This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Cementing.
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.
Casing Design | Tubing | Well Control | Drilling | Gaurav Singh RajputGaurav Singh Rajput
This document provides information on casing design, including:
- The functions of casing such as preventing hole collapse and contamination.
- Examples of typical casing strings like surface, intermediate, and production casing.
- Design considerations for casing like burst, collapse, and tension ratings.
- An example showing the iterative process of designing a casing string to withstand certain burst, collapse and tension requirements over multiple casing joints.
The document outlines the basic process and factors involved in designing well casing strings to isolate formations and safely drill to total depth.
This document provides definitions and information about directional drilling. It discusses the applications of directional drilling including its history and typical uses. It describes the main deflection tools used like whipstocks, jetting bits, and bent subs with mud motors. It also explains the two main types of mud motors - turbines and positive displacement motors. Finally, it outlines the three main types of well profiles: Type I or "build and hold", Type II "build, hold, and drop", and Type III "continuous build".
This document provides an overview of directional well drilling concepts and techniques. It discusses the necessity of directional wells, types of wellbore trajectories, survey methods used to calculate trajectory, deflection tools and techniques for adjusting well path, and different mechanical and hydraulic methods for changing wellbore direction including whipstocks, jetting bits, and downhole motors. Key trajectory calculations like dogleg severity and methods for comparing actual vs planned well paths are also summarized.
This document provides an overview of a mud engineer trainee's work experience with two rigs, DQE-32 and DQE-51. It discusses the functions of drilling fluid, types of mud, testing procedures, chemical categories used in mud systems, calculations, cementing operations, formation and downhole problems, and general mud engineering information. The trainee thanks their mentors at Petrochem for providing training support over their 3-month internship.
This document discusses the design of drillstrings and bottom hole assemblies (BHAs). It covers the components of drillstrings including drill pipe, drill collars, heavy weight drill pipe, and stabilizers. It also discusses BHA configurations and the purpose and components of BHAs. The document provides information on selecting drill collars and drill pipe grades. It covers criteria for drillstring design including collapse pressure, tension loading, and dogleg severity analysis.
This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Casing design.
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 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.
Casing Design | Tubing | Well Control | Drilling | Gaurav Singh RajputGaurav Singh Rajput
This document provides information on casing design, including:
- The functions of casing such as preventing hole collapse and contamination.
- Examples of typical casing strings like surface, intermediate, and production casing.
- Design considerations for casing like burst, collapse, and tension ratings.
- An example showing the iterative process of designing a casing string to withstand certain burst, collapse and tension requirements over multiple casing joints.
The document outlines the basic process and factors involved in designing well casing strings to isolate formations and safely drill to total depth.
This document provides definitions and information about directional drilling. It discusses the applications of directional drilling including its history and typical uses. It describes the main deflection tools used like whipstocks, jetting bits, and bent subs with mud motors. It also explains the two main types of mud motors - turbines and positive displacement motors. Finally, it outlines the three main types of well profiles: Type I or "build and hold", Type II "build, hold, and drop", and Type III "continuous build".
This document provides an overview of directional well drilling concepts and techniques. It discusses the necessity of directional wells, types of wellbore trajectories, survey methods used to calculate trajectory, deflection tools and techniques for adjusting well path, and different mechanical and hydraulic methods for changing wellbore direction including whipstocks, jetting bits, and downhole motors. Key trajectory calculations like dogleg severity and methods for comparing actual vs planned well paths are also summarized.
This document provides an overview of a mud engineer trainee's work experience with two rigs, DQE-32 and DQE-51. It discusses the functions of drilling fluid, types of mud, testing procedures, chemical categories used in mud systems, calculations, cementing operations, formation and downhole problems, and general mud engineering information. The trainee thanks their mentors at Petrochem for providing training support over their 3-month internship.
This document discusses the design of drillstrings and bottom hole assemblies (BHAs). It covers the components of drillstrings including drill pipe, drill collars, heavy weight drill pipe, and stabilizers. It also discusses BHA configurations and the purpose and components of BHAs. The document provides information on selecting drill collars and drill pipe grades. It covers criteria for drillstring design including collapse pressure, tension loading, and dogleg severity analysis.
This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Casing design.
