting agent for high-brine-content systems Liquid, low-molecular-weight polyacrylate (dry available) Powdered low-molecular-weight polyacrylate Ground lignite

TARCLEAN* TARLIFT* TARSURF* TARVIS* THINSMART* THRUCARB* THRUTROL* TRUVIS* ULTRACAP * ULTRAFREE * ULTRAFREE * L ULTRAFREE * NH ULTRAHIB* UNITROL* VERSACLEAN * B VERSACOAT *

Anticrete agent for heavy oil to thin asphaltenes Solvent for the SAGDRIL* system Water-wetter for the SAGDRIL system Liquid viscosifier for the SAGDRIL system Thinner for water-base drilling fluids Carbonate for the FLOTHRU* system Organic starch for the FLOTHRU system Viscosifier for the TRUDRIL system Encapsulator for the ULTRADRIL system ROP enhancer for the ULTRADRIL system Low-cost anticrete Non-hydrocarbon version of ULTRAFREE ROP enhancer Shale inhibitor for the ULTRADRIL system Modified polysaccharide Base fluid for the VERSACLEAN system Emulsifier and wetting agent

VERSACOAT * NA

Primary Function

Secondary Function

Synthetic Oil Water Oil

Surfactant

Emulsifier

Corrosion inhibitor Surfactant

— Emulsifier

Water

Thinner

Water Water Water Water Water Water Water Water Water Oil Water Water Water Water Water Water Oil Oil

Thinner Filtration Thinner Shale control Surfactant Surfactant Viscosifier Thinner Density Filtration Viscosifier Shale inhibitor Surfactant Surfactant Surfactant Shale inhibitor Filtration Thinner Surfactant

High flash-point emulsifier for oil-base fluids

Oil

Emulsifier

VERSADRIL* B VERSAGEL* HT VERSALIG * VERSALUBE * VERSAMOD* VERSAMUL*

Base fluid for the VERSADRIL system Hectorite Amine-treated lignite Oil-soluble lubricant Rheology modifier, LSRV Basic emulsifier package

Oil Oil Oil Oil Oil Oil

Thinner Viscosifier Filtration Lubricant Viscosifier Emulsifier

VERSAPAC*

Thermally activated, organic thixotrope

Viscosifier

VERSAPRO* P/S VERSATHIN * VERSATROL*

Primary emulsifier Thinner and conditioner for oil-base fluids Asphaltic resin

Oil Synthetic Oil Oil Oil

Filtration Thermal stability — Emulsifier Thermal stability — — — — — Filtration — Filtration — — Lubricant Lubricant — — Lubricant Emulsifier Thermal stability Surfactant Thermal stability Lubricant Filtration Lost circulation — — Surfactant Filtration Thermal stability Viscosifier Lost circulation

VERSATROL* HT

High-temperature Gilsonite

Filtration

VERSAVERT * B VERSAVERT * BT VERSAWET *

Base fluid for VERSAVERT system Thin version of worker-friendly base oil Wetting agent for oil-base fluids

Oil Synthetic Oil Oil Oil

VG-69* VG-PLUS *

Organophilic clay Organophilic clay

VG-SUPREME* VINSEAL*

Organophilic clay for the NOVA systems Filtration control and electrical stability agent

WELLZYME * A WELLZYME * NS XP-20K*

Enzyme breaker for water-base reservoir drill-in fluid Enzyme breaker without biocide for reservoir drill-in fluids Potassium chrome lignite

XP-20* N

Chrome lignite, sodium hydroxide, neutralized

TACKLE *

56

Type

Emulsifier Thinner Filtration

Thinner Thinner Surfactant

— — Lost circulation Viscosifier —

Viscosifier Viscosifier

Lubricant Lubricant Emulsifier Thinner Thermal stability Filtration Filtration

Viscosifier Filtration

Filtration —

Breaker Breaker Thermal stability

— — Emulsifier Filtration Thinner Thinner Filtration

Oil Oil Synthetic Synthetic Water Oil Synthetic Water Water Water

Water

Thermal stability

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

Drilling

Completion

You have a lot riding on your displacement procedure, because it occupies that crucial position between drilling your well and completing it. That’s why we’ve created the INTEGRATED WELLBORE CLEANING SOLUTIONS* (IWCS*) program from M-I SWACO*. Much more than just a rigid suite of services and products, the IWCS service lets us work with you to develop a custom displacement program, using exactly what you need from: • The SPEEDWELL* line of downhole cleaning tools

Simultaneous drilling, cleaning save time on 3-year, P&A well Re-entering and cleaning this well that had been abandoned for 3 years went quickly and smoothly because of the close integration of M-I SWACO tools and fluids.

• M-I SWACO displacement chemistry and additives, completion fluids, filtration services, and proprietary VIRTUAL CF* software • Single-responsibility M-I SWACO displacement engineering that makes it all work in a truly integrated fashion for your maximum productivity

Upgrade to easier, better displacements Just call your M-I SWACO representative to discover how easy and clean an effectively run displacement can be with our INTEGRATED WELLBORE CLEANING SOLUTIONS. Call today and get the most from everything you put into your well.

 Running a tricone bit made up to the SPEEDWELL PUP* scraper, brush and magnet tool along with the PUP Finger Basket saved at least one entire trip

www.miswaco.com

 Operator had a perfect packer set in the clean, junk-free hole

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

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

 M-I SWACO displacement chemicals and filtered completion brine augmented with the SPEEDWELL tools ensured a clean downhole environment

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Because it’s all connected

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

INTEGRATED WELLBORE CLEANING SOLUTIONS

57

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


APPLICATIONS

Wells in the Gulf of Mexico and elsewhere that experience Sustained Casing Pressure (SCP) — recurring pressure in casing strings that will not bleed to zero psi (bar) after the well reaches a steady state of flow.


PROBLEMS

SCP presents an ongoing, serious safety and environmental hazard. Due to the nature of the gas-bearing formations, it cannot be prevented, but it can be controlled.

The uncontrolled release of pressure from a sealed casing string presents a serious safety and environmental hazard that reportedly affects nearly half of the wells in the Gulf of Mexico. The U.S. Minerals Management Service (MMS) estimates that the problem, known as Sustained Casing Pressure (SCP), affects some 11,000 casing strings in approximately 8,000 wells in the Gulf.

According to the MMS, some 30% of the affected wells require special departure waivers to maintain production, while all of them require continuous investment in either remediation or monitoring. While half of these incidents are reported to occur in the production casing, SCP may arise in any of the annuli within a well. This problem is not unique to the Gulf and is prevalent in a number of fields worldwide.


SOLUTIONS

As part of our all-inclusive Top-Down Casing-Pressure-Remediation Process, the nucleus of the M-I SWACO approach is to increase hydrostatic pressure by pumping our specially formulated FLODENSE* AP wellintervention fluid into the annulus.


ECONOMICS

By controlling casing pressure, FLODENSE AP fluid helps operators avoid costly blowouts as well as the constant repair of production equipment and tubulars.


ENVIRONMENTAL The M-I SWACO Top-Down CasingPressure-Remediation Process can prevent the adverse environmental impact of a blowout.

Gas bubble Mud or fluid

Cement

Gas formation

58

Complementing our Top-Down Casing-Pressure-Remediation Process is our high-density FLODENSE AP well-intervention fluid. The FLODENSE AP system contains a range of fluids that can be formulated for different applications with average densities ranging between 17.5 to 18 lb/gal (2.1 to 2.16 kg/L). If an application specifies, FLODENSE AP fluids can be formulated at densities up to 20.5 lb/gal (2.46 kg/L). The FLODENSE AP system can be used as a viscous, lubricious and solids-free fluid that is engineered to fall through the annulus with minimal dispersion.

The FLODENSE AP well-intervention fluid also can be engineered with micron-sized particles that allow the fluid to pass in snakelike fashion through very narrow apertures. Densities as high as 20.5 lb/gal (2.46 kg/L) of the neat slurry permit it to fall through most existing annular fluids. Owing to its micron-sized particles, the FLODENSE AP system exhibits reduced sag and settlement compared to competing systems. In fact, the settling rate of the fluid is 1,000 times less than that of API barite, while smaller FLODENSE AP particles have a settling rate 10,000 times less than barite. Both of these systems are designed to provide hydrostatic control.

