Introduction to Drilling Fluid /or Mud used to drill Oil and Gas Wells into the sub-surface Hydrocarbon Reservoir. Overview of the rheological properties and general description.
Drilling fluids are absolutely essential during the drilling process and considered the primary well control.
Know more now about such a very important component of the drilling process.
The document discusses drilling fluids or mud, which are fluids circulated during drilling operations. There are several types of drilling fluids including water-based, oil-based, foam-based, and synthetic-based fluids. Drilling fluids serve various important functions including removing cuttings from the well, controlling formation pressure, maintaining wellbore stability, minimizing damage to the reservoir, and cooling and lubricating the drill bit. The appropriate type of drilling fluid depends on factors like the desired performance, environmental considerations, safety, cost, and availability. Water-based and oil/synthetic-based fluids are described in more detail. The document also outlines various properties and tests used to analyze the characteristics of drilling fluids.
This document provides information about drilling fluids used in oil and gas drilling operations. It discusses the key components and functions of drilling fluids, including bringing cuttings to the surface, controlling subsurface pressures, lubricating and cooling the drill bit. It also describes various types of drilling fluids like water-based muds, calcium muds, lignosulphonate muds, and KCl/polymer muds. The document discusses the role of clays and colloid chemistry in drilling fluids and outlines the properties and uses of different clay minerals.
This document discusses drilling fluid systems and their functions. It describes the classification of drilling muds as water-based or oil-based. Water-based muds can be further broken down and include bentonite muds, polymer muds, and muds with additives like gypsum, lime, potassium/lime, and mixed metal hydroxide. Oil-based muds include invert emulsion and mineral/synthetic oil-based muds. Key functions of drilling fluids are cooling and lubricating the drill bit, carrying cuttings to the surface, controlling formation pressure, and maintaining wellbore stability. Common measurements of mud properties are also outlined.
This document provides an overview of drilling fluids and their role in drilling operations. It discusses the components and properties of drilling fluids, including continuous and dispersed phases as well as additives. The types of drilling fluids are described, including water-based muds, oil-based muds, gases, and gas-liquid mixtures. The key functions of drilling fluids to support drilling operations are also outlined. The document concludes with discussions of pressure terminologies and examples of calculations related to drilling fluid properties and components.
This document discusses non-damaging drilling fluids (NDDF) used to control formation damage during drilling. NDDF was developed using non-degradable and degradable constituents to prevent damage to productive reservoirs. The basic composition of NDDF includes salts, calcium carbonate, polymers, and biocides. Two common types of NDDF are based on micronized calcium carbonate and sodium/potassium formate salts. NDDF provides advantages over conventional drilling fluids like reducing invasion of fines and bridging pore throats to minimize damage during drilling.
Drilling fluids are absolutely essential during the drilling process and considered the primary well control.
Know more now about such a very important component of the drilling process.
The document discusses drilling fluids or mud, which are fluids circulated during drilling operations. There are several types of drilling fluids including water-based, oil-based, foam-based, and synthetic-based fluids. Drilling fluids serve various important functions including removing cuttings from the well, controlling formation pressure, maintaining wellbore stability, minimizing damage to the reservoir, and cooling and lubricating the drill bit. The appropriate type of drilling fluid depends on factors like the desired performance, environmental considerations, safety, cost, and availability. Water-based and oil/synthetic-based fluids are described in more detail. The document also outlines various properties and tests used to analyze the characteristics of drilling fluids.
This document provides information about drilling fluids used in oil and gas drilling operations. It discusses the key components and functions of drilling fluids, including bringing cuttings to the surface, controlling subsurface pressures, lubricating and cooling the drill bit. It also describes various types of drilling fluids like water-based muds, calcium muds, lignosulphonate muds, and KCl/polymer muds. The document discusses the role of clays and colloid chemistry in drilling fluids and outlines the properties and uses of different clay minerals.
This document discusses drilling fluid systems and their functions. It describes the classification of drilling muds as water-based or oil-based. Water-based muds can be further broken down and include bentonite muds, polymer muds, and muds with additives like gypsum, lime, potassium/lime, and mixed metal hydroxide. Oil-based muds include invert emulsion and mineral/synthetic oil-based muds. Key functions of drilling fluids are cooling and lubricating the drill bit, carrying cuttings to the surface, controlling formation pressure, and maintaining wellbore stability. Common measurements of mud properties are also outlined.
This document provides an overview of drilling fluids and their role in drilling operations. It discusses the components and properties of drilling fluids, including continuous and dispersed phases as well as additives. The types of drilling fluids are described, including water-based muds, oil-based muds, gases, and gas-liquid mixtures. The key functions of drilling fluids to support drilling operations are also outlined. The document concludes with discussions of pressure terminologies and examples of calculations related to drilling fluid properties and components.
This document discusses non-damaging drilling fluids (NDDF) used to control formation damage during drilling. NDDF was developed using non-degradable and degradable constituents to prevent damage to productive reservoirs. The basic composition of NDDF includes salts, calcium carbonate, polymers, and biocides. Two common types of NDDF are based on micronized calcium carbonate and sodium/potassium formate salts. NDDF provides advantages over conventional drilling fluids like reducing invasion of fines and bridging pore throats to minimize damage during drilling.
This document discusses drilling fluids, including their types, functions, properties, and additives. It covers the main types of drilling fluids as water-based and oil-based, and their key functions such as removing cuttings from the wellbore, maintaining wellbore pressure and stability, lubricating and cooling the drill bit. The most common additives are described, including weighting materials to increase mud density, viscosifiers to suspend cuttings and materials, and other additives that control filtration, rheology, alkalinity and other properties. Selection of the appropriate drilling fluid depends on formation data and requirements for each well section.
