MI-Swaco - Drilling_Solutions_Catalog 2008

2008 Catalog

DRILLING SOLUTIONS

D R I L L I N G

S O L U T I O N S

Table of Contents We Are M-I SWACO

............................4

S I M U L A T I O N S O F T W A R E

PRESSPRO RT. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 VIRTUAL CF. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 VIRTUAL HYDRAULICS . . . . . . . . . . . . . . . . . . . . . 11 D R I L L I N G - F L U I D S Y S T E M S A N D A D D I T I V E S

DRILPLEX . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 GLYDRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 NOVA Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 PARALAND . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18 RHELIANT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20 SAGDRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22 SILDRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 ULTRADRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 WARP Advanced Fluids Technology. . . . . . 28 DURATHERM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 ECOGREEN . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31 ENVIROTHERM. . . . . . . . . . . . . . . . . . . . . . . . . . . . 31 ENVIROVERT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 K-MAG . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 PARADRIL. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 PARATHERM/VERSATHERM . . . . . . . . . . . . . . . . 34 POLY-PLUS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35 TRUDRIL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35 VERSACLEAN/VERSADRIL . . . . . . . . . . . . . . . . . . 36 Drilling-Fluid Systems and Additives Listing. . . . . . . . . . . . . . . . . . . . 37 A L P I N E S P E C I A L T Y C H E M I C A L S

ALPINE DRILL BEADS . . . . . . . . . . . . . . . . . . . . . . 42 ALPINE DRILL BEADS RECOVERY UNIT . . . . . . 44 BLACK FURY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 46 CELL-U-SEAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48 CLEAN SPOT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50 FORM-A-SQUEEZE . . . . . . . . . . . . . . . . . . . . . . . . 52 PA-10 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54 QUICK SLIDE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56 SACK BLACK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 58 ALPINE TRACER BEADS . . . . . . . . . . . . . . . . . . . . 60 H D D M I N I N G W A T E R W E L L

A N D

N E W - T E C H N O L O G Y D R I L L I N G

DRILPLEX HDD . . . . . . . . . . . . . . . . . . . . . . . . . . . 62 DUO-VIS/SUPER-VIS . . . . . . . . . . . . . . . . . . . . . . 63 MAX BORE HDD. . . . . . . . . . . . . . . . . . . . . . . . . . 64 MAX GEL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65

POLYPAC R . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66 POLYPAC UL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 67 ROD EASE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68 PLATINUM PAC . . . . . . . . . . . . . . . . . . . . . . . . . . . 69 PLATINUM PAC UL . . . . . . . . . . . . . . . . . . . . . . . . 70 KLA-GUARD . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 71 FLO-PLEX . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72 H D D

P R O D U C T S

DRILPLEX HDD . . . . . . . . . . . . . . . . . . . . . . . . . . . 73 DUO-TEC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 74 DUO-VIS/SUPER-VIS . . . . . . . . . . . . . . . . . . . . . . 75 POLY-PLUS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76 POLY-PLUS LV . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 77 POLY-PLUS RD . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78 PLATINUM PAC . . . . . . . . . . . . . . . . . . . . . . . . . . . 80 PLATINUM PAC UL . . . . . . . . . . . . . . . . . . . . . . . . 81 PLATINUM D-D . . . . . . . . . . . . . . . . . . . . . . . . . . . 82 MAX BORE HDD. . . . . . . . . . . . . . . . . . . . . . . . . . 83 MAX GEL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 84 ROD EASE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 85 Lost-Circulation Materials (LCM) . . . . . . . . 86 M I N I N G

P R O D U C T S

MAX GEL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 87 PLATINUM PAC . . . . . . . . . . . . . . . . . . . . . . . . . . . 88 POLY-PLUS 2000 . . . . . . . . . . . . . . . . . . . . . . . . . . 89 POLY-PLUS EHV. . . . . . . . . . . . . . . . . . . . . . . . . . . 90 POLY-PLUS RD . . . . . . . . . . . . . . . . . . . . . . . . . . . . 92 POLYPAC R . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 94 POLYSWELL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 95 RINGFREE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 96 ROD EASE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97 THREAD BOND Z. . . . . . . . . . . . . . . . . . . . . . . . . . 98 TUBE LUBE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 99 W A T E R W E L L P R O D U C T S

Lost-Circulation Materials (LCM). . . . . . . 100 POLY-PLUS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101 SUPERFOAM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 102 SUPERFOAM AF . . . . . . . . . . . . . . . . . . . . . . . . . 103 SUPER PLUG . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 104 MAX GEL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 105 PLATINUM PAC . . . . . . . . . . . . . . . . . . . . . . . . . . 106 PLATINUM PAC UL. . . . . . . . . . . . . . . . . . . . . . . 107 SMOOTH GROUT 20 . . . . . . . . . . . . . . . . . . . . . 108 SMOOTH GROUT 30 . . . . . . . . . . . . . . . . . . . . . 109 GOPHER GROUT . . . . . . . . . . . . . . . . . . . . . . . . . 110 KWIK-PLUG Fine & Micro . . . . . . . . . . . . . . . 111 KWIK-PLUG Medium & Coarse. . . . . . . . . . 112

TABLE OF

XR MESH for Shale Shaker Screens . . . . . 146 DURAFLO Composite Screens . . . . . . . . . . . 147 HIFLO Replacement Screens. . . . . . . . . . . . 148 W A S T E

T R E A T M E N T

C O N T R O L

D - G A S S E R S

M U D / G A S S E P A R A T O R S

S O L I D S - C O N T R O L S Y S T E M S

MUD/GAS SEPARATOR . . . . . . . . . . . . . . . . . . . 160 SUPER MUD/GAS SEPARATOR (SMGS) . . . . 161 TOGA System . . . . . . . . . . . . . . . . . . . . . . . . . . . 162

Solids-Control Systems . . . . . . . . . . . . . . . . 131 M I X I N G

D I S C - T Y P E

S H A K E R S

Standard Chokes . . . . . . . . . . . . . . . . . . . . . . . 163 ESUPERCHOKE . . . . . . . . . . . . . . . . . . . . . . . . . . 164 S H U T T L E

C L E A N E R S

High-Volume Mud Cleaners . . . . . . . . . . . 136

P R E S S U R E & F L U I D M A N A G E M E N T S Y S T E M ( P F M S )

C E N T R I F U G E S

FLUIDS PROCESSING SYSTEM (FPS) . . . . . . . . 141

CLEANCUT Cuttings Collection. . . . . . . . . . 142 VACUUM COLLECTION SYSTEM. . . . . . . . . . . . 143 VERTI-G Cuttings Dryer. . . . . . . . . . . . . . . . . 144 VERTI-G Low-Profile Cuttings Dryer . . . . 145

I N S T R U M E N T A T I O N

SG-SMART Data-Acquisition System . . . 168

CONTENTS

C U T T I N G S T R A N S P O R T A N D H A N D L I N G

R I G

OF

F L U I D S P R O C E S S I N G S Y S T E M ( F P S )

PRESSURE & FLUID MANAGEMENT SYSTEM (PFMS) . . . . . . . . . . . . . . . . . . . . . . . . . 167

TABLE

414 CENTRIFUGE . . . . . . . . . . . . . . . . . . . . . . . . 137 518 CENTRIFUGE . . . . . . . . . . . . . . . . . . . . . . . . 138 CD-500 CENTRIFUGE . . . . . . . . . . . . . . . . . . . . 139 CD-600 CENTRIFUGE . . . . . . . . . . . . . . . . . . . . 140

C O N S O L E S

Standard Choke Consoles . . . . . . . . . . . . . . 166

CONTENTS

C H O K E M U D

C H O K E S

AUTOCHOKE . . . . . . . . . . . . . . . . . . . . . . . . . . . . 165

OF

MEERKAT PT Shale Shaker . . . . . . . . . . . . . . 133 MONGOOSE PT Linear- and Dual-Motion Shaker. . . . . . . 134 BEM-650 Shale Shaker . . . . . . . . . . . . . . . . . 135

C H O K E S

TABLE

Mud-Mixing System . . . . . . . . . . . . . . . . . . . 132

CONTENTS

C O N T R O L

OF

Horizontal D-GASSER . . . . . . . . . . . . . . . . . . 156 Vertical D-GASSER . . . . . . . . . . . . . . . . . . . . . . 157 Compact Vacuum D-GASSER . . . . . . . . . . . 158 CD-1400 Centrifugal D-GASSER . . . . . . . . . 159

TABLE

P R E S S U R E

CONTENTS

Thermal Desorption Technologies . . . . . 152 Thermal Desorption: Hammermill . . . . 153 Thermal Desorption: Rotary Kiln. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154 Thermal Desorption: FOx System Enhancement . . . . . . . . . . . . . 155

OF

C U T T I N G S

Integrated Package Delivery . . . . . . . . . . . 130

M U D

I N J E C T I O N

Waste Injection . . . . . . . . . . . . . . . . . . . . . . . . 150 WI Training Centers . . . . . . . . . . . . . . . . . . . 151

R I G - E Q U I P M E N T E N G I N E E R I N G

S O L I D S

S C R E E N S

TABLE

GEL SUPREME . . . . . . . . . . . . . . . . . . . . . . . . . . . 113 GOPHER GROUT . . . . . . . . . . . . . . . . . . . . . . . . . 114 KWIK-PLUG Fine & Micro . . . . . . . . . . . . . . . 115 KWIK-PLUG Medium & Coarse. . . . . . . . . . 116 PLATINUM PAC . . . . . . . . . . . . . . . . . . . . . . . . . . 117 PLATINUM PAC UL. . . . . . . . . . . . . . . . . . . . . . . 118 POLY-PLUS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 119 POLY-PLUS 2000 . . . . . . . . . . . . . . . . . . . . . . . . . 120 POLY-PLUS EHV . . . . . . . . . . . . . . . . . . . . . . . . . 121 SMOOTH GROUT 20 . . . . . . . . . . . . . . . . . . . . . 122 SMOOTH GROUT 30 . . . . . . . . . . . . . . . . . . . . . 123 SMOOTH GROUT THERMAL. . . . . . . . . . . . . . . 124 TACKLE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125 MAX GEL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 126 RINGFREE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 127 M-I GEL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128

O I L F I E L D

CONTENTS

N S F C E R T I F I E D P R O D U C T S

“

The M-I SWACO solutions mindset permeates our company and positively influences the problem-solving orientation we have toward our clients, the solutions we deliver, our new-technology advancement, people development within our company and our future strategies.

”

M-I SWACO has refined the concept and development of Reservoir Drill-In Fluids (RDFs) that help operators achieve the highest returns from their valuable reservoirs with specialized fluid systems that protect production zones. Our WARP* Advanced Fluids Technology and our FLOTHRU* SMART RDF* Technology systems have not only helped operators but have won industry awards for innovation

Solutions for fluids-related problems Within M-I SWACO, we have the ability to solve problems that range from simple to complex. Dedicated teams can design entire fluids-management systems, complete with equipment, instrumentation, control systems and automation software. We have made considerable investments in research and engineering facilities as well as

Solutions that make history — every day M-I SWACO* has achieved a position of leadership in several key areas within the oilfield. We have helped operators drill a majority of the world’s deepwater and ultra-deepwater wells. We’ve pioneered the development and application of both synthetic-base and high-performance water-base drilling-fluid systems for deepwater, and we have created specialized systems for putting a fluid thermal barrier in marine risers to protect produced oil from extreme cold.

4

WE ARE and performance. We’re continuing to develop high-density RDF systems, breaker technology and active filter cakes to enhance production and facilitate total reservoir management.

laboratories and field-support operations. These facilities, and the capable and talented people who operate them, give M-I SWACO a distinct competitive edge.

WE ARE – –

M-I

– –

M-I SWACO WE

– –

M-I SWACO WE ARE

– –

M-I SWACO WE

Engineering Center in Houston and our three International Technical Centers — in Houston; Aberdeen, Scotland and Stavanger, Norway — provide 24-hr assistance, and innovative solutions, anywhere in the world. Our Ecotoxicological Laboratory in Bergen, Norway, performs a wide range of analytical services. Drilling and production frontiers such as offshore Canada, Russia and the Caspian Sea, China, Latin America, and land and offshore operations throughout North America are now just a phone call or mouse click away from powerful technical support.

ARE

M-I SWACO has made considerable investments in research and engineering facilities as well as laboratories and field-support operations. Our Research and

ARE

Research and development

WE

Before people work for M-I SWACO, we screen them not only for current skills and experience, but also for their willingness to learn new things, solve problems and help others. Once they join the M-I SWACO organization, employees have the advantages of a global learningmanagement system which provides worldwide access to learning, in-house and custom e-learning solutions, talent and competency management, and performance management.

Starting with the basic building blocks of training for the job at hand, M-I SWACO instructors quickly bring new specialists up to speed in the disciplines required for them to deliver maximum value from our products and services. M-I SWACO ensures customers around the world get the highest level of service by standardizing training courses to meet the universal expectations of all operators. Where locale dictates certain specialized practices, M-I SWACO trainers prepare field personnel for those details as well. Once these capable people are working in the field, their learning and training are not over. In fact, basic training is just the beginning of a successful career with M-I SWACO. As an organization, we are developing career paths, checkpoint criteria and progressmeasurement methods to keep M-I SWACO and its people at the forefront of the industry.

SWACO

People are a valuable asset worth developing

ARE – –

M-I SWACO WE ARE

– –

M-I

M-I SWACO

SWACO

5

Customer-focused, solutions-driven

Because we have our own R&D, manufacturing, environmental and technical resources, and can deploy them to active areas, we are often the first company to create the solutions that eventually become products and services adopted throughout the industry.

QHSE Each of our business units has a Quality, Health, Safety and Environmental (QHSE) director who reports to our headquarters in Houston. Our loss-prevention teams ensure that M-I SWACO operations are in compliance with the latest safety standards. Fulltime occupational health and safety specialists make sure that

6

our locations and the customer locations and rigs where our people work are safe. The Occupational Health group provides a management framework that monitors and investigates a broad range of health hazards and initiates controls to manage those hazards through programs such as Hearing Conservation, Respiratory Protection, Ergonomics and Malaria Control. Our customers also frequently utilize our expertise to assess potential occupational health issues involving our products at their sites. M-I SWACO people operate with an awareness of the environment and a sense of responsibility

for protecting it. We operate specialized laboratories, including a greenhouse, where our environmental specialists conduct exhaustive tests for toxicity, biodegradation, recyclability, reuse and more. On a larger scale, our environmental emphasis and expertise are guiding forces behind the company’s focus on ENVIRONMENTAL SOLUTIONS*. Prime examples of this philosophy can be seen in our line of production chemicals and our Ecotoxicological Laboratory in Bergen, Norway. M-I SWACO will continue to establish itself as a leader by listening to customers and trusting our people to develop customized solutions to solve their problems.

WE ARE – –

M-I

The solutions that drive us

SWACO WE

As we have added to our capabilities and solved problems for our clients, groups of solutions naturally evolved over time. Now we have formalized this natural alignment, placing the products and services we offer within categories of solutions. This presents our offerings in a manner that is logical to our clients and our own people. Every solution we currently provide can be found in one of the four categories below.

ARE – –

M-I SWACO WE

Engineering/simulation software Reservoir drill-in fluids Fluid-loss-control systems Intervention fluids Packer fluids Breakers

Spacers and displacement chemicals Specialized tools Completion fluids Filtration Enhanced fluids treatment Vessel cleaning

SWACO WE ARE

Cuttings transport and handling Oilfield screens Waste injection Cuttings treatment Pressure control • D-Gassers • Mud/Gas Separators • Disc-type chokes • Shuttle chokes • Choke consoles • PRESSURE & FLUID MANAGEMENT SYSTEM* (PFMS) Rig instrumentation

PRODUCTIVITY

M-I

Wellsite and project engineering Simulation software Drilling-fluid systems and additives ALPINE SPECIALTY CHEMICALS* FEDERAL* Wholesale HDD Mining & Waterwell Technical support Rig-equipment engineering Solids control • Solids-control systems • Mud mixing • Shakers • Mud cleaners • Centrifuges • FLUIDS PROCESSING SYSTEM* (FPS)

WELLBORE

– –

SOLUTIONS

ARE

DRILLING

– –

M-I SWACO WE ARE

– –

M-I M-I

Pressure control • D-Gassers • Mud/Gas Separators • Disc-type chokes • Shuttle chokes • Choke consoles • PRESSURE & FLUID MANAGEMENT SYSTEM (PFMS) Rig instrumentation Enhanced fluids treatment Vessel cleaning Water treatment Production waste management

ARE

Rig-equipment engineering Solids control • Solids-control systems • Mud mixing • Shakers • Mud cleaners • Centrifuges • FLUIDS PROCESSING SYSTEM (FPS) Cuttings transport and handling Oilfield screens Waste injection Cuttings treatment

SOLUTIONS

– –

Drag reduction Water treatment Production waste management

E N V I R O N M E N TA L

WE

Oilfield/production chemicals Chemical management H2S removal

TECHNOLOGIES

SWACO

PRODUCTION

SWACO

7

S I M U L A T I O N

S O F T W A R E

PRESSPRO RT Real-time engineering answers for technically demanding, high-cost wells

ឣAPPLICATIONS

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

ឣPROBLEMS

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.

ឣSOLUTIONS

Real-time problems require the in-time solutions uniquely available from the PRESSPRO* RT system. This proprietary, fit-for-purpose, real-time software application complements PWD data and helps maximize the benefits of ECD-management processes, both at the wellsite and in remote, onshore drilling centers. Instantaneous access to downhole pressure profiles and fluid properties during drilling and tripping helps manage drilling problems before they occur or as they start.

ឣECONOMICS

The PRESSPRO RT service targets reduced non-productive time/costs by helping to eliminate drilling problems that jeopardize the efficiency and economics of high-cost drilling programs. Remote program operation helps enhance the value of onshore drilling centers by providing information rather than just data, helps maximize efficiency and optimize workflow, and moves toward the ultimate objective of reducing wellsite personnel.

ឣ

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.

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 high-cost drilling programs. Because the system works in real time, you can make changes on the fly and impact operations that are ongoing.

The PRESSPRO package

Rig-floor display

Rig

Data source

PRESSPRO RT

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

By carefully monitoring ECD while drilling, and surge/swab pressures while tripping and running casing, the PRESSPRO RT service helps reduce the risk of lost circulation and associated mud losses to the formation.

8

The PRESSPRO RT service from M-I SWACO provides unprecedented remote and wellsite engineering support with a unique, specifically designed suite of software. Proprietary programs use surface measurements to calculate downhole pressure profiles and fluid properties in real time during drilling, tripping and other critical operations. This unique technology not only provides up-to-thesecond 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. 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 specialist trained in all aspects of drilling the most demanding deepwater, HTHP, extended-reach, and multilateral wells.

MWD/LWD Onshore drilling center

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.

Offsite centers cut cost, not service

If it impacts drilling or tripping, the PRESSPRO RT service has you covered Specially designed PRESSPRO RT modules provide valuable information about all the properties of the fluids in the wellbore. • DRILLPRO* RT software targets critical parameters that must be

• TRIPPRO* RT software calculates and displays real-time fluid parameters while tripping drill pipe and running casing — situations where wellbore conditions can change very quickly • SNAPSHOT RT software provides a continuous graphical display of downhole profiles • VISUAL HYDRAULICS software provides a visual representation of downhole metrics using an easy-to-understand 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 measurement at the bit, the PRESSPRO RT package calculates complete profiles of downhole hydraulics and mud behavior. Additionally, it can substitute for the PWD when the tool is unavailable, such as while running casing, when the tool is non-operational, or when temperatures or pressures exceed tool limitations.

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 is the gold standard in the industry against which all other hydraulic programs are compared. Together, this incomparable suite of programs is ideal for the planning, monitoring, evaluating, optimization and collaboration required to successfully tackle today’s critical wells. 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.

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 • Predefined 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 • Enhances ECD management by providing downhole pressure profiles during drilling, tripping, and other critical operations • Complements PWD when available and substitutes for PWD when the data is not available.

A L P I N E S P E C I A LT Y C H E M I C A L S CUTTINGS TRANSPORT AND HANDLING CONTROL R I G I N S T R U M E N TAT I O N

The PRESSPRO RT system can also be monitored from a remote, onshore drilling center, also known as 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. The PRESSPRO RT system has been installed in clients’ OCs to facilitate efficient deployment and provide instant, remote access to real-time drilling and other operational data. Results are compared immediately to PWD and can be merged seamlessly with the real-time data stream simultaneously accessible at the OC and at the rigsite.

considered when drilling a well. For the very first time, ECD values are calculated and displayed every second while both drilling and making connections.

S I M U L AT I O N S O F T WA R E DRILLING-FLUID SYSTEMS AND ADDITIVES H D D M I N I N G A N D WAT E R W E L L RIG-EQUIPMENT ENGINEERING SOLIDS CONTROL OILFIELD SCREENS WASTE INJECTION C U T T I N G S T R E AT M E N T PRESSURE

The PRESSPRO RT system leverages the proven technologies in the VISUAL HYDRAULICS* module and displays key downhole profiles and fluid properties in a real-time SNAPSHOT* graph that is continuously updated with live drilling and tripping data. Whereas the VIRTUAL HYDRAULICS module provides accurate planning and sensitivity analyses, the PRESSPRO RT system closes the feedback loop by monitoring current conditions, helping personnel modify drilling practices and plan for contingencies in advance. Now, the VH RHECON* module closes the information loop by generating projections that look ahead of the bit, based on current operating conditions.

9

S I M U L A T I O N

S O F T W A R E

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. Armed with this powerful software package, the M-I SWACO specialist 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,

Engineered Displacement*

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 • 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

10

• 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

Features and Benefits • Minimizes rig time for displacements • Designs a displacement that meets equipment limitations • Ensures safety and well control • Provides flexible operating parameters for critical wells • Optimizes completion fluid economics

S O F T W A R E

VIRTUAL HYDRAULICS VIRTUAL HYDRAULICS gives you an even clearer view of your fluids’ behavior downhole The true value of the VIRTUAL HYDRAULICS software suite is truly appreciated in deepwater wells where uncontrolled ECDs can quickly exceed the boundaries of narrow operating windows, in extended-reach and horizontal wells, in High-Temperature, HighPressure (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:

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

The wide range of modules in VIRTUAL HYDRAULICS covers all the issues in hydraulics modeling 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. • 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 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 • The TPRO* TEMPERATURE PROFILES generates downhole transienttemperature profiles during circulation or shut-in 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.


• 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.

• The VH RHECON provides dynamic reconnaissance simulations to optimize hydraulics ahead of the bit, using predefined drilling parameters


S I M U L A T I O N

11

D R I L L I N G - F L U I D

S Y S T E M S

A N D

A D D I T I V E S

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

ឣAPPLICATIONS

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

ឣPROBLEMS

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 prescreened, 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.

ឣSOLUTIONS

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.

ឣECONOMICS

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.

Rheogram Showing Unique Rheological Properties

ឣENVIRONMENTAL

50

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.

12

The data was obtained on a Fann 35A viscometer. Both fluids were unweighted. 80 Dial reading 70 60

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 FLO-PLEX* 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 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 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.


• 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.


A straightforward system for the most complex applications

13


S Y S T E M S

A N D

A D D I T I V E S

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

ឣAPPLICATIONS

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.

ឣPROBLEMS

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.

ឣSOLUTIONS

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

ឣECONOMICS

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

ឣENVIRONMENTAL

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

GLYDRIL

Dry cuttings

Fluid-Loss Comparisons 14 cc Fluid loss 12 10 8 6 4 2 0 KCl/PHPA

API

14

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 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.

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


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.


Compare performance, then save with GLYDRIL

15


S Y S T E M S

A N D

A D D I T I V E S

NOVA Systems The environmentally sound alternative to traditional drilling fluids

NOVA systems deliver superior drilling performance

The NOVA line has what you’re looking for to replace your conventional system • Compared to water-base systems, NOVA* systems deliver significantly improved drilling rates and improved lubricity • The choice of low synthetic-towater ratios to reduce formulation costs and environmental impact • The ability to discharge cuttings • Excellent wellbore, temperature and contamination stability • 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

16

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 has proven itself in some of the stickiest applications • Where increased rates of penetration are required to reduce total time spent drilling the well, reducing overall well costs • Drilling through highly reactive shales where aqueous fluids produce wellbore instability and viscosity problems associated with hydration and dispersion of the formation • 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, hightemperature (>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

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


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 Gulf of Mexico. 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 (i.e., sediment toxicity, biodegradation, PAH content, metals content) and discharge limitations (i.e., 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. 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.


The NOVA line satisfies virtually every country’s environmental regulations

17


S Y S T E M S

A N D

A D D I T I V E S

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

ឣAPPLICATIONS

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

ឣPROBLEMS

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.

ឣSOLUTIONS

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.

ឣ

E C O N O M I C S

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.

ឣENVIRONMENTAL

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.

18

The issues with conventional invert-emulsion fluids External phase

Weight material

Emulsifiers

Others

Internal phase

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

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.

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 filtrationcontrol additives, the latter materials can be slow to degrade leaving behind toxic, degradation-resistant waste.

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

CLIMATE

Landfarming

Increasing containment

DEPENDENT

Biopile/biocell

Increasing containment

Vermiculture

CLIMATE

Co-composting (bag composter)

Total containment

Co-composting (rotary composter)

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 to 16 lb/gal (0.9 to 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.

Slurry bioreactor

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

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


Multiple treatment options ensure minimal environmental risk

INDEPENDENT


Bioremediation: The PARALAND options

19


S Y S T E M S

A N D

A D D I T I V E S

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

ឣAPPLICATIONS

Deepwater, extended-reach and other technically demanding wells.

ឣPROBLEMS

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 ECDs, barite sag and lost circulation.

ឣSOLUTIONS

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, progressive gel strengths and other problems that result when balancing ECD values.

ឣECONOMICS

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.

ឣENVIRONMENTAL

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.

20

The practical side of a flat rheological profile 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 Conventional 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.


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


Field results that deliver on the promise of the laboratory

21


S Y S T E M S

A N D

A D D I T I V E S

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

ឣAPPLICATIONS

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.

ឣPROBLEMS

The sticky bitumen clings to bits, Bottomhole Assemblies (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.

ឣSOLUTIONS

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.

ឣECONOMICS

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

ឣENVIRONMENTAL

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.

22

Product Functions and Descriptions Product TARVIS* TARSURF*

Function Rheological properties, especially LSRV Anti-accretion drilling-fluid additive

TARLIFT*

Anti-accretion drilling-fluid additive

TARCLEAN*

Anti-accretion for rig equipment

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 >95° F (>35° C) 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

Description Biopolymer Blend of solvents and surfactants Blend of solvents and surfactants Solvent

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

• 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

• A rheological profile optimized for minimal wellbore erosion • Rheology that ensures optimum hole conditions while drilling and running casing and production liners • Onsite fluids engineers who monitor the system’s Low-ShearRate Viscosity (LSRV) with a Brookfield viscometer

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.

Drilling Waste 400 tonnes 350 300 250 200

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

150 100 50 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.

Differential Rotor Decay 0.5 Reduction in diameter (mm) 0 –0.5 –1 –1.5 –2 –2.5 –3 0

20

40

60

80

100 120 140 160 180 200

Time, min 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.


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 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:

• Oil-wetting surfactants to encapsulate tarry cuttings and promote their effective removal by the shakers and other solids-control equipment such as centrifuges


A great deal of a 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.

23


S Y S T E M S

A N D

A D D I T I V E S

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

ឣAPPLICATIONS

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.

ឣPROBLEMS

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

ឣSOLUTIONS

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

ឣECONOMICS

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.

ឣENVIRONMENTAL

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.

24

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

Filter-cake deposition

Si Physical and chemical barrier to invasion

O

H Si Clay platelets

Benefits 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.


• 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

1,400


Fewer components give you more flexibility

25


S Y S T E M S

A N D

A D D I T I V E S

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

ឣAPPLICATIONS

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

ឣPROBLEMS

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.

ឣSOLUTIONS

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

ឣECONOMICS

The system’s ability to promote well-bore stability, high Rates of Penetration (ROP) and excellent hole cleaning 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.

ឣENVIRONMENTAL 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.

26

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 10 0 20% NaCl/PHPA

ULTRADRIL (20% NaCl)

Synthetic OBM

Moisture Recovery

The inhibitive capability of the ULTRADRIL system surpasses that of a conventional water-base system and nearly matches that of a synthetic-base drilling fluid. The system’s low moisture content results in drier, firmer drilled cuttings. With densities up to 11.3 lb/gal (5.1 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 • Near-OBM/SBM performance • Easy to build and maintain • Anti-accretion agent

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

Inhibition Action #1: Superior Clay Inhibition

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

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.

The high-performance, water-base system that’s easy to build and maintain 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 such as pH titration, ammonia extraction and retort analysis to confirm product-volume percentage. The basic system consists of three main components: ULTRAHIB*, ULTRACAP* and ULTRAFREE*.


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.


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

27


S Y S T E M S

A N D

A D D I T I V E S

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

ឣAPPLICATIONS

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

ឣPROBLEMS

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.

ឣSOLUTIONS

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.

ឣECONOMICS

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.

ឣ


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.

28

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 pretreating 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

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

• 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

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

• Horizontal and extended-reach wells

• Coiled-tubing drilling • Reservoir drill-in fluids • Wells with narrow operating windows • HTHP wells • Inhibitive fluids • Wells with risk of barite sag • Drilling waste management

For completion fluids, WARP Fluids Technology wins out over 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.


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:

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

Completion and Workover Fluids

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


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

29


S Y S T E M S

A N D

A D D I T I V E S

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.

30

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.

S Y S T E M S

A N D

A D D I T I V E S

ECOGREEN 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

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.

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.


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



31


S Y S T E M S

A N D

A D D I T I V E S

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.

32

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

S Y S T E M S

A N D

A D D I T I V E S

K-MAG 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

PARADRIL 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.


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.



33


S Y S T E M S

A N D

A D D I T I V E S

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 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 the expected Bottomhole Static Temperature (BHST). The first field

34

Typical System Components Additive Linear Paraffin Low-Toxicity Mineral Oil (LTMO) EMI-783 Bentone 38 VG-SUPREME* Lime SUREMUL* SUREWET* Freshwater CaCl2 VERSATROL* VERSATROL HT Barite

Material Base fluid

Function Continuous phase

Base fluid Organophilic clay Organophilic clay Organophilic clay Calcium hydroxide Polyamide Fatty acid Freshwater Calcium chloride Gilsonite Gilsonite Barium sulfate

Continuous phase Viscosifier Viscosifier Viscosifier Alkalinity Primary emulsifier Secondary emulsifier Internal phase Salinity Fluid loss Fluid loss Density

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.

S Y S T E M S

A N D

A D D I T I V E S

POLY-PLUS 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

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

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


• 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.



35


S Y S T E M S

A N D

A D D I T I V E S

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

36

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

S Y S T E M S

A N D

A D D I T I V E S

Drilling-Fluid Systems and Additives Product Trade Name

Description

Type

Primary Function

Secondary Function

Sulfonated organic-resin blend Sulfonated organic blend Sulfonated asphalt

Water Water Water

Shale inhibitor Shale inhibitor Shale inhibitor

Filtration Filtration Filtration

Low-toxicity defoamer Caustilized lignite

Water Water

CLEAN UP*

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

Defoamer Thinner Filtration Surfactant

— Thermal stability Emulsifier Emulsifier

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

Corrosion inhibitor Corrosion inhibitor Corrosion inhibitor Corrosion inhibitor Lost circulation

— — — — —

C-SEAL* F

Coke FLCA (fine grind)

Lost circulation

—

D-D*

Drilling detergent

Surfactant

DEFOAM-A* DEFOAM-X* DRIL-FREE* DRIL-KLEEN* DRIL-KLEEN* II DRILPLEX* DRILZONE* DRILZONE* L 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 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 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* FER-OX*

Salt for ENVIROVERT system Hematite

FORM-A-PLUG* II

Acid-soluble plug

FORM-A-PLUG* ACC

Accelerator for the FORM-A-PLUG II system

FORM-A-PLUG* RET

Retarder for the FORM-A-PLUG II system

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

Defoamer Defoamer Lubricant Surfactant

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

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

Emulsifier Shale control — — Surfactant Emulsifier Shale control Emulsifier, Lubricant Shale inhibitor — — — — — — Thermal stability — Lubricant — Surfactant Surfactant — —

Emulsifier

—

Shale inhibitor Density

— —

Lost circulation

Filtration

Lost circulation

—

Lost circulation

—


ASPHASOL* ASPHASOL* D ASPHASOL* SUPREME BUBBLE BUSTER* CAUSTILIG*



37


S Y S T E M S

A N D

A D D I T I V E S


Description

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 K-17*

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 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 Potassium lignite

K-52* KLA-CURE * KLA-CURE * II KLAFLOC* I KLAFLOC* II KLA-GARD * KLA-GARD * B KLA-STOP* LO-WATE*

Potassium supplement Hydration suppressant Hydration suppressant plus detergent Low-cost shale inhibitor for floc water drilling Cationic flocculant for floc water drilling Shale stabilizer and inhibitor Salt-free KLA-GARD Shale inhibitor Ground calcium carbonate weight material

LUBE-945* M-I BAR *

Water-dispersible lubricant 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

GLYDRIL* HC GLYDRIL* LC GLYDRIL* MC HIBTROL* HIBTROL* HV HIBTROL* ULV

M-I GEL* SUPREME Non-treated bentonite, meets API specifications M-I GEL* WYOMING API-spec bentonite sourced only from Wyoming

38

Type

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

Primary Function

Secondary Function

Lost circulation Lost circulation

— —

Lost circulation

—

Lost circulation

—

Lost circulation

—

Lost circulation

—

Lubricant

Filtration

Water Water

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

Water

Filtration

Oil Water Water Water Water Water

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

Thermal stability — — — — Emulsifier Shale control — — — — — Filtration — — Filtration Lost circulation

Lubricant Density

Shale inhibition —

Lost circulation Biocide Filtration Viscosifier Viscosifier Viscosifier

— — —

Water Water Water Water Water Water

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

— — Surfactant Lubricity Lubricity Lubricity Lubricity Shale inhibition Shale inhibition Viscosifier Shale control

Filtration Filtration

M-I LUBE* M-I PAC* R

General-purpose lubricant PAC polymer, tech grade

M-I PAC* UL M-I SEAL*

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

M-I-X* II

Ground cellulose

MUD WASH* MUL HTP*

Rig wash Primary emulsifier for negative-alkalinity system

MY-LO-JEL* NOVAMOD* NOVAMUL*

Pregelatinized starch Rheology modifier, LSRV Basic emulsifier package

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

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 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 Oil-base, stuck-pipe-freeing surfactant

Corrosion inhibitor Thinner Thinner Shale inhibitor Shale inhibitor Filtration Free pipe

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

Low-toxicity, stuck-pipe spotting fluid Liquid, one-drum, stuck-pipe spotting fluid

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

Filtration Viscosifier Thermal stability — — — — — —

Free pipe Free pipe

Lubricant —

Filtration Filtration

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

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

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

Extra-low-viscosity PAC Polyanionic cellulose

Type

Primary Function

Secondary Function

Water Water

Lubricant Filtration

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

Filtration Lost circulation

— Viscosifier Shale inhibitor Shale inhibitor Filtration

Lost circulation

Filtration

Rig wash Emulsifier

— Filtration

Filtration Viscosifier Emulsifier

— — Surfactant Filtration Thermal stability Viscosifier Lubricant —

Emulsifier

Filtration Filtration Surfactant Emulsifier Thinner Thermal stability —


Description


Product Trade Name

39


S Y S T E M S

A N D

A D D I T I V E S


Description

RHEBUILD*

Viscosifier for RHELIANT system

RHEDUCE*

Thinner for RHELIANT system

RHEFLAT*

Rheological modifier for RHELIANT system

RHETHIK*

Rheological modifier for RHELIANT system

RHEOSPERSE* SAFE-CARB *

Polymeric high-temperature deflocculant Ground marble (calcium carbonate)

SALT GEL* SCREENKLEEN* SHALE CHEK *

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

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

Primary Function

Secondary Function

Viscosifier

—

Thinner

—

Viscosifier

—

Viscosifier

—

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

Thinner Filtration

— Density

Viscosifier Surfactant

— —

Water

Shale control

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

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

Viscosifier Thinner

— Surfactant

SUREWET*

Wetting agent for for invert-emulsion systems

Surfactant

Emulsifier

SV-120* SWA* EH

Corrosion inhibitor Surfactant

— Emulsifier

Water

Thinner

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

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

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

Water Water

TARCLEAN* TARLIFT* TARSURF* TARVIS* THINSMART* TRUVIS* ULTRACAP * ULTRAFREE * ULTRAFREE * L ULTRAFREE * NH

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 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

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

Filtration Thermal stability — Emulsifier Thermal stability — — — — — Filtration — — Lubricant Lubricant

TACKLE *

40

Type

Water Water Water Water Water Oil Water Water Water Water

Description

Type

Primary Function

Secondary Function

ULTRAHIB* UNITROL* VERSACLEAN * B VERSACOAT *

Shale inhibitor for the ULTRADRIL system Modified polysaccharide Base fluid for the VERSACLEAN system Emulsifier and wetting agent

Water Water Oil Oil

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

VERSATHIN * VERSATROL*

Thinner and conditioner for oil-base fluids Asphaltic resin

Oil Synthetic Oil Oil

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

VERSACOAT * NA

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

XP-20K*

Potassium chrome lignite

XP-20* N

Chrome lignite, sodium hydroxide, neutralized

Thinner Filtration

Thinner Thinner Surfactant

— Lost circulation Viscosifier —

Viscosifier Viscosifier

Lubricant Lubricant Emulsifier Thinner Thermal stability Filtration Filtration

Viscosifier Filtration

Filtration —

Thermal stability

Emulsifier Filtration Thinner Thinner Filtration

Oil Oil Synthetic Synthetic Water Oil Synthetic Water

Water

Thermal stability


Product Trade Name


41

A L P I N E

S P E C I A L T Y

C H E M I C A L S

ALPINE DRILL BEADS ALPINE DRILL BEADS* additive is a completely spherical all-co-polymer bead uncontaminated with glass or all-styrene material, designed to act as a mechanical lubricant. ALPINE DRILL BEADS lubricant is non-abrasive and temperaturestable to 450° F (232° C). It is compatible with water-, oil- and synthetic-base mud systems. Because of its high compressive strength, this lubricant is able to minimize casing wear, reduce torque and drag and lower the risk of differential sticking in depleted, underbalanced formations.