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

Before we ever attempt to design a pressure-remediation plan for your particular situation, we look at every facet of your well. We

FLODENSE AP helps put the brakes on uncontrolled casing pressure

FLODENSE AP fluid falling through CaCl2.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Designing a remediation project begins with giving your well the third degree

examine all the casing strings in the well geometry, the well survey, production data and the types and densities of the fluids in all annuli. We evaluate the bottomhole, flowing and shut-in pressures; the flowing temperatures; and the sustained pressures on the various annuli. We then review drilling records to track the mud weights used and compare those densities to the trip and background gases. We identify the drilling breaks and track the cementing records. Armed with this mountain of data, we attempt to diagnose the cause of SCP on your well by first determining if the pressure is being released from the producing formation or another farther up the hole. Pulling all these pieces together is critical to designing the ideal solution for your individual situation.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Basically, SCP refers to any amount of recurring pressure in casing strings that will not bleed to zero psi after the well reaches a steady state of flow. Any number of failures, including leaks in tubing, casing, packers, wellhead packoffs and poor or failed cement jobs, can initiate sustained casing pressure. Recognizing the critical safety, environmental and economic consequences of SCP, M-I SWACO has taken the lead in developing a systematic line of attack to reduce or control these annular pressures. While the nucleus of our approach is to increase hydrostatic pressure by pumping our specially formulated FLODENSE* AP well-intervention fluid into the annulus, our all-inclusive Top-Down Casing-PressureRemediation Process entails so much more. We study the circumstances and parameters of each well to determine the best method for inserting a fluid-delivery system through an existing wellhead and into a constricted, pressurized annulus. Our specialists carefully examine corresponding data to establish how to best deliver the fluid downhole to achieve the necessary hydrostatic column for hydrostatic enhancement. The end result is the delivery of a fluid that will establish hydraulic control.

59

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


APPLICATIONS

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


PROBLEMS

Conventional fluid systems lack the combination of characteristics that the FLOPRO* CT system uses to overcome tubing damage, extended sliding distances, high temperatures, hole-cleaning inefficiencies and narrow pressure gradients.


SOLUTIONS

The FLOPRO CT system has been specially engineered to solve the unique combination of challenges found in coiled-tubing applications.


ECONOMICS

Because it is specifically engineered for coiled-tubing applications, the system saves time as well as wear and tear on the rig and tubing; increases hole-cleaning efficiency; and protects fragile formations. Its water-base formulation saves disposal costs.


ENVIRONMENTAL The water-base FLOPRO CT system has been approved for all major drilling areas of the world.

The FLOPRO CT system is a waterbase, solids-free intervention fluid that meets the requirements of coiled-tubing drilling with specialized features:

The system that gives operators a wider range of possibilities for difficult applications

• Promotes extended coil life

The versatility of the FLOPRO CT system has dramatically extended the range of applications for coiledtubing interventions:

• Optimizes hydraulics • Lower pump pressures and Equivalent Circulating Densities (ECD) • Reduces mechanical drag, helixing and buckling • Higher flow rates • Applicable for all coil diameters and lengths With the FLOPRO CT system at work, removing debris from the wellbore and clearing the way for the insertion of production tools has never been easier or more efficient. As an added bonus, the hole typically can be cleaned thoroughly in one trip.

60

• High-strength and tapered coil • Well depths of more than 27,000 ft (8,230 m) reached with nearly 29,000-ft (8,839-m) spools • Underbalanced environments of up to 4,500 psi (31,050 kPa) • Wellbores with bottomhole temperatures of more than 300° F (149° C) • Extended-reach wells exceeding 30,000 ft (9,144 m)

Engineered to optimize your drilling efficiency and maximize your production For flexibility, the FLOPRO CT system can be built with a wide variety of base fluids: • Freshwater

• Potassium, calcium or sodium chloride • Sodium bromide • Cesium, potassium or sodium formate Compared to conventional fluids in similar situations, the FLOPRO CT system has exhibited vastly improved sliding with reduced coil helixing and buckling. Its combination of rheology modifiers and interfacial tension and drag reducers has allowed for high flow rates at minimum pressure. FLO-VIS L premium-grade, clarified xanthan gum gives the system its elevated LSRV. This high-yielding biopolymer is also dispersible and imparts the LSRV without adversely affecting the overall gross viscosity of the system.

• Seawater

Features

Benefits

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

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

• Reduces mechanical friction and coil wear • Promotes hole cleaning and solids suspension • Minimizes pressure loss and coil wear • Minimal reservoir damage • Enables entering higherangle deeper wells not previously attainable • Simplifies cleanup

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

• Low coefficient of friction • Shear-thinning rheological profile with high LSRV • Zero or minimal solids • Inhibitive fluid • Provides drag reduction • Wide density range

Discover for yourself how the FLOPRO CT system is helping operators optimize their coiled-tubing operations. Contact your local M-I SWACO representative today.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

The FLOPRO CT system is ideal for a wide range of workover operations, including removing sand and debris from a well. The rheologically engineered system poses minimal risk of formation damage in perforated intervals, with a solids content that is routinely less than 1% by volume and elevated LowShear-Rate Viscosity (LSRV) that controls invasion.

61

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


APPLICATIONS

Deep and ultra-deepwater wells that require thermal protection for produced liquids, threaded connections and cement-bond integrity.


PROBLEMS

Subsea temperatures can cool, and change the properties of, produced fluids. Temperature cycling can loosen threaded connections and compromise the integrity of cement jobs.


SOLUTIONS

ISOTHERM* fluid and the M-I SWACO proprietary TPRO ST* computer modeling software offer maximum protection against low-temperaturerelated production problems.


ECONOMICS

In addition to preventing productionrelated and production-stringintegrity problems, the fluid can be mixed on the rig, eliminating the cost of a pumping boat.

Features • Excellent insulating properties • Solids-free formulation eliminates settling and uneven insulation • Protects well from top to bottom • Compatible with production tubulars, especially CRA materials • Can be used to prevent casing collapse

62

The ISOTHERM system is a temperature-stable, solids-free insulating system based on oilsoluble components. Oil-base insulating fluids generally outperform water-base or water-miscible fluids in many applications due to their inherently lower thermal conductivity. The absence of solids means that density will not segregate over time nor will solids settle onbottom. The absence of phase separation (“top-oil” separation) can mean the difference between convective heat loss and no convective heat loss. The thermally stable rheology produces a fluid that provides insulation from the bottom to the top of the well. The ISOTHERM system’s low thermal conductivity is a function of its oil base, versus water, brine or water-miscible solvents. For example, the ISOTHERM systems have thermal-conductivity values 80% less than water and 40% less than the “best” water-miscible solvent system (kwater = 0.35 BTU/hr/ft/°F; kwms = 0.12 BTU/hr/ft/°F; koil = 0.07 BTU/hr/ft/°F).

Because the base fluid is inherently non-corrosive, the ISOTHERM system is compatible with production tubulars, especially CRA materials. In another application, the system has been used to prevent casing collapse in subsea wells. Casing collapse and sustained casing pressure in unvented annuli have not been adequately prevented by the use of vacuum-insulating tubing. Therefore, additional measures are necessary, and insulating fluids are a critical component of these measures. M-I SWACO has developed a comprehensive, project-specific approach designed to keep wells flowing at optimum rates, even after they have been shut in for extended periods. Through our flow-assurance program, we now provide a line of high-performance, oil-base, insulating packer fluids and a proprietary computer model, TPRO ST, to remove many of the uncertainties and problems surrounding convective heat loss in the annulus.

Hot

• h = the heat transfer film coefficient • k = thermal conductivity • ν = kinematic viscosity • CP • ρ = volumetric heat capacity • β = thermal expansion coefficient

Fluid

h = 0.129

k 2/3

{

(g • β • ∆T • CP • ρ ) ν

}

1/3

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Physical Properties Needed in an Insulating Annular Fluid

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

63

SAFETHERM For maximum supplemental fluid-loss protection with easy cleanup in sand-control completions


APPLICATIONS

Deepwater and ultra-deepwater wells that require thermal protection for produced liquids, threaded connections and cement-bond integrity.


PROBLEMS

Subsea temperatures can cool, and change the properties of, produced fluids. Temperature cycling can loosen threaded connections and compromise the integrity of cement jobs.


SOLUTIONS

SAFETHERM* fluid and our proprietary TPRO ST* computer modeling software offer maximum protection against low-temperature-related production problems.


ECONOMICS

In addition to preventing productionrelated and production-stringintegrity problems, the fluid can be mixed on the rig, eliminating the cost of a pumping boat.


