RUWAIS LNG PROJECT
Specification for Field Instruments
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ADNOC GAS
Specification for Field Instruments
COMPANY Contract No.
4700022871
JV TJN RUWAIS Contract No
215122C
Document Class
Class 2
Document Category (for Class 1)
OPERATING CENTER Contract No.
OPERATING CENTER Doc Ref.
1
IFC – Issued for Construction
26-Nov-2024
F. Chalon
0
ICR – Issued for Client Review
27-Jun-2024
F. Chalon
K. Michineau M. Joshi R. Ikeya R. Biju
K. Michineau M. Joshi R. Ikeya R. Biju
S. Deilles F. Kiyoshi
S. Deilles F. Kiyoshi
Rev.
Revision Purpose
Date
Prepared by
Checked by Approved by
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Specification for Field Instruments
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Table of Contents
Contents
Page
1.0
INTRODUCTION… 4
1.1 Scope of the Document … 4 1.2 Holds List … 4 1.3 References … 4 1.4 Definitions and Abbreviations … 5 2.0 AMENDMENTS TO Process Measurement Instrumentation spec. AGES-SP-04-016 … 6 3.0 APPENDIX … 16 3.1 APPENDIX 1 - AGES-SP-04-016 … 16
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Table of Changes compared to previous revision
Paragraph
Modification description
Remarks / Origin
1.3
Reference update
2.0
AGES Reference
2.0 AGES 6.2 Doc reference update
2.0 AGES 6.3 Doc reference update
2.0 AGES 6.7 Requirement for certification
2.0 AGES 7.3 & 7.4
‘Reference project’ note deleted
2.0 AGES 8.2 Thermowell minimum pipe size and immersion
length. ‘Reference project’ note deleted
2.0 AGES 8.4 Temperature transmitter installation
2.0 AGES 8.5
‘Reference project’ note deleted
2.0 AGES 9.2
‘Reference project’ note deleted
2.0 AGES 9.4
‘Reference project’ note deleted
2.0 AGES 10.2.2 2.0 AGES 10.2.4
‘Reference project’ note deleted
‘Reference project’ note deleted
2.0 AGES 10.2.6 ‘Reference project’ note deleted
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1.0
INTRODUCTION
The ADNOC Ruwais LNG Project is a two train, near net-zero electrically driven LNG facility, targeting international markets. The feed gas for the project is supplied from the Habshan Gas Processing Plant via a new export gas pipeline. The plant will have two 4.8 MTPA (nominal capacity) electric driven LNG Trains with associated LNG storage/marine export facilities and utilities.
Figure 1 – Project Context
The ADNOC Ruwais LNG Project foresees the following main components at the facility:
• Onshore LNG Liquefaction facilities for 2 x 4.8 MTPA electrically driven LNG Trains (9.6MTPA total)
• Common facilities including inlet receiving facilities, LNG storage, BOG handling, flare, refrigerant
storage and support buildings.
• Utilities to support the facilities including import power from the national grid.
• Marine facilities for LNG export and bunkering.
1.1
Scope of the Document
This specification amends ADNOC Process Measurement Instrumentation Specification AGES-SP-04-016 which is attached hereto in Appendix 1. Section 2 of this document identifies the amendments to the ADNOC Process Measurement Instrumentation Specification included in Appendix 1.
1.2
Holds List
HOLD
DESCRIPTION
1
2
1.3
References
[1] AGES-SP-04-016 [2] RLNG-000-PM-BOD-2002 [3] RLNG-000-MT-SP-6303
Process Measurement Instrumentation Project Basis of Design Positive Material Identification of Equipment and Piping
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1.4
Definitions and Abbreviations
COMPANY
CONTRACTOR
EPC ADOC POC YOC
ABU DHABI NATIONAL OIL COMPANY (ADNOC) P.J.S.C. TJN Ruwais, Joint Venture of Technip Energies France-Abu Dhabi, JGC Corporation and National Marines Dredging Company (NMDC) Engineering Procurement Construction Abu Dhabi Operating center - National Marines Dredging Company Paris Operating Center - Technip Energies Yokohama Operating center - JGC Corporation
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2.0
AMENDMENTS TO PROCESS MEASUREMENT INSTRUMENTATION SPEC. AGES-SP-04-016
Instructions contained below such as “Add”, “Substitute”, “Revised”, or “New” shall be interpreted as follows:
-
Add: Requirements shall be a continuation of the paragraph in the referenced specification.
-
Substitute: The requirement of the referenced specification shall be replaced in its entirety by the
requirements below.
- Revised: The requirement of the referenced specification shall be revised by the specific wording
below.
- New: A new requirement as described below.
The following sections are amended in AGES-SP-04-016, Rev.1
Section A – General
Sub-section 1.3.2 Abbreviations
Add:
DD
DTM
FEED
Sub-section 2.2
Device Descriptor
Device Type Manager
Front-end Engineering Design
The following ADNOC specifications are substituted with Project documents as detailed below:
AGES Reference
Project Document No.
Project Document Title
AGES-PH-04-001
RLNG-000-IC-PP-0002
Philosophy for Automation & Instrumentation Design
AGES-PH-04-009
RLNG-000-IC-SP-0601
Specification for Packaged Analysers
AGES-SP-04-011
RLNG-000-IC-SP-0661
Specification for Fire & Gas Detectors and Alarming devices
AGES-SP-04-015
RLNG-000-IC-SP-0143
Specification for Machine Monitoring System
AGES-SP-04-017
RLNG-000-IC-SP-0701
AGES-SP-07-004
RLNG-000-MT-SP-2301
Specification for Instrument Installation & Design
Specification for Protective Coating of Equipment, Piping & Structures
AGES-SP-09-002
RLNG-000-PI-SP-1021
Specification Classes Index
for Piping Material Service
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AGES Reference
Project Document No.
Project Document Title
AGES-SP-09-003
RLNG-000-PI-SP-1002
AGES-SP-09-013
RLNG-000-PI-SP-1003
AGES-GL-13-002
RLNG-000-MT-SP-6303
Specification for Valves (Cryogenic & Non- Cryogenic)
Specification for Metallic Pipes, Flanges & Fittings
Positive Material Identification of Equipment and Piping
Section B
Sub-section 6.1
Substitute: ‘All transmitters shall be provided with local LCD indicators.’
by: All transmitters shall be provided with integral LCD indicators.’
Substitute: ‘Unless otherwise specified, all transmitters shall be ‘Smart’ type based on ‘HART’ protocol as minimum.’
by: ‘Unless otherwise specified, all transmitters shall be ‘Smart’ type based on ‘HART 7’ protocol as minimum.’
Substitute: ‘Foundation Field bus Transmitters shall be used where specified in datasheets.’
by: ‘
Substitute: ‘For PCS transmitters H1 Foundation can be used as specified in AGES-PH-04-001’
by: ‘
Add: ‘Spare (unused) cable entries shall be supplied with metallic (stainless steel, brass, etc) plugs. SUPPLIER shall provide plugs with dual Ex certification (Ex db and Ex eb).’
Substitute: ‘Electronic Transmitters shall be provided with an earthing bolt on outer side of housing and an earth terminal inside of termination.’
by: ‘Electronic Transmitters shall be provided with an earthing bolt on outer side of housing and an earth terminal inside the termination box.’
After: ‘Mounting hardware shall be of corrosion resistant 316 SS, for mount-the-transmitter or mount-the- manifold type specified in the data sheet.’
add: ‘Mounting kits shall be supplied by Instrument SUPPLIER. Mounting kits shall be corrosion resistant.’
Add: Smart transmitters shall be capable of transmitting/receiving digital signals from both DCS and a hand- held communicator for configuration and maintenance. Smart transmitters shall be provided with write protection capabilities and shall provide diagnostic information to the DCS HMI and IAMS. HART configuration data (DD/DTM files) shall be provided by SUPPLIER.
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Sub-section 6.2
Substitute:
by: ‘Refer RLNG-000-PM-BOD-2002, Project Basis of Design for engineering units to be used on the Project. Units of measurement for instrument displays and calibration shall be according to the instrument datasheets.’
Sub-section 6.3
Add: ‘Refer RLNG-000-PM-BOD-2002, Project Basis of Design for site environmental conditions.’
Sub-section 6.5 Ingress Protection
Substitute:
‘The equipment minimum IP rating shall be as follows:
a) IP 65 for onshore field environments b) IP 66 for offshore & marine environments c) IP 67 for all water jet areas, splash zones in offshore installations, Sulphur Dust Environments.’
by:
‘The equipment minimum IP rating shall be as follows:
a) IP 65 for onshore field environments b) IP 66 for offshore & marine environments c) IP 67 (in addition to IP 65 / IP 66) for all water jet areas, splash zones in offshore installations, Sulphur Dust Environments.’
Sub-section 6.7 SIL Certification
Substitute:
‘Safety manual shall be provided for SIL rated transmitters.’
by:
‘Safety manual and full assessment reports shall be provided for SIL rated transmitters ‘in addition to SIL certificates.
Add new sub-section:
‘6.8 Process connection sizes
Field instruments’ process connection size shall be selected as specified in Philosophy for Automation & Instrumentation Design, RLNG-000-IC-PP-0002, section 14.3.’
Sub-section 7.1 General
Substitute: ‘Components, equipment and assemblies shall be corrosion resistance.’
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by: ‘Components, equipment and assemblies shall be corrosion and wear resistant.’
Sub-section 7.2 Pressure & Differential Pressure Gauges
Substitute: ‘In general, sensing element of pressure gauges shall be bourdon tube type. For low pressures applications (less than 0.3 barg), it shall be bellows or diaphragm seal type.’
by: ‘In general, sensing element of pressure gauges shall be bourdon tube type. For low pressures applications (less than 0.3 barg), it shall be bellows or diaphragm type. For bourdon tube type, sockets shall be the same material as the bourdon tube welded to the tube using the same filler material (minimum 316 stainless steel required).’
Substitute: ‘The accuracy of the gauge shall be to Class 2A (ASME) or Class 0.6 (BS-EN).’
by: ‘The accuracy of the pressure gauge shall be to Class 2A (ASME) or Class 0.6 (BS-EN) for process service and Class 1A (ASME) or Class 1 (BS-EN) on utility and receiving gauges.’
After: ‘…..Flushing ring shall have 1/2” vent and drain points with individual isolation valves.’
add: ‘Diaphragm seal shall have a 2” flanged process connection for pressure gauges and 3” flanged process connection for differential pressure gauges. The flange shall match the piping class and the diaphragm material shall be 316 SS minimum. Where diaphragm seals are specified without a capillary, the seal shall be furnished with the gauge threaded into the diaphragm housing. When capillary is specified, it shall be 300 series stainless steel with 316 stainless steel armor cover for mechanical protection. The seal material shall be minimum 316 stainless steel.’
Add as item 7.2.d: ‘Receiver gauges for pneumatic signals may have 1/4 inch NPT process connection.’
Add: ‘Gauges operating near zero pressure or subject to vacuum shall have a compound scale. The ranges of pressure gauges are to be based on SUPPLIER’s standard ranges to the greatest extent possible. SUPPLIER shall advise where non-standard ranges may be required. Pressure indicating scales shall be direct reading and multipliers shall not be used.
Dial size shall be 100mm for gauges in direct process/utility service. SUPPLIER shall include for supply of siphons, gauge protectors, snubbers and flushing-ring kits with vent/drain valves and plugs with the pressure gauges as required on the datasheet. Secondary/receiver type gauges not in direct process/utility service (e.g. on gas cylinders, positioners, filter-regulators, buffer air vessels, etc) can be supplied in MANUFACTURER standard dial and process connection sizes with COMPANY approval.’
Sub-section 7.3 Pressure & Differential Pressure Switches
Add: ‘Set point shall be adjustable over the entire range.’
Add: ‘Switch sensing elements shall be 316 SS unless stated otherwise on the data sheets. The pressure switches located in the high-pressure surge applications shall be protected by an internal snubber design.
Add: ‘For pressure and differential pressure switches with chemical seals and capillary, the stainless steel armoured spiral wound capillary shall be provided with minimum 2” flanged connection to process (3” flanged process connection for differential pressure switches). The flange shall match the piping class and the diaphragm material shall be 316 SS minimum. Flushing rings between instrument and process connection shall be provided with complete with drain valves, plugs and isolation block valves by SUPPLIER for testing. Flushing ring material shall be SS 316 as a minimum or higher grade as determined by process medium. Capillary lengths shall be kept to a minimum to avoid coiling excess lengths. Capillary lengths shall be as specified on the data sheet.’
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Add: ‘The following are cases where pressure switches are allowable instead of pressure transmitters subject to COMPANY approval:
• HVAC control systems
• Utility services for alarm only such as cooling water, pump seals, lube oil and air flow
• Burst rupture disc alarm
• Deluge systems
•
Inside enclosures, cabinets or buildings for loss of purge/pressurization alarm
• Low pressure auto-start of auxiliary oil pump on compressor (or other rotating equipment) lube oil
systems due to insufficient response time of transmitters
• Differential pressure across filters used for alarm only
• Low volume tank air pressure alarm used for alarm only
Sub-section 7.4 Pressure & Differential Pressure Transmitters
Add: ‘Set point shall be adjustable over the entire range.’
Add: ‘Pressure Transmitters shall be provided with bleed/test ports for calibration.’
Sub-section 8.1.1 RTD Elements
Substitute: ‘RTD accuracy class shall be Class A (as per IEC 60751) only with Pt-100 (Platinum Resistance at 0°C: 100 Ohms) element.’
by: ‘RTD accuracy class shall be Class A (as per IEC 60751) only with Pt-100 (Platinum Resistance at 0°C: 100 Ohms, 0.00385 temperature coefficient) element.’
Sub-section 8.1.2 Thermocouple Elements
Add at section beginning: ‘RTD elements are suitable and shall be selected for all applications on this Project. Use of thermocouples shall be allowed as an exception only in selected cases (such as the flare package) where thermocouples may be part of the vendor’s package standard design unable to be changed or where not possible to use RTDs.’
Sub-section 8.2 Thermowells
Substitute: ‘Pipe diameter for thermowell installations shall be at least (NPS 6) unless otherwise agreed by COMPANY.’
by : ‘Thermowells shall not be installed in line size less than 4” or mounted on the bottom of any pipe.’
Substitute: ‘Where thermowells are required in line sizes smaller than 6” NB, the thermowell shall be installed in the bend.’
by: ‘Line size below 4” shall be swaged to 4” or the thermowell installed in an elbow.’
Substitute: ‘Thermowell installation shall be as per the below table.
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Wells for insulated vessels and lines shall have extension necks and penetrate a minimum of six inches inside the vessel.
by :
Typical Insertion Lengths for Thermowells:
For thermowell installed on vessel, immersion length shall be 100 mm.
For installation on piping, thermowells immersion length shall be:
•
•
•
for pipe in 4 inch, 50 mm
for pipe above 4 inch and below 12 inch, 100 mm
for pipe above 12 inch, 200 mm
in all cases, the nozzle elevation shall be added to the immersion length for total insertion length of the thermowells.
If calculations for perpendicular insertion or angle insertion result in an acceptable length less than the minimum length in the table above, elbow insertion can be used. The required length of thermowell shall be according to the instrument datasheet.’
Substitute: ‘In columns, thermowells shall be immersed into liquid. Alternatives shall be subject to approval by COMPANY.’
by: ‘In columns and vessels, thermowell insertion length shall be designed to achieve measurement of temperature in the fluid/zone required taking into consideration the associated fabrication limitations or vendor recommendations. The required length of thermowell shall be according to the instrument datasheet.’
Add: ‘SUPPLIER shall be responsible for assuring a fit between the thermowell and the element.’
Add: ‘The flanges shall be of the same material as the thermowell.’