This document discusses sustainable drilling fluid solutions. It begins with basic terminology used in drilling fluids like mud types, additives, and functions of mud. Water-based mud and oil-based mud are compared, noting that WBM is less toxic and can meet environmental issues but is not stable above 400°F, while OBM is stable above 400°F but more toxic. New developments in bio-polymers are discussed that can viscosify drilling fluids with less toxicity and better stability. In conclusion, water-based muds with bio-polymers are the most sustainable option while also addressing environmental concerns related to drilling fluids.
This document discusses various aspects of well planning such as pore pressure and fracture gradient determination, casing depth selection, and well configuration. It describes the different types of well planning for exploration, development, and completion/workover. Key factors in well planning include interaction between drilling and other departments to optimize costs, and fully evaluating rig and well design options. Typical well casing includes conductor, surface, intermediate, and production casing. Formulas are provided for pore pressure prediction based on overburden stress, hydrostatic pressure, and compaction effects. Criteria for selecting casing setting depths include controlling formation pressures and preventing differential pressure sticking.
The document discusses various natural reservoir drive mechanisms that provide energy for hydrocarbon production including:
1) Solution gas drive where dissolved gas expands due to pressure drop, providing 5-25% oil recovery.
2) Gas cap drive where free gas expansion drives production, providing 20-40% oil recovery.
3) Water drive where aquifer water influx provides pressure to displace oil, providing 35-75% oil recovery.
4) Gravity drainage where gas migrates updip and oil downdip in high dip reservoirs.
1. The document describes an experiment conducted to determine the rheological properties of viscosity and yield point of a drilling fluid sample using a Fann viscometer.
2. Key aspects of the experiment included preparing the mud sample, measuring its viscosity at 300 and 600 RPM, and determining its plastic viscosity and apparent viscosity. Calibration of the Marsh funnel and factors affecting rheological properties are also discussed.
3. Sources of potential error in measuring viscosity are described, such as improper mud weight, excess or insufficient fluid, and improper reading of the measuring scale.
The document discusses the functions and types of casing strings used in oil and gas wells. It describes the different casing strings like conductor casing, surface casing, intermediate casing, and production casing. It also covers casing design criteria like classifications based on outside diameter, length, connections, weight, and grade. The mechanical properties of casing are discussed in relation to withstanding tensile, burst, and collapse loads during drilling and production operations.
The document discusses various properties of drilling fluids including density, cation exchange capacity, filtration properties, pH, rheology, alkalinity, lubricity, and corrosivity. It defines these key terms and describes methods for measuring properties such as cation exchange capacity, pH, rheology, and corrosivity. Controlling properties like pH and alkalinity is important for drilling fluid performance and stability.
Primary cementing involves pumping a cement slurry down the casing or drill pipe to isolate formations and support the casing. It is critical to well integrity. Some key points covered in the document include:
- Cementing is done after lowering casing to isolate formations and support the casing.
- Primary cementing techniques can include single-stage, multi-stage, or liner cementation depending on well conditions.
- Secondary cementing techniques like squeeze cementing are used to remedy issues with prior cement jobs or isolate specific formations.
- Cementing is a critical operation that requires careful planning and execution to achieve well integrity on the first attempt, as there are no second chances.
The document discusses various well completion methods and sand control techniques. It begins by explaining that well stimulation may be needed if the well's productivity has been impaired by the perforation or completion method. It then reviews different completion methods and their basic requirements to connect the reservoir, protect the casing, bring fluids to surface, provide safety measures, control sand, and provide zonal isolation. The document focuses on techniques for predicting and controlling sand production, including the use of screens, gravel packing, chemical consolidation, and frac and pack completions. It provides details on sieve analysis, gravel pack selection and sorting criteria.
A drill stem test (DST) is used to test characteristics of a newly drilled well while the drilling rig is still on site. It can provide estimates of permeability, reservoir pressure, fluid types, wellbore damage, barriers and fluid contacts. There are three main methods to analyze DST data: Horner's plot method, type curve matching method, and computer matching. Type curve matching involves matching pressure change over time data from the DST to standard type curves to determine properties like permeability and skin factor. Gringarten type curves are commonly used and account for variations in pressure over time based on reservoir-well configurations.
This document discusses drilling fluids and their properties. It provides an overview of the principal functions of drilling fluids, which include subsurface pressure control, cuttings removal and transport, suspension of solid particles, sealing of permeable formations, stabilizing the wellbore, preventing formation damage, cooling and lubricating the bit, transmitting hydraulic horsepower to the bit, facilitating collection of formation data, partial support of the drill string and casing weights, controlling corrosion, and assisting in cementing and completion. It also discusses drilling fluid classifications, properties such as viscosity and rheology, and key components of drilling fluids.
This document summarizes a student's fluid mechanics lab experiment on measuring mud density. The aim was to learn how to use a mud balance apparatus to measure the density of drilling mud and see how density changes with the addition of barite. The student first prepared a bentonite mud and measured its density. Barite was then added to increase the mud density, which was remeasured. Understanding mud density is important for maintaining proper hydrostatic pressure to prevent fluid influx from formations during drilling.
Viscosity and yield point exp. by jarjis
Experiment Number 5: Yield Point.
Koya University.
Faculty of Engineering.
Drilling Lab
Supervised By Muhammad Jamal
Determine Plastic Viscosity, Apparent Viscosity, And Yield point of a drilling fluid (mud) by using Fann VG viscometer.
=============
This a report about Filtration. written by Jarjis Muhammad, Petroleum Engineering Dep. Koya University. For more Information please contact me: www.facebook.com/Jarjis.shaqlawaee
Casing is essential for safely drilling oil and gas wells. It must withstand forces during drilling and through the life of the well. Different casing strings are run to isolate formations with different pressures and seal off problematic zones to allow deeper drilling. Surface casing isolates fresh water and supports blowout preventers. Intermediate casing increases pressure integrity to drill deeper and protects progress. Production casing houses completion equipment and isolates the producing zone. Liners are shorter strings hung from intermediate casing to complete zones economically. Proper casing and cementing is crucial to isolate formations and prevent communication between zones.
