EN ISO 10405:2006

SLOVENSKI STANDARD
01-maj-2007
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Petroleum and natural gas industries - Care and use of casing and tubing (ISO
10405:2000)
Erdöl- und Erdgasindustrie - Pflege und Gebrauch von Futterrohren und Steigrohren
(ISO 10405:2000)
Industries du pétrole et du gaz naturel - Entretien et utilisation des tubes de cuvelage et
de production (ISO 10405:2000)
Ta slovenski standard je istoveten z: EN ISO 10405:2006
ICS:
75.180.10 Oprema za raziskovanje in Exploratory and extraction
odkopavanje equipment
2003-01.Slovenski inštitut za standardizacijo. Razmnoževanje celote ali delov tega standarda ni dovoljeno.

EUROPEAN STANDARD
EN ISO 10405
NORME EUROPÉENNE
EUROPÄISCHE NORM
November 2006
ICS 75.180.10
English Version
Petroleum and natural gas industries - Care and use of casing
and tubing (ISO 10405:2000)
Industries du pétrole et du gaz naturel - Entretien et Erdöl- und Erdgasindustrie - Pflege und Gebrauch von
utilisation des tubes de cuvelage et de production (ISO Futterrohren und Steigrohren (ISO 10405:2000)
10405:2000)
This European Standard was approved by CEN on 9 November 2006.
CEN members are bound to comply with the CEN/CENELEC Internal Regulations which stipulate the conditions for giving this European
Standard the status of a national standard without any alteration. Up-to-date lists and bibliographical references concerning such national
standards may be obtained on application to the Central Secretariat or to any CEN member.
This European Standard exists in three official versions (English, French, German). A version in any other language made by translation
under the responsibility of a CEN member into its own language and notified to the Central Secretariat has the same status as the official
versions.
CEN members are the national standards bodies of Austria, Belgium, Cyprus, Czech Republic, Denmark, Estonia, Finland, France,
Germany, Greece, Hungary, Iceland, Ireland, Italy, Latvia, Lithuania, Luxembourg, Malta, Netherlands, Norway, Poland, Portugal, Romania,
Slovakia, Slovenia, Spain, Sweden, Switzerland and United Kingdom.
EUROPEAN COMMITTEE FOR STANDARDIZATION
COMITÉ EUROPÉEN DE NORMALISATION
EUROPÄISCHES KOMITEE FÜR NORMUNG
Management Centre: rue de Stassart, 36  B-1050 Brussels
© 2006 CEN All rights of exploitation in any form and by any means reserved Ref. No. EN ISO 10405:2006: E
worldwide for CEN national Members.

Foreword
The text of ISO 10405:2000 has been prepared by Technical Committee ISO/TC 67 "Materials,
equipment and offshore structures for petroleum and natural gas industries” of the International
Organization for Standardization (ISO) and has been taken over as EN ISO 10405:2006 by
Technical Committee CEN/TC 12 "Materials, equipment and offshore structures for petroleum,
petrochemical and natural gas industries", the secretariat of which is held by AFNOR.

This European Standard shall be given the status of a national standard, either by publication of
an identical text or by endorsement, at the latest by May 2007, and conflicting national standards
shall be withdrawn at the latest by May 2007.

According to the CEN/CENELEC Internal Regulations, the national standards organizations of
the following countries are bound to implement this European Standard: Austria, Belgium,
Cyprus, Czech Republic, Denmark, Estonia, Finland, France, Germany, Greece, Hungary,
Iceland, Ireland, Italy, Latvia, Lithuania, Luxembourg, Malta, Netherlands, Norway, Poland,
Portugal, Romania, Slovakia, Slovenia, Spain, Sweden, Switzerland and United Kingdom.

Endorsement notice
The text of ISO 10405:2000 has been approved by CEN as EN ISO 10405:2006 without any
modifications.
