SIST EN ISO 13628-3:2001

Petroleum and natural gas industries - Design and operation of subsea production systems - Part 3: Through flowline (TFL) systems (ISO 13628-3:2000)

La présente partie de l'ISO 13628 définit des exigences et donne des recommandations pour la conception, la fabrication et la mise en oeuvre des équipements et systèmes d'injection TFL.  Les modes opératoires et exigences présentés concernent les équipements de fond à fonctionnement hydraulique, les têtes de puits sous-marines et les suspensions de tube de production ainsi que les lignes de service et les équipements associés.  La présente partie de l'ISO 13628 concerne essentiellement les systèmes d'injection TFL pour les applications en mer et sous-marines mais peut également être utilisée pour d'autres applications telles que les puits fortement déviés ou les puits horizontaux.  La séparation en fond de mer, la surpression, le comptage et les pompes de fond ne sont pas compris dans le domaine d'application de la présente partie de l'ISO 13628.

Erdöl- und Erdgasindustrie - Konstruktion und Betrieb von Unterwasser- Produktionssystemen - Teil 3: Through-flowline (TFL)-Pumpsysteme (ISO 13628-3:2000)

In diesem Teil von ISO 13628 werden Anforderungen an und Empfehlungen für Konstruktion, Fertigung und Betrieb von TFL Ausrüstungen und -pumpsystemen festgelegt.
Es werden Verfahren für und Anforderungen an die hydraulische Wartung der Untertageausrüstung, des Unterwasser Eruptionskreuzes und des Steigrohrhängers sowie der Förderleitungen und der Ausrüstung in den Förderleitungen festgelegt.
Der vorliegende Teil von ISO 13628 gilt vorrangig für TFL Pumpsysteme für Unterwasser Offshore Anwendungen, darf jedoch auch für andere Zwecke angewendet werden, z. B. auf Richtbohrungen mit einer merklichen Ablenkung oder auf Horizontalbohrungen.
Unterwasser Trennung, Druckerhöhung, Messung und Unterwasserpumpen fallen nicht in den Anwendungsbereich dieses Teils von ISO 13628.

Industries du pétrole et du gaz naturel - Conception et exploitation des systemes de production sous-marins - Partie 3: Systemes d'injection TFL (ISO 13628-3:2000)

La présente partie de l'ISO 13628 définit des exigences et donne des recommandations pour la conception, la fabrication et la mise en oeuvre des équipements et systèmes d'injection TFL. Les modes opératoires et exigences présentés concernent les équipements de fond à fonctionnement hydraulique, les têtes de puits sous-marines et les suspensions de tube de production ainsi que les lignes de service et les équipements associés. La présente partie de l'ISO 13628 concerne essentiellement les systèmes d'injection TFL pour les applications en mer et sous-marines mais peut également être utilisée pour d'autres applications telles que les puits fortement déviés ou les puits horizontaux. La séparation en fond de mer, la surpression, le comptage et les pompes de fond ne sont pas compris dans le domaine d'application de la présente partie de l'ISO 13628.

Petroleum and natural gas industries - Design and operation of subsea production systems - Part 3: Through flowline (TFL) systems (ISO 13628-3:2000)

General Information

• Status: Published
• Publication Date: 31-May-2001
• ICS: 75.180.10 - Exploratory, drilling and extraction equipment
• Technical Committee: SS SPL - Technical Board for the general field
• Current Stage: 6060 - National Implementation/Publication (Adopted Project)
• Start Date: 01-Jun-2001
• Due Date: 01-Jun-2001
• Completion Date: 01-Jun-2001
• Ref Project: EN ISO 13628-3:2000 - Petroleum and natural gas industries - Design and operation of subsea production systems - Part 3: Through flowline (TFL) systems (ISO 13628-3:2000)

Overview

EN ISO 13628-3:2000 - "Petroleum and natural gas industries - Design and operation of subsea production systems - Part 3: Through flowline (TFL) systems" provides requirements and recommendations for the design, manufacture and implementation of through flowline (TFL) injection systems used in offshore and subsea wells. The standard covers hydraulic downhole equipment, subsea trees, tubing hangers, production suspensions, service lines and associated surface and subsea equipment for TFL applications. It applies primarily to subsea injection systems but is also applicable to highly deviated or horizontal wells. Not included are seabed separation, overpressure protection, metering/counting and downhole pumps.