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 provides an overview of directional well trajectory types and calculations. It discusses the importance of well planning, defining the surface and target locations using a local coordinate system. During drilling, the wellbore trajectory is constantly monitored in relation to the predefined target. The acceptable target size must be defined to make cost-effective decisions and ensure the well objectives are met, as drilling costs depend on the required accuracy. It also notes that the target size should reflect geological needs rather than just conventions.
This document discusses cementing processes used in oil well construction. It describes the dry and wet processes for cement manufacturing, including the key steps and materials used. It then covers the objectives of primary and secondary cementing in oil wells, including supporting casing, restricting fluid movement, and sealing off zones. Finally, it discusses various cement additives used to modify properties like viscosity, density, strength and permeability to suit specific well conditions.
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 provides an introduction to well control from Kingdom Drilling Services. It discusses primary and secondary well control, including maintaining pressure and monitoring flows. Loss of primary control can occur through pressure changes or lost circulation. Secondary control indicators include increased flow rates or mud pit volume changes. Methods for controlling kicks include circulating or bullheading. The document also covers well control terms, blowout prevention, shallow well hazards, and lost circulation detection and remedies.
Drill stem test (DST) is one of the most famous on-site well testing that is used to unveil critical reservoir and fluid properties such as reservoir pressure, average permeability, skin factor and well potential productivity index. It is relatively cheap on-site test that is done prior to well completion. Upon the DST results, usually, the decision of the well completion is taken.
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 drill stem testing (DST), which is used to evaluate reservoir properties. It describes the key components of a DST tool, including pressure recorders, test valves, packers, and more. It also outlines the steps to design a DST plan, considering factors like the test interval, packer selection and location, choke selection, and more. Finally, it explains how to execute a DST, interpreting the pressure chart by describing the initial flow, initial shut-in, final flow, and final shut-in periods marked on a sample chart.
Bullheading is a common non-circulating method for killing live wells prior to workovers. It involves pumping kill fluid into the tubing to displace produced fluids back into the formation. A bullheading schedule is generated using formation pressure, desired overbalance, fracture pressure, tubing specifications, and pump data to safely control pumping pressures within the initial and final maximum pressures. The schedule provides checkpoints to monitor pumping pressure and volume throughout the operation. Special attention should be paid to any increases in casing pressure which could indicate downhole issues.
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.
Drilling technology has evolved considerably over the past 150 years. There are now over 650 mobile offshore drilling units worldwide that can drill in water depths over 12,000 feet. Different types of offshore drilling rigs include semi-submersibles and jack-up rigs anchored to the seafloor. Drilling operations involve careful planning to identify locations where hydrocarbons are likely to exist based on geological and geophysical data collection methods.
This document discusses various techniques for directional drilling, including whipstocks, downhole motors, and steerable bottom hole assemblies. It provides details on running procedures for open hole and casing whipstocks. Downhole motors use bent subs or housing to create deflection, with adjustable bent subs allowing control of deflection from surface. Later techniques include steerable bottom hole assemblies with multiple bends or offset stabilizers to allow drilling the build section and constant angle zone with one tool.
This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Basic of well drilling process.
This document discusses downhole problems that can occur while drilling wells and methods to prevent them. It covers various downhole problems like pipe sticking, pipe failure, dog legs, key seats, shale problems, and lost circulation. Pipe sticking can be mechanical or differential. Dog legs occur from changes in formation dip or bit weight. Key seats form from doglegs. Shale problems include hole enlargement, caving, sloughing, and heaving. Lost circulation happens when mud pressure exceeds formation pressure. Prevention methods include using inhibitive muds, slowing drill string movement, and drilling with low pump pressure and fluid velocity. Faster drilling can mitigate many downhole problems by reducing shale exposure time and mud costs.
The document discusses well completion and testing methods. It begins with welcoming 7th semester mining students and introducing the instructor. It then provides definitions and overview sections on well completion, well testing, and drill stem testing. The document describes different well completion methods like open hole, cased hole, liner, and tubing completions. It also discusses wellhead equipment, well testing operations, and considerations for high pressure and high temperature testing. Overall, the document provides information on various aspects of well completion and testing.
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.
about 70 % of the existing reservoirs are impossible to reach with conventional drilling . MPD or managed pressure drilling is the best solution for HPHT and very deep reservoirs .
