A summary presentation of a 7" Liner job, demonstrating different components, mechanisms of liner hanger and other string components. Then a quick hint about cementing operation and some extra components involved in the job like the Handling equipment, VAM HT, ...etc.
Packers are tools used to form an annular seal between concentric strings of pipe or between pipe and the open hole. They isolate production zones from each other or from the annulus. Packers have slips, cones, seals, and mandrels that allow them to be set through hydraulic or mechanical means. Selection depends on application, required ratings, and setting method. Proper installation requires a clean set point without fouling components. Packers come in a variety of types including retrievable, permanent, seal bore, inflatable, and service packers.
Although there are many types and brand name of liner hanger system, basic of the equipment and operations are same. After get trained from different service provider and conducting many kind of liner hanger operation I was assigned to teach fundamental of liner system to the related engineers within the company.
Linked presentation is from the training session and shares the fundamental knowledge of liner hanger system for interested people.
The document discusses coiled tubing equipment used in well intervention operations. It describes the key components of a coiled tubing unit including the reel, injector head, power pack, control cabin and blowout preventers. It provides details on the functions of each piece of equipment and discusses considerations for coiled tubing operations like stresses on the tubing and barrier principles. The document is an in-depth overview of the surface equipment used to safely convey coiled tubing into a well.
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.
WellCare Oil Tools Pvt. Ltd., prides itself on offering great service and being able to deliver accurate formal quotes to clients within 72 hours of receiving an enquiry.
We keep a large inventory of standard flow control tools and completion packers in stock, enabling quick delivery anywhere in the world. We ensure high quality and traceability, full certification including Mill Test Reports (MTR's), certificate of Conformance, Certificate of Origin, Function Test and Pressure Test Results are available free of charge upon request for each order and are kept on file and available on request at any time in the future.
Premium thread connections like: Tenaris-Hydril, Vam and Hunting connections are available upon request and threads are cut by premium licenced machine shops in Dubai & Singapore.
Special elastomer are available: AFLAS, HNBR, Viton and HSN, Hi-Nitrile are available along with non-elastomeric seal stacks to confirm to sour well conditions.
Category Products :
Cementation Systems
Cementing Equipment
Completion Systems
Mechanical Set Packer
Seal Bore Packer
Bridge Plugs
Hydraulic Set Packer
Cement Retainer
Completion Equipment
Liner Hanger Systems
Liner Hanger
Flow Control Systems
Sliding Sleeve
Landing Nipples
Flow Control Equipment
Inflatable Packers
Inflatable Packer
Various other factors that have enabled us to gain an edge over our competitors are:
Qualitative product range
World renowned vendor base
Experienced professionals
Efficient logistics and widespread distribution network
Industry leading prices
Timely delivery
--
With Best Regards
Surender Yadav ( Marketing Manager)
Cell: +91 8696934503
For WellCare Oil Tools Private Limited, India.
This document discusses well intervention using coiled tubing. It defines coiled tubing and its main components, which include an injector head, coiled tubing reel, control unit, power pack unit, and bottom-hole assembly. Coiled tubing can be used for various applications like wellbore cleanout, milling, logging, perforating, drilling deviated wells, fluid conveyance, and tool conveyance. It has advantages over conventional drilling like not requiring connections and allowing faster tripping in and out. However, coiled tubing also has disadvantages like fatigue life limits and reduced bore diameter.
This document discusses well intervention techniques using coiled tubing. It describes coiled tubing as continuously-milled tubular product that is straightened before insertion into the wellbore. The main types of well intervention discussed are pumping, slickline, snubbing, workover, and coiled tubing. It provides details on the components and functions of a coiled tubing unit, including the reel, injector head, control cabin, power pack, blowout preventer, stripper, and bottom hole assembly.
Packers are tools used to form an annular seal between concentric strings of pipe or between pipe and the open hole. They isolate production zones from each other or from the annulus. Packers have slips, cones, seals, and mandrels that allow them to be set through hydraulic or mechanical means. Selection depends on application, required ratings, and setting method. Proper installation requires a clean set point without fouling components. Packers come in a variety of types including retrievable, permanent, seal bore, inflatable, and service packers.
Although there are many types and brand name of liner hanger system, basic of the equipment and operations are same. After get trained from different service provider and conducting many kind of liner hanger operation I was assigned to teach fundamental of liner system to the related engineers within the company.
Linked presentation is from the training session and shares the fundamental knowledge of liner hanger system for interested people.
The document discusses coiled tubing equipment used in well intervention operations. It describes the key components of a coiled tubing unit including the reel, injector head, power pack, control cabin and blowout preventers. It provides details on the functions of each piece of equipment and discusses considerations for coiled tubing operations like stresses on the tubing and barrier principles. The document is an in-depth overview of the surface equipment used to safely convey coiled tubing into a well.
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.
WellCare Oil Tools Pvt. Ltd., prides itself on offering great service and being able to deliver accurate formal quotes to clients within 72 hours of receiving an enquiry.
We keep a large inventory of standard flow control tools and completion packers in stock, enabling quick delivery anywhere in the world. We ensure high quality and traceability, full certification including Mill Test Reports (MTR's), certificate of Conformance, Certificate of Origin, Function Test and Pressure Test Results are available free of charge upon request for each order and are kept on file and available on request at any time in the future.
Premium thread connections like: Tenaris-Hydril, Vam and Hunting connections are available upon request and threads are cut by premium licenced machine shops in Dubai & Singapore.
Special elastomer are available: AFLAS, HNBR, Viton and HSN, Hi-Nitrile are available along with non-elastomeric seal stacks to confirm to sour well conditions.
Category Products :
Cementation Systems
Cementing Equipment
Completion Systems
Mechanical Set Packer
Seal Bore Packer
Bridge Plugs
Hydraulic Set Packer
Cement Retainer
Completion Equipment
Liner Hanger Systems
Liner Hanger
Flow Control Systems
Sliding Sleeve
Landing Nipples
Flow Control Equipment
Inflatable Packers
Inflatable Packer
Various other factors that have enabled us to gain an edge over our competitors are:
Qualitative product range
World renowned vendor base
Experienced professionals
Efficient logistics and widespread distribution network
Industry leading prices
Timely delivery
--
With Best Regards
Surender Yadav ( Marketing Manager)
Cell: +91 8696934503
For WellCare Oil Tools Private Limited, India.
This document discusses well intervention using coiled tubing. It defines coiled tubing and its main components, which include an injector head, coiled tubing reel, control unit, power pack unit, and bottom-hole assembly. Coiled tubing can be used for various applications like wellbore cleanout, milling, logging, perforating, drilling deviated wells, fluid conveyance, and tool conveyance. It has advantages over conventional drilling like not requiring connections and allowing faster tripping in and out. However, coiled tubing also has disadvantages like fatigue life limits and reduced bore diameter.
This document discusses well intervention techniques using coiled tubing. It describes coiled tubing as continuously-milled tubular product that is straightened before insertion into the wellbore. The main types of well intervention discussed are pumping, slickline, snubbing, workover, and coiled tubing. It provides details on the components and functions of a coiled tubing unit, including the reel, injector head, control cabin, power pack, blowout preventer, stripper, and bottom hole assembly.
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.
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 production packers, which are subsurface tools used to provide a seal between casing and tubing. Production packers serve several purposes, such as protecting casing from corrosion, providing better well control, preventing fluid movement between zones, and isolating zones of bad cement. The key components of a production packer include slips, packing elements, and a cone. Production packers can be classified as permanent or retrievable and can be set mechanically, hydraulically, or electrically. Common types of production packers include sump packers, single-bore packers, dual-bore packers, and ESP packers.
A Brief Introduction to Coiled Tubing: What is it? What to do with it?, pumps...tmhsweb
This document provides an overview of coiled tubing, including its history, equipment, and applications. It discusses how coiled tubing originated from military projects during World War II and was first used in the oilfield in 1962. The key components of a coiled tubing unit are described, including the injector, reel, control house, and other equipment. Common applications of coiled tubing in the oil and gas industry involve well intervention operations such as drilling, logging, perforating, and more. A comparison is made between addressing blockages in wells and arteries.
1. sequance of well drilling and completion part 1Elsayed Amer
The document outlines the steps for well drilling and site preparation. It describes leveling the site, digging a cellar and mud pits, hammering a conductor pipe, drilling a rathole, and transporting equipment to the site. Subsequent steps include rig setup, inspection and preparation of drill pipes and drill string, mixing and pumping spud mud, drilling initial sections, cleaning the hole, running and cementing surface casing.
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.
WELL COMPLETION, WELL INTERVENTION/ STIMULATION, AND WORKOVERAndi Anriansyah
This document discusses various well completion, intervention, and workover topics including:
- Well completion involves preparing the well for production by installing equipment like casing and tubing.
- Open hole and cased hole completions are described, along with advantages and disadvantages of each.
- Well intervention operations like scale removal, acidizing, and sand cleaning are performed during production.
- Formation damage from fluids introduced into the well is also discussed.
- Stimulation techniques like acidizing and hydraulic fracturing aim to increase well productivity. The document outlines the processes, equipment, and evaluation of these operations.
