GOC Western Hemisphere Rev1(2X Print)

GUIDANCE
ON
CERTIFICATION
“Technical Integrity Management”
Western Hemisphere Edition
Revision 1
à
Guidance On Certification
http://houston.bpweb.bp.com/gocmancon/
GOC ©
BP Exploration 1989 - 2001 All Rights Reserved
COMMISSIONING MANAGEMENT PROCESS
GUIDANCE
ON
CERTIFICATION
SECTIONS 1 TO 10
This guidance document has been requested by BP Assets to provide a collective Asset
statement of shared good practice on the minimum acceptable level of documentation
required to demonstrate that Technical Integrity has been acceptably achieved, and/or
reinstated following the completion of project and/or maintenance activities.
The document has been assembled by seeking the collective knowledge and
experience of BP Engineers having responsibility for Technical Integrity.
The compilation of this Asset knowledge has been compiled, organised and managed by
Upstream Technology Group (UTG) and any revision to this document should, in the first
©
©
instance, be directed to Mike Matula, GOC /MANCON Co-ordinator, Operations
Excellence & Operations Integrity.
John P. Platt
Commissioning Management Process System Custodian
Project Leader, Commissioning (Houston)
Upstream Technology Group (UTG)
[email protected]
+1 281-366-3002
John M. Johnson
Team Leader
Operations Excellence (Houston)
Upstream Technology Group (UTG)
[email protected]
+1 281-366-2799
GOC© & MANCON© Services
Western Hemisphere Edition
Mike Matula (Houston)
System Development Co-ordinator
[email protected]
+1 281-366-2298
For more Information, visit the BP Intranet Site @
http://houston.bpweb.bp.com/gocmancon
Issue Date: Rev 1 May 2001
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Western Hemisphere REV. 1
UPSTREAM
TECHNOLOGY
BP America Inc.
DISTRIBUTION
GUIDANCE ON CERTIFICATION
Copy 1.1
Copy 1.2
Copy 1.3
Copy 1.4
J. P. Platt - Commissioning Management Process (Custodian Consultant)
M. K. Matula - Commissioning Management Co-ordinator (Houston)
J. R. Douglas - Commissioning Management Co-ordinator (Aberdeen)
Alan Dean - GOC Consultant (Aberdeen)
SUPPORT / SERVICE GROUPS
ASSETS
ASSET PARTNERS
TO BE FINALIZED
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: i
CONTENTS
SECTION
DESCRIPTION
1.0
SYSTEM PRINCIPLES
1
1.1
INTRODUCTION
3
1.2
SYSTEM OVERVIEW
5
1.2.1 Purpose
1.2.2 Objective
1.2.3 Execution
5
5
6
1.2.4 Certification Management Database
6
1.2.5 Definitions
7
1.3
1.4
PAGE
FUNCTIONAL SYSTEMIZATION
1.3.1 General
1.3.2 Scope
1.3.3 Philosophy
8
8
8
1.3.4 System Schematics
1.3.5 Generic Examples
1.3.6 Specific Examples
1.3.7 Isolations
1.3.8 Controls and Cables
10
16
17
25
26
SYSTEM MECHANICS
1.4.1 Limits of System Handover
1.4.2 Data Input Sheets
1.4.3 Inspection and Test Plan
1.4.4 Handover Certification Packs (HCP)
1.4.5 System Safe Certificate (SS1)
1.4.6 Mechanical Completion Certificate (MC1)
1.4.7 System Handover Certificate (SH1)
1.4.8 Plant Performance Certificate (PP1)
1.4.9 Punch List (PL1)
33
33
34
35
35
36
37
38
40
41
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: ii
CONTENTS (cont.)
SECTION
DESCRIPTION
1.0
1.5
1.6
1.7
PAGE
KEY PERSONNEL
43
1.5.1 Nomination of Authorities
43
1.5.2 Design/Maintenance Planning Authority
43
1.5.3 Construction/Maintenance Authority
1.5.4 Commissioning Authority
44
44
1.5.5 Certification Administrator
1.5.6 Handover Management
1.5.7 Operating Authority
44
44
45
CHANGE CONTROL
1.6.1 Requirement for Change
45
45
1.6.2 Handover Change Request
45
1.6.3 MANCON Change
46
SYSTEM FLOW
47
1.7.1 Sequence of Events
1.7.2 Flowcharts
1.7.3 Handover Sequence of Events (Off-Site)
47
50
51
1.7.4. Handover Sequence of Events (On-Site)
1.7.5 Handover Change Request (HCR)
52
53
EXHIBIT 1
1.
List of Standard Forms
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
54
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: iii
CONTENTS (cont.)
PAGE
APPENDIX 1
1.0
Examples of an Operations System Mnemonics Matrices
i
1.1
Examples of System Limits.
ii
1.2
GOC "Carrier" Certificate Example
iii
Technical Integrity Assurance Flowcharts
Functional Certification Flowchart
1.3
Example Basis of Design Contents
iv
1.4
Asset Nomination of Authorities
v
1.5
Glossary of Terms
iv
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: iv
CONTENTS (cont.)
SECTION
DESCRIPTION
2.0
WELDING AND NDE
1
2.1
ACTIONS
2
2.1.1 General
2
2.1.2 Welders Qualifications
2.1.3 Prior Qualifications
3
3
2.1.4 NDE Qualiications
3
WELD INSPECTION
2.2.1. General
2.2.2 Use of Forms
4
4
8
2.2
PAGE
FLOWCHART 2
1.
Welding Flowchart
13
List Of Standard Forms
14
EXHIBIT 2
1.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: v
CONTENTS (cont.)
SECTION
DESCRIPTION
PAGE
3.0
PIPE TESTING
1
3.1
ACTIONS
3.1.1 General
2
2
3.1.2 Use of Forms
3
3.1.3 Calibration
8
INSTALLATION
10
Pressure Test Procedure 3.1
3.1.1 - Joint Integrity Installation
11
11
3.1.2 - Piping Pre-test Inspection
3.1.3 - Hydrotest Cleaning & Flushing
3.1.4 - Hydrostatic Testing
15
19
21
3.1.5 - Pneumatic Testing
3.1.6 - Piping Completion
3.1.7 - Fire & Gas Piping Completion
25
27
30
3.1.8 - Certification
31
OPERABILITY
32
Leak Test Procedure 3.2
3.2.1 - System Flushing Procedure
3.2.2 - Leak Test Procedure
3.2.3 - Critical Joint Installation
3.2.4 - Service Test Procedure
32
32
34
40
41
3.2.5 - Certification
43
PROCEDURES
FLOWCHART 3
1.
Pipe Testing Certification Flowchart
44
EXHIBIT 3
1.
List of Standard Forms
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
45
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: vi
CONTENTS (cont.)
SECTION
DESCRIPTION
4.0
MECHANICAL EQUIPMENT
1
4.1
ACTIONS
4.1.1 General
4.1.2 Pumps and Compressors
4.1.3 Skid Mounted Units
4.1.4 Vessels and Tanks
4.1.5 Mechanical Handling
4.1.6 Use of Forms
2
2
2
2
3
3
7
INSTALLATION & OPERABILITY
9
Machinery
4.1 - Pump/Compressor/Skid Mounted Unit Inst.
4.2 - Machinery Alignment
10
13
PROCEDURES
PAGE
Vessels
4.3 - General Requirements & Pressure Safety
Relief Devices
17
4.4 - Vessel & Tanks Fabricated (Off-Site)
4.5 - Vessel & Tanks Modified (On-Site)
24
26
Mechanical Handling
4.6 - Cranes
4.7 - Hoists, Trolleys and Gantries
4.8 - Trolley Beams and Pad Eyes
4.9 - Lifeboat Davits and Lifeboat
28
31
33
36
FLOWCHARTS 4
1. Certification Flowchart 1 - Mechanical Equipment
2. Certification Flowchart 2 - Vessels And Tanks
3. Certification Flowchart 3 - Mechanical Handling
39
40
41
EXHIBIT 4
1. List of Standard Forms
GOC©
42
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: vii
CONTENTS (cont.)
SECTION
DESCRIPTION
PAGE
5.0
STRUCTURAL
1
5.1
ACTIONS
5.1.1 General
5.1.2 Installation
5.1.3 Use of Forms
2
2
3
3
Structural Certification Flowchart
5
List Of Standard Forms
6
FLOWCHART 5
1.
EXHIBIT 5
1.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: viii
CONTENTS (cont.)
SECTION
DESCRIPTION
6.0
HVAC
6.1
PROCEDURES
PAGE
1
ACTIONS
6.1.1 General
6.1.2 Installation
6.1.3 Use of Forms
6.1.4 Calibration
2
2
2
3
7
INSTALLATION & OPERABILITY
8
6.1 - General Requirements
6.2 - Dampers
6.3 - Filtration
6.4 - Heating and Cooling Coils
6.5 - Centrifugal Fans and Drivers
6.6 - Humidifiers
6.7 - Terminal Unit, Grills & Diffusers
6.8 - Air Conditioning Units
6.9 - Air Handling Unit
6.10 - Ductwork
6.11 - Sound Attenuators
6.12 - Cooling Towers
6.13 - Areas Receiving HVAC Supply
9
11
14
16
18
21
23
25
27
29
32
34
36
FLOWCHART 6
1.
HVAC Certification Flowchart
38
List Of Standard Forms
39
EXHIBIT 6
1.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: ix
CONTENTS (cont.)
SECTION
DESCRIPTION
PAGE
7.0
ARCHITECTURAL SERVICES
1
7.1
ACTIONS
7.1.1 General
7.1.2 Use of Forms
2
2
2
Architectural Services Flowchart
4
List of Standard Forms
5
FLOWCHART 7
1.
EXHIBIT 7
1.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: x
CONTENTS (cont.)
SECTION
DESCRIPTION
8.0
CONTROL
1
8.1
ACTIONS
8.1.1 General
8.1.2 Use of Forms
2
2
4
INSTALLATION & OPERABILITY
7
8.1 - Impulse line Pressure Testing
8
8.2 - Control Cable & Fiber Optic Cable Testing
12
8.3 - General/Calibration/Installation
and Cold Loop Checking
17
8.4 - Powered Up Loop and
Function Testing
30
8.5 - System Control (Function) Testing
36
8.6 - System Performance "HIPS"
(High Integrity Performance System) Tests
37
PROCEDURES
PAGE
8.7 - Programmable Logic Controller Panels (PLCP) 41
FLOWCHART 8
1.
Control Certification Flowchart
45
List of Standard Forms
46
EXHIBIT 8
1.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: xi
CONTENTS (cont.)
SECTION
DESCRIPTION
9.0
ELECTRICAL
1
9.1
2
2
3
4
7
8
9
PROCEDURES
ACTIONS
9.1.1 General
9.1.2 Installation
9.1.3 Pre-Acceptance Procedure
9.1.4 Energization and Commissioning
9.1.5 Permit to Work Procedures
9.1.6 Safety Precautions
INSTALLATION & OPERABILITY
PAGE
10
9.1 - Power and Control Cables and Instrument
Cables
11
9.2 - Switch Gear, Motor Control Centers and
Metal Enclosed Bus Duct
23
9.3 - Circuit Breakers - Air, Molded Case and Oil
Immersed
32
9.4 - Contactor Starters and Variable Frequency
Drives
42
9.5 - Medium Voltage Air Switches
48
9.6 - Power Transformers; Oil Filled and Dry Type 51
9.7 - Motors
62
9.8 - Batteries and Battery Chargers
69
9.9 - U.P.S.
76
9.10 - Lighting and Small Power Distribution System 78
9.11 - Navigation Aids (Nav-aids)
84
9.12 - Neutral Grounding Resistors
87
9.13 - Heat Trace Cables and Circuits
90
9.14 - Grounding/Bonding
95
9.15 - Equipment for use in Hazardous Locations
97
9.16 - Oil Insulation Tests
102
9.17 - Drying of Electrical Rotating Machinery
103
9.18 - Instrument Transformer Verifications
106
9.19 - Junction Box Inspection
109
9.20 - Protective Relay Testing and Metering Circuits 111
9.21 - A.C. Generators
113
FLOWCHART 9
1.
Electrical Certification Flowchart
120
List of Standard Forms
121
EXHIBIT 9
1.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
CONTENTS - SECTIONS 1 to SECTION 10
CONTENTS
REVISION: 1
PAGE: xii
CONTENTS (cont.)
SECTION
DESCRIPTION
10.0
Civil Construction
1
10.1
2
2
ACTIONS
10.1.1 General
PAGE
10.2 Civil Work
10.2.1 Scope
10.2.2 General
10.2.3 Soils and Earthwork
10.2.4 Piling Operations
10.2.5 Concrete
3
3
3
5
5
5
10.3 Steel Construction
10.3.1 General
7
7
10.4 Piping
10.4.1 General
7
7
10.5 Use of Forms
8
10.6 Buildings, Fittings and Furnishings (Architectural)
10.6.1 General
10.6.2 Inspection Requirements
10.6.3 Surface Finishes
10.6.4 Windows and Doors
10.6.5 Fittings
10.6.6 Safety Items
10.6.7 Soft Furnishings
10.6.8 Buildings, Fittings and Furnishings
Certificate (Architectural)
11
11
12
12
13
13
14
15
15
FLOWCHART 10
1.
Civil Construction Certification Flowchart
16
Civil Buildings Certification Flowchart
17
List of Standard Forms
18
FLOWCHART 11
1.
EXHIBIT 10
1.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC © AMERICAS EDITION
REVISION: 1
SYSTEM PRINCIPLES
SECTION 1.0
SYSTEM PRINCIPLES
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
PAGE: 1
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SYSTEM PRINCIPLES
PAGE: 2
REVISION RECORD
NOTE:
Revisions are denoted in one of two ways:
i.
By a line in the right hand margin for narrative sections with the
revision number on the right.
ii. By the symbol
2
with the revision number denoted within.
REV.
DESCRIPTION OF REVISION
Date
0
1
Draft – Milne Point Pilot
First Issue
March 1998
May 2001
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
1.1
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SYSTEM PRINCIPLES
PAGE: 3
INTRODUCTION
The BP Exploration Guidance On Certification© (GOC©) has been
developed and updated, with input from the users, over a considerable
period, improving the efficiency of the Certification process by reducing
certificates to a minimum level that achieves the demonstrability of
Operational Technical Integrity. The GOC© is an integrated process that
incorporates commissioning, system turnover procedure and an
enhanced documentation procedure.