INTERNATIONAL ISO
STANDARD 10405
Second edition
2000-03-01
Petroleum and natural gas industries —
Care and use of casing and tubing
Industries du pétrole et du gaz naturel — Entretien et utilisation des tubes
de cuvelage et de production
Reference number
ISO 10405:2000(E)
©
ISO 2000
ISO 10405:2000(E)
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ii © ISO 2000 – All rights reserved

ISO 10405:2000(E)
Contents Page
Foreword.iv
1 Scope .1
2 Normative references .1
3 Terms and definitions .2
4 Running and pulling casing.2
4.1 Preparation and inspection before running.2
4.2 Drifting of casing .3
4.3 Stabbing, making up and lowering .3
4.4 Field makeup.4
4.5 Casing landing procedure .6
4.6 Care of casing in hole .6
4.7 Recovery of casing.6
4.8 Causes of casing trouble .7
5 Running and pulling tubing.9
5.1 Preparation and inspection before running.9
5.2 Stabbing, making up and lowering .11
5.3 Field makeup.11
5.4 Pulling tubing.12
5.5 Causes of tubing trouble .13
6 Transportation, handling and storage.14
6.1 Transportation.15
6.2 Handling.15
6.3 Storage.16
7 Inspection and classification of used casing and tubing.16
7.1 General.16
7.2 Inspection and classification procedures.16
7.3 Pipe wall and threaded-joint conditions.17
7.4 Service rating .18
8 Reconditioning.18
9 Field welding of attachments on casing .18
9.1 General.18
9.2 Requirements for welds .19
9.3 Processes.19
9.4 Filler for arc welding.19
9.5 Preparation of base metal.19
9.6 Preheating and cooling .19
9.7 Welding technique.20
Annex A (informative) SI units .39
ISO 10405:2000(E)
Foreword
ISO (the International Organization for Standardization) is a worldwide federation of national standards bodies (ISO
member bodies). The work of preparing International Standards is normally carried out through ISO technical
committees. Each member body interested in a subject for which a technical committee has been established has
the right to be represented on that committee. International organizations, governmental and non-governmental, in
liaison with ISO, also take part in the work. ISO collaborates closely with the International Electrotechnical
Commission (IEC) on all matters of electrotechnical standardization.
International Standards are drafted in accordance with the rules given in the ISO/IEC Directives, Part 3.
Draft International Standards adopted by the technical committees are circulated to the member bodies for voting.
Publication as an International Standard requires approval by at least 75 % of the member bodies casting a vote.
Attention is drawn to the possibility that some of the elements of this International Standard may be the subject of
patent rights. ISO shall not be held responsible for identifying any or all such patent rights.
International Standard ISO 10405 was prepared by Technical Committee ISO/TC 67, Materials, equipment and
offshore structures for petroleum and natural gas industries, Subcommittee SC 5, Casing, tubing and drill pipe.
This second edition cancels and replaces the first edition (ISO 10405:1993), which has been technically revised.
Annex A of this International Standard is for information only.
iv © ISO 2000 – All rights reserved

INTERNATIONAL STANDARD ISO 10405:2000(E)
Petroleum and natural gas industries — Care and use of casing
and tubing
1 Scope
This International Standard establishes practices for care and use of casing and tubing. It specifies practices for
running and pulling casing and tubing, including drifting, stabbing, making up and lowering, field makeup, drifting
and landing procedures. Also included are causes of trouble, as well as transportation, handling and storage,
inspection and field welding of attachments.
2 Normative references
The following normative documents contain provisions which, through reference in this text, constitute provisions of
this International Standard. For dated references, subsequent amendments to, or revisions of, any of these
publications do not apply. However, parties to agreements based on this International Standard are encouraged to
investigate the possibility of applying the most recent editions of the normative documents indicated below. For
undated references, the latest edition of the normative document referred to applies. Members of ISO and IEC
maintain registers of currently valid International Standards.
ISO 10400:1993, Petroleum and natural gas industries — Formulae and calculation for casing, tubing, drill pipe and
line pipe properties [API Bul 5C3, Bulletin on Formulas and Calculations for Casing, Tubing, Drill Pipe, and Line
Pipe Properties].
ISO 10422:1993, Petroleum and natural gas industries — Threading, gauging, and thread inspection of casing,
tubing and line pipe threads — Specification [API Spec 5B, Specification for Threading, Gauging, and Thread
Inspection of Casing, Tubing, and Line Pipe Threads].