- Other topics covered include intelligent well completions, perforating, sand control, squeeze cement
This document discusses various techniques for removing permanent packers and retrievable packers that require more than straight pulls. It describes reasons for removal such as leaks and access to lower zones. Rig-based and coiled tubing removal methods are covered. Specific techniques discussed include milling over the packer slips, using a flat bottom mill, sand line drilling, running a mill shoe and spear, and considerations for special cases. Challenges with nipple milling and examples of packer removal in case histories are also summarized.
WellCare Oil Tools Pvt. Ltd., prides itself on offering great service and being able to deliver accurate formal quotes to clients within 72 hours of receiving an enquiry.
We keep a large inventory of standard flow control tools and completion packers in stock, enabling quick delivery anywhere in the world. We ensure high quality and traceability, full certification including Mill Test Reports (MTR's), certificate of Conformance, Certificate of Origin, Function Test and Pressure Test Results are available free of charge upon request for each order and are kept on file and available on request at any time in the future.
Premium thread connections like: Tenaris-Hydril, Vam and Hunting connections are available upon request and threads are cut by premium licenced machine shops in Dubai & Singapore.
Special elastomer are available: AFLAS, HNBR, Viton and HSN, Hi-Nitrile are available along with non-elastomeric seal stacks to confirm to sour well conditions.
Category Products :
Cementation Systems
Cementing Equipment
Completion Systems
Mechanical Set Packer
Seal Bore Packer
Bridge Plugs
Hydraulic Set Packer
Cement Retainer
Completion Equipment
Liner Hanger Systems
Liner Hanger
Flow Control Systems
Sliding Sleeve
Landing Nipples
Flow Control Equipment
Inflatable Packers
Inflatable Packer
Various other factors that have enabled us to gain an edge over our competitors are:
Qualitative product range
World renowned vendor base
Experienced professionals
Efficient logistics and widespread distribution network
Industry leading prices
Timely delivery
This document discusses squeeze cementing techniques and considerations. Squeeze cementing involves pumping cement slurry under pressure against a permeable formation to create a cement seal. Key aspects covered include reasons for squeeze cementing, slurry design factors like viscosity and fluid loss control, laboratory testing methods, and primary concerns like establishing an injection rate and avoiding formation fracture. Detailed explanations are provided for methods like running squeezes through packers or cement retainers and different injection techniques.
The document discusses various types of production packers used in well completion and intervention work. It describes packers that can be set mechanically, hydraulically, or electrically and covers single bore, dual bore, sump, and ESP packers. The purposes of packers include isolating zones, facilitating gas lift, preventing fluid flow, and testing or abandoning wells. Packer setting mechanisms, components, and installation procedures are also outlined.
This document from the Occupational Safety & Health Administration provides an illustrated glossary of drilling rig components. It includes photos and definitions of over 60 different parts of a drilling rig, from major components like the derrick, drawworks, and blowout preventer, to smaller tools like tongs, slips, and elevators. Each item includes a photo and brief 1-2 sentence definition of its purpose. Additional navigational links are provided at the top and bottom of the page to related drilling safety topics.
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 discusses various components used in well completion and intervention, including landing nipples, perforated joints, flow couplings, blast joints, and wireline entry guides. It provides information on the applications and design of each component, with diagrams to illustrate their uses and configurations in the subsurface completion string. Manufacturers of some components are also mentioned. The document is authored by Eng. El Sayed Amer and appears to be presentation materials on well completion equipment and techniques.
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.
The document discusses procedures for BOP testing and kick tolerance calculations. It provides details on general BOP testing steps including using water, ensuring personnel safety, and pressure testing all equipment. It also covers kick tolerance concepts like calculating the maximum gas volume that can be circulated out of the wellbore without exceeding the weakest formation pressure. An example calculation is provided to determine a well's kick tolerance volume.
The document provides information on various wellbore equipment manufactured by Parveen including:
- Measuring line stuffing boxes that seal around wirelines and incorporate a blow out plug for safety.
- Line wipers used to wipe wirelines when removed from wells.
- Grease injection control heads that inject grease to create a seal around braided lines.
- Lubricator risers that allow wirelines to be raised above wellhead valves.
- Blowout preventers available in manual or hydraulic models in various configurations to provide protection during wireline operations.
Complete Casing Design with types of casing, casing properties, casing functions, design criteria and properties used for designing and one numerical problem
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.
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.
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.
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 production packers, which are subsurface tools used to provide a seal between casing and tubing. Production packers serve several purposes, such as protecting casing from corrosion, providing better well control, preventing fluid movement between zones, and isolating zones of bad cement. The key components of a production packer include slips, packing elements, and a cone. Production packers can be classified as permanent or retrievable and can be set mechanically, hydraulically, or electrically. Common types of production packers include sump packers, single-bore packers, dual-bore packers, and ESP packers.
A Brief Introduction to Coiled Tubing: What is it? What to do with it?, pumps...tmhsweb
This document provides an overview of coiled tubing, including its history, equipment, and applications. It discusses how coiled tubing originated from military projects during World War II and was first used in the oilfield in 1962. The key components of a coiled tubing unit are described, including the injector, reel, control house, and other equipment. Common applications of coiled tubing in the oil and gas industry involve well intervention operations such as drilling, logging, perforating, and more. A comparison is made between addressing blockages in wells and arteries.
1. sequance of well drilling and completion part 1Elsayed Amer
The document outlines the steps for well drilling and site preparation. It describes leveling the site, digging a cellar and mud pits, hammering a conductor pipe, drilling a rathole, and transporting equipment to the site. Subsequent steps include rig setup, inspection and preparation of drill pipes and drill string, mixing and pumping spud mud, drilling initial sections, cleaning the hole, running and cementing surface casing.
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.
WELL COMPLETION, WELL INTERVENTION/ STIMULATION, AND WORKOVERAndi Anriansyah
This document discusses various well completion, intervention, and workover topics including:
- Well completion involves preparing the well for production by installing equipment like casing and tubing.
- Open hole and cased hole completions are described, along with advantages and disadvantages of each.
- Well intervention operations like scale removal, acidizing, and sand cleaning are performed during production.
- Formation damage from fluids introduced into the well is also discussed.
- Stimulation techniques like acidizing and hydraulic fracturing aim to increase well productivity. The document outlines the processes, equipment, and evaluation of these operations.
- Other topics covered include intelligent well completions, perforating, sand control, squeeze cement
This document discusses various techniques for removing permanent packers and retrievable packers that require more than straight pulls. It describes reasons for removal such as leaks and access to lower zones. Rig-based and coiled tubing removal methods are covered. Specific techniques discussed include milling over the packer slips, using a flat bottom mill, sand line drilling, running a mill shoe and spear, and considerations for special cases. Challenges with nipple milling and examples of packer removal in case histories are also summarized.
WellCare Oil Tools Pvt. Ltd., prides itself on offering great service and being able to deliver accurate formal quotes to clients within 72 hours of receiving an enquiry.
We keep a large inventory of standard flow control tools and completion packers in stock, enabling quick delivery anywhere in the world. We ensure high quality and traceability, full certification including Mill Test Reports (MTR's), certificate of Conformance, Certificate of Origin, Function Test and Pressure Test Results are available free of charge upon request for each order and are kept on file and available on request at any time in the future.
Premium thread connections like: Tenaris-Hydril, Vam and Hunting connections are available upon request and threads are cut by premium licenced machine shops in Dubai & Singapore.
Special elastomer are available: AFLAS, HNBR, Viton and HSN, Hi-Nitrile are available along with non-elastomeric seal stacks to confirm to sour well conditions.
Category Products :
Cementation Systems
Cementing Equipment
Completion Systems
Mechanical Set Packer
Seal Bore Packer
Bridge Plugs
Hydraulic Set Packer
Cement Retainer
Completion Equipment
Liner Hanger Systems
Liner Hanger
Flow Control Systems
Sliding Sleeve
Landing Nipples
Flow Control Equipment
Inflatable Packers
Inflatable Packer
Various other factors that have enabled us to gain an edge over our competitors are:
Qualitative product range
World renowned vendor base
Experienced professionals
Efficient logistics and widespread distribution network
Industry leading prices
Timely delivery
This document discusses squeeze cementing techniques and considerations. Squeeze cementing involves pumping cement slurry under pressure against a permeable formation to create a cement seal. Key aspects covered include reasons for squeeze cementing, slurry design factors like viscosity and fluid loss control, laboratory testing methods, and primary concerns like establishing an injection rate and avoiding formation fracture. Detailed explanations are provided for methods like running squeezes through packers or cement retainers and different injection techniques.
The document discusses various types of production packers used in well completion and intervention work. It describes packers that can be set mechanically, hydraulically, or electrically and covers single bore, dual bore, sump, and ESP packers. The purposes of packers include isolating zones, facilitating gas lift, preventing fluid flow, and testing or abandoning wells. Packer setting mechanisms, components, and installation procedures are also outlined.