A drilling fluid, or mud, is circulated during drilling operations to carry cuttings to the surface, control formation pressure and maintain wellbore stability, cool and lubricate the drill bit, and minimize damage to the reservoir. There are three main types of drilling fluid: gaseous (like air), aqueous (water-based fluids containing additives like bentonite or polymers), and non-aqueous (oil- or synthetic-based). Proper handling and cleaning methods are required due to potential health and safety hazards from some drilling fluid components.
This document discusses different types of drilling rigs used on land and offshore. It describes land rigs as heavy, light, portable, and conventional. Offshore rigs include floating rigs like drill ships and semi-submersibles, bottom-supported rigs like jack-ups and fixed platforms, and barge and submersible rigs. It then compares stationary and mobile land rigs, noting stationary rigs have advantages like faster tripping speeds but require more investment, while mobile rigs have less investment costs but slower tripping speeds and drilling depth restrictions.
This document discusses cementing in oil and gas wells. It covers factors that affect cement slurry design like well depth and temperature. It describes cement additives that can control setting time. Float equipment like float collars and shoes are used to guide casing and enable cement circulation. Primary cementing involves pumping cement between casing and borehole to isolate formations. Secondary cementing through squeeze cementing can repair isolation barriers. Liner cementing cases off the open hole below an existing casing string. Cement plugs placed in casing are used for abandoning wells or zonal isolation.
This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Drilling Fluids
This document provides an overview of directional well trajectory types and calculations. It discusses the importance of well planning, defining the surface and target locations using a local coordinate system. During drilling, the wellbore trajectory is constantly monitored in relation to the predefined target. The acceptable target size must be defined to make cost-effective decisions and ensure the well objectives are met, as drilling costs depend on the required accuracy. It also notes that the target size should reflect geological needs rather than just conventions.
This document discusses cementing processes used in oil well construction. It describes the dry and wet processes for cement manufacturing, including the key steps and materials used. It then covers the objectives of primary and secondary cementing in oil wells, including supporting casing, restricting fluid movement, and sealing off zones. Finally, it discusses various cement additives used to modify properties like viscosity, density, strength and permeability to suit specific well conditions.
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 provides an introduction to well control from Kingdom Drilling Services. It discusses primary and secondary well control, including maintaining pressure and monitoring flows. Loss of primary control can occur through pressure changes or lost circulation. Secondary control indicators include increased flow rates or mud pit volume changes. Methods for controlling kicks include circulating or bullheading. The document also covers well control terms, blowout prevention, shallow well hazards, and lost circulation detection and remedies.
Drill stem test (DST) is one of the most famous on-site well testing that is used to unveil critical reservoir and fluid properties such as reservoir pressure, average permeability, skin factor and well potential productivity index. It is relatively cheap on-site test that is done prior to well completion. Upon the DST results, usually, the decision of the well completion is taken.
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 drill stem testing (DST), which is used to evaluate reservoir properties. It describes the key components of a DST tool, including pressure recorders, test valves, packers, and more. It also outlines the steps to design a DST plan, considering factors like the test interval, packer selection and location, choke selection, and more. Finally, it explains how to execute a DST, interpreting the pressure chart by describing the initial flow, initial shut-in, final flow, and final shut-in periods marked on a sample chart.
Bullheading is a common non-circulating method for killing live wells prior to workovers. It involves pumping kill fluid into the tubing to displace produced fluids back into the formation. A bullheading schedule is generated using formation pressure, desired overbalance, fracture pressure, tubing specifications, and pump data to safely control pumping pressures within the initial and final maximum pressures. The schedule provides checkpoints to monitor pumping pressure and volume throughout the operation. Special attention should be paid to any increases in casing pressure which could indicate downhole issues.
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.
Drilling technology has evolved considerably over the past 150 years. There are now over 650 mobile offshore drilling units worldwide that can drill in water depths over 12,000 feet. Different types of offshore drilling rigs include semi-submersibles and jack-up rigs anchored to the seafloor. Drilling operations involve careful planning to identify locations where hydrocarbons are likely to exist based on geological and geophysical data collection methods.
This document discusses various techniques for directional drilling, including whipstocks, downhole motors, and steerable bottom hole assemblies. It provides details on running procedures for open hole and casing whipstocks. Downhole motors use bent subs or housing to create deflection, with adjustable bent subs allowing control of deflection from surface. Later techniques include steerable bottom hole assemblies with multiple bends or offset stabilizers to allow drilling the build section and constant angle zone with one tool.