Keywords: EN ISO 13628-3:2000, through flowline (TFL) systems, subsea production systems, TFL injection systems.

Key Topics

• System description and components: definition of TFL systems, subsea tree, tubing hanger, diverters and selectors.
• Surface equipment: requirements for pumps, control manifold, control console, lubricator, fluid storage and separators.
• Piping design and fabrication: design criteria, material selection, welding/fabrication practices, hydrostatic and drift testing.
• Pressure rating and testing: guidance on pressure classes, testing procedures and inspection for both surface and subsea components.
• Completion equipment and tools: tubing, packers, circulation members, standing valves and TFL tool design.
• Operations and safety: personnel training, service planning, fluid selection, pumping operations and procedures for returning wells to production.
• Annexes: technical delivery conditions for TFL pipe, example operating pressure calculations, completion types and TFL capabilities.

Keywords: subsea tree, tubing hanger, TFL piping, surface control, testing and inspection.

Applications

EN ISO 13628-3:2000 is used by:

• Subsea and completion engineers designing TFL injection systems for offshore oil & gas fields.
• Equipment manufacturers and fabricators producing subsea trees, tubing hangers, service lines and TFL-specific components.
• Operators planning TFL pumping, well interventions and surface/subsea integration.
• Project managers, procurement and QA teams for specification, testing and acceptance of TFL systems.
• Regulators and standards committees referencing best-practice for safe and reliable subsea injection operations.

Typical applications include seawater or chemical injection via TFL, well stimulation operations, and circulation/control for highly deviated or horizontal wells.

Related Standards

• EN ISO 13628 series (other parts such as ISO 13628-4:1999 on subsea wellhead and tree equipment are cross-referenced).
• Referencing the ISO 13628 family helps ensure consistency across subsea tree, completion and control system design.

Using EN ISO 13628-3:2000 helps teams reduce operational risk, ensure compatibility between surface and subsea equipment, and standardize design, testing and operational practices for through flowline injection systems.

Standards Content (Sample)

SLOVENSKI STANDARD
01-junij-2001
Petroleum and natural gas industries - Design and operation of subsea production
systems - Part 3: Through flowline (TFL) systems (ISO 13628-3:2000)
Petroleum and natural gas industries - Design and operation of subsea production
systems - Part 3: Through flowline (TFL) systems (ISO 13628-3:2000)
Erdöl- und Erdgasindustrie - Konstruktion und Betrieb von Unterwasser-
Produktionssystemen - Teil 3: Through-flowline (TFL)-Pumpsysteme (ISO 13628-3:2000)
Industries du pétrole et du gaz naturel - Conception et exploitation des systemes de
production sous-marins - Partie 3: Systemes d'injection TFL (ISO 13628-3:2000)
Ta slovenski standard je istoveten z: EN ISO 13628-3:2000
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 13628-3
NORME EUROPÉENNE
EUROPÄISCHE NORM
December 2000
ICS 75.180.10
English version
Petroleum and natural gas industries - Design and operation of
subsea production systems - Part 3: Through flowline (TFL)
systems (ISO 13628-3:2000)
Industries du pétrole et du gaz naturel - Conception et Erdöl- und Erdgasindustrie - Konstruktion und Betrieb von
exploitation des systèmes de production sous-marins - Unterwasser- Produktionssystemen - Teil 3: Through-
Partie 3: Systèmes d'injection TFL (ISO 13628-3:2000) flowline (TFL)-Pumpsysteme (ISO 13628-3:2000)
This European Standard was approved by CEN on 7 December 2000.
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 Management Centre 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 Management Centre has the same status as the official
versions.
CEN members are the national standards bodies of Austria, Belgium, Czech Republic, Denmark, Finland, France, Germany, Greece,
Iceland, Ireland, Italy, Luxembourg, Netherlands, Norway, Portugal, 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
© 2000 CEN All rights of exploitation in any form and by any means reserved Ref. No. EN ISO 13628-3:2000 E
worldwide for CEN national Members.