This document from the Occupational Safety & Health Administration provides an illustrated glossary of drilling rig components. It includes photos and definitions of over 60 different parts of a drilling rig, from major components like the derrick, drawworks, and blowout preventer, to smaller tools like tongs, slips, and elevators. Each item includes a photo and brief 1-2 sentence definition of its purpose. Additional navigational links are provided at the top and bottom of the page to related drilling safety topics.
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 discusses various components used in well completion and intervention, including landing nipples, perforated joints, flow couplings, blast joints, and wireline entry guides. It provides information on the applications and design of each component, with diagrams to illustrate their uses and configurations in the subsurface completion string. Manufacturers of some components are also mentioned. The document is authored by Eng. El Sayed Amer and appears to be presentation materials on well completion equipment and techniques.
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.
The document discusses procedures for BOP testing and kick tolerance calculations. It provides details on general BOP testing steps including using water, ensuring personnel safety, and pressure testing all equipment. It also covers kick tolerance concepts like calculating the maximum gas volume that can be circulated out of the wellbore without exceeding the weakest formation pressure. An example calculation is provided to determine a well's kick tolerance volume.
The document provides information on various wellbore equipment manufactured by Parveen including:
- Measuring line stuffing boxes that seal around wirelines and incorporate a blow out plug for safety.
- Line wipers used to wipe wirelines when removed from wells.
- Grease injection control heads that inject grease to create a seal around braided lines.
- Lubricator risers that allow wirelines to be raised above wellhead valves.
- Blowout preventers available in manual or hydraulic models in various configurations to provide protection during wireline operations.
Complete Casing Design with types of casing, casing properties, casing functions, design criteria and properties used for designing and one numerical problem
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.
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.
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.
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.
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.
WellCare Oil Tools Pvt. Ltd., prides itself on offering great service and being able to deliver accurate formal quotes to clients within 48 hours of receiving an enquiry.
We keep a large inventory of standard flow control tools and completion packers in stock, enabling quick delivery anywhere in the world. We ensure high quality and traceability, full certification including Mill Test Reports (MTR's), certificate of Conformance, Certificate of Origin, Function Test and Pressure Test Results are available free of charge upon request for each order and are kept on file and available on request at any time in the future.
Premium thread connections like: Tenaris-Hydril, Vam and Hunting connections are available upon request and threads are cut by premium licenced machine shops in Dubai & Singapore.
Special elastomer are available: AFLAS, HNBR, Viton and HSN, Hi-Nitrile are available along with non-elastomeric seal stacks to confirm to sour well conditions.
Category Products :
Cementation Systems
Cementing Equipment
Completion Systems
Mechanical Set Packer
Seal Bore Packer
Bridge Plugs
Hydraulic Set Packer
Cement Retainer
Completion Equipment
Liner Hanger Systems
Liner Hanger
Flow Control Systems
Sliding Sleeve
Landing Nipples
Flow Control Equipment
Inflatable Packers
Inflatable Packer
Various other factors that have enabled us to gain an edge over our competitors are:
Qualitative product range
World renowned vendor base
Experienced professionals
Efficient logistics and widespread distribution network
Industry leading prices
Timely delivery
--
With Best Regards
Surender Yadav ( Marketing Manager)
Cell: +91 8696934503
For WellCare Oil Tools Private Limited, India.
This document provides an overview of well design and construction. It begins with an agenda and then covers topics such as different types of drill rigs used for various water depths, rig systems for hoisting, rotating, circulating, and well control, well types (exploration, appraisal, development), typical well schematics, casing strings, typical lithology for the central North Sea, casing cementation, drilling fluids, drill bits, bottom-hole assemblies, drilling problems, and well evaluation using wireline logging. The document provides essential information on the key aspects and considerations for well design and construction.
This document discusses casing, which is large diameter pipe inserted into recently drilled boreholes and cemented in place. Casing serves several important purposes in the well construction process, including preventing contamination, cave-ins, and blowouts. Proper casing design considers formation pressures and strengths to determine optimal casing depths and diameters. Wells typically include multiple casing intervals of progressively smaller diameter to reach total depth. Casing is run and cemented in stages to safely drill to target depths.
The document provides an index and descriptions of various liner hanger system products, including:
- Pocket slip liner hanger that is non-rotating and can be run with a hydraulic release or mechanical running tool. It uses hydraulic cylinders to set slips to hang the liner string during cementing.
- Model BAFN setting tool that conveys the liner and sets the hanger assembly. It can be released by right hand rotation after cementing is complete.
- Integral body cementing head that suspends drill pipe weight while retaining the plug, connects cementing lines, and includes a heavy-duty swivel and integral plug dropping manifold.
Casing is essential for safely drilling oil and gas wells. It must withstand forces during drilling and through the life of the well. Different casing strings are run to isolate formations with different pressures and seal off problematic zones to allow deeper drilling. Surface casing isolates fresh water and supports blowout preventers. Intermediate casing increases pressure integrity to drill deeper and protects progress. Production casing houses completion equipment and isolates the producing zone. Liners are shorter strings hung from intermediate casing to complete zones economically. Proper casing and cementing is crucial to isolate formations and prevent communication between zones.
The document discusses the functions and types of casing strings used in oil and gas wells. It describes the different casing strings like conductor casing, surface casing, intermediate casing, and production casing. It also covers casing design criteria like classifications based on outside diameter, length, connections, weight, and grade. The mechanical properties of casing are discussed in relation to withstanding tensile, burst, and collapse loads during drilling and production operations.
The document discusses factors related to casing design, including:
1) The design factor is the minimum acceptable safety factor, which is the ratio of the load applied to the pipe's rating.
2) The axial strength of the pipe is determined by an equation using the pipe's minimum yield strength, outer diameter, and inner diameter.
3) A triaxial stress criterion using three stress components - axial, tangential, and radial - is presented for evaluating combined loading conditions. Loads falling within the resulting design envelope meet the design criteria.
This document discusses packers, which are used in oil and gas well completions to isolate sections of the wellbore. It describes the main components and functioning of packers, including cones that force slips into the casing and compressed sealing elements. The document outlines different types of packers classified by function, installation method, and duration. Removal techniques for permanent and retrievable packers are also summarized. Safety joints are explained as a means to release packers in emergency situations by shearing pins and allowing retrieval of completion equipment above. In conclusion, the document emphasizes that packers are critical for well integrity and outlines key aspects of their design and application.
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".
Expandable liner hanger and packer exceed expectations for first deepwater we...Baker Hughes
The 113⁄4-in expandable liner hanger and packer system was successfully deployed on Saudi Aramco's first deepwater well in the Red Sea, overcoming challenges from the well's nature as a rank wildcat. The ELHP system was designed and qualified through testing to isolate a salt section and unknown rubble zone below, while preserving the preferred 95⁄8-in casing size. During drilling, losses were encountered but circulation was regained after pumping lost circulation material, allowing drilling to continue to further evaluate the pressure trend below the salt.
David Hryvniak, an experienced trail and road runner who also happens to be a doctor and assistant professor at UVA’s Department of Physical Medicine and Rehabilitation (He works with Dr. Wilder). David will talk about common overuse injuries and how to prevent those injuries.
This document outlines the Energy Resources Conservation Board's (ERCB) Directive 008 regarding surface casing depth requirements. Some key changes in the updated directive include a modified surface casing depth calculation form, deeper minimum surface casing depths of over 650 meters, additional standards for specified areas and well types, and new sections on deep surface casing, non-thermal injection/disposal wells, thermal wells, surface casing exemptions, and using a blowout preventer with surface casing. The directive provides requirements and recommendations for properly determining sufficient surface casing depth to ensure well control and protect groundwater sources during drilling operations.
This recipe for distance runners touches on a few concepts from the world of exercise physiology, yet the main focus is on how workouts fit into a sound training program.
This presentation is a course a bout wellheads which includes the basic components of the well head and the advanced techniques.
helping students who are cared about petroleum industry to increase their knowledge about this tool that is important for both drilling and production.
For Further information, use the following LinkedIn account:
https://www.linkedin.com/in/mohamed-abdelshafy-abozeima-9b7589119/
The document discusses various components of oil and gas wellheads including:
- Casing heads that suspend casing strings and provide access to annuli.
- Casing spools that support intermediate casing and allow secondary seals.
- Casing hangers that suspend and seal casing strings within heads and spools.
- Tubing heads that suspend tubing strings and connect to Christmas trees.
- Tubing hangers that suspend tubing and seal within tubing heads.
- Other components like packers, adapters, and valves that provide sealing and connections between casing/tubing strings and wellhead equipment.
Sucker rod pumps are commonly used to lift oil from wells. They consist of downhole equipment like a pump barrel and plunger, as well as surface equipment like a prime mover and walking beam. The pump operates through a reciprocating cycle where the plunger lifts fluid on the upstroke and releases it on the downstroke. Key parameters that must be calculated for pump design include the maximum and minimum polished rod loads, plunger displacement, torque requirements, and needed counterweight. Issues like fluid pound, gas interference, and leaky valves can be identified from analysis of load versus position cards measured at the surface.