Production tubing is installed in oil and gas wells to allow hydrocarbons to flow from the reservoir to the surface while protecting the casing from reservoir fluids. Tubing is specified based on its size, length, grade, and connection type. Common tubing sizes range from 2-3/8" to 4-1/2" in diameter. Tubing joints are typically 20-48 feet in length. Tubing grade depends on the application and is chosen based on strength, corrosion resistance, and availability. Connections can be either upset or non-upset threaded types.
Reservoir rocks experience compaction when fluid is produced, causing a change in pore volume and effective stress. There are three types of compressibility - rock matrix (grain) compressibility measures change in grain volume, rock bulk compressibility measures change in total formation volume, and pore volume compressibility measures change in pore space. Accurately measuring and modeling compressibility is important for predicting changes in porosity and formation properties during production.
This document discusses drilling mud, including its types, composition, properties, functions, and laboratory/field testing. It describes water-based muds and oil-based muds as the two main types, and their components such as liquids, solids, and chemicals. Key properties covered include density, viscosity, filtration, and gel strength. Important functions of drilling mud include hole cleaning, pressure control, cooling and lubrication. Common laboratory tests to evaluate mud properties and performance include measuring density, rheology, filtration, sand content, resistivity, and pH.
This paper discusses how controlling interfacial tensions between fluids and solids using micro-solution technologies can optimize production from mature, low pressure, under saturated, and low permeability reservoirs. Laboratory testing showed that treating a drilling fluid with micro-solutions reduced filtercake lift-off pressures from 10,000 kPa to 37 kPa and allowed 100% permeability regain. Field trials of wells drilled with micro-solution treated fluids showed better initial production and flow rates compared to analog wells drilled with untreated fluids. The micro-solutions reduce interfacial tensions by over 50%, improving flowback and optimizing permeability to hydrocarbons.
1) The document discusses using viscosifying surfactants for enhanced oil recovery (EOR). It introduces surfactant mesophases and how their rheological properties can increase fluid viscosity.
2) Rhodia and Poweltec's methodology for developing and testing viscosifying surfactant formulations is described. This includes measuring viscosity under reservoir conditions, fluid propagation tests in porous media, and core flood tests to evaluate oil recovery.
3) An example application to a field case demonstrates good thermal stability of a surfactant formulation and its ability to further increase oil recovery compared to polymer flooding alone.
This document discusses drilling fluids, including their types, functions, properties, and additives. It covers the main types of drilling fluids as water-based and oil-based, and their key functions such as removing cuttings from the wellbore, maintaining wellbore pressure and stability, lubricating and cooling the drill bit. The most common additives are described, including weighting materials to increase mud density, viscosifiers to suspend cuttings and materials, and other additives that control filtration, rheology, alkalinity and other properties. Selection of the appropriate drilling fluid depends on formation data and requirements for each well section.
This document discusses sustainable drilling fluid solutions. It begins with basic terminology used in drilling fluids like mud types, additives, and functions of mud. Water-based mud and oil-based mud are compared, noting that WBM is less toxic and can meet environmental issues but is not stable above 400°F, while OBM is stable above 400°F but more toxic. New developments in bio-polymers are discussed that can viscosify drilling fluids with less toxicity and better stability. In conclusion, water-based muds with bio-polymers are the most sustainable option while also addressing environmental concerns related to drilling fluids.
This document discusses various aspects of well planning such as pore pressure and fracture gradient determination, casing depth selection, and well configuration. It describes the different types of well planning for exploration, development, and completion/workover. Key factors in well planning include interaction between drilling and other departments to optimize costs, and fully evaluating rig and well design options. Typical well casing includes conductor, surface, intermediate, and production casing. Formulas are provided for pore pressure prediction based on overburden stress, hydrostatic pressure, and compaction effects. Criteria for selecting casing setting depths include controlling formation pressures and preventing differential pressure sticking.
The document discusses various natural reservoir drive mechanisms that provide energy for hydrocarbon production including:
1) Solution gas drive where dissolved gas expands due to pressure drop, providing 5-25% oil recovery.
2) Gas cap drive where free gas expansion drives production, providing 20-40% oil recovery.
3) Water drive where aquifer water influx provides pressure to displace oil, providing 35-75% oil recovery.
4) Gravity drainage where gas migrates updip and oil downdip in high dip reservoirs.
1. The document describes an experiment conducted to determine the rheological properties of viscosity and yield point of a drilling fluid sample using a Fann viscometer.
2. Key aspects of the experiment included preparing the mud sample, measuring its viscosity at 300 and 600 RPM, and determining its plastic viscosity and apparent viscosity. Calibration of the Marsh funnel and factors affecting rheological properties are also discussed.
3. Sources of potential error in measuring viscosity are described, such as improper mud weight, excess or insufficient fluid, and improper reading of the measuring scale.
The document discusses the functions and types of casing strings used in oil and gas wells. It describes the different casing strings like conductor casing, surface casing, intermediate casing, and production casing. It also covers casing design criteria like classifications based on outside diameter, length, connections, weight, and grade. The mechanical properties of casing are discussed in relation to withstanding tensile, burst, and collapse loads during drilling and production operations.
The document discusses various properties of drilling fluids including density, cation exchange capacity, filtration properties, pH, rheology, alkalinity, lubricity, and corrosivity. It defines these key terms and describes methods for measuring properties such as cation exchange capacity, pH, rheology, and corrosivity. Controlling properties like pH and alkalinity is important for drilling fluid performance and stability.