BP has attempted to keep the text to a minimum by use of flow
charts/examples where possible, and provide a "user-friendly"
document.
The Certificates and associated procedures provide the basis for
Inspection and Test (I&T) requirements, and can be applied to all new
projects, existing operational/maintenance activities and third party
fabrication. Use of the principles embodied in the GOC© enables Assets
to demonstrably achieve compliance with BP - “Getting HSE Right.”
The GOC© has been developed together with an associated
computerized certification management database (MANCON©), which
provides an electronic means to record, track and manage the I&T
activities. It should be noted that Assets can choose the certificates and
associated procedures contained in the GOC© without the MANCON©
database by substituting their chosen method of recording, tracking and
managing I&T activities. In this case, Assets should demonstrate
compliance to the above Performance Standards in the manner
described in their Safety Case.
BP Upstream Technology Group is the custodian of the GOC© and
MANCON©. Procedures will be developed to enable individual assets to
propose changes and maintain the continuous improvement process
that has been embodied in the current form of the GOC©/MANCON©.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
SYSTEM PRINCIPLES
©
The GOC
PAGE: 4
is sub-divided to assist easy access to the relevant
information.
Section 1:
System Principles
Section 2:
Section 3:
Welding and NDE
Piping
Section 4:
Mechanical
Section 5:
Section 6:
Structural
HVAC
Section 7:
Architectural
Section 8:
Control
Section 9:
Section 10:
Electrical
Civil
Within the individual discipline sections are contained the specific
procedures relevant to that discipline, plus the associated certificate proforma's.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
PAGE: 5
SYSTEM PRINCIPLES
1.2
SYSTEM OVERVIEW
1.2.1
Purpose
The intent of this document is to provide guidance on a management
control system for inspection and test (I&T) activities associated with
fabrication,
construction,
pre-commissioning,
commissioning
and
maintenance of systems being worked upon and handed over for
operation. Given the different character of individual assets and the
correspondingly different management structures in operation, it is
intended that this document merely forms the basis from which detailed,
step-by-step, individual asset based management procedures would be
developed.
1.2.2
Objective
To provide a system that, for a given new project, maintenance routine
or modification change, fulfills the following:
(a)
Identification of the limits of the system to be maintained/modified
and then handed over for operation.
(b)
For the identified limits, identifies the minimum inspection and test
(I&T) requirements for the given maintenance or modification
activity.
(c)
Identification of I&T authorities.
(d)
Standard methods of measurement for both the performance of
I&T activities and recording of requisite data.
(e) Establishes those I&T requirements satisfactorily achieved.
(f) Identification of the key personnel involved in the preparation and
acceptance of handover documentation, in readiness for the next
stage of activities.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
(g)
SYSTEM PRINCIPLES
PAGE: 6
Definition of the mechanisms for handover of the system identified
above, from the design/maintenance planning stage, through the
principal authorities, and finally to the operational stage.
(h)
Monitoring of the ongoing status of I&T activities.
(i)
A recording and tracking mechanism for works outstanding after
handover.
1.2.3
Execution
The following sections detail the fundamental components of the
system:
Section 1.3 - explains limit identification philosophy for functional
system breaks.
Section 1.4 - describes the principal elements employed in the
execution of the system.
Section 1.5 - details the key personnel (and their roles and
responsibilities).
Section 1.6 - details the change control procedures to be followed where
changes are required to either the original systems limits or
associated I&T requirements.
Section 1.7 - describes the sequence of events.
1.2.4
Commissioning Certification Management System
A number of the certification recording/tracking objectives, can be met
by the BP PC-based, Certification Management Database, known as
MANCON©. Individual discipline I&T requirements, once identified, can
be inputed into the system database and the system enables an I&T
plan (per discipline) to be generated. The database is available, for
updating as Engineering Queries (EQ’s) are raised, original
requirements re-defined, I&T activities are completed, handover(s) and
"as-built" requirements are achieved, thereby allowing the status to be
continually assessed (as required).
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SYSTEM PRINCIPLES
PAGE: 7
At the handover stage, outstanding work (punch lists and "as-built"
requirements, etc.) can also be recorded. The database may then be
accessed for the control, storage and retrieval of I&T records.
©
This document makes many references to MANCON , a typical
certification management system available and in use within BP. This is
used as an example only, to illustrate where certification and the control
of it, are interlinked. Individual assets may have their own alternative
systems, in which case their system name/procedures should replace
the word "MANCON©."
Detailed operational data for MANCON© is contained within a
MANCON© user manual.
1.2.5
Definitions
Inspection and Test Summary (ITS):
The Inspection and Test Summary is a document that details the
minimum Inspection and Test Requirements for specified activities.
Delegated Authority:
Resource Organization appointed by BP to carry out Engineering and/or
Construction activities on their behalf, for example via a Partnering or
Alliance Contract.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
1.3
1.3.1
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SYSTEM PRINCIPLES
PAGE: 8
FUNCTIONAL SYSTEMIZATION
General
Within the Whole Life Cycle context the maintenance of a consistent and
coherent philosophy for functional system limits is fundamentally
important.
This allows information to be developed, transferred,
modified etc. throughout the asset life, since it is based on identifying
functional system limits that are relevant during both the project and
operational phases.
1.3.2
Scope
This section details the philosophy to be applied when defining functional
system limits, in order that this may be linked to, and consistent with, the
document numbering system and the content of critical operational
drawings, in particular P & ID’s and E & ID’s. Examples are included for
clarification.
1.3.3
Philosophy
It is recognized that the approach currently used during the project
phase to develop PFD’s and P & ID’s is largely done by using “design
orientated” experience, and this section attempts to describe a process
to achieve a consistent approach, during all the phases of the asset.
A functional approach is different in that emphasis is placed upon what
the system does, not what the system is. As a result system limits are
not constructed from equipment packages, but rather from a strict
analysis of how the various functions needed of a facility are provided.
Also, as the facility design is developed, some decisions about
equipment selection may be undecided, this approach centres upon the
intended function of the facility equipment rather than the equipment
units themselves.
This function is top down, with a single function at the apex, describing at
the highest level why the installation exists. All other functions are
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SYSTEM PRINCIPLES
PAGE: 9
arranged as sub-functions, supporting the main function(s), at various
levels. The level of a function does not represent a measure of its
importance or criticality, merely that the function cannot be adequately
described without decomposing it into a number of sub-functions.
The primary principle should be that all valves, equipment, control
rooms/panels and/or cabling etc. that can be uniquely identified as
supporting a single function should be categorized within that system.
A secondary principle, is that for each uniquely quantifiable functional
component, the actual functional system boundary, in the absence of an
alternative operational need, shall “normally” exist, at the upstream
connection point of the first unique isolating device on the feed side and
the downstream connection point of the final unique isolating device on
the outlet side, as defined by the forward flow direction.
The BP Andrew Functional Relationships are included to illustrate these
points.
Each P & ID should, ideally, contain a single principle system, which, by
definition, contains a function by its boundaries. This then allows each P
& ID to be numbered in a way that reflects the system it represents, as
detailed in the Document Numbering System document (ETAP-PCMEN-902).
The BP Andrew Potable Water Utility P & ID is included to illustrate this
and how this relates to Functional Block A326 in the BP Andrew
Functional Relationships. Drawing number (ADP-PR-PID-0569-001)
illustrates how the P & ID boundary, functional system boundary and
function relate at the Accommodation Interface.
In practice, to aid comprehension and avoid the potential for errors
occurring, the size of a system may need more than one drawing to fully
describe its functionality. In this case, the individual drawing numbers
should be so structured to have consistency with each of the drawings
describing the total functional system.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
1.3.4
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SYSTEM PRINCIPLES
PAGE: 10
System Schematics
The guide to viewing the attached figures is summarized as follows :
Figure 1: Typical North Sea platform PFD (Andrew)
Figure 2: Primary System breakdown i.e Wells (100 series), Oil Processing (200
series), Gas Processing (300 series) and Flares (500 series)
Figure 3: Breakdown of Oil Processing (200 series) into sub-systems
Figure 4:
Breakdown of Gas Processing (300 series) into sub-systems
Figure 5: Figures 3 and 4 combined
Figure 6: Actual systems used on Andrew, with each color representing a
different system - note anomoloies such as suction scrubber on 2nd
stage of HP compressor in different system to compressor itself
Figure 7: Figures 5 and 6 combined
Figure 8: Typical use of integration of Tagging Philosophy with
FunctionalSystemization to improve clarity for everyone: projects,
commissioning, operations, etc.
Figure 9: Example of application throughout the facility - mainly to show E&I
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SYSTEM PRINCIPLES
HP
FLARE
GAS
LIFT
GAS
EXPORT
ASC
ASC
GAS
INJ.
TEG
PLANT
HP
FLARE
ASC
HP
FLARE
LP
FLARE
LIQUID
EXPORT
TEST
SEPARATOR
Figure 1: Typical North Sea platform PFD (Andrew)
HP
FLARE
GAS
LIFT
GAS
EXPORT
ASC
ASC
GAS
INJ.
TEG
PLANT
HP
FLARE
ASC
HP
FLARE
LP
FLARE
LIQUID
EXPORT
TEST
SEPARATOR
Figure 2: Primary System breakdown i.e Wells (100 series), Oil Processing (200
series), Gas Processing (300 series) and Flares (500 series)
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SYSTEM PRINCIPLES
HP
FLARE
GAS
LIFT
GAS
EXPORT
ASC
ASC
GAS
INJ.
TEG
PLANT
HP
FLARE
ASC
HP
[200]
FLARE
[510]
[1xx]
[210]
LP [520]
FLARE
LIQUID
EXPORT
[220]
TEST
SEPARATOR
[260]
[250]
[240]
[230]
Figure 3: Breakdown of Oil Processing (200 series) into sub-systems
[510] HP
FLARE
[350]
[340]
GAS
LIFT
[1xx]
[360]
GAS
EXPORT
[370]
ASC
[380]
[330]
[320]
ASC
GAS
INJ.
[1xx]
TEG
PLANT
HP
FLARE
[510]
[310]
ASC
HP
FLARE
LP
FLARE
LIQUID
EXPORT
TEST
SEPARATOR
Figure 4: Breakdown of Gas Processing (300 series) into sub-systems
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SYSTEM PRINCIPLES
HP
FLARE
[350]
[340]
GAS
LIFT
[1xx]
[360]
GAS
EXPORT
[370]
ASC
[380]
[330]
[320]
ASC
GAS
INJ.
TEG
PLANT
HP
FLARE
[510]
ASC
[310]
HP
[200]
FLARE
[510]
[1xx]
[210]
LP [520]
FLARE
LIQUID
EXPORT
[220]
TEST
SEPARATOR
[260]
Figure 5:
[230]
[250]
[240]
Figures 3 and 4 combined
HP
FLARE
GAS
LIFT
GAS
EXPORT
ASC
ASC
GAS
INJ.
TEG
PLANT
HP
FLARE
ASC
HP
FLARE
LP
FLARE
LIQUID
EXPORT
TEST
SEPARATOR
Figure 6: Actual systems used on Andrew, with each color representing a different
system - note anomoloies such as suction scrubber on 2nd stage of HP
compressor in different system to compressor itself
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SYSTEM PRINCIPLES
HP
FLARE
GAS
LIFT
GAS
EXPORT
ASC
ASC
GAS
INJ.
TEG
PLANT
HP
FLARE
ASC
HP
FLARE
LP
FLARE
LIQUID
EXPORT
TEST
SEPARATOR
Figure 7:
Figures 5 and 6 combined
HP
FLARE
[510]
[330]
[320]
PCV-33001
PIC-33001
ASCV-32001
ASC-32001
[340]
ASC
V-33001
V-32001
X-32001
TEG
PLANT
X-33001
LCV-33001
Z-33001
K-32001
[211]
[211]
[310]
[210]
Figure 8: Typical use of integration of Tagging Philosophy with Functional
Systemization to improve clarity for projects, commissioning, operations, etc.
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SUBJECT:
PACKAGE 1
ECP3003
U.P.S.
SUITE
A.C. DIST
SECTION
PAGE: 15
SYSTEM PRINCIPLES
11 KV SUPPLY
CB 4
EMERGENCY
STOP
PB 1
PACKAGE IX
RED
SHUTDOWN
SYSTEM
V.S.D.
TRANSFORMER
T 3008
EMERGENCY
STOP
PB 2
V.S.D.
CUBICLES
K 3000 VSD - CP
REMOTE EMERGENCY
STOP
HEAT
EXCHANGE
FAN
K 3000 & K 3001
INTERPOSING
RELAY PANEL
COMPRESSOR
CONTROL PANEL
AUX. MCC 12
NGL CONTROL ROOM
SOUTH WEST CANTILEVER
MB-AL-E-006
TRACE HEATING
PANEL ‘D’
TO GAS LIFT
MANIFOLD
COMPRESSOR SKID
MOTOR
PROCESS SKID
FROM SOURCE
GAS SUPPLY
PACKAGE LIMITS
SYSTEM LIMITS
Figure 9: Example of application throughout the facility - mainly to show E&I
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REVISION: 1
SUBJECT:
1.3.5
PAGE: 16
SYSTEM PRINCIPLES
Generic Examples
Traditionally, some P & ID’s have contained more than one system e.g.
the production manifold and test manifold are commonly shown on the
same drawing.
Using the philosophy described over; as they clearly
have different functions and hence are in different systems they should
be represented on different drawings.
Some items have to be shown in a line that is part of a function that the
item is not supporting directly.
L
System “C”
System “A”
L
S
F
System “B”
B
A B
Distributed systems are sometimes difficult i.e. where the generation and
distribution are traditionally in one system. However, from the primary
isolation point providing a supply into another function should be shown
on that system. See cooling water supply example illustrated below.
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SYSTEM PRINCIPLES
PAGE: 17
Specific Examples
Utility headers and connection to equipment e.g. Cooling water.
The system break will be upstream of the inlet block valve and
downstream of the outlet block valve.
System “B”
System “A”
System “B”
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SYSTEM PRINCIPLES
1.3.6.1 Relief valves and connection to vent header
System “B”
System “A”
1.3.6.2 Tank on level control
System “B”
System “A”
GOC©
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SYSTEM PRINCIPLES
1.3.6.3 Wells and Manifolds
WELL
System “D”
System “A”
System “B”
System “F”
System “C”
System “E”
1.3.6.4 Chemical Injection
System “A”
GOC©
DU
System “B”
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SYSTEM PRINCIPLES
1.3.6.5 System Total Bypass
System “B”
System “A”
1.3.6.6 Pig Receiver
System “B”
System “A”
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1.3.6.7
PAGE: 21
SYSTEM PRINCIPLES
Metering (Test and Allocation).