1)
ISO 11960:— , Petroleum and natural gas industries — Steel pipes for use as casing or tubing for wells
[API Spec 5CT, Specification for Casing and Tubing].
2)
API Bul 5A3, Bulletin on Thread Compounds for Casing, Tubing, and Line Pipe.
API Bul 5C2, Bulletin on Performance Properties of Casing, Tubing, and Drill Pipe.
3)
AWS Spec A5.1, Covered Carbon Steel Arc Welding Electrodes.
1) To be published. (Revision of ISO 11960:1996)
2) American Petroleum Institute, 1220 L Street NW, Washington DC, USA.
3) American Welding Society, 550 N.W. LeJeune Rd, PO Box 351040, Miami, FL 33135, USA.
ISO 10405:2000(E)
3 Terms and definitions
For the purposes of this International Standard, the following terms and definitions apply:
3.1
shall
is used to indicate that a provision is mandatory
3.2
should
is used to indicate that a provision is not mandatory, but recommended as good practice
3.3
may
is used to indicate that a provision is optional
4 Running and pulling casing
4.1 Preparation and inspection before running
4.1.1 New casing is delivered free of injurious defects as defined in ISO 11960 or API Specification 5CT and
within the practical limits of the inspection procedures prescribed therein. Some users have found that, for a limited
number of critical well applications, these procedures do not result in casing sufficiently free of defects to meet their
needs for such critical applications. Various nondestructive inspection services have been employed by users to
ensure that the desired quality of casing is being run. In view of this practice, it is suggested that the individual user:
a) Familiarize himself with inspection practices specified in the standards and employed by the respective mills,
and with the definition of “injurious defect” contained in the standards.
b) Thoroughly evaluate any nondestructive inspection to be used by him on tubular goods to assure himself that
the inspection does in fact correctly locate and differentiate injurious defects from other variables that can be
and frequently are sources of misleading “defect” signals with such inspection methods.
4.1.2 All casing, whether new, used or reconditioned, should always be handled with thread protectors in place.
Casing should be handled at all times on racks or on wooden or metal surfaces free of rocks, sand or dirt other
than normal drilling mud. When lengths of casing are inadvertently dragged in the dirt, the threads should be
recleaned and serviced again as outlined in 4.1.7.
4.1.3 Slip elevators are recommended for long strings. Both spider and elevator slips should be clean and sharp
and should fit properly. Slips should be extra long for heavy casing strings. The spider shall be level.
NOTE Slip and tong marks are injurious. Every possible effort should be made to keep such damage at a minimum by
using proper up-to-date equipment.
4.1.4 If collar-pull elevators are used, the bearing surface should be carefully inspected for (a) uneven wear that
may produce a side lift on the coupling with danger of it jumping off, and (b) uniform distribution of the load when
applied over the bearing face of the coupling.
4.1.5 Spider and elevator slips should be examined and watched to see that all lower together. If they lower
unevenly, there is danger of denting the pipe or badly slip-cutting it.
4.1.6 Care shall be exercised, particularly when running long casing strings, to ensure that the slip bushing or
bowl is in good condition. Tongs may be sized to produce 1,5 % of the calculated pullout strength (see ISO 10400
or API Bulletin 5C3, with the units changed to N�m if necessary) (150 % of the guideline torque given in Table 1).
Tongs should be examined for wear on hinge pins and hinge surfaces. The backup line attachment to the backup
post should be corrected, if necessary, to be level with the tong in the backup position so as to avoid uneven load
distribution on the gripping surfaces of the casing. The length of the backup line should be such as to cause
minimum bending stresses on the casing and to allow full stroke movement of the makeup tong.