The document discusses the fundamentals of mechanical seals used in pumps. It describes how mechanical seals work to prevent leaks by creating a close fit between a stationary and rotating seal surface. It covers the basic components of mechanical seals including primary sealing elements, secondary sealing elements, and hardware. It also discusses seal face materials, designs, installation, operation, and ways to control the seal environment through flushing, cooling, and heating.
The document provides information about a blowout preventer (BOP) used on an oil rig. It discusses the various components of the BOP including annular preventers, ram preventers, and control systems. It describes the purpose and functioning of different types of rams, and provides specifications for components like annular preventers, ram types, pressure ratings, and inspection procedures. Maintenance and testing of the BOP is important for safety and preventing blowouts when drilling oil wells.
Mechanical seals are used to prevent leakage of liquids and gases from pumps and other rotating equipment. There are several types of mechanical seals that can be used depending on the application. The basic components of a mechanical seal include a stationary seal face, a rotary seal face, springs or other compression devices, and secondary seals like O-rings. Proper operation requires the seal faces to be flat, perpendicular to the shaft, and in constant contact maintained by spring force. Forces acting on the seal faces include axial, radial, closing, opening, hydrostatic, and hydrodynamic forces. Materials for the seal faces must withstand friction while maintaining a thin lubricating film between the faces. Mechanical seals are also classified based on their configuration as
ROTEX Controls Pneumatic Actuator Catalog Models DRC, DRS, and DRVROTEX Controls USA
This document provides information on various actuator models from Infinity Actuators, including their specifications and capabilities. It summarizes several high performance, heavy duty actuator series for applications requiring torque ranges from 1 in-lb to over 600,000 in-lb. These include rack and pinion, scotch yoke, hydraulic, and gas over oil designs. Performance curves are shown detailing torque output over stroke position and operating pressure for many double acting models.
Ralson is India's largest bicycle tyre manufacturer located in Ludhiana. It produces over 1.5 million tyres and tubes per day using machinery like the splicer machine. The splicer machine joins the ends of inner tubes together using pneumatic cylinders and heat. It has cutting blades, dies to hold the tube, and heaters to fuse the ends together. The splicer is an automated machine that precisely cuts and joins inner tubes using a series of pneumatic cylinders controlled by solenoid valves and limit switches.
This document provides information on rolling stock components and defects. It discusses wheels, suspension systems, and vehicle bodies. Specific wheel defects like thin flanges, worn roots, and flat tires are described. Suspension systems use springs, and defects in laminated and helical springs are covered. Buffers and their defects causing eccentric buffing forces are also summarized. The document provides details on maintenance limits and rejection criteria for various rolling stock components.
This document provides information on rolling stock components and defects. It discusses wheels, suspension systems, and vehicle bodies. Specific wheel defects like thin flanges, worn roots, and flat tires are described. Suspension systems use springs, and defects in laminated and helical springs are covered. The document also discusses wheel-axle measurements and tolerances. Buffers and their defects that can cause eccentric buffing forces are explained. Finally, the document briefly introduces bogies and the four main types used for goods stock.
This document provides information on various methods for addressing casing failures, including tools and procedures for identifying the type and location of failures, cutting and removing damaged casing, repairing casing using methods like swaging, rolling, and patching, and fishing stuck drill pipe and wireline. The document includes diagrams illustrating casing repair tools and procedures.
compressor maintenance, type of compressor.pgemp93manish
The document provides details about the construction, working, and maintenance of a reciprocating compressor. It describes the key components of the compressor including the cylinder, piston, valves, crankshaft, bearings, and lubrication system. It also outlines maintenance tasks performed during an overhaul after 24,000 hours of operation, including inspection and replacement of parts like pistons, rings, bearings, and valves. Daily maintenance tasks are documented for a specific compressor overhaul including measurement of clearances, replacement of parts, and tightening of covers.
This document provides information on mechanical seals used in hydraulic systems. It discusses how centrifugal pumps work and the need for seals to prevent leakage of pressurized liquid around the pump shaft. Mechanical seals were developed to improve on common packing seals, reducing leakage and wear. The document covers types of leakage, functions of seals, classifications of seals based on design and materials, and basics of fluid power symbols.
Pilgrim International produces shaft coupling solutions including radial fit bolts. Their radial fit bolts can be installed and removed in 10-15 minutes, faster than traditional shrink fit bolts which require freezing. Radial fit bolts provide a secure, pre-engineered interference fit between coupling flanges with lower lifetime costs than shrink fit bolts which frequently cause damage upon removal.
International Journal of Engineering Research and DevelopmentIJERD Editor
This document summarizes a research paper on high pressure silent screw pumps. It describes the construction and working of three screw pumps, which use one power rotor and two idler rotors to pump fluids. Three screw pumps can pump both Newtonian and non-Newtonian fluids to pressures over 300 bar and flows of 750 m3/h. They have advantages like being noiseless even at high pressures and speeds, requiring no maintenance or lubrication. However, they also have high costs. Three screw pumps find applications in industries like marine, industrial, and environmental for tasks like machinery lubrication and fuel transport.
This document provides information on wireline equipment used to lower tools into wells. It describes typical wireline units, pressure control equipment like stuffing boxes, lubricators, tool traps, wireline blowout preventers (BOPs), and their components and functions. The goal of the pressure control equipment is to allow tools to enter the well while containing pressure and preventing leaks.
manufactures and sells circulating, fill-up and flow-back tools for oilfield ...Nikki Pope
DrawWorks products are designed to reduce risk and save time by simplifying two key drilling processes: running tubulars and handling fluids. DrawWorks offerings include the AutoFill™ Casing Fill-Up and Circulating System, the AutoValve™ Mudsaver Valve, the DPC™ Drill Pipe Circulating and Flow-Back System, the SJC™ Single Joint Compensator, and lightweight Drift Bars. This equipment is used by companies providing casing running services such as casing crews.
This document provides information on check valves from Schutte & Koerting, including:
- Check valves prevent backflow in steam and water lines to protect equipment. They close automatically in response to backflow or can be actuator controlled.
- Valves are available in configurations to meet critical application requirements, and can be tested and rated to ANSI standards.
- Specifications and dimensions are provided for standard body designs from size 3 to 30 in various pressure classes.
The document discusses the components and functioning of an anaesthesia work station's high pressure system. It describes the key components including gas cylinders, hanger yokes, cylinder pressure indicators, and pressure regulators. Gas cylinders contain medical gases at high pressure and have valves, handles, pressure relief devices, and markings. Hanger yokes orient and secure cylinders, providing a gas-tight seal. Cylinder pressure indicators display the pressure level in cylinders. Pressure regulators reduce the high cylinder pressure to a lower, constant pressure suitable for use in the anaesthesia machine.
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Part 2 Deep Dive: Navigating the 2024 Slowdownjeffkluth1
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The global retail industry has weathered numerous storms, with the financial crisis of 2008 serving as a poignant reminder of the sector's resilience and adaptability. However, as we navigate the complex landscape of 2024, retailers face a unique set of challenges that demand innovative strategies and a fundamental shift in mindset. This white paper contrasts the impact of the 2008 recession on the retail sector with the current headwinds retailers are grappling with, while offering a comprehensive roadmap for success in this new paradigm.
Navigating the world of forex trading can be challenging, especially for beginners. To help you make an informed decision, we have comprehensively compared the best forex brokers in India for 2024. This article, reviewed by Top Forex Brokers Review, will cover featured award winners, the best forex brokers, featured offers, the best copy trading platforms, the best forex brokers for beginners, the best MetaTrader brokers, and recently updated reviews. We will focus on FP Markets, Black Bull, EightCap, IC Markets, and Octa.
Unveiling the Dynamic Personalities, Key Dates, and Horoscope Insights: Gemin...my Pandit
Explore the fascinating world of the Gemini Zodiac Sign. Discover the unique personality traits, key dates, and horoscope insights of Gemini individuals. Learn how their sociable, communicative nature and boundless curiosity make them the dynamic explorers of the zodiac. Dive into the duality of the Gemini sign and understand their intellectual and adventurous spirit.
Top 10 Free Accounting and Bookkeeping Apps for Small BusinessesYourLegal Accounting
Maintaining a proper record of your money is important for any business whether it is small or large. It helps you stay one step ahead in the financial race and be aware of your earnings and any tax obligations.
However, managing finances without an entire accounting staff can be challenging for small businesses.
Accounting apps can help with that! They resemble your private money manager.
They organize all of your transactions automatically as soon as you link them to your corporate bank account. Additionally, they are compatible with your phone, allowing you to monitor your finances from anywhere. Cool, right?
Thus, we’ll be looking at several fantastic accounting apps in this blog that will help you develop your business and save time.
The Most Inspiring Entrepreneurs to Follow in 2024.pdfthesiliconleaders
In a world where the potential of youth innovation remains vastly untouched, there emerges a guiding light in the form of Norm Goldstein, the Founder and CEO of EduNetwork Partners. His dedication to this cause has earned him recognition as a Congressional Leadership Award recipient.