Page 2
CORRECTED  2003-02-05
Foreword
This document (ISO 13628-3:2000) has been prepared by Technical Committee ISO/TC 67
"Materials, equipment and offshore structures for petroleum and natural gas industries" in
collaboration with Technical Committee CEN/TC 12 "Materials, equipment and offshore
structures for petroleum 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 June 2001, and conflicting national
standards shall be withdrawn at the latest by June 2001.
According to the CEN/CENELEC Internal Regulations, the national standards organizations of
the following countries are bound to implement this European Standard: Austria, Belgium, Czech
Republic, Denmark, Finland, France, Germany, Greece, Iceland, Ireland, Italy, Luxembourg,
Netherlands, Norway, Portugal, Spain, Sweden, Switzerland and the United Kingdom.
Endorsement notice
The text of ISO 13628-3:2000 has been approved by CEN as EN ISO 13628-3:2000 without any
modifications.
NOTE Normative references to International Standards are listed in Annex ZA (normative).

Page 3
Annex ZA
(normative)
Normative references to international publications
with their relevant European publications
This European Standard incorporates by dated or undated reference, provisions from other
publications. These normative references are cited at the appropriate places in the text and the
publications are listed hereafter. For dated references, subsequent amendments to or revisions of
any of these publications apply to this European Standard only when incorporated in it by
amendment or revision. For undated references the latest edition of the publication referred to
applies (including amendments).
NOTE Where an International Publication has been modified by common modifications, indicated
by (mod.), the relevant EN/HD applies.
Publication Year Title EN Year
ISO 13628-4 1999 Petroleum and natural gas EN ISO 13628-4 1999
industries - Design and operation of
subsea production systems - Part 4:
Subsea wellhead and tree
equipment
INTERNATIONAL ISO
STANDARD 13628-3
First edition
2000-12-15
Petroleum and natural gas industries —
Design and operation of subsea production
systems
Part 3:
Through flowline (TFL) systems
Industries du pétrole et du gaz naturel — Conception et exploitation des
systèmes de production sous-marins
Partie 3: Systèmes d'injection TFL
Reference number
ISO 13628-3:2000(E)
©
ISO 2000
ISO 13628-3:2000(E)
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ii © ISO 2000 – All rights reserved

ISO 13628-3:2000(E)
Contents Page
Foreword.v
Introduction.vi
1 Scope .1
2 Normative references .1
3 Terms, definitions and abbreviated terms .1
3.1 Terms and definitions .2
3.2 Abbreviated terms .3
4 TFL system.4
4.1 Description of system .4
4.2 TFL components.4
4.3 System/equipment design .5
4.4 Pressure rating.6
5 TFL surface equipment .6
5.1 General.6
5.2 Service pump .9
5.3 TFL control manifold .9
5.4 TFL control console and instrumentation.9
5.5 Lubricator .11
5.6 Fluid storage and working tank.13
5.7 Separator .13
5.8 Testing .13
6 TFL piping system .13
6.1 General.13
6.2 Design .14
6.3 Fabrication.20
6.4 Testing .26
7 Subsea tree, tubing hanger, diverters and selectors.26
7.1 Subsea tree design.26
7.2 Subsea tree testing.35
7.3 Tubing hanger design .35
7.4 Tubing hanger testing .36
7.5 Diverters, deflectors and selectors.36
7.6 Diverter design.42
7.7 Diverter testing.43
8 Completion equipment and tools.43
8.1 General.43
8.2 Completion design.44
8.3 Tubing.44
8.4 Surface-controlled subsurface safety system.44
8.5 Packers .45
8.6 Telescoping joints .45
8.7 Landing nipples .46
8.8 Circulation members .46
8.9 Circulation controls.47
8.10 Standing valves and isolation/production devices.47
8.11 TFL tool design .48
9 Operations.48
ISO 13628-3:2000(E)
9.1 General.48
9.2 Personnel and training.48
9.3 Completion equipment.49
9.4 Satellite well and template well control systems.49
9.5 Service planning and documentation.49
9.6 Fluid selection/well preparation .50
9.7 Pumping operations .50
9.8 Returning well to production.51
10 Summary of capabilities.51
Annex A (normative) TFL pipe .52
A.1 Technical delivery conditions.52
A.2 Dimension and grades .52
A.3 Length .52
A.4 Drift tests .52
A.5 Hydrostatic tests.52
A.6 Marking .52
Annex B (informative) TFL operating pressure.53
B.1 General.53
B.2 Example problem .53
Annex C (informative) TFL completions .58
C.1 General.58
C.2 Single string, single zone, annular circulation completion.58
C.3 Single string, single zone, side string circulation completion.60
C.4 Dual-string, single-zone completion.62
C.5 Dual-string, multi-zone completions.62
Annex D (informative) TFL capabilities .65
D.1 Flow controls.65
D.2 Service work.65
Bibliography .67
iv © ISO 2000 – All rights reserved