P
F
L
L
F
F
ALLOCATION
METERING
SYSTEM “C”
System “A”
P
F
L
L
F
F
System “B”
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METERING
SYSTEM “A”
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SYSTEM “B”
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REVISION: 1
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SYSTEM PRINCIPLES
1.3.6.8 Double Barrier Isolation
System “A”
PI
System “B”
1.3.6.9 Cascaded Instrumentation
F
System “A”
L
F
GOC©
P
L
F
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SYSTEM PRINCIPLES
1.3.6.10 Power and Control Connections
System “A”
11 KV
System “E”
LOGIC
3.3 KV
P
System “D”
C
C
System “B”
GOC©
415 V
System “C”
T
OCR
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A
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SYSTEM PRINCIPLES
1.3.6.11 Control Interconnections
PIC
PT
System “A”
FQI
TT
FT
WV
UMV
System “B”
LMV
LMV
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SYSTEM PRINCIPLES
Isolations
An understanding of where and why the equipment is isolated, will aid
where the boundaries are and which side of valves they occur.
As
detailed in section 1.3.3, the actual functional system boundary shall
“normally” exist at the upstream and downstream connections of the
initial and final unique isolating devices, as defined by the forward flow
direction.
1.3.7.1 On-line Maintenance
Where a specific system may be isolated for maintenance without
affecting the capability to achieve the primary functionality of that section
of plant, then the level of isolation and acceptable leakage criteria is
extremely important.
System “A”
PI
PI
System “B”
In the illustration above, the pressure and flow in the main line (system
“A”) are fully operational while system “B” is isolated for maintenance.
1.3.7.2 Off-line Maintenance
When a specific system, necessary to support achievement of the
primary functionality of that section of plant, such as the HP separator in
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SYSTEM PRINCIPLES
PAGE: 26
a single train operation i.e. no sparing, is de-commissioned for
maintenance, it is normal practice to depressurise adjacent systems. In
this case the level of isolation and the leakage criteria are less severe.
These isolations and understanding which side of the valve would
require to be hydrocarbon free should be the system boundaries.
1.3.8 Controls and Cables
General
Each process primary system contains a sub-system for control panels
(96), and multicore cables (97), associated with that primary system.
Systemization of these configurations is straightforward, provided all
cables and equipment associated with that configuration resides in just
one primary system. The examples shown in section 1.3.8.1
demonstrate systemization of such configurations.
The introduction of Integrated Process Control Systems into our industry
changes our approach to systemization of control panels and their
multicore cables. These high technology panels perform complete
process control, ESD and in some cases fire and gas monitoring and
detection, and cannot be categorized into any one of the process primary
systems. Therefore, these ICS panels and their associated multicore
cables have been allocated their own secondary number in primary
system 6 (Safety). The examples shown in section 1.3.8.3 demonstrate
systemization of such configurations.
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REVISION: 1
PAGE: 27
SYSTEM PRINCIPLES
1.3.8.1 Local Control Panel Systemization
The following examples show a variety of different hook ups to control
panels, which serve only one primary system. It is important to remember
that all cables and equipment must reside in that primary system.
In the majority of cases stand alone control panels, their multicore cables,
junction boxes and field devices, naturally fall into only one primary system,
due to the location of field junction boxes and field devices. The
systemization of this equipment and their cables are straightforward, in that
they are all part of the same system. A local control panel serving system A
would be systematized as follows:
Local
Control
Panel
JB
Multicore
Cable 1
Cable 2
FT..
PT..
Cable 3
System A96…
TT..
System AXY…
All three field devices (FT, PT, TT) are in primary system ‘A’, and
secondary system ‘XY’. Therefore cables 1,2 and 3 become part of the
same primary and secondary system, as does the multicore cable. The
control panel only serves primary system A .
The system limits for the above example would be:
Control panel and its power supplies
A96
Multicore cable, JB, Cables 1,2 &3 and Field equipment AXY (where XY is
the secondary number)
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1.3.8.2
PAGE: 28
SYSTEM PRINCIPLES
In this example, the control panel serves more than one subsystem of
primary system A.
System AXY…
Control
Panel
JB1
Multicores
Cable 1
Cable 2
Cable 3
JB2
JB3
Cable 4
Cable 5
FT
PT
TT
LT
PT
System A96…
Cable 6
JB4
ZS
System A97…
System AXZ…
In the case where there are multiple multicore cables leaving the control
panel each to a different main junction box in the same primary system,
then systemization would be as follows:
Control panel and its power supplies
A96
Multicore cables and JBs
A97
Field devices and their cables would come under their respective secondary
system number, in this case AXY and AXZ
In this instance, the multicores have been separated from their respective
secondary system and given a separate number (A97). This is to ensure
that all multicores are installed and tested before any system is
commissioned, and furthermore to reduce to amount of cable work such as
glanding and terminating that has to be carried out when the panel is ‘live’
and partly operational.
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SYSTEM PRINCIPLES
Integrated Control Panel Systemization
Integrated Control Systems and their multicores are covered in the safety
primary system number (6).
System AXY…
ICS
Panel
Cable 1
JB1
FT
Cable 2
Multicores
PT
Cable 3
TT
Cable 4
LT
JB2
JB3
Cable 5
PT
System 690…
JB4
Cable 6
System 697…
1.3.8.4
ZS
System BXZ…
Typical Integrated system field hook-up
The example above, shows field equipment located in two primary systems
AXY… and BXZ… Because the multicores between the control panel and
its JBs cover two primary systems, systemization would be as shown.
As an integrated control network, the control panel and its multicore cables
would reside in the safety primary system No 6.
The multicores and JBs have a separate secondary number for the same
reason as described in example 1.3.8.2. Which is to ensure that all
multicores are installed and tested before any system is commissioned, and
furthermore to reduce to amount of cable work such as glanding and
terminating that has to be carried out inside a ‘live’ panel.
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REVISION: 1
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SYSTEM PRINCIPLES
1.3.8.5 The following example shows two subsystems of primary system A entering
a single junction box JB1, and a single multicore cable to ICS panel.
System AXY…
ICS
Panel
JB1
Multicores
Cable 1
Cable 2
Cable 3
FT
PT
TT
System AZZ…
JB2
Cable 4
JB3
Cable 5
LT
PT
System 690…
JB4
Cable 6
ZS
System 697…
System BXZ…
The system limits for this type of configuration would be as shown in the above
example, but additional handover information would be required to show the
relationship between the common multicore and the two subsystem loops. This
additional information would be an electrical schematic drawing of the junction
box JB1, systematized as shown in 1.3.8.6.
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SYSTEM PRINCIPLES
1.3.8.6 Junction Box Details
Junction Box 1
TB1
1
2
System AXY..
Cable 1
3
4
5
Cable 2
6
7
System AZZ..
8
9
10
Cable 3
11
12
13
System 697…
A schematic of JB1 would be highlighted to show the cable core and termination
details for each of the subsystems involved. The installation and testing of the
multicore can only be carried out under one subsystem. Where a multicore cable
is shared between more than one subsystem, references to multicore cable
number and its cores are made in each of the applicable subsystems.
For completeness, a suitably marked up drawing of the control panel
terminations of the multicore could also be included to show demarcation
between subsystems involved.
With this data recorded and logged in a database future tracability of control
equipment and their loops is accessible.
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SYSTEM PRINCIPLES
1.3.8.7 A typical Integrated System Network
System 690
System 692…
Radio
Tx/Rx
Operator
Display
Station
Operator
Display
Station
Server
Data Highway
System 691
PLC B
PLC A
PLC C
System 690…
Primary system 6 has a sub system number 90 which is allocated to these types
of integrated controls. Other applicable sub systems within 6 are:
Integrated Controls 90
Networks
91
Communications
92
The above simplified integrated control system, shows how the network would be
systematized.
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1.4.1
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SYSTEM PRINCIPLES
PAGE: 33
SYSTEM MECHANICS
Limits of System Handover (LOSH)
When the design or maintenance process has reached a "high" level of
definition, limits of system handover (LOSH) can be established by the
Construction/Maintenance Authority, in conjunction with the
Commissioning Authority. Unique handover identifying number(s),
issued by the Commissioning Authority, using the asset system
mnemonics matrix, should then be allocated, covering the work scope to
the agreed limit(s).
An example of one of the system mnemonics matrix, used within BP, is
shown in Appendix 1.0.
System limit definition is achieved by dividing the workscope into "standalone functional systems" e.g. Produced Crude, Produced Water, Lift
Gas, etc., that perform specific, quantifiable duties, and identifying the
associated interfaces, piping specification changes and isolation
boundaries between these systems and other connected systems.
These stand-alone systems may be further sub-divided into smaller
defined scopes of work (system handover limits), which may have single
or multiple-discipline content, to aid constructability, maintainability,
commissionability and transfer of plant/equipment to the operator.
For compilation of system handover limits, the most current P&ID
drawings should be marked up to identify limit boundaries and discipline
content. The Handover Authority may further sub-divide the handover
limit to detail Pre-Shutdown scope, Shutdown scope and Post-Shutdown
scope as appropriate; Appendix 1 details an example of a LOSH
Legend. Other discipline drawings may be added to define detail.
There are exceptions when P&ID drawings are not applicable, e.g.
HVAC (part), structural, architectural, etc.
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The term "black-box" is used with respect to system limit boundary
compilation. That is to say, an outlined stand-alone scope, defining the
interfaces and isolations/termination points with other systems. For an
example, see Appendix 1.1.
1.4.2
Data Input Sheets (DIS's)
Data input sheets (DIS's), detail the minimum inspection and test (I&T)
requirements for each system handover limit, usually stipulated
according to discipline by the Construction/Maintenance and/or
Engineering Authority and accepted by the Commissioning Authority.
The DIS’s should be developed using the work schedule, together with
an assessment of the risk involved, in conjunction with individual
discipline procedures contained in sections 2 to 10 of the GOC©. To
assist in this risk assessment, and thus the documentation required,
Technical Integrity Assurance flowcharts (and functional certification
flowchart) are included in Appendix 1.2. Nominated personnel who carry
out these activities and those who witness them (where appropriate)
should also be identified.
Discipline/functional certification requirements should be annotated on
DIS's, prior to the data being entered into the asset specific certification
management system e.g. MANCON©, to provide a certification
recording/tracking capability.
The DIS categories are as follows:
DIS No.
Discipline/Function
1
Mechanical - Piping
2
"
- Machinery, Vessels and Handling Equipment
3
"
- Structural
4
"
- HVAC
5
Control
- Instruments, Fire & Gas & Telecoms
6
Electrical
- Cables
7
"
- Equipment
8
Civil
- Roads & Pads, Foundations, Piling & Backfill
Refer to the appropriate GOC© discipline section for the above DIS forms.
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PAGE: 35
Inspection and Test Summary (ITS)
The Inspection and Test summary (ITS), generated on an individual
discipline basis, for a given System Handover Certificate (SH1) system
handover, is a summary of all the certification requirements for that
particular handover and forms the basis of BP Certification Management
Database (MANCON©).
The discipline procedures, DIS's and associated I&T plan(s), provide
standardization of the certification system and identification of the
various authorities involved in the execution of the plan.
1.4.4
Handover Certification Pack (HCP)
Once system handover limits and associated DIS / I&T plans have been
defined and approved, the Handover Certification Pack (HCP) may be
compiled.
This pack should contain the DIS's or certification
requirements matrix i.e. I&T plan (as appropriate), P&ID's (marked up
with the system limits) and preferably the relevant certificates (called up
in the applicable DIS's or I&T plans), which detail the testing procedures.
As work progresses, the certificates should be completed, inserted in the
HCP and the appropriate DIS or I&T plan updated accordingly. The
pack should be handed over from one performing authority to another
until final handover to the operator is achieved. The HCP should then be
returned, as soon as possible, to the appropriate asset engineering
group for document/drawing "as-built", close-out, auditing (where
appropriate) and archiving.
In certain cases, the required certification may be raised by a third party,
using their own certificates and, for contractual/legal reasons, the
originals need to be retained by the third party. Provided the third party
©
certificates embody the requirements of the corresponding GOC
certificate, the GOC© certificate shall be merely used as a "carrier"
certificate.
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SYSTEM PRINCIPLES
©
In this case, the GOC
PAGE: 36
certificate should reference the third party
certificate identifier and a copy of the authorized third party original
should be attached to it. An example of the GOC© "carrier" certificate is
contained in Appendix 1.2.
System limits, DIS's, I&T plan and HCP may be generated either on-site
or off-site. Generation on-site being particularly valid for "in-house"
activities: e.g. operational maintenance works that require "recertification" for retention of License to Operate, e.g. breaking of
containment or involving the facilities Emergency Shut Down (ESD)
systems.
Though the principles of minimum certification requirements, as
contained in section 2 to 10 of the GOC© may be followed, because of
the very nature of the activity itself; i.e. one individual carrying out the
whole process, as one activity, at one time, instead of a number of
disciplines being involved over a prolonged period, as is often the case
in a modification, the number of certificates necessary in maintenance
activities may be lower than normal modification activities. In this case,
the corresponding degree of certification, agreed by the operational
authority, shall however ensure that a true I&T requirement is
maintained and that integrity of the plant/equipment is not impaired,
before being brought back into service. HCP's in this category should
be kept, for a suitable period determined by the asset, as "hard copy
only" for auditability. It is recommended that, in such cases, the unique
system handover number(s) and general brief activity descriptions
should be added to the asset specific certification management system,
for record and tracking purposes only.
1.4.5 System Safe Certificate (SS1)
The System Safe Certificate (SS1) facilitates the handover of the system
from the Operating Authority to the Construction Authority to confirm the
system(s) as defined by the System Handover (SH1) is isolated and all
necessary tests and precautions have been carried out in readiness for safe
work with the defined limits of isolation.
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SYSTEM PRINCIPLES
The SS1 is only applicable when a Project or Modification is being
carried out on an existing facility (brown field site) and is not normally
applicable on a new build (green field site).
However, there maybe
occasions on a new build (green field site) when a system has been
handed over and is being operated by the Operating Authority, where
Construction and/or Commission Authority may be required to carry out
the requirements of an Engineering Query (EQ) or a Technical Query
(TQ), then in cases like this, the SS1 would be applicable and
appropriate on a green field site.