Add: Thermowell nozzle on vessel or line shall be 2”, RF minimum 300# rated.
Sub-section 8.4 Temperature Transmitter
Add: ‘RTDs and Thermocouples shall be connected to field-mounted (or Stanchion mounted at ground level if not accessible) temperature transmitters to convert temperature measurement into 4-20mA, HART format before wiring to ICSS channels. RTDs/Thermocouples shall not be wired directly to I/O channels except when vendor makes such a recommendation for direct wiring in packaged equipment.’
Add new sub-section:
‘8.5 Temperature Switches
The following are cases where switches are allowable instead of temperature transmitters subject to COMPANY approval:
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• Switch contacts that are an integral part of an equipment heater thermostatic contactor or similar
device.
• Over temperature device for cabinets or for panel mounted equipment.
• HVAC control systems
• Switch contacts that are an integral part of a machinery temperature monitor system
• Utility services for alarm only such as cooling water, pump seals, lube oil and air flow’
Sub-section 9.1
Substitute: ‘The design of all level instruments shall include an associated local level gauge to allow range checking and visual level verification over the calibrated range of the instrument.’
by: ‘Where possible, the design of level instruments will include an associated local level gauge to allow range checking and visual level verification over the calibrated range of the instrument.’
Add: ’The following are cases where level switches maybe allowable instead of level transmitters subject to COMPANY approval:
• HVAC control systems
• Utility services for alarm only such as cooling water, pump seals, lube oil and air flow
• Special level devices for steam drum service such as hydrastep type
• Level switches for start/stop of pumps in packaged lift stations.
• Depending on the process application, the level technology used may dictate a point source
measurement instead of a continuous measurement
Float or displacer style level switches shall be mounted on external displacer/float chambers. Direct mounting shall be limited to low pressure storage tanks and vessels.’
Sub-section 9.2 Differential Pressure Type Level Instruments
Substitute: ‘If the instrument is installed above or below the liquid level range, transmitters shall require elevation and/or suppression.’
by: ‘If the instrument is installed above or below the liquid level range, transmitter’s zero reference setting shall require elevation and/or suppression accordingly.
Add: ‘In general, differential pressure transmitters with diaphragm seal and capillary shall be used for continuous level measurement in design temperatures equal to or above -98 °C.’
Sub-section 9.4 GWR Type Level Instruments
Substitute:
‘Each GWR level transmitter shall be installed with adequate isolation, vent and drain valves for test and maintenance purposes.’
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by:
‘When externally mounted on a stand pipe, a GWR level transmitter shall be installed with adequate isolation, vent and drain valves for test and maintenance purposes.’
Substitute: ‘…..service with emulation layer of more than 4”.’
by: ‘…..service with emulsion layer of more than 4”.’
Add: ‘In general, guided wave radar transmitters shall be used for continuous level measurement in design temperatures below -98 °C unless fluid properties dictate that radar technology is not suitable.’
Add: ‘Stilling wells where required shall be included in vessel vendor scope of supply.’
Sub-section 9.7 Float/Displacer Type Level Instruments
Add: ’Float chambers shall be provided with springs to prevent damage to floats. Oversized float chambers with internal float guides are required for bubble point fluids susceptible to boiling and vapor generation. Example: LPG’s, LNG’s etc.’
Add: ’All level stand pipes, bridles and cages shall be provided with 3/4 inch NPT top and bottom valve connections for vents and drains.’
Sub-section 10.2 Differential Pressure (DP) Flow Meters
Sub-section 10.2.1 General
Add: ‘Unless otherwise noted on data sheets or recommended by manufacturer, minimum meter run lengths upstream and downstream from orifice plates, flow nozzles and venture tubes shall be in accordance with 0.5% uncertainty tables in ISO 5167-1 and applicable ASME codes and API MPMS Chapters. 0% uncertainty tables in ISO 5167-1 shall be used for high accuracy applications. Meter run lengths upstream and downstream from other flow meters shall be in accordance with applicable API MPMS Chapters, ASME codes and manufacturer’s recommendations.’
Sub-section 10.2.2 Concentric Square Edge Orifice Plate
Substitute: ‘tapings’
by: ‘tappings’
Add: ‘Tapping connection sizes shall be in accordance with piping specifications. Jacking screws shall be supplied for all orifice flanges.’
Add : ‘Unless otherwise dictated by design requirements for the pipe class, orifice flange taps shall be used for line sizes 2 inches up to and including 12” and radius taps (D and D/2 taps) shall be used for line sizes 14 inches and larger.
Substitute:
‘Meter maximum shall be selected so that normal design flow is about 70-75% of scale, while at the same time maximum design flow shall be at about 90-98% of scale.’
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by:
‘Meter range shall be in accordance with API RP 551.
Sub-section 10.2.4 Eccentric & Segmental Orifice Plate
Add : ‘Radius taps or pipe taps are not acceptable for use with eccentric or segmental orifice plates.’
Sub-section 10.2.4 Integral Orifice Plate
Substitute: ‘The upstream and downstream piping shall be socket welded to the meter body.’
By: The upstream and downstream piping shall be socket welded to the meter body to form a meter run assembly.’
Add: ‘Prefabricated meter run assemblies shall come with the required precise upstream and downstream straight length of pipe required to achieve the optimum flow metering uncertainty. Prefabricated meter run assemblies shall be shipped complete with bolts, nuts, gaskets, any required seals, and wrenches as well as their having all differential pressure taps properly plugged with ANSI 300# MNPT hex head pipe plugs. Meter tube ends shall be capped to prevent the entry of foreign matter before meter run installation in the field.
Each meter run assembly shall be supplied with a full set of documentation including but not limited to calibration certificates, material test certificates, pipe-stress calculations and installation instructions.
Sub-section 10.2.6 Venturi Tubes, Low Loss Tubes and Flow Nozzles
Add : ‘Material for venturi throats shall be minimum 316 stainless steel. Body material for venturis, flow nozzles, other in-line elements and pipe shall be minimum carbon steel. Where the nature of the fluid is such as to require a higher alloy, or other material, it shall be consistent with the piping specification and process design conditions.’
Sub-section 10.2.7 Variable Area Flow Meter (Rotameter)
Substitute:
‘The meters shall always be mounted in a true vertical position and in such a way that strain or stress caused by the weight of unsupported lines or by thermal expansion is prevented.’
by:
‘The meters shall always be mounted within 5° of the vertical position and in such a way that strain or stress caused by the weight of unsupported lines or by thermal expansion is prevented. In exceptional and specific cases, horizontal installation may be used with COMPANY approval.’
Sub-section 10.2.8 Annubars (Averaging Pitot Tubes) Flow Meter
Add (as per Reference Project): ‘Unless they are bi-directional, pitot tubes shall be permanently marked to indicate proper installation position and flow direction. Removable elements shall have blow out prevention. Extra heavy flow elements and/or double ended support shall be used in large diameter pipes or ducts or if
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PAGE 15 OF 73
high flow velocity can cause the element to deflect or vibrate. Elements shall be purged when installed in dirty services.’
Add new sub-section:
‘10.9 Flow Switches
The following are cases where flow switches are allowable instead of flow transmitters subject to COMPANY approval:
• HVAC control systems
• Utility services for alarm only such as cooling water, pump seals, lube oil and air flow
• Flow activation alarm for safety showers
• Analyzer sample systems’
Section C
Sub-section 14.1 General
Add: ‘SUPPLIER shall provide material test certificates according to EN 10204 requirements. EN 10204, 3.1 certificate for pressure retaining parts and EN 10204, 2.2 certificate for other parts.’
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3.0
APPENDIX
3.1
APPENDIX 1 - AGES-SP-04-016
AGES-SP-04-016 – PROCESS MEASUREMENT INSTRUMENTATION
The terms of Contract / Agreement No: CON22-146 shall apply for any disclosure of this document to any third party.
ADNOC Classification: Internal
THE CONTENTS OF THIS DOCUMENT ARE PROPRIETARY AND CONFIDENTIAL.
ADNOC GROUP PROJECTS AND ENGINEERING
PROCESS MEASUREMENT INSTRUMENTATION
SPECIFICATION
APPROVED BY:
NAME: Abdulmunim Al Kindy TITLE: Executive Director PT&CS EFFECTIVE DATE:
AGES-SP-04-016
All parties consent to this document being signed electronically -PT&CS/GP/INT/2021/20121Abdul Munim Al Kindy
ADNOC Classification: Internal ADNOC Classification: Internal
GROUP PROJECTS & ENGINEERING / PT&CS DIRECTORATE
CUSTODIAN
Group Projects & Engineering / PT&CS
ADNOC
Specification applicable to ADNOC & ADNOC Group Companies
REVISION HISTORY
DATE
REV.
NO
PREPARED BY / (Designation
REVIWED BY (Designation
/
Initial)
Initial)
ENDORSED BY (Designation / Initial)
ENDORSED BY (Designation / Initial)
20 Dec 2021
1
Alaaeldin Rabie /
Annamalai
Najem Qamabar/
Ebraheem
SE-I&C
Kulandaivel / SE-
VP Group Eng.
AlRomaithi / SVP-
I&C
GPE
GPE
for Mr. Alaaeldin Rabie
Group Projects & Engineering is the owner of this Specification and responsible for its custody, maintenance and periodic update.
In addition, Group Projects & Engineering is responsible for communication and distribution of any changes to this Specification and its version control.
This specification will be reviewed and updated in case of any changes affecting the activities described in this document.
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INTER-RELATIONSHIPS AND STAKEHOLDERS
a) The following are inter-relationships for implementation of this Specification:
i.
ii.
ADNOC Upstream and ADNOC Downstream Industry, Marketing & Trading Directorate.
ADNOC Onshore, ADNOC Offshore, ADNOC Sour Gas, ADNOG Gas Processing. ADNOC LNG, ADNOC Refining, Fertil, Borouge, Al Dhafra Petroleum, Al Yasat
b) The following are stakeholders for the purpose of this Specification:
ADNOC PT&CS Directorate.
c) This Specification has been approved by the ADNOC PT&CS is to be implemented by each ADNOC Group company included above subject to and in accordance with their Delegation of Authority and other governance-related processes in order to ensure compliance
d) Each ADNOC Group company must establish/nominate a Technical Authority responsible for compliance
with this Specification.
DEFINED TERMS / ABBREVIATIONS / REFERENCES
“ADNOC” means Abu Dhabi National Oil Company.
“ADNOC Group” means ADNOC together with each company in which ADNOC, directly or indirectly, controls fifty percent (50%) or more of the share capital.
“Approving Authority” means the decision-making body or employee with the required authority to approve Policies & Procedures or any changes to it.
“Business Line Directorates” or “BLD” means a directorate of ADNOC which is responsible for one or more Group Companies reporting to, or operating within the same line of business as, such directorate.
“Business Support Directorates and Functions” or “Non- BLD” means all the ADNOC functions and the remaining directorates, which are not ADNOC Business Line Directorates. “CEO” means chief executive officer.
“Group Company” means any company within the ADNOC Group other than ADNOC.
“Specification” means this Process Measurement Instrumentation Specification.
CONTROLLED INTRANET COPY
The intranet copy of this document located in the section under Group Policies on One ADNOC is the only controlled document. Copies or extracts of this document, which have been downloaded from the intranet, are uncontrolled copies and cannot be guaranteed to be the latest version.
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TABLE OF CONTENTS
1
GENERAL … 7
1.1
INTRODUCTION … 7
1.2
PURPOSE … 7
1.3 DEFINITIONS AND ABBREVIATIONS … 7
SECTION A – GENERAL … 10
2
REFERENCE DOCUMENTS … 10
2.1
INTERNATIONAL CODE(S) AND STANDARDS … 10
2.2 ADNOC SPECIFICATIONS … 16
DOCUMENTS PRECEDENCE … 17
SPECIFICATION DEVIATION/CONCESSION CONTROL … 17
PROCESS SAFETY REQUIREMENTS … 17
3
4
5
SECTION B – TECHNICAL REQUIREMENTS … 18
6
DESIGN REQUIREMENTS … 18
6.1 GENERAL … 18
6.2 UNITS OF MEASUREMENT … 20
6.3 ENVIRONMENTAL CONDITIONS … 20
6.4 EMC COMPLIANCE … 21
6.5
INGRESS PROTECTION… 21
6.6 HAZARDOUS AREA CLASSIFICATION: … 21
6.7 SIL CERTIFICATION … 21
7
PRESSURE INSTRUMENTS … 22
7.1 GENERAL … 22
7.2 PRESSURE & DIFFERENTIAL PRESSURE GAUGES … 22
7.3 PRESSURE & DIFFERENTIAL PRESSURE SWITCHES … 23
7.4 PRESSURE & DIFFERENTIAL PRESSURE TRANSMITTERS … 24
8
TEMPERATURE INSTRUMENTS & THERMOWELLS … 25
8.1 TEMPERATURE ELEMENTS … 25
8.2 THERMOWELLS … 28
8.3 TEMPERATURE GAUGES … 30
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8.4
TEMPERATURE TRANSMITTER … 31
9
LEVEL INSTRUMENTS … 31
9.1 GENERAL … 31
9.2 DIFFERENTIAL PRESSURE TYPE LEVEL INSTRUMENTS … 33
9.3 CAPACITANCE/ADMITTANCE LEVEL TYPE INSTRUMENTS … 34
9.4 GWR TYPE LEVEL INSTRUMENTS… 34
9.5 ULTRASONIC TYPE LEVEL INSTRUMENTS… 35
9.6 NUCLEAR TYPE LEVEL INSTRUMENTS … 35
9.7 FLOAT/DISPLACER TYPE LEVEL INSTRUMENTS … 36
9.8 MAGNETIC TYPE INSTRUMENTS… 36
CHAMBER SHALL BE DESIGNED AS PER ANSI B31.3. … 37
9.9 LEVEL GLASS GAUGES … 37
9.10 FLOAT AND TAPE TYPE OF LEVEL GAUGE … 38
10
FLOW INSTRUMENTS … 38
10.1 GENERAL … 38
10.2 DIFFERENTIAL PRESSURE (DP) FLOW METERS … 38
10.3 MASS FLOW METERS … 42
10.4 ULTRASONIC FLOW METERS … 44
10.5 MAGNETIC FLOW METERS … 45
10.6 TURBINE FLOW METERS … 45
10.7 POSITIVE DISPLACEMENT FLOW (PD) METERS … 46
10.8 VORTEX FLOW METER … 47
SECTION C – OTHER REQUIREMENTS … 48
11 DETAILS OF SCOPE OF SUPPLY … 48
12 QUALITY CONTROL AND ASSURANCE … 48
13 CERTIFICATIONS … 49
14
INSPECTION & TESTING REQUIREMENTS … 49
14.1 GENERAL … 49
14.2 SHOP INSPECTION ACCESS … 49
14.3 FACTORY ACCEPTANCE TEST (FAT) … 50
14.4 SITE ACCEPTANCE TEST (SAT) … 50
15
SUBCONTRACTORS/SUBSUPPLIERS … 50
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16
SPARE PARTS … 50
17
PRESERVATION & SHIPMENT … 51
17.1 PACKING AND SHIPPING … 51
17.2 PRESERVATION AND STORAGE … 51
18 COMMISSIONING … 51
18.1 PRE-COMMISSIONING PROCEDURE … 51
18.2 INSTALLATION … 51
18.3 LONG TERM SUPPORT … 51
19
TRAINING … 52
20
DOCUMENTATION/MANUFACTURER DATA RECORDS… 52
21 GUARANTEES & WARRANTY … 53
SECTION D – STANDARD DRAWINGS & DATASHEETS … 54
22 DATA SHEETS TEMPLATES … 54
23
STANDARD DRAWINGS … 55
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1 GENERAL
1.1
Introduction
This specification describes the minimum requirements for the design, engineering, marking, inspection, testing, packing and shipping of Process measurement Instruments and their minimum installation requirements.