Fine and coarse sizes available.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . Semitransparent variegated spheres Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.10 to 1.13 Solubility in water. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Insoluble Temperature range . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stable to 450° F (232° C) Size ranges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fine: 100 to 300 μm Coarse: 300 to 1,000 μm Reactivity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Inert

Applications ALPINE DRILL BEADS additive is designed for use in situations where torque, drag, casing wear, and/or the potential for differential sticking are likely. Typical applications for ALPINE DRILL BEADS lubricant are highly deviated holes, wells with high tortuosity and wells with severe or unplanned doglegs where high torque and drag are encountered.

The initial concentration of ALPINE DRILL BEADS additive is in the range of 2 to 6 lb/bbl (5.7 to 17.1 kg/m3). This value can be adjusted in accordance with the torque and drag limitations of the drilling operation. After the initial treatment, additions need to be made to replace product that is left embedded in the formation or the mud filter cake.

In wells where rotation inside of casing is required for extended periods of time, ALPINE DRILL BEADS lubricant reduces casing wear, which in turn reduces the risk of compromised casing integrity. ALPINE DRILL BEADS mechanical lubricant can also be spotted in an openhole for logging operations and for running casing at 8 to 12 lb/bbl (22.8 to 34.2 kg/m3). ALPINE DRILL BEADS lubricant is available in fine or coarse sizes, varying from 100 microns to 1,000 microns.

10 grams

1.1 SG

2.5 SG

Glass beads

3.0 SG

ALPINE co-polymer drill beads

Ceramic beads

Best Value: ALPINE co-polymer drill beads cover 150% more surface area.

42


Advantages

Toxicity and handling

Packaging and storage

• Reduces friction

Bioassay information is available upon request. Handle as an industrial chemical, wearing protective equipment and observing the precautions as described in the Material Safety Data Sheet (MSDS).

ALPINE DRILL BEADS additive is packaged in 50-lb (22.7-kg), multiwalled, paper sacks; 48 sacks to a pallet. Store in a dry location away from sources of heat or ignition, and minimize dust.

• Minimizes casing wear • Decreases torque and drag • Breaks capillary attraction • Lowers risk of differential sticking • Compatible with all drilling fluids • Non-abrasive


True weight-to-bit. The ball bearing effect of ALPINE DRILL BEADS reduces friction, torque and drag, helps prevent casing wear, and paves the wellbore.

43

A L P I N E

S P E C I A L T Y

C H E M I C A L S

ALPINE DRILL BEADS RECOVERY UNIT The ALPINE DRILL BEADS RECOVERY UNIT* (DBRU) is designed to minimize the amount of ALPINE DRILL BEADS lost to surface solids-control equipment, eliminating costly and repetitive additions of drill beads to the mud system. Without a recovery unit, the majority of drill beads would be removed from the circulating system at the shale shakers. ALPINE SPECIALTY CHEMICALS* has designed a system that meets strict industry guidelines for safety, minimizes the amount of personnel required and provides an efficient recovery method. Utilizing the ALPINE DBRU, all cuttings and solids removed at the rig shaker are transported to a second set of shakers where drill solids and waste material are separated from the drill beads, and are discharged to the waste stream, while the drill beads are recovered and returned to the suction pit.

Features • Streamlined to fit all rigs • Designed to meet OSHA standards • Customized linear-motion shakers • Self-contained and fully equipped

Benefits • Meets safety requirements • Efficient recovery of drill beads • Minimal personnel requirements • Compatible with all WBM, OBM and SBM • Screen changes in 1 min

44

Heavy-duty construction, compact design.

Features Streamlined to fit all rigs. The bead-recovery system is equipped with its own shale shakers and an efficient processing tank that requires minimum space. If required, the system can be tailored and modified to utilize the space available through a flexible arrangement of pumps and piping. Designed to meet OSHA standards. The design of the equipment, both mechanical and electrical, strictly complies with OSHA regulations. Safety rails and guards have been placed on the unit to protect workers. Customized linear-motion shakers. The DBRU’s custom-sized shakers facilitate rapid screen changes with a minimum of downtime. Screen life is maximized and the finest-mesh screens are used in order to remove drill solids while recovering the highest percentage possible of ALPINE DRILL BEADS.

Self-contained and fully equipped. The unit has the primary shaker mounted on the catch tank and has centrifugal pumps manifolded and attached on the skid. An electrical power box is built onto the skid and allows easy rig-up. The equipment arrives at the rig complete with hoses and transfer pumps for maximum efficiency. Experienced technicians are on hand at all times to monitor and service the DBRU.

ALPINE SPECIALTY CHEMICALS positions the equipment as close to the rig shale shakers as possible. As cuttings and drill beads return from downhole, they are washed down to the first shaker with base fluid where fine solids and drill beads pass through a 10-mesh screen into the catch tank. The fluid is then pumped through hydrocyclones which separate the drill solids from the drill beads. The drill solids are discharged in the

underflow of the hydrocyclones and are removed by a fine-mesh screen then transported to the solids-control waste stream. The ALPINE DRILL BEADS have a lower specific gravity (1.1 SG) than the cuttings, so they will pass with the overflow to a secondary shaker where a fine-mesh screen captures them. The drill beads are then mixed with drilling fluid and pumped to the suction pit where they are sent downhole again.

ALPINE DRILL BEADS RECOVERY UNIT Rig shakers

Cuttings trough

Beads and water to recovery shaker

Wash down return Recovery system is a self-contained, closed-loop system

Primary shaker

Recovery shaker Fluid return line

To hydrocyclone

Clean drill beads back to mud system

Cuttings and unwanted solids Wash down to rig shakers

Wash down pump

to overboard or reserve pit Cone pump

Hydrocylone separates ALPINE DRILL BEADS (1.1 SG) from unwanted solids (1.1 to 4.2 SG)

Typical Components and Footprint

Since each configuration is customized for a specific project, specifications vary. Here is a typical list of components.

Component Main recovery unit Recovery shaker Drip pan Recovery pump

Length in. (mm) 123 (3,124) 96 (2,438) 96 (2,438) 64 (1,626)

Width in. (mm) 84 (2,134) 60 (1,524) 60 (1,524) 24 (610)

Height in. (mm) 148 (3,759) 56 (1,422) 12 (305) 34 (864)

Weight lb (kg) 11,600 (5,262) 2,200 (998) 850 (386) 850 (386)


Specifications

Recovered beads returning to the mud system.


How it works

45

A L P I N E

S P E C I A L T Y

C H E M I C A L S

BLACK FURY BLACK FURY* liquid Gilsonite^ suspension is specifically formulated to stabilize water-sensitive, micro-fractured shales when drilling with water-base drilling fluids. BLACK FURY liquid gilsonite seals micro fracture, reduces dynamic fluid loss and minimizes the potential for differential sticking. Secondary benefits include improved lubricity and reduced accretion from sticky clays. The product has application in most water-base drilling fluids and is acceptable environmentally.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Black viscous liquid Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.05 to 1.09 pH . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9.0 to 9.2 (2% in distilled water) Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >200° F (93° C)

Applications

A concentration of BLACK FURY liquid Gilsonite is maintained by volumetrics as the product is only slightly soluble in water. BLACK FURY shale-control additive does not induce foaming and is not sensitive to contamination. It is compatible with other sealing agents and has been used to combat seepage losses in conjunction with fibrous materials and calcium carbonate.

BLACK FURY liquid Gilsonite can be used in most water-base drilling fluids. It has been extremely effective in lignosulfonate, potassium and PHPA mud systems. An initial treatment of 2 to 5% by volume (7 to 17.5 lb/bbl [20 to 49.9 kg/m3]) is recommended to achieve optimum results. The readily dispersible nature of the product allows high concentrations to be added easily to the mud system. The product contains glycol which aids in lubricity and inhibition.

Advantages • Improves wellbore stability and shale inhibition • Improves lubricity Mix directly in mud system.

• Improves high-temperature filtration control • Reduces bit balling potential

BLACK FURY liquid Gilsonite is temperature stable to 425° F (218° C) and reduces API, HTHP, dynamic filtration, spurt-loss values and potential for differential sticking. BLACK FURY liquid Gilsonite works best when added to the mud system before encountering known trouble zones. It can be added directly to the system through the mud hopper or pumped directly into the suction pit.

250° F (121° C) @ 600 rpm @ 1,000 psi (68.9 bar) Ceramic filter disk

BEFORE

AFTER

Note low spurt loss after BLACK FURY.

46

^Mark of American Gilsonite Company.

• Reduces filter-cake buildup in depleted sands • Excellent environmental acceptability • Field proven

BEFORE ⁄32-in.

9

8∑-in. hole ⁄32-in. mud cake 9

6∑-in. drill collar

Contact area = 5∑-in. (140 mm) Side force = 1,063,920 lb (482,586 kg) ΔP = 1 lb/gal @ 15,500 ft (4,724 m)

AFTER ⁄32-in.

3

8∑-in. hole ⁄32-in. mud cake

3

6∑-in. drill collar

Contact area = 3 in. (76 mm) Side force = 580,320 lb (263,229 kg) ΔP = 1 lb/gal @ 15,500 ft (4,724 m)

Note the superior pore-throat sealing qualities of this 14-lb/gal (1.7-kg/L) ligno mud after using BLACK FURY 3% by volume.




BLACK FURY is packaged in 55-gal (208-L) drums and in 550-gal (2,082-L) tote tanks. Store in a dry location away from sources of heat or ignition, and minimize dust.

Dynamic and HTHP filtration test equipment.


Dynamic filtration test


47

A L P I N E

S P E C I A L T Y

C H E M I C A L S

CELL-U-SEAL CELL-U-SEAL* cellulose fiber is a superior bridging agent and LostCirculation Material (LCM) designed to bridge and seal permeable formations in water-, oil- or syntheticbase mud systems. Bridging and sealing permeable formations and micro-fractured shales reduces the potential for differential sticking and lowers torque and drag tendencies. CELL-U-SEAL fiber has proven effective in reducing differential sticking when drilling extremely depleted zones where the differential pressures are very high. For added flexibility, CELL-U-SEAL fiber is available in fine, medium and coarse grades so that the optimum particle size can be selected to bridge the pores and pore throats of permeable formations. CELL-U-SEAL cellulose fiber additions have minimal effects on mud properties.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . Tan to light brown powder and fibers Bulk density. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22 to 32 lb/ft3 (352 to 513 kg/m3) Environmental . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Biodegradable/non-toxic Solubility. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 46% by weight acid soluble Particle-Size Distribution (PSD). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.5 to 2,000 μm

Applications CELL-U-SEAL cellulose fiber is a superior bridging agent field proven to be effective when drilling highly permeable, extremely porous zones with elevated differential pressures. It is effective for treating seepage losses where only minimal treatment is required to major losses where large batch treatments are necessary. CELL-U-SEAL fiber is designed to bridge and seal permeable zones, where it reduces the possibility of stuck pipe, controls lost circulation and provides better filtration control. The recommended treatment of CELL-U-SEAL material is 4 to 10 lb/bbl (11.4 to 28.5 kg/m3) by

48

volume in sweeps and/or in the entire mud system to help prevent differential sticking tendencies. Additional treatments need to be made to replace material that remains downhole or is removed by solids-control equipment. Significant quantities of the medium and coarse grades are removed by fine meshed screens (100 mesh and finer). For medium to severe losses, 25 to 40 lb/bbl (71.3 to 114 kg/m3) should be spotted across the loss zone. Combinations of fine, medium and coarse CELL-U-SEAL fiber should be contemplated in these situations. Batch treatments are often preferred to treatments

for the whole system because batch treatments minimize shaker losses and avoid bypassing shaker screens, which reduces mud contamination from drill solids. CELL-U-SEAL fiber (fine) is sized so that approximately 40 to 43% passes through a 120-mesh screen. CELL-U-SEAL lost-circulation material can be added to the mud system through the mud hopper, where good agitation occurs, and is compatible with all water-, oiland synthetic-base mud systems.

Gravel

• Easily mixed and dispersed into the mud system • Biodegradable/non-toxic • Offers unique particle sizes, smaller than conventional LCM, yet larger than solids found in most drilling fluids

Silt

Clay

100

20

90

18

80

70 Cumulative volume, %

• Compatible with all mud systems and other lostcirculation materials

Sand

16

Frequency Cumulative Mean Median

14 Actual size

60

12

50

10

40

8

30

CELL-U-SEAL dry product (enlarged 150x)

6

20

4

10

2

0 μm 4,000 2,000 1,000 500 250 121 66 31 16 10 18 30 60 120 230 400 US 5 Sieve Particle diameter

Frequency, %

• Offers some elongated material as well as granular particles, ensuring a matting effect across the formation • Inert material with minimum effect on mud properties

Sample: CELL-U-SEAL

Extended-range laser sieve analysis

• Effective bridging and sealing agent for a wide range of formations

Screen Performance: 43% by volume passes through a 120-mesh screen Particle-size distribution: PDS = 0.5 microns to 2,000 microns

0 8

4

2

1

0.5

Toxicity and handling Bioassay information is available upon request. Handle as an industrial chemical, wearing protective equipment and observing the precautions as described in the Material Safety Data Sheet (MSDS).



CELL-U-SEAL is packaged in 40-lb (18.1-kg), multi-walled, paper sacks. Store in a dry location away from sources of heat or ignition, and minimize dust.

Result: ASTM E11:61 report. Report performed by Westport Technology Center International (Houston, Texas), Deborah A. Ragland, Ph.D., and Michael C. Dix, September 30, 1999. Report number RT-99-052. Project number D115448D0000.


Advantages

49

A L P I N E

S P E C I A L T Y

C H E M I C A L S

CLEAN SPOT CLEAN SPOT* pipe-freeing agent is a water-dispersible, low-toxicity spotting fluid designed to free differentially stuck pipe by penetrating between the wall cake and metal. CLEAN SPOT additive also offers strong metal wetting characteristics and can be used as a lubricant after being incorporated into the active system.

Typical physical properties Physical appearance. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amber liquid Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >200° F (93° C) Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.91 to 0.925

Applications

Advantages

CLEAN SPOT pipe-freeing agent is a low-toxicity spotting fluid that has proven itself highly effective in environmentally sensitive areas, both onshore and offshore. Success in freeing differentially stuck pipe is greatest when the spotting fluid is applied as soon as possible after the pipe becomes stuck. A fluid that can be mixed and spotted quickly often frees the drillstring before fishing operations are required. CLEAN SPOT pills are easily prepared and are well suited for spotting situations.

• Effective soak solution that quickly frees differentially stuck pipe • Can be easily weighted with barite, FER-OX* or calcium carbonate • Can be incorporated in most mud systems • Contains no hydrocarbons and is water dispersible • Excellent stability at downhole temperatures and pressures • Aids in lubrication, improving torque and drag reduction characteristics of the fluid when incorporated in the system

Mixing procedure 1. Calculate the volume of spotting fluid required and add at least 10% to compensate for washout. In addition, include 25 bbl to remain in the drillstring after initial displacement.

CLEAN SPOT pipe-freeing agent contains no hydrocarbons, is compatible with most mud systems and can be used either weighted or unweighted in wells with differentially stuck pipe. After being used as a spotting fluid, CLEAN SPOT additive can be incorporated into the active mud system to reduce torque and drag and reduce the possibility of differential sticking.

50

2. In a clean dry tank, mix the required amount of CLEAN SPOT pipe-freeing agent from the formulation chart. Supply adequate ventilation when opening containers and in enclosed areas when mixing CLEAN SPOT additive. 3. Add required materials in the order listed and allow for the pill to agitate and homogenize the entire pill. Add weighting agents as the final step before pumping the pill. 4. Displace the slurry to the zone where the differential sticking is

suspected. Leave approximately 25 bbl (if volume is available) inside the drill pipe to displace at an hourly rate into the openhole. 5. Work the pipe while the spot is soaking. Periodically pump 1 to 2 bbl to assure that fresh CLEAN SPOT additive is being displaced across the problem zone. 6. Allow at least 24 hrs for the CLEAN SPOT pipe-freeing agent to free the stuck pipe. Note: When using CLEAN SPOT pipefreeing agent in deviated wells with angle greater than 35°, the spotting fluid should be weighted 0.5 lb/gal (0.06 SG) heavier than the fluid in the well to encourage the spotting fluid to migrate.

Quick-Mix Recipe For a 50-bbl pill

1 3 tanks of CLEAN SPOT 2 For 8 to 12 lb/gal (0.96 to 1.44 kg/L), add 1 tank or 550 gal (2,082 L) water (12 bbl) BEFORE

AFTER

Note: The dehydration and cracking of this 12.5-lb/gal (1.5-kg/L) wall cake after covering with CLEAN SPOT concentrate.

Dynamic filtration wall cakes

3 For 13 to 18 lb/gal (1.56 to 2.16 kg/L), add ∑ tank or 275 gal (1,041 L) water (6 bbl) 4 Add 400 lb (181 kg) or 8 sacks of lime. Shear and mix for 30 min. 5 Add barite to desired density. Shear and mix for 30 min to 1 hr. 6 Add 400 lb (181 kg) or 4 sacks of salt and 500 lb (227 kg) of ALPINE DRILL BEADS and mix for 15 min

BEFORE

AFTER

Note: The dehydration and cracking of this 16-lb/gal (1.9 kg/L) wall cake after covering with CLEAN SPOT concentrate.

Mixing Table, general guidelines per barrel (42-gal) 8 (0.96)

9 (1.1)

10 (1.2)

11 (1.3)

12 (1.4)

13 (1.6)

14 (1.7)

15 (1.8)

16 (1.9)

17 (2.0)

18 (2.2)

CLEAN SPOT*, gal (L)

31 (117)

30 (114)

30 (114)

29 (110)

28 (106)

27 (102)

27 (102)

26 (98)

25 (95)

25 (95)

23 (87)

Barite, lb (kg)

25 (11.3)

80 (36.3)

140 (63.5)

190 (86.2)

240 (109)

300 (136)

360 (163)

400 (181)

460 (209)

520 (236)

580 (263)

Lime, lb (kg)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

Salt, lb (kg)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

10 (4.5)

5 (2.3)

5 (2.3)

5 (2.3)

5 (2.3)

Water, gal (L)

10 (38)

10 (38)

10 (38)

10 (38)

5 (19)

5 (19)

5 (19)

5 (19)

5 (19)

5 (19)

5 (19)

Number of bbl of finished product per tank

17

18

18

18

19

19

20

20

21

22

23


Density, lb/gal (kg/L)


High-Temperature, High-Pressure filtration wall cakes

51

A L P I N E

S P E C I A L T Y

C H E M I C A L S

FORM-A-SQUEEZE FORM-A-SQUEEZE* high-fluid loss/high-solids slurry is a cost effective solution to lost circulation in all types of fractures, vugular formations, matrix and underground blowout events. When placed in and/or across a loss zone, the liquid phase squeezes from the slurry, rapidly forming a solid plug behind. This process can cure losses instantly, without time or temperature dependency.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gray powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.70 to 1.76 Solubility in water. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Slightly Odor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . None The recommended concentration of FORM-A-SQUEEZE slurry is 80 lb/bbl (228 kg/m3) in either water or base oil/synthetic. The slurry can be weighted to the desired density with barite or calcium carbonate. The slurry should be pumped to the annulus, covering at least 50% in excess of the loss zone. The drill string is then pulled slowly 90 ft (27 m) above the pill. The slurry should be gently squeezed in the range of 100 to 300 psi (6.9 to 20.7 bar) to the maximum of anticipated mud weight required for the interval, holding the pressure for 10 to 20 min.

Applications

Advantages

FORM-A-SQUEEZE Lost-Circulation (LC) plug can be used to stop losses occurring in any water-base and non-aqueous base fluids and can be easily mixed in freshwater, seawater or base oil/synthetic. It was designed to be used as:

• Quick-acting plug for fractured, vugular formations and underground blowout events

• Openhole remedial and/or preventive lost-circulation squeeze • Plug to run in front of cement squeezes • Plug to improve casing shoe integrity • Preventive LC material for seepage losses, up to 20 lb/bbl (57 kg/m3) in the whole active system • Cased-hole squeeze for sealing perforations and casing leaks

52

• Single-sack product — each 50-sack pallet of FORM-A-SQUEEZE additive makes a 25-bbl pill • Extremely easy to mix through a standard hopper in both water and base oil/synthetic • No special equipment required to spot the pill • No spacer is required — contaminant friendly to both water-base and non-aqueous base fluids • Not affected by temperature, activator and retarder formulations or pH • Temperature stable up to 450° F (232° C) • Environmentally acceptable (complies with LC50 requirements) • Can be mixed in rig slugging pit up to 17 lb/gal (2 kg/L) • Can be used in whole circulation system up to 10 lb/bbl (28.5 kg/m3) for seepage loss

Mixing Table (approximately one barrel) Weight lb/gal (kg/L) 9 (1.1) 10 (1.2) 11 (1.3) 12 (1.4) 13 (1.6) 14 (1.7) 15 (1.8) 16 (1.9)

Water (bbl) 0.88 0.84 0.81 0.78 0.74 0.71 0.68 0.65

FORM-A-SQUEEZE* 40-lb (18.1-kg) sacks 1.76 1.68 1.62 1.56 1.48 1.42 1.36 1.30

Barite 100-lb (45.4-kg) sacks 0 0.55 1.11 1.68 2.25 2.81 3.38 3.95


LC Plug compressibility comparison

FORM-A-SQUEEZE Note: More compacted

Product A

Product B

Each product, 80 lb/bbl (228 kg/m3) in water (each sample dewatered within 90 sec)

Packaging and storage FORM-A-SQUEEZE additive is packaged in standard 40-lb (18.1-kg) sacks; one pallet contains 50 sacks or 2,000-lb (907.2 kg) super-bags on request. Store in a dry, well-ventilated area away from sources of heat or ignition. Avoid generating dust. Follow safe warehousing practices regarding palletizing, banding, shrink-wrapping and/or stacking.

FORM-A-SQUEEZE weighted LC plug.




53

A L P I N E

S P E C I A L T Y

C H E M I C A L S

PA-10 PA-10* liquid additive is designed to improve the rate of penetration in waterbase drilling fluids, especially where Polycrystalline Diamond Compact (PDC) bits are being used. PA-10 liquid additive employs a non-petroleum base fluid in conjunction with surface active agents to maximize the cutting ability of the bit. The chemical makeup of the additive resists the tendency of clays to adhere to the bit and Bottomhole Assembly (BHA) and assures that weight is more effectively transferred to bottom. It also helps maintain a clean bit face so that cutters have better contact with the formation being drilled. A secondary benefit is reduced torque and drag resulting from the increased lubricity of the drilling fluid.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Light yellow-golden liquid Specific gravity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.90 to 0.93 Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >200° F (93° C)

Micro-emulsion droplets.

54

Applications PA-10 liquid additive is designed to optimize the ROP performance of water-base mud systems. It is applicable in both onshore and offshore environments. PA-10 additive coats metal surfaces, retards gumbo hydration and reduces cuttings accretion on bottomhole assemblies. PA-10 liquid additive can be mixed directly into the suction pit, preferably as near as possible to the pump suction. The product is also effective when injected directly into the pump suction. Initial treatment should be 1∑ to 2% by volume, with a target of 2 to 5% being optimum. Continuous additions of PA-10 additive should be made to the system to maintain the proper concentration as new mud is added and as mud depletes as the additive coats the wellbore and drill solids. The injection rate for PA-10 antiaccretion agent varies depending on the drill rate, hole size, pump rate and dilution level. PA-10 liquid additive is effective when pumped in pill form with a concentration of 5 to 15%, especially during sliding operations.

• Increases ROP while drilling clays and shales • Reduces torque and drag • Improves filter-cake quality • Works well with highperformance PDC bits

PA-10 is laboratory tested to enhance your mud’s performance.


• Contains surface-active metalwetting agents that reduce balling on bits and BHA • Improves metal-to-metal lubricity

Packaging and storage PA-10 liquid additive is packaged in 55-gal (208-L) drums and 550-gal (2,082-L) tanks.

Mix directly in mud system.


• Optimum performance may not be realized if the material is not added continuously in sufficient concentration while drilling



Advantages

55

A L P I N E

S P E C I A L T Y

C H E M I C A L S

QUICK SLIDE QUICK SLIDE* multi-blend lubricant is designed to decrease the coefficient of friction in all water-base drilling fluids. Decreasing the coefficient of friction reduces torque, drag and the potential for differential sticking in the wellbore. QUICK SLIDE lubricant is a suspension of polymer drill beads in a base fluid that contains no hydrocarbons. The co-polymer beads act as a mechanical lubricant, embedding themselves in the filter cake in openholes and providing mechanical standoff in cased holes, reducing metal-to-metal friction. The carrying fluid has a unique wettability characteristic that lowers the potential of accretion on the BHA and drill pipe, allowing more consistent weight to be applied to the bit. QUICK SLIDE lubricant is only slightly water soluble under most conditions, but is dispersible in water-base muds.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Milky white liquid Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >201° F (94° C) Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.00 to 1.02

Applications QUICK SLIDE multi-blend lubricant is designed for situations where torque and drag and/or the potential for differential sticking are likely, such as when drilling deviated holes or wells with high overbalance. The lubricant is applied in situations where directional concerns require extended drilling

QUICK SLIDE lubricates with micro-emulsion droplets.

56

without rotation, which causes bottomhole assemblies to hang up because of a lack of weight transfer to bottom. It is also applied during casing and logging operations where hole conditions warrant the use of a lubricant for tools and pipe to successfully reach bottom. Normal concentrations of QUICK SLIDE lubricant are in the range of 1∑ to 3% by volume (5 to 10 lb/bbl [14.3 to 28.5 kg/m3]) depending on the fluid density, desired reduction in coefficient of friction and the mud system. QUICK SLIDE blended lubricant can be used in higher concentration when applied in pills where torque and drag are clearly being produced in build sections of highly deviated wells. In those situations, concentrations should range 7 to 10% by volume (24.5 to 35 lb/bbl [69.8 to 99.8 kg/m3]). When circulating these pills, allow sufficient time for the drill beads to work themselves into the formation around the BHA.

• Lubricating suspension mineral • Non-petroleum-base liquid • Co-polymer plastic beads

QUICK SLIDE multi-blend lubricant is water dispersible and blends easily in all water-base mud systems. It can be added to the mud system through the mud hopper or directly to the surface system anywhere good agitation is available.

Advantages • Effective lubricant for water-base mud systems • Decreases the coefficient of friction, which reduces torque and drag • Reduces the potential for differential sticking • Mechanically and chemically lubricates • Temperature stable to 400° F (204° C) • Reduces the tendency for bit and BHA accretion when drilling sticky shales



QUICK SLIDE multi-blend lubricant is packaged in 55-gal (208-L) drums and in 550-gal (2,082-L) tote tanks. Store in a dry location away from sources of heat or ignition, and minimize dust.

Lubricity Test at 60 rpm (metal-to-metal tester) Coefficient of friction of water (0.33 to 0.36) = 0.35; i.e., reading at 150 in./lb is 35

Applied torque in./lb 100 150 200 300 400 500 600

Lubricity meter reading (electrical current required to sustain 60 rpm at applied torque) Base Base Base +2% BLACK FURY* Base +2% BLACK FURY +2% QUICK SLIDE +2% QUICK SLIDE* 12 11 12 11 17 24 40 56 86 115

16 20 33 45 60 80

17 13 20 25 30 33

16 19 20 24 28 31

QUICK SLIDE lubricant instantly disperses in water and is laboratory tested to enhance your mud’s performance.

Shelby County, Texas Horizontal well

12 ft/hr

12

After QUICK S LIDE

10

8

Slide, ft/hr

Dynamic filtration test

6

4

26 mL — 14 g — 4⁄32-in.

4

ft/hr Before QUICK S LIDE

14 mL — 8 g — 2⁄32-in. 2

0 Problem: Sliding unacceptable

Solution: QUICK S LIDE

The proven drilling solution: ALPINE SPECIALTY CHEMICALS maintains a database verifying the high-performance characteristics of QUICK SLIDE lubricant.


Note how the co-polymer beads embed and protrude on the face of the wall cake. The beads reduce wall force friction, increasing your ability to slide drill.



57

A L P I N E

S P E C I A L T Y

C H E M I C A L S

SACK BLACK SACK BLACK* shale inhibitor is a partially water soluble, water dispersible, coupled Gilsonite. It is used to aid in stabilizing shale sections, controlling wall-cake characteristics, minimizing spurt loss, plugging micro-fractured shales and providing HTHP fluid-loss control at elevated temperatures in water-, diesel- and synthetic-base drilling-fluid systems.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Black powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.04 to 1.06 Solubility in water. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Partially insoluble

Applications SACK BLACK additive is a coupled Gilsonite that can be used in most water- and oil-base muds. It is a free-flowing powder and can be added directly to the mud system through the mixing hopper. SACK BLACK shale inhibitor has been pretreated with a coupler to enhance its wettability in waterbase fluids and requires no additional coupler when added to a mud system. SACK BLACK shale inhibitor is ~80% non-soluble in water and therefore remains in a particulate

Advantages phase in the mud system, becoming a malleable solid that deforms as needed to seal micro fractures in shales and to reduce filtrate invasion in sands. Normal concentrations of SACK BLACK additive are in the range of 3 to 10 lb/bbl (8.6 to 28.5 kg/m3) for shale stabilizing control, and 4 to 6 lb/bbl (11.4 to 17.1 kg/m3) for high-temperature, fluid-loss control. In water- and oil-base drilling-fluid systems, SACK BLACK shale stabilizer provides the following benefits:

• Easily disperses in water • Plugs micro fractures and seals shales • Reduces HTHP fluid loss • Reduces dynamic fluid loss • Reduces torque and drag • Reduces filter-cake thickness • Stable at high temperature applications (>400° F [>204° C])

• Reduces sloughing shales • Lowers torque and drag • Reduces HTHP and dynamic filtration fluid loss • Enhances filter-cake quality Asphalt is 80% soluble in water. 4 lb/bbl (11.4 kg/m3) on API filter paper.

• Improves borehole stability • Minimizes potential differential sticking in depleted sands

Mix directly in mud system.

Gilsonite is 80% non-soluble in water. 4 lb/bbl (11.4 kg/m3) on API filter paper.

58


Untreated Gilsonite

SACK BLACK treated Gilsonite

Hydrophobic

Hydrophilic

Incapable of dispersing with water. Dispersion elapsed time: 24 hrs and counting.

Capable of dispersing with water. Dispersion elapsed time: 5 sec.

Packaging and storage SACK BLACK is packaged in 50-lb (22.7-kg), multi-walled, paper sacks. Store in a dry location away from sources of heat or ignition, and minimize dust.

Gilsonite is mined only in eastern Utah. The all-natural mineral is environmentally safe.




59

A L P I N E

S P E C I A L T Y

C H E M I C A L S

ALPINE TRACER BEADS ALPINE TRACER BEADS* deepwater cement identifier is a one-sack mixture of different-sized macroporous, translucent spheres designed to refract light. TRACER BEADS spheres allow recognition of lead cement and spacers in deepwater applications where the required volumes of cement and spacers cannot be determined except through visual identification. The unique property of TRACER BEADS additive allows visual confirmation when bottoms up has occurred at the sea floor. TRACER BEADS material is inert and has no effect on mud properties. The product can be used in all types of fluids, including cement and cement spacers.

Advantages • Extremely visible with ROV

Typical physical properties

60

Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Translucent spheres

• Allows positive identification of cement returns

Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.60 to 0.90

• Minimizes excess cement

Solubility in water . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Insoluble

• No effect on mud properties

Applications


TRACER BEADS additive is designed to refract light and is used in deepwater applications where intervals have been drilled without returns and annular volumes are unknown. Typically, an unspecified amount of cement and spacers is prepared and pumped, and the only method of assuring cement returns around the casing is by viewing the operation with a Remotely Operated Vehicle (ROV) and trying to discern differences between the mud and the cement that is displacing the mud out of the hole. When TRACER BEADS additive is mixed in the cement or the cement spacers, the ROV can distinguish the difference in the fluids because the TRACER BEADS material refracts light, allowing visual confirmation of cement returns to the sea floor.



Actual photo of ALPINE TRACER BEADS in mud pill.

TRACER BEADS material can be added to cement, cement spacers, and drilling fluids of all types. Recommended concentration is 1.75 to 2 sacks per barrel, and can be mixed through the mud hopper.

TRACER BEADS additive is packaged in 1.11 ft3 (0.03 m3), multi-walled, paper sacks. Weight per bag is variable due to variation in product specific gravity. Store in a dry location away from sources of heat or ignition, and minimize dust.


M-I SWACO* customers are pushing the limits of performance, drilling depths, well complexity and field productivity. As they face challenges such as oil sands and SAGD drilling, they are also contending with stricter environmental regulations. This is where our talent for innovation has helped so many operators. Because we have our own R&D, manufacturing, environmental and technical resources, we can create solutions that solve very specific problems in an environmentally responsible manner.

©2007 M-I L.L.C. All rights reserved. *Mark of M-I L.L.C.

www.miswaco.com


Our flexibility to innovate helps our customers succeed

61

H D D

M I N I N G

A N D

W A T E R W E L L :

N E W - T E C H N O L O G Y

D R I L L I N G

DRILPLEX HDD A specialty product used to enhance the gel strengths of MAX GEL* viscosifier, DRILPLEX* HDD viscosifier is an inorganic chemical viscosifier for waterbase, bentonite drilling fluids. DRILPLEX HDD viscosifier is only slightly soluble in water.

Applications DRILPLEX HDD viscosifier allows the formulation of fluids with exceptional shear-thinning properties, resulting in a drilling fluid with both excellent dynamic and static carrying capacity for solids. This is indicated by high yieldpoint and low plastic-viscosity readings. When not circulating, the mud instantly reverts to a gelled state and results in high suspending capacity indicated by high, non-progressive gel-strength readings. For 300 gal (1,136 L) of drilling fluid mix: • Add 1½ sacks (75 lb [34 kg]) MAX GEL viscosifier in freshwater and hydrate for 10 min. If higher rheological properties are desired, mix more gel. For every 7 lb (3.2 kg) of additional gel added, the yield point rises approximately 20 points.

62

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Off-white powder Odor. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . None Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.8 to 3.1

• After the gel is hydrated, add 6 lb (2.7 kg) of DRILPLEX HDD (3 vis cups) viscosifier and mix for an additional 5 to 10 min • For torque reduction, add 1.5 gal (5.7 L) of ROD EASE* lubricant

Advantages • High rate of penetration • Optimum cuttings transport • Excellent solids suspension • Borehole stabilization • Low drilling costs

Limitations DRILPLEX HDD fluids are not compatible with anionic products. Do not add any polymers or thinners to this fluid. Polymers and thinners destroy the rheological properties of the fluid. DRILPLEX HDD fluid should only be used to enhance a bentonite-base fluid. The mixing

tank must be clean before being used to mix DRILPLEX HDD fluid.


Packaging and storage DRILPLEX HDD viscosifier comes in 25-lb (11.3-kg) multi-walled, paper sacks with 80 sacks to a pallet. Store in a dry location away from sources of heat or ignition, and minimize dust.

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

DUO-VIS/SUPER-VIS DUO-VIS*/SUPER-VIS* xanthan gum is a high-molecular-weight biopolymer used for increasing carrying capacity in water-base systems. DUO-VIS/SUPER-VIS biopolymer has the unique ability to produce a fluid that is highly shear-thinning and thixotropic.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cream-to-tan powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.5 Bulk density. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50 lb/ft3 (800 kg/m3)

Advantages

The primary function of DUO-VIS/ SUPER-VIS biopolymer is to increase low-shear viscosity for cuttings transport and suspension. This product performs effectively in all water-base fluids, from highly weighted to low-solids systems, including freshwater, seawater, salt and heavy-brine systems. DUO-VIS/SUPER-VIS xanthan gum works to provide an optimized rheological profile with elevated low-shear-rate viscosity and highly shear-thinning characteristics with low “n” values. These characteristics frequently result in fluids with inverted flow properties (i.e., the yield point is greater than the plastic viscosity). Shear-thinning fluids have low effective viscosities at the high shear rates encountered inside the drillstring and at the bit. This low effective viscosity for minimal pressure losses and standpipe pressures allows optimized hydraulics and maximized rates of penetration. Conversely, at the low shear rates experienced in the annulus, the DUO-VIS/SUPER-VIS product enables the drilling fluid to have a high effective viscosity for adequately cleaning the well and suspending cuttings.

• Highly effective suspension enhancer; small treatments produce significant results • Provides a shear-thinning rheological profile for improved hydraulics • Minimum frictional pressure losses for additional hydraulic horsepower at the bit and low, high-shear-rate viscosity for maximum penetration rates • Viscous laminar flow in the annulus for improved wellbore stability with maximum hole-cleaning and suspension capacity • Easy to mix

Limitations • Trivalent ions such as chromium and iron can cause biopolymer precipitation and loss of viscosity or cross-linking • DUO-VIS/SUPER-VIS systems should be pretreated with either sodium bicarbonate or SAPP, and possibly citric acid, prior to drilling cement • Subject to bacterial degradation; a biocide should be used to prevent fermentation if used for prolonged periods

• Lightly anionic nature of DUO-VIS/ SUPER-VIS biopolymer requires special mixing procedures when mixed with cationic materials


Packaging and storage DUO-VIS product is packaged in 25-lb (11.3-kg) sacks. SUPER-VIS product is packaged in 2-gal (7.6-L) buckets (12.5-lb [5.7-kg] per bucket). The product can also be packaged in 15- to 21-lb (6.8 to 9.5 kg) baggies per 5-gal (18.9-L) bucket. Store in a well-ventilated area away from sources of heat or ignition. For more information, please request a product bulletin from your M-I SWACO representative.


Applications


H D D

63

H D D

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

MAX BORE HDD The MAX BORE* HDD system is a proprietary, blended, high-yielding Wyoming bentonite supplied as a single-sack product used especially in boring-fluid applications. The MAX BORE HDD system provides suspension, wellbore stability and filtration control. The system also helps reduce torque and drag for water-base applications and is designed to minimize environmental impact.