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

64

In the deepwater environment, initiating production, testing or shutting in for well intervention carry distinctive flow-assurance risks that could threaten your investment. The combination of cold temperature and high pressure can lead to temperature cycling in the wellbore, salt precipitation, or the formation of production-blocking hydrates, paraffin and asphaltene — any of which can seriously jeopardize your entire project. To give you the upper hand, M-I SWACO has developed a comprehensive, project-specific approach designed to keep your well flowing at optimum rates, even after it has been shut in for extended periods. Through our flow-assurance program, we now provide a line of high-performance, water-base, insulating packer fluids and a proprietary computer model to remove many of the uncertainties and problems surrounding convective heat loss in the annulus.

• Well shut-ins for short-term suspensions and intervention operations, causing thermal expansion and contraction of the tubular goods, inducing excessive stress in the metal that can disrupt casing/ cement bonding

SAFETHERM keeps the heat where it belongs Specially engineered for deepwater, permafrost and other coldtemperature environments, SAFETHERM provides thermal protection for your produced oil: • Aqueous-base or water-miscible fluid designed to minimize the conduction of heat away from the production string • Suppresses convective heat loss in the annulus • Compatible with a broad spectrum of fluids, elastomers and other components in a wide range of wells

Stop production-robbing problems where they start

• Brings production to the surface within the temperature criteria of processing equipment

SAFETHERM insulating packer fluid from M-I SWACO helps overcome temperature-related problems that can reduce, or even stop, production: • Heat transfer away from produced fluids, resulting in a product that is incompatible with the available surface processing equipment • Multiple casing strings where the transfer of heat into unvented annuli can increase temperature and pressure in the sealed space, posing a very serious risk of a casing collapse

• Remains thermally stable over a wide range of temperatures and pressures for extended periods of time • Eliminates convection for minimal stress on tubing, casing, seals and cement bonds • Reduced pressure cycling and thermal expansion means less loosening of makeup torque and threaded connections

• Base fluid resists thermal conduction, contains no suspended solids • Can be formulated for densities ranging from 8.33 to 12.5 lb/gal (1 to 1.5 kg/L) • pH-buffered and inhibited to minimize corrosion • Hydraulically optimized to yield low plastic viscosity with elevated low-shear-rate viscosities and yield stress

Features

Benefits

• Minimizes heat conduction and convective heat loss • Easily mixed and pumped on the rig • Environmentally acceptable components • Proprietary heat-transfer computer model • pH-buffered and corrosion-inhibitive • Thermally stable

• Prevents production-line blockage and casingstring collapse • Compatible with a wide range of elastomers and fluids • Production compatible with available surface processing equipment • Controls heat regression during production and shut-in • Reduces costs • Helps maximize production

• Flat rheological profile over a wide temperature range • Thermally stable over extended time periods • Can be mixed and pumped on the rig

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

• Can be pumped at high rates through small tubing and orifice valves, with minimal frictional pressure loss

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Components specially engineered to protect your production

SAFETHERM makes environmental sense too The components of the SAFETHERM system were specially selected to have minimal environmental impact, thereby mitigating the effects of spills or other unforeseen events. The packer fluid contains no free oil and produces no sheen.

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

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

65

SEAL-N-PEEL SEAL-N-PEEL is a uniquely engineered fluid-loss-control pill, designed specifically as a contingency for all sand-control completions. SEAL-N-PEEL provides superb supplemental fluid-loss control when mechanical devices either fail or are unavailable. It deposits an impenetrable filter cake against the inside surface of the screen assembly. When the well is ready to go on stream, the cake simply peels away, using production pressure and flow as the lift-off mechanisms. With the SEAL-N-PEEL pill, the carbonate particles are specially sized for each sand-control screen, and the stable rheological profile

ensures that these particles reach the screen surface intact. This promotes the immediate deposition of a thin, tough filter cake on the inside surface of the gravel-pack screen with very little matrix invasion. When it’s time to produce the well, surface-tension-reducing and releasing agents lower the adhesive forces that bind the filter cake to the screen, allowing it to be completely removed with very little differential pressure. There’s no invasion into the formation, no damage from remedial cleanup measures, no unstable rheological properties and no impediment to optimized production.

Features and Benefits • Acts as supplement to mechanical fluid-losscontrol devices • Particles sized specifically for each screen • Specially engineered additive reduces adhesive tendency • Contains minimal solids • Minimally invasive pill • Superb capacity to peel from the screen • Requires no remedial washes • Non-damaging to the formation

Workover and Completion Fluid Systems System Trade Name

Description

BREAKDOWN* BREAKFREE* BREAKLOOSE*

Enzyme-chelant-base system Enzyme-base system Oxidizer-base system

Calcium Bromide Calcium Bromide/ Calcium Chloride Calcium Chloride ISOTHERM

Single-salt inorganic brine Two-salt inorganic brine

Potassium Chloride Potassium Formate SAFE-LINK* 110 SAFE-LINK 140 SAFE-LINK 160 SAFE-PLUG* SAFE-PLUG* Z SAFETHERM* SEAL-N-PEEL*

Sodium Bromide Sodium Bromide/ Sodium Chloride Sodium Chloride Sodium Formate Zinc Bromide/Calcium Bromide Zinc Bromide/Calcium Bromide/ Calcium Chloride

66

Single-salt inorganic brine Oil-base packer fluid custom-designed and blended for specific DW and permafrost applications Single-salt inorganic brine Single-salt organic brine Completion fluid pill using 11 lb/gal (1.3 kg/L) CaCl2 Completion fluid pill using 14 lb/gal (1.7 kg/L) CaCl2 Completion fluid pill Completion fluid pill Completion fluid pill Water-base or water-miscible packer fluid custom-designed and blended for specific deepwater and permafrost applications Uniquely engineered fluid-loss-control pill, designed specifically as a contingency for all high-rate gravel-pack or water-pack completions when mechanical devices either fail or are unavailable Single-salt inorganic brine Two-salt inorganic brine Single-salt inorganic brine Single-salt organic brine Two-salt inorganic brine Three-salt inorganic brine

Density Range lb/gal kg/L

8.3 – 12 1 – 1.4 8.3 – 12 1 – 1.4 No density range available 8.4 – 15.1 1 – 1.8 11.7 – 15.1 1.4 – 1.8 8.4 – 11.6

1 – 1.4

7.5 8.4 – 19.7 8.4 – 13 8.4 – 11 8.4 – 14 8.4 – 16 8.3 – 15.1 15.1 – 19.2 9 – 12

0.9 1 – 2.4 1 – 1.6 1 – 1.3 1 – 1.7 1 – 1.9 1 – 1.8 1.8 – 2.3 1.1 – 1.4

8.4 – 17.5

1 – 2.1

8.4 – 12.5 10 – 12.7

1 – 1.5 1.2 – 1.5

8.4 – 10 8.4 – 11 14.2 – 19.2 15.2 – 19.2

1 – 1.2 1 – 1.3 1.7 – 2.3 1.8 – 2.3

SAFE-LINK* fluid-loss-control product comprises a chemically modified, cross-linked cellulose polymer used primarily to control loss of clear brine fluid to the formation during completion or workover operations. It controls fluid loss by applying a very viscous material across the formation face, virtually stopping the flow of brine into the formation. SAFE-LINK additive functions through a cross-linked polymer network that is held in place on the formation face. The effectiveness of this product is not dependent on bridging solids or on viscous drag within the formation matrix.

Applications SAFE-LINK additive is designed to work in non-zinc, halide brines such as CaCl2, CaBr2, NaCl, seawater, NaBr, and KCl, ranging from 8.6 to 15.1 lb/gal (1 to 1.8 kg/L) to control wholesale loss of brine to the formation. Generally, SAFE-LINK fluidloss-control additive is stable to 250° F (121° C) for at least 48 hrs of exposure. Due to the SAFE-LINK additive’s cross-linking mechanism, differential pressure greater than 2,000 psi (137.9 bar) is not advisable. Based on recommended treatment levels and recommended use, the fluid loss to moderately permeable formations (100 to 1,000 mD) can be reduced to <2 bbl/day per 30-ft (9.1-m) interval.

Features and Benefits • Premixed liquid • No special mixing equipment requirements • Good to 250° F (121° C) • Can be used at differential pressures up to 2,000 psi (137.9 bar) • Clean up with dilute acid

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

SAFE-LINK

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

67

FILTER FLOC FILTER FLOC* polymer is a suspension designed to flocculate residual displacement solids in a manner that facilitates removal from a brinebase completion fluid. By flocculating the residual displacement

SAFE-BREAK CBF SAFE-BREAK CBF emulsion preventer is a specialty solvent/surfactant blend that acts to prevent the formation of a stable emulsion between clear-brine completion fluids and reservoir crude oil.