2 © ISO 2000 – All rights reserved

ISO 10405:2000(E)
4.1.7 The following precautions should be taken in the preparation of casing threads for makeup in the casing
strings:
a) Immediately before running, remove thread protectors from both field and coupling ends and clean the threads
thoroughly, repeating as additional rows become uncovered.
b) Carefully inspect the threads. Those found damaged, even slightly, should be laid aside unless satisfactory
means are available for correcting thread damage.
c) The length of each piece of casing shall be measured prior to running. A steel tape calibrated in millimetres
(feet) to the nearest 3,0 mm (0,01 ft) should be used. The measurement should be made from the outermost
face of the coupling or box to the position on the externally threaded end where the coupling or the box stops
when the joint is made up power-tight. On round-thread joints, this position is to the plane of the vanish point
on the pipe; on buttress-thread casing, this position is to the base of the triangle stamp on the pipe; and on
extreme-line casing, this position is to the shoulder on the externally threaded end. The total of the individual
lengths so measured will represent the unloaded length of the casing string. The actual length under tension in
the hole can be obtained by consulting graphs that are prepared for this purpose and are available in most
pipe handbooks.
d) Check each coupling for makeup. If the standoff is abnormally great, check the coupling for tightness. Tighten
any loose couplings after thoroughly cleaning the threads and applying fresh compound over entire thread
surfaces, and before pulling the pipe into the derrick.
e) Before stabbing, liberally apply thread compound to the entire internally and externally threaded areas. It is
recommended that a thread compound that meets the performance objectives of API Bulletin 5A3 be used;
however, in special cases where severe conditions are encountered, it is recommended that high-pressure
silicone thread compounds as specified in API Bulletin 5A3 be used.
f) Place a clean thread protector on the field end of the pipe so that the thread will not be damaged while rolling
pipe on the rack and pulling into the derrick. Several thread protectors may be cleaned and used repeatedly for
this operation.
g) If a mixed string is to be run, check to determine that appropriate casing will be accessible on the pipe rack
when required according to the programme.
h) Connectors used as tensile and lifting members should have their thread capacity carefully checked to ensure
that the connector can safely support the load.
i) Care should be taken when making up pup joints and connectors to ensure that the mating threads are of the
same size and type.
4.2 Drifting of casing
4.2.1 It is recommended that each length of casing be drifted for its entire length just before running, with
mandrels conforming to ISO 11960 or API Specification 5CT. Casing that will not pass the drift test should be laid
aside.
4.2.2 Lower or roll each piece of casing carefully to the walk without dropping. Use rope snubber if necessary.
Avoid hitting casing against any part of derrick or other equipment. Provide a hold-back rope at the window. For
mixed or unmarked strings, a drift or “jack” rabbit should be run through each length of casing when it is picked up
from the catwalk and pulled onto the derrick floor to avoid running a heavier length or one with a lesser inside
diameter than called for in the casing string.
4.3 Stabbing, making up and lowering
4.3.1 Do not remove thread protector from field end of casing until ready to stab.
ISO 10405:2000(E)
4.3.2 If necessary, apply thread compound over the entire surface of threads just before stabbing. The brush or
utensil used in applying thread compound should be kept free of foreign matter, and the compound should never
be thinned.
4.3.3 In stabbing, lower casing carefully to avoid injuring threads. Stab vertically, preferably with the assistance
of a man on the stabbing board. If the casing stand tilts to one side after stabbing, lift up, clean and correct any
damaged thread with a three-cornered file, then carefully remove any filings and reapply compound over the thread
surface. After stabbing, the casing should be rotated very slowly at first to ensure that threads are engaging
properly and not cross-threading. If spinning line is used, it should pull close to the coupling.
NOTE Recommendations in 4.3.4 and 4.4.1 for casing makeup apply to the use of power tongs. For recommendations on
makeup of casing with spinning lines and conventional tongs, see 4.4.2.
