1 api introduction standards
DESCRIPTION
API Introduction StandardsTRANSCRIPT
Slide 1Well Design – Spring 2011
Prepared by: Tan Nguyen
Casing Design
Choosing the correct size, type, and amount of casing that is used in well construction is of utmost importance to the success of the well. The casing must be of sufficient size and strength to allow the target formations to be reached and produced.
Casing has become one of the most expensive parts of a drilling program; the average cost of tubulars is about 18% of the average cost of a completed well. Thus, an important responsibility of the drilling engineer is to design the least expensive casing program that will allow the well to be drilled and operated safely throughout its life
Introduction
The main functions of the casing in any well are:
Maintain hole integrity
Isolate abnormally pressured zones
Protect shallow weak formations from heavier mud weights required in the deeper portions of the hole
Prevent contamination of freshwater-bearing strata
Support unconsolidated sediments
Casing Components
Stop washouts under the drilling rig.
Protect fresh water sands.
To give a base and support for the next string of casing
The conductor pipe is the first casing to be put in place, and is generally installed before the rig arrives on location. Such casing can be driven to 250 feet. Conductor casing measuring between 16 to 24" outside diameter is used onshore, and between 24 to 48" for offshore.
Conductor Casing
Casing Components
Case unconsolidated formations
Support other casings
Case off lost circulation zones
Surface casing is the first string of casing used after the conductor pipe. It is required in some instances by law (to protect ground water) and is normally cemented full length. Surface casing supports the BOP stack and subsequent casing and tubing strings, and is normally the only string designed to carry compression loads.
Casing Components
Surface Casing
Well Design – Spring 2011
Prepared by: Tan Nguyen
Intermediate casing is any string between the surface and production string. Intermediate casing may or may not be cemented full length.
Intermediate casing may be used to:
Seal off weaker zones
Provide support for liner casing.
Intermediate Casing
Casing Components
Well Design – Spring 2011
Prepared by: Tan Nguyen
The fourth but not necessarily the final string of pipe run in the hole is the production casing. The production casing is used to control the hydrocarbon bearing zones that will be produced. This string of pipe adds structural integrity to the wellbore in the producing zones.
Production casing should be set before completing the well for production. It should be cemented in a manner necessary to cover or isolate all zones which contain hydrocarbons.
Production Casing
Casing Components
Mississippi: Not encounter abnormal formation pressure, lost circulation zones, salt sections. Required only conductor casing, surface casing and production casing
Offshore Louisiana and Texas Delaware Basin: Encounter abnormal pore pressure, lost circulation zones, salt sections, unstable shale sections. Required intermediate casing to protect formation below the surface casing from the pressures created by the required high drilling fluid density. Liner is used to lower the cost of drilling. It serves similarly to intermediate casing in that it isolates troublesome zones that tend to cause well problems during drilling operations.
Running Casing
Casing Components
Well Design – Spring 2011
Prepared by: Tan Nguyen
The size of the casing refers to the outside diameter (O.D.) of the main body of the tubular (not the connector). Casing sizes vary from 4.5" to 36" diameter. Tubulars with an O.D. of less than 4.5” are called Tubing.
API Standard
API Standard
Range 1 (R-1): 16 – 25 ft
Range 2 (R-2): 25 – 34 ft
Range 3 (R-3): > 34 ft
Casing is run most often in R-3 lengths to reduce the number of connections in the string. Since casing is made up in single joints, R-3 lengths can be handled easily by most rigs.
Casing Length
API Standard
Well Design – Spring 2011
Prepared by: Tan Nguyen
For each casing size there are a range of casing weights available. The weight of the casing is in fact the weight per foot of the casing and is a representation of the wall thickness of the pipe. There are for instance four different weights of 9 5/8" casing. (Drift diameter refers to the guaranteed minimum ID of the casing.)
Casing Weight
API Standard
Well Design – Spring 2011
Prepared by: Tan Nguyen
In addition to the API grades, certain manufacturers produce their own grades of material. Both seamless and welded tubulars are used as casing although seamless casing is the most common type of casing and only H and J grades are welded.
Casing Grade
API Standard
1: True elastic limit
Proportionality limit:
Up to this amount of stress, stress is proportional to strain (Hooke’s law), so the stress-strain graph is a straight line, and the gradient will be equal to the elastic modulus of the material.
Elastic limit (yield strength):
Beyond the elastic limit, permanent deformation will occur. The lowest stress at which permanent deformation can be measured is defined as yield strength.