1.4.6
Mechanical Completion Certificate (MC1)
The Mechanical Completion Certificate (MC1) facilitates the handover of
the system from the Construction/Maintenance Authority to the
Commissioning Authority.
While during the final construction stages, some commissioning
activities (e.g. flushing, leak testing and certain function tests, etc.) are
possible, with the approval of the construction performing body and
without MC1 handover, all construction and pre-commissioning activities
must have been completed and MC1 handover taken place, before
"powering-up", introduction of actual working fluids/chemicals on the
danger list or where danger to other systems may exist.
To aid constructability/maintainability/commission ability, the system
handover limits may be sub-divided into more than one "black box"/subsystem. This would occur when an advantage can be gained by having
early access to a section of plant/equipment and handover, via the
mechanical completion certificate (MC1), to the Commissioning
Authority. Each MC1 carries the same identification number as the
system handover number but with the addition of +01, +02, etc.,
depending upon the number of MC1's.
Each MC1 must be capable of isolation / termination from other
sections, ensuring safety is not impaired.
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SUBJECT:
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REVISION: 1
SYSTEM PRINCIPLES
PAGE: 38
Occasions occur when certain activities, requiring certification, are
performed outside the site location i.e. vendors fabrication/assembly
facilities, module yards etc. In this particular case, the same GOC©
principles should be applied in the generation of separate MC1's; i.e.
system handover limits established, I&T requirements determined etc.,
such that on completion, the works can be "punched" in the normal way
and prepared for handover to the Commissioning Authority. If the
completed work and associated MC1 pack are agreeable to the
Commissioning Authority, the MC1 should be accepted, the asset
certification management system updated and the MC1 pack retained at
the asset's central certification control point, rather than dispatching to
the site.
Subsequent on-site hook-up works should then form the basis of
additional independent MC1's (as appropriate), which would be
managed in the normal way. Once again vendor certification can be
utilized by using the GOC© "carrier" certificate methodology, detailed
above.
Where
the
Construction/Maintenance
performing
body
and
commissioning performing body come under the same management
authority, the MC1 may be omitted and approval authorization
undertaken via the SH1.
1.4.7
System Handover Certificate (SH1)
The System Handover Certificate (SH1) facilitates the handover of the
system from the Commissioning Authority to the Operating Authority. At
this stage, commissioning activities should have been completed.
At SH1 approval / acceptance, the following restrictions/limitations apply:
(a)
No category ‘A’ Punch List items shall remain.
(b) Engineering queries (EQs) raised shall have been answered,
assessed for its impact and where possible subsequent
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SECTION 1.0
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REVISION: 1
SYSTEM PRINCIPLES
PAGE: 39
construction/ commissioning works implemented. Only outstanding
EQ’s that do not impair the safety of plant and/or personnel and
have the approval of the operating authority shall remain (Punch List
Item category B).
(c) The Integrity Authority shall have witnessed any I&T activities
specifically requested by them.
(d) Any I&T activities required for obtaining or retaining of certificate of
fitness e.g. containment confirmation, PSV/Cat 1 protection system,
ESD system testing, Life support systems etc. shall have been
completed in full.
(e) The operator should have been provided with all technical and
operations/maintenance information i.e. equipment specifications
and data, operating and maintenance procedures etc. necessary for
Operations to safely operate the plant being handed over.
When commissioning activities require hydrocarbons introduced, to
complete the certification, e.g. gas compressor or crude pump test runs
etc., the SH1 must be handed over and accepted by the operating
authority before commencement.
In this particular case, any
outstanding activities should be entered in the "exclusions" section of
the SH1 and included on the punch list, prior to handover. Further
commissioning should then proceed under operations authority control
with appropriate certification/running logs/as-built drawings etc. added to
the HCP on completion, and copied to the operating authority (where
appropriate).
Certain circumstances arise when non-essential plant/equipment, which
fall within the SH1 limits and is not immediately required for operations
to continue, e.g. a chemical injection pump used intermittently etc., is not
available when the main system requires to be made operational.
Provided the plant/equipment can be isolated to the satisfaction of all
performing authorities, such that no impairment to safety of the plant
GOC©
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SECTION 1.0
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REVISION: 1
SYSTEM PRINCIPLES
PAGE: 40
and/or personnel exists, the outstanding plant/equipment and associated
certification may be entered into the "exclusions" section of the SH1 and
included on the punch list prior to handover. Once again, appropriate
certification, as-built drawings etc. should be added to the HCP on
completion, and copied to the operating authority (where appropriate).
Situations also arise where additional work to that originally planned,
needs to be undertaken in order to achieve the aims of the
modification/maintenance activity e.g. pipework re-routing due to a
"conflict” etc. The normal implementation method, for capturing the
additional man-hours involved, is the raising of an site instruction (S.I.).
To capture the change in system limit and/or I&T data requirements
(refer to 1.6 - Change Control), an on-site HCR should be raised and
included in the HCP and at SH1 handover, specifically brought to the
notification of the operating authority.
1.4.8
Plant Performance Certificate (PP1)
The Plant Performance Certificate (PP1) facilitates the realization of design
integrity and expectations and that the facility is performing to those
expectations for the agreed period of time, post SH1 Handover.
The Engineering & Commissioning Authority confirms that the plant
performance tests as defined are in accordance with design and vendor
requirements, specifications and drawings, and that the plant meets the
expectations of design criteria and intended purpose, provided a NonPerformance report (NP1) is not raised.
If a Non-Performance report (NP1) is raised, the Operating Authority may
not accept the PP1 until the detail of the NP1 or any subsequent
Engineering Queries (EQ) and/or Technical Queries (TQ) have been
satisfactory resolved.
Upon completion of the NP1, EQ and/or TQ process to the satisfaction of
the Operating Authority, the Operating Authority will sign the PP1 accepting
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REVISION: 1
SYSTEM PRINCIPLES
PAGE: 41
that plant performance tests have demonstrated that the design
expectations have been achieved.
1.4.9
Punch List (PL1)
The punch list form (PL1) shall detail all outstanding items of work,
according to the original work scope, at the point of handover of both
MC1 and SH1. Prior to offering the MC1/SH1 for acceptance, the work
content shall be reviewed (punched) to ensure work has been
constructed/maintained as per design/maintenance routine and that the
plant/equipment integrity is valid or has not been impaired during
maintenance. To record these items, a PL1 shall be raised (normally by
the construction/maintenance performing authority), listing all defects
found outside design/original operating capability.
At MC1 handover stage, the punch (punch-list walk-through inspection)
shall be carried out by the Construction/Maintenance performing body
together with the commissioning performing body with operations invited
to participate.
At SH1 handover stage, the punch (punch-list walk-through inspection)
shall be carried out by the Commissioning performing body together with
Operations with the Construction/Maintenance performing body invited
to participate.
Wherever possible, the PL1 should be accompanied with attached
marked-up P&ID(s) showing location of defect items. To assist detail,
other types of drawings may be added, i.e. piping isometrics, E&I line
diagrams, etc. The P&ID, having been HAZOPed, remains the primary
drawing.
There should be only one uniquely identified, discipline specific, punch
list per HCP (as many pages as required). The same PL1 shall be
carried forward from MC1 to SH1, items being signed off and/or added,
as required.
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REVISION: 1
SYSTEM PRINCIPLES
PAGE: 42
Each item on the list shall be categorized as priority ‘A’ & ‘B’.
‘A’
denoting major items which must be completed before a handover is
acceptable and priority ‘B’ denoting minor items which, provided they are
not excessive in number and with the agreement of the accepting
authority, can be completed after the handover is accepted.
The responsibility for clearing PL1 items shall, unless agreed otherwise,
rest with the Construction/Maintenance Authority, except where the
commissioning performing body/operations have requested something,
within the scope, to be left out to assist their progress, etc., e.g. a
spectacle blind left in the closed position at MC1 acceptance, to assist
commissioning leak test. This would be cleared by turning the spectacle
blind to the run position (open), prior to offering the SH1 to the operator,
for acceptance. In this particular case this would have appeared as a
"B" item at MC1 offer stage, but an "‘A’" item (commissioning to clear) at
SH1 offer stage.
The PL1 shall remain live and tracked until all items are completed and
signed off.
Where the handover is of considerable size, it is recommended that a
pre-punch is carried out in order to reduce the number of items being
entered on the official PL1, and the certification management system.
Punch list items must be restricted to "as per design/maintenance
routine" and not include "nice to have" or "preferential engineering"
items.
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SUBJECT:
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REVISION: 1
SYSTEM PRINCIPLES
1.5
KEY PERSONNEL
1.5.1
Nomination of Authorities
PAGE: 43
Dependent on the scope of the works to be completed using the GOC©,
the various performing bodies and authorities should be nominated at
the outset.
Clearly a major project will involve large discrete
departments to fulfill the required roles (both performing and
authorization) and normally the handover authorized by the head of
those departments or his nominated deputy by signature on the requisite
forms. Nomination of performing bodies and authorities is particularly
important where the projects are smaller, such as repair orders on the
plant, and all work will be carried out on site. Then, the performing
bodies and authorities defined below may be the same signatory and the
provision of information at each stage will be correspondingly less (e.g.
basis of designs (BOD's) referenced in 1.5.2 below, will not necessarily
be required). The following defines the roles of the various authorities in
so far as they apply to the Certification System. Appendix 1.4 details the
relevant performing bodies and authorities normally applicable. It is
incumbent upon the relevant Asset to fill in or delete as applicable, the
requisite names/job titles applicable to their Asset.
1.5.2
Design/Maintenance Planning Authority
The design/maintenance planning authority shall provide the Basis of
Design (BOD) which will include, but not be limited to, detailed drawings
(PFD's, P&ID's, Isometrics, etc.), material specifications, system
parameters and proposed methods of construction, maintenance,
commissioning and operation. For smaller modifications or maintenance
activity the BOD may be replaced by a scope of work (SOW).
A typical BOD contents sheet is contained in Appendix 1.3.
GOC©
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SUBJECT:
1.5.3
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SYSTEM PRINCIPLES
PAGE: 44
Construction/Maintenance Authority
The Construction/Maintenance Authority, in conjunction with the
Commissioning Authority, shall produce system handover limits, raise
Discipline Input Sheets (DIS's) by discipline, input the data into
©
MANCON
(where appropriate) and produce the HCP's.
Once the
construction, maintenance and pre-commissioning works have been
completed, punch list(s) produced and MANCON© updated (where
appropriate), the Construction/Maintenance Authority shall handover the
system(s), with the requisite completed MC1's, to the Commissioning
Authority.
1.5.4
Commissioning Authority
The Commissioning Authority, on satisfactory acceptance of the MC1
from the Construction/Maintenance Authority, will complete all
©
commissioning activities, update the punch list, update MANCON
(where appropriate) and then handover the system, with the requisite
completed SH1, to the Operating Authority.
1.5.5
Certification Administrator
The Certification Administrator undertakes the compilation, verification
and auditing of the certification process.
1.5.6
Handover Management
Handover Management, (SH1 allocation authority) controls the issuing,
deletion and general control of the unique system handover numbers
(SH1's).
GOC©
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SUBJECT:
1.5.7
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
PAGE: 45
SYSTEM PRINCIPLES
Operating Authority
The operating authority must be satisfied that all steps have been taken
by all the other performing bodies, to ensure that the system offered for
acceptance is safe, effective and operable and that the HCP will meet all
Integrity Authority and legislative requirements of the country or state
whose jurisdiction the installation is subject. The operating authority
signs the SH1 as acceptance of the operational system, subject to the
constraints/limitations detailed above.
asset nominated authorities.
1.6
CHANGE CONTROL
1.6.1
Requirement for Change
Refer to Appendix 1.4 for the
The DIS's / I&T plan is reviewed and then fixed during the
design/maintenance planning stage, but it is usually inevitable that the
system limits and/or I&T requirements for some systems may require to
be changed after the approval stage but at some stage before handover
to the operator.
The DIS's / I&T plan specify the minimum
requirements for inspection and testing, and generally this will be
sufficient for operational purposes. If, however, further activities are
identified, then the plan must be changed. Similarly, operational
reasons may dictate that the limits of the system must be changed.
The mechanism for these changes is contained in the following subsections. It is important that the correct form is selected so that the
information can be processed in an expedient manner.
1.6.2
Handover Change Request (HCR)
The Handover Change Request (HCR) form is used for controlling post
approval changes to system handover limits and/or Data. The form,
which may be raised on-site or offsite, should be transmitted to the
appointed authority, for approval. If the HCR is accepted, the limits
and/or data should be amended and the relevant information transmitted
GOC©
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REVISION: 1
SYSTEM PRINCIPLES
PAGE: 46
along the normal lines of communication (refer to section 1.6 of this
document). If, however, the HCR is rejected then it should be returned
to the originator, together with an explanation of the rejection.
1.6.3
MANCON© Change
When MANCON is being used as the certification management system
for recording and tracking purposes, then when the HCR is approved, it
also provides the necessary authorization for the change(s) to be
©
©
incorporated into MANCON , using the appropriate MANCON
procedures.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
PAGE: 47
SYSTEM PRINCIPLES
1.7
SYSTEM FLOW
1.7.1
Sequence of Events
In the following steps the word "MANCON©" is used in the context of
being an example of one of the certification management systems
available and in use within BP. Other assets, using alternative systems,
should replace the word "MANCON©" with their own system identifier.
Sequence of events:
a)
BOD/SOW produced by the design/maintenance planning authority
should be transmitted to the Construction/Maintenance Authority.
b)
The Construction/Maintenance Authority, in conjunction with the
Commissioning Authority, should define the limits of system
handover, by marking up the system drawings, and adding a
unique system handover identifier number, obtained from the SH1
allocation authority.
c)
The
Construction/Maintenance
Authority
discipline
engineers
should allocate the construction/maintenance inspection and test
requirements.
d)
The Commissioning Authority discipline engineers should allocate
the commissioning inspection and test requirements.
e)
Once the I&T plan has been authorized by all appropriate
authorities, the Certification Administrator should produce the
inspection and test certificates, the approved I&T requirements
matrices and combine these with the appropriate marked up
drawings to compile the HCP.
f) The Certification Administrator should then transmit the HCP to site.
