The document discusses various causes of stuck pipe that fall under three main categories: 1) packing off and bridging, 2) differential sticking, and 3) wellbore geometry issues. Under the first category of packing off and bridging, the document describes seven specific cases that can lead to stuck pipe, such as cutting settling in vertical or deviated wells, shale instability, unconsolidated formations, and cement blocks. Preventive actions and procedures for addressing each stuck pipe scenario are provided.
This document provides guidelines and best practices for preventing and resolving stuck pipe incidents. It discusses various sticking mechanisms including pack-offs caused by solids, unconsolidated formations collapsing into the wellbore, mobile formations being compressed, and fractured or faulted formations allowing debris to fall in. Preventative actions include maintaining proper mud weight, minimizing circulation time in risk zones, and using reamers when needed. The document provides response procedures to follow if pipe becomes stuck, such as reducing pump rates, applying torque and jarring to free the pipe. It also covers jar types, accelerator tools, and the communication needed for stuck pipe operations.
1) The document discusses different types of drill bits used in drilling operations including PDC, natural diamond, TSP, impregnated diamond, roller cone, tooth, and insert bits.
2) It explains the IADC classification system for drill bits which codes them based on factors like cutting structure, bearing type, and application in soft to hard formations.
3) The IADC dull grading code characterizes used drill bits according to wear characteristics like erosion, broken cutters, and reasons for being pulled such as being worn out.
Drilling operations can encounter various problems related to geological uncertainties, wellbore stability issues, and depletion effects. Some key risks include uncertainties in pore pressure-fracture gradient measurements, mud volcanoes causing landslides or weak formations, fault zones providing pathways for fluid flow, and maintaining wellbore integrity in low-pressure depleted zones. Operators address these challenges through careful planning, identifying potential hazard areas using seismic data, selecting appropriate drilling fluid properties, and employing wellbore strengthening techniques and lost circulation materials when needed to prevent fluid losses and wellbore collapse.
1. The document discusses different types of stuck pipe that can occur while drilling, including differential pressure pipe sticking and mechanical pipe sticking.
2. Differential pressure pipe sticking occurs when part of the drillstring embeds in the mudcake on the formation wall. Mechanical pipe sticking can be caused by cuttings accumulation, borehole instability, or key seating.
3. Methods to prevent or mitigate stuck pipe include maintaining low fluid loss and drilled solids levels, using smooth mudcake systems, and rotating drillstring. Common techniques for freeing stuck pipe include reducing hydrostatic pressure, oil spotting, or increasing mud weight.
Hi,friend,
This presentation will give some effectiveness for entry level drilling engineers!
Thanks and Best regards,
Myo Min Htet
MPRL E&P Pte Ltd.
+95933336767
myominhtetz2012@gmail.com
The document discusses various drilling problems including pipe sticking, lost circulation, hole deviation, pipe failures, borehole instability, mud contamination, and formation damage. It provides details on the causes and indicators of each problem as well as methods for minimizing and addressing each issue when it occurs. Key problems covered are differential pipe sticking due to pressure differences embedding the pipe in the mud cake, mechanical sticking from cuttings accumulation, lost circulation from fractured or porous formations, and borehole instability from stresses or fluid interaction damaging the hole.
This document provides an overview of well control techniques. It discusses the importance of maintaining primary well control by keeping hydrostatic pressure greater than formation pressure. It describes what a kick is and types of kicks that can occur. Common causes of kicks include not keeping the hole full, insufficient mud density, swabbing, lost circulation, and poor well planning. Warning signs of a kick and methods for recognition are outlined. Finally, it discusses the objective of well control and some important well control concepts like determining reservoir pressure and selecting a well control method.
The document discusses different types of drill bits used in drilling operations, including drag bits and roller cutter bits. It describes the components and functioning of each type of bit. The document also covers drill bit classification systems used to categorize bits based on attributes like cutter type, profile, and intended formation. Drill bits are graded after use based on tooth wear, bearing wear, and gauge wear.
This document provides guidelines and best practices for preventing and resolving stuck pipe incidents. It discusses various sticking mechanisms including pack-offs caused by solids, unconsolidated formations collapsing into the wellbore, mobile formations being compressed, and fractured or faulted formations allowing debris to fall in. Preventative actions include maintaining proper mud weight, minimizing circulation time in risk zones, and using reamers when needed. The document provides response procedures to follow if pipe becomes stuck, such as reducing pump rates, applying torque and jarring to free the pipe. It also covers jar types, accelerator tools, and the communication needed for stuck pipe operations.
1) The document discusses different types of drill bits used in drilling operations including PDC, natural diamond, TSP, impregnated diamond, roller cone, tooth, and insert bits.
2) It explains the IADC classification system for drill bits which codes them based on factors like cutting structure, bearing type, and application in soft to hard formations.
3) The IADC dull grading code characterizes used drill bits according to wear characteristics like erosion, broken cutters, and reasons for being pulled such as being worn out.
Drilling operations can encounter various problems related to geological uncertainties, wellbore stability issues, and depletion effects. Some key risks include uncertainties in pore pressure-fracture gradient measurements, mud volcanoes causing landslides or weak formations, fault zones providing pathways for fluid flow, and maintaining wellbore integrity in low-pressure depleted zones. Operators address these challenges through careful planning, identifying potential hazard areas using seismic data, selecting appropriate drilling fluid properties, and employing wellbore strengthening techniques and lost circulation materials when needed to prevent fluid losses and wellbore collapse.
1. The document discusses different types of stuck pipe that can occur while drilling, including differential pressure pipe sticking and mechanical pipe sticking.
2. Differential pressure pipe sticking occurs when part of the drillstring embeds in the mudcake on the formation wall. Mechanical pipe sticking can be caused by cuttings accumulation, borehole instability, or key seating.
3. Methods to prevent or mitigate stuck pipe include maintaining low fluid loss and drilled solids levels, using smooth mudcake systems, and rotating drillstring. Common techniques for freeing stuck pipe include reducing hydrostatic pressure, oil spotting, or increasing mud weight.
Hi,friend,
This presentation will give some effectiveness for entry level drilling engineers!
Thanks and Best regards,
Myo Min Htet
MPRL E&P Pte Ltd.
+95933336767
myominhtetz2012@gmail.com
The document discusses various drilling problems including pipe sticking, lost circulation, hole deviation, pipe failures, borehole instability, mud contamination, and formation damage. It provides details on the causes and indicators of each problem as well as methods for minimizing and addressing each issue when it occurs. Key problems covered are differential pipe sticking due to pressure differences embedding the pipe in the mud cake, mechanical sticking from cuttings accumulation, lost circulation from fractured or porous formations, and borehole instability from stresses or fluid interaction damaging the hole.