NIMA2024 | De toegevoegde waarde van DEI en ESG in campagnes | Nathalie Lam |...BBPMedia1
Nathalie zal delen hoe DEI en ESG een fundamentele rol kunnen spelen in je merkstrategie en je de juiste aansluiting kan creëren met je doelgroep. Door middel van voorbeelden en simpele handvatten toont ze hoe dit in jouw organisatie toegepast kan worden.
Top mailing list providers in the USA.pptxJeremyPeirce1
Discover the top mailing list providers in the USA, offering targeted lists, segmentation, and analytics to optimize your marketing campaigns and drive engagement.
[To download this presentation, visit:
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This PowerPoint compilation offers a comprehensive overview of 20 leading innovation management frameworks and methodologies, selected for their broad applicability across various industries and organizational contexts. These frameworks are valuable resources for a wide range of users, including business professionals, educators, and consultants.
Each framework is presented with visually engaging diagrams and templates, ensuring the content is both informative and appealing. While this compilation is thorough, please note that the slides are intended as supplementary resources and may not be sufficient for standalone instructional purposes.
This compilation is ideal for anyone looking to enhance their understanding of innovation management and drive meaningful change within their organization. Whether you aim to improve product development processes, enhance customer experiences, or drive digital transformation, these frameworks offer valuable insights and tools to help you achieve your goals.
INCLUDED FRAMEWORKS/MODELS:
1. Stanford’s Design Thinking
2. IDEO’s Human-Centered Design
3. Strategyzer’s Business Model Innovation
4. Lean Startup Methodology
5. Agile Innovation Framework
6. Doblin’s Ten Types of Innovation
7. McKinsey’s Three Horizons of Growth
8. Customer Journey Map
9. Christensen’s Disruptive Innovation Theory
10. Blue Ocean Strategy
11. Strategyn’s Jobs-To-Be-Done (JTBD) Framework with Job Map
12. Design Sprint Framework
13. The Double Diamond
14. Lean Six Sigma DMAIC
15. TRIZ Problem-Solving Framework
16. Edward de Bono’s Six Thinking Hats
17. Stage-Gate Model
18. Toyota’s Six Steps of Kaizen
19. Microsoft’s Digital Transformation Framework
20. Design for Six Sigma (DFSS)
To download this presentation, visit:
https://www.oeconsulting.com.sg/training-presentations
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Profiles of Iconic Fashion Personalities.pdfTTop Threads
The fashion industry is dynamic and ever-changing, continuously sculpted by trailblazing visionaries who challenge norms and redefine beauty. This document delves into the profiles of some of the most iconic fashion personalities whose impact has left a lasting impression on the industry. From timeless designers to modern-day influencers, each individual has uniquely woven their thread into the rich fabric of fashion history, contributing to its ongoing evolution.
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Explore the details in our newly released product manual, which showcases NEWNTIDE's advanced heat pump technologies. Delve into our energy-efficient and eco-friendly solutions tailored for diverse global markets.
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How to Start Up a Company: A Step-by-Step Guide Starting a company is an exciting adventure that combines creativity, strategy, and hard work. It can seem overwhelming at first, but with the right guidance, anyone can transform a great idea into a successful business. Let's dive into how to start up a company, from the initial spark of an idea to securing funding and launching your startup.
Introduction
Have you ever dreamed of turning your innovative idea into a thriving business? Starting a company involves numerous steps and decisions, but don't worry—we're here to help. Whether you're exploring how to start a startup company or wondering how to start up a small business, this guide will walk you through the process, step by step.
Starting a business is like embarking on an unpredictable adventure. It’s a journey filled with highs and lows, victories and defeats. But what if I told you that those setbacks and failures could be the very stepping stones that lead you to fortune? Let’s explore how resilience, adaptability, and strategic thinking can transform adversity into opportunity.
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Know what your zodiac sign says about your taste in food! Explore how the 12 zodiac signs influence your culinary preferences with insights from MyPandit. Dive into astrology and flavors!
5. Float Shoe
It provides two main functions:
1. The shape of the shoe helps to guide the liner through
open hole.
2. Single or double check valves prevents backflow inside
the liner.
6. REAMER SHOE with Dual float valve
•
•
•
•
•
•
Eccentric nose design can climb ledges and negotiate other wellbore
Rigid standoff stabilizer blades, combined with the cutting structure, clear a path for the
casing or liner and most types of rigid centralizers installed above.
blade cutting structure facilitates both rotating and reciprocating applications to ensure safe
passage of casing and liners.
Large flow-directed ports cover the entire wellbore during rotating and reaming and prevent
channeling during cement pumping.
Dual float valve prevents cement backflow.
Aluminum nose enables fast drillout with PDC or tri-cone bits.
7. Tapered and offset tapered noses
help casing pass severe ledges, obstructions, high angles, and previous
sidetracks. These noses also help protect the float valves from being
damaged from debris while running in the hole.
8. Ball catcher
•
•
•
A ported baffle used to stop sheared ball
or plugs from resting on the float valve
that may stop the valve from working
properly.
It’s also ported to allow normal circulation
through it.
It may be screwed as an individual joint or
inserted.
9. Landing Collar
•
Includes:
1. An integral ball seat
2. liner wiper plug seat.
•
•
When a setting ball is dropped and seated, pressure
may be applied to activate hydraulic devices in the
liner string, such as hydraulic-set liner hangers and
external casing packers.
Further increase in pressure shears out the ball and
seat, restoring full circulation through the shoe for
cementing operations.
12. Liner hanger assembly
Liner top packer
Liner hanger assembly, it consists of:
• Liner hanger
• Drillable pack-off bushing
• Liner top packer
•
•
These components remain in the wellbore and
sold to customer
Inside these components there is the liner
running tool, that is rented to the customer as
part of the liner installation service.
Drillable pack-off bushing
Liner hanger
13. The running/setting tool
•
•
•
•
•
The setting tool is used to connect the liner to the drill pipes.
It carries the liner into the well and provides a reliable releasing
mechanism when the drill pipe must be disconnected.
There is a screen at top of running tool to allow clean mud into liner
for pressure equalization without destroying or plugging any ports
inside.
Slick stinger: is a polished tool that seals inside the drillable pack-off
bushing to create a pressure seal at the liner top during the setting
process.
The wiper plug is attached to the end of the running tool assembly.
Screen at top of running tool to allow clean mud into
liner for pressure equalization without destroying or
plugging any ports inside
Drillable pack-off bushing
Wiper plug
15. FLEX-LOCK III Hydraulic-Set Liner Hanger
APPLICATION
• hydraulic-set liner hanger series is capable of hanging
exceptionally heavy liners.
• corrosion-resistant alloys (CRAs) are used.
• Differential pressure across an integral hydraulic cylinder
strokes the slips into engagement with the casing.
• The dramatic increase in hanging capacity over cone-type
hangers results from state-of-the-art design and finite
element analysis study.
• Loads transfer circumferentially into the slip seat, rather than
radially inward to the mandrel as the liner weight is hung.
• High load stresses on the mandrel beneath the slips are
avoided, preventing collapse of the hanger body under heavy
loading.
• Stress hot spots in the parent casing are eliminated.
16. FLEX-LOCK III Hydraulic-Set Rotating Liner Hanger
APPLICATION
• The FLEX-LOCK hydraulic-set rotating liner hangers
incorporate a tapered roller bearing assembly that allows the
liner to be rotated with the hanger in the set position while
cementing the liner.
• This bearing package allows the liner to be rotated at higher
RPM than hangers using conventional ball or journal bearing
systems.
Tapered roller bearing
17. FLEX-LOCK III Hydraulic-Set Rotating Liner Hanger
Advantages
• Proprietary slip design results in substantially lower and more
uniform stresses in both the parent casing and the hanger mandrel
as axial load is applied
• Kit hanger can be provided with mandrel or without, for mounting
on casing of any weight, grade or thread
• Hydraulic cylinder compatible with liner to meet NACE specifications
when required
• Premium hydraulic cylinder seals withstand up to 10,000 psi (689.6
bar) at 400°F (204°C)
• Tapered roller bearings allow rotation of liner after setting, resulting
in improved cement job
• Double grip retrievable version available
• Non left-hand rotating option for use with HRD-E setting tools
ensures secondary release if required
18. Setting mechanism
•
•
•
•
•
•
•
•
•
After ball is dropped and seated in the landing collar…it allows pressuring up the
string to set the liner hanger.
As pressure is applied at the surface…the hydraulic cylinder of the hanger shears
and strokes the slips up until they contact the casing wall.
As the weight of the liner is slacked-off, the hanger slips transfers the load to the
previous casing string.
The liner is now hung, to regain circulation, the setting ball is blown out by
increasing surface pressure to shear the pins in the seat, then sudden drop in
pressure occurs as circulation is re-established, and well is circulated until steady
and smooth pump pressure is obtained.
Now we can release the setting tool, and that depend on its type.
C2 liner setting tool > needs 10 right-hand turns, this disengages the float nut
from special carrying thread profile in the body of the top liner packer.
The drill pipe can now picked-up to ensure that the running tool is released, and
thus we expect to see only the pipe weight on the weight indicator as the liner
weight is now supported on the hanger.
Only pick-up the liner hanger couple of feet as we don’t want to activate the
packer setting device yet.