Primary cementing involves pumping a cement slurry down the casing or drill pipe to isolate formations and support the casing. It is critical to well integrity. Some key points covered in the document include:
- Cementing is done after lowering casing to isolate formations and support the casing.
- Primary cementing techniques can include single-stage, multi-stage, or liner cementation depending on well conditions.
- Secondary cementing techniques like squeeze cementing are used to remedy issues with prior cement jobs or isolate specific formations.
- Cementing is a critical operation that requires careful planning and execution to achieve well integrity on the first attempt, as there are no second chances.
The document discusses various well completion methods and sand control techniques. It begins by explaining that well stimulation may be needed if the well's productivity has been impaired by the perforation or completion method. It then reviews different completion methods and their basic requirements to connect the reservoir, protect the casing, bring fluids to surface, provide safety measures, control sand, and provide zonal isolation. The document focuses on techniques for predicting and controlling sand production, including the use of screens, gravel packing, chemical consolidation, and frac and pack completions. It provides details on sieve analysis, gravel pack selection and sorting criteria.
A drill stem test (DST) is used to test characteristics of a newly drilled well while the drilling rig is still on site. It can provide estimates of permeability, reservoir pressure, fluid types, wellbore damage, barriers and fluid contacts. There are three main methods to analyze DST data: Horner's plot method, type curve matching method, and computer matching. Type curve matching involves matching pressure change over time data from the DST to standard type curves to determine properties like permeability and skin factor. Gringarten type curves are commonly used and account for variations in pressure over time based on reservoir-well configurations.
This document discusses drilling fluids and their properties. It provides an overview of the principal functions of drilling fluids, which include subsurface pressure control, cuttings removal and transport, suspension of solid particles, sealing of permeable formations, stabilizing the wellbore, preventing formation damage, cooling and lubricating the bit, transmitting hydraulic horsepower to the bit, facilitating collection of formation data, partial support of the drill string and casing weights, controlling corrosion, and assisting in cementing and completion. It also discusses drilling fluid classifications, properties such as viscosity and rheology, and key components of drilling fluids.
This document summarizes a student's fluid mechanics lab experiment on measuring mud density. The aim was to learn how to use a mud balance apparatus to measure the density of drilling mud and see how density changes with the addition of barite. The student first prepared a bentonite mud and measured its density. Barite was then added to increase the mud density, which was remeasured. Understanding mud density is important for maintaining proper hydrostatic pressure to prevent fluid influx from formations during drilling.
Viscosity and yield point exp. by jarjis
Experiment Number 5: Yield Point.
Koya University.
Faculty of Engineering.
Drilling Lab
Supervised By Muhammad Jamal
Determine Plastic Viscosity, Apparent Viscosity, And Yield point of a drilling fluid (mud) by using Fann VG viscometer.
=============
This a report about Filtration. written by Jarjis Muhammad, Petroleum Engineering Dep. Koya University. For more Information please contact me: www.facebook.com/Jarjis.shaqlawaee
Casing is essential for safely drilling oil and gas wells. It must withstand forces during drilling and through the life of the well. Different casing strings are run to isolate formations with different pressures and seal off problematic zones to allow deeper drilling. Surface casing isolates fresh water and supports blowout preventers. Intermediate casing increases pressure integrity to drill deeper and protects progress. Production casing houses completion equipment and isolates the producing zone. Liners are shorter strings hung from intermediate casing to complete zones economically. Proper casing and cementing is crucial to isolate formations and prevent communication between zones.
Production tubing is installed in oil and gas wells to allow hydrocarbons to flow from the reservoir to the surface while protecting the casing from reservoir fluids. Tubing is specified based on its size, length, grade, and connection type. Common tubing sizes range from 2-3/8" to 4-1/2" in diameter. Tubing joints are typically 20-48 feet in length. Tubing grade depends on the application and is chosen based on strength, corrosion resistance, and availability. Connections can be either upset or non-upset threaded types.
Reservoir rocks experience compaction when fluid is produced, causing a change in pore volume and effective stress. There are three types of compressibility - rock matrix (grain) compressibility measures change in grain volume, rock bulk compressibility measures change in total formation volume, and pore volume compressibility measures change in pore space. Accurately measuring and modeling compressibility is important for predicting changes in porosity and formation properties during production.
This document discusses drilling mud, including its types, composition, properties, functions, and laboratory/field testing. It describes water-based muds and oil-based muds as the two main types, and their components such as liquids, solids, and chemicals. Key properties covered include density, viscosity, filtration, and gel strength. Important functions of drilling mud include hole cleaning, pressure control, cooling and lubrication. Common laboratory tests to evaluate mud properties and performance include measuring density, rheology, filtration, sand content, resistivity, and pH.
This paper discusses how controlling interfacial tensions between fluids and solids using micro-solution technologies can optimize production from mature, low pressure, under saturated, and low permeability reservoirs. Laboratory testing showed that treating a drilling fluid with micro-solutions reduced filtercake lift-off pressures from 10,000 kPa to 37 kPa and allowed 100% permeability regain. Field trials of wells drilled with micro-solution treated fluids showed better initial production and flow rates compared to analog wells drilled with untreated fluids. The micro-solutions reduce interfacial tensions by over 50%, improving flowback and optimizing permeability to hydrocarbons.
1) The document discusses using viscosifying surfactants for enhanced oil recovery (EOR). It introduces surfactant mesophases and how their rheological properties can increase fluid viscosity.
2) Rhodia and Poweltec's methodology for developing and testing viscosifying surfactant formulations is described. This includes measuring viscosity under reservoir conditions, fluid propagation tests in porous media, and core flood tests to evaluate oil recovery.
3) An example application to a field case demonstrates good thermal stability of a surfactant formulation and its ability to further increase oil recovery compared to polymer flooding alone.