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SUBJECT:
g)
GUIDANCE ON CERTIFICATION
SECTION 1.0
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REVISION: 1
PAGE: 48
SYSTEM PRINCIPLES
The Construction/Maintenance performing body should complete
his activities and as work progresses, the Certification Administrator
should update MANCON© (if appropriate) and insert the completed
I&T certificates in the HCP until handover, to the Commissioning
Authority, is possible.
h)
When all construction/maintenance activities have been completed,
the Construction/Maintenance performing body, the commissioning
performing body and, if possible, the operations representative
should then carry out a joint punch to the system handover limits.
i)
The Construction/Maintenance Authority should then complete and
sign the MC1 and, together with the agreed priority ‘B’ item Punch
List Items, hand over the HCP to the Commissioning Authority.
j)
The
Commissioning Authority should
review the HCP for
acceptability and if satisfied, sign the MC1 as acceptance of the
system.
k) The commissioning performing body should complete its activities
and as work progresses, the Certification Administrator should
update MANCON© (if appropriate) and insert the completed I&T
certificates in the HCP until handover, to the operating authority, if
possible.
l)
When all commissioning activities have been completed, the
commissioning performing body, the operations representative and,
if possible, the Construction/Maintenance performing body should
then carry out a joint punch to the system handover limits.
m) The Commissioning Authority completes and signs the SH1 and
together with the agreed priority B item Punch List Items hands
over the HCP to the operating authority.
n) The operating authority should review the HCP for acceptability and
once satisfied, sign the SH1 as acceptance of the system.
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REVISION: 1
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SYSTEM PRINCIPLES
o) Outstanding punch list form (PL1) items and Engineering Query
(EQ) actions should remain live and tracked by MANCON© (if
appropriate) until completion. Any further certificates, “as-built”
drawings etc., resulting from completed PL1 and EQ actions should
be added to the accepted HCP and, where appropriate, copies of
appropriate documentation transmitted to the operating authority
for information.
To ensure timely "as-building" of documentation, it is
recommended that the HCP be returned to the engineering
authority at the earliest opportunity. To achieve this feature, if
issues such as EQ resolution etc., are outstanding at point of SH1
approval by the Operating Authority and are expected to take some
time, due to material deliveries etc., then consideration should be
given to transferring these works to a separate SH1, undertaking
amendment/close-out/referencing
appropriate).
GOC©
of
documentation
BP Exploration 1989 - 2001 All Rights Reserved
(as
SUBJECT:
1.7.2
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SYSTEM PRINCIPLES
PAGE: 50
Flowcharts
The remaining pages of this section contain the following flowcharts:
a) Flowchart 1.7.3
Handover Sequence of Events (Off-site)
b) Flowchart 1.7.4
Handover Sequence of Events (On-site)
c) Flowchart 1.7.5
Handover Change Request.
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REVISION: 1
PAGE: 51
SYSTEM PRINCIPLES
Handover Certification Pack (HCP) Off-site Preparation
Flowchart 1.7.3
BOD/Scope of Work Raised
by the
Design / Maintenance
Authority
Construction / Maintenance
Authority
Set System Limits
and Mark-Up Drawings
Allocate SH1 Handover
No. (Mnemonics)
PP1 & PP1 duration
(Where appropriate)
Construction / Maintenance
Engineers
Generate I&T
Requirements
Commissioning
Discipline Engineers
Generate I&T
Requirements
Certification Administrator
Complies approved
HCP
Certification Administrator
Transmits the HCP
To Site
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REVISION: 1
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SYSTEM PRINCIPLES
Handover Certification Pack (HCP) On-site Review and Acceptance
Flowchart 1.7.4
` Is the work scope for an
existing
Operating Facility?
YES
Operations to issue an SS1
Certificate prior to any work
commencing within the SH1
Handover Limit
NO
Works Progressed
to MC1 Status
HCP Updated
Certification Management
System
Reviewed and Update
(As Appropriate)
Construction/Maintenance
Authority sign off MC1
HCP offered to
Commissioning Authority
Commissioning Authority
to Review HCP and signs
MC1 when acceptable
Certification Management
System
Reviewed and Update
(As Appropriate)
Commissioning Authority
Progresses
Works/Handover to
SH1 Status
Commissioning Authority
Progresses HCP and
signs SH1 – HCP offered
to the Operator
Certification Management
System
Reviewed and Update
(As Appropriate)
Operating Authority
Reviews HCP and signs
SH1 as appropriate
Certification Management
System
Reviewed and Update
(As Appropriate)
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SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
PAGE: 53
SYSTEM PRINCIPLES
Handover Change Request (HCR)
Flowchart 1.7.5
HCR
Raised by
originator
Refer to section 5
HCR
Transmitted to The
Appropriate
Authority
Approved
HCR
Reviewed by
Approving
Authority
Not Approved
HCR
Return to
originator with
explanation of
rejection
Limits and/or Data
Amended on
Drawings and DIS
/ ITS Plan updated
to cover limit
HCR
Updated Changes
to DIS / I&T Plan
implimented
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GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
SYSTEM PRINCIPLES
EXHIBIT 1
STANDARD FORMS
Form No.
Title
HCR
Handover Change Request
SS1
System Safe Certificate
MC1
Mechanical Completion Certificate
PL1
Punch List
SH1
System Handover Certificate
PP1
Plant Performance Certificate
NP1
Non-Performance Certificate
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PAGE: 54
SH1 No:
FORM HCR
Work Pack No:
HCR Number:
Discipline:
HANDOVER CHANGE REQUEST (HCR)
From :
SITE:
PLEASE NAME OFFICE CONTACT BELOW :
Date :
To :
DESCRIPTION & REASON FOR CHANGE:
Marked-up copies of P&ID's / Block Diagrams / DIS/ITS Print-out(s)
detailing proposed Limit and/or Data Change - include all SH1/MC1 No(s)
affected.
IS THIS CHANGE THE RESULT OF AN EQ?
* YES/NO
IF 'YES' STATE EQ REF :
* APPROVED / NOT APPROVED (* DELETE AS APPROPRIATE )
MAINTENANCE/CONSTRUCTION:
COMMISSIONING:
AUTHORITY
AUTHORITY
DATE :
DATE :
COMMENTS :
CHANGE IMPLEMENTED BY : ____________________________
GOC©
DATE : ____________________
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title
FORM SS1
(SIDE 1)
SH1 Number:
Maintenance No:
Work Pack No:
SYSTEM SAFE CERTIFICATE
SITE:
HANDOVER TITLE:
MC1 APPLICABLE *YES/NO
MC1 CERTIFICATE No(s):
FOR SAFE SYSTEM OF WORK CONTROL MEASURES SEE THE REVERSE SIDE OF THIS FORM
HANDOVER INCLUDES:
* ATTACH MARKED-UP DRAWINGS OF LIMITS OF SYSTEM / EQUIPMENT
HANDOVER EXCLUDES:
OPERATING AUTHORITY
HEREBY CONFIRMS THAT THE ABOVE SYSTEM AS DEFINED HAS BEEN ISOLATED AND ALL NECESSARY
TESTS AND PRECAUTIONS CARRIED OUT IN READINESS FOR SAFE WORK WITHIN THE BOUNDARY LIMITS
OF THE ISOLATION.
SIGNED ____________________________________________
DATE _______________________________
CONSTRUCTION / MAINTENANCE / COMMISSIONING ACCEPTANCE AUTHORITY
HEREBY ACCEPTS THE SYSTEM AS DEFINED SUBJECT TO THE RESPONSIBILITIES/LIMITATIONS AS SHOWN
ON THE CONTROL MEASURES REFERENCED OVERLEAF.
SIGNED ____________________________________________ DATE _______________________________
* Delete as Appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas Rev. 1
SSOW CONTROL MEASURES
SH1 NUMBER:
OPERATING AUTHORITY
AREA AUTHORITY OR DELEGATE
STAGE 2 RISK ASSESSMENT (APPLICABLE *YES/NO)
STAGE 2 RA No:___________________________
SIGNED:
DATE:
ISOLATION CONFIRMATION (APPLICABLE *YES/NO)
ICC No: ___________________________
SIGNED:
DATE:
SYSTEM FLUSH / PURGE / CLEAN
SYSTEM FLUSHED / PURGED / CLEANED (APPLICABLE *YES/NO)
SIGNED:
DATE:
ISOLATION MONITORING
DOUBLE BLOCK & BLEED MONITORING IN PLACE (APPLICABLE *YES/NO)
SIGNED:
DATE:
OTHER CONDITIONS / PROCEDURES
HANDOVER INCLUDES
WORKSITE
WORKSITE IN A CLEAN AND SAFE CONDITION
SIGNED:
DATE:
SERVICES
INSULATION / SCAFFOLDING COMPLETION
SIGNED:
* Delete as Appropriate
DATE:
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas Rev. 1
Project Title:
FORM MC1
(SIDE 1)
MC1 Number:
Maintenance No:
Work Pack No:
MECHANICAL COMPLETION CERTIFICATE
SITE:
HANDOVER TITLE :
NOTE: FOR PUNCH LIST REFERENCE NUMBER(S) SEE THE REVERSE SIDE OF THIS FORM
HANDOVER INCLUDES :
HANDOVER EXCLUDES :
CONSTRUCTION/MAINTENANCE AUTHORITY
I HEREBY CONFIRM THAT THE ABOVE SYSTEM AS DEFINED, HAS BEEN CONSTRUCTED, INSTALLED,
MAINTAINED AND TESTED IN FULL ACCORDANCE WITH DESIGN DRAWINGS, AND/OR MAINTENANCE
SCHEDULES.
SIGNED ____________________________________________
DATE _______________________________
COMMISSIONING AUTHORITY
I HEREBY ACCEPT THE SYSTEM AS DEFINED SUBJECT TO THE RESPONSIBILITIES / LIMITATIONS AS
SHOWN ON THE PUNCH LISTS REFERENCED OVERLEAF.
SIGNED ____________________________________________ DATE _______________________________
GOC©
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DOUBLE SIDED FORM
Americas Rev. 1
SCOPE COMPLETION
CONSTRUCTION/MAINTENANCE PERFORMING AUTHORITY
MC1 NUMBER:
MECHANICAL
STRUCTURAL COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
MECHANICAL COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
PIPING COMPLETION
(APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
CONTROL
INSTRUMENT COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
FIRE & GAS COMPLETION
(APPLICABLE *YES/NO
PUNCH LIST No:___________________________
SIGNED:
TELECOMS COMPLETION
DATE:
(APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
ELECTRICAL
ELECTRICAL COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
CIVIL
(Including Architectural)
CIVIL COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
PROTECTIVE COATINGS
(Including Insulation)
PAINTING/COATING & (APPLICABLE *YES/NO)
INSULATION COMPLETION
PUNCH LIST No:___________________________
SIGNED:
DATE:
*Delete as Appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas Rev. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
PUNCH LIST RAISED BY:
PERFORMING BODY
DISCIPLINE
SHT
OF
LOCATION:
CLEARANCE
BODY
* VENDOR/CONTRACTOR
VEN
* CONSTRUCTION
CON
* COMMISSIONING
COM
* MAINTENANCE
MTN
ITEM
No
SITE:
PUNCH LIST NUMBER
PUNCH LIST
FORM
* OPERATING
FORM PL1
DATE
PRINT NAME
SIGNATURE
OPS
DESCRIPTION
EST.
HRS.
MAT. REQ No
CAT
CLEARANCE
BODY
DATE
CLEARED
SIGNED
NOTES:
1. OUTSTANDING PAINTING/HEAT TRACING AND INSULATION TO BE RECORDED ON A UNIQUE PUNCH LIST FOR PAINTING/HEAT TRACING WITHIN THE
LIMITS OF THIS HANDOVER.
CATEGORIES:
'A'
ITEMS TO BE REPAIRED, COMPLETED OR CORRECTED BEFORE THE EQUIPMENT CAN BE SAFELY OPERATED
'B'
ITEMS THAT CAN BE REPAIRED, COMPLETED OR CORRECTED AT A LATER DATE AND WHICH ALLOWS THE
EQUIPMENT TO BE COMMISSIONED/OPERATED WITHOUT JEOPARDIZING PLANT OR PERSONNEL
*Delete as Appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas Rev. 1
Project Title:
FORM SH1
(SIDE 1)
SH1 Number:
Maintenance No:
Work Pack No:
SYSTEM HANDOVER CERTIFICATE
SITE:
HANDOVER TITLE :
MC1 APPLICABLE *YES/NO
MC1 CERTIFICATE No(s):
NOTE: FOR PUNCH LIST REFERENCE NUMBER(S) SEE THE REVERSE SIDE OF THIS FORM
HANDOVER INCLUDES :
HANDOVER EXCLUDES :
COMMISSIONING AUTHORITY
I HEREBY CONFIRM THAT THE ABOVE SYSTEM AS DEFINED HAS BEEN COMMISSIONED AND ALL
NECESSARY TESTS CARRIED OUT IN READINESS FOR SAFE CONTINUOUS OPERATION.
SIGNED ____________________________________________
DATE _______________________________
OPERATING ACCEPTANCE AUTHORITY
I HEREBY ACCEPT THE SYSTEM AS DEFINED AND SUBJECT TO THE RESPONSIBILITIES / LIMITATIONS
BEING COMPLETE AS DEFINED ON THE PUNCH LIST(S) REFERENCED OVERLEAF.
SIGNED ____________________________________________
* Delete as Appropriate
GOC©
DATE _______________________________
BP Exploration 1989 - 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas Rev. 1
SCOPE COMPLETION
COMMISSIONING / OPERATIONS AUTHORITY
SH1 NUMBER:
MECHANICAL
STRUCTURAL COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
MECHANICAL COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
PIPING COMPLETION
(APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
CONTROL
INSTRUMENT COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
FIRE & GAS COMPLETION
(APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
TELECOMS COMPLETION
DATE:
(APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
ELECTRICAL
ELECTRICAL COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
CIVIL
(Including Architectural)
CIVIL COMPLETION (APPLICABLE *YES/NO)
PUNCH LIST No:___________________________
SIGNED:
DATE:
PROTECTIVE COATINGS
(Including Insulation)
PAINTING/COATING & (APPLICABLE *YES/NO)
INSULATION COMPLETION
PUNCH LIST No:___________________________
SIGNED:
DATE:
* Delete as Appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas Rev. 1
Project Title:
FORM PP1
(SIDE 1)
SH1 Number (s) :
Maintenance No:
Work Pack No:
PLANT PERFORMANCE CERTIFICATE
SITE:
TITLE :
PLANT PERFOMANCE DURATION:
PLANT PERFORMANCE COVERS THE FOLLOWING SYSTEM(s) :
NON-PERFOMANCE REPORT (NP1)
ATTACHED
* YES / *NO
NP1 No :
ENGINEERING AUTHORITY
HEREBY CONFIRMS THAT THE FACILITY PLANT PERFORMANCE TEST(s) AS DEFINED, ARE IN
ACCORDANCE WITH DESIGN AND VENDOR REQUIREMENTS, SPECIFICATIONS AND DRAWINGS AND
MEET THE EXPECTATIONS OF DESIGN CRITERIA AND INTENDED PURPOSE.