Then slack off sufficient weight to ensure pack-off, we are now ready for the
cement job
19. SB305-3A actual OHL setting parameters
just to feel numbers on actual example
Flex-lock hydraulic-set rotating liner hanger
1.
2.
3.
4.
5.
6.
7.
8.
9.
Drop 1 7/16" bronze ball & chase same till land in landing sub,
Press up to 2,200 psi to set liner HGR,
Bleed pressure to 500 psi,
Confirm HGR set by S/OFF liner wt + 30 Klb.
Press up to 3,400 psi to shear ball seat & release running tool,
Regain circulation with 4 bpm @ 700 psi.
P/U string 3 ft, confirm running tool released (lost liner wt "80 Klb").
Slack off string 3 ft (drill pipes slack-off weight = 165 Klb) then set 30 Klb on liner HGR.
Circulate & rotate liner with while prepare mix fluid.
20. TOP DRIVE CEMENT MANIFOLD…it contains: pump down plug, and its releasing
lock, plug release flag, ball dropping sub and rotating bearing [in case of rotating
CMT manifold TD-2]
TD CEMENT MANIFOLD
21. Top Drive cement manifold
In case of rotating TD-2
This part is static
[connected to cement line]
and the rest is rotating
Hose from cement unit
Plug release lock
Pump-down plug
Plug holding sleeve
Plug dropping flag
Ball dropping sub
22. TD2 rotating
cement head
All the TD2 body rotates with
the string except for this part
which is connected to the
cement line
Pump down plug
releasing lock
Pump-down Plug dropping flag
Ball dropping sub
23. Top drive cement head
•
•
•
•
•
APPLICATION
Cementing head is used to release a pump-down plug from
surface at the desired time during cementing operations,
without the need to break a tool joint connection or hammer
union.
The TD cementing head has standard tool joint connections to
accommodate heavy liner loads.
The pump-down plug is contained within a sleeve, with fluid
flow bypassing around the plug
Until the release lever is turned 180˚. The sleeve then shifts
downward, releasing the pump-down plug. Internal fluid
bypass eliminates the need for external valves and manifold.
24. Top drive cement head
Advantages
• Compact design holds pump-down
plugs securely until release is desired
• Innovative plug stop design eliminates
potential for plug damage at the time
of release
• Internal bypass requires no
external manifold, ideal for use with
top drive or conventional rotary rigs
• Easily stackable for multiple plug
applications
• Releasing mechanism is proven
dependable over thousands of field
runs
Plug release lock
Flow is diverted
away around the
plug .. Until lock
is opened and
plug is pumped
25. Positive Ball Dropping Sub
•
Baker Hughes’ positive ball dropping sub provides a
convenient method to release a setting ball from the surface
without breaking a drill pipe connection or removing a
hammer union cap.
Ball Releasing mechanism:
• The ball is positively retained in a recess beside the flow
stream, unaffected by the fluid flow until the ball is released
by a simple turn of the release lever.
• When the release lever is rotated approximately 300 degrees,
the ball is positively ejected from the recess into the flow
stream. The lever handle is locked until the time to drop the
setting ball.
• A counter-clockwise turn of the handle confirms the presence
of the ball without risk of premature release.
27. Positive Ball Dropping Sub
Advantages
• Provides a positive means to release a setting ball into the
running string at surface
• Ball cannot be prematurely released with handle locked
• Drops various standard-sized balls
• Simple and reliable operation
28. Flag Sub
•
•
•
•
APPLICATION
The flag sub, placed below the plug dropping head, provides
immediate visual confirmation that the pump-down plug has been
released and has moved down the running string.
The trip arm, or flag, is in the horizontal position across the flow
stream before the pump-down plug is released.
As the plug passes, the flag is moved to the vertical position. The flag
can be reset to the horizontal position repeatedly when used with
multiple pump-down plugs.
Advantages:
1.Positive indication that plug has left the
plug dropping head
2.Drillpipe connections standard to provide
high tensile ratings
29. Conventional Liner Cementing Plug Systems
APPLICATION
• Cementing plug systems used in liner applications typically serve two basic functions:
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 tubulars that it's 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 drillpipe
and the liner casing.
30. Pump-Down Plug
APPLICATION
• The pump-down plug is used to wipe the
running string behind (and sometimes in
front of) the cement.
• The pump-down plug may be used to latch
into a liner wiper plug as described later, or
can be used to wipe both the running
string and the liner casing in smalldiameter liner applications.
• Multiple darts may be used to more
effectively wipe the tubulars and reduce
cement contamination. Various wiper fin,
nose, and latch configurations are available
to fit a wide range of applications.
Plug release lock
Flow is diverted
away around the
plug .. Until lock
is opened and
plug is pumped
When the lock is
opened .. The
sleeve moves
down and this
flapper opens to
release the plug
31. Wiper Plug
APPLICATION
•
•
•
•
•
Liner wiper plugs are used to separate cement from the
displacement fluid during cementing operations.
The Type I liner wiper plug is shear pinned to the bottom of
the running string, below the liner setting tool and pack off.
At the tail of the cement, a pump-down plug, is released
and follows the cement down the running string.
When the pump-down plug lands in the liner wiper plug,
pressure is increased and shears the liner wiper plug free,
allowing both plugs to be displaced as a unit to the landing
collar.
Both types of liner wiper plugs are manufactured of
drillable materials, and are rotationally locked into the
landing collar to prevent spinning during Drill out.
This ring latches inside the landing
collar to prevent the plug from
rotation while drilling it
32. Now after completing displacing the cement, and check for back flow and all OK,
it’s time to set the liner top packer *we used a ZXP packer for this demonstration+
ZXP PACKER SETTING
33. ZXP Liner Top Packer
APPLICATION
• liner packer is recognized industry-wide as today's premier high-performance
liner top packer.
• The innovative ZX seal element is designed and constructed to endure
exceptionally high circulation rates and achieve high pressure and temperature
sealing in the most demanding wellbore environments. Flow loop testing at
over 17 BPM (2.7 m3/min) confirms durability of the ZX seal.
• The packer is compression-set using a packer setting dog sub or a hydraulic
pusher tool.
• The ZXP liner packer is available with or without hold-down slips.
• ZXP packers can be run on 2 RH, and HRD-E liner setting tools.
• The ZXP liner packer is typically run as an integral component of the primary
liner hookup. It may also be run in conjunction with a tieback seal assembly to
serve as a tieback packer in the event remedial repair of the liner top is
necessary.
• Tieback extensions are commonly available in lengths of 6 ft (1.82 m) , 10 ft
(3.04 m) , 15 ft (4.57 m), and 20 ft (6.09 m) .
34. ZXP Liner Top Packer cont’d
Advantages
• Most extensively tested packer on the market
• Rugged proprietary seal element design resists swab off at high circulation
rates and mechanical damage
• Allows liner to be run in hole much faster than conventional liner packers,
saving rig time
• Aflas* (Asahi Glass of Japan) outer cover material compatible with most
wellbore environments
• Available with and without hold-down slips
• Available with all current running tool profiles
• Can be run with seal assembly as a tieback packer to isolate leaking liner top
• Standard service for many sizes is 10,000 psi (689.6 bar) at 400°F (204°C) ;
high-pressure/high-temperature-rated tools available upon request
35. ZXP setting mechanism
•
Now we have the cement in place, we are ready to set the
liner top packer
To do this:
1. Pick-up the drill pipe several feet [ in this case 10’+
[remember the running tool is already freed when setting
the hanger itself]
2. expose the spring loaded dogs in the packer setting dog
sub
3. And apply set-down weigh of the drill pipe
4. When sufficient weight has been applied to shear the
setting pins in the packer
5. Compression will energize the seal element and engages
the hold-down slips into the casing wall.
6. The packer is now set, and will provide an effective
annular seal the liner and the previous casing string.
7. We may circulate out the cement at the top of liner.
ZXP
elastomer
hold-down
slips
36. Packer Setting Dogs Sub
It’s designed to apply set down weight to mechanically set liner top packers
like ZXP. A set of spring loaded dogs are used to transfer the set down weight
from the drill string to the liner setting sleeve on the liner packer.
APPLICATION
• Packer setting dog subs are used to activate and pack off compressionset liner top packers.
• Multiple spring-loaded dogs are compressed within the packer extension
throughout liner running and cementing.
• At the appropriate time, the setting dog sub is raised out of the packer
extension and the dogs expand out to the OD of the extension.
• Setting force is transferred through the dogs and onto the packer
extension as drillpipe weight is slacked off.
38. Insert Liner Cementing Equipment
•
•
once installed, is permanently anchored and sealed in place.
The desired accessory is threaded into the bottom or top of the
seal unit, as appropriate.
The seal unit is a compact aluminum module with a 360 degree
aluminum slip. The unit also includes elastomer and metal-tometal seals. Insert cementing float valves are designed and
tested to satisfy API Recommended Practices 10F specifications
installation
• Depending on the required component configuration (packoff,
landing collar, float valve, etc.), accessory components are
added to the bottom or top of the seal unit.