The document provides an overview of various chemical enhanced oil recovery (EOR) methods including polymer flooding, colloidal dispersion gels, alkaline flooding, alkaline-polymer flooding, surfactant-polymer flooding, and alkaline-surfactant-polymer flooding. It discusses the basics of each method, how they work to increase oil recovery, examples of their application, and screening criteria for determining applicability to different reservoirs. Key topics covered include the use of polymers to increase water viscosity and improve sweep efficiency, using alkalis and surfactants to lower oil-water interfacial tension, and combining methods such as polymer gels followed by chemical EOR to control conformance.
Determining Loss of Liquid from Different Types of Mud by Various Addictives ...IRJESJOURNAL
Abstract :- Filtration is used in many industries to separate water from the solid. It is important to find fluid loss in drilling, cementing, fracturing, and almost every other type of downhole treatment design. The filter cake characterization is very essential for well selection of drilling fluid problems and formation damage. Therefore this study is taken up to experimentally investigate the effect of different concentrations of CMC, Starch, Wood fibers, Soda ash, Caustic soda, Bentonite and Barite on filtration loss and formation damages. Three different samples are used in this study at different concentration and a comparison is made. Although the discussion presented here is confined to fluid loss during drilling. Water-based drilling mud’s including Bentonite is wellknown and is being widely used in the petroleum industry. Among the important functions of water-based drilling fluid were to form filter cake on the wall of the well bore, prevent water leakage, and maintain the stability of the well wall. The properties of the water-based drilling fluid, such as the rheology and filtration loss, are affected by the fluid loss additive. Polymers, which are nontoxic, degradable, and environment friendly, are the best choice to be used as drilling fluids additives.
Produced water reinjection (PWRI) is one of the most usual ways of produced water reuse in mature fields with high water cut.
The relationship between water quality and injectivity decline in wells is well known and it is particularly important in mature
fields, such as Barrancas, an old field located in Mendoza –Argentina, with more than 40 years of water injection. In this
reservoir significant injectivity losses were recorded when fresh water was replaced by produced water in the 90´s.
Formation Damage mechanism is mainly caused by external cake. Particles are principally, iron sulfide, calcium carbonate,
and oil droplets.
The document discusses boiler water treatment. The key purposes of boiler water treatment are to prevent scale formation, corrosion, and carryover. It discusses various treatment methods like filtration, softening, and deaeration to purify feedwater before it enters the boiler. Chemicals are also added to control pH, oxygen, and total dissolved solids to ensure steam purity and protect boiler components from corrosion and scale. Proper water treatment is necessary to maintain high availability, efficiency, and lifespan of boilers and turbines.
Determination of Effect Bentonite and Additives On Drilling FluidsIRJESJOURNAL
Abstract :- Drilling fluids Play a vital role in hole Cleaning suspension of cuttings, prevent caving, and ensure the tightness of the well wall. Moreover they also help in cooling and lubricating the drilling tool, transfer the hydraulic power and carry information about the nature of the drilled formation by raising the cuttings from the bottom to the surface, using a simple mixture of water and clays, to complex mixtures of various specific organic and inorganic products as additives. These additives improve fluid rheological properties and filtration capability, allowing bits to penetrate heterogeneous geological formations The mud used in this work is barite and bentonites at different samples to know the difference in their specific gravity, viscosity, surface tension, and pH of the samples when chemical additives are added.
Prevention of dynamic sag in deepwater invert emulsion fluidamrhaggag
This document summarizes laboratory and field testing of a new sag-preventing organophilic clay (SPOC) additive for controlling barite sag in invert emulsion drilling fluids for deepwater wells. Laboratory tests showed the SPOC improved low-shear rheology and reduced sag compared to conventional organoclays. Field tests in two deepwater Gulf of Mexico wells demonstrated the SPOC, combined with a conventional organoclay, maintained rheology while minimizing sag during drilling and extended well logging periods. The SPOC additive successfully controlled barite sag in challenging deepwater drilling applications.
This document summarizes a study on the effect of pH on clay that has been contaminated by various substances. The study artificially contaminated kaolinite clay samples with different concentrations of pore fluids, salts, heavy metals, and non-metals to determine how these contaminants affect the pH level of the clay. The initial pH of the uncontaminated kaolinite clay was 6.5. Tests found that the pH decreased with increasing concentrations of sodium chloride and magnesium chloride contaminants, but increased with calcium chloride contamination. The changes in clay pH levels due to different contaminants can impact the geotechnical properties and chemical characteristics of the clay.
The document discusses scientific approaches to inhibiting the transformation of water-based process fluids. It aims to develop chemical technologies and equipment for slowing transformation through new scientific solutions. The research seeks to establish theoretical foundations for inhibition processes based on mass transfer and hydrodynamic theories. It analyzes factors causing rapid fluid changes and outlines tasks to define transformation indicators, develop inhibition methods, and create resource-efficient technologies to maintain fluid quality for over one year of use.
This document summarizes a presentation about drilling fluids. It defines drilling fluid as a mixture of clay and chemicals pumped through a drill bit to provide hydrostatic pressure, suspend cuttings, cool and lubricate the bit, and provide information from the wellbore. The presentation covers the types of drilling fluids, their functions, additives used, and rheological properties measured. It also describes the drilling fluid circulation system and discusses drilling fluid considerations and emergency remedies.
This document summarizes research on developing stable and degradable fracturing fluids using oilfield produced formation water. The fluids were formulated with guar polymers and crosslinked using borates or zirconates. Rheology tests measured viscosity at temperatures from 210-260°F, and residue analysis tested degradation with breakers at 185°F. Results showed the fluids provided sufficient viscosity for transporting proppants into fractures, and could be degraded to low viscosity to enhance hydrocarbon recovery. Using produced water reduced operating costs and environmental impacts compared to fresh water.