SIGNED ___________________________________________ DATE _____________________________
COMMISSIONING AUTHORITY
HEREBY CONFIRMS THAT THE FACILITY PLANT PERFORMANCE TEST(s) ARE COMPLETE, AND ARE IN
ACCORDANCE WITH THE PERFORMANCE STANDARDS AND SPECIFICATIONS AND MEET THE
EXPECTATIONS OF DESIGN CRITERIA AND INTENDED PURPOSE.
SIGNED ___________________________________________ DATE _____________________________
OPERATIONS AUTHORITY
HEREBY ACCEPTS THE FACILITY PLANT PERFORMANCE TEST(s) AS DEFINED, MEET THE EXPECTATIONS
OF THE DESIGN CRITERIA AND INTENDED PURPOSE, AND ASSUMES RESPONSIBILITY FOR MAINTAINING
THE TECHNICAL INTEGRITY AND DESIGN CRITERIA OF THE PLANT.
SIGNED ___________________________________________ DATE _______________________________
* Delete as Appropriate
GOC ©
BP Exploration 1989 - 2001 All Rights Reserved
Americas Rev. 1
Project Title:
FORM NP1
SH1 Number (s) :
Maintenance No:
Work Pack No:
NON-PERFORMANCE CERTIFICATE
EQUIPMENT No :
SITE:
EQUIPMENT DESCRIPTION :
SYSTEM :
LOCATION :
COMMISSIONING PROCEDURE No(s) :
PLANT PERFOMANCE DURATION:
Report:
USE CONTINUATION SHEET IF REQUIRED
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas Rev. 1
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
SYSTEM PRINCIPLES - APPENDICES
APPENDIX 1.0
Operations System Mnemonics Matrix Example
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SECTION 1
REVISION: 1
PAGE: i
SYSTEM MNEMONICS – MILNE POINT
SH1 NUMBER
Example
C 22 2 0 C 9 9 9
SEQUENTIAL NUMBER
PRIMARY SYSTEMS
LOCATION
A
A-PAD
HANDOVER TYPE IDENTIFIER
SECONDARY SYSTEM
DESCRIPTION
0
WELLPADS & WELLS
1
CONSTRUCTED/COMMISSIONED
C
DESTRUCT
D
B
B-PAD
C
C-PAD
E
E-PAD
LIQUID SEP./PUMPING
2
F
F-PAD
GAS SYSTEMS
3
G
G-PAD
WATER SYSTEMS
4
H
PAD
I
I-PAD
FLARE/RELIEF
5
6
J
J-PAD
SAFETY / ESD SYSTEMS
K
K-PAD
DRILLING SYSTEMS
7
L
L-PAD
UTILITIES
8
X
CFP
STRUCTURAL
9
PRIMARY SYSTEM 1
(LISTED UNDER RESPECTIVE PRIMARY SYSTEM)
PRIMARY SYSTEM 2
(WELL PADS & WELLS)
PRIMARY SYSTEM 3
TEMPORARY
T
RE-INSTATEMENT/REFURBISHMENT
R
SHUTDOWN DEPENDENT
S
EQUIPMENT OUTAGE
E
PRIMARY SYSTEM 4
PRIMARY SYSTEM 5
(GAS SYSTEMS)
(WATER SYSTEMS)
(FLARE / RELIEF)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
(LIQUID SEPARATION)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
1ST STG / G-LIFT DRIVE TRAIN 1
1ST STG / G-LIFT DRIVE TRAIN 2
2ND / 3RD STG DRIVE TRAIN 1
2ND / 3RD STG DRIVE TRAIN 2
1ST STG COMP TRAIN 1
1ST STG COMP TRAIN 2
1ST STG COMMON EQUIP.
2ND STG COMP TRAIN 1
01
02
03
04
11
12
13
21
WATER GENERAL
SOURCE WATER GENERAL
SOURCE WATER DEGASSING
A-PAD/CFP SOURCE WATER
B-PAD/CFP SOURCE WATER
PROD WATER GENERAL
PROD WATER COLLECTION
08
2ND STG COMP TRAIN 2
22
PROD WATER DEOILING
00
10
11
12
13
20
21
22
23
09
10
2ND STG COMMON EQUIP.
3RD STG COMP TRAIN 1
23
PROD WATER FILTRATION
24
PROD WATER BACKWASH
25
3RD STG COMP TRAIN 2
3RD STG COMMON EQUIP.
DESANDING SYSTEM
L-PAD TO C TO CFP 6” P/LINE
11
12
31
32
33
WATER INJ GENERAL
26
30
41
L-PAD TO C-PAD 14” P/LINE
13
41
WATER INJ SURGE DRUM
31
SLUG CATCHER 1ST STAGE
20
42
WATER INJ BOOSTER PUMP
32
ESP MODULE
50
51
GAS LIFT COMP TRAIN 1
GAS LIFT COMP TRAIN 2
HEATER COMMON
30
GAS LIFT COMMON EQUIP.
43
33
TEST SEP MODULE
52
HEATER TRAIN 1
31
HYDRAULIC MODULE
PAD HV POWER
53
HEATER TRAIN 2
50
51
2ND STAGE SEP TRAIN 1
GAS INJ COMP TRAIN ‘A’
2ND STAGE SEP TRAIN 2
42
GAS INJ COMP TRAIN ‘B’
60
61
CFP TO E-PAD 4” WATER INJ
PAD LV POWER
60
61
32
41
GAS DEHYDRATION
GLYCOLREGENERATION
WATER INJ PUMPING
CFP TO B-PAD 8’ WATER INJ
CFP/C P/L TO T-14 WATER INJ
37
PAD 24 V UPS / BATTERIES
62
3RD STAGE SEP TRAIN 1
GAS INJ COMP ‘C’ PAD
62
T-14 / I-PAD 6’ WATER INJ
LAUNCHER / RECEIVERS
PAD UTILITIES
70
80
81
3RD STAGE SEP TRAIN 2
51
52
CFP TO ‘B’ PAD 6’ G-LIFT
63
C-PAD TO L-PAD 6” WATER INJ
38
39
60
B-PAD TO D-PAD 4” G-LIFT
64
CONTROL ROOMS & PANELS
96
CFP TO C-PAD 6” GAS LIFT
65
MULTICOR CABLES
97
82
EXPORT PIPELINE
70
80
CFP TO E-PAD 3” GAS INJ
66
83
84
OIL RESERVE TANKS
81
C-L-F 8” GAS INJ
CONTROL ROOMS & PANELS
MULTICORE CABLES
COMMON PIG LAUNCHER
CONTROL ROOMS & PANELS
CHEMICAL INJECTION
85
86
96
97
67
70
PROD FLUID HEATING
87
IWAG START-UP AIR
88
B-PAD TO CFP 14” P/LINE
00
C-PAD TO CFP 14” P/LINE
D-PAD TO B-PAD 14” P/LINE
E-PAD TO CFP 14” P/LINE
E-PAD TO CFP 4” P/LINE
F-PAD TO L-PAD 14” P/LINE
G-PAD TO CFP 10”/14” P/LINE
G-PAD TO H-PAD 3” TEST
I-PAD TO J/G 8” P/LINE
01
02
03
04
05
06
07
10
20
J-PAD TO G-PAD 8” P/LINE
30
K-PAD TO E-PAD 14” P/LINE
40
PAD WATER INJ PUMPING
PAD HEATERS
PADS / WELLS / FLOWLINES
ESP WELLS
GAS INJECTION WELLS
GAS LIFT WELLS
PRODUCTION WELLS
WATER INJECTION WELLS
SOURCE WATER WELLS
WAG WELLS
SAND INJECTION WELLS
00
01
02
03
04
05
06
PRODUCTION HEADER
TEST HEADER / SEP
GAS INJ HEADER
WATER INJ HEADER
INSTRUMENT AIR
FUEL GAS
CLOSED DRAIN
OPEN DRAIN
ATMOSPHERIC VENT
LETTER
POWER
07
08
DIESEL FUEL
89
CENTRAL HYDRAULICS
CONTROL ROOM / PANELS
MULTICORE CABLES
90
J-PAD TO I TO H 3” P/LINE
EXPORT COOLERS / PUMPS
OIL METERING
MULTICORE CABLES
PROD WATER DEGASSING
CFP TO C-PAD 8’ WATER INJ
FLARE SYSTEM GENERAL
RELIEF HEADER
ATMOSPHEREIC VENT
FLARE IGNITION
FLARE ASSIST GAS
CONTROL ROOM/PANELS
MULTICORE CABLES
00
10
20
30
40
96
97
34
35
36
96
97
96
97
PRIMARY SYSTEM 0
PRIMARY SYSTEM 6
PRIMARY SYSTEM 7
PRIMARY SYSTEM 8
PRIMARY SYSTEM 9
(SAFETY / ESD)
(DRILLING SYSTEM)
(UTILITIES)
(STRUCTURAL)
(POWER)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
10
CONTROL ROOM / PANELS
96
SERVICE WATER
10
LIFE SUPPORT FACILITY
01
POWER GENERATION
10
FIRE & GAS
20
MULTICORE CABLES
97
OF QUARTERS FACILITY
11
GF GARAGE FACILITY
MV MAINS DISTRIBUTION
12
DELUGE
40
INERT GAS
12
13
02
03
HV MAINS DISTRIBUTION
30
UTILITY AIR
INSTRUMENT AIR
11
FIREWATER
WAREHOUSE FACILITY
23
LV MAINS DISTRIBUTION
HVAC (MODULE)
50
JET WATER
14
AUXILARY INJ MODULE
47
STANDBY GENERATOR
14
INTEGRATED CONTROL SYSTEM
90
POTABLE WATER
15
53
STANDBY GEN DISTRIBUTION
15
NETWORKS
ESD
13
91
DIESEL
16
PRODUCTION SEP MODULE
FLUID INJ MODULE
54
UPS SYSTEM
COMMUNICATIONS
92
GASOLINE
17
GAS COMPRESSION MODULE
55
MOD 68 GENERATION
16
17
CONTROL ROOM / PANELS
96
COMPRESSOR LUBE OIL
18
POWER GEN. MODULE
56
CONTROL ROOMS & PANELS
96
MULTICORE CABLES
97
FUEL GAS
20
UTILITIES MODULE
57
MULTICORE CABLES
97
METHANOL STORAGE
30
PIPELINE MODULE
58
METHANOL INJ
31
STORAGE & PUMP MODULE
61
35
FLARE MODULE
62
POUR POINT DEPRESSANT
39
GENERAL ROADS & PADS
70
DEFORMER INJ
40
BRIDGES & CULVERTS
71
POLY-ELECTROLYTE INJ
41
CORROSION INHIBITOR
42
BIOCIDE INJECTION
43
SCALE INHIBITOR
44
CHEMICAL INJ GENERAL
DE-EMULSIFIER INJECTION
46
OXY SCAVENGER INHIBITOR
47
SEQUESTERING AGENT INHIBITOR
48
DETERGENT INHIBITOR
49
COOLING HEATING MEDIUM
50
DRAINS GENERAL
June 2001 / 02
45
COAGULANT INJECTION
60
CLOSED DRAIN
61
OPEN DRAIN
62
SLOP OIL
63
WASTE DISPOSAL
64
GLYCOL STORAGE
70
HVAC (ACCOMODATION)
80
MODULE SPACE HEATING
81
CONTROL ROOM & PANELS
96
MULTICORE CABLES
97
SYSTEM MNEMONICS - SALTEND
HANDOVER NUMBER
Example
P I
P S S T 1 0 0 0
SEQUENTIAL NUMBER (XXXX)
PRIMARY SYSTEMS (P)
PLANT IDENTIFIER (PI) ID LETTERS
VAM/ETAC (COMMON OFFSITES)
VAM
ETAC
IOS
TSEP
HULL SITE
CO
VA
EA
IO
TS
HS
SECONDARY SYSTEM (SS)
UTILITES
1
STRUCTURES
2
RAW MATERIALS & PRODUCTS
3
SPARE
4
SPARE
5
CONTROL & INSTRUMENT
(SAFETY SYSTEMS)
6
ETAC PROCESS
7
VAM PROCESS
8
ELECTRICAL
9
HANDOVER TYPE IDENTIFIER (T)
(LISTED UNDER RESPECTIVE PRIMARY SYSTEM)
DESCRIPTION
LETTER
CONSTRUCTED/COMMISSIONED
C
DESTRUCT
D
TEMPORARY
T
RE-INSTATEMENT/REFURBISHMENT
R
SHUTDOWN DEPENDANT
S
EQUIPMENT OUTAGE
E
PRIMARY SYSTEM 1
(UTILITIES)
ASSOCIATED SECONDARY SYSTEMS
WATER
- TOWNS
- PROCESS
- COOLING
110
111
112
STEAM
-
HP
IP
LP
LLP
STREAM TRACING
120
121
122
123
124
CONDENSATE
-
HP
IP
LP
LLP
130
131
132
133
PRIMARY SYSTEM 2
200
RAW MATERIALS & PRODUCTS
PRIMARY SYSTEM 6
-
TANKER EXPORT
-
FLARE
FIREWATER
ROAD LOADING
EFFLUENT PIT
150
151
152
153
ASSOCIATED SECONDARY SYSTEMS
ESD LOGIC
600
DCS LOGIC
601
CONTROL SCHEMES
602
PACKAGE CONTROLS
603
CONTROL & MARSHALLING PANELS 604
MULTI CORE CABLES
605
ETAC PROCESS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
300
301
302
303
304
305
306
307
308
309
310
311
PRIMARY SYSTEM 9
PRIMARY SYSTEM 8
(PLATFORM FABRIC)
(VAM PROCESS)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
- PARENT
700
- PARENT
800
- REACTION
710
- REACTION
810
- DISTILLATION
720
- DISTILLATION
820
- CHEMICAL HANDLING
740
- BENEFIELD UNIT
830
- HEAVY ENDS
840
- CHEMICAL HANDLING
850
ANCILLARIES
VAM PROCESS
n HYDRAULIC SYSTEMS
80
n CONTROL ROOMS/PANELS
n MULTICORE CABLES
96
97
n HEAT TRACING/INSULATION/CLAD 98
99
n COMMON
ANCILLARIES ARE COMMON TO PRIMARY SYSTEMS 1 - 8
January 2001 / 01
(SPARE)
(SPARE)
PRIMARY SYSTEM 7
ASSOCIATED SECONDARY SYSTEMS
PRIMARY SYSTEM 5
PRIMARY SYSTEM 4
PARENT
ETHYLENE
OXYGEN
ACETIC ACID
VAM ACETALDEHYDE STREAM
HEAVY ORGANICE SECONDARY PRODUCT
LIGHT ORGANICE SECONDARY PRODUCT
ETAC PRODUCT
VAM PRODUCT
GAS EXPORT STREAMS
POTASSIUM HYDROXIDE
CLOSED DRAIN / OFF SPEC TANK
(ETAC PROCESS)
-
140
141
142
143
144
145
ASSOCIATED SECONDARY SYSTEMS
(CONTROL & INSTRUMENTS SAFETY SYSTEMS)
CONTROL &
INSTRUMENTS
PLANT AIR
INSTRUMENT AIR
SPARE
HP NITROGEN
LP NITROGEN
NATURAL GAS
PRIMARY SYSTEM 3
ASSOCIATED SECONDARY SYSTEMS
- PARENT
-
(RAW MATERIALS & PRODUCTS)
(STRUCTURES)
STRUCTURES
GASEOUS UTILITIES
ELECTRICAL
-
33 kV POWER
3.3 kV POWER
415 V POWER
FIRE DETECTION & ALARMS
GAS DETECTION & ALARMS
LIGHTING
SMALL POWER
HEAT TRACING
900
901
902
903
904
905
906
907
SYSTEM MNEMONICS - BRUCE
HANDOVER NUMBER
Example
B R U 2 1 2 C 9 9 9 9
SEQUENTIAL NUMBER
FACILITY
IDENTIFIER
BRUCE
BRU
PRIMARY SYSTEMS
SECONDARY SYSTEM
HANDOVER TYPE IDENTIFIER
LETTER
WELLS
1
LIQUID STABILISATION, PUMPING & EXPORT
2
CONSTRUCTED/COMMISSIONED
C
GAS COMPRESSION, CONDITIONING, LIFT.