ISO 13628-3:2000(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 part of ISO 13628 may be the subject of
patent rights. ISO shall not be held responsible for identifying any or all such patent rights.
International Standard ISO 13628-3 was prepared by Technical Committee ISO/TC 67, Materials, equipment and
offshore structures for petroleum and natural gas industries, Subcommittee SC 4, Drilling and production
equipment.
ISO 13628 consists of the following parts, with the general title Petroleum and natural gas industries — Design and
operation of subsea production systems:
� Part 1: General requirements and recommendations
� Part 2: Flexible pipe systems for subsea and marine applications
� Part 3: Through flowline (TFL) systems
� Part 4: Subsea wellhead and tree equipment
� Part 5: Subsea control umbilicals
� Part 6: Subsea production control systems
� Part 7: Workover/completion riser systems
� Part 8: Remotely Operated Vehicle (ROV) interfaces on subsea production systems
� Part 9: Remotely Operated Tool (ROT) intervention systems
Annex A forms a normative part of this part of ISO 13628. Annexes B, C and D are for information only.
ISO 13628-3:2000(E)
Introduction
This part of ISO 13628 is based on API RP 17C:1991 [5].
The TFL systems and tools described herein permit both horizontal transport and vertical entry into the wellbore.
Users of this part of ISO 13628 should be aware that further or differing requirements may be needed for individual
applications. This part of ISO 13628 is not intended to inhibit a vendor from offering, or the purchaser from
accepting, alternative equipment or engineering solutions for the individual application. This may be particularly
applicable where there is innovative or developing technology. Where an alternative is offered, the vendor should
identify any variations from this part of ISO 13628 and provide details.
vi © ISO 2000 – All rights reserved

INTERNATIONAL STANDARD ISO 13628-3:2000(E)
Petroleum and natural gas industries — Design and operation of
subsea production systems
Part 3:
Through flowline (TFL) systems
1 Scope
This part of ISO 13628 specifies requirements and gives recommendations for the design, fabrication and operation
of TFL equipment and systems.
The procedures and requirements presented are for the hydraulic servicing of downhole equipment, subsea tree
and tubing hanger, and flowlines and equipment within the flowlines.
This part of ISO 13628 primarily addresses TFL systems for offshore, subsea applications but it may also be used
in other applications such as highly-deviated wells or horizontally-drilled wells.
Subsea separation, boosting, metering and downhole pumps are outside the scope of this part of ISO 13628.
2 Normative references
The following normative documents contain provisions which, through reference in this text, constitute provisions of
this part of ISO 13628. For dated references, subsequent amendments to, or revisions of, any of these publications
do not apply. However, parties to agreements based on this part of ISO 13628 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 3183-1, Petroleum and natural gas industries — Steel pipe for pipelines — Technical delivery conditions —
Part 1: Pipes of requirement class A.
ISO 11960, Petroleum and natural gas industries — Steel pipes for use as casing or tubing for wells.
ISO 13628-4:1999, Petroleum and natural gas industries — Design and operation of subsea production systems —
Part 4: Subsea wellhead and tree equipment.
API RP 14E, Design and Installation of Offshore Production Platform Piping Systems.
API Std 1104, Welding of Pipelines and Related Facilities.
3 Terms, definitions and abbreviated terms
For the purposes of this part of ISO 13628, the following terms, definitions and abbreviated terms apply.
ISO 13628-3:2000(E)
3.1 Terms and definitions
3.1.1
bend radius
radius of curvature as measured to the centreline of a conduit
3.1.2
circulation control valve
valve normally placed across the circulation point to allow isolation of the tubing strings or tubing/casing during
production
3.1.3
circulation point
location where communication is established between supply and return fluids for TFL servicing
3.1.4
diverter
device used to direct tools at a branch connection
NOTE Used generically, it refers to that category of equipment which includes deflectors, diverters and selectors.
3.1.5
drift
gauge used to check the minimum radius of curvature and minimum ID of loops, flowline and nipples
3.1.6
H-member
nipple assembly that provides fluid communication and circulation between strings of tubing in the wellbore
3.1.7
loop
curved section of pipe allowing change in direction of TFL flowlines
3.1.8
lubricator
tube and valve assembly that permits tool-strings to be inserted into and removed from a pressurized system
3.1.9
parking system
system whereby tools/equipment for a particular tubing size are transported through a flowline of a larger size by a
transport (carrier) piston string which is left behind or "parked" outside the well while the remaining equipment
continues into the tubing
3.1.10
profile
internal conduit configuration (receptacle) used to engage tools
3.1.11
recess
enlargement in conduit bore, normally concentric with the bore
3.1.12
sealing bore
polished section of conduit that receives a packing element
3.1.13
flowline
service line
line from a platform or land facility to a subsea facility used for TFL servicing
NOTE It may also be used for production or other testing of the well.
2 © ISO 2000 – All rights reserved