• After the insert unit and its setting tool are positioned inside
the liner joint, hydraulic pressure from a small hand pump is
applied to complete the setting process.
• The setting tool is then removed, and the liner joint is marked
with accessory position and description.
39. Insert Liner Cementing Equipment
Advantages
• Modular insert seal unit easily converts to landing collar, float collar, guide/float
shoe, drillable packoff, or ball catcher sub
• Simple and reliable installation can be performed at the wellsite
• Eliminates multiple premium thread charges and expensive corrosion-resistant
collar bodies
• Manufactured from drillable aluminum and phenolic components
42. Spherolite
•
•
•
Hollow glass microspheres made from a low heat conductivity glass composition containing a
high vacuum and thin metal coating deposited on the inner wall surface.
It can be used to make a superior insulation materials in construction of highly efficient solar
energy collectors and insulation systems.
Also as filter materials in plastic, plastic foam and in concrete and asphalt composition.
43. Tuned Cementing Solutions (TCS™)
Lightweight Systems
•
Halliburton enables you to choose from all three primary categories of lightweight cements,
so your choices can be based on your requirements, such as:
1. Water-extended– Use water-extended slurries when cost is your primary concern.
These slurries can provide the required levels of fill if conditions are not too demanding.
2. Hollow microspheres – Use Tuned Light™ (hollow microspheres) slurries when high
strength or achieving the lowest permeabilities are the main drivers or when a
premium cement is required and foam is not an option.
3. Foam – Use the Zoneseal® Isolation Process
(foam cement) when gas migration or shallow
water flow potentials are problems. Foam is
also the best choice when long-term stress
protection is a primary driver.
44. Tuned Light™ XL Cement Blend
Quick-setting, High-Strength, Lightweight Cement Blend for Problem Top-Hole Jobs
•
•
•
Halliburton Tuned Light XL cement blend contains carefully selected additives that produce
lightweight slurries with strengths equal to or better than standard accelerated 16 parts per
gallon (ppg) Class G cement slurries at the low temperatures found in the North Sea mud
line. At a nominal Tuned Light XL slurry weight of 12.7 ppg, the initial set at 50°F is just three
hours while the first compressive strength reaches 5,000 psi. Tuned Light XL slurries are also
mildly thixotropic, which minimizes fallback in situations where surface gas is a potential
problem.
These special properties are extremely important in areas where operators often drill
through formations near the surface that are weak and nonconsolidated. These formations
tend to break down because their fracture gradient cannot withstand the normal cement
slurry weight of 16 ppg. The result is cement losses and inability to bring cement up to the
mud line.
Remedial treatments to top-up the primary job involve rig time, more cement and longer
waiting-on-cement (WOC) time. Conventional lightweight slurries may solve the problem of
losses, but do not develop adequate strength to endure the stresses on the conductor
casings. In addition, it is important to consider the low temperatures of 40- to 50°F usually
encountered in the North Sea seabed
45.
46. Tuned Light® Cement
Important Benefits
• Low Density. Tuned Light XL slurries are mixed and field-proven at a wide range of densities,
maximizing seabed returns and reducing the need for remedial top-up jobs.
• Thixotropic. The Tuned Light XL slurry will gel up in approximately one hour and softy set in
about three hours. In effect, this means that the casing can be released within three hours of
the time the job ends.
• Faster Transition Times. The Tuned Light XL slurry’s zero gel time, measured with
Halliburton’s Mini Macs™ analyzer, was 20 minutes. The transition time was determined to
be 10 minutes at 55°F and 500 psi. Based on Halliburton’s accepted guidelines on gas
migration, the Tuned Light XL slurry qualifies as gas-tight for low gas flow potential (GFP)
factors.
• Compressive Strength. Supporting the conductor is critical. Tuned Light XL slurries develop
compressive strength at low densities and cool temperatures that exceed conventional
slurries under the same conditions.
47. Cement silos
• There are three silos for cement on the rig and another three for Barite.
• They are all connected together and to the supply line from the boat.
• Silo capacity is measured be weight cell mounted on bottom of it and
connected to gauge that displays the weight in thousands pounds.
• Cement is transferred to the unit by carrying it with pressurized air,
depend on the vacuum pressure that air induces when passes near the
powder cement.
• Also the silo itself is pressurized to force cement out of it.
• Air supply should be opened first before opening the cement line
52. SAPESCO handling equipment
•
•
•
•
•
•
•
•
•
•
Rotary hand slips
Safety clamp
Single joint elevator
Spider slips [pneumatic]
Spider elevator [pneumatic]
Side door elevator
HYT elevator [tubing]
Drifts
Stabbing guide
Thread protectors
•
•
Jam unit
Wincatt software
53. Power tong with side door
Revolution
High/low gear
control
Hydraulic piston used to hang the
tong in the air tagger to dampen
vertical vibrations and bouncing
*shouldn’t be placed here+
1.25” pressure
line INLET
1” pressure
line outlet
Side door
with safety
control
Revolution
counter
54. Stabbing guide
Thread protector
This part rotates and
[with the dies]
everything else is static
Some of CSG
running
equipment
This handle rotates
the tong
Main motor
that drives
the tong
55. JAM system
Joint Make-up Analysis system
•
JAM - Joint Analyzed Make-Up. Yes it is a computer system that is used to graph each joint on
make up. A load cell is stuck on the tong to snubbing line, this measures torque like the old
torque gauge and a turns counter on tong rotor counts the turns. Computer is set up with
figures of pipe type minimum and optimal torque and shoulder values. Once the joint makes
optimum torque a dump valve will kick in so joint can not be over torqued. Used alot on
chrome and completions.....
•
Also referred to as "torque turn" graph display enables you witness the amount of turns vs
the amount of torque through the connection makeup. Interpretation of these graphs
determine whether the connection makeup is acceptable or not. How the seals engage or
not etc. With todays sophisticated connections with shoulders and seals this practice is
essential.
56. JAM system
Key features:
1. Monitors torque during makeup
2. Controls final torque
3. Records about 1,000 connections
4. Displays torque value
5. User can input different handle lengths
6. 500 samples per second
7. Made for non-premium API connections
8. Torque downloadable to PC after each job
Included hardware:
1. Dump valve cable
2. Power cable
3. CT cable
4. High capacity junction box with pressure transducer
57. JAM chart
axis-1 of your graph shows no. of turns usually to within 1/100 turns
axis-2 generally indexes 3-torques per graph, shoulder torque to where connection "shoulders",
delta torque to where additional torque past shoulder to final torque.
59. WinCatt™
•
•
WinCatt™ is a software tool which interacts with external control hardware to provide real
time monitoring and control of tubular connection power tong make-up. The graphical user
interface and logical software structure combined with powerful control, data acquisition and
presentation capabilities enable the user to easily specify make-up parameters, control the
make-up process and evaluate quality.
WinCatt™ was developed with an emphasis on the user's needs for reliability, accuracy, and
ease of use.
KEY FEATURES ARE:
1. monitors torque, turns, and rotational speed during make-up
2. controls speed during make-up (optional)
3. controls based on either final torque or final turns
4. includes calibration management system
5. includes automatic "Start Recording" & "Dump Valve Release"
6. includes automatic descriptive comments with optional over-ride
7. available with optional pressure test system
62. Back-up slides
•
•
•
•
•
LubraGlide® BEADS
– Advantages, concentrations & Uses
VAM-TOP thread
– Normal VS. high torque
BAKERLOK® Thread-Locking Compound
Dull-bit grading for the 8 ½” bit used in SB305-3A
Diaphragm pump
63. LubraGlide® BEADS
It’s MECHANICAL lubricity in the hole.
Advantages
• Reduces torque and drag
• Reduces casing wear
• Is non-abrasive
• Is recoverable & environmentally safe
• Is thermally stable up to 500°F
• Is compatible with both oil and water base mud
• Is Resistance to deformation is greater than 25,000 psi
hydrostatic,
• Thermally stable down hole to 500°F in a drilling
environment
“CE’’ CO-POLYMER
64. LubraGlide® BEADS
Concentrations:
• Concentrations of 2 – 8 ppb (5.71 – 22.87 Kg/m3)
recommended to control torque and drag
• Concentrations of 8 –12 ppb (22.87 – 34.31 Kg/m3)
recommended for spotting in wire-line operations and
running casing
• The optimum concentration of Lubra-Glide beads is ten
(10) pounds per barrel.
• The volume of fluid to be treated is calculated based on
the volume necessary to cover the open hole from the
bottom of the hole to a point approximately two
hundred (200) feet above the kick off point in the open
hole.
• If the kick off point is already behind casing, then the
entire open hole volume should be treated.
65. LubraGlide® BEADS
Typical Uses for LUBRA-GLIDE CE CO -POLYMER BEADS®
• Spot in hole prior to running casing or liners
• Spot in hole prior to logging operations
• Allows more true weight to bit
• Spot in key seats to reduce torque, drag, and sticking
problems
• Apply LUBRA-GLIDE CE CO-POLYMER BEADS® fine
beads for torque and drag in coil tubing operations or
with work strings
• Lubricant for OBM or SBM
• Aids in prevention of differential sticking when using
OBM or SBM
• Aids in directional changes or sliding
66. Energized metal-to-metal seal
• A patented metal-to-metal seal system offers excellent gastight sealing, under even the most severe combined loads, as
encountered in deviated or long horizontal wells.