SAFE-LUBE SAFE-LUBE* additive is a patentpending, water-soluble brine lubricant. The chemistry demonstrates an exceptional reduction in metalto-metal friction when added to

SAFE-T-PICKLE SAFE-T-PICKLE* additive is a highly effective, non-aromatic, highflashpoint pipe-dope solvent that contains no recognized carcinogens. It is effective in cleaning commonly

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solids, the contaminant can be easily transported to the surface and removed through the brine filtration process. For completion fluid applications, FILTER FLOC polymer is applied as a spacer in the displacement train. FILTER FLOC additive is intended for

use in freshwater, seawater, monovalent, and calcium brine fluids. FILTER FLOC additive can also be utilized in the reclamation of completion fluid brines. For reclamation applications, optimum FILTER FLOC polymer additions are determined through pilot testing.

SAFE-BREAK CBF preventer is formulated to penetrate the formation with minimal adsorption and to provide oil/brine separation at the leading edge of invading fluid. It is soluble in all non-zinc-bromide or non-formate-base completion fluids. It will not “gunk out” of

solution at typical bottomhole temperatures. This combination of properties makes SAFE-BREAK CBF effective at the lowest possible concentration and maximizes the possibility for full reclamation of the completion fluid.

brine-base completion fluids at extremely low concentrations. SAFE-LUBE lubricant is designed to reduce the coefficient of friction in seawater, sodium chloride, sodium bromide, calcium chloride and calcium bromide completion fluids.

Torque and drag in completion fluids in high-angle, extended-reach wells has become a major concern to completion operations. SAFE-LUBE lubricant has reduced torque and drag up to 50% at extremely low concentrations in field applications.

used copper- and zinc-base compounds. A fast-acting solvent that requires minimum contact time, SAFE-T-PICKLE solvent is effective over a wide temperature range and is ideal for deepwater applications. It removes excess pipe dope that

is used to lubricate pipe threads during tripping operations. Removal efficiency is a function of flow rate and contact time. A minimum of five minutes’ contact at a flow rate of 120 ft/min (36.6 m/min) is recommended.

Product Trade Name Ammonium Chloride (dry) Calcium Bromide (dry) Calcium Bromide (liquid) Calcium Chloride (dry) Calcium Chloride (liquid) DUO-VIS * FILTER FLOC*

SAFE-LUBE* SAFE-PEEL* SAFE-SCAV * CA SAFE-SCAV * HS SAFE-SCAV * NA SAFE-SCAVITE * SAFE-SOLV * E SAFE-SOLV * OM SAFE-SURF * E SAFE-SURF * O

Xanthan gum Blend of surfactants and solvents designed to suspend OBM, pipe dope and mineral-scale solids and transport them from the well Starch derivative Clarified xanthan gum in a liquid medium Premium-grade, clarified xanthan gum Shale stabilizer and inhibitor Shale inhibitor Dry, crystalline inorganic salt for mixing clear brines (8.4 – 9.7 lb/gal [1 – 1.2 kg/L]) Dry, crystalline organic salt for mixing clear brines (8.4 – 13.3 lb/gal [1 – 1.6 kg/L]) Non-emulsifier Non-emulsifier for non-zinc-base clear brine Breaker for brine viscosifiers Breaker for brine viscosifiers Non-emulsifier for zinc-base clear brine Sized ground marble Biocide – Not available in the U.S.A. Corrosion inhibitor for clear brines Brine corrosion inhibitor Concentrated corrosion inhibitor for clear brines Corrosion inhibitor for clear brines High-temperature corrosion inhibitor for clear brines Amine-base corrosion inhibitor Defoamer for clear brines Blend of surfactants, flocculants and solvents designed to flocculate and suspend iron solids Water-soluble brine lubricant Filter-cake releasing agent Oxygen scavenger for calcium-base clear brines Hydrogen sulfide scavenger for clear brines Oxygen scavenger for monovalent clear brines Scale inhibitor for clear brine Pipe-dope pickle solvent Dispersible solvent for O/SBM Nonionic wellbore cleaning agent for oil- and water-base fluids Displacement surfactant/detergent chemical for oil/synthetic-base fluids Displacement surfactant/detergent chemical for water-base fluids Displacement surfactant/detergent chemical for water-base fluids Displacement wash chemical for water-base fluids Pipe dope removal Hydroxyethylcellulose (HEC) powder Liquid HEC viscosifier for clear brines Liquid HEC viscosifier for high-density clear brines Liquid viscosifier in a highly purified mineral oil carrier Specially formulated liquid HEC 12.5-lb/gal (1.5-kg/L) brine Dry, crystalline inorganic salt for mixing clear brines (8.4 – 10 lb/gal [1 – 1.2 kg/L]) Dry, crystalline organic salt for mixing clear brines (8.4 – 11 lb/gal [1 – 1.3 kg/L]) 19.2-lb/gal (2.3-kg/L) clear brine

Secondary Function —

Brine density adjustment Brine density adjustment Brine density adjustment Brine density adjustment Viscosifier Flocculant

— Shale control Shale control Shale control — Filtration

Filtration Viscosifier Viscosifier Shale control Shale control Shale control

Viscosifier Viscosifier Fluid-loss control — — Brine preparation

Brine density adjustment Polymer breaker Non-emulsifier Polymer breaker Polymer breaker Non-emulsifier Fluid-loss control Biocide Corrosion inhibitor Corrosion inhibitor Corrosion inhibitor Corrosion inhibitor Corrosion inhibitor Corrosion inhibitor Foam control Flocculant

— — — — — — — — — — — — — — — Filtration

Lubricant Fluid-loss control Corrosion control Corrosion control Corrosion control Scale inhibitor Surfactant Solvent Surfactant Surfactant/detergent

— — — — — — — — — —

Surfactant/detergent Surfactant/detergent Surfactant

— — —

Solvent Viscosifier Viscosifier Viscosifier Viscosifier Viscosifier Brine density adjustment Brine density adjustment Brine density adjustment Brine density adjustment

— Fluid-loss control Fluid-loss control Fluid-loss control Fluid-loss control Fluid-loss control — — — —

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

SAFE-SURF * W SAFE-SURF * WE SAFE-SURF * WN SAFE-T-PICKLE* SAFE-VIS * SAFE-VIS * E SAFE-VIS * HDE SAFE-VIS * LE SAFE-VIS * OGS Sodium Bromide (liquid) Sodium Chloride (dry) Sodium Formate (dry) Zinc Bromide/ Calcium Bromide

Dry, crystalline inorganic salt for mixing clear brines (8.4 – 11.8 lb/gal [1 – 1.4 kg/L]) 11.6 lb/gal (1.4 kg/L) clear brine

Primary Function Shale control

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

FLO-TROL* FLO-VIS * L FLO-VIS * PLUS KLA-GARD * KLA-STOP* Potassium Chloride (dry) Potassium Formate (dry) SAFE-BREAK* 611 SAFE-BREAK* CBF SAFE-BREAK* L SAFE-BREAK* S SAFE-BREAK* ZINC SAFE-CARB * SAFE-CIDE* SAFE-COR * SAFE-COR * 220X SAFE-COR * C SAFE-COR * E SAFE-COR * HT SAFE-COR * Z PLUS SAFE-DFOAM * SAFE-FLOC * I

Description Dry, crystalline inorganic salt for mixing clear brines (typically at 3 – 6 wt %) Dry, crystalline inorganic salt for mixing clear brines (8.4 – 15.3 lb/gal [1 – 1.8 kg/L]) 14.2 lb/gal (1.7 kg/L) clear brine

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Workover and Completion Fluid Products

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OPTIBRIDGE Versatile software that takes the guesswork out of designing non-damaging reservoir fluids Any fluid entering your reservoir affects production. Whether it’s a kill pill, a reservoir drill-in fluid or one designed for lost circulation or perforation sealing, it must be formulated precisely to block invasion and, ultimately, prevent formation damage. The first step in designing a non-damaging fluid is to determine the ideal particle-size distribution for the bridging material. Our proprietary OPTIBRIDGE* software gives the M-I SWACO engineer a tool for precisely and quickly selecting correctly sized bridging agents. With the OPTIBRIDGE program, the M-I SWACO engineer inputs formation data as well as information about locally available products. Then the software calculates the “best-fit” mixture of locally produced bridging particles for effectively sealing the formation face. The OPTIBRIDGE tool is another example of our commitment to ensure the integrity and long-time productivity of your reservoir.