1.2 Purpose
This specification shall be applied for the design requirements of:
a) Pressure Measurement Instruments b) Temperature Measurement Instruments c) Level Measurement Instruments d) Flow Measurement Instruments
This specification provides the general requirements for Process measurement Instruments but shall be read in conjunction with the instrument data sheets and purchase order requisition provided at the time of enquiry.
1.3 Definitions and Abbreviations
1.3.1
Definitions
The following defined terms are used throughout this specification:
“COMPANY” means ADNOC, ADNOC Group or an ADNOC Group Company, and includes any agent or consultant authorized to act for, and on behalf of the COMPANY.
“CONTRACTOR” means the parties that carry out all or part of the design, engineering, procurement, construction, commissioning or management for ADNOC projects. CONTRACTOR includes its approved MANUFACTURER(s), SUPPLIER(s), SUB-SUPPLIER(s), and SUB-CONTRACTOR(s).
“MANUFACTURER” means the Original Equipment Manufacturer (OEM) or MANUFACTURER of one or more of the component(s) which make up a sub-assembly or item of equipment assembled by the main SUPPLIER or his nominated SUB-SUPPLIER.
‘may’ means a permitted option
‘shall’ indicates mandatory requirements
‘should’ means a recommendation
“SUB-CONTRACTOR” means any party engaged by the CONTRACTOR to undertake any assigned work on their behalf. COMPANY maintains the right to review all proposed SUB-CONTRACTORs; this right does not relieve the CONTRACTOR of their obligations under the Contract, nor does it create any contractual relationship between COMPANY and the SUB-CONTRACTOR.
“SUPPLIER” means the party entering into a Contract with CONTRACTOR to provide the materials, equipment, supporting technical documents and/or drawings, guarantees, warranties and/or agreed services
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in accordance with the requirements of the purchase order and relevant specification(s). The term SUPPLIER includes any legally appointed successors and/or nominated representatives of the SUPPLIER.
“SUB-SUPPLIER” means the sub-contracted SUPPLIER of equipment sub-components, software and/or support services relating to the equipment / package, or part thereof, to be provided by the SUPPLIER. COMPANY maintains the right to review all proposed SUB-SUPPLIERS, but this right does not relieve the SUPPLIER of their obligations under the Contract, nor does it create any contractual relationship between COMPANY and any individual SUB-SUPPLIER.
“CONCESSION REQUEST” - A deviation requested by the CONTRACTOR or SUPPLIER, usually after receiving the contract package or purchase order. Often, it refers to an authorization to use, repair, recondition, reclaim or release materials, components or equipment already in progress or completely manufactured but which does not meet or comply with COMPANY requirements. A CONCESSION REQUEST is subject to COMPANY approval.
1.3.2
Abbreviations
The abbreviations used throughout this specification are shown in Table 1.1
Table 1.1 List of Abbreviations
Abbreviations
ATEX
Atmospheres Explosibles – European Union Directive 94/9/EC.
CENELEC
European Committee for Electro-Technical Standardization
DCS
DCA
DN
EMC
EMI
EPC
ESD
FANR
FAT
FM
HART
Distributed Control System
Design Change Authorization
Nominal Diameter (metric)
Electro-Magnetic Compatibility
Electro-Magnetic Interference
Engineering Procurement and Construction
Emergency Shutdown System
Federal Authority for Nuclear Regulation
Factory Acceptance Test
Factory Mutual
Highway Addressable Remote Transducer
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IAMS
ICSS
IEC
IP
IS
ITP
LCD
MPMS
MTTF
MTTR
NDT
NPS
NPT
PCS
PMI
PMS
RF
RTJ
SAT
SIL
Instrument Asset Management System
Integrated Control and Safety System
International Electrotechnical Commission
Ingress Protection
Intrinsic Safety
Inspection and Test plan
Liquid Crystal Display
Manual of Petroleum Measurement Standards
Mean Time To Failure’ is the expected time to failure of a system in a
population of identical systems.
Mean Time To Restore’ is the statistical average of time taken to identify and
repair a fault (including diagnosis).
Non-Destructive Testing
Nominal Pipe Size
National Standard Pipe Taper (Thread)
Process Control System
Positive Material Identification
Piping Material Specification
Raised Face
Ring Type Joint
Site Acceptance Test
Safety Integrity Level
SMART
TPI
Single Modular Auto-ranging Remote
Third Party Inspector
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SECTION A – GENERAL
2
REFERENCE DOCUMENTS
2.1
International Code(s) and Standards
The following codes and standards, to the extent specified herein, form a part of this specification. They have been rationalized to avoid duplication between the many regulatory organisations. When an edition date is not indicated for a code or standard, the latest edition in force at the time of SUPPLIER’S proposal submittal shall apply.
Standard
Description
American Gas Association (AGA)
AGA Report 3
Orifice Metering of Natural Gas
AGA Report 7
Measurement of Gas by Turbine Meters
AGA Report 8
Compressibility Factors of Natural Gas and other related Hydrocarbon Gases
AGA Report 9
Measurement of Gas by Multipath Ultrasonic Meters
AGA Report 11
Measurement of Natural Gas by Coriolis Meter
American Petroleum Institute (API)
API RP 551
Process Measurement Instrumentation
API RP 552
Transmission systems
API RP 14C
Analysis, Design, Installation, and Testing of Safety Systems for Offshore Production Facilities
API MPMS 1
Vocabulary
API MPMS 3.1B
Standard Practice for Level Measurement of Liquid Hydrocarbons in Stationary Tanks by Automatic Tank Gauging
API MPMS 5.1
General Considerations for Measurement by Meters
API MPMS 5.2
Measurement of liquid hydrocarbons by displacement meters
API MPMS 5.3
Measurement of Liquid Hydrocarbons by Turbine Meters
API MPMS 5.4
Accessory Equipment for Liquid Meters
API MPMS 5.5
Fidelity and Security of Flow Measurement Pulsed-Data Transmission Systems
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API MPMS 5.6
Measurement of Liquid Hydrocarbons by Coriolis Meters
API MPMS 5.8
Measurement of Liquid Hydrocarbons by Ultrasonic Flow Meters
API MPMS 6.6
Pipeline Metering Systems
API MPMS 6.7
Metering Viscous Hydrocarbons
API MPMS 13.1
Statistical Aspects of Measuring and Sampling Section 1-Statistical Concepts and Procedures in Measurements
API MPMS 13.3
Measurement Uncertainty
API MPMS 14.10
Measurement of Flow to Flares
API MPMS 22.3
Testing Protocol for Flare Gas Metering
API MPMS 14.12
Measurement of Gas by Vortex Meter
API MPMS 14.3.1
Orifice Metering of Natural Gas and Other Related Hydrocarbon Fluids-Concentric, Square-edged Orifice Meters Part 1: General Equations and Uncertainty Guidelines
API MPMS 14.3.2
Orifice Metering of Natural Gas and Other Related Hydrocarbon Fluids - Concentric, Square-edged Orifice Meters
API MPMS 14.3.3
Orifice Metering of Natural Gas and Other Related Hydrocarbon Fluids— Concentric, Square-edged Orifice Meters Part 3: Natural Gas Applications
API MPMS 14.3.4
Orifice Metering of Natural Gas and Other Related Hydrocarbon Fluids— Concentric, Square-edged Orifice Meters Part 4—Background, Development, Implementation Procedure, and Example Calculations
API MPMS 14.9
Measurement of Natural Gas by Coriolis Meter
API MPMS 20.1
Allocation Measurement
API MPMS 20.2
Production Allocation Measurement Using Single-phase Device
API MPMS 20.5
Recommended Practice for Application of Production Well Testing in Measurement and Allocation
American Society of Mechanical Engineers (ASME)
ASME B40.100
Pressure Gauges and Gauge Attachments
ASME B16.5
Pipe Flanges and Flanged Fittings NPS ½ through NPS 24 Metric/Inch Standard
ASME B16.36
Orifice Flanges
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ASME PTC19.3 TW
Thermowells Performance Test Codes
ASME-MFC-1
Glossary of Terms used in the Measurement of Fluid Flow in Pipes
ASME-MFC-2M
Measurement Uncertainty for Fluid Flow in Closed Conduits
ASME-MFC-3M
Measurement of Fluid Flow in Pipes Using Orifice, Nozzle, and Venturi
ASME-MFC-4M
Measurement of Gas Flow by Turbine Meters
ASME-MFC-5.1
Measurement of Liquid Flow in Closed Conduits using Transit-Time Ultrasonic Flowmeters
ASME-MFC-5.3
Measurement of Liquid Flow in Closed Conduits Using Doppler Ultrasonic Flowmeters
ASME-MFC-6
Measurement of Fluid Flow in Pipes Using Vortex Flowmeters
ASME-MFC-7
Measurement of Gas Flow by Means of Critical Flow Venturis and Critical Flow Nozzles
ASME-MFC-8M
Fluid Flow in Closed Conduits: Connections for Pressure Signal Transmissions Between Primary and Secondary Devices
ASME-MFC-9M
Measurement of Liquid Flow in Closed Conduits by Weighing Method
ASME-MFC-10M
Method for Establishing Installation Effects on Flowmeters
ASME-MFC-11
Measurement of Fluid Flow by Means of Coriolis Mass Flowmeters
ASME-MFC-12M
Measurement of Fluid Flow in Closed Conduits Using Multiport Averaging Pitot Primary Elements
ASME-MFC-13M
Measurement of Fluid Flow in Closed Conduits: Tracer Methods
ASME-MFC-14M
Measurement of Fluid Flow Using Small Bore Precision Orifice Meters
ASME-MFC-16
Measurement of Fluid Flow in Closed Conduits with Electromagnetic Flowmeters
ASME-MFC-18M
Measurement of Fluid Flow Using Variable Area Meters
ASME-MFC-19G
Technical Report -Wet Gas Metering Guideline
ASME-MFC-21.1
Measurement of Gas Flow by Means of Capillary Tube Thermal Mass Flowmeters and Controllers
ASME- MFC-1.2
Thermal Mass Meters - Dispersion Flowmeters
ASME- MFC-22
Measurement of Liquid by Turbine Flowmeters
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ASME- MFC-26
Measurement of Gas Flow by Bellmouth Inlet Flowmeters
BRITISH STANDARD (BS)
BS EN 837
Pressure Gauges
BS 3463
BS 8452
Observation and gauge glasses for pressure vessels
Use of clamp-on ultrasonic flow-metering techniques for fluid applications
International Society of Automation (ISA)
ISA- S 71.04
Environmental Conditions for Process Measurements and Control Systems: Air Contaminants
International Electrotechnical Commission (IEC)
IEC 60079
Electrical apparatus for Explosive gas atmospheres (All parts)
IEC 60381
Analogue signals for process control systems
IEC 60529
Degrees of Protection Provided by Enclosures (IP Code)
IEC 60584
Thermocouples
IEC 60751
Industrial platinum resistance thermometers and platinum temperature sensors
EC 60770
Transmitters for use in industrial-process control system
IEC 60947-5-2
Low-voltage switchgear and control gear - Control circuit devices and switching elements - Proximity switches
IEC 61000
Electromagnetic compatibility (EMC) - (All parts)
IEC 61010
Safety requirements for electrical equipment for measurement, control and laboratory use
IEC 61152
Dimensions of Metal-Sheathed Thermometer Elements
EC 61326
IEC 61508
IEC 61511
Electrical equipment requirements
for measurement, control and
laboratory use- EMC
Functional Safety of Electrical, Electronic and Programmable Electronic Safety- Related Systems (All Parts)
Functional Safety-Safety Instrumented Systems for the Process Industry Sector (All Parts)
IEC 61515
Mineral insulated metal-sheathed thermocouple cables and thermocouples
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IEC 62591
IEC 61298
Industrial networks – Wireless communication network and communication profiles – Wireless HART
Process measurement and control devices- General methods and procedures for evaluating performance
European Committee for Electrotechnical Standardization
CENELEC EN 60947- 5-6
Low-Voltage Switchgear and Control gear Part 5-6: Control Circuit Devices and Switching Elements DC Interface for Proximity Sensors and Switching Amplifiers (NAMUR)
International Association of Oil & Gas Producers (IOGP)
IOGP 547
Hydrocarbon process single and multi-layer level measurement Recommended Practice
International Society of Automation (ISA)
ISA 51.1
Process Instrumentation Terminology
International Organization for Standardization (ISO)
ISO 9001
Quality Management Systems - Requirements.
ISO 5167-1
ISO 5167-2
ISO 5167-3
ISO 5167-4
ISO 5167-5
Measurement of Fluid Flow by Means of Differential devices inserted in circular cross-section conduits running full – Part 1- General principles and requirements
Measurement of Fluid Flow by Means of Differential devices inserted in circular cross-section conduits running full – Part 2- Orifice Plates
Measurement of Fluid Flow by Means of Differential devices inserted in circular cross-section conduits running full – Part 3- Nozzles and Venturi nozzles
Measurement of fluid flow by means of pressure differential devices inserted in circular cross-section conduits running full - Part 4: Venturi tubes
Measurement of fluid flow by means of pressure differential devices inserted in circular cross-section conduits running full - Part 5: Cone meters
ISO TR 9464
Guidelines for the use of ISO 5167
ISO TR15377
Measurement of fluid flow by means of pressure-differential devices — Guidelines for the specification of orifice plates, nozzles and Venturi tubes beyond the scope of ISO 5167
ISO 2714
Liquid hydrocarbons — Volumetric measurement by displacement meter
ISO 10790
Measurement of Fluid Flow in closed conduits- Guidance to selection, installation
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and use of Coriolis meters (mass flow, density, and volume flow measurements)
ISO/ TR 12764
Measurement of Fluid Flow in closed conduits- Flow rate Measurement by means of Vortex shedding Flowmeters in circular cross-section conduits running full
ISO/TR 12765
Technical Report- Measurement of Fluid flow in closed conduits: Methods using transit time ultrasonic flow meters
ISO 13359
Measurement of Conductive Liquid Flow Electromagnetic Flowmeters – Overall Length
in Closed Conduits – Flanged
ISO 14511
Measurement of Fluid Flow in Closed Conduits – Thermal Mass Flowmeters
ISO 12242
ISO 17089-1
ISO 17089-2
Measurement of fluid flow in closed conduits - Ultrasonic transit-time meters for liquid
Measurement of fluid flow in closed conduits - Ultrasonic meters for gas - Part 1: Meters for custody transfer and allocation measurement
Measurement of fluid flow in closed conduits - Ultrasonic meters for gas - Part 2: Meters for industrial applications
ISO 80079
Explosive atmospheres
ISO 5168
Measurement of fluid flow- Procedures for the evaluation of uncertainties
ISO 4006
Measurement of fluid flow in closed conduits- Vocabulary and symbols
ISO Guide 98-3
Uncertainty of measurement- Guide measurement (GUM)
to
the expression of uncertainty
in
ISO Guide 99
NAMUR
International vocabulary of metrology- Basic and general concepts and associated terms (VIM)
NAMUR NE 43
NAMUR NE 043 – Standardization of the Signal Level for the Failure Information of Digital Transmitters
NAMUR NE 107
Self-Monitoring and Diagnosis of Field Devices
National Association of Corrosion Engineers (NACE)
NACE MR- 0175/ISO 15156
Material Requirements for Sulphide Stress Cracking and Stress Corrosion Cracking Resistance in Sour Oil Field Environments
NACE MR0103
Petroleum, petrochemical and natural gas industries Metallic materials resistant to sulfide stress cracking in corrosive petroleum refining environments.