This document discusses chemical EOR methods including surfactants and polymers. Surfactants are used to lower interfacial tension between oil and water, change rock wettability, and generate foams or emulsions. Polymers such as HPAM increase water viscosity for mobility control. Successful polymer flooding projects can recover 5-30% of original oil in place through improved sweep efficiency. Key factors for polymer flooding include reservoir continuity, remaining oil saturation, and favorable injection conditions.
IRJET - Evaluation of Wheat Husk as Environment Friendly Fluid Loss Addit...IRJET Journal
This document evaluates wheat husk powder (WHP) as an environmentally friendly fluid loss additive to replace carboxymethyl cellulose (CMC) in water-based drilling fluids. Drilling fluids were prepared with varying concentrations of WHP and CMC, and their rheological and filtration properties were tested. The results showed that drilling mud prepared with 3-4% WHP had better filtration properties, with thinner mud cakes and lower fluid loss volumes, compared to mud prepared with CMC. WHP also improved the rheological properties of the mud and provided thermal stability up to 100°C. Therefore, WHP is an effective and environmentally-friendly replacement for CMC as a fluid loss additive in water-
DRILLING FLUIDS FOR THE HPHT ENVIRONMENTMohan Doshi
A BRIEF REVIEW OF THE DRILLING FLUIDS FOR DRILLING HPHT WELLS. HPHT WELLS ARE NOT BUSINESS AS USUAL AND THE SAME APPLIES TO HPHT DRILLING FLUIDS. THE FLUID CHEMISTRY AND THE FLUID COMPOSITION HAVE TO BE TAILORED TO MEET THE RIGORS OF THE HIGH TEMPERATURE ENVIRONMENT
- The document discusses reservoir characteristics including rock and fluid properties that are important to understand for optimal hydrocarbon recovery. Techniques like seismic data, well logging, and testing provide valuable data to build reservoir models.
- Key rock properties that impact hydrocarbon storage and flow include porosity, permeability, and wettability. Core analysis in the lab and well logs provide data on these properties.
- Understanding fluid properties like phase behavior under reservoir conditions of pressure and temperature is also important for predicting production performance and fluid composition.
This document discusses reservoir characteristics, rock and fluid properties, and drive mechanisms. It provides information on:
1) Techniques like seismic data, well logging, core analysis, and well testing that are used to understand the reservoir and develop an accurate reservoir model.
2) Reservoir characteristics including rock type, porosity, permeability, and factors that allow hydrocarbon accumulation like sufficient pore space and traps.
3) Rock properties such as porosity, permeability, and how they impact fluid flow.
4) Fluid properties including phase behavior under varying pressures and temperatures, properties of different fluid types, and sampling techniques.
5) Common experiments done to analyze reservoir fluids using pressure-volume-temperature cells
Effect of fly ash on the rheological and filtration properties of water based...eSAT Journals
Abstract An experimental investigation was carried out to study the effect of fly ash on the rheological and filtration properties of water based drilling fluids with the objective of the development of environmentally acceptable non-damaging and inhibitive drilling fluid system to drill sensitive formations. Initially, different drilling fluids combinations were prepared using carboxy methyl cellulose (low viscosity grade), polyanionic cellulose, xanthan gum, and potassium chloride. The rheological properties as well as filtration properties of these drilling fluids were measured by API recommended methods. These drilling fluids show very good rheological behavior but poor filtration loss characteristics. When fly ash was added in these drilling fluid combinations, a nanoparticles fluid system was established which has better control on filtration properties without affecting the rheological properties and has good potential for the drilling of sensitive formations. Index Terms: Filtrate Loss Properties, Rheological Properties, Wellbore Instability, Inhibitive Drilling Fluid, Nanoparticles, Shale.
IJRET : International Journal of Research in Engineering and Technology is an international peer reviewed, online journal published by eSAT Publishing House for the enhancement of research in various disciplines of Engineering and Technology. The aim and scope of the journal is to provide an academic medium and an important reference for the advancement and dissemination of research results that support high-level learning, teaching and research in the fields of Engineering and Technology. We bring together Scientists, Academician, Field Engineers, Scholars and Students of related fields of Engineering and Technology.
Boger fluids are elastic fluids with constant viscosity that exhibit both liquid and solid behaviors. They are highly dilute polymer solutions that do not experience shear thinning. Boger fluids are useful in rheology experiments to isolate the effects of elasticity from other non-Newtonian behaviors. They allow experiments comparing an elastic Boger fluid to a Newtonian fluid with the same viscosity to isolate the impact of elasticity. Boger fluids are commonly made from small amounts of polymers like polyacrylamide added to viscous fluids like corn syrup or maltose syrup.
Comparative analysis between traditional aquaponics and reconstructed aquapon...bijceesjournal
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Drilling fluids
1. भारतीय प्रौद्योगिकी संस्थान (भारतीय खनन विद्यापीठ), धनबाद
INDIAN INSTITUTE OF TECHNOLOGY (ISM), DHANBAD
पेट्रोलियम अलभयांत्रिकी विभाि
Department of Petroleum Engineering
Term Presentation on;
‘Rheology and Filtration Characteristics of Drilling
Fluids for Efficient Drilling Operations’
PRITISH BARMAN 2nd Semester,
M.Tech (2016-18)
2. Content
OBJECTIVE
INTRODUCTION
Properties Of Drilling Fluids
Rheology Characteristics
Filtration Control
Case Study
CONCLUSION
REFERENCES
3. Objective
Describe Drilling Fluid
Properties of Drilling Fluid
μ, ρ,Fluid Loss, pH, PV, YP, gel, Alkalinity
Discuss Rheological Characteristics
Rheology & Hydraulics, Fluid Types
Filtration Loss Control
Filtration Control Agents
Lost Circulation Materials
API Fluid Loss Description
Case Study
Summarize
4. Introduction to Drilling Fluids
(a.k.a Mud) -complex mixture of a base, either water, oil or air
and various additives.