This document provides an overview of well control techniques. It discusses the importance of maintaining primary well control by keeping hydrostatic pressure greater than formation pressure. It describes what a kick is and types of kicks that can occur. Common causes of kicks include not keeping the hole full, insufficient mud density, swabbing, lost circulation, and poor well planning. Warning signs of a kick and methods for recognition are outlined. Finally, it discusses the objective of well control and some important well control concepts like determining reservoir pressure and selecting a well control method.
The document discusses different types of drill bits used in drilling operations, including drag bits and roller cutter bits. It describes the components and functioning of each type of bit. The document also covers drill bit classification systems used to categorize bits based on attributes like cutter type, profile, and intended formation. Drill bits are graded after use based on tooth wear, bearing wear, and gauge wear.
1. Open-hole completions, also called 'barefoot' completions, involve setting casing above the productive interval and drilling into and through the reservoir, leaving it uncased and exposed to the wellbore.
2. For a simple open-hole well completion, the process involves setting production casing above the zone of interest before drilling into it, leaving it open to the wellbore, and then installing wellhead equipment to control flow.
3. Key steps include drilling into the formation, installing wellhead valves and pipes to direct and burn off initial flow, and cleaning the well until the flow stabilizes before testing and starting production.
This document discusses drilling optimization by considering drilling problems and their solutions. It begins by describing different types of stuck pipe situations including bridging, pack off, wellbore geometry issues, and differential sticking. It then examines indicators and prevention methods for several specific causes of stuck pipe like unconsolidated formations, cement blocks, junk, key seating, ledges, undergauge holes, and mobile formations like salt. The document also reviews rate of penetration factors, well control methods, kick causes, and provides a case study example for calculating differential force, buoyant weight, hook load, and margin of overpull to free a stuck pipe.
This document provides an overview of basic well control procedures including:
- Kick detection and control methods like primary prevention and secondary detection and control
- Shut-in procedures such as hard, soft, and specialized shut-ins
- Well kill procedures including calculating initial and final circulating pressures, the wait-and-weight/engineer's method, and providing an example pump schedule.
It describes the key objectives and considerations for safely controlling a well when kicks occur and bringing the well pressure to a controlled state.
The document discusses various drilling problems that can occur such as pipe sticking, loss of circulation, hole deviation, and more. It describes the causes and solutions for different types of pipe sticking problems including differential pressure sticking and mechanical sticking due to cuttings accumulation, borehole instability, or key seating. The document also covers loss of circulation issues and explains common lost circulation zones and causes. Planning and understanding potential problems is key to successfully reaching the target zone.
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.
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.
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 document discusses different types of drill bits used in drilling operations. It describes roller cone bits, which have three rotating cones with teeth. The design of roller cone bits is influenced by factors like the journal angle, cone offset, tooth shape and angle, and bearing design. The document also discusses insert bits, which use tungsten carbide inserts pressed into the cone, and PDC bits, which employ a layer of polycrystalline diamond. Standards for grading and classifying bits based on wear are also outlined.
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 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.
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.
This document discusses directional drilling techniques and their applications. It begins by defining directional drilling as deflecting a wellbore in a specified direction to reach a target below the surface. It then lists several applications of directional drilling including drilling multiple wells from a single location, drilling in inaccessible locations, avoiding geological problems, sidetracking, relief well drilling, and horizontal drilling. The document also discusses directional drilling applications in mining, construction, and geothermal engineering. It provides details on well profiles, azimuth and quadrants, horizontal well types, and directional drilling assemblies for building angle and holding angle.
The document discusses cement used in oil and gas wells. It covers cement composition, classes of cement, additives for controlling density, acceleration, retardation and viscosity. It also discusses cementing operations, equipment and performing a good cementing job. Key factors include casing centralization, pipe movement, drilling fluid viscosity, hole condition and achieving proper displacement velocity.
Directional drilling is the process of directing a wellbore along a non-vertical trajectory towards a predetermined target. It involves techniques like whipstocks, jet bits, and downhole motors to gradually build angle in the wellbore. There are three main types of directional well paths: Type I involves continuously building angle to a maximum and then holding; Type II involves building, holding, and dropping the angle; Type III only involves continuously building angle. Survey calculation methods like the average angle method are used to determine the wellbore position between survey points by calculating average inclination and azimuth angles.
This document discusses casing design and selection for oil and gas wells. It begins by explaining the functions of different casing strings, including conductor, surface, intermediate, production casing, and liners. Key factors in determining casing setting depths are discussed, such as mud weight profiles, formation pressures, and hole sizes. Common casing sizes and connections are also outlined. Proper casing design is important for well integrity and cost-effectiveness of the drilling project.
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.
Drilling Bit Introduction and bit Selection (Part 1)Amir Rafati
(PART 1,2 & 3)
1. Drilling mechanisms
2. Bit classifications (fixed cutter and roller cone bits)
3. IADC code descriptions
4. Tri-cone bits life time
5. Geometrical analysis of roller cone bits
• Fundamentals of bit design
• Basics of cone geometry design
• Oversize angle
• Offset
• Teeth and inserts
• Additional design criteria: tooth to tooth and groove clearances and etc.
• Cone-shell thickness
• Bearings factors
• Rock bit metallurgy
• Heat treatment
• Legs and cones material
• Tungsten carbide materials
• Legs and cones hard facing
• Tungsten carbide grade selection for inserts
• Bearings, seals and lubrication
• Bearing shape
• Bearing precisions and geometry
• Seal systems and seal details
• Dull grading system
6. Geometrical analysis of PDC bits
• PDC materials and constructions
• Matrix materials testing
• Differs between matrix & steel body
• Matrix body bits manufacturing
• Steel body bits manufacturing
• PDC bit design parameters: mechanical, hydraulic, rock properties
• Weld strength of PDC bits and cutters
• PDC cutter manufacturing process
• Tsp cutter properties vs PDC
• The influences of bit profile and profile elements
• PDC forces
• PDC bit stability
• PDC bit steer-ability
• Back rake
• Side rake
• Depth of cut
• Cutter exposure
• Cutter density
• Thermal damage and degradation of cutters
• Cutting mechanics
• PDC cutter substrate and its thickness
• Cutting structure elements
• Single set bladed cutting structures
• Plural set bladed cutting structures
• Dull grading system
7. ROP management based on drilling parameters
• WOB
• Rpm
• Sold content of mud
• Mud weight
• Cutter shape
• Cutters geometry
• Depth
• Abnormal pressure
• Drilling formation properties
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.
Casing Seat depth and Basic casing design lecture 4.pdfssuserfec9d8
1. The maximum gas kick pressure from the total depth as the internal pressure.
2. Formation pore pressure at the casing shoe as the external pressure.
3. The casing must be designed to withstand the difference between the maximum internal gas kick pressure and external pore pressure, known as the resultant pressure.
This document discusses the drilling fluid circulation system used in drilling operations. It describes the key components of the system including mud pumps, solids removal equipment, and treatment equipment. Mud pumps are typically positive displacement pumps, namely duplex or triplex pumps. The document provides details on how drilling fluid is pumped from the surface to the drill bit, circulates in the wellbore, and returns to the surface while removing cuttings.