Applications The MAX BORE HDD system provides suspension, improves wellbore stability, controls filtration, and helps reduce torque and drag in boringfluid applications. It is a costeffective product for achieving viscosity for hole cleaning, gel strength for cuttings suspension and transport, wellbore stability, fluid-loss control, and filter-cake quality in freshwater and seawater applications. Typical concentrations of the MAX BORE HDD system range from 15 to 45 lb/100 gal (18 to 54 kg/m3).

Typical physical properties Physical appearance. . . . . . . . . . . . . . . . . . . . . . Light tan/gray-green powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.3 to 2.6 Bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . 48 to 52 lb/ft3 (769 to 833 kg/m3)

• Hydrates more than other types of clays and is best for generating viscosity for hole cleaning, developing gels for suspension and controlling filtration • Unique size, shape and high surface area provide superior filtration characteristics • Provides lubricity and wellbore stability for ease of drilling and stability of water-sensitive clays and shales • Non-toxic and environmentally safe

Limitations


Packaging and storage The MAX BORE HDD system is packaged in 50-lb (22.7-kg) multi-walled sacks, 56 per pallet. Store in a well-ventilated area away from sources of heat or ignition.

Performance is reduced in salty (>10,000 mg/L Cl–) or hard (>240 mg/L Ca++) waters due to decreased hydration.

Advantages • One-sack system provides ease of mixing and reduces the number of products required to prepare boring fluid

64

Typical Amounts of MAX BORE HDD Additions Added to Freshwater Drilling application/desired results Normal drilling Clay environments Gravel/rock/cobble

lb/100 gal 20 – 25 10 – 15 25 – 30

lb/bbl 8.5 – 10 4–6 10 – 13

kg/m3 25 – 29 12 – 18 29 – 37

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

MAX GEL MAX GEL* viscosifier is a premium 220-bbl yield Wyoming bentonite blended with special extenders, capable of yielding more than twice as much viscosity as regular Wyoming bentonite. MAX GEL viscosifier is an easily mixed, superior Wyoming sodium bentonite for freshwater drilling and boring applications.

Applications MAX GEL viscosifier is used in the following applications to rapidly build mud viscosity and provide superior hole cleaning, as well as to help control lost circulation, formation sloughing and promote hole stability in unconsolidated formations: • Potable-water wells • Mineral exploration (coring and rotary drilling) • Horizontal directional drilling • Blast holes • Shaft drilling • Monitor/observation wells • Gel-foam, air-drilling applications

Advantages • Yields more quickly than API-standard bentonite

• Higher penetration rates than regular bentonite systems due to lower solids content

Typical physical properties Physical appearance. . . . . . . . . . . . . . . . . . . . . . Light tan/gray-green powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.3 to 2.5 Approximate yield . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 220 bbl/ton

• Reduced transportation and storage costs as a result of less product required for treatment

described in the Material Safety Data Sheet (MSDS).

• Finer grind to enable rapid mixing


Limitations Loses effectiveness in water containing >7,500 mg/L sodium chloride/240 mg/L calcium. If dispersants or thinners are to be used, they should be added sparingly, using 50% or less of the normal treatment.


MAX GEL bentonite is packaged in 50-lb (22.7-kg), multi-walled, paper sacks and is available in bulk. Store in a dry location (slip hazard when wet) and minimize dust (use dustless systems for handling, storage and cleanup). Material can be palletized at either 56 sacks/pallet or 70 sacks/pallet. Store in a well-ventilated area away from sources of heat or ignition.

Bioassay information is available upon request. Handle as an industrial chemical, wearing protective equipment and observing the precautions as

Typical Amounts of MAX GEL Additions Added to Freshwater Drilling application/desired results Normal drilling In gravel or other poorly consolidated formation Lost-circulation control Added to freshwater mud to improve hole-cleaning properties, increase hole stability and develop filter cakes

lb/100 gal 15 – 25

lb/bbl 6 – 11

kg/m3 15 – 30

25 – 40 35 – 45

12 – 18 15 – 20

35 – 50 40 – 45

5 – 10

2–5

6 – 14


• Non-toxic and proven suitable for use in drilling potable water wells

Certified to NSF/ANSI 60


H D D

65

H D D

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

POLYPAC R POLYPAC* R polyanionic cellulose is a high-quality, water-soluble polymer designed to control fluid loss and increase viscosity in water-base muds.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . White, free-flowing powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.5 to 1.6 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 8.0

Applications POLYPAC R additive controls fluid loss in freshwater, seawater, KCl and salt muds. The polymer forms a thin, resilient, low-permeability filter cake that minimizes the potential for differential sticking and the invasion of filtrate and mud solids into permeable formations. POLYPAC R fluid-loss-control additive resists bacterial attack, eliminating the need for biocides or preservatives. It is effective in low concentrations, with the normal fluid-loss treatment ranging from 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). POLYPAC R polymer also develops viscosity to a degree that is dependent on the solids concentration, salinity and makeup water chemistry. POLYPAC R anionic polymer attaches to and encapsulates exposed shales and drill cuttings. This protective polymer “envelope” inhibits the dispersion of shale cuttings and restricts fluid interactions with exposed shales.

66

Advantages • Effective in low concentrations for controlling fluid loss and building viscosity • Encapsulates shale particles to inhibit swelling and dispersion • Resists bacterial attack, requiring no biocides or preservatives • Functions over a wide range of salinity, hardness and pH levels • Applicable in all water-base muds, ranging from low-solids, non-dispersed polymer systems to high-density, dispersed systems • Compatible with all common mud-treating additives • Excellent environmental acceptability

Limitations • Circulating temperature stability of approximately 300° F (149° C)

• Effective in systems with total hardness <1,000 mg/L (as calcium), but can be precipitated in the combined presence of high hardness and high pH


Packaging and storage POLYPAC R anionic polymer is packaged in 50-lb (22.7-kg) and 55-lb (25-kg), heavy-duty, multi-walled, waterproof sacks. Store in a dry, well-ventilated area away from incompatibles or sources of heat or ignition.

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

POLYPAC UL POLYPAC* UL Polyanionic Cellulose (PAC) is a high-quality, watersoluble polymer designed to control fluid loss. Because it is an Ultra-Low (UL) additive, it causes minimal increase in viscosity in water-base muds.

Applications

Physical appearance . . . . . . . . . . . . . . . . . . . . . . . White, free-flowing powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.5 to 1.6 pH (1% solubility). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 8.0

This protective polymer “envelope” helps inhibit the dispersion of shale cuttings and restricts fluid interactions with exposed shales. In saturated salt systems, POLYPAC UL additive tends to work significantly better than regular-viscosity PAC materials. For difficult filtration-control fluids, a combination of UL and regularviscosity PAC products is generally more effective.

• Excellent environmental acceptability

Advantages


• Effective in low concentrations for controlling fluid loss and building viscosity


• Produces minimal viscosity increase • Encapsulates shale particles to inhibit swelling and dispersion • Resists bacterial attack, requiring no biocides or preservatives • Functions over a wide range of salinity, hardness and pH levels • Has application in all waterbase muds (compatible with all common mud-treating additives)

Limitations • Circulating temperature stability to approximately 300° F (149° C) • Effective in systems with total hardness <1,000 mg/L (as calcium), but can be precipitated in the combined presence of high hardness and high pH

Packaging and storage POLYPAC UL polymer is packaged in 50-lb (22.7-kg) and 55-lb (25-kg), heavy-duty, multi-walled, waterproof sacks. Store in a cool, dry place.


POLYPAC UL polymer controls fluid loss in freshwater, seawater, KCl, and salt muds. It forms a thin, resilient, low-permeability filter cake that minimizes the potential for differential sticking and the invasion of filtrate and mud solids into permeable formations. POLYPAC UL additive resists bacterial attack, eliminating the need for biocides or preservatives. It is effective in low concentrations, with the normal fluid-loss treatment ranging from 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). In saltwater and PAC-polymer systems, higher concentrations are required for encapsulation, with normal concentrations ranging from 1 to 3 lb/bbl (2.85 to 8.6 kg/m3). POLYPAC UL additive generates less viscosity than regular POLYPAC polymer. The viscosity generated depends on solids concentration, salinity, and makeup-water chemistry. The anionic POLYPAC UL polymer attaches to and encapsulates exposed shales and drill cuttings.



H D D

67

H D D

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

ROD EASE This product is a superior lubricant for HDD, coring, and rotary drilling.

Applications ROD EASE* lubricant mixes instantly and is not affected by water quality. For this product to deliver rod protection and reduce torque after drilling has started, consideration must be given to the number of rods and the amount of fluid in the hole. Treatment can require dosing the system with several pails of lubricant. Established maintenance levels are required after initial dosage and treatment. Normal treatment levels are 1 to 2% of fluid volume or 1 to 2 pints (0.473 to 0.946 L) per 100 gal (378.5 L) of drilling fluid. The dosage amount should be increased if the penetration rate decreases, torque increases, or the run length decreases indicating poor cutting.

Advantages • Reduces torque • Prevents rust and scale • Environmentally safe • Increases penetration rates • Extends bit and mud motor life • Increases mud motor efficiency • Reduces wear on rods and equipment

68

Typical physical properties Physical appearance. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Dark brown liquid Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.887 pH. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.0 to 7.5 Boiling point. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 572° F (>300° C) Freezing point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . –77° F (–25° C) Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 554° F (290° C)

• Maximizes rig potential and steering control • Enhances the effectiveness of powdered drilling-fluid additives ROD EASE lubricant is based on an environmentally safe technology that has proven effective in lubricating downhole consumables. This product has produced both bit-life and penetration increases of more than 25% during drilling operations. Because ROD EASE lubricant reduces torque and drag, the operator can use the drill rig to its full potential, meaning thrusts and pulls are at a minimum, and steering control is precise. Tests performed in the M-I SWACO laboratory in Houston confirm the effects of ROD EASE lubricant.

Limitations None.


Packaging and storage ROD EASE lubricant is packaged in 5-gal (18.9-L) buckets and 55-gal (208.2-L) drums. Store in a well-ventilated area away from sources of heat or ignition.

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

PLATINUM PAC PLATINUM PAC* polyanionic cellulose is a readily dispersible, watersoluble polymer designed to control fluid loss in water-base muds.


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . White or off-white powder Ionic character. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Anionic

Applications

Bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.64 to 9.0 g/cm3

PLATINUM PAC polyanionic cellulose is effective in low concentrations, with the normal fluid-loss treatment ranging from 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). This product is applicable in all water-base muds, ranging from low-solids, non-dispersed polymer systems to high-density, dispersed systems. It is used as a filtrate reducer and borehole stabilizer in water-base drilling applications.

pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 9.0

• Effective in low concentrations for controlling fluid loss


• Functions over a wide range of salinity, hardness and pH levels


Advantages

• Compatible with all common mud-treating additives


• Controls fluid loss and produces a thin, slick, tough filter cake

Limitations

• Inhibits the hydration of drill solids and encapsulates the drill solids for easier removal • Exhibits superior mixing in low-shear environments • Is more readily dispersible than conventional dry PAC polymers

• Encapsulates shale particles to inhibit swelling and dispersion • Resists bacterial attack, requiring no biocides or preservatives

• Circulating temperature stability to approximately 300° F (149° C) • Effective in systems with total hardness <1,000 mg/L (as calcium), but can be precipitated in the combined presence of high hardness and high pH

PLATINUM PAC polyanionic cellulose is packaged in 2-lb (0.91-kg) bottles, 25/case, 25-lb (11.3-kg) net product in 5-gal (18.9-L) buckets, and 50-lb (22.7-kg) bags. PLATINUM PAC additive should be stored inside under cool, dry conditions.


H D D


69

H D D

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

PLATINUM PAC UL PLATINUM PAC* UL Polyanionic Cellulose (PAC) is a high-quality, water-soluble polymer designed to control fluid loss. Because it is an “Ultra-Low” (UL) additive, it causes a minimal increase in viscosity in water-base muds. PLATINUM PAC UL additive is readily dispersible in a wide range of water-base mud systems.

Applications PLATINUM PAC UL additive controls fluid loss in freshwater, seawater, KCl, and salt muds. It forms a thin, resilient, low-permeability filter cake that minimizes the potential for differential sticking and the invasion of filtrate and mud solids into permeable formations. PLATINUM PAC UL additive resists bacterial attack, eliminating the need for biocides or preservatives. It is effective in low concentrations, with the normal fluid-loss treatment ranging from 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). In saltwater and PAC-polymer systems, higher concentrations are required for encapsulation, with normal concentrations ranging from 1 to 3 lb/bbl (2.85 to 8.6 kg/m3). Because PLATINUM PAC UL additive is low viscosity, generating less viscosity as compared to the POLYPAC* and PLATINUM PAC products. The viscosity generated depends on the solids concentration, salinity and makeup-water chemistry. PLATINUM PAC UL anionic polymer attaches to and encapsulates

70


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . White, free-flowing powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.5 to 1.6 pH (1% solubility). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 8.0

exposed shales and drill cuttings. This protective polymer “envelope” inhibits the dispersion of shale cuttings and restricts fluid interactions with exposed shales. In saturated salt systems, PLATINUM PAC UL additive tends to work significantly better than regular-viscosity PAC materials. For difficult filtration-control fluids, a combination of the UL product and regular-viscosity PAC products is generally most effective.

Advantages • Readily dispersible • Effective in low concentrations for controlling fluid loss and building viscosity • Produces minimal viscosity increase • Encapsulates shale particles to inhibit swelling and dispersion • Resists bacterial attack, requiring no biocides or preservatives • Functions over a wide range of salinity, hardness and pH levels • Has application in all water-base, low-solids, non-dispersed mud systems. Compatible with all common mud-treating additives.




Packaging and storage PLATINUM PAC UL anionic polymer is packaged with 25-lb (11.3-kg) net product in 5-gal (19-L) buckets and 50-lb (22.7-kg) bags. Store in a cool, dry place.

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

KLA-GUARD KLA-GARD* shale stabilizer reduces the swelling of sensitive shales and drill cuttings exposed to water-base drilling fluids. It inhibits shale hydration, reducing the effect of drill solids on viscosity, and it works to minimize problems such as excessive dilution rates, increased torque and drag, high surge and swab pressures, and bottomhole assembly balling. This high-quality, concentrated product has applications in a wide variety of mud systems and has such low toxicity characteristics it can be considered for offshore applications.

Applications

Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Clear, blue liquid Specific gravity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.1 pH (1% solution). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 8.5 Solubility in water @ 68° F (20° C) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100% Flash point. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >210° F (99° C) (PMCC)

penetration, interval length and reactivity of the shale. A minimum concentration of 4 lb/bbl (11.4 kg/m3) is required for the product to be effective. One lb/bbl of KLA-GARD stabilizer contributes 508 mg/L chlorides; KLA-GARD B stabilizer, a chloride-free formulation, is available. To prevent bacterial attack, a biocide should be used. KLA-GARD stabilizer works by being adsorbed onto active solids, thereby reducing their sensitivity to water. This action causes the product to be depleted from the mud system at a rate dependent on the reactivity of the formation, cuttings size and amount of hole volume drilled. A test procedure is available to monitor the approximate concentration of excess KLA-GARD stabilizer.

Advantages • Highly effective shale stabilizer • Effective at all pH levels • Environmentally acceptable • Stable at temperatures in excess of 400° F (204° C) • Reduces potential for bit balling • Reduces the amount of dilution required and the associated treatment costs • Unaffected by contaminants such as hard water, cement or CO2

Limitations • Should not be added to systems containing high concentrations

of active solids; flocculates muds with high Methylene Blue Test (MBT) values, causing excessive viscosity • Limits the hydration of all clay materials, therefore bentonite additions must be prehydrated in freshwater • Due to the interaction of KLA-GARD stabilizer with active solids and bentonite, increased attention must be given to filtration control • Product is biodegradable and requires a biocide


Packaging and storage KLA-GARD stabilizer is packaged in 55-gal (208-L) drums and 5-gal (18.9-L) cans. Store in a dry, well-ventilated area. Keep container closed. Keep away from heat, sparks and flames. Store away from incompatibles. Follow safe warehousing practices regarding palletizing, banding, shrink-wrapping and/or stacking. For more information, please request a product bulletin from your M-I SWACO representative.


KLA-GARD stabilizer should be specified for applications where additional inhibition is needed as an alternative to gyp, lime and potassium systems. It can improve the inhibition of water-base fluids to a level that competes with oil-base muds for many applications. Due to the powerful effect KLA-GARD stabilizer has on active solids, it should only be added to: mud systems containing low concentrations of active solids, bentonite-free systems or freshly prepared low-solids systems containing a minimum amount of prehydrated bentonite. These systems should have a methylene blue capacity of less than 12.5 lb/bbl (35.6 kg/m3) with 2 to 5 lb/bbl (5.7 to 14.3 kg/m3) of prehydrated bentonite for filtration control. KLA-GARD stabilizer is compatible with most drilling-fluid additives, and is especially suited for use in freshly prepared, low-solids polymer systems such as the POLY-PLUS* system. It is most effective when the use of organic thinners, such as SPERSENE* lignosulfonate, is minimized. Normal concentrations of KLA-GARD stabilizer range from 4 to 8 lb/bbl (11.4 to 22.8 kg/m3) depending on hole size, rate of



H D D

71

H D D

M I N I N G

A N D

W A T E R W E L L :


D R I L L I N G

FLO-PLEX FLO-PLEX fluid-loss-control agent is a polysaccharide derivative used to control filtration in the DRILPLEX system at recommended concentrations. FLO-PLEX additive will not destroy the low-end rheology of the DRILPLEX system as observed with conventional anionic fluid-losscontrol agents such as CMC and PAC. FLO-PLEX additive is effective in seawater fluids, but all hardness should be treated out before adding the FLO-PLEX product. FLO-PLEX agent may be used in any other type of fluid where starches and cellulosic additives are permitted. The temperature stability of FLO-PLEX agent is about 250° F (120° C), but may be extended to 300° F (149° C) by the addition of a thermal stability agent such as PTS-200* additive. FLO-PLEX additive is resistant to bacterial degradation.

Applications Traditional fluid-loss additives tend to destroy the high-end rheology that makes the DRILPLEX system unique. Conventional anionic fluid-loss agents will thin the DRILPLEX system. Therefore, a separate additive was developed to provide fluid-loss control without lowering the yieldpoint value and breaking the cross-links. FLO-PLEX fluid-losscontrol additive, a polysaccharide

72

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . White powder pH (4% water) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9.5 to 10.5 Solubility in water . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Soluble Bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . 35 to 40 lb/ft3 (560 to 640 kg/m3)

derivative, is very effective in the DRILPLEX system. When preparing new fluid, FLO-PLEX agent should be added at concentrations no less than 3.5 lb/bbl (9.8 kg/m3), if fluid-loss control is required. Lower concentrations can cause loss of rheology. Treatment levels can be increased to 4.5 to 5 lb/bbl (12.8 to 14.3 kg/m3) as required to maintain low filtration rates. Hardness in the seawater should be treated out. FLO-PLEX additive can be used in other water-base systems, and it will not be degraded by the action of bacteria.

Advantages • Specially designed as the fluid-loss-control agent for the DRILPLEX system • Performs in other water-base systems • Resistant to attack from bacteria

• Temperature limits may be increased to 300° F (149° C) by using thermal-extension additives

Limitations • Water hardness must be removed • Ineffective in high levels of magnesium


Packaging and storage FLO-PLEX additive is packaged in 50-lb (22.7-kg) multi-walled, paper sacks. Store in a dry location away from sources of heat or ignition, and minimize dust.

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S

DRILPLEX HDD A specialty product used to enhance the gel strengths of MAX GEL* viscosifier, DRILPLEX* HDD viscosifier is an inorganic chemical viscosifier for waterbase, bentonite drilling fluids. DRILPLEX HDD viscosifier is only slightly soluble in water.

Applications DRILPLEX HDD viscosifier allows the formulation of fluids with exceptional shear-thinning properties, resulting in a drilling fluid with both excellent dynamic and static carrying capacity for solids. This is indicated by high yieldpoint and low plastic-viscosity readings. When not circulating, the mud instantly reverts to a gelled state and results in high suspending capacity indicated by high, non-progressive gel-strength readings. For 300 gal (1,136 L) of drilling fluid mix: • Add 1½ sacks (75 lb [34 kg]) MAX GEL viscosifier in freshwater and hydrate for 10 min. If higher rheological properties are desired, mix more gel. For every 7 lb (3.2 kg) of additional gel added, the yield point rises approximately 20 points.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Off-white powder Odor. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . None Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.8 to 3.1

• After the gel is hydrated, add 6 lb (2.7 kg) of DRILPLEX HDD (3 vis cups) viscosifier and mix for an additional 5 to 10 min • For torque reduction, add 1.5 gal (5.7 L) of ROD EASE* lubricant

Advantages • High rate of penetration • Optimum cuttings transport • Excellent solids suspension • Borehole stabilization • Low drilling costs

Limitations DRILPLEX HDD fluids are not compatible with anionic products. Do not add any polymers or thinners to this fluid. Polymers and thinners destroy the rheological properties of the fluid. DRILPLEX HDD fluid should only be used to enhance a bentonite-base fluid. The mixing

tank must be clean before being used to mix DRILPLEX HDD fluid.


Packaging and storage DRILPLEX HDD viscosifier comes in 25-lb (11.3-kg) multi-walled, paper sacks with 80 sacks to a pallet. Store in a dry location away from sources of heat or ignition, and minimize dust.


H D D


73

H D D

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S

DUO-TEC DUO-TEC* additive is a dispersible, non-clarified technical-grade xanthan gum that provides viscosity, including low-shear-rate viscosity, and weight-material suspension for all water-base mud systems. DUO-TEC xanthan gum has the unique ability to produce a fluid that is highly shear-thinning and thixotropic.

Applications The primary function of DUO-TEC xanthan gum is to increase viscosity for cuttings transport and suspension. DUO-TEC xanthan gum performs effectively in all waterbase fluids, from highly weighted to low-solids systems. This includes freshwater, seawater, salt and heavy-brine systems. DUO-TEC xanthan gum works to provide an optimized rheological profile with elevated low-shear-rate viscosity and highly shear-thinning characteristics with low “n” values. These characteristics frequently result in fluids with inverted flow properties, i.e., the yield point being greater than the plastic viscosity. Shear-thinning fluids have low effective viscosities at the high shear rates encountered inside the drillstring and at the bit. This low effective viscosity for minimal pressure losses and standpipe pressures allows optimized hydraulics and maximized rates of penetration. Conversely, at the low shear rates experienced in the annulus, DUO-TEC xanthan gum enables the fluid to have a high effective viscosity for adequately cleaning the well and suspending cuttings. DUO-TEC xanthan gum should be added slowly through the hopper to prevent lumping and minimize waste. It should be added at the rate of approximately one 25-lb (11.3-kg) sack every seven minutes. The time

74


required for the product to yield its ultimate viscosity depends on salinity, temperature and shear. The amount of DUO-TEC xanthan gum required depends upon the desired viscosity. Normal concentrations range from 0.50 to 2.5 lb/bbl (1.43 to 7.1 kg/m3) for most mud systems. Special fluids and difficult hole cleaning conditions can require higher concentrations up to 4 lb/bbl (11.4 kg/m3). The addition of salt, an antioxidant and thermal stabilizers improves temperature stability in DUO-TEC fluids from 250° to 280° F (121° to 138°C). Specially formulated systems/pills have been used at temperatures up to 400° F (204° C). DUO-TEC xanthan gum is subject to bacterial degradation, and treatments with a biocide are recommended to prevent fermentation.

Advantages • Highly effective viscosifier • Shear-thinning rheological profile for improved hydraulics • Minimum frictional pressure losses for additional hydraulic horsepower at the bit and low, high-shear-rate viscosity for maximum penetration rates • Viscous laminar flow in the annulus for improved wellbore stability with maximum hole cleaning and suspension capacity • Easy to mix

Limitations • Trivalent ions such as chromium and iron can cause biopolymer precipitation and loss of viscosity or cross-linking • Not tolerant of high pH or high calcium ion conditions • DUO-TEC systems should be pretreated with either sodium bicarbonate or SAPP and possibly citric acid prior to drilling cement • Subject to bacterial degradation, a biocide should be used to prevent fermentation. Slightly anionic nature of DUO-TEC xanthan gum requires special mixing procedures when mixed with cationic materials.


Packaging and storage DUO-TEC xanthan gum is packaged in 25-lb (11.3-kg) or 55.1-lb (25-kg), plastic-lined, multi-walled, paper sacks. Store at room temperature in a dry, well-ventilated area. Keep in original container. Keep container closed. Store away from incompatibles.

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S

DUO-VIS/SUPER-VIS DUO-VIS*/SUPER-VIS* xanthan gum is a high-molecular-weight biopolymer used for increasing carrying capacity in water-base systems. DUO-VIS/SUPER-VIS biopolymer has the unique ability to produce a fluid that is highly shear-thinning and thixotropic.


Advantages

The primary function of DUO-VIS/ SUPER-VIS biopolymer is to increase low-shear viscosity for cuttings transport and suspension. This product performs effectively in all water-base fluids, from highly weighted to low-solids systems, including freshwater, seawater, salt and heavy-brine systems. DUO-VIS/SUPER-VIS xanthan gum works to provide an optimized rheological profile with elevated low-shear-rate viscosity and highly shear-thinning characteristics with low “n” values. These characteristics frequently result in fluids with inverted flow properties (i.e., the yield point is greater than the plastic viscosity). Shear-thinning fluids have low effective viscosities at the high shear rates encountered inside the drillstring and at the bit. This low effective viscosity for minimal pressure losses and standpipe pressures allows optimized hydraulics and maximized rates of penetration. Conversely, at the low shear rates experienced in the annulus, the DUO-VIS/SUPER-VIS product enables the drilling fluid to have a high effective viscosity for adequately cleaning the well and suspending cuttings.

• Highly effective suspension enhancer; small treatments produce significant results • Provides a shear-thinning rheological profile for improved hydraulics • Minimum frictional pressure losses for additional hydraulic horsepower at the bit and low, high-shear-rate viscosity for maximum penetration rates • Viscous laminar flow in the annulus for improved wellbore stability with maximum hole-cleaning and suspension capacity • Easy to mix

Limitations • Trivalent ions such as chromium and iron can cause biopolymer precipitation and loss of viscosity or cross-linking • DUO-VIS/SUPER-VIS systems should be pretreated with either sodium bicarbonate or SAPP, and possibly citric acid, prior to drilling cement • Subject to bacterial degradation; a biocide should be used to prevent fermentation if used for prolonged periods

• Lightly anionic nature of DUO-VIS/ SUPER-VIS biopolymer requires special mixing procedures when mixed with cationic materials


Packaging and storage DUO-VIS product is packaged in 25-lb (11.3-kg) sacks. SUPER-VIS product is packaged in 2-gal (7.6-L) buckets (12.5-lb [5.7-kg] per bucket). The product can also be packaged in 15- to 21-lb (6.8 to 9.5 kg) baggies per 5-gal (18.9-L) bucket. Store in a well-ventilated area away from sources of heat or ignition. For more information, please request a product bulletin from your M-I SWACO representative.


Applications


H D D

75

H D D

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S

POLY-PLUS POLY-PLUS* polymer is a highmolecular-weight, anionic liquid designed to provide cuttings encapsulation and shale stabilization. POLY-PLUS additive also acts as a viscosifier, friction reducer and flocculant. POLY-PLUS polymer can be used in mud systems using makeup waters from freshwater to saltwater.


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . Cream colored, opaque liquid Odor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Slightly hydrocarbon Specific gravity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.07 to 1.10 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.0 to 9.0 Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >200° F (93.3° C) (PMCC) Pour point. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . –20° F (–28.9° C)

Applications POLY-PLUS polymer mud systems. The POLY-PLUS system provides excellent cuttings encapsulation and improved wellbore stability. Typical concentrations of POLY-PLUS are 0.75 to 3 lb/bbl (2.1 to 8.5 kg/m3). It is also effective in salt muds, such as KCl- or NaCl-enhanced fluids, although slightly higher concentrations of POLY-PLUS polymer may be required. Clear-water fluids. POLY-PLUS polymer can be used in clear-water, solids-free drilling fluids. The POLY-PLUS system increases viscosity and enhances solids removal by flocculating the undesired solids. It also provides cuttings encapsulation and improved wellbore stability. This system is frequently used in slim-hole, continuous-coring applications. Adding 0.5 to 1.75 lb/bbl (1.4 to 5 kg/m3) enhances solids removal by flocculating solids. Low-Solids, Non-Dispersed (LSND) muds. POLY-PLUS polymer is well suited to LSND systems. In reducedbentonite muds, POLY-PLUS additive serves as a bentonite extender to increase viscosity and as a flocculant to more efficiently remove drill solids. It also encapsulates cuttings and improves wellbore stability. Weighted muds. POLY-PLUS polymer can be used in weighted muds for cuttings encapsulation, improved wellbore stability, secondary viscosity, and improved filter-cake integrity. The effectiveness of the polymer diminishes as the

76

Viscosity (typical) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~ 500 cP

Concentration1 lb/bbl (kg/m3) 0.50 (1.4) 0.75 (2.1)

gal/bbl (L/m3) 0.056 (1.3) 0.084 (2.0)

gal/100 gal 0.133 0.200

0.110 (2.6) 0.170 (4.0)

0.262 0.405

1.00 (3.0) 1.50 (4.3) 1Based

on 30% active material

concentration of organic, anionic dispersants increases. POLY-PLUS sweeps. Viscous POLY-PLUS sweeps are effective for periodic hole cleaning. Circulating a POLY-PLUS sweep through the well or borehole helps clear accumulated cuttings and maintain a clean hole.

• Improves the lubricity of most mud systems, particularly nondispersed systems, dispersed mud, when used in combination with a lubricant • Helps prevent bit balling and balling on stabilizers and bottomhole assemblies by coating and lubricating solids

Advantages


• Provides excellent cuttings encapsulation and limits cuttings dispersion


• Provides improved shale stabilization • Enhances drill-solids removal in clear water systems and the carrying capacity of foams • Liquid product for easy mixing and rapid yield • Is versatile and multipurpose • Low pour point of –20° F (–28.9° C) for easy use in cold climates • Can be used to viscosify clearwater, low-solids drilling fluids

Packaging and storage POLY-PLUS polymer is packaged in 5-gal (18.9-L) buckets. Store in a dry location away from sources of heat or ignition, and minimize dust. For more information, please request a product bulletin from your M-I SWACO representative.

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S

POLY-PLUS LV POLY-PLUS LV acrylic co-polymer is a low-molecular-weight, mediumcharge acrylic co-polymer designed to provide cuttings encapsulation and clay-dispersion inhibition. It is designed for use in fluids based on fresh and saline water environments. POLY-PLUS LV acrylic co-polymer provides minimal viscosity increase and can enhance filtration properties. When added to MAX GEL* viscosifier or MAX BORE* HDD bentonite, POLY-PLUS LV acrylic co-polymer produces an inhibitive drilling-fluid system without affecting fluid properties.

Applications

Recommended treatment Approximate amounts of POLY-PLUS LV acrylic co-polymer added to water-base fluid.

Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . White, granular powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.7 pH (0.5 % solution). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.0 to 8.0 Solubility in water . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Soluble

Advantages




• Enhances removal of drill solids by reducing dispersion tendencies • Minimal contribution to the viscosity of the system • For use in seawater, KCl or freshwater systems • Provides improved shale stabilization • Significantly lower screenblinding potential compared to higher-molecular-weight encapsulators

Packaging and storage POLY-PLUS LV acrylic co-polymer is packaged in 27.5-lb (12.5-kg), 5-gal (18.9-L) buckets. Store in a dry location away from sources of heat or ignition, and minimize dust.

• Does not negatively affect positive rheological profiles

Limitations Makeup water should be treated with soda ash or bicarbonate to reduce hardness and increase the performance of the product.

Bentonite-free drilling fluid Added to MAX GEL* viscosifier or MAX BORE* HDD bentonite for inhibition Foam drilling (stiff foams)

lb/100 gal 0.5 to 1.5

lb/bbl 0.2 to 0.6

kg/m3 0.6 to 1.8

0.25 to 0.75 0.5 to 1.0

0.1 to 0.3 0.2 to 0.4

0.3 to 1.0 0.6 to 1.2


POLY-PLUS LV acrylic co-polymer provides excellent cuttings encapsulation by adsorbing onto the clay surfaces and forming a protective film that prevents cuttings from sticking to each other or the shaker screen. The product is also effective in seawater and KCl-based fluids. Normal dosage rates are between 1 and 3 lb/bbl (3 and 9 kg/m3). Due to the low molecular weight of this polymer, the mixing process requires less shear than polymers with higher molecular weights. The resulting fluid can pass through fine shaker screens without blinding. Recommendations: Total hardness should be treated out first with bicarbonate/soda ash. Maintain pH below 10 for optimum performance.



H D D

77

H D D

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S

POLY-PLUS RD POLY-PLUS RD acrylic co-polymer (PHPA) is a readily dispersible product designed to provide cuttings encapsulation and shale stabilization. It is formulated for easy mixing with improved dispersion to eliminate “fish eyes.” This is beneficial when rapidly mixing either large quantities or high concentrations of polymer where good mixing equipment is unavailable. POLY-PLUS RD acrylic co-polymer acts as a viscosifier, friction reducer and flocculant. It also provides some fluid-loss control. POLY-PLUS RD acrylic co-polymer is a specially treated, high-molecularweight product. It can be used in systems ranging from low solids to weighted muds, using makeup waters from freshwater to saltwater.

Applications POLY-PLUS RD acrylic co-polymer mud systems. POLY-PLUS RD additive provides excellent cuttings encapsulation and improved wellbore stability. Typical concentrations of POLY-PLUS RD acrylic co-polymer are 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). It is also effective in salt muds, such as KCl- or NaCl-enhanced fluids, although slightly higher concentrations of POLY-PLUS RD acrylic co-polymer can be required. Clear-water fluids. POLY-PLUS RD acrylic co-polymer can be used in clear-water, solids-free drilling fluids. This product enhances solids removal by flocculating the undesired solids and increasing viscosity. The polymer also provides cuttings encapsulation and

78

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . White, granular powder Odor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Slightly hydrocarbon Specific gravity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.25 to 1.40 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.7 Bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . 40 to 46 lb/ft3 (641 to 737 kg/m3) Nature of charge. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Anionic Activity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >90%

improved wellbore stability. POLY-PLUS RD acrylic co-polymer is frequently used in slim-hole, continuous-coring applications.

sweep through the well helps clear accumulated cuttings and maintain a clean hole.

Low-Solids, Non-Dispersed (LSND) muds. POLY-PLUS RD acrylic co-polymer is well suited to LSND systems. In reduced-bentonite muds, POLY-PLUS RD additive extends bentonite to increase viscosity, flocculates drill solids for more efficient removal, encapsulates cuttings and improves wellbore stability.

Addition method

POLY-PLUS RD sweeps. Viscous POLY-PLUS RD acrylic co-polymer sweeps are effective for periodic hole cleaning. Circulating a POLY-PLUS RD acrylic co-polymer

POLY-PLUS RD acrylic co-polymer can be mixed directly into the active mud system. It can also be premixed at higher concentrations in a separate pit or chemical barrel, then blended into the active system. Sweeps can be prepared by mixing POLY-PLUS RD acrylic co-polymer directly in the active system at the suction pit or by premixing a high concentration in a separate pit and allowing the polymer to fully yield before being pumped.

Typical Properties of POLY-PLUS RD in Freshwater Concentration lb/bbl (kg/m3) 0.125 (0.4) 0.25 (0.7) 0.50 (1.4) 0.75 (2.1) 1.00 (2.9) 1.50 (4.3)

PV cP 2 3 4 6 9 15

YP lb/100 ft2 1 2 4 8 11 17

Marsh Funnel sec/qt 28 31 34 46 60 110

• Readily dispersible and does not form “fish eyes” • Excellent cuttings encapsulator limits cuttings dispersion • Provides improved shale stabilization • Powdered material has significantly lower toxicity than invert-emulsion, liquid polymers • Highly concentrated product (>90% activity) reduces transportation costs and storage space requirements • Aids in preventing balling on the bit, stabilizers and bottomhole assembly by coating and lubricating solids • Enhances removal of drill solids • Can be used to viscosify clearwater and low-solids drilling fluids

Limitations • Severe flocculation can occur during the initial treatment of POLY-PLUS RD acrylic co-polymer in a non-dispersed mud system. Flocculation causes high viscosity until all of the solids are coated. POLY-PLUS RD acrylic co-polymer

mud systems use low concentrations (<15 lb/bbl [<43 kg/m3]) of MAX GEL viscosifier to reduce this interaction. Continued additions of POLY-PLUS RD polymer result in a stable system with the desired rheology. • Calcium-sensitive — begins to precipitate when the calcium concentration exceeds 300 mg/L. • pH-sensitive with an optimum pH range of 8.5 to 10.5. At levels above this range, hydrolysis can convert acrylamide into acrylate and release ammonia (NH3). • Temperature-stable to approximately 350° F (177° C), although the co-polymer can begin to release ammonia (NH3) and hydrolyze into polyacrylate when exposed to prolonged temperatures above 275° F (135° C) • Subject to shear degradation of its viscosity and can lose its ability to viscosify. Cuttings encapsulation and shale stabilization are not affected.

Contamination POLY-PLUS RD acrylic co-polymer reacts with multivalent cations such

as calcium. In concentrations greater than 300 mg/L, calcium causes the polymer to precipitate. Use soda ash to remove calcium concentrations above 300 mg/L. Treat cement contamination to keep the calcium and pH as low as possible. Use sodium bicarbonate along with a pH-reducing product like lignite or citric acid to treat cement contamination.

Toxicity and handling Bioassay information available upon request. No special requirements are necessary for handling and storage. Avoid inhalation of dust. A dust respirator and goggles are recommended if mixing in an enclosed area.

Packaging and storage POLY-PLUS RD acrylic co-polymer is packaged in 50-lb (22.7-kg), multiwalled, paper sacks or 5-gal (18.9-L) buckets. Store in a dry location away from sources of heat or ignition, and minimize dust.