• The seal integrity remains constant after repeated make-ups
and break-outs.
• The seal geometry protects against galling.
Improved hook thread design
• A modified hook thread profile with 3° reverse angle on the
load flank, not only provides the connection with superior
tension strength but also increases its resistance to
compression.
• The excellent structural strength including increased bending
and compression resistance, makes this connection especially
suited for highly deviated and long horizontal wells.
• Optimized thread geometry minimizes the risk of galling, even
when thread lubricants are poorly applied.
67. Reverse angle torque shoulder
• A reverse angle torque shoulder provides a positive torque stop which allows for accurate
power-tight make-up and minimizes hoop stresses in the connection.
• The “wedge” effect caused by the reverse angle gives the connection superior structural
strength.
• The shoulder design is optimized in order to resist adverse conditions such as combined
compression and external pressure or combined bending, compression, and torque.
68.
69. VAM® TOP HT
Based on the main features of the VAM® TOP
connection.
This connection provides reinforced torque
capability for liners and where High Torque is
anticipated (torque rotating liner while
running, rotating casing when cementing)
The torque shoulder
dimension on VAM® TOP HT is
significantly larger than VAM
TOP which enables the
connection to withstand
combined load for various
applications using high torque
70.
71. The detailed actual sequence followed on SB305-3A as a guide for future operations
7” OHL OPERATION SUMMARY
72. 7” OHL Operation summary
1.
2.
3.
4.
5.
Conditioning the hole before running
Running the liner
Setting the liner hanger
7” OHL CEMENT JOB
Setting the ZXP packer
73. Conditioning the hole before running
•
•
•
•
On the last trip out of hole before running the liner:
Sweep hole with 50 BBL HVP while rotate and reciprocate string
Continue circulate until returns are cuttings free.
Sweep hole w/ 50 BBL inhibited WBM pill to surface - control sweeping rate while WBM pill
against baba salt to induce more erosion/dissolving to salt.
• Flow check then record torque on BTM with and without pump.
• POH on elevator to casing window and record same parameters again inside casing
• Spot LubraGlide® pill (120 BBLs Hi Vis pill on bottom), observe well stable and POOH.
We used LubraGlide® exclusively in this case to assist in running the casing in through BABA
salt section to avoid sticking potentials.
74. Running the liner
•
•
•
•
•
•
•
•
•
•
Change 5" top ram to 7" ram, retrieve wear bushing, pressure test & close shear ram while
change top ram. Install wear bushing & diverter packer again
M/U baker top drive plug dropping manifold, RU cement surface line, flush, pressure test,
test top drive manifold then LD as one piece.
RU 7" handling equipment.
Apply Bakerlok thread-locking compound to all shoe track connections. Install 1 CENTEC
centralizer per joint
Install insert ball catcher in box of first joint of shoe joint, test float equipment in both
directions.
RIH with 7" liner & install pip tag at the desired depth.
PU & MU 7" baker flex lock rotating liner hanger with ZXP packer & setting tool
Tie back sleeve id =7.375", extension 10 ft
Cont. RIH with 7" liner on HWDP and DP till TD, then PU & MU loaded cement manifold
Circulate 1.5 times string capacity
75. Setting the liner hanger
•
•
•
•
•
•
•
•
•
Drop 1 7/16" bronze ball & chase same till land in landing sub,
Press up to 2,200 psi to set liner HGR,
Bleed pressure to 500 psi,
Confirm HGR set by s/off liner wt + 30 klb.
Press up to 3,400 psi to shear ball seat & release running tool,
Regain circulation with 4 bpm @ 700 psi.
P/u string 3 ft, confirm running tool released (lost liner wt "80 klb").
Slack off string 3 ft (drill pipes slack-off weight = 165 klb) then set 30 klb on liner HGR.
Circulate & rotate liner with while prepare mix fluid.
76. 7” OHL CEMENT JOB
•
•
R/U CMT surface line & test same to 400/4000 psi
Batch mix CMT slurry in 100 BBL batch mixer
Perform cement job as follow:
• Pump 50 bbl 7.0 ppg pre flush w/ 4.0 bpm.
• Pump 50 bbl 11.5 ppg tuned spacer ahead w/ 4.0 bpm.
• With 98 bbl 12.5 ppg batch mixed cement (equivalent to 113 bbl 13 ppg down hole) “g” neat
+ 14% salt (302 sxs) with cement unit with 4.0 bpm.
• Release 5” dp pump down plug (flag tripped).
• Pump 5 bbl 13.0 ppg tuned spacer behind with 4.0 bpm.
• Rotate 7" liner all the time while pumping CMT & displacement w/ 15 rpm
77. Setting the ZXP packer
•
•
•
•
•
P/U string 10 ft to activate ZXP setting dogs sub, slack off 70 klb on ZXP packer, PKR set.
May see surface indication for PKR set [weight indicator greatly disturbed].
Maintain S/O wt. For 5 min on the packer.
Pooh w/ baker liner setting tool ( 600 ft above expected TOC )
Drop foam ball, sweep hole with 50 BBL HVP, normal circulate 1.5 complete cycles while
reciprocate & rotate string with 20 RPM and circulate with high GPM.
78. The detailed actual sequence followed on SB305-3A as a guide for future operations
SCAB LINER OPERATION SUMMARY
79. SCAB liner operation summary
•
•
•
•
•
•
•
MU BAKER TD CMT manifold. RU cement surface line, flush, pressure test same to 500 /
5,000 psi. test top drive manifold / 5" DP single joint using cement unit to 500 / 5,000 psi,
hold, OK, L/D same as one piece to be ready when pick-up again.
RU SAPESCO 7" handling equipment
PU BAKER ported TIE BACK SEAL ASSY. with three seal units, VAM TOP
– 7” baker landing collar,
– Installed insert orifice float valve at box end of the joint that is directly above tie back
seal assy. & function test for insert orifice float valve and float collar.
– Apply BAKER-LOK to all shoe track connections.
– Install one aluminum tabulator each joint.
M/U 7” x 9 5/8” HMC hydraulic set liner hanger, "HMC" 2HR type tie back sleeve (8.9 ft
extension).
R/D 7" scab liner SAPESCO handling equipment.
RIH with 7” scab liner on 5" HWDP & 5" DP .
PU & MU loaded cement manifold.
80. Test for tie back stem & sleeve
•
Circulate with 200 psi and slack off slowly to enter the ported TIE BACK STEM into the liner
TIEBACK SLEEVE until pressure start to increase, stop the pump, mark the pipe (marker#1).
• Continue going down to NO-GO while monitor stabbing of seal unit inside liner tie back
sleeve on martin decker, Slack off 15 klb locating tie back sleeve ring mark the pipe
(marker#2).
• P/U string to normal P/U weight and test tie back stem seal to 500 psi from inside drill pipe,
OK.
• Bleed off pressure to 200 psi and while holding pressure pick up until observe a pressure
drop.
Now we’re sure that the TIE-Back stem seals working OK everything is working fine
• Circulate hole clean while prepare mix fluid and CMT slurry.
81. 7” SCAB liner Cement job
•
•
•
•
•
•
•
•
•
•
•
•
Perform 7" scab liner cement job using HALL CMT unit as follow:
Pump tuned spacer as spacer ahead
Pump cement slurry,
Release 5" DP pump down plug (flag had tripped).
Pump tuned spacer as spacer behind
Displace with 45 bbl., 16 ppg weighted OBM pill
Displace with 10 bbl., 11.2 ppg OBM (pump down plug latch to wiper plug may or may not be
observed).
Displace with 27.5 bbl. 11.2 ppg OBM
Pump 7.5 bbl., 16 ppg tuned spacer , will cover the liner top when drill pipe is out to reduce
contamination with displacing mud.
Displace with 45.5 bbl. 11.2 ppg OBM
Displace with 10 bbl. 11.2 ppg OBM
Bump plug at 1400 psi for 10 min, ok, bleed off pressure while sting in, had no return fluid.
82. Setting the SCAB liner hanger
•
Open lines back to cement unit displacement tanks while sting in with seal assy. Till had 10
klb S/Off WT and confirmed NO-GO (at marker#2),
Pressure up t/3200 psi and set 7" scab liner "HMC" hanger. Slack down liner weight plus 30
klb on setting tool and confirmed hanger set.
Pressure up t/3000 psi and release setting tool, bleed off pressure keeping relief valve open,
check string p/u weight had drill pipe weight confirming RT free.
•
•
•
•
P/U 5 ft with setting tool with no U-tube observed, R/D BAKER TD2 cement manifold, POOH 6
STD'S 5" DP above expected TOC.
Drop Halliburton foam ball and conventionally circulate hole clean max. GPM
POOH W/7'' baker liner running tool to surface and LD same.
PU & MU 8 1/2" clean out assy. To clean-out top of scab liner.