4.3.4 The use of power tongs for making up casing made desirable the establishment of recommended torque
values for each size, mass and grade of casing. Early studies and tests indicated that torque values are affected by
a large number of variables, such as variations in taper, lead, thread height and thread form, surface finish, type of
thread compound, length of thread, mass and grade of pipe, etc. In view of the number of variables and the extent
that these variables, alone or in combination, could affect the relationship of torque values versus made-up
position, it was evident that both applied torque and made-up position have to be considered. Since the joint pullout
strength formula in API Bulletin 5C2 contains several of the variables believed to affect torque, using a modified
formula to establish torque values was investigated. Torque values obtained by taking 1 % of the calculated pullout
value were found to be generally comparable to values obtained by field makeup tests using API modified thread
compound in accordance with API Bulletin 5A3. Compounds other than API modified thread compound may have
other torque values. This procedure was therefore used to establish the makeup torque values listed in Table 1. All
values are rounded to the nearest 10 N�m (10 ft·lbf). These values shall be considered as a guide only, due to the
very wide variations in torque requirements that can exist for a specific connection. Because of this, it is essential
that torque be related to made-up position as outlined in 4.4.1. The torque values listed in Table 1 apply to casing
with zinc-plated or phosphate-coated couplings. When making up connections with tin-plated couplings, 80 % of
the listed value can be used as a guide. The listed torque values are not applicable for making up couplings with
PTFE (polytetrafluoroethylene) rings. When making up round thread connections with PTFE rings, 70 % of the
listed values are recommended. Buttress connections with PTFE seal rings may make up at torque values different
from those normally observed on standard buttress threads.
NOTE Thread galling of gall-prone materials (martensitic chromium steels, 9 Cr and 13 Cr, duplex stainless steels and Ni
base alloys) occurs during movement — stabbing or pulling and makeup or breakout. Galling resistance of threads is primarily
controlled in two areas — in surface preparation and finishing during manufacture and in careful handling practices during
running and pulling.
Threads and lubricant shall be clean. Assembly in the horizontal position should be avoided. Connections should
be turned by hand to the hand-tight position before slowly power-tightening. The procedure should be reversed for
disassembly.
4.4 Field makeup
4.4.1 The following practice is recommended for field makeup of casing:
a) For round thread, 114,3 mm (4 1/2-in) to 339,7 mm (13 3/8-in) outside diameter (OD):
1) It is advisable when starting to run casing from each particular mill shipment to make up sufficient joints to
determine the torque necessary to provide proper makeup. See 4.4.2 for the proper number of turns
beyond hand-tight position. These values may indicate that a departure from the values listed in Table 1 is
advisable. If other values are chosen, the minimum torque should be not less than 75 % of the value
selected. The maximum torque should be not more than 125 % of the selected torque.
2) The power tong should be provided with a reliable torque gauge of known accuracy. In the initial stages of
makeup, any irregularities of makeup or in speed of makeup should be observed, since these may be
indicative of crossed threads, dirty or damaged threads, or other unfavourable conditions. To prevent
galling when making up connections in the field, the connections should be made up at a speed not to
exceed 25 r/min.
4 © ISO 2000 – All rights reserved

ISO 10405:2000(E)
3) Continue the makeup, observing both the torque gauge and the approximately position of the coupling
face with respect to the thread vanish point position.
4) The torque values shown in Tables 1 and 2 have been selected to give recommended makeup under
normal conditions and should be considered as satisfactory providing the face of the coupling is flush with
the thread vanish point or within two thread turns, plus or minus, of the thread vanish point.
5) If the makeup is such that the thread vanish point is buried two thread turns and 75 % of the torque shown
in Table 1 is not reached, the joint should be treated as a questionable joint as provided in 4.4.3.
6) If several threads remain exposed when the listed torque is reached, apply additional torque up to 125 %
of the value shown in Table 1. If the standoff (distance from the face of the coupling to the thread vanish
point) is greater than three thread turns when this additional torque is reached, the joint should be treated
as a questionable joint as provided in 4.4.3.
b) For buttress thread casing connections in sizes 114,3 mm (4 1/2-in) to 508,0 mm (20-in) OD, makeup torque
values should be determined by carefully noting the torque required to make up each of several connections to
the base of the triangle. Then using the torque value thus established, make up the balance of the pipe of that
particular weight and grade in the string.
c) For round thread, 406,4 mm (16-in), 473 mm (18 5/8-in) and 508 mm (20-in) OD:
1) Makeup of 406,4 mm (16-in), 473 mm (18 5/8-in) and 508 mm (20-in) OD shall be to a position on each
connection represented by the thread vanish point or the base of the triangle using the minimum torque
shown in Table 1 as a guide.