This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Basic of well drilling process.
This document discusses downhole problems that can occur while drilling wells and methods to prevent them. It covers various downhole problems like pipe sticking, pipe failure, dog legs, key seats, shale problems, and lost circulation. Pipe sticking can be mechanical or differential. Dog legs occur from changes in formation dip or bit weight. Key seats form from doglegs. Shale problems include hole enlargement, caving, sloughing, and heaving. Lost circulation happens when mud pressure exceeds formation pressure. Prevention methods include using inhibitive muds, slowing drill string movement, and drilling with low pump pressure and fluid velocity. Faster drilling can mitigate many downhole problems by reducing shale exposure time and mud costs.
The document discusses well completion and testing methods. It begins with welcoming 7th semester mining students and introducing the instructor. It then provides definitions and overview sections on well completion, well testing, and drill stem testing. The document describes different well completion methods like open hole, cased hole, liner, and tubing completions. It also discusses wellhead equipment, well testing operations, and considerations for high pressure and high temperature testing. Overall, the document provides information on various aspects of well completion and testing.
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.
about 70 % of the existing reservoirs are impossible to reach with conventional drilling . MPD or managed pressure drilling is the best solution for HPHT and very deep reservoirs .
A drilling fluid, or mud, is circulated during drilling operations to carry cuttings to the surface, control formation pressure and maintain wellbore stability, cool and lubricate the drill bit, and minimize damage to the reservoir. There are three main types of drilling fluid: gaseous (like air), aqueous (water-based fluids containing additives like bentonite or polymers), and non-aqueous (oil- or synthetic-based). Proper handling and cleaning methods are required due to potential health and safety hazards from some drilling fluid components.
This document discusses different types of drilling rigs used on land and offshore. It describes land rigs as heavy, light, portable, and conventional. Offshore rigs include floating rigs like drill ships and semi-submersibles, bottom-supported rigs like jack-ups and fixed platforms, and barge and submersible rigs. It then compares stationary and mobile land rigs, noting stationary rigs have advantages like faster tripping speeds but require more investment, while mobile rigs have less investment costs but slower tripping speeds and drilling depth restrictions.
This document discusses cementing in oil and gas wells. It covers factors that affect cement slurry design like well depth and temperature. It describes cement additives that can control setting time. Float equipment like float collars and shoes are used to guide casing and enable cement circulation. Primary cementing involves pumping cement between casing and borehole to isolate formations. Secondary cementing through squeeze cementing can repair isolation barriers. Liner cementing cases off the open hole below an existing casing string. Cement plugs placed in casing are used for abandoning wells or zonal isolation.
This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Drilling Fluids
This is an academic lecture for the Diploma in Engineering Mining and Mine Survey Technology Students based on the syllabus of the Bangladesh Technical Education Board (BTEB), Bangladesh. The course is related to Drilling Fluids.
Subject: Petroleum Well Design & Completion
This document discusses drilling fluids and cementing processes used in oil and gas drilling operations. It defines drilling mud as a fluid mixture used to carry rock cuttings to the surface and lubricate/cool the drill bit. Mud engineers are responsible for testing and treating the mud. The main types of drilling mud are water-based, oil-based, and synthetic-based. Cementing involves pumping cement slurry into the annular space between the casing and borehole to secure the casing and prevent fluid migration. Primary cementing is the initial process, while secondary cementing repairs or improves the primary cement job through techniques like squeeze cementing and plug cementing. Common cement types used include Portland cement, oil well cement, Class
This document contains information about well drilling design presented by Md. Majedur Rahman. It discusses selecting the optimal mud weight, defining hydraulic optimization, and describing components of the drilling string, drill bit, drill pipe, drill collar, and hoisting system. It also addresses well design characteristics, underbalanced drilling design, effects of high mud weight, barrier elements of well design, and test string design. The document is intended to help students understand well drilling design concepts.
Cementing involves pumping cement slurry down the casing string to isolate formations and support the casing. Key steps include:
1. Pumping cement slurry down the casing string after displacing drilling mud with a spacer fluid.
2. Releasing cement plugs to separate the cement from other fluids and indicate when cement displacement is complete.
3. Allowing the cement to set and harden before testing the zonal isolation provided by the cement sheath.
Proper additives, testing, calculations and centralization of the casing are important to achieve a good cement bond between the casing and formation.
