Petroleum Engineer's Guide to Oil Field Chemicals and Fluids

Johannes Fink

• Publisher: Gulf Professional Publishing
• Year: 2011
• eBook ISBN: 9780123838452
• Topic: Tecnología e ingeniería
• Subtopic: Ingeniería química y bioquímica

Petroleum Engineer's Guide to Oil Field Chemicals and Fluids is a comprehensive manual that provides end users with information about oil field chemicals, such as drilling muds, corrosion and scale inhibitors, gelling agents and bacterial control. This book is an extension and update of Oil Field Chemicals published in 2003, and it presents a compilation of materials from literature and patents, arranged according to applications and the way a typical job is practiced. The text is composed of 23 chapters that cover oil field chemicals arranged according to their use. Each chapter follows a uniform template, starting with a brief overview of the chemical followed by reviews, monomers, polymerization, and fabrication. The different aspects of application, including safety and environmental impacts, for each chemical are also discussed throughout the chapters. The text also includes handy indices for trade names, acronyms and chemicals. Petroleum, production, drilling, completion, and operations engineers and managers will find this book invaluable for project management and production. Non-experts and students in petroleum engineering will also find this reference useful. - Chemicals are ordered by use including drilling muds, corrosion inhibitors, and bacteria control - Includes cutting edge chemicals and polymers such as water soluble polymers and viscosity control - Handy index of chemical substances as well as a general chemical index

Chapter 1. Drilling Muds

According to the American Petroleum Institute (API), a drilling fluid is defined as a circulating fluid, used in rotary drilling to perform any or all of the various functions required in drilling operations.

Drilling fluids are mixtures of natural and synthetic chemical compounds used to cool and lubricate the drill bit, clean the hole bottom, carry cuttings to the surface, control formation pressures, and improve the function of the drill string and tools in the hole. They are divided into two general types: waterbased drilling muds (WBMs) and oil-based drilling muds (OBMs). The type of fluid base that is used depends on drilling and formation needs, as well as the requirements for disposing of the fluid after it is no longer needed. Drilling muds are a special class of drilling fluids used to drill most deep wells. The term mud is used because of the thick consistency of the formulation.

Drilling fluids serve several fundamental functions (Brazzel, 2009; Melbouci and Sau, 2008):

• Control of downhole formation pressures,

• Overcoming the fluid pressure of the formation,

• Avoiding damage to the producing formation,

• Removal of cuttings generated by the drill bit from the borehole, and

• Cooling and lubricating the drill bit.

In order to perform their fundamental functions, drilling fluids should possess several desirable characteristics, which greatly enhance the efficiency of the drilling operation.

These include desired rheological properties (plastic viscosity, yield value, low-end rheology, and gel strengths), fluid loss prevention, stability under various temperature and pressure operating conditions, stability against contaminating fluids, such as salt water, calcium sulfate, cement, and potassium contaminated fluids (Melbouci and Sau, 2008).

The drilling fluid should also have penetration enhancement characteristics that wet the drill string and keep the cutting surfaces of the drill bit clean (whether it is a roller cone or other configuration).

Wetting ability is at least in part a function of the surface tension of the fluid. The fluid should also have a high degree of lubricity and to minimize friction between the drill string and the wall of the borehole to minimize of differential sticking. In this situation, the hydrostatic pressure of the drilling fluid column must be sufficiently higher than the formation pressure so that the drill string is forced against the wall of the borehole and stuck.

It should also prevent the solids of the formation, primarily shales and clays, from swelling, so reducing the incidence of drill sticking, undergauge holes etc.

Classification of Muds

The classification of drilling muds is based on their fluid phase alkalinity, dispersion, and the type of chemicals used in their formulation. The classification according to (Lyons, 1996) is reproduced in Table 1.1.

Table 1.1 Classification of Drilling Muds

^dDispersed systems
^nNondispersed systems
Class	Description
Fresh water muds^d	pH from 7–9.5, include spud muds, bentonite-containing muds, phosphate-containing muds, organic thinned muds (red muds, lignite muds, lignosulfonate muds), organic colloid muds
Inhibited muds^d	Water-based drilling muds that repress hydration of clays (lime muds, gypsum muds, sea water muds, saturated salt water muds)
Low-solids muds^n	Contain less than 3–6% of solids. Most contain an organic polymer
Emulsions	Oil in water and water in oil (reversed phase, with more than 5% water)
OBMs	Contain less than 5% water; mixture of diesel fuel and asphalt

Drilling muds are usually classified as either WBMs or OBMs, depending upon the continuous phase of the mud. However, WBMs may contain oil and OBMs may contain water (Guichard et al., 2008).

OBMs generally use hydrocarbon oil as the main liquid component, with other materials such as clays or colloidal asphalts being added to provide the desired viscosity together with emulsifiers, polymers, and other additives including weighting agents. Water may also be present, but in an amount not usually greater than 50% by volume of the entire composition. If more than about 5% of water is present, the mud is often referred to as an invert emulsion, i.e., a water-in-oil emulsion.

WBMs conventionally contain viscosifiers, fluid loss control agents, weighting agents, lubricants, emulsifiers, corrosion inhibitors, salts, and pH control agents. Water makes up the continuous phase of the mud, and is usually present as at least 50 volume percent of the entire composition. Oil is also usually present in small amounts, but will typically not exceed the amount of the water, so that the mud will retain its character as a water-continuous-phase material.

Potassium muds are the most widely accepted water mud system for drilling water sensitive shales. K⁺ ions attach to clay surfaces and lend stability to the shale that is exposed to drilling fluids by the bit. The ions also help to hold the cuttings together, minimizing its dispersion into finer particles. Potassium chloride, KCl is the most widely used source of potassium, with others being potassium acetate, potassium carbonate, potassium lignite, potassium hydroxide, and potassium salt of partially hydrolyzed polyacrylamide (PHPA).

For rheological control, different types of polymers are used, such as xanthan gum and PHPA. For fluid loss control, mixtures of starch and polyanionic cellulose (PAC) are often used. Carboxymethyl starch, hydroxypropyl starch, carboxymethyl cellulose (CMC), and sodium polyacrylate are also ...

Table of contents

• Cover image
• Table of Contents
• Front Matter
• Copyright
• Preface
• Chapter 1. Drilling Muds
• Chapter 2. Fluid Loss Additives
• Chapter 3. Clay Stabilization
• Chapter 4. Lubricants
• Chapter 5. Bacterial Control
• Chapter 6. Corrosion Inhibitors
• Chapter 7. Scale Inhibitors
• Chapter 8. Gelling Agents
• Chapter 9. Filter Cake Removal
• Chapter 10. Cement Additives
• Chapter 11. Transport
• Chapter 12. Drag Reducers
• Chapter 13. Gas Hydrate Control
• Chapter 14. Antifreeze Agents
• Chapter 15. Odorization
• Chapter 16. Enhanced Oil Recovery
• Chapter 17. Fracturing Fluids
• Chapter 18. Water Shutoff
• Chapter 19. Oil Spill Treating Agents
• Chapter 20. Waste Disposal
• Chapter 21. Dispersions, Emulsions, and Foams
• Chapter 22. Defoamers
• Chapter 23. Demulsifiers
• Appendix 1. List of Tradenames
• Appendix 2. List of Acronyms
• Subject Index