RE-INJECTION & EXPORT
3
DESTRUCT
D
DESCRIPTION
(LISTED UNDER RESPECTIVE PRIMARY SYSTEM)
4
WATER SYSTEMS
5
FLARE AND VENT SYSTEMS
TEMPORARY
T
RE-INSTATEMENT/REFURBISHMENT
R
SHUTDOWN DEPENDENT
S
EQUIPMENT OUTAGE
E
6
SAFETY SYSTEMS
DRILLING SYSTEMS
7
UTILITIES
8
PLATFORM FABRIC
9
PRIMARY SYSTEM 1
(WELLS)
ASSOCIATED SECONDARY SYSTEMS
PLATFORM
PLATFORM
WELL
WELL
SLOT
WELL
--A22
--A09
A01
A06
---
A1
B1
B2
B3
A20
---
A14
A8
A17Y
A12Z
A10Y
--A24
A08
-----
A2
A3
A4
A5
A6
A7
SLOT
WELL
C1
C2
C3
C4
C5
C6
--A23
C7
C8
A03
A16Z
A18
A05
-----
B4
B5
B6
B7
B8
WAD
PLATFORM
PLATFORM
SLOT
KEITH
WELL
SLOT
D1
D2
B01
B04Y
M2
A04
A07
A02
A11
D3
D4
D5
D6
B02Z
B03Z
B06
B05
M3
M4
M5
M6
-----
D7
D8
SLOT
WELL
M1
SLOT
K1
K2
M7
M8
--
PRIMARY SYSTEM 2
PRIMARY SYSTEM 3
PRIMARY SYSTEM 4
PRIMARY SYSTEM 5
(LIQUID STABILISATION, PUMPING & EXPORT)
(GAS SYSTEMS)
(WATER SYSTEMS)
(FLARE AND VENT SYSTEMS)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
n H.P. HYDROCYCLONES
n L.P. HYDROCYCLONES
01
HP FLARE
02
LP FLARE
ATMOSPHERIC VENT
10
20
30
20
MAINTENANCE VENT
40
30
FLARE IGNITION
50
H.P. GAS CONDENSATE TEST MANIFOLD
00
L.P. COMPRESSOR
10
DE-OILING
M.P. GAS CONDENSATE TEST MANIFOLD
STATFJORD TEST MANIFOLD
01
02
M.P. COMPRESSOR A
M.P. COMPRESSOR B
20
21
DE-GASSING
10
M.P. GAS CONDENSATE PRODUCTION MANIFOLD A
03
M.P. COMPRESSOR C
22
WATER INJECTION
M.P. GAS CONDENSATE PRODUCTION MANIFOLD B
STATFJORD OIL PRODUCTION MANIFOLD
04
05
DEHYDRATION TRAIN A
DEHYDRATION TRAIN B
30
31
PRODUCED WATER REINJECTION
KEITH PRODUCTION MANIFOLD
06
GLYCOL REGENERATION A
H.P. SEPARATOR TRAIN A
10
GLYCOL REGENERATION B
32
33
H.P. SEPARATOR TRAIN B
EXPORT COMPRESSOR A
40
PUQ TEST SEPARATOR
11
12
EXPORT COMPRESSOR B
41
L.P. SEPARATOR TRAIN A
L.P. SEPARATOR TRAIN B
13
14
CR SLUG CATCHER
15
EXPORT COMPRESSOR C
WARM UP HOT GAS
GAS RE-INJECTION
GAS FISCAL METERING
42
43
50
60
70
CR TEST SEPARATOR
16
MOL BOOSTER PUMP A
20
GAS EXPORT PIPELINE
MOL BOOSTER PUMP B
MOL BOOSTER PUMP C
21
22
GAS REINJECTION PIPE LINE
81
KEITH GAS LIFT MANIFOLD
90
MOL PUMP A
30
MOL PUMP B
MOL PUMP C
31
32
LIQUID FISCAL METERING
LIQUID EXPORT PIPE LINE
40
50
WAD TEST PIPE LINE
WAD PRODUCTION PIPE LINE
60
70
PRIMARY SYSTEM 6
PRIMARY SYSTEM 7
(SAFETY SYSTEMS)
ASSOCIATED SECONDARY SYSTEMS
EVACUATION SYSTEMS
PLATFORM CONTROLS
EMERGENCY POWER
FIRE PROTECTION
(ACTIVE)
n HELIDECK
n LIFEBOATS
n OTHER ESCAPE
ACCOMODATION
PLANT VENTILATION
01
02
MUD MIXING - ACTIVE AND RESERVE
03
FLUIDS
n INDUSTRIAL WATER
n POTABLE WATER
n PLANT AIR
n INSTRUMENT AIR
MUD MIXING - DEGASSING/DESANDING
04
MUD PUMPS
05
n FIRE & GAS
12
RIG UTILITIES
n TELECOMS
n GENERAL ADDRESS
13
14
CEMENTER UNIT
06
07
CUTTINGS RE-INJECTION
08
n PLATFORM ADDRESS
15
WELL SERVICES EQUIPMENT
n NAVAIDS
09
16
n WASH WATER
n INTEGRATED CONTROLS
17
CHEMICALS n DEMULSIFIER
n CONTROL NETWORKS
18
n COMMUNICATIONS
19
n CR MCS
20
n POWER GENERATION
n POWER DISTRIBUTION
21
n UPS / BATTERIES
n FIRE PUMPS
n FIRE LOOP
23
31
n
n
n
n
n
09
n CORROSION INHIBITOR
n SCALE INHIBITOR
n
n
n
n
n
22
32
33
INERT GAS
SEAWATER
DIESEL
FUEL GAS
SPARE NUMBER
OXYGEN SCAVENGER
CHLORINATION
BIOCIDE
HYDRATE REMOVER/INHIB
ANTIFOAM
11 COMMS
12
13 SANITARY
19
n WAX INHIBITOR
20
21
n SPARE NUMBER
22
35
n HAZARDOUS OPEN DRAINS
n DELUGE
n COATINGS
38
n FIREWALLS
42
n TEMPORARY REFUGE
51
n HVAC
52
n MEDICAL SUITE
53
n HOTEL FACILITIES
54
n DIRAVENT SYSTEMS
61
n BLOW-OUT PANELS
PERSONNEL PROTECTION n B.A. SETS
n SURVIVAL SUITS
42
51
n NETWORKS
n SEWAGE
52
61
18
n POLYELECTROLYTE
n HALON
n SPRINKLER
n EXTINGUISHERS
36
37
n COOLING
MEDIUMS
n TELEPHONES
71
14 HELICOPTER n HELICOPTER REFUELING
81
n MATERIAL HANDLING
15 SUPPORT
FACILITY
AND LIFTING
16
EQUIPMENT
n WORKSHOP/LABORATORIES 82
17
n CLOSED DRAINS
DRAINS
ASSOCIATED SECONDARY SYSTEMS
00 POWER GEN n MAIN GENERATION
31
01
n HV MAIN GENERATION DIST. 32
n MV MAIN GENERATION DIST. 33
02
03
n LV MAIN GENERATION DIST. 34
n STANDBY GENERATION
04
35
05
n STANDBY GENERATION DIST. 36
n
LIGHTING & SMALL POWER 37
06
n WELDING SOCKETS
38
07
n HEATING MEDIUMS
41
08 MEDIUMS
34
EXPLOSION PROTECTION n BLAST WALLS
January 2001 / 01
BULK CEMENT HANDLING
BULK MUD HANDLING
(PLATFORM FABRIC)
ASSOCIATED SECONDARY SYSTEMS
n MUSTER AREAS
04
n EMERGENCY SHUTDOWN 11
n HYDRANT / MONITORS
n FOAM
FIRE PROTECTION
(PASSIVE)
(UTILITIES)
ASSOCIATED SECONDARY SYSTEMS
01
02
03
PRIMARY SYSTEM 9
PRIMARY SYSTEM 8
(DRILLING SYSTEM)
23
n NON HAZARDOUS OPEN DRAINS 24
25
n STORM DRAINS
41
71
72
81
82
ANCILLARIES
n HYDRAULIC SYSTEMS
80
n CONTROL ROOMS/PANELS
n MULTICORE CABLES
96
97
n HEAT TRACING/INSULATION/CLAD
98
99
n COMMON
D PLATFORM
n MAIN MODULE (D10)
n DRILLING MODULE
AND DERRICK (D20)
PUQ PLATFORM n LEVEL 1 & 2 (P10)
n LEVEL 3, 4, 5 (P20)
n FLARE STACK (P30)
n ACCOMODATION (P40)
D1
D2
P1
P2
P3
P4
n D TO PUQ BRIDGE (P60) P6
CR PLATFORM n MAIN MODULE
n D TO CR BRIDGE
C10
C40
SYSTEM MNEMONICS - FORTIES
SH1 NUMBER
Example
A 2 1 2 C 9 9 9 9
SEQUENTIAL NUMBER
PLATFORM IDENTIFIER
PLATFORM
PRIMARY SYSTEMS
LETTER
FORTIES ALPHA
A
FORTIES BRAVO
B
FORTIES CHARLIE
C
FORTIES DELTA
D
FORTIES ECHO
E
FORTIES UNITY
U
DYCE
X
HANDOVER TYPE IDENTIFIER
SECONDARY SYSTEM
DESCRIPTION
LETTER
PLATFORM FABRIC
0
WELLS
1
CONSTRUCTED/COMMISSIONED
C
M.O.L. SYSTEM
2
DESTRUCT
D
NGL/DGL SYSTEMS
3
UTILITIES
(LISTED UNDER RESPECTIVE PRIMARY SYSTEM)
TEMPORARY
T
RE-INSTATEMENT/REFURBISHMENT
R
SHUTDOWN DEPENDENT
S
4
FLARE AND VENT SYSTEMS
5
PLATFORM EMERGENCY AND SAFETY SYSTEMS
EQUIPMENT OUTAGE
E
6
GAS LIFT SHUTDOWN
G
DRILLING SYSTEMS
7
NGL SHUTDOWN
N
IMPORT/EXPORT SYSTEMS
8
PWD SHUTDOWN
P
PLATFORM GENERATION
9
PRIMARY SYSTEM 1
PRIMARY SYSTEM 1
PRIMARY SYSTEM 1
PRIMARY SYSTEM 1
PRIMARY SYSTEM 1
(WELLS)
(WELLS)
(WELLS)
(WELLS)
(WELLS)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
FORTIES DELTA
FORTIES ECHO
FORTIES ALPHA
WELL
WELL
FORTIES BRAVO
03
4/1
SLOT
21
1/2
02
4/2
20
1/3
01
4/3
19
1/4
04
4/4
22
1/5
05
4/5
23
1/6
06
4/6
24
1/1
SLOT
WELL
SLOT
WELL
1/1
06
4/1
1/2
1/3
2/1
09
08
07
2/1
09
5/1
27
2/3
2/2
08
5/2
26
2/4
10
2/3
07
5/3
25
2/5
11
2/4
10
5/4
28
2/6
12
2/5
11
5/5
29
3/1
15
2/6
12
5/6
30
3/1
15
6/1
33
3/2
14
6/2
32
3/3
13
6/3
31
3/4
03
SLOT
21
20
10
1/2
05
4/2
20
E2
15
1/3
04
4/3
19
E3
09
2/1
09
4/4
22
E4
04
2/2
08
4/5
23
4/6
02
27
07
24
E5
2/3
5/1
E6
08
10
27
2/4
5/2
26
E7
14
2/5
11
5/3
25
E8
07
2/6
12
5/4
28
E9
13
3/1
15
5/5
29
E10
03
3/2
14
5/6
30
E11
16
3/3
13
6/1
33
E12
12
3/4
16
6/2
32
E13
05
6/3
31
E14
01
19
4/4
22
1/4
04
4/4
22
4/5
23
1/5
05
4/5
23
4/6
24
1/6
06
4/6
24
5/1
27
5/4
5/5
25
28
29
5/6
30
08
5/2
26
2/3
07
5/3
25
2/4
10
5/4
28
2/5
11
5/5
29
2/6
12
5/6
30
3/1
15
6/1
33
6/2
32
2/2
3/3
13
6/1
33
3/2
14
3/4
16
6/2
32
3/3
13
16
3/5
17
6/3
31
3/4
16
3/5
17
3/5
17
3/6
18
3/5
17
3/6
18
3/6
18
3/6
18
HYDRAULIC SYSTEMS
CONTROL ROOMS/PANELS
MULTICORE CABLES
HYDRAULIC SYSTEMS
80
96
HEAT TRACING/INSULATION/CLAD
97
98
COMMON
99
CONTROL ROOMS/PANELS
MULTICORE CABLES
HEAT TRACING/INSULATION/CLAD
COMMON
99
31
HYDRAULIC SYSTEMS
80
96
97
98
6/3
HYDRAULIC SYSTEMS
80
96
CONTROL ROOMS/PANELS
MULTICORE CABLES
HEAT TRACING/INSULATION/CLAD
97
98
COMMON
99
CONTROL ROOMS/PANELS
MULTICORE CABLES
HEAT TRACING/INSULATION/CLAD
COMMON
PRIMARY SYSTEM 2
PRIMARY SYSTEM 3
PRIMARY SYSTEM 4
(M.O.L.SYSTEM)
(NGL/DGL SYSTEMS)
(UTILITIES)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
80
96
HYDRAULIC SYSTEMS
CONTROL ROOMS/PANELS
MULTICORE CABLES
97
98
99
HEAT TRACING/INSULATION/CLAD
COMMON