Jarring is a process that transfers stored energy in the drill pipe into kinetic energy by releasing a delay mechanism in the jar. This provides a sudden impact. There are two main types of jars: hydraulic jars, which use hydraulic fluid to delay firing, and mechanical jars, which have a preset load to trigger them. Hydraulic jars provide a variable impact depending on applied load and time, while mechanical jars are sensitive only to load. Common jars used in drilling include hydraulic drilling jars, hydraulic/mechanical drilling jars, and power stroke hydraulic drilling jars.
The document provides tips for writing effective business emails, including making the recipient understand the purpose, taking action, and maintaining a connection. It recommends emails be short, simple, and specific; positive, active, and simple to encourage action; and include a subject line, introduction, main point, call to action, closing, and potentially questions. The document contrasts positive and negative language and provides examples of direct and indirect requests. It also discusses email structure and appropriate language for different parts of the email.
1. Open-hole completions, also called 'barefoot' completions, involve setting casing above the productive interval and drilling into and through the reservoir, leaving it uncased and exposed to the wellbore.
2. For a simple open-hole well completion, the process involves setting production casing above the zone of interest before drilling into it, leaving it open to the wellbore, and then installing wellhead equipment to control flow.
3. Key steps include drilling into the formation, installing wellhead valves and pipes to direct and burn off initial flow, and cleaning the well until the flow stabilizes before testing and starting production.
This document discusses drilling optimization by considering drilling problems and their solutions. It begins by describing different types of stuck pipe situations including bridging, pack off, wellbore geometry issues, and differential sticking. It then examines indicators and prevention methods for several specific causes of stuck pipe like unconsolidated formations, cement blocks, junk, key seating, ledges, undergauge holes, and mobile formations like salt. The document also reviews rate of penetration factors, well control methods, kick causes, and provides a case study example for calculating differential force, buoyant weight, hook load, and margin of overpull to free a stuck pipe.
This document provides an overview of basic well control procedures including:
- Kick detection and control methods like primary prevention and secondary detection and control
- Shut-in procedures such as hard, soft, and specialized shut-ins
- Well kill procedures including calculating initial and final circulating pressures, the wait-and-weight/engineer's method, and providing an example pump schedule.
It describes the key objectives and considerations for safely controlling a well when kicks occur and bringing the well pressure to a controlled state.
The document discusses various drilling problems that can occur such as pipe sticking, loss of circulation, hole deviation, and more. It describes the causes and solutions for different types of pipe sticking problems including differential pressure sticking and mechanical sticking due to cuttings accumulation, borehole instability, or key seating. The document also covers loss of circulation issues and explains common lost circulation zones and causes. Planning and understanding potential problems is key to successfully reaching the target zone.
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.
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.
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 document discusses different types of drill bits used in drilling operations. It describes roller cone bits, which have three rotating cones with teeth. The design of roller cone bits is influenced by factors like the journal angle, cone offset, tooth shape and angle, and bearing design. The document also discusses insert bits, which use tungsten carbide inserts pressed into the cone, and PDC bits, which employ a layer of polycrystalline diamond. Standards for grading and classifying bits based on wear are also outlined.
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 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.
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.
This document discusses directional drilling techniques and their applications. It begins by defining directional drilling as deflecting a wellbore in a specified direction to reach a target below the surface. It then lists several applications of directional drilling including drilling multiple wells from a single location, drilling in inaccessible locations, avoiding geological problems, sidetracking, relief well drilling, and horizontal drilling. The document also discusses directional drilling applications in mining, construction, and geothermal engineering. It provides details on well profiles, azimuth and quadrants, horizontal well types, and directional drilling assemblies for building angle and holding angle.
The document discusses cement used in oil and gas wells. It covers cement composition, classes of cement, additives for controlling density, acceleration, retardation and viscosity. It also discusses cementing operations, equipment and performing a good cementing job. Key factors include casing centralization, pipe movement, drilling fluid viscosity, hole condition and achieving proper displacement velocity.
Directional drilling is the process of directing a wellbore along a non-vertical trajectory towards a predetermined target. It involves techniques like whipstocks, jet bits, and downhole motors to gradually build angle in the wellbore. There are three main types of directional well paths: Type I involves continuously building angle to a maximum and then holding; Type II involves building, holding, and dropping the angle; Type III only involves continuously building angle. Survey calculation methods like the average angle method are used to determine the wellbore position between survey points by calculating average inclination and azimuth angles.
This document discusses casing design and selection for oil and gas wells. It begins by explaining the functions of different casing strings, including conductor, surface, intermediate, production casing, and liners. Key factors in determining casing setting depths are discussed, such as mud weight profiles, formation pressures, and hole sizes. Common casing sizes and connections are also outlined. Proper casing design is important for well integrity and cost-effectiveness of the drilling project.
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.
Drilling Bit Introduction and bit Selection (Part 1)Amir Rafati
(PART 1,2 & 3)
1. Drilling mechanisms
2. Bit classifications (fixed cutter and roller cone bits)
3. IADC code descriptions
4. Tri-cone bits life time
5. Geometrical analysis of roller cone bits
• Fundamentals of bit design
• Basics of cone geometry design
• Oversize angle
• Offset
• Teeth and inserts
• Additional design criteria: tooth to tooth and groove clearances and etc.
• Cone-shell thickness
• Bearings factors
• Rock bit metallurgy
• Heat treatment
• Legs and cones material
• Tungsten carbide materials
• Legs and cones hard facing
• Tungsten carbide grade selection for inserts
• Bearings, seals and lubrication
• Bearing shape
• Bearing precisions and geometry
• Seal systems and seal details
• Dull grading system
6. Geometrical analysis of PDC bits
• PDC materials and constructions
• Matrix materials testing
• Differs between matrix & steel body
• Matrix body bits manufacturing
• Steel body bits manufacturing
• PDC bit design parameters: mechanical, hydraulic, rock properties
• Weld strength of PDC bits and cutters
• PDC cutter manufacturing process
• Tsp cutter properties vs PDC
• The influences of bit profile and profile elements
• PDC forces
• PDC bit stability
• PDC bit steer-ability
• Back rake
• Side rake
• Depth of cut
• Cutter exposure
• Cutter density
• Thermal damage and degradation of cutters
• Cutting mechanics
• PDC cutter substrate and its thickness
• Cutting structure elements
• Single set bladed cutting structures
• Plural set bladed cutting structures
• Dull grading system
7. ROP management based on drilling parameters
• WOB
• Rpm
• Sold content of mud
• Mud weight
• Cutter shape
• Cutters geometry
• Depth
• Abnormal pressure
• Drilling formation properties
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.