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2.2 ADNOC Specifications
Document Number Title
AGES-PH-04-001
Automation and Instrumentation Design Philosophy
AGES-SP-04-009
Analyzer Package System
AGES-SP-04-011
F&G detectors and devices
AGES-SP-04-015
Machinery Instrument Systems
AGES-SP-04-017
Instrument Installation Design and instrument Piping Classes
AGES-GL-07-001
Material Selection Guidelines
AGES-SP-07-003
Requirements for Material in Severe Service
AGES-SP-07-004
Painting and Coating
AGES-SP-07-007
Welding & Non Destructive Examination (NDE)
AGES-SP-07-011
Preservation & Export Packing Specification
AGES-SP-09-002
Piping Material Specification Index
AGES-SP-09-003
Piping & Pipeline Valves Specification
AGES-SP-09-005
Specification for Fasteners and Gaskets
AGES-SP-09-008
Insulation Specification
AGES-SP-09-013
Specification for Pipe Fittings and Flanges
AGES-SP-13-001
Criticality Rating Specification
AGES-SP-13-002
Procurement Inspection & Certification Requirements in Projects
AGES-GL-13-002
Positive Material Identification of Equipment & Piping
AGES-GL-16-003,
Basic Engineering Design Data
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3 DOCUMENTS PRECEDENCE
The Codes and Standards referred to in this specification shall, unless stated otherwise, be the latest approved issue at the time of Purchase Order placement.
It shall be the SUPPLIER’S and CONTRACTORS’S responsibility to be, or to become, knowledgeable of the requirements of the referenced Codes and Standards.
The SUPPLIER/CONTRACTOR shall notify the COMPANY of any apparent conflict between this specification, the related data sheets, the Codes and Standards and any other specifications noted herein.
Resolution and/or interpretation precedence shall be obtained from the COMPANY in writing before proceeding with the design/manufacture.
In case of conflict, the order of document precedence shall be:
UAE Statutory requirements
ADNOC HSE Standards
Equipment datasheets and drawings
Project Specifications and standard drawings
COMPANY Specifications
National / International Codes and Standards
4
SPECIFICATION DEVIATION/CONCESSION CONTROL
Deviations from this specification are only acceptable where the SUPPLIER has listed in his quotation the requirements he cannot, or does not wish to comply with, and COMPANY/CONTRACTOR has accepted in writing the deviations before the order is paced.
In the absence of a list of deviations, it will be assumed that the SUPPLIER complies fully with this specification.
Any technical deviations to the Purchase Order and its attachments including, but not limited to, the Data Sheets and Narrative Specifications shall be sought by the SUPPLIER only through Concession Request Format. Concession requests require CONTRACTOR’s and COMPANY’S review / approval, prior to the proposed technical changes being implemented. Technical changes implemented prior to COMPANY approval are subject to rejection.
5
PROCESS SAFETY REQUIREMENTS
Sr No. 1
2
3
Description
Field Instrument related to SIS shall meet the highest Safety Integrity Level (SIL) specified for each of the Safety Instrumented Functions (SIFs) in the Safety Requirement Specifications or SIL study report.
Field Instrument related to SIS and associated components shall be minimum SIL-2 certified by the qualified & accredited certifying agency meeting IEC 61508 and/or equivalent machine related functional safety standards.
Documentation required by IEC 61508/ IEC 61511 for Field Instrument related to SIS shall be provided by SUPPLIER/ CONTRACTOR inclusive of Safety Manuals, Certificates, Test Reports, Reliability Data, etc.
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SECTION B – TECHNICAL REQUIREMENTS
6
DESIGN REQUIREMENTS
6.1 General
The Field instruments shall be designed and constructed in accordance with the requirements of this specification, AGES-PH-04-001 & referenced codes and standards.
All field Instruments and its accessories shall be sourced from the COMPANY Approved Suppliers List (AVL).
All field instruments shall have a design life of 15 years and be suitable for continuous service in the environment specified.
Unless otherwise stated, the minimum accuracy of instruments and closed control loops shall be:
Local Gauges: ± 1.0% of full scale. Electronic Transmitters: ± 0.025% of full range. Closed Loop: ± 1.0%.
Field instruments shall be designed for continuous operation. The following design criteria shall be applied while selecting the various filed instruments, but not limited to:
a. Highest availability and reliability b. High MTBF and low MTTR c. Utilizing the latest applicable proven technologies d. Compatibility with existing instrumentation and systems e. Safety to personnel and equipment during operation and maintenance f. Ease of inspection and accessibility for maintenance and repairs. g. Suitability for sustained operation in the prevailing harsh environmental and marine conditions. h. Electrical and electronic equipment suitable for operation in the designated classification of
hazardous areas.
All transmitters shall be provided with local LCD indicators.
Unless otherwise specified, all transmitters shall be ‘Smart’ type based on ‘HART’ protocol as minimum. Foundation Field bus Transmitters shall be used where specified in datasheets.
Unless otherwise specified or external power supply is required, Electronic instruments shall operate on 24 VDC, 2 wire loop powered from the control systems (for example PCS, SIS, F&G, etc.).
For PCS transmitters H1 Foundation can be used as specified in AGES-PH-04-001
Unless otherwise specified by the COMPANY, the signal cable entries shall be M20 x 1.5. The same requirement shall apply to Thermocouple and RTD terminal heads.
For externally powered instruments, additional separate cable entry (M20 x 1.5) for power cables is required
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The use of wireless transmitters shall be subject to COMPANY approval. When the requirement for wireless transmitters are specified, it shall comply with AGES-SP-04-019, Wireless Instrumentation System.
Threaded end connections shall be NPT (taper) as per ASME B1 20.1 and Flanged end connections shall be as per ASME B16.5.
All transmitters shall be furnished with integral digital indicators. Indicators shall be readily visible from operating positions and under the normal (natural or artificial) lighting levels. Malfunction of indicator shall not cause malfunction of the instrument and its output. Indicator shall be capable of being removed / replaced without affecting operation of transmitter, etc. Indicators shall be furnished with a scale to match the input engineering units range.
Circuits shall protect against and suppress electrical surges and transients of up to 1500V, 50-60 Hz that may be included in field wiring. Transient and surge protection on all input/output shall be designed as per API RP 552.
Lightning arresters (Transient Protectors) for the electronic signal built into the transmitter housing shall be provided when specified in the data sheets, for mounting in plant top structures or open space areas.
Electronic Transmitters shall be provided with an earthing bolt on outer side of housing and an earth terminal inside of termination.
Electronic Transmitters shall be reverse polarity protected.
Over range protection shall at least 30 % above specified range limits or at maximum design process pressure, whichever is higher, without calibration shift.
Transmitters shall be calibrated to the range indicated on the instrument datasheets and provided with a traceable certificate of calibration. Transmitters shall be calibrated using a normal multipoint calibration method at 0%, 25%, 50%, 75%, 100% of the range to ensure correct range and no hysteresis.
Unless otherwise specified, the instrument ranges shall be selected such that the normal value will be between 50 and 75% of scale range taking into account the specified minimum and maximum values.
In case of dual transmitters (one for the control and one for the safety) for the same process measurement, they shall have same range, span and they shall have fully independent process connections using separate taps and shall be located close together as practical to allow comparison of measurements on vessels, equipment or line. Transmitters shall not be shared between monitoring/control and Safety
All flanged end connections shall be per ASME B16.5. Flange rating, facing and finish shall be as specified on the instrument datasheets and shall conform to the requirements of piping material specification & classification.
Mounting hardware shall be of corrosion resistant 316 SS, for mount-the-transmitter or mount-the-manifold type specified in the data sheet.
Hand-Held communicator (if requested in the specification or purchase order ) shall be supplied suitable for the area classification and shall be complete with battery, carrying case, lead set with mini-grabbers and alligator clips and any other item necessary to complete the equipment.
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The software and accessories that are required to configure / troubleshoot the instrument or it’s peripherals to be provided by the SUPPLIER.
6.2 Units of Measurement
Process Design Basis for each project shall be generally referred for the Units of Measurement. The units for field instrument display & gauges shall be as per Units of Measurement defined in Instrumentation & Control Design Basis and AGES-GL-16-003, Basic Engineering Design Data.
6.3 Environmental Conditions
The design, construction and functions of field instruments shall be suitable for:
a. Contaminants (e.g., dust, dirt, sand, silicones, oil, or sea water spray) b. Local environmental conditions during normal and emergency situations (e.g., ambient temperature,
vibration, background noise, dust storms, effects of rain, snow, fog and wind);
c. Potential interferences (e.g., EMI / RFI)
Tropicalization shall be applied to protect the electrical circuits and electronic cards from being degraded by corrosion. Contacting of dissimilar metals shall also be avoided to prevent galvanic corrosion. All printed circuit boards shall be suitably coated by a means which has been proven to be effective in the protecting of circuits and components under offshore/H2S environment. SUPPLIER shall provide Type Test certification per type of electronic module/card from independent 3rd party certification authority confirming that all the measures considered shall mitigate the air-borne contaminants of G3 Severity as defined in ISA 71.04.
All outdoor mounted electronic instruments shall be provided with sunshades. These shall be designed to shade the enclosure throughout the high ultra-violet portion of the day.
Instruments shall be selected for reliability in the working environment without the need for special environmental control. Particular attention shall be paid to possible effects of corrosion, vibration, humidity, and extremes of temperatures.
All instrument material and components coming in contact with sour gas (as decided by piping material class), shall be certified per NACE MR0103 for refinery applications (latest edition).
Unless otherwise specified the below requirements shall be applied.
Temperature:
a. Maximum Temperature in shade: 54 °C b. Maximum solar metal Temperature in the sun: 87 °C c. Minimum ambient Temperature: 5 °C
Relative Humidity:
a. Minimum to Maximum (at 43 °C): 5 percent to 95 percent b. Design: 100 percent
Note: maximum and minimum temperatures are 58 °C in shade and 4 °C respectively for certain Onshore sites.
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6.4 EMC Compliance
The design and installation of all electrical / electronic instruments shall meet the radio frequency interference (RFI) and electromagnetic interference (EMI) (IEC 61000) emission (IEC 61000 6-4) and immunity (IEC 61000 6-2) requirements for an industrial environment.
The EMI / RFI effect shall be less than 0.1% of span when the instrument is subjected to an electromagnetic field strength of 30 V/m for frequency range 20 to 1000 MHz.
6.5
Ingress Protection
The degree of Ingress Protection (IP) for equipment enclosure shall comply with IEC 60529 and equipment data sheets.
The equipment minimum IP rating shall be as follows:
a) b) c)
IP 65 for onshore field environments IP 66 for offshore & marine environments IP 67 for all water jet areas, splash zones in offshore installations, Sulphur Dust Environments.
6.6 Hazardous area classification:
All electronic instruments/accessories shall be certified for use in Zone 1, Gas Group IIB, Temperature Class T3 (200 °C) hazardous area, as a minimum in accordance with the requirements of IEC 60079.
Approved national authority shall certify instruments installed in hazardous areas (e.g. UL, BASEEFA, FM). Manufacturer self-declaration for explosion protection equipment shall not be acceptable.
All electronic and electrical equipment shall carry apparatus marking as per IEC Ex and additional ATEX marking shall be applicable for equipment conforming to CENELEC / IEC as per EU Directive ATEX 94/9/EC.
Ex certified equipment also requires an Emirates Conformity Assessment System (ECAS) Ex Certificate of Conformity (CoC) issued by a notified body. Requirement for the ECAS Ex program utilizes IEC Standards, and qualification of conformity is met by meeting the requirements of the IECEx scheme in full, including mandatory factory site Quality Assessment Reports (QARs)
For instrumentation installed in hazardous area, Ex ia or ib (Intrinsically Safe) design is the preferred method for hazardous area protection. Unless approved by COMPANY the use of flameproof or increased safety instruments shall be avoided.
6.7 SIL Certification
Transmitters connected to safety systems shall be minimum SIL 2 certified. Safety manual shall be provided for SIL rated transmitters.
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7
PRESSURE INSTRUMENTS
7.1 General
Unless otherwise specified the material of construction for enclosure shall be 316L SS for all offshore application as a minimum and painted as per COMPANY Specification AGES-SP-07-004, Painting and Coating.
The material of wetted parts of instruments shall be selected to satisfy the process fluid characteristics, operating and environmental conditions. Instrument wetted materials shall be 316L SS as a minimum, unless alternative metallurgy dictated by process conditions is required and specified on the datasheets.
For onshore application the material of construction for enclosure shall be 316L SS or Cu free marine grade Aluminium as specified by COMPANY as a minimum and painted as per COMPANY Specification AGES- SP-07-004, Painting and Coating.
For offshore application the use of Aluminium, copper and copper alloys is strictly prohibited. Cast Aluminium (including copper free) or SS 302, SS 303, SS 304 material shall not be used for any instruments housing.
Components, equipment and assemblies shall be corrosion resistance.
The measurement principle shall be selected on the basis of service conditions, accuracy requirements and maintenance aspects.
Pressure instrument isolation valve shall be provided with 2-way integral valve manifold, flow instrument and level instruments (DP type) shall be provided with 5 valve integral manifold for instrument/ isolation.
7.2 Pressure & Differential Pressure Gauges
Gauges shall be designed to ASME B40.100 or to BS-EN-837.
In general, sensing element of pressure gauges shall be bourdon tube type. For low pressures applications (less than 0.3 barg), it shall be bellows or diaphragm seal type. Differential Pressure gauges shall be balanced bellows or diaphragm type.
The accuracy of the gauge shall be to Class 2A (ASME) or Class 0.6 (BS-EN).
Pressure and Differential Pressure (DP) gauges and panel-mounted instruments shall have dials measuring 100 mm (4 inches) in diameter. Gauges shall have white dials with black numerals in engineering units as specified in the datasheet.
Draught gauges for heaters, furnaces, etc. shall be of rugged construction and suitable for outdoor installation. They shall have stainless steel 316L SS cases and be either of the edgewise or circular pattern type
The range shall be selected in such a manner that the normal operating zone falls in the middle thirds of scale for pulsating service and from 50 to 75 % of span for normal service. Scale graduations shall cover 270°.
As a minimum, all pressure devices shall be provided with over-range protection as per ASME B40.100 & EN-837 without affecting the accuracy of the gauge.
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Pressure and DP gauges shall be safety pattern gauges, they shall have industrial solid front, safety glass windows, back blowout protection and weatherproof, corrosion resistant cases. The casing shall be 316L SS, and for offshore application the case shall be 316L SS and painted.
Gauge movements shall be corrosion resistant.
Micrometer pointer shall be provided in all gauges. Gauges shall have internal zero adjustment mechanism, unless otherwise specified.
The gauge shall withstand a steady pressure of 1.3 times the maximum scale value for an extended period as per EN-837-1, if in some cases, where the design pressure exceeds the maximum overpressure of the gauge, then suitable gauge protector (or gauge saver) shall be provided.
For pulsating service applications, dampener (snubber) shall be provided.
Pressure gauges shall be provided with liquid filled case if specified in the datasheets. Fill materials shall be environmental friendly and shall be compatible with process fluids and ambient/process temperature limitations and shall be approved by COMPANY.
Diaphragm seal type pressure gauges shall be provided with Flushing ring between instrument and Process connection. Flushing ring material shall be 316SS as a minimum or higher grade as determined by process medium. Flushing ring shall have 1/2” vent and drain points with individual isolation valves.
The DP gauges shall be provided with a suitable pressure equalising/travel stop mechanism to ensure there is no loss of calibration of derangement on application of full static pressure in either of the legs.
The DP Gauges shall be able to handle full static design pressure as differential (either on High Pressure side or Low Pressure side) without damage to the sensor. The maximum static pressure shall be as per instrument data sheet.
The DP type flow gauges (when approved by COMPANY) shall be provided with square root scale graduated in actual flow reading in engineering units, as specified in the datasheets. DP type level gauges when used shall be provided with linear scale graduated in actual level or % reading, as specified in the datasheets.