On 8-round-thread casing, a 9,5 mm (3/8-in) equilateral triangle is die-stamped at a distance of
L + 1,6 mm (1/16 in) from each end (for L , see Figure 2.1 in ISO 10422:1993 or API Spec 5B). The base
4 4
of the triangle will aid in locating the thread vanish point for basic power-tight makeup; however, the
position of the coupling with respect to the base of the triangle shall not be a basis for acceptance or
rejection of the product. Care shall be taken to avoid cross-threading in starting these larger connections.
The tongs selected should be capable of attaining high torques [67 800 N�m (50 000 ft·lbf)] for the entire
run. Anticipate that maximum torque values could be five times the minimum experienced in makeup to
the recommended position.
2) Joints that are questionable as to their proper makeup in item a) 5) or a) 6) should be unscrewed and laid
down to determine the cause of improper makeup. Both the pipe thread and mating coupling thread
should be inspected. Damaged threads or threads that do not comply with the specification should be
repaired. If damaged or out-of-tolerance threads are not found to be the cause of improper makeup, then
the makeup torque should be adjusted to obtain proper makeup [see item a) 1)]. It should be noted that a
thread compound with a coefficient of friction substantially different from common values may be the
cause of improper makeup.
4.4.2 When conventional tongs are used for casing makeup, tighten with the tongs to the proper degree of
tightness. The joint should be made up beyond the hand-tight position at least three turns for sizes 114,3 mm
(4 1/2 in) to 117,8 mm (7 in), and at least three-and-one-half turns for sizes 193,7 mm (7 5/8 in) and larger, except
244,5 mm (9 5/8 in) and 273,1 mm (10 3/4-in) grade P-110, and 508 mm (20-in) grade J-55 and K-55, which should
be made up four turns beyond the hand-tight position. When using a spinning line, it is necessary to compare hand
tightness with spin-up tightness. In order to do this, make up the first few joints to the hand-tight position, then back
off and spin up joints to the spin-up tight position. Compare the relative positions of these two makeups and use
this information to determine when the joint is made up the recommended number of turns beyond hand tight.
4.4.3 Joints that are questionable as to their proper tightness should be unscrewed and the casing laid down for
inspection and repair. When this is done, the mating coupling should be carefully inspected for damaged threads.
Parted joints should never be re-used without shopping or regauging, even though the joints may have little
appearance of damage.
4.4.4 If casing has a tendency to wobble unduly at its upper end when making up, indicating that the thread may
not be in line with the axis of the casing, the speed of rotation should be decreased to prevent galling of threads. If
ISO 10405:2000(E)
wobbling persists despite the reduced rotational speed, the casing should be laid down for inspection. Serious
consideration should be given before using such casing in a position in the string where a heavy tensile load is
imposed.
4.4.5 In making up the field joint, it is possible for the coupling to make up slightly on the mill end. This does not
indicate that the coupling on the mill end is too loose but simply that the field end has reached the tightness with
which the coupling was screwed on at the manufacturer’s facility.
4.4.6 Casing strings should be picked up and lowered carefully and care exercised in setting slips to avoid shock
loads. Dropping a string even a short distance may loosen couplings at the bottom of the string. Care should be
exercised to avoid setting casing down on its bottom end or otherwise placing it in compression because of the
danger of buckling, particularly in that part of the well where hole enlargement has occurred.
4.4.7 Definite instructions should be available as to the design of the casing string, including the proper location
of the various grades of steel, weights of casing and types of joint. Care should be exercised to run the string in
exactly the order in which it was designed. If any length cannot be clearly identified, it should be laid aside until its
grade, its weight or the type of joint can be positively established.