OPTIBRIDGE software makes sure no void is left unsealed The OPTIBRIDGE program improves on the popular Ideal Packing Theory, which takes a graphical approach to determine the optimum sizing of bridging material for specific formation characteristics. Basically, this theory examines all the voids in a given formation and considers the full range of particlesize distribution that will be required to fill them effectively. OPTIBRIDGE software takes that theory a major step further. It generates a mathematical model based on the largest pore size, also known as the D∑ rule.

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Using the software, the M-I SWACO engineer examines data from the targeted formation, including maximum pore-size opening, permeability and/or screen sizes, and combines that input with the bridging-particle information. From that model, the OPTIBRIDGE program automatically generates a target line of the optimum blend of particles that will effectively minimize solids and filtrate invasion. Once the optimum blend is known, the ratio of bridging materials can be perfectly matched to the formation characteristics. Because the OPTIBRIDGE program considers characteristics of your specific formation and matches them with bridging particles available in your area, there is no concern about having to wait or bear the burden of extraordinary delivery costs. What’s more, this powerful software package ensures the desired solids are maintained in the fluid system, allowing you to maximize your solids-control program while still maintaining the precise particle-size distribution of the bridging agent.

OPTIBRIDGE software: One more weapon in the battle against reservoir damage The OPTIBRIDGE program clearly illustrates the ingenuity and lengths that M-I SWACO will undertake to develop systems and tools to minimize formation damage and maximize your production. To find out more about how the OPTIBRIDGE program is performing for our customers worldwide, contact your local M-I SWACO representative.

OPTIBRIDGE software generates a target line that defines the ideal blend of locally produced bridging materials that would best fit the targeted formation characteristics. Available anywhere in the world, the OPTIBRIDGE service is an ideal tool for formulating a non-damaging reservoir drill-in fluid. It also can be used to design fracture-sealing and lost-circulation treatments, and to formulate kill and perforation-sealing pills for workover and completion operations.

Features • Accurately matches local bridging agents with formation characteristics • Applicable for reservoir drill-in fluids, lost-circulation treatments, kill pills, fracture sealing and perforation sealing • Prevents fluid invasion • Uses actual formation and bridging-agent information that will provide an optimum filter cake

Benefits • Reduces formation damage • Takes the guesswork out of selecting bridging material • Lowers material costs • Optimizes production

VIRTUAL RDF* (Reservoir Drill-In Fluids) software package is available to M-I SWACO operational personnel. VIRTUAL RDF consists of a suite of programs used in the selection, design, and optimization of reservoir drilling fluids. The suite includes OPTIBRIDGE, FINV*, RDFX*, BREAKER ADVISOR* and RDF FORMULATOR*. In addition the standard M-I SWACO reference modules, CONV and Tables are included. • OPTIBRIDGE optimizes bridging particle-size distribution based on reservoir characteristics such as pore size (preferred) or permeability. • FINV indicates potential filtrate invasion depth based on exposure time and filtration properties. • RDFx is a reservoir drillingfluid selector program that assists the project engineer in choosing an appropriate RDF for a specific project. • RDF FORMULATOR is a reservoir drilling-fluid formulation program. It is capable of formulating water and invertemulsion based reservoir drilling fluids and can formulate all M-I SWACO RDF systems.

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

• BREAKER ADVISOR is a program to assist the completion/project engineer in selecting an appropriate breaker for a given project. The program uses reservoir, drilling, completion and production information to assist it the selection process.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

PRODUCTION SCREEN TESTER (PST). The correct design and maintenance of a reservoir drill-in fluid is critical where open-hole completions are planned. The particle-size distribution of solids in the open hole must be carefully chosen, primarily to bridge across the exposed formation, but it may also permit flowback through the openings in the completion assembly. Initial fluid design and testing must be done in the laboratory, but once drilling has started in the reservoir, any flowback testing on field samples normally requires urgent shipping to shore, resulting in delays of days between sampling and test results. M-I SWACO has designed the PRODUCTION SCREEN TESTER to perform onsite testing of fluid flowback at the rigsite. The unit allows field fluid to be tested in realtime on samples of identical completion screen. This test also assists in determining the optimum cleanup chemistry such as the M-I SWACO BREAKFREE or BREAKOVER treatments.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

VIRTUAL RDF

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PRESSPRO RT Real-time engineering answers for technically challenging wells with narrow operating windows


APPLICATIONS

Deepwater, high-temperature, extended-reach wells and wells with very narrow pressure windows.


PROBLEMS

Drilling-fluid properties must be monitored and adjusted constantly to handle rapidly changing wellbore conditions and to avoid losing expensive, premium fluids that could violate environmental regulations and damage producing formations.


SOLUTIONS

The proprietary programs of the PRESSPRO* RT package use surface measurements to calculate realtime downhole pressure and corresponding fluid properties during drilling and tripping so problems can be managed as they arise. Onshore drilling centers (OCs) provide reliable control from remote sites.


ECONOMICS

The PRESSPRO RT service can mitigate and even eliminate drilling problems that can jeopardize the efficiency and economics of highcost drilling programs. Onshore centers maximize efficiency by optimizing workflow and reducing the number of personnel required at the drillsite.

The PRESSPRO RT service from M-I SWACO provides unprecedented wellsite engineering support with a unique, specifically designed suite of software. Proprietary programs use surface measurements to calculate real-time downhole pressure and corresponding fluid properties during drilling and tripping. This unique technology not only provides up-to-the-second Equivalent Static Densities (ESDs) and Equivalent Circulating Densities (ECDs) at any point in the wellbore during drilling, but also delivers surge and swab pressure measurements, Equivalent Dynamic Density (EDD) while tripping drill pipe or setting casing. A manned computer system for ECD management calculates downhole hydraulics using surfacemeasured drilling and tripping data. And the real-time VIRTUAL HYDRAULICS* package leverages the proven technology, updating and displaying current data via the VIRTUAL HYDRAULICS SNAPSHOT* graph.

VIRTUAL HYDRAULICS provides a “snapshot.” PRESSPRO RT gives you the “movie.” Now, the industry has access to an immediate processing technology that expands on the field-proven M-I SWACO VIRTUAL HYDRAULICS and VIRTUAL RHEOLOGY* platforms to consistently and accurately calculate ECDs and pump pressure as they occur. You get the information you need to mitigate, and even eliminate, critical drilling problems and events that can jeopardize the efficiency and economics of highcost drilling programs. Because the system works in real time, you can make changes on the fly and impact operations that are ongoing.

MWD/LWD provider

Data-source company system


ENVIRONMENTAL

By allowing greater control of ECD and allowing surge/swab pressures to be monitored during tripping, the PRESSPRO RT service safeguards the environment and the fragile permeability of producing formations. Onshore centers contribute to environmental safety by removing personnel from the work site and placing them in an offsite facility.

The virtual sensor package provides ESD, ECD, and other key values for display at the driller’s station as if they were measured values. Using the PRESSPRO RT package is like running the VIRTUAL HYDRAULICS package in real time.

Real-time downhole data

PRESSPRO RT calculated variables send back to data source

Real-time data — measured and calculated

Measured real-time surface data from data source

M-I SWACO PRESSPRO RT system

Remote computer Rig-floor display

Office computer connected to PRESSPRO RT computer — using Reachout with TCP/IP

The PRESSPRO RT package includes a computer that connects to the data-source company’s computer to receive and send data. The real-time data, in turn, is either sent back to the data-acquisition company or to another third party responsible for the rig-floor display.

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Offsite centers cut cost, not service

Specially designed PRESSPRO RT modules provide valuable information about all the properties of the fluids in the wellbore. • DRILLPRO* RT targets critical parameters that must be consider when drilling a well. For the very first time, ECD values are calculated and displayed every second

• SNAPSHOT* RT provides a continuous graphical display of downhole profiles • VISUAL HYDRAULICS* provides a visual representation of downhole metrics using an easy-tounderstand color scale.

PRESSPRO RT and PWD: a perfect match The PRESSPRO RT package is an integral part of ECD management. It does not replace the popular Pressure While Drilling (PWD) tool. Instead, it complements PWD data, comparing the “what are” measurements of PWD with a “what should be” scenario for early detection of impending problems. While PWD provides a single-point profile at the bit, the PRESSPRO RT package calculates complete profiles of downhole hydraulics and mud behavior, substituting PWD when the data is not available, a situation that occurs when running casing or when PWD tools break or cannot be used because of high-temperature/ high-pressure conditions.