ISO 13628-3:2000(E)
3.1.14
flowline signature
service line signature
particular set of pressure pulses (spikes) read or recorded at the surface that identifies a certain point in the
service/flowline or well as tools are pumped past
3.1.15
subsea tree
christmas tree placed at the seabed
3.1.16
TFL piping system
all piping from the surface lubricator through the flowline and tubing to the deepest point in the well to which TFL
tools can be circulated
3.1.17
tubing-retrievable safety valve
downhole safety valve run in the well on tubing
NOTE It is normally surface-controlled and has an ID close to the size of the tubing bore, thereby providing an almost
unrestricted bore.
3.1.18
wye spool
piping section of a subsea tree where the loop joins the vertical tubing bore
3.2 Abbreviated terms
BHP bottom-hole pressure
CCV circulation control valve
EUE external upset end
ID inside diameter
OD outside diameter
SDC side door choke
SCSSV surface-controlled subsurface safety valve
SVLN safety valve landing nipple
TFL through flowline
TRSV tubing-retrievable safety valve
TMD total measured depth
TVD true vertical depth
ISO 13628-3:2000(E)
4 TFL system
4.1 Description of system
The TFL method allows various well servicing operations to be performed by utilizing fluid to transport tools through
flowlines and loops into and out of tubing strings. The differential pressure of the transport fluid across the
tool-string provides the force required to perform the various operations as shown in Figure 1.
Key
1 Tools
2Pistons
Figure 1 — Differential pressure, � p
4.2 TFL components
Figure 2 is a representation of a typical TFL system. The basic components of a system include the surface
equipment, flowlines, subsea tree, TFL service tools and associated downhole equipment. The function of this
system is to provide the means of transport and control of TFL tools. The transportation of tools is provided by the
pumping equipment while the control of these tools is provided by the pumping rate, instrumentation and TFL
control manifold. The basic criteria of a TFL system are
� to have an appropriate pressure rating for the system;
� to provide necessary volumes of fluid required by the TFL operations;
� to control the equipment within operating specifications.
4 © ISO 2000 – All rights reserved