Advantages


79

H D D

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S




Applications



pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 9.0




Advantages




Limitations


80

• Effective in low concentrations for controlling fluid loss • Encapsulates shale particles to inhibit swelling and dispersion • Resists bacterial attack, requiring no biocides or preservatives



M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S


Applications









PLATINUM PAC UL additive controls fluid loss in freshwater, seawater, KCl, and salt muds. It forms a thin, resilient, low-permeability filter cake that minimizes the potential for differential sticking and the invasion of filtrate and mud solids into permeable formations. PLATINUM PAC UL additive resists bacterial attack, eliminating the need for biocides or preservatives. It is effective in low concentrations, with the normal fluid-loss treatment ranging from 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). In saltwater and PAC-polymer systems, higher concentrations are required for encapsulation, with normal concentrations ranging from 1 to 3 lb/bbl (2.85 to 8.6 kg/m3). Because PLATINUM PAC UL additive is low viscosity, generating less viscosity as compared to the POLYPAC* and PLATINUM PAC products. The viscosity generated depends on the solids concentration, salinity and makeup-water chemistry. PLATINUM PAC UL anionic polymer attaches to and encapsulates



H D D

81

H D D

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S

PLATINUM D-D PLATINUM D-D* additive is an aqueous blend of surface-active agents. It is designed to reduce the surface tension of all water-base mud systems and reduce the sticking tendency of water-sensitive shale cuttings.

Applications PLATINUM D-D additive has application in all drilling areas and can be used in virtually any water-base drilling fluid. It is used primarily in upper-hole drilling to minimize bit and Bottomhole Assembly (BHA) balling, reduce surface tension, and aid in dropping sand and removing drill solids. PLATINUM D-D additive frequently reduces torque and drag, even when no oil is present in the system. Normal treatments range from 0.1 to 0.2 lb/bbl (0.29 to 0.57 kg/m3) and provide satisfactory performance under most conditions. In severe gumbo shale areas, 4 to 6 lb/bbl (11.4 to 17.1 kg/m3) concentrations of PLATINUM D-D additive are recommended to minimize bit and BHA balling; higher concentrations can cause foaming and require a defoamer. This product is effective in all water-base systems including freshwater, brackish

82

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Light red liquid Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.038 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.5 to 8.5 Solubility in water . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100% Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >200° F (>93° C)

water, seawater and saturated saltwater fluids.

Advantages • Minimizes bit and BHA balling • Reduces the surface tension of the liquid phase, helping to drop sand and remove drill solids • Improves water-wetting action on all solids and reduces the sticking tendency of reactive shale cuttings • Effective in all water-base muds

Limitations The freezing point of PLATINUM D-D additive is 32° F (0° C). D-D CWT additive, a special cold-weather formulation with a freezing point of –29° F (–20° C), is also available.

Toxicity and handling Bioassay information is available upon request. Handle as an industrial chemical, wearing protective equipment and observing the precautions as described in the Material Safety Data Sheet (MSDS). Fluids containing high concentrations of PLATINUM D-D additive may not be suitable for discharge into all marine environments.

Packaging and storage PLATINUM D-D liquid is packaged in 5-gal (18.9-L) cans and 55-gal (208.2-L) drums. Store in a well-ventilated area away from sources of heat or ignition.

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S

MAX BORE HDD The MAX BORE* HDD system is a proprietary, blended, high-yielding Wyoming bentonite supplied as a single-sack product used especially in boring-fluid applications. The MAX BORE HDD system provides suspension, wellbore stability and filtration control. The system also helps reduce torque and drag for water-base applications and is designed to minimize environmental impact.

Applications The MAX BORE HDD system provides suspension, improves wellbore stability, controls filtration, and helps reduce torque and drag in boringfluid applications. It is a costeffective product for achieving viscosity for hole cleaning, gel strength for cuttings suspension and transport, wellbore stability, fluid-loss control, and filter-cake quality in freshwater and seawater applications. Typical concentrations of the MAX BORE HDD system range from 15 to 45 lb/100 gal (18 to 54 kg/m3).

Advantages

Physical appearance. . . . . . . . . . . . . . . . . . . . . . Light tan/gray-green powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.3 to 2.6 Bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . 48 to 52 lb/ft3 (769 to 833 kg/m3)

• Hydrates more than other types of clays and is best for generating viscosity for hole cleaning, developing gels for suspension and controlling filtration • Unique size, shape and high surface area provide superior filtration characteristics • Provides lubricity and wellbore stability for ease of drilling and stability of water-sensitive clays and shales • Non-toxic and environmentally safe

Limitations Performance is reduced in salty (>10,000 mg/L Cl–) or hard

(>240 mg/L Ca++) waters due to decreased hydration.


Packaging and storage The MAX BORE HDD system is packaged in 50-lb (22.7-kg) multi-walled sacks, 56 per pallet. Store in a well-ventilated area away from sources of heat or ignition.

Typical Amounts of MAX BORE HDD Additions Added to Freshwater Drilling application/desired results Normal drilling Clay environments Gravel/rock/cobble

lb/100 gal 20 – 25 10 – 15 25 – 30

lb/bbl 8.5 – 10 4–6 10 – 13

kg/m3 25 – 29 12 – 18 29 – 37


• One-sack system provides ease of mixing and reduces the number of products required to prepare boring fluid



H D D

83

H D D

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S



Advantages • Yields more quickly than API-standard bentonite • Non-toxic and proven suitable for use in drilling potable water wells • Higher penetration rates than regular bentonite systems due to lower solids content

84












lb/100 gal 15 – 25

lb/bbl 6 – 11

kg/m3 15 – 30

25 – 40 35 – 45

12 – 18 15 – 20

35 – 50 40 – 45

5 – 10

2–5

6 – 14

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S






Limitations None.




H D D


85

H D D

M I N I N G

A N D

W A T E R W E L L :

H D D

P R O D U C T S

Lost-Circulation Materials (LCM) Cedar Fiber Cedar Fiber is a specially processed blend of fibers of controlled length, giving proper size distribution for regaining circulation. • Non-fermenting • Amounts used vary from 1 to 35% by volume

Packaging and storage Cedar Fiber is packaged in 40-lb (18-kg) bags.

directly to the pits and gunned into the mud. The most important aspect of combating lost circulation is using the correct particle size. Consequently, it is recommended that a combination of materials be added to ensure a good particle-size distribution. If left in the mud for an extended period of time, drilling paper may be susceptible to bacterial degradation. A bactericide may be necessary to prevent fermentation.

Packaging and storage Mica Mica is a selected, non-abrasive mineral available in fine and coarse grades. Mica has no adverse effect on mud properties. It is used to prevent and regain lost returns. Fine mica can pass through a 20-mesh screen.

Application • Lost circulation: 5 to 15 lb (2.25 to 6.75 kg)

Packaging and storage Mica is packaged in 50-lb (22.68-kg) sacks.

Drilling Paper Drilling paper is a blend of variable-sized particles of ground paper that is applicable for use in all water-base mud systems. Drilling paper can be used in concentrations of up to 20 lb/bbl (57 kg/m3) in slug treatments or as an additive to the entire system. In areas of known lost-circulation zones, it is advisable to pretreat the system before drilling into the zone of loss. Drilling paper can be mixed through the mud hopper or added

86

Drilling paper is packaged in 40-lb (18-kg) plastic sacks.

Cottonseed Hulls Cottonseed hulls are fibrous and biodegradable, creating an excellent bridging agent when large-particlesize material is needed. They can be used in any water-base mud system. Cottonseed hulls are used in concentrations of up to 20 lb/bbl (57 kg/m3) as slug treatments or as an additive to the entire system. In areas of known lost-circulation zones, it is advisable to pretreat the system before drilling into the zone of loss. Cottonseed hulls can be mixed through the mud hopper or added directly to the pits and gunned into the mud. The most important aspect of combating lost circulation is using the correct particle size. Consequently, it is recommended that a combination of materials be added to ensure a good particle-size distribution. If left in the mud for an extended period of time, cottonseed hulls can be susceptible to bacterial degradation, resulting in the release of H2S and CO2 into the mud. Bactericide may be necessary to prevent fermentation.

Packaging and storage Cottonseed hulls are packaged in 50-lb (22.68-kg) and 100-lb (45.37-kg) burlap or paper sacks.

FED-SEAL FED-SEAL* lost-circulation material is an engineered product that contains an optimum blend of granular, fibrous and flake materials. FED-SEAL LCM is available in three grinds (coarse, medium and fine) covering a wide range of lostcirculation problems. FED-SEAL additive is normally recommended in concentrations of 20 to 30 lb/bbl (57 to 86 kg/m3) mixed in a slug of 100 to 200 bbl and spotted at the zone of loss, displacing the slurry at a reduced pumping rate with either large nozzles or an open-ended system. FED-SEAL LCM can be added to either the water-base mud being used at the time of loss or in any special purpose slurry prepared for squeeze applications. The FED-SEAL product has been used for preventive measures or as a “filler” because the fine grade can pass through 20-mesh shaker screens in concentrations of 2 to 10 lb/bbl (6 to 28 kg/m3).

Limitations Do not mix in oil muds.

Toxicity and handling Bioassay information is available upon request.

Packaging and storage FED-SEAL LCM is packaged in 40-lb (18-kg) multi-walled, paper sacks.

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S















lb/100 gal 15 – 25

lb/bbl 6 – 11

kg/m3 15 – 30

25 – 40 35 – 45

12 – 18 15 – 20

35 – 50 40 – 45

5 – 10

2–5

6 – 14





H D D

87

H D D

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S




Applications



pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 9.0




Advantages




Limitations


88




M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S

POLY-PLUS 2000 POLY-PLUS 2000 polymer is a multifunction synthetic co-polymer developed for use in freshwater-, potassium- and saltwater-base drilling fluids. POLY-PLUS 2000 water-free dispersion has excellent freeze/thaw stability and is not subject to phase separation or premature activation inside the pail or drum. POLY-PLUS 2000 co-polymer provides the same benefits as regular POLY-PLUS polymer, but at lower concentration.

Applications Viscosity. POLY-PLUS 2000 co-polymer is a cost-effective viscosifier in lowsalinity fluids. Its shear-thinning properties maximize penetration rates at the bit under high shear rates and exhibit excellent holecleaning characteristics under low shear rates. It also allows for easy solids deposition in settling pits. Shale stabilization/inhibition. POLY-PLUS 2000 co-polymer can be used alone or in conjunction with KCl to stabilize active shales. It protects by encapsulating reactive shales, forming a protective coating on the wellbore and around cuttings. Coating reduces the shale’s tendency to absorb water, swell and slough.

Flowline flocculant. Small concentrations of POLY-PLUS 2000 co-polymer (0.01 to 0.05 lb/bbl [0.028 to 0.14 kg/m3]) economically flocculate drill solids. Additions should be made at the flowline to optimize settling time of drill solids in the pits. Friction reduction/lubrication. The POLY-PLUS 2000 co-polymer’s shear-thinning properties reduce power losses at points of high shear,

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . White liquid dispersion Odor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Slightly hydrocarbon Viscosity (typical) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200 to 500 cP Specific gravity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.06 to 1.08 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 7.5 Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 248° F (120° C)

especially at the drill bit and at the other restrictions such as the pump discharge, drill collars, etc. The polymer structure also helps reduce turbulence, which reduces erosion and the likelihood of washouts in weak formations.

bleach per 100 gal (378.5 L) of fluid formulated with POLY-PLUS 2000 additive. Do not use perfumed liquid bleach or solid calcium hypochlorite.

Limitations

Foam stabilization. 1 to 2 vis cups (1 to 2 L) per 100 gal (378.5 L) of fluid.

POLY-PLUS 2000 co-polymer is less effective in fluids with total hardness values in excess of 200 ppm. To optimize POLY-PLUS 2000 co-polymer characteristics, total hardness should be maintained at 100 ppm or less. POLY-PLUS 2000 additive is not as effective in temperatures above 275° F (135° C). The effective temperature range can be increased to 325° F (162° C) by adding an oxygen scavenger to the mud. The effectiveness of POLY-PLUS 2000 additive also decreases in fluids that have a pH of 10.2 or greater.

Advantages


• 50% active material

Bioassay information available upon request. Handle as an industrial chemical, wearing protective equipment and observing the precautions as described on the Material Safety Data Sheet (MSDS).

Application Viscosity. Add 1 to 3 vis cups (1 to 3 L) per 300 gal (1,135 L) of fluid for desired viscosity. Shale inhibition. At least 1 vis cup (1 L) per 300 gal (1,135 L) of fluid. Fluid-loss control. At least 2 vis cups (2 L) per 300 gal (1,135 L) of fluid to be effective. Some solids can be required. Lubricity. At least 1 vis cup (1 L) per 300 gal (1,135 L) of fluid.

• Low dosage rate for comparable viscosities • Encapsulates drill solids • Stabilizes clay formations

Cleanup POLY-PLUS 2000 co-polymer can be chemically broken down with liquid bleach in regular household concentration (5% sodium hypochlorite). Use 5 gal (18.9 L) of liquid

Packaging and storage POLY-PLUS 2000 co-polymer is supplied in 5-gal (18.9-L) buckets.


Foam stabilization. The long-chain polymer of POLY-PLUS 2000 additive creates a tighter, stronger foam, which improves the fluid’s cuttings-carrying capacity.



H D D

89

H D D

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S

POLY-PLUS EHV POLY-PLUS EHV acrylic co-polymer is an extremely-high-molecularweight, high-charge, polyacrylamide supplied as a dry granular powder. POLY-PLUS EHV acrylic co-polymer produces very high viscosity solutions at low dosage rates, particularly in freshwater. It has excellent handling characteristics, mixes easily and dissolves quickly when added to water-base fluid systems.

Applications POLY-PLUS EHV acrylic co-polymer is ideally suited for applications such as water-well drilling, mineral exploration, and construction applications. Due to its very high molecular weight, POLY-PLUS EHV additive is also an excellent flocculant for dewatering drilling fluids, waste pits and sumps. POLY-PLUS EHV acrylic co-polymer has several functions, including: Viscosifier. As a viscosifier, the addition of 0.5 to 1 lb/bbl (1.4 to 2.9 kg/m3) of POLY-PLUS EHV acrylic co-polymer is a cost-effective way to generate viscosity in fresh- or low-salinity drilling fluids. Its shearthinning capacity ensures maximum power at the bit under high shear while retaining excellent carrying capacity under low-shear conditions. Flocculant. As a flowline flocculant, POLY-PLUS EHV acrylic co-polymer can also be used for clear-water or low-solids drilling. Adding a 5% solution of POLY-PLUS EHV acrylic co-polymer into the flowline or just prior to any mechanical separation greatly enhances the removal of drill solids. Friction reducer. Adding POLY-PLUS EHV acrylic co-polymer into a drilling fluid helps to reduce turbulent flow, friction, and power losses at points of high shear. Lowering turbulent flow also helps reduce erosion and washouts of fragile geologic structures. Add slowly and uniformly through a high-shear jet type mixer. 90


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . White, granular powder Ionic character. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Anionic Density . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.8 g/cc Bulk density. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50 lb/ft3 (800 kg/m3) pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.0 to 8.0

Continue to circulate and agitate the slurry until all materials are dispersed and dissolved. Recommended application amounts:

• Provides high cohesiveness to bind sandy soil and gravel • Enhances core recovery in continuous wireline coring operations

Normal consolidated formation:

• Facilitates the removal of drilled soils from augers

1.5 to 2 lb (0.7 to 0.9 kg) per 100 gal (378.5 L) water (0.6 to 0.8 lb/bbl [1.7 to 2.3 kg/m3])

• Non-fermenting, no petroleum distillates and easily broken down with household bleach

Unconsolidated formation: 2.5 to 3.5 lb (1.1 to 1.6 kg) per 100 gal (378.5 L) water (1 to 1.5 lb/bbl [2.9 to 4.3 kg/m3])

Advantages • Provides a clay-free boring fluid that disperses easily with minimal shear • Soil stabilizer can be used to replace bentonite at a ratio of 1:100 (e.g., one 50-lb [22.7-kg] bag can replace 2.5 tons [2.3 metric tons] of bentonite in a typical geo-construction application) • Produces very-high-viscosity slurries at low dosage rates • Slurries typically have low gel strength • Slurry binds loose sand, clay, shale and gravel, facilitating their removal and preventing dispersal into the slurry • Reduces fluid loss by penetrating the surrounding soil with a highviscosity gel fluid, sealing the walls of the excavation site without the use of a conventional filter cake • Stabilizes reactive formations and is an efficient viscosifier for a clear, solids-free drilling fluid

Cleanup POLY-PLUS EHV acrylic co-polymer can be chemically broken down with liquid bleach in regular household concentration (5% sodium hypochlorite). Use 1 gal (3.8 L) of liquid bleach per 100 gal (378.5 L) of fluid formulated with POLY-PLUS EHV acrylic co-polymer. Do not use perfumed liquid bleach or solid calcium hypochlorite.

Toxicity and handling When used in accordance with the manufacturer’s published instructions, this product is considered non-hazardous. Drill cuttings exposed to POLY-PLUS EHV acrylic co-polymer should be washed with calcium hypochlorite to break down the POLY-PLUS EHV acrylic co-polymer before the cuttings can be confined or stored in a sealed container or drum.

Packaging and storage POLY-PLUS EHV acrylic co-polymer is supplied in 5-gal (18.9-L) buckets. POLY-PLUS EHV acrylic co-polymer should be stored inside under cool, dry conditions. When stored under these conditions, it has a shelf life of at least one year.

Drilling waste · Screen costs · Transport costs · Setup · Footprint · Crane lifts

Profits · Drilling efficiency · Total performance · Safety · Project completions

about the new MEERKAT* PT shaker with reduced footprint, optional dual motion and killer economics.

www.miswaco.com ©2008 M-I L.L.C. All rights reserved. *Mark of M-I L.L.C.


INCREASE ASK


REDUCE

91

H D D

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S

POLY-PLUS RD POLY-PLUS RD acrylic co-polymer (PHPA) is a readily dispersible product designed to provide cuttings encapsulation and shale stabilization. It is formulated for easy mixing with improved dispersion to eliminate “fish eyes.” This is beneficial when rapidly mixing either large quantities or high concentrations of polymer where good mixing equipment is unavailable. POLY-PLUS RD acrylic co-polymer acts as a viscosifier, friction reducer and flocculant. It also provides some fluid-loss control. POLY-PLUS RD acrylic co-polymer is a specially treated, high-molecularweight product. It can be used in systems ranging from low solids to weighted muds, using makeup waters from freshwater to saltwater.

Applications POLY-PLUS RD acrylic co-polymer mud systems. POLY-PLUS RD additive provides excellent cuttings encapsulation and improved wellbore stability. Typical concentrations of POLY-PLUS RD acrylic co-polymer are 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). It is also effective in salt muds, such as KCl- or NaCl-enhanced fluids, although slightly higher concentrations of POLY-PLUS RD acrylic co-polymer can be required. Clear-water fluids. POLY-PLUS RD acrylic co-polymer can be used in clear-water, solids-free drilling fluids. This product enhances solids removal by flocculating the undesired solids and increasing viscosity. The polymer also provides cuttings encapsulation and

92

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . White, granular powder Odor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Slightly hydrocarbon Specific gravity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.25 to 1.40 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.7 Bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . 40 to 46 lb/ft3 (641 to 737 kg/m3) Nature of charge. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Anionic Activity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >90%

improved wellbore stability. POLY-PLUS RD acrylic co-polymer is frequently used in slim-hole, continuous-coring applications.

sweep through the well helps clear accumulated cuttings and maintain a clean hole.

Low-Solids, Non-Dispersed (LSND) muds. POLY-PLUS RD acrylic co-polymer is well suited to LSND systems. In reduced-bentonite muds, POLY-PLUS RD additive extends bentonite to increase viscosity, flocculates drill solids for more efficient removal, encapsulates cuttings and improves wellbore stability.

Addition method

POLY-PLUS RD sweeps. Viscous POLY-PLUS RD acrylic co-polymer sweeps are effective for periodic hole cleaning. Circulating a POLY-PLUS RD acrylic co-polymer

POLY-PLUS RD acrylic co-polymer can be mixed directly into the active mud system. It can also be premixed at higher concentrations in a separate pit or chemical barrel, then blended into the active system. Sweeps can be prepared by mixing POLY-PLUS RD acrylic co-polymer directly in the active system at the suction pit or by premixing a high concentration in a separate pit and allowing the polymer to fully yield before being pumped.

Typical Properties of POLY-PLUS RD in Freshwater Concentration lb/bbl (kg/m3) 0.125 (0.4) 0.25 (0.7) 0.50 (1.4) 0.75 (2.1) 1.00 (2.9) 1.50 (4.3)

PV cP 2 3 4 6 9 15

YP lb/100 ft2 1 2 4 8 11 17

Marsh Funnel sec/qt 28 31 34 46 60 110

• Readily dispersible and does not form “fish eyes” • Excellent cuttings encapsulator limits cuttings dispersion • Provides improved shale stabilization • Powdered material has significantly lower toxicity than invert-emulsion, liquid polymers • Highly concentrated product (>90% activity) reduces transportation costs and storage space requirements • Aids in preventing balling on the bit, stabilizers and bottomhole assembly by coating and lubricating solids • Enhances removal of drill solids • Can be used to viscosify clearwater and low-solids drilling fluids

Limitations • Severe flocculation can occur during the initial treatment of POLY-PLUS RD acrylic co-polymer in a non-dispersed mud system. Flocculation causes high viscosity until all of the solids are coated. POLY-PLUS RD acrylic co-polymer

mud systems use low concentrations (<15 lb/bbl [<43 kg/m3]) of MAX GEL viscosifier to reduce this interaction. Continued additions of POLY-PLUS RD polymer result in a stable system with the desired rheology. • Calcium-sensitive — begins to precipitate when the calcium concentration exceeds 300 mg/L. • pH-sensitive with an optimum pH range of 8.5 to 10.5. At levels above this range, hydrolysis can convert acrylamide into acrylate and release ammonia (NH3). • Temperature-stable to approximately 350° F (177° C), although the co-polymer can begin to release ammonia (NH3) and hydrolyze into polyacrylate when exposed to prolonged temperatures above 275° F (135° C) • Subject to shear degradation of its viscosity and can lose its ability to viscosify. Cuttings encapsulation and shale stabilization are not affected.

Contamination POLY-PLUS RD acrylic co-polymer reacts with multivalent cations such

as calcium. In concentrations greater than 300 mg/L, calcium causes the polymer to precipitate. Use soda ash to remove calcium concentrations above 300 mg/L. Treat cement contamination to keep the calcium and pH as low as possible. Use sodium bicarbonate along with a pH-reducing product like lignite or citric acid to treat cement contamination.

Toxicity and handling Bioassay information available upon request. No special requirements are necessary for handling and storage. Avoid inhalation of dust. A dust respirator and goggles are recommended if mixing in an enclosed area.

Packaging and storage POLY-PLUS RD acrylic co-polymer is packaged in 50-lb (22.7-kg), multi-walled, paper sacks or 5-gal (18.9-L) buckets. Store in a dry location away from sources of heat or ignition, and minimize dust.


Advantages


93

H D D

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S

POLYPAC R POLYPAC* R polyanionic cellulose is a high-quality, water-soluble polymer designed to control fluid loss and increase viscosity in water-base muds.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . White, free-flowing powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.5 to 1.6 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 8.0

Applications POLYPAC R additive controls fluid loss in freshwater, seawater, KCl and salt muds. The polymer forms a thin, resilient, low-permeability filter cake that minimizes the potential for differential sticking and the invasion of filtrate and mud solids into permeable formations. POLYPAC R fluid-loss-control additive resists bacterial attack, eliminating the need for biocides or preservatives. It is effective in low concentrations, with the normal fluid-loss treatment ranging from 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). POLYPAC R polymer also develops viscosity to a degree that is dependent on the solids concentration, salinity and makeup water chemistry. POLYPAC R anionic polymer attaches to and encapsulates exposed shales and drill cuttings. This protective polymer “envelope” inhibits the dispersion of shale cuttings and restricts fluid interactions with exposed shales.

94

Advantages • Effective in low concentrations for controlling fluid loss and building viscosity • Encapsulates shale particles to inhibit swelling and dispersion • Resists bacterial attack, requiring no biocides or preservatives • Functions over a wide range of salinity, hardness and pH levels • Applicable in all water-base muds, ranging from low-solids, non-dispersed polymer systems to high-density, dispersed systems • Compatible with all common mud-treating additives • Excellent environmental acceptability

Limitations • Circulating temperature stability of approximately 300° F (149° C)

• Effective in systems with total hardness <1,000 mg/L (as calcium), but can be precipitated in the combined presence of high hardness and high pH


Packaging and storage POLYPAC R anionic polymer is packaged in 50-lb (22.7-kg) and 55-lb (25-kg), heavy-duty, multi-walled, waterproof sacks. Store in a dry, well-ventilated area away from incompatibles or sources of heat or ignition.

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S

POLYSWELL POLYSWELL* co-polymer is used in lost circulation and expands to 200 times its volume in freshwater. This material is environmentally safe.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . White powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.8 to 1.0

Applications POLYSWELL co-polymer is used to fill or seal fractures. As the material fully hydrates, the fracture/void is sealed. This product can also be spotted in caving zones to reduce caving problems. Directly after placing the POLYSWELL pill, pull up above the problem zone to prevent sticking. Full hydration occurs in 20 to 30 min. Circulate with mud and LostCirculation Material (LCM) to fill the bridge.

Advantages • POLYSWELL co-polymer can be prehydrated before adding • Because of its swelling capacity and variability in size, POLYSWELL additive can accumulate in a variety of fracture sizes

Solubility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Swells on contact with water

Method of addition


POLYSWELL additive can be mixed in water or drilling mud with or without LCM. Add 1 to 3 lb (0.5 to 1.5 kg) per 4 gal (20 L) of water or mud in a pail. (Lesser and greater amounts have been used.) Pump the mixture as soon as possible once the dry polymer beads are mixed. When using POLYSWELL additive in core drilling, be sure the core tube has been pulled before pumping the solution downhole. Repeat as necessary to stop fluid loss.


Limitations Improper placement of the POLYSWELL additive can result in stuck drill rods.

Packaging and storage POLYSWELL co-polymer is packaged in 5-gal (18.9-L) buckets. Store in a dry location away from sources of heat or ignition.


H D D


95

H D D

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S

RINGFREE RINGFREE* additive is a highly efficient, thermally stable thinner and surface-active agent that removes bentonite clays from the drillstring. It is environmentally acceptable and contains no heavy metals. Because it dissolves rapidly, RINGFREE additive immediately affects the rheology of most drilling fluids.

Applications RINGFREE additive is used primarily to prevent bit balling and mud rings. It can also be used to reduce the viscosity and gel strengths of most freshwater drilling fluids.

Advantages • RINGFREE additive is an excellent clay dispersant that quickly penetrates sticky clays that can cause tools to stick • Works quickly to alleviate hole problems and reduce costly pulling times or lost pipe

96


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pale yellow liquid Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 pH as supplied. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 to 7.5

Methods of addition


• Bit balling/mud rings: Use ½ vis cup (0.5 L) per 300 gal (1,135 L) of fluid up to 0.5 to 1.5 gal (1.9 to 5.7 L) per 300 gal (1,135 L) of fluid. An alternate method is to slug rods with 1 vis cup (1 L) on connections.


• Thinning: Slowly add RINGFREE additive to the mud as needed to reduce viscosity.


Limitations Effectiveness is reduced in fluids with more than 1,000 ppm dissolved calcium and 10,000 ppm chlorides. Since RINGFREE additive reduces mud rheology, caution should be exercised when adding it to the active mud system.

RINGFREE additive is packaged in 5-gal (18.9-L) buckets. Store in a well-ventilated area away from sources of heat or ignition.

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S






Limitations None.




H D D


97

H D D

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S

THREAD BOND Z THREAD BOND* Z is a unique grease containing 50% metallic-zinc powder. It is easy to apply, offers good coverage and has excellent adhesion. The high level of solids enables THREAD BOND Z to provide antiseizing capabilities, help reduce friction, prevent galling and resist water washout. THREAD BOND Z helps minimize rusting of the pipe threads during storage.

Applications THREAD BOND Z is used primarily on the threads of rotary, shouldered connections in drill pipe and drill collars. It helps prevent galling during makeup and is an effective thread sealant under high temperatures and pressures. It is particularly suited for drilling deep wells.

Advantages THREAD BOND Z reduces costs by extending the life of tool joints. A thin layer of this product

98

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Grey paste Solids %. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50 Dropping point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 385° F (196° C) Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 430° F (221° C)

is sufficient to perform well in all drilling applications.

Method of addition THREAD BOND Z can be brushed on joints down to 0° F (–17.7° C) while retaining its consistency up to 385° F (196° C). Extreme temperatures may cause the base grease to melt and the mineral oil to oxidize, however, the solid fillers will remain to prevent metal-to-metal contact and reduce seizure. This product should be thoroughly mixed prior to use to ensure homogeneity as it may separate during extended storage periods.


Packaging and storage THREAD BOND Z is packaged in 3-gal (11.4-L) buckets.

M I N I N G

A N D

W A T E R W E L L :

M I N I N G

P R O D U C T S

TUBE LUBE TUBE LUBE* paste is brown and opaque. Since TUBE LUBE paste is made completely of natural fatty acids, it is 100% biodegradable and non-toxic.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Brown opaque paste Odor. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Faint soap pH . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9.5

Applications TUBE LUBE paste is used to lubricate the inner core barrel and core to facilitate core entry and removal. TUBE LUBE additive provides increased lubricity to waterbase drilling fluids. It can be used as a maintenance addition or can be added when torque and drag become a problem. TUBE LUBE paste is especially applicable in high-angle, exploratory drilling to reduce bit wear and increase effective bit weight.

Advantages • TUBE LUBE paste lubricates the inner tube, which allows highly fragmented or unconsolidated cores to enter easily and not be lost to the hole after coring • Reduces core-removal time

Solubility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100%

Method of addition To lubricate the inner core tube, put a ball of TUBE LUBE paste inside the inner core barrel prior to running into the core barrel. The lubricating ability of TUBE LUBE additive can be increased by coating the ball with a polymer, such as POLYPAC* additive, prior to inserting the ball into the inner tube. TUBE LUBE paste can be added to the drilling fluid to increase the lubricity. For most applications, the concentration of this product is 0.5 to 1.5% by volume. At this concentration 1.5 to 4.5 gal (5.7 to 17.1 L) of TUBE LUBE paste per 300 gal (1,135 L) of fluid is required to build the proper ratio.

Some cases can require more paste. The quantity depends on the mud type and drilling characteristics.


Packaging and storage TUBE LUBE paste is packed in 3-gal (11.4-L) buckets.


H D D


99

H D D

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

Lost-Circulation Materials (LCM) Cedar Fiber Cedar Fiber is a specially processed blend of fibers of controlled length, giving proper size distribution for regaining circulation. • Non-fermenting • Amounts used vary from 1 to 35% by volume

Packaging and storage Cedar Fiber is packaged in 40-lb (18-kg) bags.

directly to the pits and gunned into the mud. The most important aspect of combating lost circulation is using the correct particle size. Consequently, it is recommended that a combination of materials be added to ensure a good particle-size distribution. If left in the mud for an extended period of time, drilling paper may be susceptible to bacterial degradation. A bactericide may be necessary to prevent fermentation.

Packaging and storage Mica Mica is a selected, non-abrasive mineral available in fine and coarse grades. Mica has no adverse effect on mud properties. It is used to prevent and regain lost returns. Fine mica can pass through a 20-mesh screen.

Application • Lost circulation: 5 to 15 lb (2.25 to 6.75 kg)

Packaging and storage Mica is packaged in 50-lb (22.68-kg) sacks.

Drilling Paper Drilling paper is a blend of variable-sized particles of ground paper that is applicable for use in all water-base mud systems. Drilling paper can be used in concentrations of up to 20 lb/bbl (57 kg/m3) in slug treatments or as an additive to the entire system. In areas of known lost-circulation zones, it is advisable to pretreat the system before drilling into the zone of loss. Drilling paper can be mixed through the mud hopper or added

100

Drilling paper is packaged in 40-lb (18-kg) plastic sacks.

Cottonseed Hulls Cottonseed hulls are fibrous and biodegradable, creating an excellent bridging agent when large-particlesize material is needed. They can be used in any water-base mud system. Cottonseed hulls are used in concentrations of up to 20 lb/bbl (57 kg/m3) as slug treatments or as an additive to the entire system. In areas of known lost-circulation zones, it is advisable to pretreat the system before drilling into the zone of loss. Cottonseed hulls can be mixed through the mud hopper or added directly to the pits and gunned into the mud. The most important aspect of combating lost circulation is using the correct particle size. Consequently, it is recommended that a combination of materials be added to ensure a good particle-size distribution. If left in the mud for an extended period of time, cottonseed hulls can be susceptible to bacterial degradation, resulting in the release of H2S and CO2 into the mud. Bactericide may be necessary to prevent fermentation.

Packaging and storage Cottonseed hulls are packaged in 50-lb (22.68-kg) and 100-lb (45.37-kg) burlap or paper sacks.

FED-SEAL FED-SEAL* lost-circulation material is an engineered product that contains an optimum blend of granular, fibrous and flake materials. FED-SEAL LCM is available in three grinds (coarse, medium and fine) covering a wide range of lostcirculation problems. FED-SEAL additive is normally recommended in concentrations of 20 to 30 lb/bbl (57 to 86 kg/m3) mixed in a slug of 100 to 200 bbl and spotted at the zone of loss, displacing the slurry at a reduced pumping rate with either large nozzles or an open-ended system. FED-SEAL LCM can be added to either the water-base mud being used at the time of loss or in any special purpose slurry prepared for squeeze applications. The FED-SEAL product has been used for preventive measures or as a “filler” because the fine grade can pass through 20-mesh shaker screens in concentrations of 2 to 10 lb/bbl (6 to 28 kg/m3).

Limitations Do not mix in oil muds.


Packaging and storage FED-SEAL LCM is packaged in 40-lb (18-kg) multi-walled, paper sacks.

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S




Applications POLY-PLUS polymer mud systems. The POLY-PLUS system provides excellent cuttings encapsulation and improved wellbore stability. Typical concentrations of POLY-PLUS are 0.75 to 3 lb/bbl (2.1 to 8.5 kg/m3). It is also effective in salt muds, such as KCl- or NaCl-enhanced fluids, although slightly higher concentrations of POLY-PLUS polymer may be required.

Low-Solids, Non-Dispersed (LSND) muds. POLY-PLUS polymer is well suited to LSND systems. In reducedbentonite muds, POLY-PLUS additive serves as a bentonite extender to increase viscosity and as a flocculant to more efficiently remove drill solids. It also encapsulates cuttings and improves wellbore stability. Weighted muds. POLY-PLUS polymer can be used in weighted muds for cuttings encapsulation, improved wellbore stability, secondary viscosity, and improved filter-cake integrity. The effectiveness of the polymer diminishes as the


gal/bbl (L/m3) 0.056 (1.3) 0.084 (2.0)

gal/100 gal 0.133 0.200

0.110 (2.6) 0.170 (4.0)

0.262 0.405

1.00 (3.0) 1.50 (4.3) 1Based




Advantages







Clear-water fluids. POLY-PLUS polymer can be used in clear-water, solids-free drilling fluids. The POLY-PLUS system increases viscosity and enhances solids removal by flocculating the undesired solids. It also provides cuttings encapsulation and improved wellbore stability. This system is frequently used in slim-hole, continuous-coring applications. Adding 0.5 to 1.75 lb/bbl (1.4 to 5 kg/m3) enhances solids removal by flocculating solids.

Viscosity (Typical) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~ 500 cP


H D D

101

H D D

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

SUPERFOAM SUPERFOAM* agent is water-soluble and biodegradable. This material, designed exclusively for mineral and water-well drilling, has the ability to foam in fresh, brackish or salty waters.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Clear liquid Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.07 Solubility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100%

Applications Used in air-drilling applications, the SUPERFOAM product acts as a foaming agent. Based on the amount of product added and the injection rate, it can be used for dust suppression, mist, foam and stiff-foam drilling.

Advantages SUPERFOAM liquid is more concentrated and is an economically viable alternative to regular foaming agents.

Methods of addition • To use as a dust suppressor or to prevent bit balling in damp formations: Mix ¼ to ½ pints (0.11 to 0.23 L) per 50 gal (189 L) of water. • For mist drilling with moderate amounts of water intrusion: Mix 1 to 2 pints (0.5 to 0.95 L) per 50 gal (189 L) of water.

102

• For foam drilling with excessive amounts of water intrusion: Mix 4 pints (1.89 L) of SUPERFOAM liquid per 50 gal (189 L) of water. • For slug drilling: Mix ¼ pint (0.11 L) in 2 gal (7.6 L) of water • Stiff foams: To obtain desired viscosity, mix MAX GEL or POLY-PLUS 2000 product in 50 gal (189 L) of water and stir in ½ gal (1.9 L) of SUPERFOAM liquid. Pump the slurry into the air stream at 7 to 10 gal (26.6 to 38 L) per min.

Limitations When used as recommended, there are no limitations imposed on this product.


Packaging and storage SUPERFOAM liquid is packaged in 5-gal (18.9-L) buckets and 55-gal (208.2-L) drums. Store in a well-ventilated area away from sources of heat or ignition.

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

SUPERFOAM AF SUPERFOAM AF product is a watersoluble, biodegradable foaming agent. This material is designed exclusively for mineral and waterwell drilling. SUPERFOAM AF additive has the ability to foam in fresh, brackish or salty waters. SUPERFOAM AF foaming agent is completely biodegradable and will not contaminate streams or groundwater. SUPERFOAM AF foaming agent presents no disposal problems and is not harmful to personnel, vegetation or livestock.

Applications SUPERFOAM AF additive is used as a foaming agent in air-drilling applications. Based on the amount of SUPERFOAM AF foaming agent added and the injection rate, it can be used for dust suppression, mist, foam and stiff-foam drilling.

Advantages • Produces stable, consistent foam in all types of water • Environmentally acceptable and biodegradable • Lubricating properties make it suitable for use with downhole hammers

Physical appearance. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Clear, amber solution Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.01 Solubility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100% pH. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 to 8

Methods of addition

Limitations

• To use as a dust suppressor or to prevent bit balling in damp formations: Mix 1⁄3 to π pints (0.2 to 0.4 L) per 50 gal (189 L) of water.