Instrument connection for pressure and DP gauges shall be as follows, unless otherwise specified:
a. b.
c.
Pressure gauges shall have ½” NPT (M) instrument connection located on the bottom of the gauge. Panel / flush mounted gauges shall have a ¼” NPT (M) instrument connection located on the back of the gauge. Differential pressure instruments shall have ½” NPT (F) instrument connections.
7.3 Pressure & Differential Pressure Switches
Use of pressure switches is not allowed and shall not be used in any application without prior written approval from COMPANY.
Pressure switches shall be piston type and Differential-Pressure switches shall be bellows type, unless otherwise specified.
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The switch shall be DPDT, snap acting dry contact micro-switch (2NO+2NC), hermetically sealed/ encapsulated, in general. The contact rating shall be 1.0A @ 24VDC / 0.5 @ 48 V DC for resistive loads or 10 A @ 240V AC for inductive loads.
It should have been type tested for at least one million successful on-off operations at full load (inductive).
All switch contacts shall be silver plated, as a minimum.
Switch repeatability shall be better than ±0.20 %.
The set point shall be adjustable internally. Manufacturer shall provide a locking and sealing mechanism for locking and sealing the set point adjuster. An indicating scale shall be provided for set point adjustment (accessible on opening the cover). There shall not be any effect of vibrations on the set point adjustment after the locking is put in place. Pressure switches shall have fixed differential.
Supplier shall check dead band of switch is set at minimum; and it falls between set pressure and operating pressure to ensure automatic reset of switch when pressure returns to normal.
Proper earthing-lug shall be provided at switch body to suit earth wire up to 4 sq.mm.
Flying leads are not acceptable. The lead wires from the switch shall be connected to an integral terminal block within switch housing. All screw connection shall be vibration proof and captive.
Proof pressure shall be at least twice the maximum and value of span.
Purge rings shall be wafer type carrier ring to fit between flanges (of diaphragm seals, when used) on the upstream or process side.
Threaded end connections shall be NPT (taper) as per ASME B 1.20.1 and Flanged end connections shall be as per ASME B 16.5.
Instrument connection shall as follows, unless otherwise specified:
a. b.
Pressure switches shall have ½” NPT (F) bottom instrument connection Differential-pressure switches shall have ½” NPT (F) instrument connection
7.4 Pressure & Differential Pressure Transmitters
Electronic Transmitters shall be SMART microprocessor based type to provide better performance characteristics and accuracy, and shall incorporate a non-volatile memory, which shall store complete configuration data of the transmitter. Transmitter shall have self-diagnostic features. In the event of detection of failure, the output shall be driven to a predefined value.
The primary sensing shall be diaphragm with low displacement electronic type sensor - capacitance cell or piezo-strain or silicon resonant. Other sensors require feedback reports of application in Oil & Gas industry for at least three years in service and use, proto-type instruments are not permitted.
Transmitters in Hydrogen service shall be Gold Plated Diaphragm to avoid the Hydrogen permeation.
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Performance Characteristics for Electronic transmitters:
a. Reference accuracy shall be better than ± 0.15 % FS for Pressure and ± 0.20 % FS for Differential
pressure transmitters.
b. Repeatability for all transmitters shall be better than ± 0.05 % of span, unless otherwise specified. c. Drift shall be less than 0.1% over a six-month period. d. The (precision) resolution shall be better than 0.025% (12 bit with an accuracy of ±0.1%± 1 LSB on
Analog to Digital and vice-versa conversions).
For non-clean applications such as slurry, dirty, highly viscous etc., Diaphragm seal type transmitters shall be provided with Flushing ring between instrument and Process connection. Flushing ring material shall be SS 316 as a minimum or higher grade as determined by process medium. Flushing ring shall have 1/2” vent and drain points with individual isolation valves.
A spare set of O-rings and setscrews for end flange (oval, mono etc.) connections shall be provided for each transmitter.
Transmitters with flying leads are not acceptable and all terminations shall be within enclosure.
The zero of range shall be fully suppressed or elevated (i.e. zero of scale shall be fully elevated or suppressed) within the lower and upper range limits.
Manifold selection and installation shall be as per requirement stated in AGES-PH-04-001, Automation and Instrumentation Design Philosophy.
The design requirement of “Diaphragm Seals with capillary extension” shall be as per requirement stated in AGES-PH-04-001, Automation and Instrumentation Design Philosophy.
8
TEMPERATURE INSTRUMENTS & THERMOWELLS
8.1 Temperature Elements
8.1.1 RTD Elements
For narrow span or differential span high accuracy measurements from –200°C (- 330°F) up to 450°C (840°F), RTDs shall be used.
RTD accuracy class shall be Class A (as per IEC 60751) only with Pt-100 (Platinum Resistance at 0°C: 100 Ohms) element.
All temperature measurements for control, alarm and trip shall be with duplex type RTD sensors.
SUPPLIER shall offer 3-wire RTD for process measurement as a minimum. 4-wire RTD shall be provided when specified in data sheet.
SUPPLIER shall ensure that the complete assembly shall include element, head and entry/entries and with components such as head extension, lock nut union, nipples etc. (All components in SS 316).
RTD elements shall be metal sheathed.
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Wire size shall be minimum 22 AWG (American Wire Gauge) or equal.
Teflon insulators shall be used, unless otherwise specified.
Element diameter shall be 6 mm nominal.
RTD sensors shall be spring-loaded to ensure good contact with the tip of thermowell.
8.1.2 Thermocouple Elements
Thermocouple (T/C) designations shall be as per IEC 60584-1: Thermocouple, Part1- Reference tables. The requirement shall be as specified in data sheet.
Element type shall be as specified in data sheet or selected based on the temperature ranges in the following table.
Type
Thermocouple material
Normal temperature range °C (°F)
Standard tolerance (a) °C (°F)
Chromel constantan
Iron constantan
Chromel alumel
Platinum 13% rhodium platinum
Platinum 10% rhodium platinum
Copper constantan
–200 °C to 0 °C 0 °C to 870 °C (–328 °F to 1600 °F) 0 °C to 760 °C (32 °F to 1400 °F) 200 °C to 0 °C 0 °C to 1260 °C (–328 °F to 2300 °F) 0 °C to 1480 °C (32 °F to 2700 °F) 0 °C to 1480 °C (32 °F to 2700 °F)
–200 °C to 0 °C 0 °C to 370 °C (328 °F to 700 °F)
±1.7 or ±1% ±1.7 or ±½%
±2.2 or ±¾%
±2.2 or ±2% ±2.2 or ±¾%
±1.5 or ±¼%
±1.5 or ±¼%
±1.0 or ±1.5% ±1.0 or ±¾%
E
J
K
R
S
T
Note:
a) The tolerance expressed in °F is 1.8 times larger than in °C. If tolerance is in %, the % applies to
the temperature being measured expressed in °C.
b) The Normal operating temperature range is the operating range within the standard tolerance. c) Where type K thermocouples operate on temperatures services above 800°C and hydrogen
diffusion to the thermocouple material may be expected, magnesium-oxide insulated thermocouples with Inconel protective sheeting should be used, or a titanium getter wire shall be specified in addition to the normal execution.
Tolerance class shall be Class 1 as per Thermocouples - Part 1: EMF specifications and tolerances, unless otherwise specified in data sheet.
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All temperature measurements for control, alarm and trip shall be with Duplex type Thermocouple element. However, SUPPLIER shall offer Duplex as standard (with the second element as standby or local check reference or spare), unless otherwise qualified in data sheet.
Thermocouple elements shall be mineral insulated type and metal sheathed as per IEC 61152: Dimensions of Metal sheathed thermometer elements and IEC 61515: Mineral Insulated Thermocouple cables and Thermocouples.
Sheaths shall be of austenitic stainless steel and preferably of 316 SS.
Thermocouples shall be ungrounded (insulated) type, unless otherwise stated.
Element diameter shall be 6 mm nominal and tolerance on diameter shall be as per IEC 61515.
The complete assembly shall include Duplex (thermocouple) element, Pipe nipples, Union, Head assembly with terminal block & conduit entry/entries/connection as specified in data sheet. Assembly shall be made of 316 SS as a minimum
Thermocouple assemblies shall be furnished with terminal blocks with signal screw terminals and ground terminal. Terminals shall be identified by polarity. The flying lead to the terminals shall be colour coded or ends sleeved & identified by polarity.
Thermocouple elements shall have mechanical type lug at the Thermocouple head terminal block.
For Furnace/Heater TC and Multipoint TC:
For installations in cracking furnaces the type of thermocouples and the specific installation requirements for measuring skin temperatures of furnace tubes and other specific furnace measurements shall be in accordance with the LICENSOR and/or SUPPLIER’s standards. All such thermocouple installations will require COMPANY approval.
Additionally the following shall be considered as applicable:
In each furnace two additional type B thermocouples shall be installed close to two of the type K skin couples for checking purposes. These type B thermocouples shall be connected to an accessible Junction box for termination to portable instrument.
For monitoring furnace tubes at very high temperatures, such as in hydrocracking furnaces, consideration may be given to the use of optical pyrometers, provided they are only used for trend indication.
With regard to deterioration (drift) of type K thermocouples at very high temperatures, such as in hydrocracking furnaces, consideration should be given to the use of type B thermocouples, provided these are then only used for furnace coil balancing. For some applications, both types K & B may be required in order to cover wide range from start up to normal operation.
All thermocouples used for furnace coil balancing shall be from the same batch and be calibrated/ certified for the specified operating temperature. In addition to the standard identification, the thermocouples shall be provided with batch and certificate number. In high temperature applications pyrometers may by used.
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In order to properly calibrate the pyrometers, a Type R thermocouple with a double walled ceramic thermowell having a 50% length metallic sleeve and a continuous inert gas (N2) purge shall be provided.
Multipoint Reactor Thermocouple:
Process Licensor recommendation to be sought for the critical process application like multipoint reactor thermocouple
Where multiple thermocouple assemblies are required, e.g. for measuring temperature at several levels in a reactor, they shall be assembled from mineral insulated thermocouple elements of appropriate lengths, in a flexible metal sheath or bound together with a metal wire or mesh to form a composite flexible assembly. Where specified the elements with wells may be delivered in one assembly.
8.2 Thermowells
The mechanical construction of the thermowell shall be such that the process fluid shall not induce vibrations in all possible flowing conditions i.e. at all possible combinations of flow velocity range, temperature and pressure variations as well as fluid properties such as viscosity, etc. Supplier shall provide wake frequency calculation as per ASME PTC 19.3 TW latest edition to prove safe design of the thermowell. The wake frequency calculation shall be approved by Company before fabrication
Forged Thermowells shall be solution annealed and subjected to PWHT (Post Weld Heat Treatment) prior to machining, when required by PMS, or specified in data sheet.
SUPPLIER shall ensure that the process conditions causing the thermowell to wake and vibrate are avoided by suitably altering material/mechanical construction or type of thermowell as the case may be.
Spherical or domed tip may be applied for high pressure-high velocity service to reduce the Vortex effect.
Thermowells to be used as Test wells elements shall be supplied with SS 316 plug and chain.
Company standard reference drawing (SECTION-D) shall be the basis for fabrication of the thermowell, unless otherwise specified in data sheet. The preference should be given to tapered design thermowell and machined from single solid drilled bar stock material with lap flange.
Bore of thermowell shall suit type of element. Element shall snugly fit into the bore to meet speed of response specified.
Preferred temperature element (RTD or T/C) diameter shall be between 6mm and suitable for thermowell bore of 6.2 - 6.5mm.
Thermowells shall be minimum SS-316L unless alternative metallurgy is specified or dictated by process conditions. For seawater services, Monel shall be used. Other materials shall be selected as per the relevant piping class. Thermowell shall comply with NACE requirement for H2S applications
Pipe diameter for thermowell installations shall be at least (NPS 6) unless otherwise agreed by COMPANY
For thermowell flange size connection shall be as per the AGES-PH-04-001
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Thermowell installation shall be as per the below table.
In columns, thermowells shall be immersed into liquid. Alternatives shall be subject to approval by COMPANY.
Shorter immersion lengths may be accepted where wake frequency and stress calculations limit the immersion length provided the required measuring accuracy and process response time can still be achieved.
The use of collars is not permitted.
Where thermowells are required in line sizes smaller than 6” NB, the thermowell shall be installed in the bend. Wells for insulated vessels and lines shall have extension necks and penetrate a minimum of six inches inside the vessel.
Line Size
6”
8” and above
Thermowell Insertion Length (U)
Standout (S) = 150 mm
Standout (S) = 250 mm
255 mm
305 mm
355 mm
405 mm
Equipment / Tank / Vessel
440 mm (Typical)
For the temperature gauges on the X-MAS tree shall be as per the below table, unless otherwise specified by the X-MAS Tree SUPPLIER as per the supply. Contractor shall check with SUPPLIER of X-MAS tree and ensure the design of temperature gauges including thermowells.
Flange size
Working Pressure Rating
Thermowell immersion length
2 9/16”
3 1/8”
4 1/16”
5 1/8”
4 1/16”
5 1/8”
5000 psi
5000 psi
5000 psi
5000 psi
10000 psi
10000 psi
100mm
125mm
125mm
125mm
Note-2
Note-2
Thermowell Thread detail and rating
1” NPT / 9000 #
1” NPT / 9000 #
1” NPT / 9000 #
1” NPT / 9000 #
Note-2
Note-2
Note-1: The details given in the above table is based on existing installation. Note-2: Thermowell type, rating, and immersion length details for API-10000 rated X-MAS tree equipment shall be as per X-MAS tree SUPPLIER’s recommendation.
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8.3 Temperature Gauges
Bimetallic type temperature gauges shall be selected as a default choice. Use of filled system type temperature gauges shall be avoided for any application, as the accuracy of the filled system type temperature gauges is greatly affected by change in ambient temperature.
Bi-metal thermometers shall be used for local indication of temperature from -30°C to + 400°C.
Filled system type temperature gauges only are considered for the applications where the access, process conditions or mechanical considerations to preclude the use of bimetallic type temperature gauges.
Filled system type temperature gauges with capillary extension shall be used where remote local indication is required.
The temperature scale shall be in °C unless otherwise specified in the project data sheet, based on any operational specific requirement. In such case temperature gauges are provided with dual scale (°C and °F).
Performance characteristics:
Accuracy : ± 1.0% span Repeatability: ±0.5% of span.
Dial size shall be 100mm (4 inch) nominal for bimetallic type temperature gauges unless otherwise specified in the data sheet.
Temperature gauge shall be with 316 SS material complete with thermowell
The sensing bulb shall be inserted at same depth as “U” length. Rigid stem extension shall be with adjustable union connection, which shall permit an adjustment of 6” prior to insertion.
The rotatable head adjustable at all angles shall be provided for direct mounted rigid stem temperature gauges.
The compression fitting/adjustable union shall be provided for all temperature gauges to ensure the insertion length and mounting direction adjustment.
Scale shall be white laminated phenol with black graduations for all gauges.
The window material shall be shatterproof laminated glass.
All gauges shall have external zero adjustment.
The range shall be selected in such a manner that the normal operating zone falls between 50 to 75% of span.
For all temperature gauges, the movement shall be of 316/ 316L SS, as a minimum. This shall apply to all accessories too. Use of SS 304 for movement is not acceptable.
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8.4 Temperature Transmitter
Performance Characteristics
Reference accuracy shall be better than ± 0.15% FS. Repeatability for all transmitters shall be better than ± 0.05% of span, unless otherwise specified. Drift shall be less than 0.1% over a six-month period. The (precision) resolution shall be better than 0.025% (12 bit with an accuracy of ±0.1% ±1 LSB on
Analog to Digital and vice-versa conversions).
Electronic Transmitters shall be microprocessor based open loop digital type only (as opposed to force- balance type) to provide for better performance characteristics including greater accuracy.