PRESSPRO RT and VIRTUAL HYDRAULICS packages are a winning combination Now a vital element in many operators’ onshore real-time drilling centers, the PRESSPRO RT package is the only technology that provides intime equivalent static and equivalent circulating densities at any point in the wellbore during drilling. VIRTUAL HYDRAULICS software, long an integral component of the M-I SWACO PRESSPRO RT wellsite engineering service, uses surface

Features • Managed by a specially trained, onsite, criticalwell analyst • Can be operated from remote Operation Centers • Monitors drilling and tripping parameters • A dedicated computer can be interfaced to an existing data acquisition system with the data-acquisition source on the rig • Pre-defined screens for targeted drilling/tripping components • Downhole profiles calculated and updated every second and displayed as virtual sensors

Benefits • Prevents/minimizes downhole fluid losses due to lost circulation • Early detection of impending problems by providing “what should be” data to compare with “what is” • Minimizes mud-related non-productive time • Helps reduce drilling costs • Provides real-time monitoring for immediate response • Complements PWD when available and substitutes for PWD when the data is not available

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

If it impacts drilling or tripping, the PRESSPRO RT service has you covered

• TRIPPRO* RT calculates and displays real-time fluid parameters while tripping drill pipe and running casing — situations where wellbore conditions can change very quickly

measurements to calculate downhole pressure and corresponding fluid properties during drilling and tripping. The PRESSPRO RT service perfectly complements the PWD by filling in the gaps in that technology and substituting for PWD when data is unavailable. The PRESSPRO RT system is one more example of why M-I SWACO is the industry leader when it comes to developing solutions to the most demanding applications.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

The PRESSPRO RT system can also be monitored from an offsite center. Real-time OCs can perform certain critical and routine functions traditionally performed at the wellsite and all input from experts who have a “virtual presence” at multiple wellsites. OCs can provide reliable, inexpensive transmission of drilling data to and from remote sites with minimal delay. Simulation computers can be installed in the OC to facilitate efficient deployment and provide instant, remote access to real-time drilling and other operational data. Results can be compared immediately to WD and can be merged seamlessly with the real-time data stream simultaneously accessible by the OC and at the rigsite.

while both drilling and making connections.

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

And the PRESSPRO RT system is a real wellsite service. The PRESSPRO RT system and dedicated computer aboard the rig are maintained by an M-I SWACO critical-well analyst, an experienced fluids engineer specially trained in all aspects of drilling the most demanding deepwater, HTHP, extended-reach, and multilateral wells. If additional assistance is necessary, the M-I SWACO analyst is connected to additional support personnel outside the immediate drilling area.

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VIRTUAL CF Powerful software for designing and optimizing wellbore displacements When displacing drilling fluid with a completion or reservoir drill-in fluid, neglecting critical variables can lead to a world of headaches down the road. Excessive rig time. Damaged reservoirs. Added cleanup and filtration costs. Lower production. Our proprietary VIRTUAL CF* software package considers all the parameters, taking the uncertainty out of wellbore displacements. This sophisticated, integrated suite of computer programs targets the hydraulics modeling and displacement profiles of high-density brines and other completion fluids to enhance wellbore cleanup and ultimately the productivity of your well.

Engineered Displacement*

Armed with this powerful software package, the M-I SWACO engineer can, with an unequaled degree of accuracy: • Minimize rig time for displacements by calculating all critical variables in the wellbore, including spacer volume, rheologies, fluid regime, velocity, contact time, pump strokes, pump pressure and differential pressures • Design a displacement that meets equipment limitations by inputting exact wellbore geometry, including angle, and calculating such parameters as hydraulic horsepower, pill volume, flow rate, choke pressures and back pressures — all based on actual wellbore geometry

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• Ensure safety and well control by providing back-pressure schedules for those cases where differential or bottomhole pressures must be maintained • Provide flexible operating parameters for critical wells by simulating displacement in either direction, tracking all fluids in the displacement as a function of volume or pump strokes, and displaying position, pressure, rate and other data at any point in the wellbore • Optimize completion fluid economics by predicting equivalent static and local brine density at any point in the wellbore, accounting for varying temperatures from surface to bottom, which is especially beneficial in the cold, deepwater environments

VIRTUAL HYDRAULICS Version 3.0 gives you an even clearer view of your fluids’ behavior downhole

• The VH RHECON provides dynamic reconnaissance simulations to

• The OPTIPRO* bit hydraulics optimization package in which rheological properties are results of the optimization process • Improved models and parametric analyses for hole cleaning, ECD management, 3-D velocity profiles, downhole temperatures, and pressures and more • New graphics to address key hydraulics-related issues

downhole fluid properties, and includes a host of liner surgereduction tools • The VIRTUAL HYDRAULICS PLAN*, or VH PLAN*, performs hydraulic optimizations based on surface equipment limits and downhole ECD and hole-cleaning requirements • OPTIPRO, or OPTIMUM PROFILES, optimizes fluid rheology and hydraulics based on surface equipment limits and downhole ECD and hole-cleaning requirements

• A totally redesigned, state-of-theart software system

• The TPRO* TEMPERATURE PROFILES generates downhole transienttemperature profiles during circulation or shut-in

The wide range of modules in VIRTUAL HYDRAULICS 3.0 covers all the issues in hydraulics modeling

• DENSITY PROFILES, or DPRO*, provides downhole ESD calculations based on PVT characteristics of base-fluid and drilling-fluid composition

With VIRTUAL HYDRAULICS 3.0, we kept some of the classics that you had come to depend on, but have added a host of newly engineered modules that considers every aspect of hydraulics analysis. Complementing our new VIRTUAL HYDRAULICS NAVIGATOR, that allows our engineers to get up close and personal with your wellbore, we have added or enhanced a wide range of modules designed to consider every downhole condition.

• VOLPRO*, or VOLUME PROFILES calculates changes in fluid volume and trapped pressure in annuli, based on temperature and pressure changes in HTHP and LT environments

• VIRTUAL ROTARY DRILLING HYDRAULICS*, or VRDH, uses downhole ECD and pressure-loss calculations to generate a veritable “SnapShot” of downhole profiles • VIRTUAL HYDRAULICS RHECON provides reconnaissance simulations (pseudo real-time analysis) of transient drilling, tripping and circulation, and effect on ECDs and hole-cleaning • The widely used TRIPPRO*, or TRIPPING PROFILES* module provides optimum running speed based on transient surge and swab models combined with variable

• LEAK-OFF* test module generates volume requirements and leakoff pressure and equivalent density calculations accounting for temperature- and pressuredependent fluid density • GEOM* (WELL GEOMETRY) module considers standard and complex well geometries, including bypass subs, subsea BOPs, pilot holes and coil-tubing, among others • DIRPRO* (DIRECTIONAL PROFILES) generates both 2-D and 3-D directional profiles As its predecessor did in the past, the new-generation VIRTUAL HYDRAULICS 3.0 promises to deliver more information rather than mere data — information you can use to make educated decisions about how to safely, efficiently and costeffectively drill your well.

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

• The innovative VIRTUAL HYDRAULICS NAVIGATOR* 3-D visualization system was developed by M-I SWACO to create a virtual window into downhole hydraulics and related issues. The concept is the ideal combination of advanced drilling technology and 3-D computer graphics. The VH NAVIGATOR module makes it possible to navigate interactively through a virtual well and critically examine and analyze downhole hydraulics calculated by VRDH (snapshot case) and VH RHECON* (transient case) on a standard-issue laptop or PC using a gamepad or keyboard. Invaluable as an analysis tool, the VIRTUAL HYDRAULICS NAVIGATOR module is also a great training tool for office-based and field personnel, as well as non-drillers.

optimize hydraulics ahead of the bit, using predefined drilling parameters

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

The true value of the VIRTUAL HYDRAULICS software suite is truly appreciated in deepwater wells where uncontrolled Equivalent Circulating Densities (ECDs) can quickly exceed the boundaries of narrow operating windows, in extended-reach and horizontal wells, in HTHP applications and other technically demanding wells. Proven on thousands of projects, both critical and more routine applications, this powerful computational tool literally gives M-I SWACO engineers a virtual snapshot of downhole fluid behavior — before drilling begins and while the well is in progress. This accurate prediction of downhole hydraulics has a proven, positive effect on overall well performance. Now, M-I SWACO has raised the bar to an entirely new level with the release of VIRTUAL HYDRAULICS Version 3.0. Now you have everything you have come to rely on from this unparalleled hydraulics monitoring package, and much more:

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

VIRTUAL HYDRAULICS NAVIGATOR

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Barite Sag Sag is defined as a significant variation in mud density, both higher and lower than the nominal mud weight, while circulating bottoms-up after a trip or a logging/casing run. This phenomenon occurs in deviated wells and is most severe in extended-reach wells. Sag can lead to a multitude of well-related problems among which are lost circulation, loss of well control, stuck pipe and poor cement jobs.