Casing Seat depth and Basic casing design lecture 4.pdfssuserfec9d8
1. The maximum gas kick pressure from the total depth as the internal pressure.
2. Formation pore pressure at the casing shoe as the external pressure.
3. The casing must be designed to withstand the difference between the maximum internal gas kick pressure and external pore pressure, known as the resultant pressure.
This document discusses the drilling fluid circulation system used in drilling operations. It describes the key components of the system including mud pumps, solids removal equipment, and treatment equipment. Mud pumps are typically positive displacement pumps, namely duplex or triplex pumps. The document provides details on how drilling fluid is pumped from the surface to the drill bit, circulates in the wellbore, and returns to the surface while removing cuttings.
Jarring is a process that transfers stored energy in the drill pipe into kinetic energy by releasing a delay mechanism in the jar. This provides a sudden impact. There are two main types of jars: hydraulic jars, which use hydraulic fluid to delay firing, and mechanical jars, which have a preset load to trigger them. Hydraulic jars provide a variable impact depending on applied load and time, while mechanical jars are sensitive only to load. Common jars used in drilling include hydraulic drilling jars, hydraulic/mechanical drilling jars, and power stroke hydraulic drilling jars.
The document provides tips for writing effective business emails, including making the recipient understand the purpose, taking action, and maintaining a connection. It recommends emails be short, simple, and specific; positive, active, and simple to encourage action; and include a subject line, introduction, main point, call to action, closing, and potentially questions. The document contrasts positive and negative language and provides examples of direct and indirect requests. It also discusses email structure and appropriate language for different parts of the email.
ONGC is India's largest oil and gas company established in 1956 with a vision to be a world-class energy company. It has over 34,000 employees and revenue of $24 billion in 2008. To diversify risk away from its core upstream business and obsolete technology, ONGC acquired MRPL in 2002 and invested in downstream refining and retailing. It also expanded globally through acquisitions and grew production in India through new technology and financial restructuring.
Deconvolution and Interpretation of Well Test Data ‘Masked’ By Wellbore Stora...iosrjce
When a well test contains a series of different flow rates, or a continuously varying flow rate, the
combination of the pressure transients due to varying flow rate is called convolution. while deconvolution
means removing a distorting effect upon the variable of interest. This paper is on the study of an analytical
technique that can be used to explicitly deconvolve wellbore storage distorted well test data using pressure data
and the flow rate. Then to determine the reservoir properties from this deconvolved well test data by using the
conventional well test interpretation methods. Also the comparison of the material balance deconvolution
method results with the β-deconvlolution method result were carried out and then used to determine which
method was a better deconvolution tool. The results showed that the material balance deconvolution technique
performed very well with minor discrepancies and gave better estimation of the reservoir parameters.
This document provides a history and overview of ONGC (Oil and Natural Gas Corporation Ltd.) in India. It discusses ONGC's establishment before Indian independence in 1948 and key events through the 1990s when it was converted to a limited company. It outlines ONGC's corporate strategic goals to double reserves and recovery factors. The document also summarizes ONGC's corporate rejuvenation campaign involving restructuring and HR initiatives. It lists some of ONGC's mergers, acquisitions, and strategic alliances in the early 2000s. Finally, it provides a brief SWOT analysis of ONGC's strengths, weaknesses, opportunities, and threats.
Effective Communication Skills A Presentation by: Ms.Charu Agarwal Blog: learn2excel.blogspot.com
The presentation discusses effective communication skills and the communication process. It explains that communication involves conveying messages clearly from a sender to a receiver. The communication process involves a source encoding a message, sending it through a channel, the receiver decoding the message, and providing feedback. It also provides tips for improving communication skills such as developing voice, making eye contact, listening, and not jumping to conclusions.
financial analysis of ongc Final project sunilpatel188
The document provides information about Oil and Natural Gas Corporation Limited (ONGC), India's largest oil and gas exploration and production company. It discusses ONGC's history beginning in 1955, assets and operations, vision, mission, subsidiaries, and board of directors. Key points include that ONGC produces over 80% of India's oil and gas, operates assets across several basins and regions in India, and has expanded operations globally through subsidiaries like ONGC Videsh Limited.
The document discusses efficiency improvements at the Oil and Natural Gas Corporation's (ONGC) Uran plant in India. The Uran plant processes 50% of India's oil production through various units like gas stabilization, ethane/propane recovery, and LPG production. The study analyzes recovery factors for the LPG and EPRU units over time, finding a decline in the oldest LPG1 unit likely due to fouling heat exchangers. Recommendations include periodic maintenance, equipment replacements, and optimization of resources to increase production and profits. Replacing gas turbines with electric motors in LPG1 could save electricity costs and increase profits by over 23 crore rupees annually.
This document provides a summary of the history and operations of Oil and Natural Gas Corporation Limited (ONGC), India's largest oil and gas company. It discusses how ONGC was established in 1956 by the government of India to develop the country's oil and natural gas resources. It outlines ONGC's key discoveries and expansions from the 1960s onward, including major offshore finds. The document also provides background on ONGC's operations, locations, employees and facilities.
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The document provides guidelines for writing internship reports, including:
1. Internship reports allow students to practice organizing and presenting information to decision makers. They should include a clear problem definition, study details and outcomes, conclusions, and recommendations.
2. Reports should be based on an aspect of the internship organization and follow a standardized format including sections for objectives, essential elements, conclusions, and recommendations.
3. General guidelines specify the report length, formatting, and inclusion of sections like an introduction, discussion, and references. The report should be analytical rather than descriptive.
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The document provides tips for effectively learning English. It recommends taking an active approach to learning, such as writing journals in English, reading books and guessing meanings of unfamiliar words, rewriting class notes, watching English television and movies, and keeping a vocabulary notebook. It also stresses the importance of speaking English regularly with friends and maintaining a positive mindset to continue improving one's English skills over time.
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Torque and Drag: Concepts that Every Drilling and Completion Engineer Should ...pvisoftware
This white paper talks about torque and drag concepts that every drilling and completion engineer should know. With TADPRO, the risks associated with drilling and completing a well can be assessed and much of the risk can be remediated during pre-job planning.
How to develop an effective Business Development StrategyHein Roth
In this presentation, the visitor is introduced to the essentiality of developing a balanced Business Development Strategy for any business. Strong focus is given to the importance of having an effective Inbound Marketing Strategy, some Outbound Marketing Strategies, all with the aim to generate better leads and to drive more business through the front door of one's business. Attention is also given on how to convert leads into actual long-term business relationships.
The document outlines a business acceleration system from Alchemy that aims to help companies increase customers, sales, and profits. It does this through proven strategies and techniques to capture more market share by winning new customers and increasing loyalty. These include developing multiple marketing channels, implementing the "7 profit multipliers" to boost key metrics like leads, conversion rates, and average transaction value, and creating systems that allow the business to run profitably without constant oversight. The goal is to build a highly valuable business that can be sold or operated independently on "autopilot".