The document discusses well drilling design. It begins with welcoming 7th semester mining students and introducing the instructor. It then covers topics like well design characteristics, selection of optimum mud weight, hydraulic optimization, components of the drilling string and hoisting system, and test string design. The document provides details on each topic with the goal of helping students understand well drilling design.
This document discusses casing and cementing in oil and gas wells. It describes the five types of casing used: surface, conductor, intermediate, and production casing. It also discusses cement composition, slurry design, when cementing is required, and well cementing techniques. The primary functions of casing and cementing are to prevent fluid migration and provide zonal isolation between geological formations in the wellbore. Cementing the casing strings helps achieve these functions and is an important part of well construction.
1. Grouting is a process of injecting fluid materials like cement into subsurface soils or rocks to fill pores and fissures.
2. There are different types of grouting materials and methods depending on the permeability and structure of the soil or rock.
3. Grouting is used for ground improvement on construction projects, fixing anchors, repairing defects, and other applications.
Module on Special and high performance concreteErankajKumar
The document discusses different types of special concretes used in construction, including grouting, guniting, underwater concreting, and hot and cold weather concreting. Grouting involves injecting cement grout into cracks and voids to improve stability. Guniting uses a cement-sand mix applied at high pressure to repair damaged concrete. Underwater concreting requires special techniques like the tremie method and uses additives to allow placement under water. Hot and cold weather concreting require precautions like cooling or heating aggregates and protecting fresh concrete to account for temperature effects.
1. Grouting is a process of injecting fluid materials like cement into soil or rock to fill pores and fissures.
2. There are different types of grouts including suspension, solution, and chemical grouts. Common materials used are cement, water, sand, and chemicals.
3. Grouting has applications in construction projects like mass concrete structures, ground anchors, and tunnel works. It can also be used to repair cracks in buildings.
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.
The document discusses drilling fluids, including their types, functions, properties, additives, and equipment/design considerations. The key types are water-based and oil-based muds. Drilling fluids must perform critical functions like controlling subsurface pressures, removing cuttings from the wellbore, lubricating the drill bit, and maintaining wellbore stability. Achieving these functions depends on optimizing properties like density, viscosity, and gel strength through the use of various additives like weighting agents, viscosifiers, and filtration control materials. Careful fluid selection and design is needed based on formation data and drilling conditions.
This document discusses well completion, which involves all post-drilling operations necessary for hydrocarbon production. It describes how completion planning must consider reservoir characteristics, fluid properties, and production forecasts to optimize equipment selection and well design. The document outlines different types of completions, including open hole, cased hole, tubingless, packerless, single string, selective, and multiple string configurations. Factors that influence completion design are also summarized such as reservoir pressure, permeability, fluid chemistry, temperature, and long-term production.
Grouting and guniting are construction techniques used to fill voids and apply concrete coatings. Grouting involves placing a cementitious mixture into cavities to strengthen structures, fill gaps, and stop leaks. There are different types of grouts for various applications. The guniting process involves mixing cement and sand then projecting it at high pressure onto surfaces using compressed air. It can be used on vertical, overhead and horizontal surfaces to rehabilitate concrete structures. Both grouting and guniting are effective techniques for repairing and strengthening buildings and infrastructure.
The document discusses liner cementing. It defines liners and describes typical liner assembly components. It outlines reasons for running liners such as reduced casing costs. It describes different liner types including drilling, production, scab/stub, and tie-back liners. It discusses considerations for liner cementing such as tight annular clearances and limited pump rates. It also presents widely used cementing methods and factors in selecting liner hangers. The document provides an example calculation for cementing a liner.
This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Well control and blowout preventions.
Primary cementing involves pumping a cement slurry down casing to isolate zones and support the casing. It is done soon after casing installation. Secondary cementing addresses later issues and includes techniques like squeeze cementing which forces slurry into annuli under pressure to seal leaks or supplement prior jobs. Proper planning and execution of cementing operations is important for achieving zonal isolation and well integrity.