Definition of Yield Strength
Well Design – Spring 2011
Prepared by: Tan Nguyen
The chemical composition of casing varies widely, and a variety of compositions and treatment processes are used during the manufacturing process This means that the physical properties of the steel varies widely. The materials which result from the manufacturing process have been classified by the API into a series of “grades”. Each grade is designated by a letter, and a number. The letter refers to the chemical composition of the material and the number refers to the minimum yield strength of the material e.g. N-80 casing has a minimum yield strength of 80000 psi and K-55 has a minimum yield strength of 55000 psi. Hence the grade of the casing provides an indication of the strength of the casing. The higher the grade, the higher the strength of the casing.
Casing Grade
API Standard
Well Design – Spring 2011
Prepared by: Tan Nguyen
Individual joints of casing are connected together by a threaded connection. These connections are variously classified as: API; premium; gastight; and metal-tometal seal. In the case of API connections, the casing joints are threaded externally at either end and each joint is connected to the next joint by a coupling which is threaded internally.
The standard types of API threaded and coupled connection are:
• Short thread connection (STC)
• Long thread connection (LTC)
• Buttress thread connection (BTC)
API Specifications, Standard and Bulletins
API SPEC 5CT, “Specification for casing a tubing”: Covers seamless and welded casing and tubing, couplings, pup joints and connectors in all grades. Processes of manufacture, chemical and mechanical property requirements, methods of test and dimensions are included.
API STD 5B, “Specification for threading, gauging, and thread inspection for casing, tubing, and line pipe threads”: Covers dimensional requirements on threads and thread gauges, stipulations on gauging practice, gauge specifications and certifications, as well as instruments and methods for the inspection of threads of round-thread casing and tubing, buttress thread casing, and extreme-line casing and drill pipe.
API RP 5A5, “Recommended practice for filed inspection of new casing, tubing and plain-end drill pipe”: Provides a uniform method of inspecting tubular goods.
API Standard
API Specifications, Standard and Bulletins
API RP 5B1, “Recommended practice for thread inspection on casing, tubing and line pipe”: The purpose of this recommended practice is to provide guidance and instructions on the correct use of thread inspection techniques and equipment.
API RP 5C1, “Recommended practice for care and use of casing and tubing”: covers use, transportation, storage, handling, and reconditioning of casing and tubing.
API RP5C5, “Recommended practice for evaluation procedures for casing and tubing connections”: Describes tests to be performed to determine the galling tendency, sealing performance and structural integrity of tubular connections.
API BULL 5A2, “Bulletin on thread compounds”: Provides material requirements and performance tests for two grades of thread compound for use on oil-field tubular goods.
API Standard
API Specifications, Standard and Bulletins
API BULL 5C2, “Bulletin on performance properties of casing and tubing”: Covers collapsing pressures, internal yield pressures and joint strengths of casing and tubing and minimum yield load for drill pipe.
API BULL 5C3, “Bulletin on formulas and calculations for casing, tubing, drillpipe and line pipe properties”: Provides formulas used in the calculations of various pipe properties, also background information regarding their development and use.
API BULL 5C4, “Bulletin on round thread casing joint strength with combined internal pressure and bending.”: Provides joint strength of round thread casing when subject to combined bending and internal pressure.
API Standard
Casing Running Procedures
Casing leaks are often caused by damaging the threads while handling and running the casing on the rig. It has also been known for a joint of the wrong weight or grade of casing to be run in the wrong place, thus creating a weak spot in the string. Such mistakes are usually very expensive to repair, both in terms of rig time and materials. It is important, therefore, to use the correct procedures when running the casing.
Rig-Site Operation
Casing Running Procedures
As more joints are added to the string the increased weight may require the use of heavy duty slips (spider) and elevators
If the casing is run too quickly into the hole, surge pressures may be generated below the casing in the open hole, increasing the risk of formation fracture. A running speed of 1000 ft per hour is often used in open hole sections. If the casing is run with a float shoe the casing should be filled up regularly as it is run, or the casing will become buoyant and may even collapse, under the pressure from the mud in the hole.
The casing shoe is usually set 10-30 ft off bottom.
Rig-Site Operation
Liner Running Procedures
Liners are run on drillpipe with special tools which allow the liner to be run, set and cemented all in one trip. The liner hanger is installed at the top of the liner. The hanger has wedge slips which can be set against the inside of the previous string. The slips can be set mechanically (rotating the drillpipe) or hydraulically (differential pressure). A liner packer may be used at the top of the liner to seal off the annulus after the liner has been cemented.
Rig-Site Operation
(a) Run the liner on drillpipe to the required depth;
(b) Set the liner hanger;
(c) Circulate drilling fluid to clean out the liner;
(d) Back off (disconnect) the liner hanger setting tool;
(e) Pump down and displace the cement;
(f) Set the liner packer;
(g) Pick up the setting tool, reverse circulate to clean out cement and pull out of hole.