ISO 13628-3:2000(E)
Key
1Water 8 Subsea tree
2 Tank 9 TFL bends
3Pump 10 Subsea wellhead
4 Lubricator 11 Circulation point (H-member)
5 Manifold and instrumentation 12 Well
6 Pressure transducers 13 Mudine
7 Flowline/service line 14 Platform
Figure 2 — Typical offshore TFL installation
4.3 System/equipment design
TFL tools (see Figure 3) have been designed to operate in various tubing sizes commonly used in subsea wells.
TFL tool design is dependent upon the tubing ID and the minimum radius of curvature of tube bends. The design of
a TFL piping system shall take into account the internal diameters of the conduit and receptacles and the pressure
ratings of the pipe and tubing. The ID of the service line should be the same as the ID of the downhole tubing
strings, otherwise it should incorporate a parking system. If the ID is too large, fluid will bypass the tool-string piston
units, reducing their force capability and resulting in inaccurate measurement of tool position. Conversely, if the ID
is too small it can prevent tool passage, can cause excessive drag or can damage and wear the tool, seals and
piston units.
Annex A specifies the requirements for TFL pipe and Table A.1 lists pipe ID dimensions that are compatible with
tubing sizes.
ISO 13628-3:2000(E)
Key
1 Piston units
2 Accelerator
3Stem
4 Hydraulic jar
5 Pulling tool
Figure 3 — Typical TFL service string
4.4 Pressure rating
The pressure rating of a TFL system shall be greater than the maximum pressure to be encountered during TFL
operations throughout the life of the installation. As a guide, consideration should be given to practical
combinations of the following:
� maximum static bottom-hole pressure of the well, minus the hydrostatic pressure of the fluids in the TFL
system;
� pressure to overcome frictional losses when circulating fluids and tool-strings;
� pressure required to operate all the TFL devices. This includes not only service tools but also downhole
isolation and plugging equipment;
� hydraulic shocks or surges in the system which may occur during operations such as jarring;
� pressure required to kill the well if the TFL system is to be used to pump well kill fluids into the producing
formation.
Multiple-well systems shall consider the effect of the higher pressure wells in the system.
Additional information about the system pressure rating and TFL fluids is provided in clause 9 and annex B.
5 TFL surface equipment
5.1 General
TFL surface equipment (see Figure 4) includes a service pump, TFL control manifold, TFL control console,
lubricator, fluid storage, separator and piping system. The pump pressure and flow rating should be compatible with
the design of the system, taking into account the tool transport speeds referenced in clause 9 (see Table 1),
tool-string actuation pressures and the fluid bypass that may occur during these operations. Sufficient volume
(see 5.6) should be provided in the tanks and tubing strings to assure that all operations can be handled effectively.
The surface facility (see Figure 5) should provide space to accommodate the TFL facilities, and the equipment
6 © ISO 2000 – All rights reserved

ISO 13628-3:2000(E)
layout should be arranged with due regard to the proximity of the control console, pump, manifolding and lubricator,
and the space needed to easily insert and remove extended-length tool-strings. If this equipment is located on a
drilling/production platform, the use of basic platform equipment (such as high-volume mud pump or kill pump) may
eliminate the need for dedicated equipment.
Dimensions in metres (ft)
Key
1 Production control manifold
2 Threaded quick connection with plug 12 From mixing tank
3 Flowmeter 13 From dry oil tank (optional)
4 High pressure strainer 14 Gas blanket
5 High pressure strainer 15 Fill-up line
6 Choke 16 From separator liquid dump
7 Flowmeter 17 To separator
8 High pressure/high volume triplex pump 18 Optional valve
9 795 l (5 BBL) open tank 19 Optional surface choke arrangement
10 Working tank 20 To production manifold
11 From platform saltwater system (optional) 21 To well
a
Recommended minimum straight level section.
Figure 4 — Example of TFL platform piping
ISO 13628-3:2000(E)
Key
1 Fluid mixing tank
2 Storage tank 9 Control console
3 Work table 10 Entry loops
4 Roller table 11 Diverters
5 Pump unit 12 To other wells in system
6 Surface control manifold 13 Well 3
7 Tool feeders 14 Well 2
8 Dual horizontal lubricator 15 Well 1
Figure 5 — Typical surface equipment arrangements for installations
8 © ISO 2000 – All rights reserved