4.4.8 To facilitate running and to ensure adequate hydrostatic head to contain reservoir pressures, the casing
should be periodically filled with mud while being run. A number of things govern the frequency with which filling
should be accomplished: weight of pipe in the hole, mud weight, reservoir pressure, etc. In most cases, filling every
six to ten lengths should suffice. The hydrostatic balance of reservoir pressure should not be jeopardized by too
infrequent filling. Filling should be done with mud of the proper weight, using a conveniently located hose of
adequate size to expedite the filling operation. A quick-opening/quick-closing plug valve on the mud hose will
facilitate the operation and prevent overflow. If rubber hose is used, it is recommended that the quick-closing valve
be mounted where the hose is connected to the mud line, rather than at the outlet end of the hose. It is also
recommended that at least one other discharge connection be left open on the mud system to prevent buildup of
excessive pressure when the quick-closing valve is closed while the pump is still running. A copper nipple at the
end of the mud hose may be used to prevent damaging the coupling threads during the filling operation.
NOTE The foregoing mud fill-up practice will be unnecessary if automatic fill-up casing shoes and collars are used.
4.5 Casing landing procedure
Definite instructions should be provided for the proper string tension, also on the proper landing procedure after the
cement has set. The purpose is to avoid critical stresses or excessive and unsafe tensile stresses at any time
during the life of the well. In arriving at the proper tension and landing procedure, consideration should be given to
all factors, such as the well temperature and pressure, the temperature developed due to cement hydration, the
mud temperature and changes of temperature during producing operations. The adequacy of the original tension
safety factor of the string as designed will influence the landing procedure and should be considered. If, however,
after due consideration it is not considered necessary to develop special landing procedure instructions (and this
probably applies to a very large majority of the wells drilled), then the procedure should be followed of landing the
casing in the casing head at exactly the position in which it was hanging when the cement plug reached its lowest
point or “as cemented.”
4.6 Care of casing in hole
Drill pipe run inside casing should be equipped with suitable drill-pipe protectors.
4.7 Recovery of casing
4.7.1 Breakout tongs should be positioned close to the coupling but not too close since a slight squashing effect
where the tong dies contact the pipe surface cannot be avoided, especially if the joint is tight and/or the casing is
light. Keeping a space of one-third to one-quarter of the diameter of the pipe between the tongs and the coupling
should normally prevent unnecessary friction in the threads. Hammering the coupling to break the joint is an
injurious practice. If tapping is required, use the flat face, never the peen face of the hammer, and under no
circumstances should a sledge-hammer be used. Tap lightly near the middle and completely around the coupling,
never near the end or on opposite sides only.
6 © ISO 2000 – All rights reserved

ISO 10405:2000(E)
4.7.2 Great care should be exercised to disengage all of the thread before lifting the casing out of the coupling.
Do not jump casing out of the coupling.
4.7.3 All threads should be cleaned and lubricated or should be coated with a material that will minimize
corrosion. Clean protectors should be placed on the casing before it is laid down.
4.7.4 Before casing is stored or reused, pipe and thread should be inspected and defective joints marked for
shopping and regauging.
4.7.5 When casing is being retrieved because of a casing failure, it is imperative to future prevention of such
failures that a thorough metallurgical study be made. Every attempt should be made to retrieve the failed portion in
the “as-failed” condition. When thorough metallurgical analysis reveals some facet of pipe quality to be involved in
the failure, the results of the study should be reported.
4.7.6 Casing stacked in the derrick should be set on a firm wooden platform and without the bottom thread
protector since the design of most protectors is not such as to support the joint or stand without damage to the field
thread.
4.8 Causes of casing trouble
4.8.1 The more common causes of casing trouble are listed in 4.8.2 to 4.8.17.
4.8.2 Improper selection for the depth and pressures encountered.
4.8.3 Insufficient inspection of each length of casing or of field-shop threads.
4.8.4 Abuse in mill, transportation and field handling.
4.8.5 Nonobservance of good rules in running and pulling casing.
4.8.6 Improper cutting of field-shop threads.
4.8.7 The use of poorly manufactured couplings for replacements and additions.
4.8.8 Improper care in storage.
4.8.9 Excessive torquing of casing to force it through tight places in the hole.
4.8.10 Pulling too hard on a string (to free it). This may loosen the couplings at the top of the string. They should
be retightened with tongs before finally setting the string.
4.8.11 Rotary drilling inside casing. Setting the casing with improper tension after cementing is one of the greatest
contributing causes of such failures.