Head mounted transmitters shall be preferred, however, Remote mounting of transmitter shall be considered for the following applications:
Inaccessible locations
- Line locations / areas / equipment where there are continuous vibrations
- Location is exposed to hot radiating surfaces and its temperature exceeds 52° C
- When specified in Project specifications , Data sheets
In case of remote mounting, SS316L mounting accessories shall be provided.
Transmitter output shall be linear with temperature. Necessary linearization circuits shall be provided.
The wiring shall be hermetically sealed and wiring rigidly encapsulated within the housing.
Terminals shall be identified by polarity. The internal flying lead to the terminals shall be colour coded or ends sleeved & identified by polarity.
9
LEVEL INSTRUMENTS
9.1 General
For level measurement, depending on the process conditions, the following techniques shall be considered for selection of suitable type level instrument based on medium and suitability: (Level instruments without moving parts are preferred).
Differential pressure type instruments. Capacitance and admittance type instruments. Radar / Guided Wave Radar (GWR) Ultrasonic type instruments. Radioactive type instruments. Magneto-restrictive type Magnetic gauge and transmitter type instruments. Transparent and Reflex gauge.
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Float/Displacer type instruments LVDT (these types are least preferred/shall be considered as the
last option).
Level instruments shall be connected directly to vessels and not to inlet or outlet piping. Connections to the bottom of vessels shall be avoided whenever possible, and shall not be used when settlement of solids may be expected.
Level range for monitoring & control application shall cover the entire range i.e range shall cover the trip set points as applicable.
The design of all level instruments shall include an associated local level gauge to allow range checking and visual level verification over the calibrated range of the instrument.
The gauges shall have a minimum accuracy of ± 1.0% of the full scale. The range of level gauge shall cover the measuring range of level transmitters.
Vent and drain valves shall be provided on level gauges.
Purging or heating shall be considered to ensure proper operation of level instruments for highly viscous liquids containing water or solids, especially if the latter tends to form sediments.
Dedicated, independent process connections shall be used for level measurements that are part of safety instrumented system or required to enhance reliability. They shall be close together to allow comparison of measurements on vessels. The tapping points shall be at the same elevation. Level bridles shall not be used for level instruments which are part of safety instrumented system without COMPANY approval.
For bridle design shall be as per AGES-PH-04-001
Level gauges in vaporizing services shall be oversized to accommodate the dynamic state within them.
Ultrasonic, capacitance, admittance, radar, microwave, radioactive, laser type instruments shall be used for highly viscous, waxy or fouling services and for emulsive interface level measurements (subject to proven track record from Manufacturer for similar application).
All continuous level measurement instruments shall be provided with a means of In-Situ calibration and testing. Particular attention shall be given to the problems associated with the calibration of direct mounted level instruments.
Level switches shall be avoided. However, if a transmitter is not feasible, a level switch may be considered with COMPANY approval. They shall be hermetically sealed double pole double throw type switch contacts.
Level gauges/Radar/Ultrasonic level instruments shall have the size, rating marked on the instrument connection flanges.
Selection of level instrument for a specific application shall require a comparison of the following:
Compatibility with process fluids. Functionality. Suitability.
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Maintainability. Operability. Cost.
For all applications, the difference in liquid density and gas/vapor density shall be taken into account when specifying any fluid specific gravity dependent instruments. Temperature compensation may be required in some situations.
Special consideration to variation in fluid properties that would affect the measurement principle due to different operating conditions shall be accounted for during design. (e.g. Impact of pressurization and depressurization on di-electric constant of gases).
Level transmitter’s range shall cover the operating levels of the service.
For diaphragm seal instruments in lethal service, the diaphragm seal flange facing shall be as per piping class and project specification.
Vessel top mounted instruments should be avoided, to be considered only subject to COMPANY written approval.
9.2 Differential Pressure Type Level Instruments
Differential pressure level transmitters shall be used for continuous liquid measurement and where the liquid density is constant.
Manifolds (5-valve) shall be integral with transmitter, provided for instrument isolation, pressure equalization and/or bleeding for DP type level instruments.
For all applications, the difference between liquid density and gas/vapor density shall be taken into consideration when calculating the range for differential pressure instruments.
Diaphragm seals are required in lethal, severely dirty, corrosive, hazardous fluids, or fouling service.
When differential pressure transmitters are used on atmospheric pressure tanks or vessels, the low side shall be left open to atmosphere.
If the instrument is installed above or below the liquid level range, transmitters shall require elevation and/or suppression.
When used on dirty or viscous fluids, the high pressure side of the smart electronic D/P transmitter shall have a 3” flange with an extension so the diaphragm is flush with the inside surface of the vessel. The low-pressure side connection shall be a ½” connection or diaphragm seal with capillary connected to the vessel.
Where chemical seals are specified, they shall come assembled with the instrument and pre-filled capillary, where applicable. The seal material shall be compatible with the process fluid. The capillary material shall be SS 316 having SS 316 protection tube with PVC sheath.
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Flushing rings shall be wafer type to fit between the diaphragm seal & process side connection. Long bolting to accommodate the flushing ring shall be provided. 2 number ½” NPTF connection shall be provided for vent and drain connections with isolation valves.
Use of non-capillary DP level measurement shall be considered where long capillary lengths and faster response times are envisaged. Wherever dual transmitters are used for such applications, the master and slave units shall operate on a single loop power supply.
In cryogenic applications (temperatures below - 22 ºC) Differential Pressure transmitters shall be self-draining.
9.3 Capacitance/Admittance Level Type Instruments
Capacitive/Admittance level transmitters shall be used mainly on water base fluids or to measure interface level between water and oil. They shall be used only when differential pressure transmitter cannot be applied.
Capacitive/Admittance instruments shall not be used in a service if the dielectric constant of the liquid under measurement changes due to different operating conditions.
Capacitive/Admittance instruments can be used for alarm and non-critical on-off control applications if the dielectric constant of process medium remains same for all operating conditions.
9.4 GWR Type Level Instruments
Guided wave radar (GWR) shall be considered as first choice for interface liquid level measurement unless it is not suitable for the given process conditions and applications.
For flare drums service, GWR shall be facilitated with dynamic vapor compensation to automatically compensate for dielectric changes.
Each GWR level transmitter shall be installed with adequate isolation, vent and drain valves for test and maintenance purposes.
GWR should be avoided for foam service, Low dielectric constant service (below 2) and service with emulation layer of more than 4”.
GWR instruments shall be used for liquid/liquid interfaces.
Non-contact type radar level instruments may be considered for toxic or hazardous service (H2S).
Non-contact type radar level instruments shall be mounted on the top of the vessel and pointed straight down. Guided tubes can be used if the instruments cannot be mounted in the horizontal plane.
Measures shall be taken to prevent vapor condensation and deposits that may affect the performance of radar instruments.
Radar level instruments require a relatively flat fluid surface. If the surface is turbulent then a still well shall be used.
When using guided wave radar technology the following shall be considered:
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Process nozzle connection size shall be as per requirement detailed in AGES-PH-04-001. Programming settings for dielectric constant and strongest signal or first signal.
9.5 Ultrasonic Type Level Instruments
Ultrasonic level instruments shall only be considered for storage vessels and effluent pits, in corrosive service, or if maintenance is difficult to perform.
When using ultrasonic instruments on pressurized vessels, process isolation valve shall be used.
Ultrasonic level instruments shall not be used in vessels where vapors given off can vary the density above the liquid and also in places where the noise from process medium or equipment can affect the level measurement.
Ultrasonic level instruments shall not be used in high temperature process applications.
Ultrasonic instruments shall be shielded to prevent false readings caused by noise interference.
9.6 Nuclear Type Level Instruments
Radioactive type instruments shall only be used with COMPANY approval. Proven Track Record is mandatory for the use of these type of instruments. Two types of radioactive instruments shall be considered, Gamma ray absorption and Neutron backscatter.
Radioactive type instruments shall meet applicable statutory regulations governing the handling and use of radioactive sources. All Radioactive type Instruments installations shall comply with government requirements, Federal Authority for Nuclear Regulation (FANR); for installation and radiation limits, shielding, etc.
A storage area that meets the requirements of the local regulatory body shall be made available for storage of removed sources.
The preferred source type is Caesium 137 (CS137), Cobalt 60 (Co60) (or Americium-241 (Am-241)) based on application requirement and sized for a 10 year operating life. Other sources require COMPANY approval.
The source holder shall incorporate a lockable source isolation method for locking the shutter in place. It shall be encapsulated in Titanium.
Scintillation crystals or plastics shall be used in preference to all other detector types.
If continuous measurement is required, a line detector shall be used in preference to line source.
In separator applications, radioactive type level profilers could be used to monitor sand build up and to detect foam and emulsion interface layers allowing optimization of injection chemical usage and separator performance.
Nuclear level profiler shall provide density profile of the separator. The instrument shall provide 4-20 mA outputs representing oil, water, foam, emulsion and total level when specified in Data sheet.
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Nuclear level Interface cabinet (NIC) complete with controller & HMI shall be provided.
The cabinet shall be 2100x800x800mm, Rittal type. Ingress protection shall be IP 42 as minimum. The components within the cabinet shall be suitable for environmental condition defined for the project.
The Nuclear level profiler shall be PLC based system having 100% redundancy at the processor, communication and I/O level.
The PLC system design shall be as per AGES-SP-04-018, Programmable Logic Controller and shall be integrated with ICSS system as per requirement detailed in AGES-SP-04-007, Instrumentation for Packaged Equipment Specification.
9.7 Float/Displacer Type Level Instruments
Float/ Displacer type transmitters shall be considered for ranges below 350mm (14 inches).
Displacement type will be used for clean liquid applications up to 1219 mm (48 inches). External displacer cages, segregated from vessels by block valves shall be used. External displacer cages will be supplied with 2” minimum flange side and bottom connections and rotatable heads.
Internal float/Displacers transmitters shall only be used:
If the vessel can be isolated safely without disruption to operations. If there are no other suitable technical measurement method.
a) b) c) As a redundant measurement.
Float/Displacers type transmitters shall not be used in the following:
a) Highly viscous, waxy, turbulent, dirty or fouling service and for emulsive interface level measurements. b) Liquid-Liquid interfaces if the two fluids form an emulsion or do not have a clean interface. c) Liquid-Liquid interfaces with specific gravity differences less than 0.10. d) Liquid-Liquid or Liquid-Gaseous services where either the upper or lower fluid specific gravity is not
relatively constant.
Floats/Displacers shall be made of a material compatible with the process fluid and be the correct size and density for the application.
For high temperature (higher than 200 °C) as well as low temperature (lower than 0 °C), insulation extension or torque tube extension shall be applied.
9.8 Magnetic Type Instruments
Magnetic type instruments shall be used for high pressure, high temperature, and toxic or hazardous duties.
Magnetic level gauges shall be provided as first choice for local level measurement applications unless it is not suitable for the application and its design shall be as per requirement specified in AGES-PH-04-001.
Magnetic type gauges may be used for environmental, personnel safety hazard elimination, or if corrosiveness of process fluid precludes feasible application.
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For local indication:
a) Positive action mechanisms shall be used, with two color flaps. b) The reading scale shall be adjustable.
The level chamber shall be 316 SS as a minimum, unless the service requires additional corrosion protection. The floats shall be stamped with same tag number as level gauge along with the density of the float. Vented Float shall not be used without prior written approval from COMPANY.
With 316 SS chamber, 316 SS flanges shall be used or of material required by the applicable piping and material specifications.
Magnetic chamber shall be provided with travel stops at both end of travel to ensure no mechanical damage to the float.
Center-to-center length of magnetic level instrument shall not be more than 2 m. For level coverage beyond 2 m, multiple level gauges shall be used with a minimum overlap of 100 mm in visibility.
All vents and drains shall be fitted with isolation valves.
Chamber shall be designed as per ANSI B31.3.
9.9 Level Glass Gauges
Level gauge type selection and design shall be as per requirement specified in AGES-PH-04-001.
Level gauges shall cover the complete range of measurement associated with level controls, alarms, shutdown devices, and transmitters.
Compensation shall be made for expansion and contraction of gauges used on hot or cold liquids. When used in services with temperatures greater than 260°C (500°F) or pressure greater than 7000 kPa (1000 PSIG), Belleville type spring washer construction shall be used.
Glass tube gauges shall be subject to COMPANY approval. Tubular gauge glasses shall not be used in process service or in severe utility service without COMPANY approval.
Gauge glasses valves shall be angle pattern, offset design, with internal ball checks. Valves shall be connected to vessels through flanged connection. When gauge valves are used in extremely hot or corrosive fluids, they shall be Outside Screw and Yoke type.
All vents and drains shall be fitted with isolation valves
Where magnetic float type level gauges are unsuitable, armored gauge glasses, complete with gauge cock isolation valves and integral ball check blow-out protection shall be specified. Gauge glass type shall be through vision or reflex type.
Reflex type gauges are preferred over through vision except for the following applications where through vision type gauges are better suited:
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a) Determining the interface between two liquids (cannot be observed with reflex type). b) Viscous fluids (fluids tend to clog grooves in reflex type). c) Determining the color or turbidity of a fluid. d) Steam and condensate above 20 bar gauge.
Level glasses shall be of the transparent type and shall not be supplied with illuminators unless approved by COMPANY. Each gauge shall be stamped with the maximum working pressure and temperature and shall be rated at least twice the operating pressure of the service.
Top/top, bottom/bottom gauge connections shall be used.
9.10 Float and Tape type of level gauge
Float and Tape type of level gauge shall only be used for local indication on non-hydrocarbon tanks where specified.
10 FLOW INSTRUMENTS
10.1 General
Flow Instrument selection and design shall be as per requirement specified in AGES-PH-04-001.
The Flow meter technology shall be selected based on the application, required size, pressure rating, pressure drop, accuracy, available straight meter run, rangeability, multi-phase, bi-directional flow … etc.
Sizing calculations shall use base conditions defined in project specification and AGES-GL-16-003, Basic Engineering Design Data..
Pressure and temperature measurements shall be considered where required for density compensation. For gases and steam flow application, temperature and pressure transmitters shall be installed in conjunction with the flow transmitter to make the compensation calculation in the DCS. The temperature and pressure transmitters shall be carefully located to avoid any turbulence flow.
Manufacturer’s installation requirements shall be followed as a minimum.
Use of straightening vanes or flow conditioners shall be subject to COMPANY approval. Flow Conditioners or Straightening Vanes shall be selected in accordance with ISO-5167 / API MPMS 14.3.2.
All transmitters shall be furnished with integral digital indicators. Digital indicators shall be readily visible from operating positions and under normal (natural or artificial) lighting conditions.
10.2 Differential Pressure (DP) Flow Meters
10.2.1 General
In general D/P type flow measurement are preferred for applications where line sizes from 2 inches up to 24 inches and a Reynolds number at minimum flow more than 10,000.
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The minimum accuracy and rangeability of flow meters shall be as per AGES-PH-04-001.
DP flow meters shall not be chosen for pulsating flows.
Differential transmitters used with orifice plate installations should have a 5 valve integral manifold.
Transmitters should be close coupled, if feasible.
For ESD/Trip applications a separate transmitter including manifold, isolation valves and impulse lines shall be installed and connected to the second pair of tapings on orifice flanges. Tapping’s of the primary impulse lines are not acceptable.
Where remote installation of a differential pressure type flow meter is required, the impulse lines shall be as short as practical, of equal lengths and shall run adjacent to each other away from direct sunlight where possible.
Meters in liquid services shall be installed so that meters are always full of liquid and shall be installed to avoid trapping gases. In gas service, liquid trapping shall be avoided.
10.2.2 Concentric Square Edge Orifice Plate
Concentric orifice plates shall normally be used. Other types e.g. eccentric, segmental, etc. shall only be used where required to meet particular service conditions, subject to COMPANY approval.