Module on admixture , polymer and exposy resinsErankajKumar
The document discusses admixtures, polymers, and epoxy resins used in construction materials. It begins by defining admixtures as chemical compounds added to concrete mixes to modify properties such as workability, hydration rate, and strength. Common admixtures include accelerators, retarders, air-entrainers, and water reducers. The document then classifies and describes various admixture types and discusses their functions, advantages, and disadvantages. It provides details on specific admixture materials and how they affect concrete properties. The overall purpose is to educate civil engineering students on admixture fundamentals and applications in construction technology and management.
How to Download & Install Module From the Odoo App Store in Odoo 17Celine George
Custom modules offer the flexibility to extend Odoo's capabilities, address unique requirements, and optimize workflows to align seamlessly with your organization's processes. By leveraging custom modules, businesses can unlock greater efficiency, productivity, and innovation, empowering them to stay competitive in today's dynamic market landscape. In this tutorial, we'll guide you step by step on how to easily download and install modules from the Odoo App Store.
This presentation was provided by Rebecca Benner, Ph.D., of the American Society of Anesthesiologists, for the second session of NISO's 2024 Training Series "DEIA in the Scholarly Landscape." Session Two: 'Expanding Pathways to Publishing Careers,' was held June 13, 2024.
Andreas Schleicher presents PISA 2022 Volume III - Creative Thinking - 18 Jun...EduSkills OECD
Andreas Schleicher, Director of Education and Skills at the OECD presents at the launch of PISA 2022 Volume III - Creative Minds, Creative Schools on 18 June 2024.
A Visual Guide to 1 Samuel | A Tale of Two HeartsSteve Thomason
These slides walk through the story of 1 Samuel. Samuel is the last judge of Israel. The people reject God and want a king. Saul is anointed as the first king, but he is not a good king. David, the shepherd boy is anointed and Saul is envious of him. David shows honor while Saul continues to self destruct.
1. WELCOME TO THE STUDENTS
7th Semester (Mining)
Bogura Polytechnic Institute, Bogura.
Md. Majedur Rahman
B. Sc (Hon’s), M. Sc in Geology & Mining, RU
Instructor (Tech)
Mining and Mine Survey Technology
Bogura Polytechnic Institute, BOGURA.
Presented By
Prepared by Md. Majedur Rahman, E-mail: majedu1r_ru6871@yahoo.comMay 29, 2020 1
2. Petroleum Well Design & Completion
Course Code No. 69372
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
May 29, 2020 2
3. Chapter-07
Understand the Cementing
7.1 Define cementing.
7.2 Describe factors affecting cement slurry design.
7.3 State cement additives.
7.4 Describe floating equipment's.
7.5 Describe primary and secondary cementation.
7.6 Application of liner cementation.
7.7 Define cement plug.
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
May 29, 2020 3
4. Part of the process of preparing a well for further drilling, production
or abandonment, cementing a well is the procedure of developing and
pumping cement into place in a wellbore. Most
commonly, cementing is used to permanently shut off water
penetration into the well.
Cement is used to hold casing in place and to prevent fluid migration
between subsurface formations.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
4
7.1 Define cementing.
5. Cementing Principle
• To support the vertical and radial loads applied to the casing
• Isolate porous formations from the producing zone formations
• Exclude unwanted sub-surface fluids from the producing interval
• Protect casing from corrosion
• Resist chemical deterioration of cement
• Confine abnormal pore pressure
• To increase the possibility to hit the target
Cement is introduced into the well by means of a cementing head. It
helps in pumping cement between the running of the top and
bottom plugs.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
5
6. 7.2 Describe factors affecting cement slurry design.
Cement slurry is a mixture of Portland cement, water, and additives. A cement
slurry is forced into the annulus between the outside of the casing that has been
run in the well and the walls of the borehole.
• FACTORS AFFECTING CEMENT SLURRY DESIGN
The factors which influence the slurry design are :
1. Well depth, well diameter and casing size.
2. Bottom hole static temperature (BHST).
3. Bottom hole circulating temperature (BHCT).
4. Mud density/nature of mud in the well bore.
5. Samples of available cement, cement additives and water that is to be used in actual
job.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
6
7. The thermal and pressure conditions existing in the bore hole is of fundamental
importance to the planning, designing and execution of cementing operation. Also,
quality of cement, cement additives and mixing water affect the properties of
cement slurry. Slurry design should be carried out under well simulated conditions
with the cementing materials to be used at site. Following major factors have been
found important which need careful consideration in the design of cement slurry.