When used as recommended, there are no limitations imposed on this product.

• For mist drilling with moderate amounts of water intrusion: Mix 1.5 to 3 pints (0.8 to 1.5 L) per 50 gal (189 L) of water.


• For foam drilling with excessive amounts of water intrusion: Mix 6 pints (2.9 L) of SUPERFOAM AF foaming agent per 50 gal (189 L) of water. • For slug drilling: 1⁄3 pint (0.2 L) in 2 gal (7.6 L) of water • Stiff foams: To obtain desired viscosity, mix MAX GEL viscosifier or POLY-PLUS 2000 additive in 50 gal (189 L) of water to 32 sec/qt and stir in π gal (3 L) of SUPERFOAM AF foaming agent. Pump the slurry into the air stream at 7 to 10 gal (26.6 to 38 L) per min.


Packaging and storage SUPERFOAM AF foaming agent is packaged in 5-gal (18.9-L) buckets and 55-gal (208.2-L) drums. Store in a well-ventilated area away from sources of heat or ignition.


• Improves hole cleaning and penetration rates



H D D

103

H D D

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

SUPER PLUG SUPER PLUG* additive is a proprietary blend of bentonite, hydroxides and silicates. It is a 100% inorganic additive designed to minimize environmental impacts in hole-abandonment applications. SUPER PLUG additive is designed to offer superior sealing characteristics where low-permeability, flexible seals are required.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . Light tan to gray powder Specific gravity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.45 to 2.55 pH. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.0 to 10.0 (5% aqueous suspension) Solubility . . . . . . . . . . . . . . . Insoluble in water, forms colloidal suspension

Limitations


SUPER PLUG additive can be used to plug and abandon any type of drilled hole.

Limitations are the same as for most bentonite products. High chlorides and calcium decrease the yield of this product.

Advantages


• SUPER PLUG additive is an all-natural bentonite product


SUPER PLUG additive is packaged in 50-lb (22.7-kg) multi-walled, moisture-resistant bags. It is also available in super sacks. Store in a well-ventilated area away from sources of heat or ignition.

Applications

• Hydrates easily and sets efficiently

Method of addition Mix one 50-lb (22.7-kg) bag of SUPER PLUG additive with 33 to 43 gal (125 to 163 L) freshwater. This mixture is pumpable with most pumping equipment available. Though progressive cavity or positive displacement pumps offer the best results, diaphragm or gear pumps can also be used.

104


SUPER PLUG Slurry at Various Solids Content SUPER PLUG* lb (kg) 50 (22.7) 50 (22.7)

Water gal (L) 33 (125) 43 (163)

Density lb/gal (kg/L) 9.2 (1.1) 9 (1.08)

Fluid loss cm3 (in3) 8.9 (.54) 13 (0.8)

Solids content % 15.4 12.1

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S















lb/100 gal 15 – 25

lb/bbl 6 – 11

kg/m3 15 – 30

25 – 40 35 – 45

12 – 18 15 – 20

35 – 50 40 – 45

5 – 10

2–5

6 – 14





H D D

105

H D D

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S




Applications



pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 9.0




Advantages




Limitations


106




M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

PLATINUM PAC UL PLATINUM PAC* UL Polyanionic Ccellulose (PAC) is a high-quality, water-soluble polymer designed to control fluid loss. Because it is an “Ultra-Low” (UL) additive, it causes a minimal increase in viscosity in water-base muds. PLATINUM PAC UL additive is readily dispersible in a wide range of water-base mud systems.

Applications









PLATINUM PAC UL additive controls fluid loss in freshwater, seawater, KCl, and salt muds. It forms a thin, resilient, low-permeability filter cake that minimizes the potential for differential sticking and the invasion of filtrate and mud solids into permeable formations. PLATINUM PAC UL additive resists bacterial attack, eliminating the need for biocides or preservatives. It is effective in low concentrations, with the normal fluid-loss treatment ranging from 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). In saltwater and PAC-polymer systems, higher concentrations are required for encapsulation, with normal concentrations ranging from 1 to 3 lb/bbl (2.85 to 8.6 kg/m3). Because PLATINUM PAC UL additive is low viscosity, generating less viscosity as compared to the POLYPAC* and PLATINUM PAC products. The viscosity generated depends on the solids concentration, salinity and makeup-water chemistry. PLATINUM PAC UL anionic polymer attaches to and encapsulates



H D D

107

H D D

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

SMOOTH GROUT 20 SMOOTH GROUT* 20 slurry is an easy-to-use bentonite-grouting composition containing highswelling sodium montmorillonite clay. It is designed for use in water wells and monitoring wells, for sealing the annular space around a well casing, and for plugging drilled holes and abandoned wells. SMOOTH GROUT 20 slurry contains no organic additives or polymers. The SMOOTH GROUT 20 system, a one-sack formulation, mixes with freshwater to yield a 20% pumpable grouting slurry with an extended working time. When set up, the SMOOTH GROUT 20 slurry develops a satisfactory seal with adequate structural strength and low-hydraulic conductivity. When properly placed, SMOOTH GROUT 20 slurry remains flexible, rehydratable and unstratified through heating and cooling cycles.

Applications • Sealing and grouting casings • Sanitary sealing in water-well construction • Sealing in monitoring wells • Plugging abandoned exploration boreholes

Advantages • Inorganic, non-fermenting and non-toxic • Develops lower-solids slurries up to 20% total active solids


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Beige to tan powder Moisture content . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8% Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 pH (8% slurry) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.0 Slurry density . . . . . . . . . . . . . . . . . . . . . . . . 9.4 lb/gal (1.1 kg/L) for 20% solids Dry bulk density. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 60 lb/ft3 (961.1 kg/m3) Screen analysis. . . . . . . . . . . . . . . . . . . 75% min. passing through 200-mesh

• Firm texture providing structural stability after grout is set


Addition method SMOOTH GROUT 20 slurry should be mixed with freshwater to obtain optimum results. The recommended mixing rate is a 50-lb (22.7-kg) sack of SMOOTH GROUT 20 slurry with 24 gal (90.8 L) of water to make a 20%-active-solids slurry. The viscosity and consistency of mixed-grout slurry can be modified by adjusting the amount of water used to obtain varying solids content. 1. Using a mixing device, blend one 50-lb (22.7-kg) sack of SMOOTH GROUT 20 slurry into 24 gal (90.8 L) of freshwater.


Packaging and storage SMOOTH GROUT 20 slurry is packaged in 50-lb (22.7-kg), heavy-duty, multi-walled, waterproof sacks. Store in a cool, dry place. Store in a dry location away from sources of heat or ignition, and minimize dust.

2. Blend, do not over-mix. The resulting slurry should look like cake batter, containing partially yielded bentonite. This pumpable slurry contains 20% solids. Pump into hole without delay.

• Easy one-sack mixing • Mixed and handled with most conventional rig equipment • Permanent, flexible seal prevents entry of contaminants from the surface • Extended working time controlled by grout-solids content

108

SMOOTH GROUT 20 Slurry at Various Solids Content SMOOTH GROUT* 20 lb (kg) 50 (22.7) 50 (22.7) 50 (22.7)

Water gal (L) 30 (113.6) 27 (102.2) 24 (90.8)

Solids content % 16.7 18.2 20

Usable slurry gal (L) 33 (124.9) 30 (113.6) 27 (102.2)

Estimate working time (min) 30 – 60 15 – 30 5 – 15

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

SMOOTH GROUT 30 SMOOTH GROUT* 30 additive is an easy-to-use bentonite-grouting composition containing highswelling, sodium montmorillonite clay. It is designed for use in water wells and monitoring wells, for sealing the annular space around the well casing, and for plugging drilled holes and abandoned wells. SMOOTH GROUT 30 material contains no organic additives or polymers. A one-sack formulation of SMOOTH GROUT 30 additive mixes with freshwater to yield a 30% pumpable grouting slurry with an extended working time. When it sets up, the SMOOTH GROUT 30 slurry develops a satisfactory seal with adequate structural strength and low hydraulic conductivity. When properly placed, the SMOOTH GROUT 30 composition remains flexible, rehydratable, and unstratified though heating and cooling cycles.

Applications • Sealing and grouting casing • Sanitary sealing in water-well construction • Sealing in monitoring wells • Plugging and abandoning exploration boreholes

• Inorganic, non-fermenting and non-toxic • Develops lower-solids slurries up to 30% activity

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Beige to tan powder Moisture content . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8% Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 pH (8% slurry) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.0 Slurry density . . . . . . . . . . . . . . . . . . . . . . . . 10 lb/gal (1.2 kg/L) for 30% solids Dry bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 64 lb/ft3 (1,025.2 kg/m3) Screen analysis. . . . . . . . . . . . . . . . . . . 75% min. passing through 200-mesh

• Easily mixed with most conventional rig equipment • Permanent, flexible seal prevents entry of contaminants from the surface • Extended working time controlled by the grout solids content

Water gal (L) 14 (53) 15 (56.8) 16 (61)

Limitations

• Firm texture providing structural stability after grout set


Addition method


SMOOTH GROUT 30 additive should be mixed with freshwater to obtain maximum results. A 50-lb (22.7-kg) sack of SMOOTH GROUT 30 additive with 14 gal (53 L) of water makes a 30%-active-solids slurry. The viscosity and consistency of a mixed grout slurry can be modified by adjusting the amount of water used to obtain varying solids content.


1. Using a mixing device, blend one 50-lb (22.7-kg) sack of SMOOTH GROUT 30 additive into 14 gal (53 L) of freshwater.


2. Blend, do not over-mix. The resulting slurry should look like cake batter. Pump through tremie line without delay.

Solids content % 30 28.6 27.3

Usable slurry gal (L) 17 (64.4) 18 (68.1) 19 (72)


Packaging and storage SMOOTH GROUT 30 additive is packaged in 50-lb (22.7-kg), multi-walled, paper sacks and is available in bulk. Store in a dry location (slip hazard when wet) and minimize dust (use dustless systems for handling, storage, and cleanup). Material can be palletized at either 56/pallet or 70/pallet. Store in a well-ventilated area away from sources of heat or ignition. For more information, please request a product bulletin from your M-I SWACO representative.


Advantages



H D D

109

H D D

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

GOPHER GROUT GOPHER GROUT* granular bentonite grouting composition contains highswelling sodium montmorillonite clay. It is designed for use in water wells and monitoring wells, for sealing the annular space around well casing, and for plugging drilled holes and abandoned wells. GOPHER GROUT composition contains no organic additives or polymers. A one-sack formulation of GOPHER GROUT granular bentonite grouting composition mixes with freshwater to yield 20%-pumpable grouting slurry with an extended working time. When set up, the GOPHER GROUT grouting composition develops a satisfactory seal with adequate structural strength and low hydraulic conductivity. When properly placed, GOPHER GROUT grouting composition remains flexible, rehydratable and unstratified through heating and cooling cycles.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Beige to tan granular Screen analysis . . . . . . . . . . . . . . . . . . . . 90% max passing through 20-mesh Moisture content . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8% Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.0 Slurry density . . . . . . . . . . . . . . . . . . . . . . . . 9.4 lb/gal (1.1 kg/L) for 20% solids Dry bulk density. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80 lb/ft3 (1,281 kg/m3)

• Sealing and grouting casing

1. Using a mixing device, blend one 50-lb (22.7-kg) sack of GOPHER GROUT grouting composition into 24 gal (91 L) of freshwater.

• Plugging and abandoning exploration boreholes

Advantages • Inorganic, non-fermenting and non-toxic • Develops lower-solids slurries up to 20% total active solids • Easily mixed and handled with most conventional mixing equipment • Permanent, flexible seal prevents entry of contaminants from the surface • Extended working time controlled by grout solids content • Firm texture providing structural stability after grout set

3. Add silica sand at a steady, continuous rate (approximately 2 min). Continue mixing until a consistent mixture is reached.

GOPHER GROUT grouting composition should be mixed with freshwater to obtain maximum results. The recommended mixing rate is a 50-lb (22.7-kg) sack of GOPHER GROUT grouting composition with 24 gal (91 L) of water to make a 20%-active-solids slurry. Adjust the amount of water to alter viscosity and consistency.

Waterwell mixing procedures

• Sealing monitor wells

2. Mix for approximately 1 min.

Addition methods

Applications • Sanitary sealing in water well construction

110




2. Blend, do not over-mix. The resulting slurry should be like lumpy cake batter. Pump through tremie line without delay.

Geothermal mixing procedures 1. Start the mixing device in 27 gal (102 L) of freshwater and add one 50-lb (22.7-kg) sack of GOPHER GROUT grouting composition.


Packaging and storage GOPHER GROUT grouting composition is packaged in 50-lb (22.7-kg), heavy-duty, multiwalled, waterproof sacks. Store in a cool, dry place.

GOPHER GROUT Slurry at Various Solids Content GOPHER GROUT* lb (kg) 50 (22.7) 50 (22.7) 50 (22.7)

Water gal (L) 30 (114) 28 (106) 24 (91)

Solids content % 16.7 17.5 20.0

Usable slurry gal (L) 33 (125) 31 (117) 27 (102)


M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

KWIK-PLUG Fine & Micro KWIK-PLUG* Fine and KWIK-PLUG Micro granular bentonite products are composed of dried sodiummontmorillonite clay. KWIK-PLUG products can be used as a sealant for earthen structures and dry, shallow-hole abandonment. KWIK-PLUG products can also be used to control lost circulation in mud used in rotary or coring operations.


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gray-white granular Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 Solubility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Insoluble in water KWIK-PLUG Fine . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97% min. passing 4-mesh KWIK-PLUG Fine . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5% max. passing 20-mesh KWIK-PLUG Micro. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97% min. passing 8-mesh KWIK-PLUG Micro . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5% max. passing 20-mesh

Applications • Seal or grout casing in well construction • Plug abandoned earthen boreholes • Seal ponds and other water structures

Advantages • High-swelling Wyoming bentonite that forms tight seals • Granular product with reduced dust • Forms a low, permeable and flexible seal

Addition methods



Packaging and storage KWIK-PLUG granular bentonite product is packaged in 50-lb (22.7-kg), heavy-duty, multi-walled, waterproof sacks and various sized super sacks. Store in a cool, dry place.


For an earthen structure seal, the normal treatment is 1 to 2 lb/ft2 (4.88 to 9.76 kg/m2), depending on the soil type. Treatment concentration should be tested using a 5-gal (18.9-L) bucket with holes

punched in the bottom. Put the soil to be treated in the bucket and add 1 to 2 lb (0.5 to 0.9 kg) of KWIK-PLUG granular bentonite. Pour water into the bucket and observe the seal. By using this method, the exact concentration of KWIK-PLUG product can be determined. For lost-circulation control in mud rotary applications, add KWIK-PLUG granular bentonite directly to the suction pit. For coring-rig applications, mix KWIK-PLUG product in vegetable oil and pour the solution down the rods. Pump slurry to the point of the lost circulation, then pick up the rods and wait while the slurry hydrates. For dry, shallow-hole abandonment, pour the required amount of KWIK-PLUG product directly down the borehole and hydrate with freshwater.


H D D

111

H D D

M I N I N G

A N D

W A T E R W E L L :

W A T E R W E L L

P R O D U C T S

KWIK-PLUG Medium & Coarse The KWIK-PLUG Medium & Coarse products are screen-sized bentonite composed of a naturally occurring clay which is used to seal and plug earthen boreholes. KWIK-PLUG material will travel through water standing in the hole and reach the bottom of the hole with minimum hydration or swelling. The annular space can be completely filled, and bridging of the particles in the upper portion of the hole minimized. The annular space being completely filled is necessary to form an effective, long-term plug. KWIK-PLUG material is available in two sizes: KWIK-PLUG Coarse (¾-in. [19.1-mm]) size and KWIK-PLUG Medium (3⁄8-in. [9.5-mm]) size. The size of the open annular space will determine which size should be used. When the annular space is ¾-in. (19.1-mm) or more, KWIK-PLUG Medium material is recommended. When the annular space is 1½ in. (38.1 mm) or more, KWIK-PLUG Coarse material is recommended.

Applications • Environmental monitoring wells • Sealing outside casing annulus • Plugging decommissioned boreholes

112


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Beige to tan powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 to 2.6 Permeability of resulting plug. . . . . . . . . . . . . . . . . . . . . . . . . . 1 x 10–9 cm/sec. Moisture. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15% Bulk density KWIK-PLUG Medium . . . . . . . . . . . . . . . . . 68 lb/ft3 (1,089.2 kg3) Bulk density KWIK-PLUG Coarse . . . . . . . . . . . . . . . . . . . 64 lb/ft3 (1,025.2 kg3)

• Sealing lost-circulation zones • Sealing above gravel packs

Advantages • Prevents entry of surface water into boreholes • Forms a permanent, flexible, downhole seal • Allows hole re-entry • Easy to apply, no mixing expense • More cost effective compared to pelletized bentonite


Toxicity and handling Bioassay information available upon request. Handle as an industrial chemical, wearing protective equipment and observing the precautions as described on the Material Safety Data Sheet (MSDS).

Packaging and storage KWIK-PLUG material is packaged in 50-lb (22.7-kg), heavy-duty, multi-walled, waterproof sacks and various sized super sacks. Store in a cool, dry place.

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

GEL SUPREME GEL SUPREME* viscosifier is a premium-grade Wyoming bentonite (a sodium montmorillonite clay) which has not been chemically treated. It is used as a primary filter-cake-building filtrationcontrol and suspension agent in freshwater systems, and has application in all water-base mud systems. GEL SUPREME is a high-quality product that meets the API specification for non-treated bentonite.

Applications GEL SUPREME bentonite is used to increase viscosity and reduce fluid loss in water-base drilling fluids. It is a cost-effective product for achieving viscosity, controlling fluid loss and maintaining filter cake quality in freshwater and seawater muds. Typical concentrations for GEL SUPREME additive range from 5 to 35 lb/bbl (14.3 to 100 kg/m3). As with all bentonite products the yield decreases as the salinity increases. In muds containing more than 10,000 mg/L chlorides, the performance of GEL SUPREME viscosifier is significantly reduced unless it is prehydrated in freshwater, before adding it to the mud system.


Typical physical properties Physical appearance. . . . . . . . . . . . . . . . . . . . . . Light tan/gray-green powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.3 to 2.6 Bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . 48 to 52 lb/ft3 (769 to 833 kg/m3) API Specifications — Suspension Properties1 Dispersed plastic viscosity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10cP, min. Yield point/plastic viscosity ratio. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.5, max. Dispersed API filtrate volume . . . . . . . . . . . . . . . . . . . . . . . . . . . 12.5 cm3, max. 1Suspension

of 25 grams non-treated bentonite in 350 cm3 deionized water.

to be more desirable for certain applications. • The small particle size, unique flat shape and high surface area of hydrated GEL SUPREME viscosifier provides superior filtration characteristics • Promotes the deposition of thin compressible, filter cakes in the wellbore

Limitations Performance reduced in salty (>5,000 mg/L C1–) or hard (>240 mg/L Ca++) waters due to decreased hydration.


Packaging and storage GEL SUPREME bentonite is packaged in 50-lb (22.7-kg), multi-walled, paper sacks and is available in bulk. Minimize dust (use dustless systems for handling, storage and cleanup). Store in a dry location (slip hazard when wet).

• Hydrates more than other types of clays and is best for generating viscosity, developing gels for suspension and controlling filtration • A premium-grade, API, nontreated bentonite. Therefore, it does not contain chemical treatments and is considered

Typical Amounts of GEL SUPREME Additions Added to Freshwater Drilling application/desired results Normal drilling In gravel or other poorly consolidated formation Lost-circulation control Added to freshwater mud to improve hole-cleaning properties, increase hole stability and develop thin filter cakes

lb/100 gal 50 – 70

lb/bbl 20 – 30

kg/m3 60 – 85

70 – 95 105 – 130

30 – 40 45 – 55

85 – 115 125 – 155

45

20

55


Advantages


H D D

113

H D D

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

GOPHER GROUT GOPHER GROUT* granular bentonite grouting composition contains highswelling sodium montmorillonite clay. It is designed for use in water wells and monitoring wells, for sealing the annular space around well casing, and for plugging drilled holes and abandoned wells. GOPHER GROUT composition contains no organic additives or polymers. A one-sack formulation of GOPHER GROUT granular bentonite grouting composition mixes with freshwater to yield 20%-pumpable grouting slurry with an extended working time. When set up, the GOPHER GROUT grouting composition develops a satisfactory seal with adequate structural strength and low hydraulic conductivity. When properly placed, GOPHER GROUT grouting composition remains flexible, rehydratable and unstratified through heating and cooling cycles.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Beige to tan granular Screen analysis . . . . . . . . . . . . . . . . . . . . 90% max passing through 20-mesh Moisture content . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8% Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.0 Slurry density . . . . . . . . . . . . . . . . . . . . . . . . 9.4 lb/gal (1.1 kg/L) for 20% solids Dry bulk density. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80 lb/ft3 (1,281 kg/m3)

• Sealing and grouting casing

1. Using a mixing device, blend one 50-lb (22.7-kg) sack of GOPHER GROUT grouting composition into 24 gal (91 L) of freshwater.

• Plugging and abandoning exploration boreholes

Advantages • Inorganic, non-fermenting and non-toxic • Develops lower-solids slurries up to 20% total active solids • Easily mixed and handled with most conventional mixing equipment • Permanent, flexible seal prevents entry of contaminants from the surface • Extended working time controlled by grout solids content • Firm texture providing structural stability after grout set

3. Add silica sand at a steady, continuous rate (approximately 2 min). Continue mixing until a consistent mixture is reached.

GOPHER GROUT grouting composition should be mixed with freshwater to obtain maximum results. The recommended mixing rate is a 50-lb (22.7-kg) sack of GOPHER GROUT grouting composition with 24 gal (91 L) of water to make a 20%-active-solids slurry. Adjust the amount of water to alter viscosity and consistency.

Waterwell mixing procedures

• Sealing monitor wells

2. Mix for approximately 1 min.

Addition methods

Applications • Sanitary sealing in water well construction

114




2. Blend, do not over-mix. The resulting slurry should be like lumpy cake batter. Pump through tremie line without delay.

Geothermal mixing procedures 1. Start the mixing device in 27 gal (102 L) of freshwater and add one 50-lb (22.7-kg) sack of GOPHER GROUT grouting composition.


Packaging and storage GOPHER GROUT grouting composition is packaged in 50-lb (22.7-kg), heavy-duty, multiwalled, waterproof sacks. Store in a cool, dry place.

GOPHER GROUT Slurry at Various Solids Content GOPHER GROUT* lb (kg) 50 (22.7) 50 (22.7) 50 (22.7)

Water gal (L) 30 (114) 28 (106) 24 (91)

Solids content % 16.7 17.5 20.0

Usable slurry gal (L) 33 (125) 31 (117) 27 (102)


M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

KWIK-PLUG Fine & Micro KWIK-PLUG* Fine and KWIK-PLUG Micro granular bentonite products are composed of dried sodiummontmorillonite clay. KWIK-PLUG products can be used as a sealant for earthen structures and dry, shallow-hole abandonment. KWIK-PLUG products can also be used to control lost circulation in mud used in rotary or coring operations.


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gray-white granular Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 Solubility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Insoluble in water KWIK-PLUG Fine . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97% min. passing 4-mesh KWIK-PLUG Fine . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5% max. passing 20-mesh KWIK-PLUG Micro. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97% min. passing 8-mesh KWIK-PLUG Micro . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5% max. passing 20-mesh

Applications • Seal or grout casing in well construction • Plug abandoned earthen boreholes • Seal ponds and other water structures

Advantages • High-swelling Wyoming bentonite that forms tight seals • Granular product with reduced dust • Forms a low, permeable and flexible seal

Addition methods



Packaging and storage KWIK-PLUG granular bentonite product is packaged in 50-lb (22.7-kg), heavy-duty, multiwalled, waterproof sacks and various sized super sacks. Store in a cool, dry place.


For an earthen structure seal, the normal treatment is 1 to 2 lb/ft2 (4.88 to 9.76 kg/m2), depending on the soil type. Treatment concentration should be tested using a 5-gal (18.9-L) bucket with holes

punched in the bottom. Put the soil to be treated in the bucket and add 1 to 2 lb (0.5 to 0.9 kg) of KWIK-PLUG granular bentonite. Pour water into the bucket and observe the seal. By using this method, the exact concentration of KWIK-PLUG product can be determined. For lost-circulation control in mud rotary applications, add KWIK-PLUG granular bentonite directly to the suction pit. For coring-rig applications, mix KWIK-PLUG product in vegetable oil and pour the solution down the rods. Pump slurry to the point of the lost circulation, then pick up the rods and wait while the slurry hydrates. For dry, shallow-hole abandonment, pour the required amount of KWIK-PLUG product directly down the borehole and hydrate with freshwater.


H D D

115

H D D

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

KWIK-PLUG Medium & Coarse The KWIK-PLUG Medium & Coarse products are screen-sized bentonite composed of a naturally occurring clay which is used to seal and plug earthen boreholes. KWIK-PLUG material will travel through water standing in the hole and reach the bottom of the hole with minimum hydration or swelling. The annular space can be completely filled, and bridging of the particles in the upper portion of the hole minimized. The annular space being completely filled is necessary to form an effective, long-term plug. KWIK-PLUG material is available in two sizes: KWIK-PLUG Coarse (¾-in. [19.1-mm]) size and KWIK-PLUG Medium (3⁄8-in. [9.5-mm]) size. The size of the open annular space will determine which size should be used. When the annular space is ¾-in. (19.1-mm) or more, KWIK-PLUG Medium material is recommended. When the annular space is 1½ in. (38.1 mm) or more, KWIK-PLUG Coarse material is recommended.

Applications • Environmental monitoring wells • Sealing outside casing annulus • Plugging decommissioned boreholes

116


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Beige to tan powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 to 2.6 Permeability of resulting plug. . . . . . . . . . . . . . . . . . . . . . . . . . 1 x 10–9 cm/sec. Moisture. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15% Bulk density KWIK-PLUG Medium . . . . . . . . . . . . . . . . . 68 lb/ft3 (1,089.2 kg3) Bulk density KWIK-PLUG Coarse . . . . . . . . . . . . . . . . . . . 64 lb/ft3 (1,025.2 kg3)

• Sealing lost-circulation zones • Sealing above gravel packs

Advantages • Prevents entry of surface water into boreholes • Forms a permanent, flexible, downhole seal • Allows hole re-entry • Easy to apply, no mixing expense • More cost effective compared to pelletized bentonite


Toxicity and handling Bioassay information available upon request. Handle as an industrial chemical, wearing protective equipment and observing the precautions as described on the Material Safety Data Sheet (MSDS).

Packaging and storage KWIK-PLUG material is packaged in 50-lb (22.7-kg), heavy-duty, multi-walled, waterproof sacks and various sized super sacks. Store in a cool, dry place.

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S




Applications



pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 9.0

• Effective in low concentrations for controlling fluid loss




Advantages




Limitations


• Encapsulates shale particles to inhibit swelling and dispersion • Resists bacterial attack, requiring no biocides or preservatives




H D D


117

H D D

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S


Applications PLATINUM PAC UL additive controls fluid loss in freshwater, seawater, KCl, and salt muds. It forms a thin, resilient, low-permeability filter cake that minimizes the potential for differential sticking and the invasion of filtrate and mud solids into permeable formations. PLATINUM PAC UL additive resists bacterial attack, eliminating the need for biocides or preservatives. It is effective in low concentrations, with the normal fluid-loss treatment ranging from 0.25 to 1 lb/bbl (0.71 to 2.85 kg/m3). In saltwater and PAC-polymer systems, higher concentrations are required for encapsulation, with normal concentrations ranging from 1 to 3 lb/bbl (2.85 to 8.6 kg/m3). Because PLATINUM PAC UL additive is low viscosity, generating less viscosity as compared to the POLYPAC* and PLATINUM PAC products. The viscosity generated depends on the solids concentration, salinity and makeup-water chemistry. PLATINUM PAC UL anionic polymer attaches to and encapsulates

118









M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S




Applications POLY-PLUS polymer mud systems. The POLY-PLUS system provides excellent cuttings encapsulation and improved wellbore stability. Typical concentrations of POLY-PLUS are 0.75 to 3 lb/bbl (2.1 to 8.5 kg/m3). It is also effective in salt muds, such as KCl- or NaCl-enhanced fluids, although slightly higher concentrations of POLY-PLUS polymer may be required.

Low-Solids, Non-Dispersed (LSND) muds. POLY-PLUS polymer is well suited to LSND systems. In reducedbentonite muds, POLY-PLUS additive serves as a bentonite extender to increase viscosity and as a flocculant to more efficiently remove drill solids. It also encapsulates cuttings and improves wellbore stability. Weighted muds. POLY-PLUS polymer can be used in weighted muds for cuttings encapsulation, improved wellbore stability, secondary viscosity, and improved filter-cake integrity. The effectiveness of the polymer diminishes as the


gal/bbl (L/m3) 0.056 (1.3) 0.084 (2.0)

gal/100 gal 0.133 0.200

0.110 (2.6) 0.170 (4.0)

0.262 0.405

1.00 (3.0) 1.50 (4.3) 1Based




Advantages







Clear-water fluids. POLY-PLUS polymer can be used in clear-water, solids-free drilling fluids. The POLY-PLUS system increases viscosity and enhances solids removal by flocculating the undesired solids. It also provides cuttings encapsulation and improved wellbore stability. This system is frequently used in slim-hole, continuous-coring applications. Adding 0.5 to 1.75 lb/bbl (1.4 to 5 kg/m3) enhances solids removal by flocculating solids.

Viscosity (typical) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~ 500 cP


H D D

119

H D D

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

POLY-PLUS 2000 POLY-PLUS 2000 polymer is a multifunction synthetic co-polymer developed for use in freshwater-, potassium- and saltwater-base drilling fluids. POLY-PLUS 2000 water-free dispersion has excellent freeze/thaw stability and is not subject to phase separation or premature activation inside the pail or drum. POLY-PLUS 2000 co-polymer provides the same benefits as regular POLY-PLUS polymer, but at lower concentration.

Applications Viscosity. POLY-PLUS 2000 co-polymer is a cost-effective viscosifier in lowsalinity fluids. Its shear-thinning properties maximize penetration rates at the bit under high shear rates and exhibit excellent holecleaning characteristics under low shear rates. It also allows for easy solids deposition in settling pits. Shale stabilization/inhibition. POLY-PLUS 2000 co-polymer can be used alone or in conjunction with KCl to stabilize active shales. It protects by encapsulating reactive shales, forming a protective coating on the wellbore and around cuttings. Coating reduces the shale’s tendency to absorb water, swell and slough. Foam stabilization. The long-chain polymer of POLY-PLUS 2000 additive creates a tighter, stronger foam, which improves the fluid’s cuttings-carrying capacity. Flowline flocculant. Small concentrations of POLY-PLUS 2000 co-polymer (0.01 to 0.05 lb/bbl [0.028 to 0.14 kg/m3]) economically flocculate drill solids. Additions should be made at the flowline to optimize settling time of drill solids in the pits. Friction reduction/lubrication. The POLY-PLUS 2000 co-polymer’s shear-thinning properties reduce power losses at points of high shear,

120


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . White liquid dispersion Odor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Slightly hydrocarbon Viscosity (typical) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200 to 500 cP Specific gravity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.06 to 1.08 pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.5 to 7.5 Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 248° F (120° C)

especially at the drill bit and at the other restrictions such as the pump discharge, drill collars, etc. The polymer structure also helps reduce turbulence, which reduces erosion and the likelihood of washouts in weak formations.

bleach per 100 gal (378.5 L) of fluid formulated with POLY-PLUS 2000 additive. Do not use perfumed liquid bleach or solid calcium hypochlorite.

Limitations

Foam stabilization. 1 to 2 vis cups (1 to 2 L) per 100 gal (378.5 L) of fluid.

POLY-PLUS 2000 co-polymer is less effective in fluids with total hardness values in excess of 200 ppm. To optimize POLY-PLUS 2000 co-polymer characteristics, total hardness should be maintained at 100 ppm or less. POLY-PLUS 2000 additive is not as effective in temperatures above 275° F (135° C). The effective temperature range can be increased to 325° F (162° C) by adding an oxygen scavenger to the mud. The effectiveness of POLY-PLUS 2000 additive also decreases in fluids that have a pH of 10.2 or greater.

Advantages


• 50% active material


Application Viscosity. Add 1 to 3 vis cups (1 to 3 L) per 300 gal (1,135 L) of fluid for desired viscosity. Shale inhibition. At least 1 vis cup (1 L) per 300 gal (1,135 L) of fluid. Fluid-loss control. At least 2 vis cups (2 L) per 300 gal (1,135 L) of fluid to be effective. Some solids can be required. Lubricity. At least 1 vis cup (1 L) per 300 gal (1,135 L) of fluid.

• Low dosage rate for comparable viscosities • Encapsulates drill solids • Stabilizes clay formations

Cleanup POLY-PLUS 2000 co-polymer can be chemically broken down with liquid bleach in regular household concentration (5% sodium hypochlorite). Use 5 gal (18.9 L) of liquid

Packaging and storage POLY-PLUS 2000 co-polymer is supplied in 5-gal (18.9-L) buckets.

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

POLY-PLUS EHV POLY-PLUS EHV acrylic co-polymer is an extremely-high-molecularweight, high-charge, polyacrylamide supplied as a dry granular powder. POLY-PLUS EHV acrylic co-polymer produces very high viscosity solutions at low dosage rates, particularly in freshwater. It has excellent handling characteristics, mixes easily and dissolves quickly when added to water-base fluid systems.

Applications POLY-PLUS EHV acrylic co-polymer is ideally suited for applications such as water-well drilling, mineral exploration, and construction applications. Due to its very high molecular weight, POLY-PLUS EHV additive is also an excellent flocculant for dewatering drilling fluids, waste pits and sumps. POLY-PLUS EHV acrylic co-polymer has several functions, including:

Flocculant. As a flowline flocculant, POLY-PLUS EHV acrylic co-polymer can also be used for clear-water or low-solids drilling. Adding a 5% solution of POLY-PLUS EHV acrylic co-polymer into the flowline or just prior to any mechanical separation greatly enhances the removal of drill solids. Friction reducer. Adding POLY-PLUS EHV acrylic co-polymer into a drilling fluid helps to reduce turbulent flow, friction, and power losses at points of high shear. Lowering turbulent flow also helps reduce erosion and washouts of fragile geologic structures. Add slowly and uniformly through a high-shear jet type mixer.

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . White, granular powder Ionic character. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Anionic Density . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.8 g/cc Bulk density. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50 lb/ft3 (800 kg/m3) pH (1% solution) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.0 to 8.0

Continue to circulate and agitate the slurry until all materials are dispersed and dissolved. Recommended application amounts:

• Provides high cohesiveness to bind sandy soil and gravel • Enhances core recovery in continuous wireline coring operations

Normal consolidated formation:

• Facilitates the removal of drilled soils from augers

1.5 to 2 lb (0.7 to 0.9 kg) per 100 gal (378.5 L) water (0.6 to 0.8 lb/bbl [1.7 to 2.3 kg/m3])

• Non-fermenting, no petroleum distillates and easily broken down with household bleach

Unconsolidated formation: 2.5 to 3.5 lb (1.1 to 1.6 kg) per 100 gal (378.5 L) water (1 to 1.5 lb/bbl [2.9 to 4.3 kg/m3])

Advantages • Provides a clay-free boring fluid that disperses easily with minimal shear • Soil stabilizer can be used to replace bentonite at a ratio of 1:100 (e.g., one 50-lb [22.7-kg] bag can replace 2.5 tons [2.3 metric tons] of bentonite in a typical geo-construction application) • Produces very-high-viscosity slurries at low dosage rates • Slurries typically have low gel strength • Slurry binds loose sand, clay, shale and gravel, facilitating their removal and preventing dispersal into the slurry • Reduces fluid loss by penetrating the surrounding soil with a highviscosity gel fluid, sealing the walls of the excavation site without the use of a conventional filter cake • Stabilizes reactive formations and is an efficient viscosifier for a clear, solids-free drilling fluid

Cleanup POLY-PLUS EHV acrylic co-polymer can be chemically broken down with liquid bleach in regular household concentration (5% sodium hypochlorite). Use 1 gal (3.8 L) of liquid bleach per 100 gal (378.5 L) of fluid formulated with POLY-PLUS EHV acrylic co-polymer. Do not use perfumed liquid bleach or solid calcium hypochlorite.

Toxicity and handling When used in accordance with the manufacturer’s published instructions, this product is considered non-hazardous. Drill cuttings exposed to POLY-PLUS EHV acrylic co-polymer should be washed with calcium hypochlorite to break down the POLY-PLUS EHV acrylic co-polymer before the cuttings can be confined or stored in a sealed container or drum.

Packaging and storage POLY-PLUS EHV acrylic co-polymer is supplied in 5-gal (18.9-L) buckets. POLY-PLUS EHV acrylic co-polymer should be stored inside under cool, dry conditions. When stored under these conditions, it has a shelf life of at least one year.


Viscosifier. As a viscosifier, the addition of 0.5 to 1 lb/bbl (1.4 to 2.9 kg/m3) of POLY-PLUS EHV acrylic co-polymer is a cost-effective way to generate viscosity in fresh- or low-salinity drilling fluids. Its shearthinning capacity ensures maximum power at the bit under high shear while retaining excellent carrying capacity under low-shear conditions.



H D D

121

H D D

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

SMOOTH GROUT 20 SMOOTH GROUT* 20 slurry is an easy-to-use bentonite-grouting composition containing highswelling sodium montmorillonite clay. It is designed for use in water wells and monitoring wells, for sealing the annular space around a well casing, and for plugging drilled holes and abandoned wells. SMOOTH GROUT 20 slurry contains no organic additives or polymers. The SMOOTH GROUT 20 system, a one-sack formulation, mixes with freshwater to yield a 20% pumpable grouting slurry with an extended working time. When set up, the SMOOTH GROUT 20 slurry develops a satisfactory seal with adequate structural strength and low-hydraulic conductivity. When properly placed, SMOOTH GROUT 20 slurry remains flexible, rehydratable and unstratified through heating and cooling cycles.