Rig-Site Operation
Prepared by: Tan Nguyen
Casing Design
Choosing the correct size, type, and amount of casing that is used in well construction is of utmost importance to the success of the well. The casing must be of sufficient size and strength to allow the target formations to be reached and produced.
Casing has become one of the most expensive parts of a drilling program; the average cost of tubulars is about 18% of the average cost of a completed well. Thus, an important responsibility of the drilling engineer is to design the least expensive casing program that will allow the well to be drilled and operated safely throughout its life
Introduction
The main functions of the casing in any well are:
Maintain hole integrity
Isolate abnormally pressured zones
Protect shallow weak formations from heavier mud weights required in the deeper portions of the hole
Prevent contamination of freshwater-bearing strata
Support unconsolidated sediments
Casing Components
Stop washouts under the drilling rig.
Protect fresh water sands.
To give a base and support for the next string of casing
The conductor pipe is the first casing to be put in place, and is generally installed before the rig arrives on location. Such casing can be driven to 250 feet. Conductor casing measuring between 16 to 24" outside diameter is used onshore, and between 24 to 48" for offshore.
Conductor Casing
Casing Components
Case unconsolidated formations
Support other casings
Case off lost circulation zones
Surface casing is the first string of casing used after the conductor pipe. It is required in some instances by law (to protect ground water) and is normally cemented full length. Surface casing supports the BOP stack and subsequent casing and tubing strings, and is normally the only string designed to carry compression loads.
Casing Components
Surface Casing
Well Design – Spring 2011
Prepared by: Tan Nguyen
Intermediate casing is any string between the surface and production string. Intermediate casing may or may not be cemented full length.
Intermediate casing may be used to:
Seal off weaker zones
Provide support for liner casing.
Intermediate Casing
Casing Components
Well Design – Spring 2011
Prepared by: Tan Nguyen
The fourth but not necessarily the final string of pipe run in the hole is the production casing. The production casing is used to control the hydrocarbon bearing zones that will be produced. This string of pipe adds structural integrity to the wellbore in the producing zones.
Production casing should be set before completing the well for production. It should be cemented in a manner necessary to cover or isolate all zones which contain hydrocarbons.
Production Casing
Casing Components
Mississippi: Not encounter abnormal formation pressure, lost circulation zones, salt sections. Required only conductor casing, surface casing and production casing
Offshore Louisiana and Texas Delaware Basin: Encounter abnormal pore pressure, lost circulation zones, salt sections, unstable shale sections. Required intermediate casing to protect formation below the surface casing from the pressures created by the required high drilling fluid density. Liner is used to lower the cost of drilling. It serves similarly to intermediate casing in that it isolates troublesome zones that tend to cause well problems during drilling operations.
Running Casing
Casing Components
Well Design – Spring 2011
Prepared by: Tan Nguyen
The size of the casing refers to the outside diameter (O.D.) of the main body of the tubular (not the connector). Casing sizes vary from 4.5" to 36" diameter. Tubulars with an O.D. of less than 4.5” are called Tubing.
API Standard
API Standard
Range 1 (R-1): 16 – 25 ft
Range 2 (R-2): 25 – 34 ft
Range 3 (R-3): > 34 ft
Casing is run most often in R-3 lengths to reduce the number of connections in the string. Since casing is made up in single joints, R-3 lengths can be handled easily by most rigs.
Casing Length
API Standard
Well Design – Spring 2011
Prepared by: Tan Nguyen
For each casing size there are a range of casing weights available. The weight of the casing is in fact the weight per foot of the casing and is a representation of the wall thickness of the pipe. There are for instance four different weights of 9 5/8" casing. (Drift diameter refers to the guaranteed minimum ID of the casing.)
Casing Weight
API Standard
Well Design – Spring 2011
Prepared by: Tan Nguyen
In addition to the API grades, certain manufacturers produce their own grades of material. Both seamless and welded tubulars are used as casing although seamless casing is the most common type of casing and only H and J grades are welded.
Casing Grade
API Standard
1: True elastic limit
Proportionality limit:
Up to this amount of stress, stress is proportional to strain (Hooke’s law), so the stress-strain graph is a straight line, and the gradient will be equal to the elastic modulus of the material.
Elastic limit (yield strength):
Beyond the elastic limit, permanent deformation will occur. The lowest stress at which permanent deformation can be measured is defined as yield strength.