• DENSITY
Density of cement slurry is adjusted to:
1. Counter-balance the formation pressure,
2. Control the loss of slurry in weak zones,
3. Facilitate the effective mud removal/ displacement.
Normally, slurry density is kept higher than the mud for facilitating the
displacement of drilling fluid from annulus. The density difference of 0.2 to 0.5
gm/cc is normally recommended between mud and cement slurry .However,
formation to be cemented is the controlling factor to decide the extent of increase
over mud density .
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
7
8. • THICKENING TIME
Thickening time is a function of both temperature and pressure. Thickening time
can also be shortened by interruption of pumping (loss of agitation). Thus,
thickening time of a slurry must be established for realistic conditions to
ensure adequate pumping time for slurry placement. BHCT is used for determining
thickening time. Thickening time of the cement slurry should be sufficient which
should enable the operator to place the slurry to the predetermined depth safely.
Some margin of safety is also included so as to cover up the time of break down
while cementing. However I excessive thickening time over job time should
be avoided to prevent:
1. Delays in resuming drilling operation
2. Formation of free water pockets
3. Settling and separation of cement slurry components
4. Loss of hydrostatic head and gas cutting. Normally, recommended thickening
time is considered to be one hour plus the time required for the job.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
8
9. 7.3 State cement additives.
The rate at which hydration occurs when water is mixed with cement can be
altered using chemical additives. Additives are chemicals and materials
blended into base cement slurries to change the performance of the cement.
Due to the inherent nature of base cements and because of the demands
placed on the cement sheath throughout the life of the well, the
performance properties of the cementing slurry are modified to address the
specific and unique conditions of each well Anon. Many of the additives
currently used are organic, polymeric materials which have been specifically
formulated for use in well cementing operations Cowan and Eoff. Typical
chemical additives for oil and as well cementing operations include;
accelerator, retarders, extenders, fluid loss and loss circulation additives,
dispersants, and many more.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
9
10. There are 8 general categories of additives.
• Accelerators reduce setting time and increases the rate of
compressive strength build up.
• Retarders extend the setting time.
• Extenders lower the density
• Weighting Agents increase density.
• Dispersants reduce viscosity.
• Fluid loss control agents.
• Lost circulation control agents.
• Specialty agents.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
10
11. 7.4 Describe floating equipment's.
Floating equipment is generally used in the lower section of the well to help:
• Reduce strain on the derrick while guiding casing past ledges and slough zones in
the hole;
• Provide a landing point for bottom and top cementing plugs (pumped ahead of
and behind the slurry as part of cementing operations);
• Provide a backpressure valve to prevent cement from flowing back into the inner
diameter of the casing after the cement has turned the corner into the annulus
and the top plug has been bumped.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
11
12. Basic floating equipment includes the float collar and either the guide shoe or float
shoe:
• The guide shoe runs on the first joint of casing to be run into the hole to help
maneuver the casing past annular irregularities. The guide shoe includes side
ports and an open end to enable fluid circulation for mud conditioning, hole
cleaning, and cement placement.
• The float shoe contains a backpressure valve that prevents fluids from entering
the casing while the pipe is lowered into the hole and prevents cement from
flowing back into the casing after placement, while enabling circulation down
through the casing.
• Float collars are placed one to three joints above the guide shoe or float shoe.
They provide a seat for the cement plugs, the bottom plug pumped ahead of the
cement and the top plug behind the full volume of slurry. Once seated, the top
plug shuts off fluid flow and prevents over-displacement of the cement. The
space between the float shoe and the float collar provides a containment area to
entrap the likely-contaminated fluids from the wiping action of the top cementing
plug, securing the contaminated fluid away from the shoe where a strong cement
bond is of primary importance. Float collars include a backpressure valve and
serve basically the same function as the float shoe.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
12
13. Advantages of Float Equipment's
• Drillability of plugs and float equipment is easy and fast with either
conventional rotary bits or PDC bits.
• WiperLok system provides a proven anti-rotational mechanism and is
available in both standard as well as Sub-Surface Release plugs (SSR™
Plugs ).
• Withstands long periods of circulation with highly abrasive fluids.
• Top and bottom plugs rated to 80% of burst pressure for most
standard weight and grade casing.