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This document provides guidance on writing a report to the principal. It discusses the purpose and format of such a report. The report is a formal account of an incident addressed to the principal to allow for investigation and action. The suggested format includes addressing the recipient, including the sender's name, subject and date. The report should be written in sections and past tense. It ends with a clear conclusion and inference. An example question is provided where a student would write a report to the principal on the lack of interest in sports among classmates and provide suggestions to address the problem.
This document discusses various drilling problems and solutions. It covers problem solving mechanics, the importance of teams, maintaining morale, and effective communication. Specific downhole problems covered include stuck pipe, shale instability, unconsolidated formations, fractured formations, cement blocks, soft cement, and junk in the hole. Actions to free stuck pipe and clean the wellbore are also described.
Drilling fluids, also called drilling muds, are circulated during rotary drilling operations to perform critical functions such as cooling the drill bit, removing drill cuttings from the wellbore, maintaining well pressure, and providing information to geologists. The key types of drilling fluids are water-based mud, oil-based mud, and air/foam. Drilling fluid properties like density, viscosity, gel strength, and filtration must be carefully controlled to prevent problems during drilling like blowouts, stuck pipe, and hole instability.
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This presentation is about wellbore control. It showcases the causes of well control situations, the types of well control and the calculations that should be made to appropriately control a wild well
This document provides an overview of well control procedures. It discusses causes of kicks such as swabbing or pumping light mud that can lead to underbalance. Primary well control relies on mud hydrostatic pressure, while secondary control uses a blowout preventer. Tertiary control involves pumping substances to stop downhole flow. Methods for killing a well are also presented, including the driller's method, wait and weight, volumetric, and bullheading. Kick detection equipment like the pit volume totalizer and flow indicator are also outlined.
In the process of drilling oil wells, we may face the problem of the blowout of oil wells because we do not control the exact time of the well. Therefore, in the above simplified report, it explains how to predict and properly shut-in the well to prevent blowout.
This document discusses two types of mechanical pipe sticking: from cuttings and borehole instability, and key seating. It also discusses differential pressure pipe sticking caused by a thick mud cake, excessive pipe length in the mud cake, high differential pressure, and low lubricity mud cake. To prevent pipe sticking, it recommends practices like aggressive rotation for cuttings removal, maintaining borehole stability, limiting key seating, using low fluid loss mud, and maintaining proper differential pressure. If stuck occurs, it notes mechanical, chemical, and hydrostatic methods can be used for release, including applying reverse circulation, changing mud properties, or nitrogen injection.
This document discusses well control methods used to maintain control of a well during drilling, completion, and workover operations. It defines a kick as unwanted fluid flow from the formation into the wellbore due to pressure differences, while a blowout is an uncontrolled release of formation fluids. Common causes of kicks include low density drilling fluid, abnormal formation pressures, swabbing, and lost circulation. Key well control concepts covered include hydrostatic pressure, formation pressure, fracture pressure, bottomhole pressure, equivalent circulating density, and swab and surge pressures. Warning signs of a kick and standard kick circulation procedures like shutting in the well and calculating kill mud weight are also summarized.
DRILLING RELATED DOWN HOLE PROBLEMS.pptxAMIRRAZA66
Uncover the complexities beneath the Earth's surface with our in-depth presentation on Downhole Problems in Engineering. This insightful slide explores the multifaceted challenges faced in drilling operations, covering topics such as wellbore stability, reservoir dynamics, and advanced drilling technologies. Navigate through the intricacies of subsurface engineering and discover innovative strategies to overcome downhole obstacles. Elevate your understanding of the fascinating intersection between technology, geology, and engineering in the realm of drilling.
The document provides details about a team project to design and manufacture a stuffing box assembly. It includes:
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2) Descriptions of the purpose of a stuffing box to prevent leakage around a rotating shaft while allowing movement, and typical materials used like cast iron for the body and asbestos for packing.
3) An overview of the manufacturing processes used including green sand casting, machining operations like drilling and threading, and potential defects from casting like blowholes and porosity.
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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.
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Primary cementing involves placing cement between the casing and borehole to isolate zones and support the casing. It involves running casing, circulating mud, pressure testing, pumping wash/spacer, mixing and pumping cement slurry, and displacing with fluid. Secondary cementing, like squeeze cementing, is used to repair improper zonal isolation, eliminate water intrusion, or repair casing leaks by pumping cement through perforations or casing leaks. It can be done with low or high pressure placement using techniques like running squeeze or hesitation squeeze to fill perforations or fractures.
The fifth presentation of a series of presentations on Operations Geology. Very basic, just to introduce beginners to operations geology. I hope the end users will find this and the following presentations very helpful.
Drilling hazards dependent on mud control masoomMasoom Shani
This document summarizes common drilling hazards and how to overcome them through proper mud control. It discusses salt section hole enlargement which can be prevented using a salt saturated mud system. Heaving shale problems from hydrating clays can be addressed by changing the mud system properties or composition. Blowouts occur when formation pressure exceeds mud pressure and can be controlled by maintaining proper mud weight and using a blowout preventer. Lost circulation happens when mud is lost to formations and can be prevented or cured by circulating lost circulation materials in the mud.
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2. Cornish Rex cats have a unique coat with only down hair, making them soft. They are playful, active cats good for families with kids.
3. Sphynx cats are hairless with blue eyes and sweet personalities. They need weekly baths and to stay warm as they can't regulate temperature well.
4. LaPerm cats have curly coats from a spontaneous genetic mutation. They are friendly, calm cats that may be good for people with allergies.
5. Scottish Fold
Dutch law now requires covered markets for hygiene. Rotterdam's Markthal market has been redeveloped under a huge arched structure to comply. The arch houses 228 apartments above a 120m long market hall with stalls, restaurants, and 1200 parking spaces below a mural depicting produce.
The document discusses the benefits of exercise for mental health. Regular physical activity can help reduce anxiety and depression and improve mood and cognitive functioning. Exercise has also been shown to boost self-esteem and can serve as a healthy way to manage stress.
Giant virus resurrected from 30,000 year-old iceMohan Doshi
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The document provides guidance on troubleshooting issues that may arise while drilling and maintaining the drilling fluid system. It discusses four key properties (density, viscosity, gel strength, filtration) that must be adequately monitored and controlled. Issues covered include contamination, abnormal pressure, lost circulation, fluid characteristics like high viscosity or fluid loss. For each problem, the summary lists typical symptoms and recommends solutions such as changing the mud weight or viscosity, adding lost circulation materials, or using solids control equipment.
Savannah cats were bred starting in the 1990s by crossing domestic cats with African serval cats. They became popular among breeders and pet owners in the late 1990s. Savannah cats are considered very loyal pets and are the largest domesticated cat breed due to their slim bodies that allow them to weigh between 3-10 kg while still looking large compared to other cats. There are different types of Savannah cats based on their genetic ratios from breeding.