Applications • Sealing and grouting casings • Sanitary sealing in water-well construction • Sealing in monitoring wells • Plugging abandoned exploration boreholes

Advantages • Inorganic, non-fermenting and non-toxic • Develops lower-solids slurries up to 20% total active solids


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Beige to tan powder Moisture content . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8% Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 pH (8% slurry) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.0 Slurry density . . . . . . . . . . . . . . . . . . . . . . . . 9.4 lb/gal (1.1 kg/L) for 20% solids Dry bulk density. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 60 lb/ft3 (961.1 kg/m3) Screen analysis. . . . . . . . . . . . . . . . . . . 75% min. passing through 200-mesh

• Firm texture providing structural stability after grout is set


Addition method SMOOTH GROUT 20 slurry should be mixed with freshwater to obtain optimum results. The recommended mixing rate is a 50-lb (22.7-kg) sack of SMOOTH GROUT 20 slurry with 24 gal (90.8 L) of water to make a 20%-active-solids slurry. The viscosity and consistency of mixed-grout slurry can be modified by adjusting the amount of water used to obtain varying solids content. 1. Using a mixing device, blend one 50-lb (22.7-kg) sack of SMOOTH GROUT 20 slurry into 24 gal (90.8 L) of freshwater.


Packaging and storage SMOOTH GROUT 20 slurry is packaged in 50-lb (22.7-kg), heavy-duty, multi-walled, waterproof sacks. Store in a cool, dry place. Store in a dry location away from sources of heat or ignition, and minimize dust.

2. Blend, do not over-mix. The resulting slurry should look like cake batter, containing partially yielded bentonite. This pumpable slurry contains 20% solids. Pump into hole without delay.

• Easy one-sack mixing • Mixed and handled with most conventional rig equipment • Permanent, flexible seal prevents entry of contaminants from the surface • Extended working time controlled by grout-solids content

122


Water gal (L) 30 (113.6) 27 (102.2) 24 (90.8)

Solids content % 16.7 18.2 20

Usable slurry gal (L) 33 (124.9) 30 (113.6) 27 (102.2)


M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

SMOOTH GROUT 30 SMOOTH GROUT* 30 additive is an easy-to-use bentonite-grouting composition containing highswelling, sodium montmorillonite clay. It is designed for use in water wells and monitoring wells, for sealing the annular space around the well casing, and for plugging drilled holes and abandoned wells. SMOOTH GROUT 30 material contains no organic additives or polymers. A one-sack formulation of SMOOTH GROUT 30 additive mixes with freshwater to yield a 30% pumpable grouting slurry with an extended working time. When it sets up, the SMOOTH GROUT 30 slurry develops a satisfactory seal with adequate structural strength and low hydraulic conductivity. When properly placed, the SMOOTH GROUT 30 composition remains flexible, rehydratable, and unstratified though heating and cooling cycles.

Applications • Sealing and grouting casing • Sanitary sealing in water-well construction • Sealing in monitoring wells • Plugging and abandoning exploration boreholes

• Inorganic, non-fermenting and non-toxic • Develops lower-solids slurries up to 30% activity

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Beige to tan powder Moisture content . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8% Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.5 pH (8% slurry) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.0 Slurry density . . . . . . . . . . . . . . . . . . . . . . . . 10 lb/gal (1.2 kg/L) for 30% solids Dry bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 64 lb/ft3 (1,025.2 kg/m3) Screen analysis. . . . . . . . . . . . . . . . . . . 75% min. passing through 200-mesh

• Easily mixed with most conventional rig equipment • Permanent, flexible seal prevents entry of contaminants from the surface • Extended working time controlled by the grout solids content

Water gal (L) 14 (53) 15 (56.8) 16 (61)

Limitations

• Firm texture providing structural stability after grout set


Addition method


SMOOTH GROUT 30 additive should be mixed with freshwater to obtain maximum results. A 50-lb (22.7-kg) sack of SMOOTH GROUT 30 additive with 14 gal (53 L) of water makes a 30%-active-solids slurry. The viscosity and consistency of a mixed grout slurry can be modified by adjusting the amount of water used to obtain varying solids content.


1. Using a mixing device, blend one 50-lb (22.7-kg) sack of SMOOTH GROUT 30 additive into 14 gal (53 L) of freshwater.


2. Blend, do not over-mix. The resulting slurry should look like cake batter. Pump through tremie line without delay.

Solids content % 30 28.6 27.3

Usable slurry gal (L) 17 (64.4) 18 (68.1) 19 (72)


Packaging and storage SMOOTH GROUT 30 additive is packaged in 50-lb (22.7-kg), multi-walled, paper sacks and is available in bulk. Store in a dry location (slip hazard when wet) and minimize dust (use dustless systems for handling, storage, and cleanup). Material can be palletized at either 56/pallet or 70/pallet. Store in a well-ventilated area away from sources of heat or ignition. For more information, please request a product bulletin from your M-I SWACO representative.


Advantages



H D D

123

H D D

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

SMOOTH GROUT THERMAL Applications SMOOTH GROUT THERMAL* is a specially blended high-solids bentonite that can be mixed with sand in a two-part, thermally conductive grouting material. SMOOTH GROUT THERMAL can be mixed to meet a range of thermal conductivity from 0.40 to 1.20 Btu. SMOOTH GROUT THERMAL has been carefully developed as a thermally conductive grout to heighten the performance of ground-source, heat-loop applications.

Advantages SMOOTH GROUT THERMAL improves the efficiency and system performance of ground-source, heat-loop systems by matching the thermal conductivity of the surrounding soil and creating a permanent, flexible seal to prevent aquifer contamination. Depending on site soil conditions, SMOOTH GROUT THERMAL can be mixed and adjusted to meet individual thermal-conductivity requirements, improving the transfer of heat between the fluid circulated in the loop and the surrounding soil for optimum system performance.

124


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Grayish powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.62 Thermal conductivity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.4 to 1.20 Btu

Methods of addition


Place freshwater in a paddle-mixing tank of a commercial grout mixer. Start the grout mixer paddle, and add one 50-lb (22.7-kg) bag of SMOOTH GROUT THERMAL high-solids bentonite to the water. Mix for about 1 min. Add silica sand at a steady rate (1 to 2 min), and continue mixing for about 2 min to obtain a consistent mixture. Pump with a positive-displacement pump through a tremie pipe at a rate of 5 to 15 gal/min (18.9 to 56.8 L/min).


Packaging and storage SMOOTH GROUT THERMAL is packaged in 50-lb (22.7-kg) bags.

Limitations Makeup water salinity and hardness will determine mixing ability of the product.

K Btu/hr ft ° F 0.40 0.80 0.90 1.0 1.2

Silica lb (kg) 0 (0) 150 (68) 200 (91) 300 (136) 350 (159)

Water gal (L) 14 (53) 17 (64) 19 (72) 22 (83) 25 (95)

Yield 16.4 26.2 30.4 38 43.3

Weight lb/gal (kg/L) 10.2 (1.22) 13.1 (1.57) 13.4 (1.61) 14 (1.68) 14.1 (1.68)

Total solids % 30 58.5 61.2 65.2 65.7

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

TACKLE TACKLE* liquid polymer is a lowmolecular-weight, anionic thinner designed to deflocculate a wide range of water-base drilling fluids. This concentrated aqueous product has proven itself in applications from the surface to total depth. While it is frequently used as a shallow-hole thinner to knock the “fluff” out of spud mud, it also maintains effective performance in more complex systems. This synthetic additive has a high temperature limit and is not subject to bacterial degradation.

Applications TACKLE liquid polymer is an effective additive for reducing and stabilizing viscosity in a wide range of systems. It is most effective in freshwater fluids that are low in soluble calcium. TACKLE polymer is used most often in high-temperature applications and in low-solids, non-dispersed, polymer muds such as the POLY-PLUS system. Normal treatments range from 0.1 to 2 lb/bbl (0.3 to 5.7 kg/m3).

Advantages An effective deflocculant in freshwater, KCl and seawater fluids: • Thermally stable to >400° F (>204° C)

Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amber to brown liquid Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.2 to 1.3 Flash point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . >212° F (>99° C) (PMCC)

• Effective in weighted or unweighted fluids and compatible with both non-dispersed and dispersed systems • Works well as a deflocculant in POLY-PLUS polymer mud systems • Compatible with most common mud additives • A concentrated liquid thinner, easily added to the mud system through the mud hopper or directly into the surface system

Limitations Highly anionic additive precipitated by high concentrations of divalent cations such as calcium and magnesium. Total hardness must be maintained below 200 mg/L with soda ash. • Should not be used in calcium systems such as lime, gyp or untreated seawater muds that have high soluble calcium • Effectiveness is limited in high-solids mud

• Initial treatments with TACKLE additive can actually increase viscosity when the concentration is very low, ~0.1 lb/bbl (~0.3 kg/m3). Dilution to reduce the solids, in conjunction with continued treatments with TACKLE additive, reduces viscosity • Pilot tests are recommended prior to treating with this product


Packaging and storage TACKLE liquid polymer is packaged in 5-gal (18.9-L) cans. Store in a well-ventilated area away from sources of heat or ignition.


• Not subject to bacterial degradation



H D D

125

H D D

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S



Advantages • Yields more quickly than API-standard bentonite • Non-toxic and proven suitable for use in drilling potable water wells • Higher penetration rates than regular bentonite systems due to lower solids content

126












lb/100 gal 15 – 25

lb/bbl 6 – 11

kg/m3 15 – 30

25 – 40 35 – 45

12 – 18 15 – 20

35 – 50 40 – 45

5 – 10

2–5

6 – 14

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

RINGFREE RINGFREE* additive is a highly efficient, thermally stable thinner and surface-active agent that removes bentonite clays from the drillstring. It is environmentally acceptable and contains no heavy metals. Because it dissolves rapidly, RINGFREE additive immediately affects the rheology of most drilling fluids.

Applications RINGFREE additive is used primarily to prevent bit balling and mud rings. It can also be used to reduce the viscosity and gel strengths of most freshwater drilling fluids.

Advantages • RINGFREE additive is an excellent clay dispersant that quickly penetrates sticky clays that can cause tools to stick • Works quickly to alleviate hole problems and reduce costly pulling times or lost pipe


Typical physical properties Physical appearance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pale yellow liquid Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 pH as supplied. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 to 7.5

Methods of addition


• Bit balling/mud rings: Use ½ vis cup (0.5 L) per 300 gal (1,135 L) of fluid up to 0.5 to 1.5 gal (1.9 to 5.7 L) per 300 gal (1,135 L) of fluid. An alternate method is to slug rods with 1 vis cup (1 L) on connections.


• Thinning: Slowly add RINGFREE additive to the mud as needed to reduce viscosity.


Limitations Effectiveness is reduced in fluids with more than 1,000 ppm dissolved calcium and 10,000 ppm chlorides. Since RINGFREE additive reduces mud rheology, caution should be exercised when adding it to the active mud system.

RINGFREE additive is packaged in 5-gal (18.9-L) buckets. Store in a well-ventilated area away from sources of heat or ignition.


H D D


127

H D D

M I N I N G

A N D

W A T E R W E L L :

N S F

C E R T I F I E D

P R O D U C T S

M-I GEL M-I GEL* viscosifier is a premiumgrade bentonite (a sodium montmorillonite clay) that will yield 91 to 100 bbl of 15-cP mud per ton (1.7 m3/100 kg). It is used as a primary filter-cake-building, filtrationcontrol and suspension agent in freshwater systems, and has application in all water-base mud systems. M-I GEL viscosifier is a high-quality product which meets the ISO 13500 Clause 9 (formerly known as API Spec 13A, Section 9) specifications for bentonite.


Typical physical properties Physical appearance. . . . . . . . . . . . . . . . . . . . . . Light tan/gray-green powder Specific gravity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.3 to 2.6 Bulk density . . . . . . . . . . . . . . . . . . . . . . . . . . 48 to 52 lb/ft3 (769 to 833 kg/m3) ISO 135000 Clause 9 Specifications: Suspension properties (Suspension of 22.5 g into 350 cm3 water): Viscometer dial reading at 600 fpm. . . . . . . . . . . . . . . . . . . . . . . . . . 30, min. Yield point/plastic viscosity ratio . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3, max. Filtrate volume . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 cm3, max. Residue >75μ (wet screen) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4% wt, max.

Applications M-I GEL viscosifier is a cost-effective means of achieving viscosity, fluidloss control and filter-cake quality in freshwater and seawater muds. Typical concentrations for M-I GEL viscosifier range from 5 to 35 lb/bbl (14.3 to 100 kg/m3). As with all bentonite products, the yield decreases as water salinity increases. In muds containing more than 10,000 mg/L chlorides, the performance of M-I GEL viscosifier is significantly reduced unless prehydrated in freshwater before adding to the mud system.

Advantages • Hydrates more than other types of clays and is best for generating viscosity, developing gels for suspension and controlling filtration

128

• Small particle size, unique flat shape and high surface area of hydrated M-I GEL viscosifier provides superior filtration characteristics

Handle as an industrial chemical, wearing protective equipment and observing the precautions as described in the Material Safety Data Sheet (MSDS).

• Promotes the deposition of thin, compressible filter cakes in the wellbore


Limitations • Performance reduced in salty (>5,000 mg/L Cl–) or hard (>240 mg/L Ca++) waters due to decreased hydration


M-I GEL viscosifier is packaged in 100-lb (45.4-kg), multi-walled, paper sacks, 88-lb (40-kg) sacks, big bags and is available in bulk. Store in a dry, well-ventilated area. Keep container closed. Store away from incompatibles. Follow safe warehousing practices regarding palletizing, banding, shrinkwrapping and/or stacking.

DRILLING SOLUTIONS

Wellsite and project engineering Simulation software Drilling-fluid systems and additives ALPINE SPECIALTY CHEMICALS* FEDERAL* Wholesale HDD Mining & Waterwell Technical support Cuttings transport and handling

Cuttings treatment Mud mixing Oilfield screens Pressure control Rig-equipment engineering Rig instrumentation Solids control Waste injection

Cuttings transport and handling

Production waste management

Cuttings treatment

Rig-equipment engineering

Enhanced fluids treatment Mud mixing Oilfield screens

Rig instrumentation

Pressure control

Waste injection

Solids control Vessel cleaning Water treatment

ENVIRONMENTAL SOLUTIONS

WELLBORE PRODUCTIVITY

Spacers and displacement chemicals Specialized tools

Fluid-loss-control systems Intervention fluids Packer fluids Breakers

Completion fluids Filtration

Oilfield/production chemicals

Produced water management

Chemical management

Production-tank cleaning

H2S removal

Production waste management

Drag reduction

Enhanced fluids treatment Vessel cleaning

Water treatment

PRODUCTION TECHNOLOGIES

www.miswaco.com

©2008 M-I L.L.C. All rights reserved. *Mark of M-I L.L.C.


Engineering/simulation software Reservoir drill-in fluids


A complete array of services available worldwide

129

R I G - E Q U I P M E N T

E N G I N E E R I N G

Integrated Package Delivery ឣAPPLICATIONS

Any well or DWM project where there is room for improvement in drilling time, production rates, environmental issues and overall costs.

ឣPROBLEMS

When equipment and processcontrol systems have not been fully integrated, overlap of effort, ineffective project management, lost time and increased environmental risk result.

ឣSOLUTIONS

Integrated Package Delivery in the areas of fluids, drilling waste management equipment and processcontrol encourages the use of flexible yet defined processes working in concert. From in-depth project understanding to strategic management, the solutions afforded by IPD enable seamless operations.

ឣECONOMICS

As part of a realistic, unified plan, project-specific bulk-handling and drilling waste management packages result in reduced costs of shared materials and spares, improved operational efficiency, and reduced risk.

ឣENVIRONMENTAL Integrated equipment and processcontrol packages help ensure the right balance between production and environmental impact.

Reduce risk. Lower costs. Get measurable, improved results on your next project. Those are the exact results that the M-I SWACO Integrated Package Delivery (IPD) capabilities deliver through integrated mud mixing, fluids processing, drilling and Drilling Waste Management (DWM). We can apply this integration to our drilling and DWM product lines across the globe, helping you succeed in harsh environments, where extended life requirements of assets and facilities matter most, where QHSE issues demand continual close attention, and where it

makes good business sense to reduce spares. As the world’s largest supplier of drilling and completion fluids and drilling waste management equipment, M-I SWACO can take you from flowline to ultimate reuse or disposal as a logical extension of our vast knowledge of fluid technology and management. Our Aberdeen-based IPD organization manages the design, procurement, manufacture, installation and commissioning of custom-built, integrated equipment packages for M-I SWACO operations worldwide. The team also has offices in Houston, Stavanger, Volgograd and Singapore.

Features and Benefits • Meet goals faster and more efficiently through informed, up-tothe-minute engineering decisions • Achieve higher-quality results from improved project insight • Maximize the drilling fluids program through detailed engineering equipment design and process

• Reduce non-productive time through remote control and monitoring • Mitigate QHSE incidents through preliminary planning, removal of personnel from hazardous environments and consistent documentation

This is a summary page. For complete information, please refer to the 2008 M-I SWACO ENVIRONMENTAL SOLUTIONS catalog. 130

C O N T R O L :

S O L I D S - C O N T R O L

S Y S T E M S

Solids-Control Systems ឣAPPLICATIONS

Onshore and offshore rigs where an integrated approach to fluids and cuttings processing is needed to maximize the operational efficiency of the drilling rig.

ឣPROBLEMS

The design of some solids-control systems does not reflect changes in technology, regulatory requirements and the increasing operational challenges of drilling in new frontiers.

ឣSOLUTIONS

M-I SWACO has proven experience in fluids-related technologies, advanced research and development in solids control, systems knowledge and capabilities, and QHSE excellence.

ឣECONOMICS

By optimizing the solids-control system design and integration with our fluids knowledge, we improve drilling efficiency and reduce operational costs.

Improve drilling efficiency and environmental compliance with an integrated solidscontrol system

ឣENVIRONMENTAL

The goal of all modern solidscontrol systems is to reduce overall well costs through the efficient removal of drilled solids while reducing and minimizing the loss of drill fluids. Additional goals include worker health and safety and environmental compliance. The key to designing the best systems in the market comes down to working with the rig designers,

M-I SWACO solids-control and cuttings-handling systems are customized to meet local compliance and regulatory guidelines.

contractors, operators and ship yards to provide the best in class. To operate each type of equipment so that the maximum separation efficiency is achieved requires a lot of thought, and many factors must be considered. The quantity and sizing of equipment must be specific so that the efficiency of the solidscontrol system can be maximized through data such as final volume of mud accumulated while drilling, total volume of solids removed and fluid dilution rates. The greater percentage of drill solids removed and drilling fluid preserved, the higher the operating efficiency.

This is a summary page. For complete information, please refer to the 2008 M-I SWACO ENVIRONMENTAL SOLUTIONS catalog.

Delivering solutions

Mud returns with drill solids

Header boxes designed with controlled flow distribution and purpose-built controls

Clean mud Latest shaker and screening technology

Drill solids Waste disposal

S I M U L AT I O N S O F T WA R E DRILLING-FLUID SYSTEMS AND ADDITIVES A L P I N E S P E C I A LT Y C H E M I C A L S H D D M I N I N G A N D WAT E R W E L L RIG-EQUIPMENT ENGINEERING SOLIDS CONTROL CUTTINGS TRANSPORT AND HANDLING OILFIELD SCREENS WASTE INJECTION C U T T I N G S T R E AT M E N T PRESSURE CONTROL R I G I N S T R U M E N TAT I O N

S O L I D S

131

S O L I D S

C O N T R O L :

M U D

M I X I N G

Mud-Mixing System ឣ

A P P L I C A T I O N S

ឣ

P R O B L E M S

ឣ

S O L U T I O N S

Onshore and offshore rigs where logistics demand that drilling and completion fluids be mixed onsite with the same degree of safety, accuracy and thoroughness as fluids mixed at a mud plant.

Manually introducing drilling-fluid additives to the fluid stream can pose health hazards, can result in inaccurate mixtures and can reduce the productivity of rig personnel.

The customizable mud-mixing system from M-I SWACO is designed, manufactured and installed by people with a thorough understanding of the mixing process and the attendant health, safety and environmental issues.

ឣ

E C O N O M I C S

The safety, accuracy, automation and design features of the M-I SWACO Mud-Mixing system result in increased worker safety and the savings in time and money that result from the system’s features.

ឣ


The enclosures and automated features on system components greatly reduce the exposure of rig personnel to potentially hazardous materials.

Regardless of rig size or project complexity, M-I SWACO will use our operational and engineering experience to design a system that meets the customers and market expectations. We will then engineer, fabricate and commission the mud-mixing system required to perform efficiently and safely. Whether it’s a single HIRIDE* eductor, or a fully automated, touchscreen-controlled, multifunction system, it will deliver the best performance available. If one quality best describes the system, it is “versatility.” Originally conceived for mixing drilling fluids, an M-I SWACO system can be designed for completion fluids as well. Rugged construction, using low-temperature carbon steel and stainless steel, ensures long life in hostile environments. All components feature a minimized footprint and the flexibility to be positioned as rig space dictates.

System components • Solids induction – Bulk-bag-additive unit – Surge tank – Automatic sack slitter and pallet lifter

• HIRIDE* eductor • HISIDE* blender (rental) • Liquids injection – Caustic soda mix tank – Chemical-additive unit • System control — The overall control system for the fluidsmixing package consists of a Programmable Logic Controller (PLC) control cabinet networked via Ethernet to a server panel holding two redundant server PCs, a logger PC and viewer monitors. A maintenance and diagnostic Profibus MPI network is provided for diagnostic and maintenance tasks. The Mud-Mixing system runs on Cimplicity Plant Edition^ which is run on the Windows XP^ operating system as the main SCADA package. A Microsoft SQL server is configured as the logging PC to afford reliable historic data logging and retrieval. User interface and system control is achieved via a trackball/mouse and keyboard. All communications between the application PLCs and the workstations are controlled via the M-I SWACO dual redundant servers.


^Cimplicity Plant Edition is a mark of GE Fanuc Automation. ^Windows XP is a mark of Microsoft Corporation.

C O N T R O L :

S H A K E R S

MEERKAT PT Shale Shaker

ឣAPPLICATIONS Drilling rigs and separation operations where space is at a premium and performance requirements are high.

ឣPROBLEMS

Because drilling rates and conditions change as drilling progresses, solids-control equipment must handle varying solids characteristics. When premium drilling fluids are used, maximum fluids recovery is of critical concern.

ឣSOLUTIONS

The dual-motion MEERKAT* PT shaker not only manages the high cuttings volumes associated with surface hole sections (linear motion), it can change on the fly to balanced elliptical motion for longer cuttingsretention times. Shaker performance gets an extra boost from M-I SWACO specialists and field personnel who provide expert advice and service.

ឣECONOMICS

The generous throughput capacity of the shaker can handle cuttings loads generated by high ROP, saving rig time. The balanced elliptical motion recovers greater amounts of valuable drilling fluid, produces drier cuttings for easier disposal and prolongs screen life.

ឣENVIRONMENTAL The MEERKAT PT shaker processes cuttings more thoroughly than conventional units, producing cuttings that require less treatment for disposal. The thorough processing also reduces the need for dilution which results in smaller waste volumes.


The flexibility of dual motion The dual-motion shale shaker that adapts as solids change M-I SWACO has combined linear and balanced elliptical motion technology to create the revolutionary MEERKAT PT dual-motion shaker. The design incorporates a 0.6-hp vibrator motor that allows it to perform on an unparalleled level. But as drilling conditions change, the MEERKAT PT dual-motion shaker

can be adjusted “on the fly.” Simply flipping a switch on the control box reconfigures the shaker from linear to balanced elliptical motion. There is no need to suspend or shut down operations. With the MEERKAT PT shaker operating in the gentler balanced elliptical mode, solids encounter reduced G-forces and longer screen residence time. This results in drier solids, improved drilling-fluid recovery, longer screen life and reduced operating costs.

Features and Benefits • Units can be customized to meet both tight-space requirements and high-performance criteria • All configurations are compact and modular • Linear motion for fast conveyance and heavy loading; balanced elliptical motion for maximum retention time and drier cuttings • Elliptical motion at the flip of a switch without stopping the shaker • Balanced basket functions flawlessly in either linear or balanced elliptical mode, with dry, light loads or wet, heavy loads • Most reliable mechanical jacking system in the industry —

simple and easy to use; requires no pinning • Unique distribution box option can replace flowline possum belly, providing increased handling capacity and dampening the velocity of fluid from the flowline • Pre-tensioned composite screens for fast screen changes and overall ease of use • Ultra-tight seal between screen and screen bed eliminates solids buildup and costly bypass of solids • Largest net-usable screen area among shakers of similar footprint: 15.9 ft2 (1.5 m2)


S O L I D S

133

S O L I D S

C O N T R O L :

S H A K E R S

MONGOOSE PT Linear- and Dual-Motion Shale Shaker

ឣAPPLICATIONS

Onshore and offshore projects where shaker size is a significant issue and where cuttings with varying quantities and properties are experienced.

ឣPROBLEMS

Because drilling rates and conditions change as a well progresses, solidscontrol equipment must handle varying solids characteristics. When premium drilling fluids are used, maximum fluids recovery is of critical concern.

ឣSOLUTIONS

The dual-motion MONGOOSE* PT shaker not only manages the high cuttings volumes associated with surface hole sections (linear motion), it can change on the fly to balanced elliptical motion for longer cuttingsretention times. Shaker performance gets an extra boost from M-I SWACO engineers and field personnel who provide expert advice and service.

ឣECONOMICS

The generous throughput capacity of the shaker can handle cuttings loads generated by high ROP, saving rig time. The balanced elliptical motion recovers greater amounts of valuable drilling fluid, produces drier cuttings for easier disposal and prolongs screen life.

ឣENVIRONMENTAL

The MONGOOSE PT shaker processes cuttings more thoroughly than conventional units, producing cuttings that require less treatment for disposal. The thorough processing also reduces the need for dilution which results in smaller waste volumes. This is a summary page. For complete information, please refer to the 2008 M-I SWACO ENVIRONMENTAL SOLUTIONS catalog. 134

1Patents

applicable to MONGOOSE PT include 6,485,640; 6,513,664; 6,679,385; 6,746,602; 6,838,008.

The flexibility of dual motion The dual-motion shale shaker that adapts as solids change M-I SWACO has combined linear and balanced elliptical motion technology to create the revolutionary MONGOOSE PT dual-motion shaker. The MONGOOSE PT design incorporates a 0.6-hp vibrator motor1 that allows it to perform on an unparalleled level. But as drilling conditions change, the MONGOOSE PT dual-motion shaker can be adjusted “on the fly.” Simply flipping a switch on the control box reconfigures the shaker from linear to balanced elliptical motion. There is no need to suspend

or shut down operations. With the MONGOOSE PT shaker operating in the gentler balanced elliptical mode, solids encounter reduced G-forces and longer screen residence time. This results in drier solids, improved drilling-fluid recovery, longer screen life and reduced operating costs.

The economy of linear motion The dual-motor MONGOOSE PT linear-motion shaker is especially effective while drilling top-hole sections where heavy, high-volume solids are usually encountered. In these intervals, shakers need to generate high G-forces to effectively move dense solids across the screens.

Features and Benefits • Linear motion for fast conveyance and heavy loading; balanced elliptical motion for maximum retention time and drier cuttings • Elliptical motion at the flip of a switch without stopping the shaker • Balanced basket functions flawlessly in either linear or balanced elliptical mode, with dry, light loads or heavy loads • Most reliable mechanical jacking system in the industry — simple and easy to use; requires no pinning

• Unique distribution box option can replace flowline possum belly, providing increased handling capacity and dampening the velocity of fluid from the flowline • Pre-tensioned composite screens for fast screen changes and overall ease of use • Ultra-tight seal between screen and screen bed eliminates solids buildup and costly bypass of solids • Largest net-usable screen area among shakers of similar footprint: 21.2 ft2 (1.97 m2)

C O N T R O L :

S H A K E R S

BEM-650 Shale Shaker 650 ឣAPPLICATIONS

Offshore and onshore projects where more effective fluids/solids separation is required in addition to the reduction of costs related to shaker performance.

ឣPROBLEMS

Conventional shakers exhibit one or more — or all — of the following: inefficient solids handling and fluid recovery, screen blinding, premature screen wear and safety issues.

ឣSOLUTIONS

The BEM-650* shaker is the thirdgeneration balanced elliptical motion shale shaker from M-I SWACO. It provides better solids removal and fluid recovery with less screen wear while occupying a relatively small footprint.

ឣECONOMICS

Significantly drier cuttings, improved solids removal and fluid recovery at high feed rates, longer screen life and minimal downtime add up to significant savings.

ឣENVIRONMENTAL More efficient fluids/solids separation results in significantly smaller disposal volumes of dryer cuttings.

Features and Benefits • Patented1, balanced elliptical motion produces a drier cuttings discharge and results in improved separation efficiency • Stainless steel construction reduces maintenance costs as a result of low corrosion • State-of-the-art motion generators are oilfield proven and require minimal maintenance • Flowback pan between top and bottom decks maximizes effective screening area • Integral scalping deck improves process capacity, reduces installation costs and improves primary deck screen life • Gumbo slide design minimizes gumbo buildup • Dual-angle bottom deck improves separation of water-base-mud cuttings • Shallow header tank delivers better fluids distribution to screens with no solids settling • Sloping sump design with left and/or right discharge minimizes settling of ultra-fines • Meets certification requirements at highest level — ATEX, NORSOK, CE and UL-rated versions available • Low operational noise levels ensure safety • Extra-long drip lips • Easy-to-install optional vaporextraction hood reduces operator exposure to vapors associated with drilling fluids • M-I SWACO design and service organization provides assistance with rig installation surveys, flow-distribution design to shakers, as well as shaker house and solids-control system design

Controls

Flow-Distribution Box

Two Inspection/Cleanout Ports

• Detachable flow-distribution box with built-in lift points allows for flexible installation • Allows true, “cold” installation to 10-in. (254-mm) pipe flange • No welding, torch cutting or grinding is necessary • Two large slide gates, with reliable tab/slot locators, reduce tendency to clog with gumbo

• Removable cover allows easy access for rear-screen inspection and maintenance • Contains splashing and prevents fluid loss during surges • Improves access to rear clamp blades

• Control panel, with simple start/stop button is suitable for remote operation, reducing operator exposure to vapors associated with drilling fluids • Easy-to-use pneumohydraulic deck-angle adjustment2 reduces mud losses from screens • Bed-angle indicator aids accurate adjustment of basket angle

Screen Technology • Composite screen technology increases effective open area, improves process capacity and maximizes screen life • Special, lightweight screen design allows for easier screen handling • Pre-tensioned screens (top and bottom decks) allow for quicker screen changes • All screens front load to improve operator safety

Screen-Clamping System • Operated by single three-way, three-position SST ball valve • Pressure regulator permanently set to proper operating pressure • Pneumatic quick clamping of screens3 for quick screenchanging operations • Screen clamping and angle adjustment operated by rig air supply, lowering maintenance and utilities • All components bolt on • Clamp blade axles cast into part with larger shaft size • Clamp blade receivers have tighter tolerance and increased materials depth

This is a summary page. For complete information, please refer to the 2008 M-I SWACO ENVIRONMENTAL SOLUTIONS catalog. 1Vibratory 2Patent

Screen Separator U.S. Patent No. 5,265,730 pending

3U.S. Patent No. 6,513,665


S O L I D S

135

S O L I D S

C O N T R O L :

M U D

C L E A N E R S

High-Volume Mud Cleaners The M-I SWACO line of mud cleaners consists of a two-stage separation process using a combination of hydrocyclones mounted over a shale shaker to operate as a single unit. Designed to handle the entire circulating volume, mud cleaners are effective on both weighted and unweighted drilling-fluid systems in removing and drying solids while retaining the expensive liquid. The hydrocyclones make the primary separation with underflow directed onto the shaker’s vibrating screen. Used correctly, the M-I SWACO mud cleaners lower both drilling-fluid and disposal costs. Versatile. M-I SWACO mud cleaners can be configured with an M-I SWACO D-SILTER*, a D-SANDER* or both over a high-performance shaker to process weighted or unweighted drilling-fluid systems. Environmentally efficient. Removing and drying drilled solids helps meet environmental regulations by minimizing waste generated and reducing disposal costs. Minimizes maintenance. Continuous removal of sand and abrasive cuttings from drilling fluids cuts downtime and reduces repair and replacement of worn parts on downstream equipment.

Features and Benefits • Assists with environmental compliances • Cuts downtime and reduces repair • Complete product line provides diverse configuration options • Field-proven performance • Lowers drilling-fluid and disposal costs • Minimizes maintenance on downstream equipment • Compatible with oilor water-base muds • Effective in controlling drilled solids and retaining expensive barite

136

Wide range of mud cleaners for your drilling-fluid system. M-I SWACO mud cleaners are available in a variety of configurations. The Model 6T4 (12 clone), Model 8T4 (16 clone) and Model 10T4 (20 clone) D-SILTERS, when matched with an M-I SWACO shale shaker, provide processing rates from 900 to 1,500 GPM (3,406.9 to 5,678.1 L/min). The Model 2-12 D-SANDER, when matched with an M-I SWACO shaker, provides processing capabilities to 1,000 GPM (3,785.4 L/min).

The three-in-one Model 2-12 D-SANDER and Model 6T4 (12 clone) D-SILTER mounted over an M-I SWACO high-performance shaker provides the most versatile separation combination package with rates of 1,000 and 900 GPM (3,785.4 and 3,406.9 L/min) respectively.

Works with oilor water-base muds M-I SWACO mud cleaners are designed to work with either oil- or water-base weighted muds, as well as with either dispersed or non-dispersed muds. They are also effective on unweighted drilling-fluid systems, removing fine drilled solids while retaining expensive liquid phases. Fieldproven, M-I SWACO mud cleaners are especially effective in controlling drilled solids and retaining expensive barite when used in conjunction with M-I SWACO fine-screen shale shakers and centrifuges.


C O N T R O L :


414 CENTRIFUGE The M-I SWACO 414 CENTRIFUGE* delivers high performance and low operating costs for oilfield and industrial mud and fluidshandling applications. This highly efficient decanting centrifuge recovers up to 95% of barite and returns it to the active system, while rejecting finer, low-gravity solids. The advanced design of the stainless steel bowl and scroll maintains an even layer of conveyed solids for more uniform separation and maximum solids-control efficiency.

Features and Benefits

The M-I SWACO 414 CENTRIFUGE — precision equipment engineered to handle rugged oilfield service.

• Balanced scroll design increases recovery capacity • Efficient operation processes up to 140 GPM (530 L/min) with a 6- to 10-micron cut on weighted mud systems; processes up to 250 GPM (946.4 L/min) with a 5- to 7-micron cut point on unweighted mud • Stainless steel bowl, scroll compartment and cover to resist corrosion and abrasion • Tungsten-carbide scroll points with wide spacing of flights at the narrow end create a finer layer of conveyed solids for more uniform separation under high G-forces • Precision balanced to run at high RPMs for extended periods with greater efficiency, minimizing maintenance and downtime • Operating safety controls include self-limiting vibration and torque switches to protect against catastrophic failure

• Variable speed electro-hydraulic backdrive is available as an option for the 414 CENTRIFUGE • Recovers up to 95% of barite, minimizing costly additions while maintaining prescribed mud weights • Rejects finer, low-gravity solids from drilling fluids • Cost-efficient operation — reduces discard volume versus dilution displacement alternatives 30 to 60% depending upon mud weights • Ideal for use with weighted or unweighted mud systems • Rugged construction and corrosion-resistant materials provide long service life and low maintenance costs in the toughest oilfield environments

Liquid zone

Drying zone

Whole mud feed


Liquid return to active

Pool

Beach

Solids discard


S O L I D S

137

S O L I D S

C O N T R O L :


518 CENTRIFUGE The M-I SWACO 518 CENTRIFUGE* is the premier high-speed, decanting centrifuge for drilling-mud and fluids-handling applications. Ruggedly built for oilfield and industrial service, it is especially effective in environmentally sensitive areas. It delivers high fluidrecovery rates and efficient solids control to significantly reduce the costs of makeup fluids and disposal. The M-I SWACO 518 CENTRIFUGE is precision-balanced for smooth operation over long periods at speeds of 1,900 to 3,250 RPM, generating centrifugal forces up to 2,100 G’s.

Features and Benefits • Innovative design includes longer bowl for increased retention time, resulting in drier solids and finer cut points • Tungsten carbide scroll points with wide spacing flights at tapered end create a finer layer of conveyed solids for consistent, uniform separation and maximum solids-control efficiency • Stainless steel bowl, scroll, compartment and cover resist corrosion and provide long service life • Precision balanced to run at high RPMs for extended periods with greater efficiency, minimizing maintenance and downtime

• Skid mounted, low profile minimizes space requirements • Effectively removes the finest silts and returns valuable fluids for reuse • Reduces makeup fluids, dilution, cleanup and disposal costs • Ideal for any solids-control application; especially valuable in environmentally sensitive areas • Rugged construction and corrosion-resistant materials provide long service life and low maintenance costs in the toughest oilfield environments • Works efficiently with other M-I SWACO equipment to maximize solids control

How it works The heart of an M-I SWACO centrifuge is its high-speed, precisionbalanced rotating stainless-steel bowl. Inside the bowl, a doublelead spiral-screw conveyor rotates in the same direction as the bowl but at a slightly slower RPM. Feed slurry enters through a hollow axle at the narrow end and is distributed to the bowl. Centrifugal force as high as 500 G’s at 1,900 RPM (or 2,100 G’s at 3,250 RPM) holds the slurry against the Liquid zone


bowl wall in a “pool.” Trapped silt and sand-sized particles settle and spread against the bowl wall where they are conveyed to the solids underflow discharge ports by tungsten-carbide-tipped scroll flights. Silt and sand particles exit damp, but with no free liquid. The free-liquid phase carries the fine, 2- to 3-micron-size particles through the nonplugging stainless steel and tungstencarbide hardfaced-discharge ports. Drying zone

Whole mud feed

Liquid return to active

Pool

Beach

Solids discard

C O N T R O L :


CD-500 CENTRIFUGE High-volume solids removal. The CD-500 CENTRIFUGE can process up to 200 GPM (757.1 L/min) of drilling fluid. Variable bowl speed. The bowl speed can be adjusted infinitely from 379 G’s at 1,200 RPM to 2,066 G’s at 2,800 RPM to control particle separation (cut point) for improved solids removal or cleaner effluent: • At 1,600 RPM and feed rates of 200 GPM (757.1 L/min), it provides a D90 cut point of 8 to 12 microns, depending upon the composition of the mud • At 2,800 RPM and feed rates of 100 GPM, (378.5 L/min) it provides a D90 cut point of 3 to 6 microns, depending upon the composition of the mud Variable-speed pump. Calibrating pump speed with feed rate allows an optimum relationship between the two variables that improves solids-control efficiency. Programmable Logic Controller (PLC). The PLC makes and monitors speed adjustments and may be housed within an explosion-proof enclosure. RPM readouts of the conveyor and bowl are displayed at the control panel. Tungsten-carbide scroll points. Tungsten-carbide hardfaced points at the tapered end of the scroll protect the conveyor against wear. Specially designed, widely spaced flights. Conveyor pitch in the conical section is designed

to reduce plugging and promote maximum solids removal at highdifferential speeds. Stainless steel components. The stainless steel bowl, scroll, compartment and cover resist corrosion and provide long service life. Operating safety controls. Safety features include self-limiting vibration and torque switches to protect against catastrophic failure known to occur in other “high-speed” centrifuges. Drive options. The centrifuge can be supplied with a number of drives: standard electric, PLCcontrolled; variable-frequency drive; or hydraulic drive. Mounting options. For tight-fitting offshore installations, the centrifuge can be supplied with a pedestal mount. For land applications, the low-mount design allows for a simple centrifuge stand with one set of handrails.