• Polyurethane plug material is resistant to wear, making it ideal for
long casing strings
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
13
14. Float Equipment's
• Sure-Seal 3™ Float Equipment
• Sure-Seal 3 Float Valves
• Guide Shoes
• Cement Nose Guide Shoe - Model 202
• Downjet Cement Nose Guide Shoe - Model 222
• Composite Nose Guide Shoe - Model 202WM
• Texas Pattern Guide Shoe - Model 112
• Saw Tooth Pattern Guide Shoe - Model 105
• Large Bore Guide Shoe - Model L202
• Sure-Seal 3 Float Shoes
• Sure-Seal 3 Float Shoes
• Sure-Seal 3 Float Collars
• Auto-Fill Float Equipment
• Stab-in Float Equipment
• Insert Float Equipment
• SurgeMaster II
• MudMaster II Filter Shoe ™ and Auto-Fill Float Equipment
• Centralizer Sub and Float Equipment
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
14
15. 7.5 Describe primary and secondary cementation.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
15
16. Basic cementing procedure
1. Running Casing
2. Circulating mud by rig pump
3. Pressure testing
4. Pumping wash and spacer
5. Dropping the bottom plug
6. Mixing slurry
7. Pumping lead slurry
8. Pumping tail slurry
9. Dropping the top plug
10. Displacing slurries and plugs with fluid
11. Checking returns
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
16
17. Running casing
• The first joint of the casing run into the well has a float or guide shoe
attached to the end.
• After the first or second joint, a float collar is installed. The space
between the float collar and the shoe is called a shoe track.
• When the casing string is run to the desired depth, special
connections may need to be made just at the wellhead; this process is
called nippling up.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
17
19. Pressure testing
The high-pressure treating lines running from the cement unit to the
well connection must be pressure tested before the cementing process
begins
1. Prime the cement unit and lines with water to fill all the lines
2. Close the valve at the wellhead, and make sure no one is near the
lines
3. Increase the pressure to a predetermined level by having the unit
pump water.
4. Hold the pressure for about 5 minutes, and monitor for leaks.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
19
27. Checking returns
• The float collar contains a check valve
• At the end of a cementing job, check to ensure that the float collar or
float shoe is not leaking
• This check is done by allowing fluid to flow back to the cement unit
displacement tanks
• If the float collar or shoe is working correctly, 2 to 5 bbl will flow back
and then stop
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
27
28. Remedial/Secondary Cementing
When a primary cement job objectives have not been achieved, or
when the cement or casing has failed over time, it may be necessary to
repair the problem.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
28
29. Squeeze cementing
Cement slurry is forced through holes or splits in the casing to repair a
primary cement job or a well problem.
Purposes of squeeze cementing
1. Repair improper zonal isolation
2. Eliminate water intrusion
3. Repair casing leaks
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
29
39. 7.6 Application of liner cementation.
A liner is a string of casing that does not extend up to the wellhead. It
is used to case-off the open hole below an existing casing string.
Running such a string at the end of a drilling operation ensures that
the completion will be run in unworn casing.
Application
Cement plug system used in liner applications typically serve two
basic function:
1. They serve as physical barriers between the cement and other
wellbore fluids as they are being pumped, while effectively
wiping the cement from the tabular that its pumped through.
2. They confirm displacement volumes of both the running string
and the liner. Visible pressure indications signal when the
cement has been completely displaced from both the drill pipe
and the liner casing.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
39
40. 7.7 Define cement plug.
Cement plugs are placed into the casing or the open hole for many purposes:
• Abandoning depleted zones
• Sealing off lost circulation zones
• Sidetracking or directional drilling
• Abandoning the entire well
There are two techniques to place cement plugs: dump bailer and balanced plug.
• Dump bailer: this method requires the use of a bridge plug. The tool which contains the
cement slurry is run with the wireline and it is opened when it touches the bridge plug and
then the cement is dumped while pulling the tool. This method is used for shallow depths.
• Balanced plugs: it is the most common method. It is performed by running drill pipe string or
tubing at the desired depth. The mud contamination is avoided by pumping spacer to provide
proper placement. The volumes should be carefully calculated to obtain equal height of
cement in the annulus and the drill pipe string when completing the displacement and then
the string is slowly pulled with no rotation in order to do not disturb the balanced cement
plug.
May 29, 2020
Prepared by Md. Majedur Rahman, E-mail:
majedu1r_ru6871@yahoo.com
40