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GUIDELINES FOR EFFECTIVE HOLE CLEANING IN DIRECTIONAL WELLSMohan Doshi
This document provides guidelines for effective hole cleaning when drilling wells. It discusses that hole cleaning, which is removing drilled material from the borehole, is an important but often overlooked part of the drilling process. For high angle and deviated wells, cuttings follow a complex path down the hole and can accumulate on the low side of the borehole if not properly removed. The key factors that influence effective hole cleaning are discussed, including maintaining adequate flow rates and annular velocities, optimizing drilling fluid properties, and using drill pipe rotation to help move cuttings. High density sweeps are also recommended to help clean cuttings from deviated wellbores.
Software Engineering and Project Management - Introduction, Modeling Concepts...Prakhyath Rai
Introduction, Modeling Concepts and Class Modeling: What is Object orientation? What is OO development? OO Themes; Evidence for usefulness of OO development; OO modeling history. Modeling
as Design technique: Modeling, abstraction, The Three models. Class Modeling: Object and Class Concept, Link and associations concepts, Generalization and Inheritance, A sample class model, Navigation of class models, and UML diagrams
Building the Analysis Models: Requirement Analysis, Analysis Model Approaches, Data modeling Concepts, Object Oriented Analysis, Scenario-Based Modeling, Flow-Oriented Modeling, class Based Modeling, Creating a Behavioral Model.
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An improved modulation technique suitable for a three level flying capacitor ...IJECEIAES
This research paper introduces an innovative modulation technique for controlling a 3-level flying capacitor multilevel inverter (FCMLI), aiming to streamline the modulation process in contrast to conventional methods. The proposed
simplified modulation technique paves the way for more straightforward and
efficient control of multilevel inverters, enabling their widespread adoption and
integration into modern power electronic systems. Through the amalgamation of
sinusoidal pulse width modulation (SPWM) with a high-frequency square wave
pulse, this controlling technique attains energy equilibrium across the coupling
capacitor. The modulation scheme incorporates a simplified switching pattern
and a decreased count of voltage references, thereby simplifying the control
algorithm.
Applications of artificial Intelligence in Mechanical Engineering.pdfAtif Razi
Historically, mechanical engineering has relied heavily on human expertise and empirical methods to solve complex problems. With the introduction of computer-aided design (CAD) and finite element analysis (FEA), the field took its first steps towards digitization. These tools allowed engineers to simulate and analyze mechanical systems with greater accuracy and efficiency. However, the sheer volume of data generated by modern engineering systems and the increasing complexity of these systems have necessitated more advanced analytical tools, paving the way for AI.
AI offers the capability to process vast amounts of data, identify patterns, and make predictions with a level of speed and accuracy unattainable by traditional methods. This has profound implications for mechanical engineering, enabling more efficient design processes, predictive maintenance strategies, and optimized manufacturing operations. AI-driven tools can learn from historical data, adapt to new information, and continuously improve their performance, making them invaluable in tackling the multifaceted challenges of modern mechanical engineering.
Use PyCharm for remote debugging of WSL on a Windo cf5c162d672e4e58b4dde5d797...shadow0702a
This document serves as a comprehensive step-by-step guide on how to effectively use PyCharm for remote debugging of the Windows Subsystem for Linux (WSL) on a local Windows machine. It meticulously outlines several critical steps in the process, starting with the crucial task of enabling permissions, followed by the installation and configuration of WSL.
The guide then proceeds to explain how to set up the SSH service within the WSL environment, an integral part of the process. Alongside this, it also provides detailed instructions on how to modify the inbound rules of the Windows firewall to facilitate the process, ensuring that there are no connectivity issues that could potentially hinder the debugging process.
The document further emphasizes on the importance of checking the connection between the Windows and WSL environments, providing instructions on how to ensure that the connection is optimal and ready for remote debugging.
It also offers an in-depth guide on how to configure the WSL interpreter and files within the PyCharm environment. This is essential for ensuring that the debugging process is set up correctly and that the program can be run effectively within the WSL terminal.
Additionally, the document provides guidance on how to set up breakpoints for debugging, a fundamental aspect of the debugging process which allows the developer to stop the execution of their code at certain points and inspect their program at those stages.
Finally, the document concludes by providing a link to a reference blog. This blog offers additional information and guidance on configuring the remote Python interpreter in PyCharm, providing the reader with a well-rounded understanding of the process.
Redefining brain tumor segmentation: a cutting-edge convolutional neural netw...IJECEIAES
Medical image analysis has witnessed significant advancements with deep learning techniques. In the domain of brain tumor segmentation, the ability to
precisely delineate tumor boundaries from magnetic resonance imaging (MRI)
scans holds profound implications for diagnosis. This study presents an ensemble convolutional neural network (CNN) with transfer learning, integrating
the state-of-the-art Deeplabv3+ architecture with the ResNet18 backbone. The
model is rigorously trained and evaluated, exhibiting remarkable performance
metrics, including an impressive global accuracy of 99.286%, a high-class accuracy of 82.191%, a mean intersection over union (IoU) of 79.900%, a weighted
IoU of 98.620%, and a Boundary F1 (BF) score of 83.303%. Notably, a detailed comparative analysis with existing methods showcases the superiority of
our proposed model. These findings underscore the model’s competence in precise brain tumor localization, underscoring its potential to revolutionize medical
image analysis and enhance healthcare outcomes. This research paves the way
for future exploration and optimization of advanced CNN models in medical
imaging, emphasizing addressing false positives and resource efficiency.
1. STUCK PIPE – PACKING AND BRIDGING
There are 3 categories of stuck pipe.
1. PACKING OFF AND BRIDGING: There are seven cases in this
category.
1.1 CUTTING SETTLING
1.1.1 Cutting settling in near well bore wells and
1.1.2 Cutting setting in deviated wells
1.2 Shale instability
1.3 Unconsolidated formations
1.4. Fractured formations
1.5. Soft cement
1.6. Cement Blocks
1.7. Junk
2. DIFFERENTIAL STICKING: There is only one case in this category.
3. WELLBORE GEOMETRY: There are eleven cases in this category.
1. Stiff bottom hole assembly
2. Key seat
3. Micro doglegs
4. Ledges
5. Mobile formations
6. Undergauge hole
7. Hydro-Pressured Shale
8. Geo-Pressured Shale
9. Overburden Stress
10. Tectonic Stress
11. Unconsolidated Formation
2. 1. PACKING OFF AND BRIDGING
1.1 CUTTING SETTLING
1.1.1 CUTTING SETTLING IN A VERTICAL OR NEAR
VERTICAL WELLBORE CAUSES STUCK PIPE
Cutting settling in vertical or near vertical wellbore – typically the wells classified as
vertical or near vertical wells has inclination less than 35 degree.
How does it happen?
Cuttings in the wellbore are not removed from the annulus enough because there is not
enough cutting slip velocity in and/or drilling mud properties in the wellbore is bad.