Definition of Yield Strength
Well Design – Spring 2011
Prepared by: Tan Nguyen
The chemical composition of casing varies widely, and a variety of compositions and treatment processes are used during the manufacturing process This means that the physical properties of the steel varies widely. The materials which result from the manufacturing process have been classified by the API into a series of “grades”. Each grade is designated by a letter, and a number. The letter refers to the chemical composition of the material and the number refers to the minimum yield strength of the material e.g. N-80 casing has a minimum yield strength of 80000 psi and K-55 has a minimum yield strength of 55000 psi. Hence the grade of the casing provides an indication of the strength of the casing. The higher the grade, the higher the strength of the casing.
Casing Grade
API Standard
Well Design – Spring 2011
Prepared by: Tan Nguyen
Individual joints of casing are connected together by a threaded connection. These connections are variously classified as: API; premium; gastight; and metal-tometal seal. In the case of API connections, the casing joints are threaded externally at either end and each joint is connected to the next joint by a coupling which is threaded internally.
The standard types of API threaded and coupled connection are:
• Short thread connection (STC)
• Long thread connection (LTC)
• Buttress thread connection (BTC)
API Specifications, Standard and Bulletins
API SPEC 5CT, “Specification for casing a tubing”: Covers seamless and welded casing and tubing, couplings, pup joints and connectors in all grades. Processes of manufacture, chemical and mechanical property requirements, methods of test and dimensions are included.
API STD 5B, “Specification for threading, gauging, and thread inspection for casing, tubing, and line pipe threads”: Covers dimensional requirements on threads and thread gauges, stipulations on gauging practice, gauge specifications and certifications, as well as instruments and methods for the inspection of threads of round-thread casing and tubing, buttress thread casing, and extreme-line casing and drill pipe.
API RP 5A5, “Recommended practice for filed inspection of new casing, tubing and plain-end drill pipe”: Provides a uniform method of inspecting tubular goods.
API Standard
API Specifications, Standard and Bulletins
API RP 5B1, “Recommended practice for thread inspection on casing, tubing and line pipe”: The purpose of this recommended practice is to provide guidance and instructions on the correct use of thread inspection techniques and equipment.
API RP 5C1, “Recommended practice for care and use of casing and tubing”: covers use, transportation, storage, handling, and reconditioning of casing and tubing.
API RP5C5, “Recommended practice for evaluation procedures for casing and tubing connections”: Describes tests to be performed to determine the galling tendency, sealing performance and structural integrity of tubular connections.
API BULL 5A2, “Bulletin on thread compounds”: Provides material requirements and performance tests for two grades of thread compound for use on oil-field tubular goods.
API Standard
API Specifications, Standard and Bulletins
API BULL 5C2, “Bulletin on performance properties of casing and tubing”: Covers collapsing pressures, internal yield pressures and joint strengths of casing and tubing and minimum yield load for drill pipe.
API BULL 5C3, “Bulletin on formulas and calculations for casing, tubing, drillpipe and line pipe properties”: Provides formulas used in the calculations of various pipe properties, also background information regarding their development and use.
API BULL 5C4, “Bulletin on round thread casing joint strength with combined internal pressure and bending.”: Provides joint strength of round thread casing when subject to combined bending and internal pressure.
API Standard
Casing Running Procedures
Casing leaks are often caused by damaging the threads while handling and running the casing on the rig. It has also been known for a joint of the wrong weight or grade of casing to be run in the wrong place, thus creating a weak spot in the string. Such mistakes are usually very expensive to repair, both in terms of rig time and materials. It is important, therefore, to use the correct procedures when running the casing.
Rig-Site Operation
Casing Running Procedures
As more joints are added to the string the increased weight may require the use of heavy duty slips (spider) and elevators
If the casing is run too quickly into the hole, surge pressures may be generated below the casing in the open hole, increasing the risk of formation fracture. A running speed of 1000 ft per hour is often used in open hole sections. If the casing is run with a float shoe the casing should be filled up regularly as it is run, or the casing will become buoyant and may even collapse, under the pressure from the mud in the hole.
The casing shoe is usually set 10-30 ft off bottom.
Rig-Site Operation
Liner Running Procedures
Liners are run on drillpipe with special tools which allow the liner to be run, set and cemented all in one trip. The liner hanger is installed at the top of the liner. The hanger has wedge slips which can be set against the inside of the previous string. The slips can be set mechanically (rotating the drillpipe) or hydraulically (differential pressure). A liner packer may be used at the top of the liner to seal off the annulus after the liner has been cemented.
Rig-Site Operation
(a) Run the liner on drillpipe to the required depth;
(b) Set the liner hanger;
(c) Circulate drilling fluid to clean out the liner;
(d) Back off (disconnect) the liner hanger setting tool;
(e) Pump down and displace the cement;
(f) Set the liner packer;
(g) Pick up the setting tool, reverse circulate to clean out cement and pull out of hole.
Rig-Site Operation