Features and Benefits • Provides precise control over the separation process to accommodate variations in solids loading and material sizes; can be regulated to produce cleaner effluent • High-volume processing • Adjustable speeds on bowl, scroll and pump • Automatic PLC monitoring and adjustment compensates for varied drilling conditions, while reducing operator involvement and effort • Allows drilling at high ROP • Runs efficiently at high speeds for prolonged periods • Rugged construction and corrosion-resistant materials provide long service life and low maintenance costs in the toughest oilfield environments • Protection against failure at high speeds • Reduces solids packoff • Works efficiently with other M-I SWACO equipment to maximize solids control

How it works The heart of the M-I SWACO CD-500 CENTRIFUGE is its highspeed, precision-balanced rotating stainless steel bowl. Inside the bowl, a single-lead spiral-screw conveyor rotates in the same direction as the bowl but at a lower RPM. Feed slurry enters through a hollow axle at the narrow end and is distributed to the bowl. Centrifugal force as high as 379 G’s at 1,200 RPM (or 2,066 G’s at 2,800 RPM) holds the slurry against the

bowl wall in a “pool.” Trapped silt and sand-sized particles settle and spread against the bowl wall where they are conveyed to the solids underflow discharge ports by the tungsten-carbide-tipped scroll flights on the conveyor. Silt and sand particles exit damp, but with no free liquid. The cleaned fluid is discharged through weirs that regulate the pool depth.



S O L I D S

139

S O L I D S

C O N T R O L :


CD-600 CENTRIFUGE The CD-600 CENTRIFUGE* from M-I SWACO is specially engineered for high-volume drilling. Controlled and monitored via a Programmable Logic Controller (PLC), the centrifuge experiences less solids packoff, produces cleaner effluents, requires fewer operating personnel and features automatic adjustment for different operating conditions. A touch screen on the operator’s console provides the interface for monitoring the RPM of the conveyor and bowl and for adjusting motor

speed. The manual control panel for the centrifuge has the option for operating the centrifuge manually or automatically. The main drive speed can be adjusted on the touch screen panel when operating the CD-600 CENTRIFUGE manually.

Features and Benefits • High processing volumes • Resists packoff • More thorough processing for cleaner effluents • Requires fewer operating personnel • Automatically adjusts to changing drilling conditions • Manual or automatic control via touch-screen or manual control panel

Specifications Physical Data • Bowl size • Length • Width • Height • Weight

Conveyor 23.5 x 76 in. (598 x 1,928 mm) 178 in. (4,500 mm) 87 in. (2,210 mm) 85 in. (2,145 mm) 19,842 lb (9,000 kg)

Rotating Assembly • Length • Lambda ratio • Weight

• Weight • Type • Pitch • Material: Body Flighting Hard-facing

115 in. (2,911 mm) 3.23 (bowl length/ bowl inside diameter) 2,116 lb (960 kg)

Gear Box

23.5 in. (598 mm) 52 in. (1,322 mm) Duplex A890 (4A)

• Gear ratio • Torque

• Type

Cylindrical Section • Diameter • Length • Material

Conical Section • Diameter, large end • Length • Diameter, small end • Cone angle • Material: Conical section Discharge ports

23.5 in. (598 mm) 23.9 in. (606 mm) 18 in. (450 mm) 7° Duplex A890 (4A) Tungsten carbide (hard facing/HRC 67)

Duplex A890 (4A) AISI 304 stainless steel Tungsten carbide (hard facing/HRC 67) Two-stage ZSPN 621-190-87 (Cyclo SUMITOMO gear box) 87:1 9,330 ft-lb (12,650 Nm) maximum 198 lb (90 kg) Variable, 1 to 50 rpm

Control System • Automatic control by PLC • Closed-loop hydraulic power package with 180-hp electric motor • Touch-screen panel

Area Equivalent • Ae = 2.114 x 106 m2

Overload Protection • Primary • Secondary

• Weight • Differential speed

1,080 lb (490 kg) One lead 5.9 in. (150 mm)

Electrical Resettable back drive of the torque limiter

Theoretical Solids-Conveying Capacity at 50-rpm Differential Speed • Qs = 38.594 m3/hr

Maximum G-force at 2,600-rpm Bowl Speed • G = 2.267 x 103 or 2,267 G


C O N T R O L :

F L U I D S

P R O C E S S I N G

S Y S T E M

( F P S )

FLUIDS PROCESSING SYSTEM (FPS) ឣAPPLICATIONS

Land rigs that require a high degree of control over the solids-control function in order to reduce costs, improve solids-control efficiency and satisfy the most demanding environmental requirements.

ឣPROBLEMS

Despite growing performance and environmental demands on land rigs, the solids-control systems on many rigs are collections of equipment from various sources, with little or no fine-tuning and real integration to optimize performance.

ឣSOLUTIONS

The FLUIDS PROCESSING SYSTEM* (FPS*) from M-I SWACO is a complete solids-control solution — from shale shakers to centrifuges to D-GASSER units — strategically combined into a single, skid-mounted unit.

ឣECONOMICS

Typical rig-owned solids-control equipment is less than 50% effective; the M-I SWACO FPS units achieve 80 to 90% efficiency in solids removal and drillingfluids recapture.

ឣENVIRONMENTAL The system is designed to reduce or entirely eliminate the need for reserve pits, minimize waste and help satisfy the most stringent environmental requirements.

The FLUIDS PROCESSING SYSTEM from M-I SWACO is a complete solids-control solution — from shale shakers to centrifuges to D-GASSER units — strategically combined into a single, skidmounted unit. Just as important, every FPS comes with a round-theclock service crew, backed by a system supervisor and on-call technical services engineers.

System integration. Instead of a collection of equipment from various sources, the FPS is a fieldproven network of solids-control components specifically designed to function as a single unit. Custom engineering. M-I SWACO analyzes well parameters and drilling objectives for each application and tailors the right combination of equipment for optimal results.


Features and Benefits Improved Efficiency and Processing Rates • M-I SWACO FPS units achieve 80 to 90% efficiency in solids removal and drilling-fluids recapture • Increased ROP of nearly 40% • Average 37% reduction in drill bit consumption • An average of 33% faster in drilling days to TD • Helps prevent lost circulation • Reduces circulation time to condition mud • Reduces pump maintenance and downtime • Reduces potential for stuck pipe and hole problems • Improves well logging, mud circulation and mud conditioning

Cost Savings

Equipment Features

• Reduces mud costs up to 43% • Reduces costs of transporting makeup water, diesel and chemical makeup materials • Significantly reduces site preparation and restoration costs • Reduces waste haul-off expense

• Skid shakers and MUD/GAS SEPARATOR (MGS) together for one lift • MGS pivots down for easy moving • Hydroclones fold into tanks • Tanks designed for easy cleaning, easy operating and moving faster • Tanks designed for easy operating • Optional covered tank design to eliminate roofs • Optional cantilevered skid (mechanical or hydraulic) • Tanks designed for QHSE issues • Cantilever walkways reduce pinch points (quicker rig up/down) • Reduces trip hazards by having valves on side of tank • Reduces operator fatigue

Environmental Advantages • Reduces or entirely eliminates the need for reserve pits • Minimizes waste • Helps satisfy the most stringent environmental requirements

Flexibility • Versatile enough for use with water-, oil- or synthetic-base fluids • Saves transport and assembly time


S O L I D S

141

C U T T I N G S

T R A N S P O R T

A N D

H A N D L I N G

CLEANCUT Cuttings Collection

ឣAPPLICATIONS

Offshore and onshore projects where large amounts of drill solids must be handled and stored prior to shipment.

ឣPROBLEMS

Under increasingly stringent regulations dictating zero or near-zero discharge of drill solids, and with increased concerns of personnel safety, operators have had to rethink the way in which cuttings contaminated with oil- and synthetic-base drilling fluids are handled.

ឣSOLUTIONS

The CLEANCUT* process provides a complete field-proven method for containing, handling, temporarily storing and transporting drill cuttings within a totally enclosed and protected environment. Our experienced engineers and technical personnel ensure that you get the exact system you need.

ឣ

E C O N O M I C S

The CLEANCUT system can handle cuttings generated at high ROP, reducing and even eliminating downtime caused by overloaded processing equipment. The flexible configuration can be engineered to fit rig layouts with small equipment footprints.

ឣENVIRONMENTAL The totally enclosed system design prevents exposure of personnel and the environment to contaminated wastes, even in extreme arctic and tropical conditions.

In addition to deeper water depths, complex logistics and hostile environments, offshore operators face another challenge — zero, or nearzero, discharge of drill solids. With increasing environmental regulations, operators have had to rethink the way in which cuttings contaminated with oil- and synthetic-base drilling fluids are handled.

New thinking solves an old problem It’s not that other companies haven’t tried to remediate the cuttings disposal situation; they have. Skip-and-ship, slurrification and re-injection are just some of the methods devised for coping with this situation. In contrast, the CLEANCUT process is the comprehensive, economical solution that is borne of three decades of proven M-I SWACO materials handling and worldwide

waste-management expertise. The result is a complete field-proven method for containing, handling and transporting drill cuttings. By looking at the problem of cuttings disposal from the operator’s perspective, we have developed a totally enclosed system for pumping cuttings from shaker to storage, storage to boat and then from boat to a receiving station onshore prior to processing. The increase in safety and reduction of environmental exposure is obvious to even the casual observer.

Features and Benefits Safety

Reliability

• Crane lifts are minimized, improving offshore safety • Conveying is fully enclosed and automated, with minimum involvement of personnel

• Dense phase conveying technology, now proven in oilfield service, has been proven in three decades of tough service in a range of industries • All equipment is built and certified to DNV standards

Ease of Use • Flexible installation to suit rig layout with small equipment footprints • The system can transfer raw cuttings at high rates • Cuttings are pumped to the supply boat through a quick-connect flexible hose • The ISO-PUMP unit is certified by DNV for shipping worldwide as a standard container

Environmental Protection • Totally enclosed system • No addition to waste stream • Can encompass the entire cuttings supply chain • The first total solution from shaker to process plant


T R A N S P O R T

A N D

H A N D L I N G

VACUUM COLLECTION SYSTEM ឣAPPLICATIONS

Rigs and/or other installations requiring an enclosed system for: cuttings collection and transportation; slurrification and re-injection; rig, pit and tank cleaning; vessel cleaning; and fluid recovery.

ឣPROBLEMS

With growing concerns for personnel safety, environmental issues and an increased emphasis on saving costly rig time, the industry has required a totally enclosed system for collecting and storing drilled cuttings.

ឣSOLUTIONS

The VACUUM COLLECTION SYSTEM* (VCS*) from M-I SWACO collects, moves and stores drilled cuttings within a totally enclosed environment that minimizes spills and contamination.

ឣECONOMICS

In addition to preventing many safety and environmental problems, the VCS is easy to configure to any rig, requires little or no welding, and sets up quickly and easily. These same features allow it to be moved from one location to another in a minimal amount of time.

ឣENVIRONMENTAL The totally enclosed system minimizes spills and containment problems, vapor escape or safety issues that can arise with open systems.

Features and Benefits Field-Proven • Operated successfully for major producers around the world since 1993

Versatile • Suitable for most applications: cuttings collection and transportation; slurrification and re-injection; rig, pit and tank cleaning; vessel cleaning; and fluid recovery

Safe • No hazardous moving parts • Fill sensors for automatic shut-off • Vacuum power skid is completely contained • Customized, non-sparking blower design with hazardousduty class electric motors • Explosion-proof (Class I, Zone I) 30- or 100-hp electric motor

Efficient • Maximizes filling of cuttingscollection modules • Cuttings collection and disposal does not interrupt drilling

• Conveys fluids and cuttings horizontally and vertically, saving valuable rig-floor space • Skid-mounted diaphragm pump for recycling and fluid transfer

Environmental Compliance • Designed to meet or exceed future discharge regulations

Total Containment • Contains all drilling waste streams • Minimizes potential contamination during drilling

Modular Design • Flexible design allows central rig location with remote on/off • Suitable for all rig configurations

Simple Installation • Minimal or no welding required • Makes hookup faster and safer • Preinstalled collection pipe serves multiple collection locations • Equipment tool box with spare parts includes connections, pipe, wands and hoses



C U T T I N G S

143

C U T T I N G S

T R A N S P O R T

A N D

H A N D L I N G

VERTI-G Cuttings Dryer ឣAPPLICATIONS

More stringent cuttings-discharge regulations have pressured operators and drilling contractors to reduce drilling waste volumes and recover premium products for reuse.

In the quest for improved environmental practices, operators need solids-control solutions that take liquids/solids separation to a new level. The VERTI-G cuttings dryer from M-I SWACO incorporates a high-speed vertical centrifuge that achieves maximum liquids/solids separation in large-volume processing. This gives operators a critical advantage in meeting increasingly stringent environmental regulations for offshore cuttings disposal.

ឣSOLUTIONS

The VERTI-G process

Offshore and onshore projects where the recovery of valuable drilling fluid from cuttings, as well as recovery of whole mud lost from shaker failure, rig motion and screen blinding are priorities.

ឣPROBLEMS

The VERTI-G* cuttings dryer features a state-of-the-art design that can process varying amounts of cuttings and fluids, typically up to 60 tons (61 metric tons) per hour. Dry solids discharged from the dryer are typically <5% oil content by wet weight.

ឣECONOMICS

The VERTI-G cuttings dryer improves overall cost-efficiency, producing reduced amounts of extremely dry cuttings for disposal and recovering valuable fluid for reuse. It is effective with water-, oil- and synthetic-base drilling fluids.

ឣENVIRONMENTAL

The VERTI-G dryer minimizes waste volumes, dramatically reducing disposal costs and ensuring compliance with local regulations.

Cuttings from shale shakers are conveyed to the VERTI-G dryer through a variety of site-engineered conveyance systems that include gravity feed, pneumatic transfer, vacuum transfer and screw conveyors. The flow of cuttings into the VERTI-G centrifuge is PCL-controlled and continuously fed to yield optimum liquids/solids separation. Once cuttings are introduced into the dryer’s charge hopper, widely spaced, independently adjustable flights continuously direct cuttings to the screen surface. Flights within the VERTI-G dryer create a rolling action that promotes further separation and prevents screen plugging. Under high G-forces created by the large cone diameter, liquids/ solids separation occurs instantly as cuttings make contact with the finer-mesh, high-capacity centrifuge screen while producing cleaner return fluid and drier solids discharge. Solids are discharged at the screen bottom and fall by gravity into the water-flushed cuttings trough and shunted overboard. Solids can also be collected for onshore disposal. Processed liquids pass through the screen and then exit through one of two effluent openings. The fluid is collected and pumped to the M-I SWACO decanting centrifuge for final processing and reuse in the active mud system.


Capacity Typically, VERTI-G dryers process up to 60 tons (61 metric tons) of material per hour.

Features and Benefits Superior Environmental Performance • Highly effective liquids/solids separation minimizes fluid content of cuttings • Reduces waste-disposal volumes

Improved Drilling-Fluid Recovery • Effective separation reclaims high percentages of fluid that can be reused in the active mud system • Recovers whole mud lost from shaker failure, rig motion and screen blinding

Safety • Explosion-proof motors and start/stop boxes are certified for use in Class I, Division I areas • Custom-built stands and walkways integrated into the rigs reduce risk to personnel

Skilled Operators • Experienced M-I SWACO personnel maintain peak operating efficiency

Operational Advantages • Programmable Logic Controller (PLC), with automatic warning indicators, monitors temperature, torque, oil levels and operating hours • High-capacity, continuousfeed units have the throughput to keep up with drilling • Tungsten-carbide-coated, independently adjustable flights reduce wear and ensure optimal tolerance

Ease of Maintenance • Normal wear parts are easily accessible from the top of the unit; belts are easily changed without removing gear assembly • Interchangeable tungstencarbide rotor blades protect rotor and gear box from excessive erosion, minimizing main component failure

ARRANGEMENT DRAWING: VERTI-G LOW-PROFILE CUTTINGS DRYER All dimensions are expressed in inches (millimeters). 8 (203) liquid effluent return line quantity 2 typical

11.8 (300) C of G

1.8 (46) C of G

16.2 (411) C of G

42.5 (1,080) 91.7 (2,329) Stand height may vary

Centrifuge solids discard (optional)

16.3 (413) C of G

Overboard flange 12 (304) or 14 (356) available

97.8 (2,484) 11.8 (300) C of G

2 (51) slide flush rail can be rotated

81.5 (2,070) typical width

10.9 (277) 1.8 (46) C of G 94 (2,388) C of G

System component specifications VERTI-G Low-Profile Cuttings Dryer Dryer Length with Motor in. (mm) 97.8 (2,483)

Width in. (mm)

Height in. (mm)

Weight lb (kg)

81.5 (2,070)

42.5 (1,080)

4,200 (1,905)

Power Requirements • 380 to 440V/3-phase/60Hz (150-amp circuit breaker) • One (1) 30-hp explosion-proof motor for centrifuge • One (1) 0.5-hp explosion-proof motor for lubricator pump

Operational Specifications This is a summary page. For complete information, please refer to the 2008 M-I SWACO ENVIRONMENTAL SOLUTIONS catalog.

• Screen turns up to 1,022 rpm • G-force — up to 400

Screen Specifications Opening in. (mm) 0.008 (0.203) 0.010 (0.254) 0.015 (0.381) 0.020 (0.508)

Equivalent Tyler mesh

Canadian & U.S. mesh

Micron equivalent

65 60 45 32

70 60 45 35

203 254 381 508


VERTI-G Low-Profile Cuttings Dryer

145

O I L F I E L D

S C R E E N S

XR MESH for Shale Shaker Screens

ឣAPPLICATIONS

Offshore and onshore projects where greater flow capacity and longer screen life for new and existing shakers would be considered benefits in reducing overall well costs.

ឣPROBLEMS

Conventional, thin-wire, squaremesh screens are prone to blinding and early failure. Conventional, thin-wire, rectangular-mesh screens are prone to excessive wire movement which significantly degrades separation.

ឣSOLUTIONS

The XR MESH* weave uses largediameter wire and a modifiedmesh geometry that results in a self-cleaning screen that last two to four times longer than comparable standard-mesh screens.

ឣECONOMICS

Operators running XR MESH screens on a wide variety of shakers report significantly increased flow capacities and major savings in screenreplacement costs.

ឣENVIRONMENTAL

Use of XR MESH screens has consistently provided longer screen life, increased fluids recovery and improved solids-control performance, resulting in an overall reduction of drilling waste.

The extended-life rectangular mesh

Increased fluidhandling capacity

The patented1 XR MESH design combines high-performance geometry and sturdy construction to dramatically upgrade the effectiveness of any major OEM shale shaker. Its unique, rectangular mesh promotes higher fluid-handling capacity. But unlike other rectangular designs, XR MESH material has the stability and strength to extend screen life by as much as four times compared to standard-mesh screens. The result is a screen mesh that reduces total costs and substantially improves solids control.

XR MESH screens deliver higher conductance and increased flow capacity, with significantly less blinding. The rectangular weave of an XR MESH screen maximizes open area on the screen and allows greater fluid passage. In addition, the larger length-to-width ratio of XR MESH openings increases flow capacity from 20 to 40% compared to standard meshes. Increased conductance allows the use of finer mesh screens and improves overall solids performance. Separation potential for XR MESH screens is consistent with layered square (Ultra-Fine) meshes.

Patented XR design XR MESH screen is utilized in a unique three- or four-layer arrangement that creates exceptional shale shaker screens. The XR MESH screen design features innovative oblong openings with a greater length-to-width ratio than other rectangular meshes. It also incorporates wire diameters that are 50% larger than comparable meshes. The large-diameter wire is calendared to lock mesh openings securely in place. All layers are made of finely woven stainless steel. The second layer increases screen life by acting as a buffer between the fine top mesh and coarse backup layer(s), as well as serving as a mechanical deblinding agent for the top mesh.

Longer life The larger wire diameters of XR MESH design increase durability and extend screen life, resulting in fewer screen changes and less downtime. Side-by-side testing conducted in a variety of drilling environments indicates that XR MESH equipped screens last from two to four times longer than comparable standard-mesh screens.

Blinding resistance All shaker screens experience some degree of blinding, which occurs when particles similar in size to the mesh opening become trapped, blocking fluid flow. However, the geometry of XR MESH design makes it much less susceptible to blinding. In addition, XR MESH screens provide a measure of self-cleaning. Since the layers of mesh do not have to be bonded together, limited movement can occur during shaker operation. This allows the second layer to brush against the top layer, helping to dislodge trapped particles.

Conductance/flow capacity Transmittance is the product of conductance and usable screening area, and allows for comparisons between different screens for total fluid-handling capacity. Please note that “XR” refers to an XR MESH hookstrip screen with a 1-in. (25.4-mm) perforated backing. XL (Ultra-Fine) refers to standard square-mesh hookstrip screens also with a 1-in. (25.4-mm) perforated backing.


1U.S. Patent No. 5,944,197.

S C R E E N S

DURAFLO Composite Screens ឣAPPLICATIONS

Offshore and land rigs running M-I SWACO BEM-600, BEM-650 and MONGOOSE PT shale shakers, and Brandt VSM 300 brand shakers.

The anatomy of a three-layer DURAFLO screen

Triple-layer screen mesh

ឣPROBLEMS

Metal shaker screens have inherent problems: rusting, delamination, weight and reduced processing area.

ឣSOLUTIONS

DURAFLO OEM screens for the M-I SWACO BEM-600, BEM-650 and MONGOOSE PT shale shakers and replacement screens for Brandt VSM 300 brand shakers offer higher throughput rates than metal screens as well as longer life, lower weight, and fast, easy repair.

High-strength, glass-reinforced plastic frame

ឣECONOMICS

Higher throughput rates reduce operating costs by optimizing shaker performance, while longer frame life translates into lower screen-replacement costs.

ឣENVIRONMENTAL

The variety of mesh sizes and types on the DURAFLO screen lets operators match separation efficiency to the formation, for better separation and lower drilling waste volumes.

High-tensile-strength steel rod sub-structure

DURAFLO screen frames consist of a grid made from a composite of high-strength plastic and glass, reinforced with high-tensilestrength steel rods. Because these frames balance durability with strength, they are more efficient transport mechanisms than steel frames in several ways. DURAFLO screens have higher throughput capacities and significantly longer operational lives. They do not rust or delaminate, so they can be

used, stored and reused. Model for model, composite frames weigh less than all-steel frames. And they have an increased open area, providing a higher conductance rate. Patented1 DURAFLO Composite Frame technology, combined with three different screen meshes, lets you choose the right mesh for the job without sacrificing long life, throughput capacity or any of the other composite screen advantages.

Features and Benefits • Available for M-I SWACO BEM-600, BEM-650 and MONGOOSE PT shale shakers and Brandt VSM 300 brand shakers • Patented, composite frame design • Smaller, more numerous panels • Open area remains unchanged • Screen weight remains the same • SNAP-LOK plug-repair system for the Brandt VSM 300 shaker

• Improved labeling system • Screen is resistant to fluids that shorten metal-frame-screen life • Consistently manufactured, rugged construction • Increased operational life • Lower screen replacement costs • Quick and easy to repair • Less downtime • Does not rust or delaminate • Improved QHSE considerations

This is a summary page. For complete information, please refer to the 2008 M-I SWACO ENVIRONMENTAL SOLUTIONS catalog. 1U.K.

Patent No. GB 2,322, 590; U.S. patents pending.


O I L F I E L D

147

O I L F I E L D

S C R E E N S

HIFLO Replacement Screens Because you have to drill different types of formations, you have to make choices in your shaker screens. Quite often, this choice involves a trade-off of using a mesh that is efficient but is mounted on a frame that leaves a lot to be desired. With drilling costs on the rise, you need to be choosing among positive options, not trade-offs.

The anatomy of a two-layer HIFLO screen TBC screen mesh (shown as an example)

High-strength, glass-reinforced plastic frame

HIFLO composite frame technology is the basis for greater efficiency As often happens, screen manufacturers call great attention to their screen meshes while avoiding the subject of the frames. Usually, it is because the frames are all-metal and are not engineered as well as the screen mesh material. In contrast, HIFLO* patented screen frames consist of a grid made from a composite of high-strength plastic and glass, reinforced with high-tensile-strength steel rods. Because these frames balance durability with strength, they are more efficient transport

High-tensile-strength steel rod sub-structure

mechanisms than steel frames in several ways. HIFLO screens have higher throughput capacities and significantly longer operational lives. They do not rust or delaminate, so they can be used, stored and reused. Model for model, HIFLO frames weigh less than

all-steel frames. And they have an increased open area, providing a higher conductance rate. When compared to metal-frame screens, HIFLO screens for use with Brandt VSM 100^ brand shakers have 27% more open area.

Features and Benefits • HIFLO frames combine durability, lightweight and longer life into a cost-effective alternative to metal frames • Longer frame life translates into longer overall screen life • Higher throughput rates further reduce operating costs by optimizing shaker performance • A choice of mesh styles ensures flexibility for drilling a range of formations

• TBC mesh delivers a well-defined separation efficiency or cut • Ultra-Fine (XL) mesh overcomes the blinding problems associated with sandstone • XR three-layer mesh configuration maintains separation efficiency while reducing the effects of inter-cloth abrasion and resists blinding • Larger-diameter wire gives XR MESH screens the longest life in the industry today


^Mark of Varco I/P, Inc.

First commercial use of CLEANCUT system

598

well sections drilled

1,053,593

barrels cuttings collected

2,849,292 feet drilled

72,083

hours operating time

ZERO NPT Any Questions?

Seven years of delivering solutions Drilling 16-in. section moves at 131 ft/hr safely, no NPT

Bulk cuttings transfers at up to 22 tons/hr, 131 ft vertically

During peak drilling operations in the OBM phases on this well, the CLEANCUT* system contained up to 1,273 ft/day (388 m/day) of 16-in. hole at ROPs of up to 131 ft/hr (40 m/hr). In the 12∏-in. and 8∑-in. sections and the 12∏-in. sidetrack, it contained an average of 1,680 ft/day (512 m/day). No spills or discharges to the sea. No restrictions on ROP. No equipment-related Non-Productive Time (NPT).

For platform-to-vessel conveyance, the CLEANCUT bulk-transfer system is proven technology, regularly moving cuttings 500 ft (152 m) horizontally and 98 to 164 ft (30 to 50 m) down to the supply vessel. With the practice of Waste Injection (WI) increasing, the system’s rate of up to 22 tons/hr (20 tonnes/hr), 131 ft (40 m) vertically up or down, is even better news for both short hauls and interfield transfers.

www.miswaco.com ©2008 M-I L.L.C. All rights reserved. *Mark of M-I L.L.C.


2000

149

W A S T E

I N J E C T I O N

Waste Injection ឣAPPLICATIONS

Onshore and offshore projects, especially in remote and environmentally sensitive locations.

ឣPROBLEMS

Disposal regulations and policies have tightened, especially in remote and environmentally sensitive areas. Traditional disposal practices, especially those which could result in reliance on storage and transport, may present costly safety and logistical challenges and exposure that can lead to long-term liability.

ឣSOLUTIONS

M-I SWACO has optimized the Waste Injection (WI) process, matching it to your development-program requirements. Our integrated service is complete: from preliminary engineering studies through implementation, continuous injectionpressure monitoring and analysis for process assurance.

ឣ

E C O N O M I C S

When coupled with advanced technologies for managing logistics, WI from M-I SWACO offers permanent, cost-efficient solutions for disposal of wastes from upstream and downstream sectors.

ឣENVIRONMENTAL WI is a key component in compliance strategy, offering a sound process solution for locales where traditional disposal options are not viable, such as extremely sensitive, highly regulated environmental areas.

Features and Benefits Onsite Cuttings Disposal • Is a cost-effective alternative • Eliminates cuttings transport and landfill disposal fees • Achieves zero discharge • Maintains the goal of total cuttings containment • Assists in environmental compliance • Ensures successful operations through engineered design and monitoring and analysis services • Collection and disposal are accomplished without costly downtime

Environmentally Responsible • The practical option for onshore and offshore drilling areas with zero-discharge policies

Operationally Reliable • Field-proven technology • Redundancy features to enhance reliability. Shutdown of one component does not stop cuttings processing.

• Equipment built to the highest quality standards for safety and consistent performance • 24-hr monitoring analysis coverage

Equipment Flexibility • Modular components are custom-configured to adapt to cuttings volume, flexibility, space availability and other specific client requirements • Vacuum system provides more options for location of equipment, allowing placement where other conveyance systems could not work • Compact size leaves more floor space for other drilling operations

Expertise • Operations performed by highly qualified and specialized M-I SWACO personnel assuring maximum efficiency • Authorized licensee of the patented ARCO slurrification/ re-injection process


150

• Drill cuttings • Production waste • Well cleanup waste • Storage waste • Scale waste • Spent drilling fluids • Spent completion fluids • Produced sand • Produced water • Waste water • Naturally occurring radioactive waste (NORM)

Our record speaks for itself M-I SWACO has been providing WI services to the petroleum industry since 1991. Along the way several benchmarks have been set at some of the highest profile, most environmentally sensitive areas of the world, including the North Sea, Alaska, Azerbaijan, Mexico, Canada and Russia. Millions of barrels of waste slurry have been injected on single long-term project sites. M-I SWACO was first: to implement modular, all-weather offshore packages designed for high penetration rates (1995); to implement mobile, unitized, all-weather onshore WI facilities (1999); to integrate HMI (Human Machine Interface) to WI control systems

WI Training Centers Training is the key to successful WI operations M-I SWACO is committed to assuring the competency of personnel and delivers both theoretical and practical hands-on training solutions in all aspects of the WI process to both employees and customers. Training centers around the world are fully equipped with training rooms, laboratories, WI/CLEANCUT training simulators, a full-scale WI slurrification system, a CLEANCUT cuttings collection and transport system, a VACUUM COLLECTION SYSTEM (VCS) and an M-I SWACO 518 CENTRIFUGE. The WI curriculum is competency-based, requiring trainees to complete trainerassessed tasks and follows the requirements of ISO 9001 and ISO 10015. M-I SWACO WI Training Centers are located in Aberdeen, Scotland; Bangkok, Thailand; and Houston, Texas.

(2003); and was the first and only WI provider to fully develop and implement an assurance-based quality program (CAP-2005). Our WI assurance process was created to permit the detection and identification of potential risks and suggest mitigating actions. By understanding and analyzing every step of the operation, M-I SWACO provides assurance of success and monitors efficiency to prolong the life of the injector. Today, an average of 4 million barrels are injected on an annual basis with the number of jobs increasing exponentially. You’ll find M-I SWACO on the frontiers of development applying the newest technologies with the highest standard of care.


Types of wastes suitable for injection

151

C U T T I N G S

T R E A T M E N T

Thermal Desorption Technologies ឣAPPLICATIONS

for example, as a base material in the construction of roads or building blocks.

Onshore and offshore projects where drilling waste solids from oil-base mud operations need appropriate “end-point” disposal.

Finding the best solutions

ឣPROBLEMS

The best solutions are the result of an in-depth understanding of the unique project situation and issues that can include:

Untreated, oil-contaminated drilling waste creates environmental liability and often is a source of unrealized revenue.

• Project location

ឣSOLUTIONS

The project-specific, advanced Thermal Desorption technology options from M-I SWACO incorporate efficient processes for reclaiming entrained hydrocarbons, minimizing waste and preparing solids for disposal.

ឣECONOMICS

M-I SWACO preproject analysis helps determine the optimum thermal desorption method(s) for a particular situation, allowing the operator to optimize operations and control the capital cost of the equipment required.

ឣENVIRONMENTAL

Recovered synthetic, oil, diesel or low-toxicity mineral oil can be reintroduced to the active mud system, used as a supplemental fuel or sold for reuse. Treated solids are contained and rigorously tested prior to disposal.

How it works M-I SWACO uses indirect-heat thermal desorption to volatilize hydrocarbons from oily solids in a closed chamber using carefully controlled heat. Temperature levels and retention time in the chamber are closely monitored to ensure maximum phase separation without exceeding the fractionation point of the base oil. Vapors are collected and rapidly condensed. The condensate is then divided into fractions with a specially engineered oil/water separator. Recovered base oil is collected, tested and recycled. Water is recovered and is also used to re-wet treated solids which can then be disposed of onsite or taken to a disposal facility.

152

• Source of material • Discharge or reuse • Recovery • Logistics Oil-base drilling waste is a fact of life in the oil and gas industry. Base oil entrapped in drill cuttings represents a potential dual liability: environmental and financial. While oil-base fluids remain the systems of choice for many operators, strict regulation of usage in many areas requires specialized treatment prior to disposal. M-I SWACO offers three thermal desorption technologies — Thermal Phase Separation (TPS), Hammermill (onshore and offshore systems), and Rotary Kiln. All are designed to reduce the amount of produced waste at the source, reclaim valuable base oils and prepare solids for disposal. The M-I SWACO thermal desorption technologies are capable of producing dry, clean solids with less than 1%, and often less than 0.5%, Total Petroleum Hydrocarbon (TPH) content. All TPS, Hammermill and Rotary Kiln units are engineered for high mobility and feature the flexibility to adapt to changing operational requirements. After appropriate treatment, discharge material can often be used as a fundamental building material;

• Storage capacity • Preprocessing preparation • Separation of solids, oil and water • Processor type and capacity Addressing each set of circumstances allows M-I SWACO to address the broad spectrum customer needs, including removal of contaminants, safe solids disposal, reuse of hydrocarbons and water, cost control and safety.

Thermal desorption and revenue generation Oil-contaminated cuttings actually represent two forms of revenue for operators: one direct and one indirect. The direct stream is represented by the base oil recovered from the cuttings. The reclaimed product can be reused in making up drilling fluid, used as a fuel supplement or sold. The savings or income is direct, immediate and significant. The indirect revenue stream derives from the reduction in disposal costs and environmental exposure, both of which can quickly turn a successful project into a financial liability.


– Transport trucks hauling skips for onshore processing

Hammermill: Onshore Application The Hammermill desorption process is based on direct mechanical heating through the use of a pounding mill’s action on the cuttings. The combination of high mechanical shear and in-situ heat generation creates an environment that promotes flash evaporation of water and hydrocarbons. There is no ignition source in this type of desorption process, hence the term “friction.” This technology eliminates the need for large surfaces and complex systems for warming and maintaining a heat-transfer medium, e.g., hot oil, steam or exhaust gas. It is fast, clean and efficient to run. Due to the operating flexibility of the mechanical approach to desorption, Hammermill systems can be designed as compact units that meet the highest safety and explosion-proofing standards. The limited process temperatures and very short retention time required for complete removal of oil in the solids are key benefits because this significantly reduces the risk of thermal degradation of the recovered base fluids.

Hammermill: Offshore The Hammermill unit is sized for offshore applications and can be installed in the space previously allocated for the skips that would ordinarily be used to collect and transport cuttings to shore. Through

– Diesel cranes unloading skips at the onshore treatment facility – Forklifts emptying skips at the onshore treatment facility

Reduced cost, increased safety • Eliminates rental of cuttings containers the integration of the proven CLEANCUT cuttings transfer and storage technology with an M-I SWACO TCC modular design, we provide the total offshore solution, including:

• Eliminates waste hauling to shore • Eliminates manpower needed for handling skips • Eliminates crane lifts handling skips

• Pneumatic transfer of drilled cuttings to the Hammermill • Completely enclosed system sized for offshore installations • CLEANCUT system and TCC Vapormill PLC-controlled reduce manpower requirements • Cross-trained CLEANCUT and TCC specialists • Modular, DNV 2-7.1-approved modules • Minimal rig-up/rig-down time • Plug and socket on cabling to reduce rig-up/rig-down time • ATEX-approved • Rated for Zone 2 use

Reduced emissions • Best available technology for drive module featuring the new CAT C32 low-emissions engine (less than Tier 2)

Features • ATEX approved • CE marked • Small footprint • Low manpower requirements • Operates very cleanly and quietly • Excellent for offshore application as well as onshore

Benefits • Limited process temperature • Very short retention time required for complete removal of oil in the solids • Reduced risk of thermal degradation of valuable base oils • Efficient, intense agitation breaks up solid particles and induces flash distillation without thermal degradation of the oil

• Reduces emissions generated in the transport and handling of skips: – Offshore diesel crane for loading boats – Ship-to-shore boat hauling skips – Onshore diesel cranes handling skips



Thermal Desorption: Hammermill

153

C U T T I N G S

T R E A T M E N T

Thermal Desorption: Rotary Kiln Thermal Desorption: Rotary Kiln The Rotary Kiln technique of Thermal Desorption is an effective, high-throughput method of recovering produced water and light hydrocarbons from drill cuttings. This technique, which uses a rotating, inclined cylinder, has been successfully used for many decades in the oilfield and other industries. The M-I SWACO Rotary Kiln process moves contaminated soil to a feed auger that delivers it into the kiln where an indirectly fired thermal desorber heats the soil, driving off the oil and water as vapor. In indirect-firing all heat is transferred to the cuttings through the vessel shell wall, a process designed to preserve the characteristics of the recovered oil. The oil-free soil is then cooled by a water spray in the discharge end of the kiln and is next moved to a discharge auger where it is further cooled for disposal offsite.