When pumps are off, cuttings fall down due to gravitational force and pack and
annulus. Finally, it results in stuck pipe.
Note: In order to clean annulus effectively, the annular velocity must be more than
cutting slip velocity in dynamic condition. Moreover, mud properties must be able to
carry cutting when pumps on and suspend cutting when pumps off.
Warning signs of cutting setting in vertical well
There are increase in torque /drag and pump pressure.
You may see over pull when picking up and pump pressure required
to break circulating is higher without any parameters changes.
Indications when you are stuck due to cutting bed in vertical well
When this stuck pipe caused by cutting settling is happened,
circulation is restricted and sometimes impossible. It most likely
happens when pump off (making connection) or tripping in/out of
hole.
What should you do for this situation?
Attempt to circulate with low pressure (300-400 psi). Do not use high
pump pressure because the annulus will be packed harder and you
will not be able to free the pipe anymore.
Apply maximum allowable torque and jar down with maximum trip
load. Do not try to jar up because you will create worse situation.
3. Attempt until the pipe is free, then circulate and work pipe until the
wellbore is clean. Check cutting at shale shakers, torque/drag and
pump pressure in order to ensure hole condition.
FIG 1. PACKING OFF AND BRIDGING
Preventive actions
1. Ensure that annular velocity is more than cutting slip velocity. You can
learn more about cutting slip velocity calculation via these links:
a. Cutting Slip Velocity Calculation Method 1,
b. Cutting Slip Velocity Calculation Method 2)
2. Ensure that mud properties are in good shape.
3. Consider pump hi-vis pill. You may try weighted or unweighted and
see which one gives you the best cutting removal capability.
4. 4. If you pump sweep, ensure that sweep must be return to surface
before making any connection. For a good drilling practice, you should
not have more than one pill in the wellbore.
5. Circulate hole clean prior to tripping out of hole. Ensure that you have
good reciprocation while circulating.
6. Circulate 5-10 minutes before making another connection in order to
clear cutting around BHA.
7. Record drilling parameters and observe trend changes frequently.
8. Optimize ROP and hole cleaning.
1.1.2 CUTTING SETTLING IN DEVIATED WELLS CAUSE
STUCK PIPE
Cutting settling in deviated wells – typically a well which has inclination more than 35
degree is classified as a deviated well.
How does it happen?
For the deviated wells, cuttings tend to set at the low side of the
wellbore and form a cutting bed.
When there is a lot of cutting in the bed, it will slide down and pack
the string. Moreover, while pulling out of hole, BHA will move some
cutting bed and finally the cutting bed will pack BHA and drill string
(stuck pipe).
Warning signs of cutting setting in deviated wells
Drilling with high angle well (more than 35 degree).
While drilling with a mud motor, cutting cannot be effectively
removed due to no pipe rotation.
Increase in torque and drag (you must have a trend to see if
torque/drag is abnormal)
Increase in pump pressure without changing any mud properties.
5. Indications when you are stuck due to cutting bed in deviated wells
The stuck pipe can happen while drilling and tripping out of hole.
Most of the time, it will happen while POOH.
Increase in torque and drag while drilling.
Increase in drag while tripping out.
Circulation pressure is higher than normal. Sometimes, it is impossible
to circulate.
What should you do for this situation?
Attempt to circulate with low pressure (300-400 psi). Do not use high
pump pressure because the annulus will be packed harder and you
will not be able to free the pipe anymore.
Apply maximum allowable torque and jar down with maximum trip
load. Do not try to jar up because you will create worse situate.
Be patient, and attempt until the pipe is free, then circulate and work
pipe until the wellbore is clean. Do not continue operation until the
6. hole is properly clean. Check cutting at shale shakers, torque/drag and
pump pressure in order to ensure hole condition.
Preventive actions:
1. Ensure that annular velocity is more than cutting slip velocity.
2. Ensure that mud properties are in good shape.
3. Consider pump hi-vis pill. You may try weighted or unweighted and
see which one gives you the best cutting removal capability.
4. If you pump sweep, ensure that sweep must be return to surface
before making any connection. For a good drilling practice, you
should not have more than one pill in the wellbore.
5. Circulate hole clean prior to tripping out of hole. Ensure that you have
good reciprocation while circulating.
6. Circulate 5-10 minutes before making another connection in order to
clear cutting around BHA.
7. Record drilling parameters and observe trend changes frequently.
8. Optimize ROP and hole cleaning.
1.2 STUCK PIPE DUE TO SHALE INSTABILITY
Shale instability occurs when the shale formations become unstable and finally
formations break apart and fall into an annulus.
Water in the mud absorbed by shale formations causes swelling effect on formations.
When there is a lot of water, shales will not be able to hold their particles together and
finally fall apart into the well. Finally shale particles will jam the drill string.
The shale instability is a chemical reaction which is time dependent. It means that you
may not see it on day one, you may see it after you have been drilling for days.
The three figures below will help you get more understanding about shale instability
and stuck pipe.
Warning signs of shale instability
Torque and drag increase. An over pull may be observed.
7. Mud properties became worse. You will see an increase in plastic
viscosity, yield point (drilling mud becomes thicker).
Pump pressure increases.
Soft shale over shale shakers.
Indications when you stuck due to shale instability
When it happens, you may observe very high pump pressure at small
rate and sometimes circulation may be impossible.
Most of the time it will happen when pulling out of hole. However, it
can be possibly occur while drilling as well.
What should you do for this situation?
1. Attempt to circulate with low pressure (300-400 psi). Do not use high
pump pressure because the annulus will be packed harder and you
will not be able to free the pipe anymore.
2. If you are drilling or POOH, apply maximum allowable torque and jar
down with maximum trip load.
3. If you are tripping in hole, jar up with maximum trip load without
applying any torque.
4. Attempt until pipe free and circulate to clean wellbore.
Preventive actions
1. For water based mud – you may need to add some salts that
compatible with a mud formula in order to reduce chemical reaction
between water and shale. Moreover, you should consider adding some
coating polymers to prevent water contact with formation.
2. Use oil based mud instead of water based mud because oil will not
react with shale.
3. Keep good flow rate to ensure good hole cleaning.
4. Perform back reaming and/or wiper trip.
5. Keep good mud properties.
9. FIG 3.3 SWELLED FORMATION FALLS APART AND PACKS OFF THE
ANNULUS RESULTING IN STUCK PIPE
1.3 UNCONSOLIDATED FORMATION CAUSES STUCK PIPE
The situation could happen when drilling into unconsolidated formations such as
gravel, sand, peat, etc. Since bond between particles are weak, particles in the
formations will separate and fall down hole. If there are a lot of unconsolidated particles
in the annulus, the drilling string can possibly be packed off and stuck.
Warning signs when you get stuck due to unconsolidated formation
This situation could happen either while drilling or tripping. There is
more chance that the situation can happen while drilling.
Slight loss may possibly be seen while drilling.