Fundamentals • Occurs on directional wells with weighted muds • Primarily a dynamic settling problem • Severity is usually dependent on the length of the static period (trip, logging/casing run) • Can lead to a variety of drilling/completion problems

Boycott settling mechanism

Sag-related problems • Lost circulation • Stuck pipe • Poor cement jobs • Loss of well control • Loss of well

Light Fluid Suspension Zone Sag Bed Slump Static

Dynamic

Wells with high risk

Barite sag is the result of dynamic settling, static settling, and slumping. Local settling at top and low-side of hole during low-rate circulation and static periods create a pressure imbalance which forces lighter mud upwards and accelerates barite settling (Boycott effect). Most difficult well conditions occur when barite beds “slump” towards the bottom of the hole, causing density variation.

• High-angle and ERD wells • Any wells with angle >30° and MW >12 lb/gal (1.44 kg/L) at risk • ERD wells are most critical — long deviated section • HTHP wells — mud thinning and product degradation

Low-Shear Conditions

Mass of Weighting Particles

• Running casing — creates lowshear annular flow; can be aggravated by excessive thinning • Tripping/Logging — drillstring/ logging tools can break gels and generate low-shear flow • Pumping slowly • ECD restrictions • Well-control situations • Fracture breathing (ballooning) — mud returning from fractures creates low-shear flow • Boat ride — rocking motion can break gel structure and promote settling, if not agitated

• Finer and lighter particles will sag less • Adverse effects: higher PV resulting in higher ECD

• Well and casing design — may promote sag in low annular velocity sections • Hydraulics design — optimize pump rate (minimum ECD with least sag), annular geometry

Sag indicators • Light mud followed by heavy mud when circulating bottoms-up • Abnormal standpipe pressures — U-tube effect due to heavy mud in annulus • High ECDs, mud losses — BHA rotation in a slug with slumping barite • High torque and drag — pipe/barite bed contact • Unexpected kicks due to the light mud column

Factors influencing sag

Drillstring Rotation • Rotation moves sag beds into flow stream • Sliding increases beds buildup

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Time • Sag severity increases with static or low-shear time • Time for running casing/ logging should account for sag minimization

Well Design • Hole angle — wells >30° with MW >12 lb/gal (1.44 kg/L) are prone to sag; <75° may experience slumping • Pressure and temperature — temperature may induce mud thinning and degradation

Mud Formulation and Properties • Low-shear rheology — controls dynamic sag • Gel strengths — mainly control static settling • Emulsifier and wetting agent — type and concentration • Low-gravity solids — type and concentration • Base-oil selection — affects sag tendency in OBM/SBM • Oil viscosity • Interaction with viscosifiers and surfactants

While there’s no such thing as easy deepwater projects, there’s one way to make them less challenging — call M-I SWACO. We’ve helped operators drill more than 50% of the world’s deepwater and ultra-deepwater wells, and we’ve learned lessons that only experience can teach.

Challenges and solutions

Gas hydrates deepwater challenges are best overcome through: • Understanding the technical limits of equipment and materials • A full range of products and systems, engineering software, and technical services • Insistence on the use of the best available technology and practices • A strong commitment to, and insistence upon, a complete management system for dealing with the quality, health, safety and environmental aspects of deepwater drilling

Cold-water temperatures Managing the drilling-fluid system to ensure proper fluid behavior at downhole and riser temperatures can pose a difficult challenge in deepwater drilling. Rigsite rheology testing should be

performed at low temperatures, using a chiller as well as the standard API test temperatures. The data should be incorporated into VIRTUAL HYDRAULICS modeling.

2 4 6 8

Drillstring

10 12

Annulus

14 16

Formation

18 20 25

50 VIRTUAL HYDRAULICS

75 100 Temperature (°F)

125

150

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

Measured Depth (1,000 ft)

0

Gas hydrates are ice-like crystals that form when free water, hydrocarbon gas, cold temperatures and high pressure are present, i.e., under the conditions encountered in deepwater drilling. Hydrate plugs can form and prevent circulation of the drilling fluid. Hydrate remediation is a costly and dangerous process, so every possible precaution should be taken to prevent hydrates from forming in the first place. M-I SWACO recommends these best practices at the minimum: • Target full thermodynamic inhibition • Primary inhibitor — NaCl • Secondary inhibitor — glycol • Utilize WHyP and SWIFT for modeling • The M-I SWACO testing facilities in Houston and Stavanger can run hydrateinhibition tests on specific fluids • Contingency for glycol/ brine in BOP and chokeand-kill lines • Consider using invertemulsion systems as soon as the riser is attached • Kinetic hydrate inhibitor — EMI-571*

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Two of the major challenges in deepwater are the difficulty and expense involved. Narrow operating windows, shallow hazards, cold temperatures, wellcontrol problems, logistics and supply difficulties contribute to the challenge of operating in deepwater. The expenses come in the form of remote locations; expensive rigs; large volumes of consumables, including drilling, reservoir drill-in and completion fluids; and the necessity of using premium fluids. Experience has taught M-I SWACO a lot about the behavior of fluids in the deepwater environment. Solutions to

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Deepwater

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Lost Circulation Perhaps no downhole problem has a more profound and widespread economic impact on drilling operations than lost circulation. In fact, it has been reported that the complications associated with lost returns cost the industry hundreds of millions of dollars a year.

Definition

Problems

Lost circulation or lost returns are the partial or total loss of whole drilling fluid to subsurface formations. Lost circulation occurs when the openings in the formation allow the passage of whole fluid into the formation, resulting in losses ranging from 1 bbl/hr to complete loss of returns.

Economics is the biggest problem associated with lost returns. When circulation is lost, the drilling-fluid costs rise appreciably, along with the expenses associated with rig and equipment delays.

Causes and potential lost-circulation zones

Designing and managing bridging agents — Particle-Size Distribution (PSD)

Lost circulation occurs by one of the two following mechanisms. • Natural losses — invasion occurs in, or whole fluid is lost to, formations that are highly permeable, unconsolidated, fractured, cavernous or vugular • Induced losses — the fluid is lost due to excessive induced pressure hydraulically fracturing the formation

• Ideal Packing Theory (IPT) can be defined as the full range of particle-size distribution required to effectively seal all voids including those created by bridging agents. A good rule of thumb is having D90 equal to the opening sizes of the fractures. • M-I SWACO proprietary software for PSD optimization is called OPTIBRIDGE. The program enables the user to determine the optimum blend of bridging materials by inputting either maximum pore size or, if available, permeability.

Locating the thief zone Losses 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 a balled-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 in torque and the kelly free falls while drilling, coupled with an instant loss in circulation. Losses are normally “off-bottom” if: • They first occur while tripping, drilling quickly or increasing 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 return apparent mud weight higher than last casing shoe fracture gradient Smaller particles fill any remaining gaps

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Large blocking particles providing initial bridging

Wellbore stability is a complex balance of mechanical (pressure and stress) and chemical factors. The chemical composition and mud properties must combine to provide a stable wellbore until casing can be run and cemented.

largely to mechanical actions, with erosion most often being caused by hydraulic forces and excessive bit nozzle velocities. Hole enlargement through sand sections may be reduced significantly by following a more conservative hydraulics program, particularly with regard to impact force and nozzle velocity. Sands that are poorly consolidated and weak require a slight overbalance to limit wellbore enlargement and a good-quality filter cake containing bentonite to limit wellbore enlargement. In shales, if the mud weight is sufficient to balance formation stresses, wells are usually stable — at first. With water-base muds, chemical differences cause interactions between the drilling fluid and shale, and these can lead (over time) to swelling or softening. This causes other problems, such as sloughing and tight hole conditions. Highly fractured, dry, brittle shales, with high dip angles, can be extremely unstable when drilled. The failure of these dry, brittle formations is mostly mechanical and not normally related to water or chemical forces.