4.8.12 Drill-pipe wear while drilling inside casing is particularly significant in drifted holes. Excess doglegs in
deviated holes, or occasionally in straight holes where corrective measures are taken, result in concentrated
bending of the casing that in turn results in excess internal wear, particularly when the doglegs are high in the hole.
4.8.13 Wire-line cutting, by swabbing or cable-tool drilling.
4.8.14 Buckling of casing in an enlarged, washed-out uncemented cavity if too much tension is released in
landing.
4.8.15 Dropping a string, even a very short distance.
4.8.16 Leaky joints, under external or internal pressure, are a common cause of trouble, and may be due to the
following:
a) improper thread compound;
ISO 10405:2000(E)
b) undertonging;
c) dirty threads;
d) galled threads due to dirt, careless stabbing, damaged threads, too rapid spinning, overtonging or wobbling
during spinning or tonging operations;
e) improper cutting of field-shop threads;
f) pulling too hard on the string;
g) dropping the string;
h) excessive making and breaking;
i) tonging too high on casing, especially on breaking out (this gives a bending effect that tends to gall the
threads);
j) improper joint makeup at the mill;
k) casing ovality or out-of-roundness;
l) improper landing practice, which produces stresses in the threaded joint in excess of the yield point.
4.8.17 Corrosion, which can damage both the inside and outside of casing, can be recognized by the presence of
pits or holes in the pipe. Corrosion on the outside of casing can be caused by corrosive fluids or formations in
contact with the casing or by stray electric currents flowing out the casing into the surrounding fluids or formations.
Severe corrosion may also be caused by sulfate-reducing bacteria. Corrosion damage on the inside is usually
caused by corrosive fluids produced from the well, but the damage can be increased by the abrasive effects of
casing and tubing pumping equipment and by high fluid velocities such as those encountered in some gas-lifted
wells. Internal corrosion might also be due to stray electric currents (electrolysis) or to dissimilar metals in close
contact (bimetallic galvanic corrosion).
Because corrosion may result from so many different conditions, no simple or universal remedy can be given for its
control. Each corrosion problem shall be treated as an individual case and a solution attempted in the light of the
known corrosion factors and operating conditions. The condition of the casing can be determined by visual or
optical-instrument inspections. Where these are not practical, a casing-caliper survey can be made to determine
the condition of the inside surfaces. No tools have yet been designed for determining the condition of the outside of
casing in a well. Internal casing-caliper surveys indicate the extent, location and severity of corrosion. On the basis
of the industry’s experience to date, the following practices and measures can be used to control corrosion of
casing:
a) Where external casing corrosion is known to occur or stray electric current surveys indicate that relatively high
currents are entering the well, the following practices can be employed:
1) good cementing practices, including the use of centralizers, scratchers and adequate amounts of cement
to keep corrosive fluids from coming into contact with the outside of the casing;
2) electrical insulation of flow lines from wells by the use of nonconducting flange assemblies to reduce or
prevent electric currents from entering the well;
3) the use of highly alkaline mud or mud treated with a bactericide as a completion fluid to help alleviate
corrosion caused by sulfate-reducing bacteria;
4) a properly designed cathodic protection system similar to that used for line pipe, to alleviate external
casing corrosion. Protection criteria for casing differ somewhat from the criteria used for line pipe.
Literature on external casing corrosion or persons competent in this field should be consulted for proper
protection criteria.
8 © ISO 2000 – All rights reserved

ISO 10405:2000(E)
b) Where internal corrosion is known to exist, the following practices can be employed.
1) In flowing wells, packing the annulus with fresh water or low-salinity alkaline muds. (It may be preferable in
some flowing wells to depend upon inhibitors to protect the inside of the casing and the tubing.)
2) In pumping wells, avoiding the use of casing pumps. Ordinarily, pumping wells should be tubed as close to
bottom as practical, regardless of the position of the pump, to minimize the damage to the casing from
corrosive fluids.
3) Using inhibitors to protect the inside of the casing against corrosion.
c) To determine the value and effectiveness of the above practices and measures, cost and equipment-failure
records can be compared before and after application of control measures. Inhibitor effectiveness may also be
checked by means of caliper surveys, v
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