Drilling torque and pump pressure abnormally increase.
Abnormal drag can be observed while picking up pipe.
Indications when you are stuck due to unconsolidated formation
Observe a lot of particles of gravel, sand, pea over shale shakers.
Increase in mud weight, rheology and sand content in drilling mud.
10. When it happens, the annulus may be completely packed off or
bridged off; therefore, circulation is very difficult or impossible to
establish.
Most of the time this situation happens while drilling a surface section
where formation bonding is not strong. Moreover, it can occur
suddenly.
What should you do for this situation?
1. Attempt to circulate with low pressure (300-400 psi). Higher pump rate
is not recommended because it will cause more cutting accumulation
around a drill string and your drillstring will become harder to get
free.
2. If you are drilling or POOH, apply maximum allowable torque and jar
down with maximum trip load.
3. If you are tripping in hole, jar up with maximum trip load without
applying any torque.
4. When the pipe is free, circulate to clean wellbore prior to drilling
ahead.
FIG 4 - STUCK PIPE DUE TO UNCONSOLIDATED FORMATIONS
11. Preventive actions:
1. Use high vis/weight sweep to help hole cleaning.
2. Ensure that fluid loss of drilling mud is not out of specification. Good
fluid loss will create good mud cake which can help seal the
unbounded formation.
3. Control ROP while drilling into unconsolidated zones and take time to
clean the wellbore if necessary.
4. Slow tripping speed when BHA is being passed unconsolidated zones
to minimize formation falling down.
5. Minimize surge pressure by starting/stopping pumps slowly and
working string slowly.
6. Spot gel across suspected formations prior to tripping out of hole. Gel
could prevent some particles to fall down into the wellbore.
1.4 FRACTURED FORMATION CAUSES STUCK PIPE
While drilling into naturally fractured formations, pieces of formations fall down in the
annulus and cause the drill string to get stuck.
Warning signs when you get stuck due to Fractured Formation
Drilling into potential naturally fractured zones as limestone, sand
stone, carbonate, etc
Big caving observed on shale shakers while drilling
Observed volume to fill the hole is more than normal hole size
Stuck identification for Fractured Formation
This situation can occur during drilling or tripping.
Torque and drag are suddenly changed and tend to be erratic while
drilling.
Over pull off slip is noticed.
Circulation could be restricted (you may get or not get good
circulation)
12. FIG 5 - STUCK PIPE DUE TO NATURALLY FRACTURED FORMATION
What should you do for this situation?
Stuck while moving up, jar down with maximum allowable trip load
without applying any torque!!!
Stuck while moving down, jar up without apply torque
Pump weighted hi-vis sweep with maximum allowable flow rate
Preventive actions:
Keep mud in good shape. Good and thin mud cake, with good
bridging particles can support fractured formation in some cases.
If the suspected zones are drilled, you should take time to circulate
hole clean before making head way.
Start and stop circulation slowly to minimize surge pressure.
Work pipe with restricted speed to prevent surging formations.
13. Tripping speed should be slow while BHA is being run into suspected
zones.
The fractured formations require time to get stabilized.
1.5 SOFT CEMENT CAUSES STUCK PIPE
The drillstring/BHA is in soft cement and when circulation is established, pumping
pressure causes the soft cement to flash set (cement becomes hard quickly). Finally the
drill string gets stuck due to hard cement around it.
Warning signs when you get stuck due to Cement Blocks
Run in hole after the open hole cement job as cement balanced plug is
completed.
Unable to see firm cement while attempting to find the theoretical top
of cement. It indicates that you may be in the soft cement.
Stuck identification for Soft Cement
It happens when pump pressure is brought up and pump pressure
increases quickly.
Rotary torque suddenly increases.
When the soft cement is flash set, you may not be able to get
circulation or get low circulation at very high pump pressure.
What should you do for this situation?
First of all, before jarring operation, you must bleed off trapped
pressure in the string.
Apply jar with maximum trip load. Jar at the opposite direction of
string movement. For example, if you are stuck while moving up, you
need to jar down. On the other hand, you need to jar up, if you are
stuck while moving down.
Preventive actions:
Ensure that cement is properly set prior to tripping to top of cement.
14. Stop at least 100 ft above the calculated top of cement and establish
circulation prior to tag top of cement.
Tag cement slow with pump on.
Don’t clean out cement too fast. Attempt to control drill and check pick
up/slack off weight and torque frequently while drilling out cement.
FIG 6 – STUCK PIPE DUE TO FLASH SETTING OF CEMENT
1.7 Cement Blocks Causes Stuck Pipe
Cement around casing shoe or open hole cement squeeze becomes unstable and finally
chunks of cement fall into a wellbore. If there are a lot of cement chunks in the annulus,
drilling string will be stuck.
Warning signs when you get stuck due to Cement Blocks
Rat hole is too long.
Drilling in to areas where open hole cement jobs as cement squeeze or
kick off plug were performed.
15. FIG 7 – STUCK PIPE DUE TO CEMENT BLOCKS
Stuck identification for Cement Blocks
Cement chunks are seen at shale shakers.
There is cement content in mud logger samples.
Stuck pipe due to cement blocks can occur anytime.
Circulation is not restricted.
Torque and drag are drastically increased and erratic.
What should you do for this situation?
Stuck while moving up, jar down with maximum allowable trip load.
Gradually apply torque if required.
16. Stuck while moving down, jar up without applying torque.
Pump weighted hi-vis sweep with maximum allowable flow rate to
clean large pieces of cement around drilling string/BHA.
Preventive actions:
Do not leave a long rat hole.
Ream with circulation through casing shoe and areas where there is
open hole cement.
Attempt to clean cement in the annulus prior to drilling.
Wait for cement setting long enough before drilling ahead.
Minimize tripping speed when BHA passes through casing shoe or
cement plug/cement squeeze depth.
1.7 JUNK CAUSES STUCK PIPE
Junk from the surface drops into the wellbore casing stuck pipe. It could be happened
due to several factors as poor housekeeping on the rig floor, rotary table not covered,
surface/down hole equipment failure.
Warning signs when you get stuck due to junk
Observe equipment on surface falling downhole
If down hole equipment failure, the drill string gets jammed suddenly
without any sings.
Stuck pipe by the junk can occur any time.
Suspicious substance as metal, wood, rubber may be found at the shale
shaker.
Stuck identification for Junk
Torque suddenly becomes erratic.
Drag increases
Equipment on the rig floor falls down hole.
17. FIG 8. STUCK PIPE DUE TO JUNK IN THE HOLE
What should you do for this situation?
If you get stuck while moving up, jar down with maximum trip load.
Torque may be applied with caution.
If you get stuck while moving down, jar up without any toque applied
in the drill string.
Preventive actions:
Maintain good housekeeping on the rig floor
Ensure that hole cover is used all the time when work on rotary table.
Maintain tool used on the rig floor in a good condition.