Water Based Mud (WBM), Oil Based Mud (OBM), and
Aerated Mud (ABM)
weighting, rheology, filtration control, eccentricity and hole
cleaning etc.
overbalance to contain kick and blowout
cutting lifting
shale inhibition
borehole stability
keeping the bit and the drill string cool,
prevent pipe sticking
drag and torque on the drill string
5. Properties of Drilling Fluids
Viscosity
internal resistance provided by a fluid to its flow
attraction between molecules of a liquid
adhesion and cohesion on suspended particles and liquid
most familiar instrument used on field is ‘Marsh Funnel’
Unit of viscosity in oil industry is centipoises (cp)
Density
The term mud weight is used in connection with mud often than
density
quantity of solids in the liquid phase
ρm = Mw+Ms /Vw+Vs
6. Properties of Drilling Fluids
Fluid Loss
Fluid loss is defined as the loss of a mud filtrate (liquid
phase) into a permeable formation
Mud solids are deposited on the walls of the hole, and
filtrate invades the formation
object is to form a thin, tough filter cake to prevent
excessive loss of filtrate
7. Properties of Drilling Fluids
pH
The pH, or hydrogen ion concentration, is a measure of the relative
acidity or alkalinity.
Generally, the pH of mud falls between 8 and 11
major role in controlling the solubility of calcium
At high pH values, calcium solubility is very limited
high-pH mud suitable for use in the drilling of carbonate formation
pH value is also an important indicator for the control of corrosion
A minimum value of 9.5 should be maintained to prevent oxygen
corrosion
high pH tends to disperse (disintegrate) the active clays in the mud
Starch is used as a fluid loss additive.
Starch is susceptible to bacterial attack at pH values below 11.5
8. Properties of Drilling Fluids
Alkalinity
Alkalinity or acidity of a mud is indicated by the pH.
The pH scale is logarithmic and hence a high pH mud may vary
considerably without a noticeable change in pH.
The filtrate and mud can both be measured to show the
phenolphthalein alkalinity.
The test for filtrate is carried out by putting 1 or more milliliters of
filtrate into a titration dish and adding 2 or 3 drops of phenolphthalein
indicator solution.
Drops of 0.02 normal nitric or sulfuric acid solutions are then added
until the pink coloration just disappears.
The alkalinity is measured as the number of milliliters of acid per
milliliter of filtrate.
The test for mud is similar except that to one milliliter of mud, 25 to 50
milliliters of water are added for dilution and 4 or 5 drops of
phenolphthalein are added. The result is measured the same as for the
filtrate.
9. Rheological Characteristics
Rheology and Hydraulics
Rheology and hydraulics are interrelated studies of
fluid behavior.
Fluid rheology and hydraulics are engineering terms
that describe the behavior of fluids in motion.
Rheology is the science of deformation and flow of
matter.
Primarily concerned with the relationship between
shear stress and shear rate and the impact they have
on fluid flow characteristics inside tabular and annular
spaces.
10. Rheological Characteristics
Plastic Viscosity
The plastic viscosity (PV) is calculated by measuring the
shear rate and stress of the fluid. These values are
derived by using a Fann viscometer, which is a rotating
sleeve viscometer, and may be a simple hand operated
two speed model or a more complex variable speed
electric model. The two speed model operates at 300
and 600 rpm.
i.e. PV (cp) =Ɵ600-Ɵ300
11. Rheological Characteristics
Yield Point
Yield point, the second component of resistance to
flow in a drilling fluid, is a measurement of the electro-
chemical or attractive forces in a fluid. These forces are
a result of negative and positive charges located on or
near the particle surfaces.
Mathematically yield point is calculated from the
equation:-
YP = Ɵ300 – PV
YP = (2 × Ɵ300) – Ɵ600
Unit of YP is lbs /100ft².
12. Rheological Characteristics
Gel Strength
It is the measurement of the attractive forces of the
mud while at rest or under static conditions.
The magnitude of gelation, as well as the type of gel
strength, is important in the suspension of cuttings
and weight material.
Two readings: 10 second and 10 minute with the speed
of the viscometer set at 3 rpm.
The fluid must have remained static prior to each test,
and the highest peak reading will be reported.
The unit of gel strength is same as yield point,
i.e. lbs/100 ft²
13. Table: Comparison of non-Newtonian, Newtonian, and viscoelastic properties
Viscoelastic
Kelvin material,
Maxwell material
"Parallel" linear
combination of elastic and
viscous effects
Some lubricants, water
Time-dependent
viscosity
Rheopecty
Apparent
viscosity increases with
duration of stress
Synovial fluid, printer ink,
Thixotropic
Apparent
viscosity decreases with
duration of stress
xanthan gum solutions,
some clays, some drilling
many paints
Non Newtonian
Viscosity
Shear thickening
(dilatant)
Apparent viscosity
increases with increased
stress
Suspensions of corn -starch in
water
Shear thinning
(pseudoplastic)
Apparent
viscosity decreases with
increased stress
paper pulp in water, latex
paint, ice, blood, sand in
Generalized
Newtonian fluids
Viscosity is constant.
Stress depends on normal
and shear strain rates and
also the pressure applied
on it
Blood plasma,
custard, water
15. Rheology Control Agents
Viscosifier (Suspending Agents)
Additives in drilling fluid which serve the purpose to provide desired
viscosity required for various functions such as cutting carrying
capacity and gel strength of mud.