ISO 13628-3:2000(E)
Table 1 — Recommended flow rates for TFL tools
Nominal tubing ID
mm (in)
50,8 (2) 63,5 (2 1/2) 76,2 (3) 101,6 (4) 127 (5)
Feature
Flow rate
l/min (bbl/min)
Tool transport 318 (2,0) 477 (3,0) 636 (4,0) 795 (5,0) 954 (6,0)
Restricted line
159 (1,0) 159 (1,0) 318 (2,0) 318 (2,0) 318 (2,0)
(max.)
Locating and
79,5 (0,5) 79,5 (0,5) 159 (1,0) 159 (1,0) 159 (1,0)
landing (max.)
5.2 Service pump
Generally, triplex-type positive displacement pumps have been used for TFL operations although slow speed
duplex and high-pressure multi-stage centrifugal pumps have also been successfully used by some operators. The
primary recommendations for the pumps are as follows:
� pressure and flow rate capability should be in accordance with clause 9;
� a relief valve should be provided on the pump discharge to protect the pump and piping system against
over-pressure or hydraulic shocks and surges;
� pump suction piping should have connections for auxiliary tanks or mixing facilities;
� the TFL pump drive should be designed to allow smooth changes to be made over the range of operating
conditions described in clause 9.
5.3 TFL control manifold
Valving arrangements shall be designed to direct pump flow and fluid return to the service lines, tanks, separators,
etc., as needed to perform TFL operations. Piping and valves should be capable of handling the maximum working
pressure of the system. Valves and actuators should be selected to permit rapid line switching (i.e. within 2 s or
less). Valving should provide for return of fluids through an adjustable back pressure regulator or choke and
through flow meters. The regulator or choke is used to regulate back pressure on the return line to control inflow
from the well or fluid loss to the formation during downhole TFL operations.
5.4 TFL control console and instrumentation
Figure 6 shows a typical TFL instrumentation/control console. This instrumentation enables the monitoring of tool
progress, tool operation and well fluid gain or loss. Instrumentation generally includes pressure gauges with strip
chart recorders, pressure transducers located on the lubricator or manifold, and flow rate meters and volume
totalizers on both the pump discharge and return lines. The instrumentation should be designed to withstand the
vibrations and pressure surges that can occur. High-pressure screens or filters should be installed upstream of
turbine flow meters to minimize damage to the meters by debris. Other types of meter may be used without the
need for such filters.
In addition to control console instrumentation, pressure transducers with surface readout may be installed at the
wellhead to assist in monitoring the tool location. Other special tool detection systems may be installed to monitor
the location of a tool as it moves through the TFL system.
ISO 13628-3:2000(E)
Key
1 Dual flow meters and totalizers 8 Hydraulic choke and manifold – control valves
2 Explosion-proof instrumentation box 9 Engine – start, stop and emergency kill
(Class 1 Div 1 Grp 0)
10 Engine – throttle
3 Dual pressure gauges
11 Transmission – gear selector
4 Two-pen strip-chart recorder
12 Totalizer reset
5 Chart recorder on/off switch
13 Power-on switch
6 Power-off switch
14 Totalizer reset
7 Monitoring gauges (engines, pumps and transmission)
15 Back-pressure control
Pump – oil temperature
Pump – oil pressure
Back-pressure signal
Transmission – oil temperature
Transmission – oil pressure
Engine – water temperature
Engine – oil pressure
Engine – tachometer
System hydraulic pressure
System air pressure
Figure 6 — Typical TFL instrumentation control console
10 © ISO 2000 – All rights reserved

ISO 13628-3:2000(E)
5.5 Lubricator
5.5.1 General
A lubricator allows tool-strings to be inserted into and removed from a pressurized system. Generally, a TFL
lubricator consists of a horizontal launch tube section 6 m to 18 m (20 ft to 60 ft) long with quick-connecting unions
at the ends, a full-opening block valve, bleed valves and a connection for pumping fluid into the lubricator. Figure 7
shows the principal features of the lubricator.
During some fishing and remedial operations that need extended-length tool-strings, it may be necessary to use the
service line to the subsea tree as part of the lubricator. The line pressure shall be bled off during each use.
Key
1 Quick union or flange 6Sumps
2 Bleed valve 7 Bull plug assembly with quick union
3 Full-opening valve 8Valve
4Oversizedtube 9 Tool direction
5 Pipeline
Figure 7 — Typical lubricator skid
5.5.2 Design
A primary consideration in designing a TFL lubricator is preventing ID reductions or misalignments that could
impede tool passage or cause seal damage or other tool damage. The lubricator ID should be sufficiently larger
than the flowline ID, in order to permit the tools to be loaded and removed easily, but not so oversized that a high
pump rate would be required to move the tools from the lubricator into the flowline. In general, if the lubricator ID is
1,6 mm to 4,8 mm (1/16 in to 3/16 in) larger than the service line nominal ID, these criteria will be satisfied.
As a safety feature, pressure bleed-off valves should be provided at both ends of the lubricator launch tube to
ensure blow-down of pressure on both sides of the tool-string before removing the tool from the lubricator. The
design should allow collection of excess fluids from the lubricator. Branch connections should be located so as to
ensure the tool-string can be launched and will not slam into the lubricator end when it returns to the surface. A
power-assisted tool feeder (providing push/pull) and work tables may be necessary for loading and/or removing
larger/longer tool-string sizes (see Figure 8).
ISO 13628-3:2000(E)
Key
1 Hydraulic tool feeder 4 Roller table
2 Entry loops 5 Working tank
3Diverters 6 Horizontal lubricator
Figure 8 — TFL surface equipment
12 © ISO 2000 – All rights reserved