Condensed fluid Hot gases

Oil

Heat exchanger

Water

Pump Blower Production of water and oil

Fluid recovery water oil

Rotating cylinder

Water

Oil

Evaporated gases leave the cylinder tio dra Hy

Contaminated solids and fluids enter External warming system

r ate (W

n

rec

ry ove

)

Inert solids

(oil recovery)

Features

Benefits

• Variable process rates from 15 MT/day to 35MT/day depending on material composition and kiln size • Modular design enables custom system configurations • Truck-mounted mobile design • Minimal rig-up /rig-down time • Indirect thermal desorption

• Operates with low emissions • Recovers more than 99% of valuable base oil for immediate reuse • Consistent treated solids results: 1% TPH • Significantly less solids carryover (<1% BSW) in recovered oil • Effectively treats high-liquidcontent cuttings (>40%) by weight • Reusable recovered oil quality • Minimal personnel requirements


Thermal Desorption: FOx System Enhancement The Fluid Oxidizer (FOx*) process enhancement is a straightforward solution that removes pungent odors from thermally recovered oil and water produced by all three M-I SWACO Thermal Desorption technologies. The process is based on the ozone treatment of both oil and water, proven to be an effective method of removing odors caused by high temperatures and thermal cracking. The FOx enhancement is the first analytical method developed to scientifically quantify and treat odor. Previously, the industry relied on a smell test and Volatile-OrganicCompound (VOC) measurement to quantify odor of thermally recovered oil and water. The FOx enhancement is available for land projects and is currently being configured for offshore use. Field tests with a pilot unit in Kazakhstan have proved the effectiveness of ozone treatment technology in treating thermally recovered oil with the oxidation of organic compounds to enhance final product quality. The tests showed successful treatment of oil and water in multiple 24-hr continuous runs. A majority (in the range of 95, 85 and 84%) of participants from three discrete locations ranked ozonetreated oil as less offensive than untreated oil, while some participants (70, 35 and 33%) ranked ozone-treated oil as less offensive than virgin base oil.

Specifications FOx Land Unit Specifications • Self-contained and portable • Unit size ISO 20-ft (6.1-m) container • Normal +41° F/104° F operating (+5° C/+40° C) temperature • Survival –4° F/104° F temperature (–20° C/+40° C) • Ingress IP55 Protection Rating • Recovered 793 gal/day Oil Process (3,000 L/day) Rate • Recovered 2,906 gal/day Water (11,000 L/day) Process Rate • Voltage 400V AC • Frequency 50 Hz • Conformity CE, GOST R (Voltage, frequency, IP rating, and conformity can be configured to suit each project or application.)

Features • Self-contained, 20-ft, (6.1-m) portable unit • Integrated air supply • CE marked

Benefits • Cleans both water and oil • Purifies oil without creating a waste stream • Eliminates challenges associated with clay filtration



Thermal Desorption: FOx System Enhancement

155

P R E S S U R E

C O N T R O L :

D - G A S S E R S

D-GASSERs Introduced in 1951, the M-I SWACO D-GASSER* has performed reliably on over 200,000 wells and earned its reputation as the standard of the industry. All M-I SWACO D-GASSER

by recirculating gas-cut mud. With its smaller footprint, 42 x 60.7 in. (1,066.8 x 1,541.8 mm), the vertical model is ideal for confined-space applications.

units are designed to remove virtually all entrained gases, including H2S and corrosive oxygen, from drilling mud. This reduces the threat of dangerous and costly blowouts caused

Horizontal D-GASSER Specifications • Length • Width • Height • Weight • Capacity

157 in. (3,988 mm) 42 in. (1,067 mm) 87 in. (2,210 mm) 3,350 lb (1,521 kg) 1,000 gpm (3,785.4 L/min)

A R R A N G E M E N T D R AW I N G : H O R I Z O N TA L D - G A S S E R All dimensions are expressed in inches (millimeters).

176.9 (4,493) 157 (3,988)

42 (1,067)

103.5 (2,629)

5.9 (150)

47.9 (1,217) 22.4 (569)

12.5 (318) 17.6 (447) 32.7 (831)

6.8 (173)

34.5 (876) 21 Typ. (533)


5.8 (147)

ARRANGEMENT DRAWING: VERTICAL D-GASSER All dimensions are expressed in inches (millimeters).

13.8 (350.5)

45 typ 4 plcs

20.3 (515.6)

13.5 (342.9)

36 (914.4) diameter

27 (685.8)

12 (304.8)

2.5 (63.5)

18.2 (462.3) .31 30.3 (7.9) (769.6)

149 (3,784.6) 119.9 (3,045.5) 56.9 (1,445.3) 36.3 (922)

54.8 (1,392)

34.2 (868.7)

Specifications • Length • Width • Height • Weight • Capacity

60.7 in. (1,541.8 mm) 42 in. (1,066.8 mm) 149 in. (3,784.6 mm) 2,950 lb (1,339 kg) 800 gpm (3,028.3 L/min)

42 (1,066.8)

21 (533.4) 42 (1,066.8) 60.7 (1,541.8)

20.3 (515.6)

31.7 (805.2)

Features and Benefits • Skid-mounted. Simplifies spotting and installation. • Self-contained. The unit consists of a cylindrical vacuum tank with internal baffle system, vacuum pump, jet nozzle and three-way float valve. • Three-way float valve. Unique design allows venting to the flare line during H2S service. • Simple operation. The returnflow, gas-cut mud is drawn into the tank through a vacuum

created by the discharge jet and pump. The mud is then dispersed in a thin layer over a two-tier, baffle-plate system where the entrained gas, including H2S and corrosive oxygen, is recovered by the vacuum pump. The freed gas is then discharged at a safe distance from the drilling operation while the restored mud is returned to the active mud system. • Few moving parts. The D-GASSER unit features only three moving parts: the float inside the vacuum

vessel, the vacuum breaker valve, and the vacuum pump. The float ensures that the system maintains the desired mud-fill level within the vessel during operation. • High performance. An M-I SWACO D-GASSER can handle up to 1,000 GPM (3,785.4 L/min) while restoring mud to its original density. • Built rugged. The unit is ruggedly built and coated inside and out with corrosion-resistant epoxy to ensure long life and minimum maintenance.



Vertical D-GASSER

157

P R E S S U R E

C O N T R O L :

D - G A S S E R S

Compact Vacuum D-GASSER Process overview Gases are entrained in drilling fluids from the wellbore during normal drilling operations as well as during “kicks” or wellcontrol situations. These gases present safety hazards and create operational problems when gasladen fluid reaches the surface. Degassing is accomplished at the surface by one of two methods (1) atmospheric separation or (2) vacuum separation. The simplest form of atmospheric degassing occurs naturally in the

Features and Benefits • Fiberglass leaves eliminate corrosion; reduce repair and maintenance costs • Large Cleanout Port allows easier access for cleaning inside of D-GASSER • Greater surface area allows gas-entrained mud to be released more efficiently • Interchangeability of many of the parts as the Horizontal D-GASSER allows use of existing inventory parts • Same field-proven vacuum pump as Horizontal D-GASSER • Shorter footprint can be installed in smaller spaces

surface mud tank system. As the mud flows over the shale shakers and through the pits, gas bubbles will form in the mud and escape to the atmosphere. In event of hazardous gases being present, it is desirable to localize the point where gas is released from the mud by installing a vacuum-style degasser. Vacuum-style degassers are installed in the first compartment downstream of the sand trap and upstream of any centrifugal pumps. Vacuum degassers work by removing entrained gases from

the drilling fluid by exposing the fluid to pressures well below ambient atmospheric pressure.

How it works The M-I SWACO Compact D-GASSER unit works by removing entrained gases from the drilling fluid as illustrated at right. Vacuum degassing is more effective than atmospheric degassing due to the exposure of the drilling fluid to pressures well below ambient atmospheric pressure. The unit directs the incoming fluid flow over internal plates that create large surface areas over which thin layers of the fluid continuously flow. The transit time required for the gas to travel up, through the fluid and “break out” of the mud is minimized by spreading the fluid into thin layers. At pressures below atmospheric pressure, the rate at which gas separates from a fluid is accelerated. The low pressure promotes the growth of large gas bubbles which rise rapidly to the nearest surface. The free gas that breaks out of the drilling fluid is continuously removed from the vessel by the

action of the piston-style vacuum pump on the unit. The removed gas is typically directed to the flare stack. The level of mud within the vessel is controlled by a float valve to ensure that the disk stack is never submerged. As fluid level rises and lifts the float, air enters the vessel through the three-way valve to decrease the vacuum inside the vessel. With less vacuum inside the vessel, the rate at which fluid is drawn into the tank slows and the rate at which fluid exits the vessel increases. The fluid level inside the vessel drops rapidly until the float lowers and full vacuum is restored. A liquid-trap tank in the gasremoval piping collects any fluid or condensate that may have entered the gas-removal piping. A float ball in the liquid-trap tank prevents the liquids from entering the vacuum pump.

Incoming fluid disperses in thin layers over the internal disk stack

Gas outlet Motive force fluid to venturi jet pump Fluid level Degassed mud


Outlet to mud pit

Inlet: gas cut mud

C O N T R O L :

D - G A S S E R S

CD-1400 Centrifugal D-GASSER The M-I SWACO CD-1400 Centrifugal MUD D-GASSER* unit provides an innovative and space-saving solution to degassing problems. The D-GASSER units use a patented, centrifugal-force system rather than conventional vacuum or impact systems. M-I SWACO D-GASSER units exert centrifugal force to the mud, multiplying the force acting on the gas bubbles to increase buoyancy and release. The increase in buoyancy accelerates the bubble-rise velocity. As the bubbles rise toward the surface, they escape the mud and are further broken down by flow turbulence. The freed gas and the gas-free mud are then separately discharged as desired.

CD-1400 Centrifugal D-GASSER

Features and Benefits • Removes entrained gases. The centrifugal D-GASSER units remove all of the entrained gases from the drilling fluids in the return flow by using high-speed centrifugal force. • Reduces potential blowouts. The removal of entrained gases, including H2S and corrosive oxygen, from drilling fluids reduces the threat of dangerous and costly blowouts caused by recirculating gas-cut mud. • In-tank mounting. Easy-to-install, in-tank mounting virtually eliminates the need for rig-floor space.

• Energy efficient. System requires less energy to operate with UL-approved, 25-hp, explosion-proof 230/460 VAC 3-phase 60-Hz motor. • Self-contained. The unit is complete with centrifugal cylinder unit, screens, electric motor and mount. • High performance. Provides lowest hp/GPM throughput ratio, generating up to 1,000 to 1,300 GPM (4,164 to 4,921 L/min), depending on operating conditions.

ARRANGEMENT DRAWING: CD-1400 CENTRIFUGAL D-GASSER All dimensions are expressed in inches (millimeters).

19.9 (505.5)

N2

23.8 (604.5)

N1 20.8 13.2 (528.3) (335.3)

41.5 (1,054.1) 121.9 (3,096.3) 71.7 (1,821.2) 67.1 (1,704.3) 59.4 (1,508.8)

21 (533.4)

0.9 typ (22.9) 21.2 (538.5)

64.9 (1,648.5)

10 typ

24 typ

on 37.7 B.C. (957.6)

Notes N1 Mud discharge nozzle 6 in. (152.4 mm) N2 Gas discharge nozzle 2.5 in. (63.5 mm)



P R E S S U R E

159

P R E S S U R E

C O N T R O L :

M U D / G A S

S E P A R A T O R S

MUD/GAS SEPARATOR The field-proven M-I SWACO MUD/GAS SEPARATOR* is an extremely reliable, vital piece of safety equipment for today’s drilling operations. It is ideal for use where drilling is likely to encounter large volumes of gas, sour gas or when an operator is drilling with an underbalanced mud column. The MUD/GAS SEPARATOR is primarily used to separate and safely vent large pockets of free gas, that may include toxic gases such as hydrogen sulfide, from the drilling-fluid system.

Features and Benefits • Separates large volumes of free gas including H2S • Reduces threat of hazardous and toxic gases • Skid-mounted for easy transport • Versatile configurations • Designed to ASME and NACE specifications • Corrosion-resistant epoxy coated to ensure long life

Separates free gas. Separates and vents large pockets of free-gas accumulations, including toxic gases such as H2S, from the active system. Reduces hazardous gas threat. The separated gas is carried by vent lines to a remote location and flared. Failsafe gas delivery is controlled by a back-pressure manifold valve in the flare line. Skid-mounted and trailerable. Simplifies transport, spotting and installation. Unit can lay down during over-the-road transport. Versatile configuration. The MUD/GAS SEPARATOR is available in either a land or compact offshore configuration. The land version is designed so it can be raised or lowered for flowline adjustments to minimize piping. ASME and NACE specifications. The only separator designed in accordance with ASME and NACE specifications. Rugged construction. The unit is ruggedly built and coated with corrosion-resistant epoxy to ensure long life while processing hazardous and toxic gases.

How it works The M-I SWACO MUD/GAS SEPARATOR consists of a cylindrical pressure vessel in a fixed vertical position. Inside is a series of specially angled baffle plates, stepped from the top to the bottom. When contaminated mud is routed into the separator, it flows downward successively over each plate. During this process, the heads of entrained gases “break out.” The released gas is then carried by the vent lines to a remote location where it can be safely flared.

The flow of liquid from the vessel can be regulated by a liquidlevel-control valve or a U-tube, ensuring adequate retention time in the separator for the gas to break out. The gas delivery from the MUD/GAS SEPARATOR to the flare line can be controlled by a backpressure manifold (valve) in the flare line. The M-I SWACO MUD/GAS SEPARATOR is ideal to assist in controlling dangerous, nearsurface expansion and accumulation of gas during a well kick.


C O N T R O L :

M U D / G A S

S E P A R A T O R S

SUPER MUD/GAS SEPARATOR (SMGS) The M-I SWACO SUPER MUD/GAS SEPARATOR* offers the highest gas- and liquid-handling capacity available. Its highly efficient baffling system maximizes mud/gas separation, enabling operators to drill deeper, larger-diameter wells and exploratory wells at higher circulating rates while safely handling greater volumes of gas. It also minimizes mist carryover and gas-cut mud at the flowline.

How it works • The mud enters the vessel through the intake line • The fluid runs over the baffle system as gas is separated and migrates out of the vessel through the flare line • The degassed mud is discharged into the active mud system through the mud return line

Gas to flare line

Intake line

Degassed mud returned to system

Specifications • 200-ft (60.9-m) flare line up to 12-in. (304.8-mm) diameter • 8-in. (203.2-mm) inlet and 12-in. (304.8-mm) return flowlines • Atmospheric operation1: Gas capacity 65 MMscf/d Fluid capacity 38,000 bbl/d • Pressured operation: Gas capacity 83 MMscf/d Fluid capacity 59,000 bbl/d • Vessel: Diameter 6 ft (1.8 m) Height 22.3 ft (6.8 m) Flare line 12 in. (304.8 mm) • Weight: 24,000 lb (10,866 kg) • Skid: 8 x 10 x 30.4 ft (2.4 x 3.1 x 9.3 m)

Features and Benefits • Large 6- x 22.3-ft (1.8- x 6.8-m) diameter vessel with 12-in. (304.8-mm) flare line. Allows the highest gas- and liquid-handling capacity available. • Optimizes safety and control. The SUPER MUD/GAS SEPARATOR unit enhances safe drilling practices during underbalanced conditions, improves “kick” handling capabilities, permits optimum circulation rates and large-diameter holes to be drilled through the targeted zone, provides more efficient separation of emulsions and gas-cut mud in either gas or oil environments, and eliminates the need and cost of a skimming system in a gas environment. • High-efficiency baffle system. Maximizes mud/gas separation, minimizes mist carryover which produces a cleaner flare and minimizes gas-cut mud at the flowline. • Capable of pressured operation. Increases gas- and liquid-handling capacities and permits immediate sale of gas during drilling operations.

• Adjustable U-tube (liquid seal) height to 14 ft (4.3 m) without additional elevation of the vessel. Increases vessel pressure, creating higher flare capacity, enabling more efficient separation of emulsions and gas-cut mud in either gas or oil environments. • Higher liquid-capacity vessel with multiple nozzle ports. Permits pumping of “hot” mud directly into the vessel to reduce gas hydrates. Increases mud gradient within U-tube to increase gas-handling capacity. • Manufactured to exacting standards in accordance with: – NACE MR-01-75 for H2S service. Provides for safe handling of corrosive, deadly sour gas and gas-cut drilling fluids. – OSHA 29CFR 1910 for safety. Provides safe and easy access for rig-up and servicing via ladder and platform system. – ASME boiler and pressure vessel code Section VIII, Division I, Section IX, lethal service and so stamped. Provides maximum rigsite safety during underbalanced drilling operations.

This is a summary page. For complete information, please refer to the 2008 M-I SWACO ENVIRONMENTAL SOLUTIONS catalog. 1Gas-

and liquid-handling capacity can be increased by customizing your system configuration.


P R E S S U R E

161

P R E S S U R E

C O N T R O L :

M U D / G A S

S E P A R A T O R S

TOGA System Almost all the gases encountered in drilling operations are extremely dangerous. This is due to the flammability and explosiveness of hydrocarbon vapors when mixed with air. These vapors may also contain highly corrosive hydrogen sulfide gas which is fatal to humans and can cause complete failure in some steels. Developed by M-I SWACO research and engineering, the TOGA* system combines two field-proven products — the M-I SWACO D-GASSER and M-I SWACO MUD/GAS SEPARATOR — working together to totally separate and vent or flare all gases. Safely vents all gases. The TOGA system is a totally enclosed gasseparation system that safely removes and/or flares all gases in the drilling fluid circulated from the wellbore.

Features and Benefits • Totally enclosed system safely removes and/or flares all gases • Ideal for control of continuous underbalanced drilling • Available in a variety of configurations to accommodate virtually all applications • Meets or exceeds all safety regulations for drilling in H2S environments • Two vacuum pumps for increased discharge capacity and redundancy for routine maintenance and repair • Removes virtually all entrained gases, including H2S and corrosive oxygen, from drilling fluids • Restores mud to its original density allowing for reuse in the active mud system • Reduces the threat of dangerous and costly blowouts • Prevents gas from escaping into the active mud system

Efficient. Effectively contains and separates gases encountered while drilling. Meets or exceeds safety regulations. The TOGA system meets USGS and Texas Railroad Commission regulations as well as API guidelines and NACE standards for drilling in H2S environments. Multiple applications. The TOGA system is suitable for both onshore and offshore applications. The

Used primarily to control highvolume free gas, the TOGA system is also a valuable tool during a well kick to help control the near-surface expansion of gas. It is also ideal for control of continuous underbalanced drilling.

M-I SWACO total-gas-containment system safely vents all gases Gas vent line Vacuum D-GASSER MUD/GAS SEPARATOR Gas vent line Gas vent line

Mud tank Degassed mud Gas-cut mud from flowline or shale shaker

Back flow


system is available in a variety of efficient configurations including land, space-saving offshore, and highly mobile trailer-mounted versions.

C O N T R O L :

D I S C - T Y P E

C H O K E S

Standard Chokes The M-I SWACO 10,000-psi (689-bar), 15,000-psi (1,034-bar) and 20,000-psi (1,379-bar) SUPERCHOKE* units are the most widely used and respected well-killing and high-pressurecontrol drilling chokes in the industry. For more than 35 years, these chokes have been especially effective when used during well kicks, well testing and well cleanup operations. They are designed and manufactured for H2S and abrasivefluid applications and in accordance with API and NACE standards. High pressure drilling chokes. Built to handle 10,000 to 20,000 psi (689 to 1,379 bar), M-I SWACO chokes are precision engineered for precise well control.

Full flow

Restricted flow

Fully closed

Unique choke-plate design. Heavy duty, diamond-lapped tungstencarbide plates are honed to a flatness measured by lightbands

10k SUPERCHOKE

Chokes 10k SUPERCHOKE* 15k SUPERCHOKE 20k SUPERCHOKE

and feature unique half-moonshaped orifices. Rotation of the actuator fork allows finite regulation of the size of the opening from full open to full close. Positive closure. A 17° deadband overlap beyond the full-close position is designed to ensure closure even if the plates become worn following extended exposure to abrasive-laden fluid flow. Pressure drops or surges don’t affect the quality of the seal in the plateto-plate design. In fact, the seal improves under pressure. Tungsten-carbide wear sleeves. Hardfacing on wear sleeves increases in-service life. Extended wear sleeves are available to absorb effects of abrasive downstream turbulence, especially during underbalanced drilling operations. Versatile. Ideal for onshore and offshore applications. Controls can be operated from either remote or onsite consoles.

15k SUPERCHOKE

Three methods of operation • Normal operations: Activation is rig-air operated • If rig air is lost: Activation is manual with hydraulic pump located on remote-control skid • If hydraulic lines are severed: Activation is manual with bar provided on indicator head Manufactured to exacting standards. Constructed for H2S service and abrasive-fluid applications in accordance with API 6A and NACE MR-01-75 standards.

Features and Benefits • Built for the oilfield • Precision engineered • Handles 10,000 to 20,000 psi (689 to 1,379 bar) • Unique choke-plate design • Provides positive closure • Tungsten-carbide wear sleeves extend in-service life • Ideal for onshore and offshore applications

20k SUPERCHOKE

Length

Width

Height

Weight

35.7 in. (906.8 mm) 43.3 in. (1,099.8 mm) 43.4 in. (1,102.4 mm)

21.6 in. (548.6 mm) 21.6 in. (548.6 mm) 24.3 in. (617.2 mm)

11.5 in. (292.1 mm) 11.5 in. (292.1 mm) 13.2 in. (335.3 mm)

441 lb (200 kg) 600 lb (272 kg) 650 lb (295 kg)



P R E S S U R E

163

P R E S S U R E

C O N T R O L :

D I S C - T Y P E

C H O K E S

ESUPERCHOKE The ESUPERCHOKE* drilling choke from M-I SWACO is the latest evolution of a proven idea — a remotely operated, electrically actuated, variable-speed version of the SUPERCHOKE* drilling choke. The small, portable, remote actuator control panel is easily carried to the drill floor by an operator and will replace the large choke console currently required for hydraulic operation. Although the ESUPERCHOKE unit has many outstanding features, they all have one goal — to give the operator a high degree of control, safety and speed in well-control situations.

Features and Benefits • Variable-speed drive. The operator can control the speed at which the choke is opened or closed. This gives the operator precise chokepositioning adjustment during critical well-control situations. • Faster open/close speeds. Eight seconds from full-open to fullclose. The operator can rely on a quick response from the actuator assembly during well-control operations. The ESUPERCHOKE system’s response time exceeds the hydraulic 10k SUPERCHOKE system in cold weather environments. • Performance tested to full 10k operating pressure. The electric actuator required only 26% maximum available peak current operating at maximum speed and load. This performance test assures that the ESUPERCHOKE unit will meet the operator’s well-control needs. The rated peak current for the motor is 14.1 amps RMS. • High torque. The ESUPERCHOKE system is capable of over 19,400 in.-lb (2,191.9 Nm) of torque. It can sever a ∑-in. (12.7-mm) alloy steel rod, demonstrating its ability to clear

obstructions that may become lodged between the plates while drilling or flowing back a well, and still attain a fully closed position. • Electronic pressure sensing and transmitting. The design of the ESUPERCHOKE eliminates the need for hydraulic hoses and fittings. This greatly reduces calibration and maintenance requirements while enhancing accuracy. • Three modes of operation. Remote at driller’s console, Local at the choke manifold, Manual at the choke valve, using the hand-wheel. Whether on the drill floor or at the choke manifold, the ESUPERCHOKE system allows accessibility for an operator to quickly respond to a well-control situation. The three modes of operation also provide redundancy and ensure that the operator has control of the choke at all times. • Reduced cabling requirements. The ESUPERCHOKE unit requires only one communication cable between the Remote and the Local console. Simplified cabling lessens tripping hazards and


troubleshooting while providing the operator with the best available transmission medium for data communication. • Zero gear lash. In critical wellcontrol situations, the operator must rely on the choke valve to open and close without delay. The ESUPERCHOKE drilling choke provides absolutely no play in the gear box when actuated. • Small and portable. The system is designed for transport by an operator and easily placed in the doghouse or on the driller’s console. • Advanced position enunciation. The LCD digital display includes both the percentage (%) of open/ close and the choke-bean size. The operator can closely monitor the choke’s precise position and the rate of change in the choke’s position, giving a “feel” for the well during operation. The advanced position enunciation is provided at both the rig floor and the choke manifold for greater accessibility during critical well-control operations.

C O N T R O L :

S H U T T L E

C H O K E S

AUTOCHOKE

The M-I SWACO 10k and 15k AUTOCHOKE* provides easier, more precise well-pressure control. The AUTOCHOKE reduces the risk of formation breakdown or secondary bubbles during well-control and drilling operations, assuring faster, safer kick control and implementation of Managed-Pressure-Drilling (MPD) practices. The AUTOCHOKE regulates pressure automatically under all conditions. Choke operators no longer have to fight controls during transition operations such as mud-pump startup or shutdown, making or breaking connections, or when mud and gas are flowing alternately through the choke. The AUTOCHOKE also makes stripping pipe simpler and safer by maintaining casing pressure. As drill pipe is lowered into the hole, an equal volume of fluid is automatically displaced through the choke. Typical applications include MPD; UnderBalanced Drilling (UBD); H2S service; all pressure control up to 15,000 psi (1,034 bar); controlling kicks and killing wells; frac flowback; and Equivalent-CirculatingDensity (ECD) drilling.


Shuttle nut Shuttle

Inlet Dynamic trim Extended trim

Static trim Long trim

Discharge

Features and Benefits • Patented sliding shuttle/sleeve design automatically adjusts fluid flow to regulate well, casing and drill-pipe pressures • Triple, tungsten-carbide wear sleeves provide downstream choke-bore protection • No-leak shut-in seals (metal-tometal and Teflon-to-metal) • High-capacity, 3-in. (76.2-mm) choke bore • Long-life for severe service operations, tungsten-carbide static-trim, reversible dynamic trim, hard-faced (stellite) shuttle assembly and internal removablebody sleeve preventing valvebody erosion • Chrome-plated internal bores for corrosion resistance • Plated and stainless external surfaces eliminate painting • Simple seal replacement • Electronic position indicator, computer compatible; control console includes digital pump stroke counters with rate meter, stop watch and clock • Easy, predictable standpipe pressure control

• Preset maximum pressure capability • No-leak shut-in • Precision control for stripping pipe into the hole; for UBD and MPD techniques when controlling back pressures; of bottomhole pressure during well-control operations, UBD and MPD; and reduces lost circulation, gas intrusion, fluid costs, production damage and blowouts • Self-cleaning orifice reduces plugging; easy-to-maintain internal components • Tungsten-carbide or stellitecoated internal wear parts are all replaceable, eliminating the need to ever machine or recertify the valve body; more durable than needle-valve or rotatingdisc chokes • Improved flow characteristics at throttle point and through choke bore • Simple, eight-bolt design allows internal inspection in only five minutes • Rated for H2S service


P R E S S U R E

165

P R E S S U R E

C O N T R O L :

C H O K E

C O N S O L E S

Standard Choke Consoles M-I SWACO chokecontrol consoles M-I SWACO choke-control consoles are available as single- or dual-chokecontrol units and with standard pressure gauges or state-of-the-art digital gauges. The single-choke-control console is precision-built to provide accurate control of your operation, yet is built to withstand the harshest conditions. It operates either hydraulically or manually and is self-contained and skid-mounted for easy installation on or near the rig. A key feature of the console is the large easy-to-read gauges which monitor critical drill-pipe and casing pressure. A choke position indicator shows relative plate opening from “full open” to “full close.” The dual-choke control console provides a separate valve to regulate chokes from independent hydraulic systems during special applications.

An operator has full command of both chokes without switching controls. The dual unit offers all the benefits of the single-choke-control

Digital choke console

Features and Benefits

The M-I SWACO digital choke console provides drillers one of the most accurate and quickresponse choke-control systems in the industry. The panel layout is ergonomically designed to provide operator comfort with userfriendly placement of gauges. The console has both digital and standard 10,000-psi (689-bar) drill-pipe and casing-pressure gauges, a 3,000-psi (207-bar) gauge to display hydraulic pressure for each system and a 200-psi (14-bar) gauge to display air-supply pressure. The panel features a larger choke position

Consoles Single Console Dual Console

indicator gauge, high-speed bypass valve and two choke open/close speeds — “Regulated” and “Maximum.”

Length 55 in. (1,397 mm) 55 in. (1,397 mm)

Width 27 in. (686 mm) 27 in. (686 mm)


console. For greater space efficiency, it features the same footprint as the single-choke-control console.

• Quick responding and highly accurate • Provides operator comfort and reduces fatigue • Long in-service life • Easy to reconfigure from single- to dual-choke control • Digital and standard flushmounted gauges • Easy-to-read gauges • Two choke open/close speeds • Built of corrosion-resistant stainless steel • Ergonomic panel height and panel design

Height 65 in. (1,651 mm) 69 in. (1,753 mm)

Weight 588 lb (267 kg) 690 lb (313 kg)

C O N T R O L : & F L U I D M A N A G E M E N T

S Y S T E M

( P F M S )

PRESSURE & FLUID MANAGEMENT SYSTEM (PFMS)

ឣAPPLICATIONS

Coiled-tubing and workover rigs; conventional drilling projects with small-footprint requirements; and cleanup, frac and flowback, re-entry and recompletion operations.

ឣPROBLEMS

The equipment configurations used on most rigs are not suited to coiled-tubing drilling or other types of drilling that require very close monitoring of pressures and solidscontrol parameters. Additionally, these more common configurations are not optimized for small spaces.

ឣSOLUTIONS

The M-I SWACO PRESSURE & FLUID MANAGEMENT SYSTEM* has been designed specifically for the needs of coiled-tubing drilling: automatic, accurate control of pressures and fluids parameters; small equipment footprint; and self-contained electrical and plumbing.

ឣECONOMICS

The PRESSURE & FLUID MANAGEMENT SYSTEM gives operators and drilling contractors a big advantage in controlling the problems that can ruin a project financially: blowouts, stuck pipe, lost circulation, formation damage, collateral-equipment damage and lost time due to logistics problems.

ឣENVIRONMENTAL

In most areas, smaller drilling operations are subject to the same environmental restrictions as larger projects. The PRESSURE & FLUID MANAGEMENT SYSTEM reduces disposal and fluids costs in addition to the environmental benefits of avoiding well-control incidents.

Features and Benefits Ease of Logistics • The three-piece modular system is skid-mounted • A 154-bbl, three-compartment tank with all the pumping, mixing, fluids-moving capabilities necessary • Single-point accountability — only M-I SWACO is on location for Drilling Waste Management (DWM) and pressure control • No welding or bolting required, all plumbing uses victaulic or hammered unions for fast rig-up • Smaller footprint, lighter load, meets all height and weight limitations for transportation • Reduced requirements for additional hoses, pumps and lines • All electrical is self-contained, requiring only one 300-kw supply connection to the main electrical distribution panel on the tank

Cost Reduction • Significant reduction in wellcontrol events, stuck pipe, lost circulation, formation damage and collateralequipment damage • Reduced disposal and fluids costs • Rig-up through rig-down is faster, improving overall project cost

Superior Performance This is a summary page. For complete information, please refer to the 2008 M-I SWACO ENVIRONMENTAL SOLUTIONS catalog.

• A continuous, closed-loop, pressure-control and drilling waste management system of field-proven equipment: patented 10k AUTOCHOKE

units, FMC 1502 2-in. (50.8-mm), 15,000-psi (1,034-bar) manifold, M-I SWACO MUD/GAS SEPARATOR, vacuum D-GASSER, 4T4 D-SILTER and patented MONGOOSE PT shaker equipped with patented OEM composite screens • Sensitive and precise wellheadpressure, casing-pressure and drill-pipe-pressure control • Chokes rated for severe-service operations (engineered for reduced wear) and H2S rated • The 3-in. (76.2-mm), full-bore 10k AUTOCHOKE features a non-plugging, self-cleaning orifice • Efficient gas separation achieved by a vortex- and baffling-effect in the MUD/GAS SEPARATOR, and baffling- and vacuum-effect in the D-GASSER • Dual-motion MONGOOSE PT shaker: linear motion for fast conveyance and heavy loading; balanced elliptical motion for maximum retention time and drier cuttings • Pre-tensioned OEM composite screens for fast change-out, accommodate a greater fluid capacity, resist blinding, produce a drier solids discharge, and are the most rugged, efficient and longest-lasting screens available • A 600-GPM- (2,271.2-L/min-) capacity 4T4 D-SILTER that will efficiently remove silt and sand particles above 25 microns and some as small as 5 microns


P R E S S U R E P R E S S U R E

167

R I G

I N S T R U M E N T A T I O N

SG-SMART Data-Acquisition System

The SG-SMART* data-acquisition system is an advanced driller’s monitoring system that can accurately measure, monitor and display all drilling variables in real time. This computer-controlled data-acquisition system employs integrated microcontroller technology and fiber optics to provide

Features and Benefits • Integrated microcontroller technology, fiber optics and state-of-the-art electronics • Designed to enhance drilling operations • Built-in diagnostics to simplify troubleshooting • Expandable for future technologies • Drilling data can be transmitted to a remote monitor • Optional data storage of all parameters • Real-time measurement and display of critical drilling data • Intrinsically safe operation in hazardous locations • Reliable operation in a wide range of temperatures • Simple, practical and easy to use • Field repairability reduces downtime • Stainless steel enclosures resist corrosion

accurate, instantaneous measurement and display critical drilling data. The M-I SWACO SG-SMART dataacquisition system has been awarded U.S. patents1 for its intrinsically safe operation in hazardous locations.

• Level I. Provides basic monitoring and measurement functions of PVT (up to 10 pits), gain or loss, PVT for two trip tanks with gain/loss, total pump strokes (5 pumps), return-flow rate (0 to 100%), fill-stroke count (each fill and total).

Features

• Level II. This system monitors and tracks additional information, including: Rate of Penetration (ROP), RPM, pump pressure, hydraulic and rotary torque, weight-on-bit, and hook load.

Easy to use. A common-sense interface makes the SG-SMART system simple and easy to use, and its self-documenting, menu-driven features facilitate evaluation and analysis. Designed for the driller. Both the hardware and the software are designed to assist the driller. Data displays in easy-to-read alphanumeric and graphical formats. Accurate. Integrated microcontroller technology and fiber optics link the sensors with the system to ensure high-speed accuracy, reliability and improved measurement resolution. Safe and reliable. CSA-approved, field-proven and intrinsically safe for installations in Class I, Division I areas, the SG-SMART system can operate in a wide range of temperatures from –25° to 150° F (–32° to 65° C). Minimum maintenance. Built-in diagnostics simplify troubleshooting, stainless steel enclosures resist corrosion, and field repairability reduces downtime. Versatile. Besides measuring and monitoring parameters onsite, all information displayed on the driller’s monitor can be transmitted via regular, voice-grade telephone lines to a remote monitor located anywhere in the world. Flexible. Two levels of capability allow expandability:


1U.S.

Patent Nos. 5,583,764, 5,838,589 and 6,574,652.

• Options. Choice of additional analog output channels, company man’s display, tool pusher’s display, circular chart recorder and transmission hardware to remote monitor.

Major Components The SG-SMART data-acquisition system consists of four major components: • Driller’s Monitor • CPU Junction Box • Barrier Box • One Satellite Box (Level I) or Two Satellite Boxes (Level II)

A major international operator wanted to determine the value of replacing three standard shaker units with two M-I SWACO* MONGOOSE* PT shakers. An online test while drilling compared flow capacity, cuttings dryness and time savings.

Onshore Argentina:

Two MONGOOSE PT shakers outperform three standard units; screen usage drops from 45 to 4 The solution and results M-I SWACO installed two MONGOOSE PT shakers over holding tanks on the operator’s land rig and connected them to a manifold carrying fluid evenly to both shakers in the course of drilling 15 wells. The MONGOOSE PT shakers successfully handled the same circulating fluid volume as the three standard shakers: 140- to 250-mesh screens at flow rates of 450 to 460 GPM (1,703 to 1,741 L/min) and a drilling rate of 63.6 ft/hr (19.4 m/hr). Improved cuttings dryness (WOC) resulted in 8% waste reduction and 5,283 gal (20 m3) per well of drilling mud saved — an average of $18,156 per well. The ability to convert the MONGOOSE PT shaker’s motion from linear to elliptical helped reduce fluid loss by 8%, for an average mud-cost savings of $2,570. The 15-well program required only four screens, compared to the 45 screens consumed for the same number of wells drilled with the standard shakers. Screen savings amounted to $17,835.

See for yourself how M-I SWACO prevents costly problems for operators worldwide. This success story is just one of hundreds where our ENVIRONMENTAL SOLUTIONS* specialists, equipment, processes and services prevent serious problems for operators every day. Your M-I SWACO representative can tell you more about our complete suite of solutions.

“M-I SWACO replaced three standard shakers with two MONGOOSE PT shakers to optimize solids-control system efficiency, reduce the WOC percent in cuttings, cut dilution

www.miswaco.com

expenses and saved $121,465.” ©2007 M-I L.L.C. All rights reserved. *Mark of M-I L.L.C.


The situation

169

P.O. Box 42842 Houston, Texas 77242-2842 Tel: 281·561·1300 Fax: 281·561·1441 www.miswaco.com E-mail: [email protected] Technology Centers: HOUSTON, TEXAS Tel: 281·561·1300 · Fax: 281·561·1441 ABERDEEN, SCOTLAND Tel: 44·1224·334634 · Fax: 44·1224·334650 STAVANGER, NORWAY Tel: 47·51·577300 · Fax: 47·51·576503 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.

©2008 M-I L.L.C. All rights reserved. *Mark of M-I L.L.C. FMC.0600.0804.R1 (E) 2.5M Litho in U.S.A.

MI-Swaco - Drilling_Solutions_Catalog 2008

Recommend Documents