These include:
a.Bentonite Clay
b.CMC, Carboxymethyl Cellulose
c. Xanthan Gum
d.Guar Gum
e.PAC HV, Poly Anionic Cellulose (High Viscosity)
16. Rheology Control Agents
Flocculants
Are used to increase viscosity for improved hole cleaning, to
increase bentonite yield and to clarify or de-water low solids drilling
fluids. Flocculants cause colloidal particles in suspension to group
into clusters or flocs causing solids to settle out. Flocculants
commonly used in the oilfield include:
Drill Salt (Brine), NaCl, Sodium Chloride
KCL, Potassium Chloride
Hydrated Lime, Calcium Hydroxide
Gypsum, Calcium Sulfate
Soda Ash, Sodium Carbonate
Sodium Bicarbonate (Bicarbonate of Soda)
TSPP, Tetrasodium Pyrophosphate
Polyacrylamide Polymers
17. Rheology Control Agents
Thinning (De-flocculants) Agents
Modify the relationship between viscosity and percentage of solids
in a drilling fluid. Thinning agents can be used to reduce gel
strength to improve pump-ability of a drilling fluid. Thinning agents
function as a de-flocculants to prevent the flocculation of clay
particles which produce high viscosity and gel strength.
a.Lignosulphonates
b.Ligthin (Caustized Lignite)
c. Lignite
18. Rheology Control Agents
Emulsifiers
To create a homogeneous mixture (an emulsion) of two insoluble
liquids. Emulsifiers may be anionic (negatively charged), non-ionic
(neutral) or cationic (positively charged) chemicals, depending on
whether they are used as primary or secondary emulsifiers.
Fatty acid and amine based chemicals are used in oil base drilling fluids.
Detergents and soaps
Organic acids
Water based surfactants are used for water base drilling fluids.
19. Filtration Control Additives:
Filtration Control Agents
These products reduce fluid loss of a drilling fluid in various
operating conditions including water base drilling systems, oil base
drilling systems, high temperature and high temperature drilling
environments.
Water Based Drilling Fluids
a.Bentonite
b.CMC, CarboxyMethyl Cellulose
c. PHPA, Partially Hydrolyzed Polyacrylamide
d.PAC LV, Poly Anionic Cellulose (Low Viscosity)
e.PAC HV, Poly Anionic Cellulose (High Viscosity)
f. Drill Amyl, Modified Starch
20. Filtration Control Additives:
Loss Circulation Materials (LCM)
The primary function of Loss Circulation Materials is to
physically plug the zone in the formation that is losing
drilling fluids. Commonly used products offered by include:
Nut Plug
Mica (Medium grade)
Mica (Fine grade)
Mica (Coarse grade)
21. Case Study:
‘Future Direction of Research and Challenges in
Mud Engineering’
Developing environment-friendly OBM for Field Application
Formulation of an environmentally friendly drilling fluid with zero impact on
the environment.
Ammnullah (2010) proposed the use of waste vegetable oil in the
formulation of environment friendly OBM.
Ogunrinde and Dosunmu (2010) suggested the use of palm-oil. A major
multinational oil company for off-shore drilling operations had used highly
de-aromatized aliphatic solvents to formulate low toxicity mud system.
Challenge is to bring down the cost of formulation of these muds.
22. Case Study:
‘Future Direction of Research and Challenges in
Mud Engineering’
Development of environment friendly mud additives
Hazardous effects of additives on marine and human life had been reported.
Effect ranges from minor physiological changes to reduced fertility and
higher mortality rates.
For example,
1) Jonathan et al. (2002) reported that
ferro-chrome lignosulfonate (a thinner and deflocculant) affected the survival and
physiological responses of fish eggs and fry.
The filtration control additive CMC (carboxymethylcellulose) causes the death of
fish fry at high concentrations (1000-2000 mg/ml) and physiological changes start
the level of at 12-50 mg/ml.
2) On the other hand, corrosion inhibitors such as phosphoxit-7, EKB-2-2,
and EKB-6-2 cause genetic and teratogenic damages in humans.
23. Case Study:
‘Future Direction of Research and Challenges in
Mud Engineering’
Development of mud and/or additives for HTHP Applications
At extreme high temperature and high pressure (HTHP) conditions, mud
systems formulated with macro and micro based materials (chemicals and
polymers) become drastically altered.
This is due to the breakage or association of polymer chains and branches by
vibration,
Brownian motion and
thermal stress
causing drastic reduction in gelling and viscous properties.
To solve this problem, nanos with excellent thermal stability and with extreme
pressure consistency should be developed.
24. Conclusion
The success and smooth operation of the entire drilling program is
based on optimum designing and monitoring of the drilling fluid, is
mud.
Various additives are added to each mud system to achieve desired
mud characteristics of rheology, weighting and filtration control.
Weighting is primarily achieved by adding weighting agents commonly
barite, lignite etc.
Rheology control includes monitoring the parameters of plastic
viscosity, apparent viscosity, yield point, equivalent circulation density,
and gel strength.
High Filtration may cause serious damages to the formation
To keep the fluid loss in check, it is necessary to design the mud
according to the particular geo technical order of the well.
Filtration control additives are used to condition the mud for reducing
the fluid loss, additionally,
lost control materials like mica flakes are pumped to arrest abnormal
filtrate loss by forming physical barriers between the wellbore and the
formation.
25. References
Devereux, S., 1999. Drilling Technology: In Nontechnical Language,
PennWell Books.
Fink, J., 2011. Petroleum engineer’s guide to oil field chemicals and
fluids, Access Online via Elsevier.
Hawker, D., 2001. Drilling Fluid Hydraulics.
Max R. Annis, M.V.S., 1996. Drilling Fluid Technology Exxon Manual.
Skalle, P., 2010. Drilling Fluid Engineering, Bookboon.