ISO 13628-3:2000(E)
5.5.3 Fabrication
The lubricator piping shall be designed and fabricated in accordance with API RP 14E and clause 6.
5.6 Fluid storage and working tank
A working tank or other fluid storage vessel should be provided in the surface facilities. The storage capacity should
be at least equal to the volume of the flowlines and tubing strings. However, if the available space restricts the size
of the tank, and if make-up liquid is available, and if excess fluids can be safely disposed of, smaller tanks may be
used. A working tank is very useful for keeping track of allowances for lost circulation or well fluid influx. A split
6,3 m (40 bbl) tank (see Figure 8 ) has been found to be a workable size for this function. The working fluid type
may vary (diesel, dead crude, inhibited water or brine, etc.) and suitable connections should be available to access
these sources. Special precautions shall be taken to satisfy the relevant area classification when using crude oil or
handling fluid returns.
5.7 Separator
A separator is generally required to remove gas from the return stream. Removal of the gas helps to obtain
repeatable performance in tool operations and tool location and is covered further in clause 9.
The separator should be sized and pressure-rated as appropriate to handle the well fluids, the maximum pumping
rate and any fluid surges when switching flow paths during TFL operations.
5.8 Testing
The entire TFL platform facility assembly (see Figure 4) should be pressure tested in accordance with API RP 14E.
In addition, the ID of the piping through which TFL tools are to pass should be gauged using the tests described in
clause 6.
6 TFL piping system
6.1 General
The TFL piping system consists of the following:
a) the surface piping between the lubricator and the top of riser;
b) the riser from the seabed;
c) a relatively straight flowline section;
d) the preformed TFL loops or bends used to change tool direction in restricted spaces;
e) the subsea tree;
f) the tubing string, downhole accessories and their end connections.
All piping connectors and connecting methods shall provide free, unrestricted passage of tools and shall not cause
damage to either metallic seals or non-metallic seals on the TFL tools, TFL pistons or other TFL tool-string
components.
ISO 13628-3:2000(E)
6.2 Design
6.2.1 Piping
6.2.1.1 General
TFL pipe shall be either a rigid metallic tubular or a flexible tubular, the latter being constructed of composites of
metallic and non-metallic materials.
6.2.1.2 Materials
Various metal grades have been used for TFL piping, including carbon steel (ISO 3183-1 and ISO 3183-2 [6]),
austenitic-ferritic ("duplex") stainless steel, martensitic stainless steel ("13-chrome"), and others.
More detailed information on the appropriate materials can be found in API RP 17A [4] and ISO 13628-1 [8] for
subsea production control systems and in ISO 10420 [7] for flexible pipe.
6.2.1.3 Diameters
Except as noted below, the flowline(s) and other straight portions of the piping system shall have the same
minimum ID and maximum ID as the well tubing string(s) (see Table A.1); this practice minimizes the amount of
fluid bypassing between the TFL pistons and the pipe wall and improves TFL tool-positioning control. There are
situations, however, when the flowline ID must be larger than the well tubing. This occurs when flowlines are
particularly long, and large IDs are needed in order to reduce the pressure drop along the line. For this case, a
parking system should be employed as is shown in Figure 9. A large diameter TFL tool carrier transports the
downhole service tool-string to the subsea wellhead and releases or picks up the smaller diameter downhole tool-
string.
14 © ISO 2000 – All rights reserved

ISO 13628-3:2000(E)
Key
1 Carrier string
2Parkinglatch
3 Service tool-string
Figure 9 — Parking system
© ISO 2
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