Various chemical inhibitors or additives can be added to help control mud/shale interactions. Systems with high levels of calcium, potassium or other chemical inhibitors are best for drilling into water-sensitive formations. Salts, polymers, asphaltic materials, glycols, oils, surfactants and other shale inhibitors can be used in water-base drilling fluids to inhibit shale swelling and prevent sloughing. Shale exhibits such a wide range of composition and sensitivity that no single additive is universally applicable. Oil- or synthetic-base drilling fluids are often used to drill the most water-sensitive shales in areas with difficult drilling conditions. These fluids provide better shale inhibition than water-base drilling fluids. Clays and shales do not hydrate or swell in the continuous phase, and additional inhibition is provided by the emulsified brine phase (usually calcium chloride) of these fluids. The emulsified brine reduces the water activity and creates osmotic forces that prevent adsorption of water by the shales.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

Regardless of the chemical composition of the fluid and other factors, the weight of the mud must be within the necessary range to balance the mechanical forces acting on the wellbore (formation pressure, wellbore stresses related to orientation and tectonics). Wellbore instability is most often identified by a sloughing formation, which causes tight hole conditions, bridges and fill on trips. This often makes it necessary to ream back to the original depth. (Keep in mind these same symptoms also indicate holecleaning problems in high-angle and difficult-to-clean wells.) Wellbore stability is greatest when the hole maintains its original size and cylindrical shape. Once the hole is eroded or enlarged in any way, it becomes weaker and more difficult to stabilize. Hole enlargement leads to a host of problems, including low annular velocity, poor hole cleaning, increased solids loading, fill, increased treating costs, poor formation evaluation, higher cementing costs and inadequate cementing. Hole enlargement through sand and sandstone formations is due

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

Wellbore Stability

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

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INTEGRATED FLUIDS ENGINEERING Reducing your drilling time, lowering your drilling costs, increasing production and meeting your environmental objectives. More than 1,600 wells have proven it.


APPLICATIONS

Any well, whether complex or relatively simple, where there is room for improvement in drilling time, production rates, environmental issues and overall costs.


PROBLEMS

Traditional bundled services often present problems of gaps, overlaps and even conflicts among the service companies. This results in lost time and money as well as increased risks to health, safety and the environment.


SOLUTIONS

The M-I SWACO IFE approach ensures that all fluids-related services and equipment work in concert with each other to shorten drilling time, increase production, meet environmental regulations and lower overall costs.


ECONOMICS

With all the well’s aspects planned far in advance, and a true integration of personnel, services and equipment, IFE will reduce overall drilling and completion costs.


ENVIRONMENTAL

During well planning, certified M-I SWACO IFE personnel coordinate all the factors that influence the environmental performance of the well, including fluids, drilling waste management methods and equipment, and post-well operations.

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What is IFE? The INTEGRATED FLUIDS ENGINEERING (IFE) approach is a totally different method of drilling and completing a well. It is a results-driven and comprehensive fluids solution which optimizes the design, delivery and management of wellsite fluids and fluids-related services. The IFE program utilizes all M-I SWACO products, equipment and technology engineered by highly trained personnel.

INTEGRATED FLUIDS ENGINEERING was created for challenges • High day rates and shrinking budgets demand that operators reach TD quickly and that producing formations yield the most oil and gas possible • The use of expensive, sophisticated equipment requires logistics and operations to be carried out seamlessly, with no gaps or overlaps • Increasingly stringent regulations are putting a bigger burden on operators to improve health and safety conditions, and either reduce the amount of drilling waste or bear the costs of dealing with it The bottom line — get the most productivity from every person, service, instrument, tool and product used in drilling and completing your wells.

The IFE approach optimizes your drilling waste management program In planning your well, M-I SWACO engineers look at the whole picture, including the generation and management of drilling waste. We will always strive to manage wastes at the highest possible (widest) level of the pyramid, and then move down the priorities as circumstances dictate.

Waste minimization: prioritized strategy

Reduce Reuse Recycle

Waste minimization

Recover Residue

Making the most of valuable information One of the tools we use in our improvement process is our proprietary software. As various situations and needs have arisen, M-I SWACO has authored fit-forpurpose computer programs to support the IFE mission. This powerful, industry-accepted software suite is another reason that only M-I SWACO can provide true INTEGRATED FLUIDS ENGINEERING solutions. Our IFE-related software includes: • ONEPLAN/ONE-TRAX* • PRESSPRO RT • OPTIBRIDGE • VIRTUAL HYDRAULICS • VIRTUAL COMPLETION FLUIDS* • WASTE MANAGEMENT ADVISOR*

Drilling and Reservoir Drill-In Fluids • Hole cleaning • Barite sag • Bit balling/accretion • ECD margins • Lost circulation • Bottomhole temperature

• Formation damage • Displacements • Wellbore cleanup • Precipitates

Mixing Technologies • Chemical/polymer consumption • Mixing pad mud for riserless drilling • Additional mixing capacity

• Asphaltenes • Solids plugging • Water block • Fines migration

• Stuck pipe • Depleted zones • Contaminants • Rate of Penetration (ROP) • Drilling salt/subsalt • Formation damage

General (all products and services)

• Hydrates • Formation evaluation

• Cost

SPEEDWELL* Tools • Risk of connection failure • Expensive downhole equipment

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

• Downtime/non-productive time • Quality, Health, Safety and Environmental (QHSE)

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

• Trips after drilling cement

• Logistics

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

• Pressure control/UBD

Completion Fluids

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

By integrating key M-I SWACO products and services, IFE gives you real value, positively affecting factors that determine your success

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SPEEDWELL Tools 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 You can trust the SPEEDWELL* product line to perform even in the harsh conditions that treacherous downhole environments can throw at an operation with no warning. We have been an integral part of fishing and milling operations, displacements, solids removal, debris retrieval, and perforation cleanup

One-piece mandrel is constructed of high-yield steel, is designed for drilling cement and has no external fasteners.

in every major drilling area of the world. M-I SWACO has established an integrated, time-saving approach to the wellbore cleanup and displacement operation. The M-I SWACO Displacement Tool Box includes our SAFE* Series cleanup and displacement chemicals, filtration, our VIRTUAL HYDRAULICS program, the

torque-reduction program and, of course, the SPEEDWELL line. This gives our customers the most integrated, comprehensive approach to dealing with the most challenging wells anywhere in the world. This is just a sample of the overall spud-to-production approach that M-I SWACO will bring to your operation.

Larger-bore mandrels allow the fluid to do its work, promoting better circulation and reverse circulation for solids removal. Non-rotating magnets can be

One tool carries everything: scrapers, brushes, magnets, gauge rings and handling features in addition to providing excellent annular bypass so solids can exit the cased hole.

Double-crimped, stainless steel brushes stand up to harsh operating conditions and do not rotate. They outperform carbon steel, straight-wire brushes that become brittle and break from chemical exposure and movement. Wear values have been established to ensure continuous brush contact throughout the run.

Centralizers rotate independently of the workstring to reduce wear on casing and liner. SPEEDWELL can eliminate the need for a gauge ring by placing a centralizer at drift on your PUP tool.

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run on the same mandrel with scraper and brush carriers, eliminating the need for additional tools on your next project.

Junk basket carriers can be placed on the PUP mandrel, just like brushes, scrapers and magnets. The baskets have an unrestricted, 360° opening at the top.

Two styles of non-rotating scraper blades: Knurled-face-style for aggressive cleaning and smooth-face-style for special requests. Wear values have been established to ensure continuous blade contact throughout the run.

SPEEDWELL modular tool design allows you to run the tool with a regular box down to eliminate a bit sub. We can also furnish bit or mill, already made up on the tool.

SOLUTIONS IFE WORKOVER AND COMPLETION FLUID SYSTEMS

DISPLACEMENT AND CLEANUP WORKOVER AND COMPLETION FLUID PRODUCTS

Perforation-debris cleanup

Cased-hole cleanup and debris removal

Riser cleaning and jetting

Liner-top testing and cleanup

FLUIDS TECHNOLOGY FLUIDS ENGINEERING FLUIDS DRILLING-FLUID SYSTEMS RESERVOIR DRILL-IN FLUID SYSTEMS DRILLING-FLUID AND RDF PRODUCTS

The flexible, SPEEDWELL approach gives you maximum effectiveness on any well

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P.O. Box 42842 Houston, Texas 77242-2842 Tel: 281·561·1300 Fax: 281·561·1441 www.miswaco.com E-mail: [email protected] This information is supplied solely for informational purposes and M-I SWACO makes no guarantees or warranties, either expressed or implied, with respect to the accuracy and use of this data. All product warranties and guarantees shall be governed by the Standard Terms of Sale. Nothing in this document is legal advice or is a substitute for competent legal advice.

©2006 M-I L.L.C. All rights reserved. *Mark of M-I L.L.C. FMC.0600.0604.R1 (E) 500 Litho in U.S.A.