Orifice tapings:
For top orifice meter connections orifice flange taps shall be on the vertical flange centrelines and for side orifice meter connections orifice flange taps shall be on the horizontal flange centrelines.
Tapings at 45º above the horizontal for vapour service and 45º below the horizontal for liquid service may only be used where particular installation constraints arise. Generally orifice tapping orientation shall be in accordance with the project piping standards.
Orifice Plate shall be sized, designed and fabricated in accordance with ISO 5167-2 and shall also comply to design requirement detailed in AGES-PH-04-001
Unless otherwise stated in the instrument data sheet, the minimum accuracy of orifice plate shall be ± 2 - 4% of full scale flow.
Straight meter run shall be as per ISO 5167-2, considering the Beta ratio and the piping configuration.
Orifice plate material shall be 316 stainless steel minimum unless otherwise specified in the data sheets.
The orifice plate Beta ratio shall be between 0.20 and 0.60 for liquids and between 0.20 and 0.70 for gases and steam.
Meter maximum shall be selected so that normal design flow is about 70-75% of scale, while at the same time maximum design flow shall be at about 90-98% of scale.
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Standard differential pressure range shall be 2500mm H2O. Other ranges such as 500mm H2O, 1250mm H2O, 5000mm H2O may be selected. However, range below 250mm H2O and higher than 5000mm H2O shall not be selected unless approved by COMPANY.
Orifice plate thickness shall be as per ISO 5167-2, required calculation (if any) shall be submitted by the orifice supplier.
Standard pipe Flanged end connections shall be as per ASME B16.5. Rating and facing shall be as specified in data sheet. Taps shall have NPT threaded end connections. Minimum Flange rating is 300 # class.
10.2.3 Quadrant Edge (Quarter Circle) Orifice Plate
Quadrant Edge (Quarter Circle) Orifice Plates shall be designed in accordance with ISO TR 15377.
For Reynolds numbers less than 4000, conic or quadrant edge orifice plates are desired.
10.2.4 Eccentric & Segmental Orifice Plate
Eccentric Orifice plates shall be designed in accordance with ISO TR 15377.
Segmental orifice plate installations shall be specified conforming to API MPMS Chapter 14.3.1.
Eccentric or segmental orifices plates are recommended for dirty fluids, slurries, or wet gases; conic and quadrant edge orifice plates can be considered for viscous liquids.
10.2.5 Integral Orifice Plate
For line sizes less than 2”, Integral orifice meters shall be used if plugging is not a problem and found suitable. Orifice unit shall be designed as per ASME MFC-14M. Flanges shall be socket welded to the upstream and downstream piping sections, which shall be supplied with the meter. The upstream and downstream piping shall be socket welded to the meter body. The orifice plate shall be 316 SS and the meter body, flanges and piping shall be 316L SS unless otherwise specified on the data sheets. Integral orifice meters shall be factory calibrated.
10.2.6 Venturi Tubes, Low Loss Tubes and Flow Nozzles
Venturi tubes, low loss tubes, and flow nozzles shall be used where high pressure recovery is necessary or where only low inlet pressure is available. Venturi tubes shall be used to measure suction flow of centrifugal compressors.
Venturi tubes and flow nozzles of circular cross section shall be constructed in accordance with the requirements of ISO 5167-3, 4 and and shall also comply to design requirement detailed in AGES-PH-04- 001.Unless otherwise specified, one pressure tapping shall be provided for upstream and one for downstream pressure measurement. The Supplier shall furnish calculation sheets for all venturi tubes, low loss tubes and flow nozzles. Venturi tubes shall be flanged type, other process connections require COMPANY approval.Flow nozzles shall be used when a higher flow capacity than an orifice plate is required and when a lower permanent pressure drop than an orifice plate is required.
Flow nozzles do not recover pressure similar to a Venturi tube.
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Flow nozzles shall be flanged type with taps located on the piping, alternate taps locations, such as throat tapping, can be used with COMPANY approval.
Flow nozzles shall conform to ISO 5167-3.
10.2.7 Variable Area Flow Meter (Rotameter)
The use of variable area flow meters, often known as rotameters shall be for simple applications such as measurement of purge, cooling or sealing fluids, or in sample conditioning system for analyzers.
Variable area flow meters shall be of armored all-metal type.
Design and selection shall also meet the requirement specified in specification AGES-PH-04-001 and API 551 standard.
Unless otherwise stated in the instrument data, the minimum accuracy and rangeability of variable area flow meters shall be as per AGES-PH-04-001.
Rotameters can be provided with integral transmitters for indication purposes if specified in the instrument data sheet.
Variable area flow meters shall be mounted with the center of the indicating scale at approximately 1.3 m above grade or platform and in such a way that maintenance can easily be carried out. Sufficient clearance shall be provided over and under the meters for dismantling, cleaning or repair.
The meters shall always be mounted in a true vertical position and in such a way that strain or stress caused by the weight of unsupported lines or by thermal expansion is prevented.
The meters shall be offset from the main line and be located between block valves. Block valves shall of the same size as the meter connections.
Variable area meters with a top extension shall have a vent line with a 1/4 inch NPT needle valve. Where feasible, the vent line shall have a permanent connection to a point down-stream of the meter. This point shall have a sufficiently lower pressure to ensure a continuous escape of possible vapors from the meter extension, if required.
Glass tube meters with light metal protective cases are permitted only for air and water services unless the temperature or pressure exceeds the meter rating.
10.2.8 Annubars (Averaging Pitot Tubes) Flow Meter
Unless otherwise stated in the instrument data sheet the minimum accuracy and rangeability of the annubar flow meters shall be as per AGES-PH-04-001.
Annubar/pitot tube primary elements are of value under certain conditions where other measurement devices are impractical or inoperable due to low-operating pressure, low fluid velocity, excessive pipe size, and limited room. They are also useful where permanent pressure loss must be low, high accuracy is not required, and installation and maintenance costs must be minimized.
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The installation shall be designed to permit insertion and removal without shutdown.
Annubars may be used especially for air flow measurements in ducts.
Annubars shall be gear driven, retractable type. An isolation valve or other means of isolation shall be provided so that a process shutdown is not necessary to retract the annubar.
Annubar assemblies shall be flanged type (unless installed in ducting).
The SUPPLIER’S recommendations for installation for liquids and gases in horizontal or vertical lines shall be followed.
Upstream and downstream straight length shall be as per SUPPLIER requirements to meet the specified accuracy.
The use of secondary supports (on the bottom of the pipe should the annubar insertion span the entire diameter of the pipe) shall be as recommended by the Supplier.
10.2.9 V-Cone Flow Meter
V cone flow meter selection, design and installation shall be per requirement specified in AGES-PH-04-001 and ISO 5157-5
Unless otherwise stated in the instrument data sheet, the minimum accuracy and rangeability of the V cone flow meters shall be as per AGES-PH-04-001. The V cone meter shall be supplied with flow calibration certificate for its discharge coefficient.
V-Cone flow meters shall be used when other D/P flow elements such as orifice plates and Venturi tubes are not acceptable due to straight length requirements.
V-Cone Meter typically requires 2-3 pipe diameters upstream and 1 pipe diameter downstream straight run as a minimum. Additional straight length shall be as per supplier recommendation.
The permanent pressure loss for V-Cone meter is lower than that of a typical orifice plate meter.
V Cone shall conform to ISO 5167-5.
10.3 Mass Flow Meters
10.3.1 Coriolis Flow Meter
Coriolis flow meter selection, design and installation shall be per requirement specified in AGES-PH-04-001 and API MPMS Chapter 5.6.
Unless otherwise stated in the instrument data, the minimum accuracy and rangeability of the Coriolis flow meters shall be as per AGES-PH-04-001.
The flow meter shall be rated for the design pressure and temperature per the line class. The flow meter shall normally be 316L SS inside a 304L SS housing unless the line class specifies otherwise. Factors such as
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erosion, corrosion, and coatings will result in measurement errors over longer period and sensor failure and hence tube material shall be compatible with process fluid. It shall also be ensured that erosion does not take place inside the sensor while measuring abrasive products. The sensor maximum flow velocity requirements should be maintained during design.
The transmitters for Coriolis flow meters shall be integrally mounted where the metering tube is accessible or remotely where the metering tube is inaccessible
Coriolis flow meters shall be used where mass flow or density outputs are required, high accuracies are needed, when no obstructions to flow are desired (i.e. suspended solids) and when no straight meter run is available.
Coriolis flow meters can be used in corrosive fluids and viscous fluids or light slurry service.
The calibration parameters shall be stored in non-volatile memory, and be capable of being reconfigured in the field. The transmitter shall provide two independently configurable 4-20 mA analogue outputs, proportional to flow rate, density or temperature; one frequency output proportional to flow rate and independent of the analogue outputs; one digital output indicating flow direction, fault alarm, or zero in progress.
The selected location for Coriolis type flow meters must be free of sources of electromagnetic interference and vibration. The inlet and outlet piping must be anchored securely to avoid transmitting stresses and vibration to the flow meter.
For liquid flow meters, the sensing tubes must be mounted such that slug flow is minimized and entrained gases can exit the meter. In addition, the piping must remain full during operation. Adequate backpressure must be maintained to avoid flashing and cavitation.
Since the pressure loss is substantially higher than other flow meters, design shall ensure that cavitation and flashing does not occur.
For gas flow meters, the sensing tubes must be mounted such that any liquids can freely drain from the meter.
Coriolis flow meters shall be in line flanged type.
10.3.2 Thermal Mass Flow Meter
Unless otherwise stated in the instrument data, the minimum accuracy and rangeability of the Thermal mass flow meters shall be as per AGES-PH-04-001.
Thermal flow meters are thermal conductivity dependent, as such, they shall not be used for continuous flow measurement of hydrocarbon streams that are mixed with a non-hydrocarbon gas, particularly hydrogen. Thermal flow meter is also not suitable for refinery flare gas measurement because of the fluctuation of the hydrogen content and also not to be used for wet steam measurement or other fluids with entrained liquids. This flow meter is also not recommended for streams where coatings can occur.
Thermal mass flow meter type selection (constant power and constant temperature) shall be in consultation with manufacturer based on its proven record for similar application. For better measurement time response,
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the constant temperature type meter is generally preferred. Where reaction time of less than five seconds is necessary, constant power type is typically selected.
The straight run requirements shall be considered as per ASME MFC-21.2
For applications where better accuracy and turn-down is required, multi-probe type can be considered. The maximum operating temperature limit of thermal flow meter shall be considered during its selection and design
Thermal mass flow meters may be used metering clean gases and flare gas flow measurements. Thermal flow meter shall be supplied with factory calibration report for specific application considering its sensitiveness to fluid’s physical properties.
The Insertion Thermal Mass flow meter shall be supplied as a flange type complete with retractable probe with full bore ball valve isolation, packing gland assembly, safety chain.
The inline Thermal Mass flow meter shall be supplied complete with sensors mounted in a flanged meter tube.
10.4 Ultrasonic Flow Meters
Ultrasonic flow meter selection, design and installation shall be per requirement specified in AGES-PH-04- 001
Unless otherwise stated in the instrument data sheet, the minimum accuracy and rangeability of the ultrasonic flow meters shall be as per AGES-PH-04-001.
Ultrasonic flow meters shall be used in flare gas measurement and when a nonintrusive, no pressure loss, and/or high accuracy meter is required. Ultrasonic flow meters shall not be used in fouling services that will block or plug the transducer paths (such as waxing service).
Only ultrasonic flow meters based on the time of flight method shall be used.
When high accuracy is required, multipath ultrasonic flow meters shall be used.
Ultrasonic flow meters shall be suitable for bi-directional flow.
Low pressure gases with high hydrogen content are difficult to measure in large pipe and require internal sensors. Further, the piping configuration and accuracy requirements affect the number and orientation of the transducers which shall be considered during selection. The limitation from maximum allowable viscosity shall also be considered in the selection of ultrasonic flow meter.
The ultrasonic flow meters shall be provided with noise rejection algorithms to prevent interference from noise source; e.g. severe service valves, pump cavitation, or vessel aeration etc. and the flow meter shall have provision to change the frequency acoustic signal to overcome the noise from process & pipe line system.
Ultrasonic shall normally be spool piece inline type with integrally mounted transducers. Clamp on type can be used subject to COMPANY approval.
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10.5 Magnetic Flow Meters
Magnetic flow transmitter shall be designed as per specification AGES-PH-04-001
Unless otherwise stated in the instrument data sheet, the minimum accuracy and rangeability of the magnetic flow meters shall be as per AGES-PH-04-001.
The metering tube shall be rated for the design pressure and temperature as per the line class. The metering tube material shall be 304 SS, unless the line class specifies otherwise. The meter tube shall be lined with a material suitable for the application. For tube liners, Teflon, Kynar, polyurethane, and in some applications, ceramics shall be among the materials considered. The liner shall be attached to the tube such that the partial or full vacuum will not cause the liner to collapse. The field coils and cores shall be field replaceable without removing the tube from the line and without affecting calibrated accuracy.
The material for the electrodes shall be selected based on process conditions. For electrodes, 316 SS, tantalum, Monel, Hastelloy C, titanium, platinum, or Alloy 20 shall be considered. Ultrasonic cleaning shall be considered where the process fluid may coat the electrodes. Grounding rings shall be furnished to assure that the fluid is at the same potential as the flow meter.
The transmitters for magnetic flow meters shall be integrally mounted where the metering tube is accessible or remotely where the metering tube is inaccessible. The transmitters shall be of a “smart” type microprocessor based design. The calibration parameters shall be stored in nonvolatile memory, and be capable of being reconfigured in the field. The transmitter shall display both the flow rate and totalized flow. ”
Magnetic flow meters shall be used in conductive liquid services such as water services, but can also be used in highly corrosive services as long as the liquid meets the minimum conductivity requirements specified by the SUPPLIER.
Magnetic flow meters shall be in line flange type.
Liner selection shall depend on service temperature and resistance to deterioration by flowing liquid.
Electrodes shall be made of corrosion resistant materials suitable to the process fluid.
Proper grounding shall be in compliance with SUPPLIER recommendations.
10.6 Turbine Flow Meters
Unless otherwise stated in the instrument data sheet, the minimum the minimum accuracy and rangeability of the turbine flow meters shall be as per AGES-PH-04-001.
The body shall be rated for the design pressure and temperature as per the line class. The body material shall be carbon steel, unless the line class specifies otherwise. The material for the internal moving parts shall be selected based on process conditions. For rotors, aluminium and 316 SS shall be considered. For inlet diffusers, stainless steel shall be considered. Bearings shall be tungsten carbide. Rotor shrouds shall be used when measuring higher viscosity fluids or fluids having varying viscosity.
Turbine meters shall be selected based on the meter’s area of operation. Adequate meter back-pressure must be verified to avoid cavitation. Due consideration shall be given to prevent turbine meters from over-
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ranging and from suffering hydraulic shock. All turbine meters shall have signal amplifiers mounted close to the meter.
Turbine meter may be used on clean liquid streams where high accuracy or greater flow rangeability is required
Turbine meters shall be used only for fluids fully in the liquid phase without solid particles. They should not be used in any dirty service.
Turbine meters should be mounted with a suitable flow conditioning assembly. It is recommended that the meter be installed downstream of a strainer for protection and upstream of the system control valve.
The use of flow conditioning plates, filters, and strainers shall be in accordance with supplier recommendations.
Turbine flow meters shall have flanged connections.
10.7 Positive Displacement Flow (PD) Meters
PD meters shall be designed, engineered and fabricated generally in accordance with API MPMS 5.2 & AGES-PH-04-001.
Unless otherwise stated in the instrument data sheet, the minimum accuracy and rangeability of the PD flow meters shall be as per AGES-PH-04-001.
Positive displacement meters shall have flanged connections and shall have a removable strainer installed ahead of each meter. The body shall be rated for the design pressure and temperature per the line class. The body material shall be carbon steel, unless the line class specifies otherwise. The body design shall minimize the effects of piping stress and vibration. The construction shall facilitate cleaning, inspection and service.
The material for the internal moving parts shall be selected based on process conditions and type of meter applied. For gear type meters 316 SS or Alloy 20 gears and shafts shall be considered. For rotor type meters, heat treated aluminum or nickel plated cast iron rotors, nitrided alloy steel shafts and stainless steel bearings shall be considered. For rotary blade type meters, heat treated aluminum, nickel plated cast iron, or 316 SS blades with stainless steel sealed bearings shall be considered.
Positive displacement meters shall normally have a direct coupled pulse generator and be provided with signal amplifiers mounted close to the meters. For fluids that are toxic or highly dangerous, magnetically coupled pulse counters shall be used.
Positive displacement meters are not recommended for use with non-lubricating liquids such as propane, butane, etc. when approved by COMPANY for use in non-lubricating process services, they shall be provided with automatic pressure lubrication of bearings, gears, etc. In addition:
a. Flow limiting devices shall be considered to prevent over-ranging of positive displacement meters. b. Certain types of positive displacement meters have their maximum capacity limited not only by flow, but also by the maximum allowable pressure drop across the meter. Consideration shall be given to limiting the maximum pressure drop especially when the meter is used with liquids having a high viscosity.
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c. Meters shall be protected against damage due to hydraulic shock, caused for example by quick
opening or closing of a valve.
The selections between turbine meters and positive displacement meters should take into account the following considerations:
a. The application of turbine meters is normally limited to products with relatively low viscosities, typically 10 mm2/s (10 cSt); positive displacement meters are recommended for higher viscosities only.
Turbine meters are preferred for use with non-lubricating liquids such as LPG, gasoline, water, etc. PD Meters shall be straight through dual case rotary vane type or oval gear type only.
In view of their considerable mass, especially for large sizes, positive displacement meters and their ancillary equipment, such as filters and vapour eliminators shall be installed such that they are well supported, and can easily be reached by hoisting equipment.
10.8 Vortex Flow Meter
Vortex meters shall be designed, engineered and fabricated generally in accordance with AGES-PH-04-001.
Unless otherwise stated in the instrument data sheet, the minimum accuracy and rangeability of the Vortex flow meters shall be as per AGES-PH-04-001
Vortex flow meters shall be used where the flow is always turbulent (as the accuracy falls off with Reynolds numbers below 20,000).
Vortex flow meters are capable of withstanding maximum temperatures up to 400°C and are suitable for low pressure drops.
Vortex meters shall be used for large ranges of flow measurements in gases or low viscosity liquids. Measured operating flow range must be 70% of calculated maximum flow range. .
The transmitter shall have integral display for the flow rate.
Vortex flow meter shall be sized to cover minimum flow conditions resulting in a smaller meter than line size.
Vortex meter shall be selected to avoid cavitation during normal or abnormal conditions.
Vortex flow meters shall be flanged connection type, reducing flange type can be used with COMPANY approval.
Dual sensor meters shall be used if control or shutdown functionality or wherever else a high availability is required.
Flow rate shall not exceed 115 to 120% of the design value to prevent damage to shedding bar. The metering tube shall be rated for the design pressure and temperature per the line class. The metering tube and shedding bar material shall be 316L SS, unless the line class specifies otherwise. The transmitters for vortex flow meters shall be integrally mounted where the metering tube is accessible or remotely where the metering
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tube is inaccessible. The transmitters shall be of a “smart” type microprocessor based design. The calibration parameters shall be stored in non-volatile memory, and be capable of being reconfigured in the field.
SECTION C – OTHER REQUIREMENTS
11 DETAILS OF SCOPE OF SUPPLY
The SUPPLIER shall supply the field instruments and accessories as stated in the purchase order and detailed in the data sheets. The provided equipment shall meet the technical requirements of this specification.
The SUPPLIER’s scope of supply will include and not be limited to:
Inspection and Test plan Inspection and Testing Procedures/Reports
a) Field instruments and accessories as stated in the purchase order. b) Data sheets and detailed sizing calculation as applicable c) List of exceptions and non-compliance d) Detailed dimensional drawings and Technical catalogue for all items e) Wiring drawing with detailed Termination Details f) Manufactures Record Book and material certificates g) Operation and maintenance manuals h) i) j) Calibration certificates, SIL certificates for Instruments in safety function k) FAT services at SUPPLIER’s facility l) Spare parts as detailed in the purchase order m) Special test equipment and tools n) Packing and preservation o) Weights and dimensions of cases for shipping p) Warranty and guarantee q) Uncertainty calculations when specified
12 QUALITY CONTROL AND ASSURANCE
SUPPLIER’s quality management systems shall comply with all the requirements of ISO 9001 - Quality Management Systems – Requirements and ISO 9004 - Quality Management — Quality of an Organization — Guidance to Achieve Sustained Success. The quality system shall provide for the planned and systematic control of all quality-related activities performed during design.
The quality management system shall be implemented in accordance with the CONTRACTORs Quality Manual and the Project Quality Plan, which shall both together with all related / referenced procedures, be submitted to COMPANY for review, comment and approval.
CONTRACTOR shall have in effect at all times, a QA/QC program, which clearly establishes the authority and responsibility of those responsible for the quality management system. Persons performing quality functions shall have sufficient and well-defined authority to enforce quality requirements that initiate, identify, recommend and provide solutions to quality problems and verify the effectiveness of the corrective action.
The CONTRACTOR shall identify in purchase documents to its SUB-CONTRACTORs all applicable QA/QC requirements imposed by the COMPANY and shall ensure compliance. On request, CONTRACTOR shall
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provide objective evidence of its QA/QC surveillance of its SUB-CONTRACTORs activities. If selected SUB- CONTRACTORs have ISO 9001 certification, as required for contracted scope, then copies of these certifications are to be provided for COMPANY review. The COMPANY may elect to waive their audits in favour of ISO 9001 registrar audits. Any contracted services without ISO 9001 certification will be subject to COMPANY audit requirements.
A representative / service engineer from Original MMS and CCS Manufacturer shall be available at site during site installation, SIT, Commissioning & SAT phases, in order to ensure QA/QC of the installation.
COMPANY reserves the right to inspect materials and workmanship standards at all stages of manufacture and to witness any or all tests. CONTRACTOR, 30 days after award but prior to the pre-inspection meeting, shall provide COMPANY with a copy of its manufacturing Inspection and Test Plan (ITP) for review and inclusion of any mandatory COMPANY / CONTRACTOR witness or hold points.
Equipment shall only be purchased from SUPPLIERs approved by COMPANY Category Management. This approval indicates that the SUPPLIER has an approved Quality management system and a proven track record in supply of this equipment type.
SUPPLIER shall comply to Criticality Rating for Equipment outlined in respective ADNOC Group Company’s Quality System Specifications for requirements of production checks, shop inspection, testing and material certification.
The SUPPLIER shall provide equipment inspection and test reports as per approved Inspection and Test Plan by CONTRACTOR.
SUPPLIER shall submit a quality plan for approval by COMPANY.
13 CERTIFICATIONS
SUPPLIER shall provide hazardous area certificates for all provided electronic field instruments.
SUPPLIER shall provide material inspection certificates requirements as specified in the purchase order.
SUPPLIER shall provide Calibration certificates & SIL certificate for devices used in safety functions.
14
INSPECTION & TESTING REQUIREMENTS
14.1 General
Prior to the start of device manufacture, an Inspection and Test Plan (ITP) shall be submitted for approval by COMPANY. The ITP shall include all inspection and test activities to be performed, including those at SUBSUPPLIERS works.
14.2 Shop Inspection Access
COMPANY and COMPANY/CONTRACTOR appointed TPI shall at all times have access to the SUPPLIER and any SUBSUPPLIER facility engaged in providing material or supplying equipment in the scope of this purchase order for the purpose of inspecting the materials and equipment.
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14.3 Factory Acceptance Test (FAT)
The FAT will evaluate each field instrument is built and operating as per the technical requirements of this specification. The FAT procedure will be provided by SUPPLIER and approved by COMPANY.
Testing and inspection shall be carried out and witnessed by the CONTRACTOR / COMPANY representatives. All formal testing shall be conducted in accordance with written test procedures
The test procedures shall be furnished by the SUPPLIER to the CONTRACTOR /COMPANY at least 15 working days prior the FAT for approval. All instruments shall be calibrated, tested and provided with calibration certificates and certification labels.
14.4 Site Acceptance Test (SAT)
The objective of the SAT is to verify that the “as installed” field devices meets or exceeds the specified functional requirements
The Supplier shall prepare a formal procedures document for Site Acceptance Tests for COMPANY approval.
15 SUBCONTRACTORS/SUBSUPPLIERS
The SUPPLIER shall assume full responsibility and overall guarantee for the equipment package and associated equipment.
The SUPPLIER shall transmit all relevant purchase order documents including specifications to his SUBSUPPLIERS and SUBCONTRACTORS.
It is the SUPPLIER’S responsibility to enforce all Purchase Order and Specification requirements on his SUBSUPPLIERS and SUBCONTRACTORS.
The SUPPLIER shall submit all relevant SUBSUPPLIER and SUBCONTRACTOR drawings and engineering data to the CONTRACTOR and COMPANY.
The SUPPLIER shall obtain and transmit all SUBSUPPLIER and SUBCONTRACTORS warranties to the CONTRACTOR/COMPANY, in addition to the system warranty.
16 SPARE PARTS
A listing of recommended spare parts for Construction and Commissioning and for two years operations shall be provided by the SUPPLIER and will be detailed in the purchase order.
Spare parts list shall be provided in COMPANY SPIR (Spare Parts Interchangeability Record) template or Project SPIR format
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17 PRESERVATION & SHIPMENT
17.1
Packing and Shipping
Preparation for shipment shall be in accordance with purchase order Preservation and Export Packing requirements and COMPANY specification of Packing and Preservation. SUPPLIER shall be solely responsible for the adequacy of the preparation for shipment provisions with respect to materials and application, and to provide equipment at the destination in ex-works condition when handled by commercial carriers. Adequate protection shall be provided to prevent mechanical damage and atmospheric corrosion in transit and at the jobsite. Preparation for shipment and packing will be subject to inspection and rejection by COMPANY’S inspectors. All costs occasioned by such rejection shall be to the account of the SUPPLIER. Equipment shall be packed and securely anchored Bracing, supports, and rigging connections shall be provided to prevent damage during transit, lifting, or unloading. Separate, loose, and spare parts shall be completely boxed. Pieces of equipment and spare parts shall be identified by item number and service and marked with CONTRACTOR’S order number, tag number, and weight, both inside and outside of each individual package or container. A bill of material shall be enclosed in each package or container of parts. One complete set of the installation, operation, and maintenance instructions shall be packed in the boxes or crates with equipment. This is in addition to the number called for in the Purchase Order.
17.2 Preservation and Storage
Equipment and materials shall be protected to withstand ocean transit and extended period of storage at the jobsite for a minimum period of 18 months. Equipment shall be protected to safeguard against all adverse environments, such as humidity, moisture, rain, dust, dirt, sand, mud, salt air, salt spray, and seawater. All equipment and material shall be preserved, and export packed in accordance with project specifications and COMPANY specification of Packing and Preservation.
18 COMMISSIONING
18.1 Pre-Commissioning Procedure
Pre-commissioning shall include, but is not limited to, the following: An audit and inspection of equipment received. A deficiency report shall be written and appropriate action taken to rectify any problems observed.
18.2
Installation
If required SUPPLIER shall provide supervision assistance for installation and commissioning of field instruments at site.
18.3 Long Term Support
SUPPLIER must provide assurances that supplied equipment will not be obsolete in the next 15 years. In the belief that equipment will eventually be withdrawn from sale, a firm commitment by the SUPPLIER that for his standard products there will be either repair capability or equivalent parts and/or products available for a minimum of 15 years from the withdrawal date is required. SUPPLIER may be requested to provide a “roadmap” of equipment obsolescence.
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19 TRAINING
SUPPLIER shall quote an option for training courses covering installation, operation and maintenance of the field instruments at COMPANY Facilities.
20 DOCUMENTATION/MANUFACTURER DATA RECORDS
SUPPLIER shall submit the type and quantity of drawings and documentation for COMPANY authorization or information as listed in the individual Requisitions and Purchase Orders.
Mutual agreement on scheduled submittal of drawings and engineering data shall be an integral part of any formal Purchase Order.
All drawings, documents, information, correspondence, test reports, operating and maintenance instructions and like items shall be in the English language and metric Units.
All documents and drawings issued by the SUPPLIER shall be produced in an electronic format compatible with recent and standard office computer software. It is desired to have as much documentation as possible available on DVD-ROM with search and retrieval capabilities
Comments made by COMPANY on drawing submittal shall not relieve SUPPLIER or SUBSUPPLIERS of any responsibility in meeting the requirements of the specifications. Such comments shall not be construed as permission to deviate from requirements of the Purchase Order unless specific and mutual agreement is reached and confirmed in writing.
Each drawing shall be provided with a block in the bottom right-hand corner incorporating the following information:
i. Official trade name of the SUPPLIER. SUPPLIER’S drawing number. ii. Drawing title giving the description of contents whereby the drawing can be identified. iii. A symbol or letter indicating the latest issue or revision. iv. PO number and item tag numbers. v.
Revisions to drawing shall be identified with symbols adjacent to the alterations, a brief description in tabular form of each revision shall be given, and if applicable, the authority and date of the revision shall be listed. The term “Latest Revision” shall not be used.
The below list of documents required is intended to define the minimum technical documents to be provided by the VEDNOR. This list is not exhaustive and additional documentation necessary for the work execution shall be provided by SUPPLIER.
i. ii. iii. iv. v. vi. vii. viii. ix. x. xi. xii.
Clause wise compliance to specification and List of deviations/exceptions to requirements specified. Technical catalogue for all items including accessories, drawings, etc. Drawings for all items including weight details, GA drawings, etc. Electrical drawings and schematics Bill of materials Instruments datasheets Hazardous area certificates Inspection and Test Plan (ITP) FAT/SAT procedure Test certificates and reports. Calibration Certificates. IP or NEMA Class Certificates
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Natural frequency, Vortex frequency & other calculations for thermowells xiii. NDE results xiv. xv. PMI results xvi. QA/QC procedure xvii. xviii. xix. xx. Operations and Maintenance Manuals Safety Manual (if SIL rating is required) xxi. SIL Rating Certificates (for ESD instruments) xxii. Sizing calculation reports for flow instruments xxiii.
List of spare parts, tools and test equipment Packing Marking and Shipping Procedure Preservation and Site Storage Procedure
21 GUARANTEES & WARRANTY
The SUPPLIER shall guarantee, in accordance with the general conditions, that the provided equipment shall meet the performance conditions specified in this specification, the purchase order, associated documents and Data Sheets.
The SUPPLIER will provide warranty services for a minimum period of 18 months from purchase date or 12 months after installation, whichever is later. The warranty services shall comprise any diagnostic services, on-site repairs or replacements, and technical support required to ensure that the instruments operate as specified during the defined warranty period and shall be provided at no additional cost to COMPANY.
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SECTION D – STANDARD DRAWINGS & DATASHEETS
22 DATA SHEETS TEMPLATES
Data sheets shall be prepared in the format as Per Project Template Requirements.
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23 STANDARD DRAWINGS
Thermowell Standard Drawing (All Dimensions are in mm)
Figure 1
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Figure 2
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Figure 3
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Project: Q-32859 - NMDC - Ruwais Folder: RFQ Files