BULK SEPARATOR FEED SYSTEMS
01
NGL GAS COMPRESSOR
01
TEST SEPARATOR FEED SYSTEMS
02
V16 SYSTEM
02
BULK SEPARATOR V01
BULK SEPARATOR V02
03
04
V06/V19/GLYCOL SYSTEM
03
PLANT AIR SYSTEM
INSTRUMENT AIR SYSTEM
02
03
V17 SYSTEM
04
TEST SEPARATOR
PRODUCTION GAS SCRUBBING
05
06
V18 SYSTEM
05
V20 GAS SCRUBBING
06
GAS LIFT MANIFOLD
LP BOOSTER/TRANSFER PUMPS
07
NGL PLANT RECYCLE
07
NITROGEN SYSTEM
SEAWATER DISTRIBUTION SYSTEM
DIESEL DISTRIBUTION
FUEL GAS DISTRIBUTION
04
05
06
07
08
RISER LIFT GAS SUPPLY (ON F A)
08
MULTIPHASE PUMP
09
GAS LIFT COMPRESSOR
10
P W COLLECTION HEADER
V160 DEGASSING VESSEL
10
11
TURBINE IGNITION GAS SUPPLY
DEMULSIFIER SYSTEM
CORROSION INHIBITOR SYSTEM
KO/UNLOADING COMPRESSOR
11
CLOSED CIRCUIT COOLING SYSTEM
12
V601 DEGASSING VESSEL
12
08
10
11
12
13
CONTROL ROOMS/PANELS
PWRI
13
96
MULTICORE CABLES
P W T TRAIN A (T602/W38)
14
97
P W T TRAIN B (T601/W600)
15
HEAT TRACING/INSULATION/CLAD
COMMON
98
99
STAND BY HYDROCYCLONE (FA ONLY)
16
RECLAIMED OIL VESSEL V1760 (FA & FD)
17
SEAWATER INJECTION SYSTEM
20
PRODUCED WATER SANDWASH SUPPLY
30
SEAWATER SANDWASH SUPPLY
31
HYDRAULIC SYSTEMS
80
SCALE INHIBITOR SYSTEM
OXYGEN SCAVENGER/BIOCIDE SYSTEM
SODIUM HYPOCHLORITE SYSTEM
FLOTATION AGENT SYSTEM
CLOSED DRAIN SYSTEM
TRI-ETHYLENE GLYCOL
01
ASSOCIATED SECONDARY SYSTEMS
STANDBY GENERATION
HV SWITCHBOARDS/DISTRIBUTION
LV SWITCHBOARDS/DISTRIBUTION
30
HP FLARE SYSTEM
01
31
32
MP FLARE SYSTEM
LP FLARE SYSTEM
02
03
LIGHTING AND SMALL POWER
WELDING SOCKETS
33
34
UPS/BATTERIES
NAVAIDS
TELECOMMUNICATIONS
ACCOMMODATION
35
36
37
40
41
LLP FLARE SYSTEM
ATMOSPHERIC VENT SYSTEM
MAINTENANCE VENT SYSTEM
FLARE IGNITION
CONTROL ROOMS/PANELS
04
05
06
07
96
MULTICORE CABLES
HEAT TRACING/INSULATION/CLAD
97
98
COMMON
99
SANITARY SERVICES
HVAC
HELICOPTER REFUELLING
DRAG REDUCING AGENT (DRG)
18
T71 AND LP DRAIN SYSTEM
OPEN DRAIN SYSTEM
20
COMMON
METHANOL INJECTION SYSTEM
22
16
17
50
60
70
80
96
97
98
99
21
96
MULTICORE CABLES
97
HEAT TRACING/INSULATION/CLAD
COMMON
98
99
PRIMARY SYSTEM 6
PRIMARY SYSTEM 7
(IMPORT/EXPORT SYSTEMS)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
PRIMARY SYSTEM 9
PRIMARY SYSTEM 0
(PLATFORM GENERATION)
(PLATFORM FABRIC)
PRIMARY SYSTEM 8
(DRILLING SYSTEM)
(PLATFORM EMERGENCY AND SAFETY SYSTEMS)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
PACKAGE 1 SWITCHGEAR
01
PACKAGE 2 MOL
02
PACKAGE 3 WELLHEADS
03
04
PACKAGE 4 DRILLING UTILITIES
04
HYDROSTART
05
PACKAGE 5 PRODUCTION
05
CONTROL ROOMS/PANELS
96
97
PACKAGE 6 DRILLING/BOP
06
MULTICORE CABLES
PACKAGE 7 GENERATION
07
HEAT TRACING/INSULATION/CLAD
98
PACKAGE 8 NGL PLANT
08
COMMON
99
PACKAGE 9 NORTH ACCOMMODATION
SOUTH TRUSS ACCOMMODATION
09
10
PACKAGE 11 HELIDECK
11
PACKAGE 12 FLARE TOWER
12
13
FIRE PROTECTION SYSTEM
01
BULK MUD HANDLING
01
EXPORT SYSTEM
01
02
FE 12" BULK TRANSFER SYSTEM
01
02
BULK CEMENT HANDLING
JO1
HP FIREWATER LOOP
02
LP FIREWATER LOOP
03
MUD MIXING - ACTIVE AND RESERVE
03
FE 6" TEST TRANSFER SYSTEM
03
JO2
JO3
02
03
HYDRANT/MONITORS
04
MUD MIXING - DEGASSING/DESANDING
04
FISCAL METERING SYSTEM
04
JO4
HI-EX FOAM
05
AIR COOLING - MUD PUMPS
05
FE BULK IMPORT SYSTEM ON FA
05
HALON SYSTEMS
06
RIG UTILITIES
06
FE TEST IMPORT SYSTEM ON FA
06
SPRINKLER SYSTEM
07
CONTROL ROOMS/PANELS
96
INFIELD IMPORT SYSTEM ON FC
07
DELUGE SYSTEM
08
MULTICORE CABLES
97
BRAE IMPORT SYSTEM
08
EXTINGUISHERS
09
HEAT TRACING/INSULATION/CLAD
98
MONTROSE IMPORT SYSTEM
09
FIRE & GAS DETECTION/CONTROL
10
COMMON
99
BUCHAN IMPORT SYSTEM
10
PERSONNEL PROTECTION
20
FORTIES FIELD 36" EXPORT SYSTEM
11
FIREWALLS
30
FORTIES FIELD 32" EXPORT SYSTEM
12
EMERGENCY SHUTDOWN SYSTEM
40
UNITY MANIFOLD
20
21
PACKAGE 13 DRILLING DERRICK
22
PACKAGE 14 OFFICE BLOCK
14
98
BRUCE IMPORT SYSTEM
NELSON IMPORT SYSTEM
23
PACKAGE 15 GRID LINE 1
15
99
ETAP IMPORT SYSTEM
24
PACKAGE 16 RADIO TOWER
16
BRITANNIA
25
GAS INJECTION MANIFOLD
17
CONTROL ROOMS/PANELS
96
GL PROCESS MODULE
18
MULTICORE CABLES
97
GL COMPRESSOR MODULE
19
HEAT TRACING/INSULATION/CLAD
98
MATERIAL HANDLING
96
COMMON
99
ARCHITECTURAL
97
PAINTING/PROTECTIVE COATING
98
COMMON
99
CONTROL ROOMS/PANELS
MULTICORE CABLES
96
97
HEAT TRACING/INSULATION/CLAD
COMMON
January 2001 / 01
98
99
PRIMARY SYSTEM 5
MECH HANDLING/LIFTING EQUIP
HYDRAULIC SYSTEM
CONTROL ROOMS/PANELS
MULTICORE CABLES
HEAT TRACING/INSULATION/CLAD
14
15
80
96
97
(FLARE AND VENT SYSTEMS)
ASSOCIATED SECONDARY SYSTEMS
POTABLE WATER
CONTROL ROOMS/PANELS
SLOT
E1
19
26
WELL
SLOT
21
4/3
5/1
WELL
4/1
01
09
SLOT
06
02
2/1
WELL
1/1
1/3
5/3
14
1/1
WELL
4/1
1/2
5/2
3/2
21
SLOT
20
4/3
04
WELL
4/2
4/2
05
2/2
FORTIES CHARLIE
SLOT
SCOTT IMPORT SYSTEM
SYSTEM MNEMONICS - ANDREW & CYRUS
SH1 NUMBER
Example
7 2 1 2 C 9 9 9 9
SEQUENTIAL NUMBER
PLATFORM IDENTIFIER
PLATFORM
CODE
ANDREW
7
CYRUS
8
PRIMARY SYSTEMS
HANDOVER TYPE IDENTIFIER
SECONDARY SYSTEM
DESCRIPTION
1
OIL SYSTEMS
2
CONSTRUCTED/COMMISSIONED
C
GAS SYSTEMS
3
DESTRUCT
D
WATER SYSTEMS
4
FLARE & VENT SYSTEMS
(LISTED UNDER RESPECTIVE PRIMARY SYSTEM)
TEMPORARY
T
RE-INSTATEMENT/REFURBISHMENT
R
SHUTDOWN DEPENDENT
S
EQUIPMENT OUTAGE
E
5
PLATFORM EMERGENCY AND SAFETY SYSTEMS
6
DRILLING SYSTEMS
7
UTILITES
8
PLATFORM FABRIC
9
PRIMARY SYSTEM 1
PRIMARY SYSTEM 1
(WELLS)
(WELLS)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
CYRUS
ANDREW
WELL
WELL
SLOT
13
01
02
14
02
03
15
03
04
16
04
05
17
05
06
18
06
07
19
07
08
20
08
09
21
09
10
22
10
11
23
11
12
24
12
80
96
97
HYDRAULIC SYSTEMS
CONTROL ROOMS/PANELS
MULTICORE CABLES
HEAT TRACING/INSULATION/CLAD
COMMON
98
99
HEAT TRACING/INSULATION/CLAD
COMMON
ANDREW PRODUCTION
CYRUS PRODUCTION
98
99
(FLARE AND VENT SYSTEMS)
(WATER SYSTEMS)
ASSOCIATED SECONDARY SYSTEMS
97
PRIMARY SYSTEM 5
PRIMARY SYSTEM 4
(GAS SYSTEMS)
ASSOCIATED SECONDARY SYSTEMS
80
96
CONTROL ROOMS/PANELS
MULTICORE CABLES
PRIMARY SYSTEM 3
(OIL SYSTEM)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
n TEST SEPARATOR HYDROCYCLONES
00
HP FLARE
10
10
n H.P. SEPARATOR HYDROCYCLONES
01
H.P. COMPRESSION
20
n L.P. SEPARATOR HYDROCYCLONES
02
DEHYDRATION
30
13
EXPORT COMPRESSION
40
14
15
GAS LIFT
50
GAS FISCAL METERING
60
MP FLARE
LP FLARE
LLP FLARE
ATMOSPHERIC VENT
MAINTENANCE VENT
FLARE IGNITION
20
30
40
50
60
70
GAS EXPORT PIPELINE
70
RE- INJECTION
80
00
COMPRESSOR TURBINE
00
10
11
L.P. COMPRESSION
12
n FISCAL METERING
n M.O.L. PUMPING
n EXPORT PIPELINE
n SEPARATION
n BOOSTER PUMPING
20
TEST SEPARATOR
H.P. SEPARATOR
L.P. SEPARATOR
BOOSTER PUMPING
SLOT
01
PRIMARY SYSTEM 2
n
n
n
n
WELL
SLOT
HYDRAULIC SYSTEMS
ANDREW TESTING
LETTER
WELLS
21
DE-OILING
n CYRUS SEPARATOR HYDROCYCLONES 03
DE-GASSING
10
SEPARATOR DE- SANDING
20
n LIQUID FISCAL METERING 22
CYRUS PIPELINES/RISERS
n PRODUCTION
n GAS LIFT
30
31
n RISER LIFT
32
PRIMARY SYSTEM 6
(PLATFORM EMERGENCY AND SAFETY SYSTEMS)
ASSOCIATED SECONDARY SYSTEMS
EVACUATION SYSTEMS
PLATFORM CONTROLS
EMERGENCY POWER
FIRE PROTECTION
(ACTIVE)
ACCOMODATION
ASSOCIATED SECONDARY SYSTEMS
BULK MUD HANDLING
01
BULK CEMENT HANDLING
02
03
MUD MIXING - ACTIVE AND RESERVE
03
n MUSTER AREAS
n EMERGENCY
SHUTDOWN
n FIRE & GAS
04
MUD MIXING - DEGASSING/DESANDING
04
11
AIR COOLING - MUD PUMPS
05
12
RIG UTILITIES
n TELECOMS
n GENERAL ADDRESS
13
14
CONTROL ROOMS/PANELS
06
96
MULTICORE CABLES
n PLATFORM ADDRESS
97
15
n NAVAIDS
16
n POWER GENERATION
n POWER DISTRIBUTION
21
22
23
n UPS/BATTERIES
n FIRE PUMPS
n FIRE LOOP
n HALON
n SPRINKLER
n EXTINGUISHERS
35
36
37
n DELUGE
n COATINGS
38
n FIREWALLS
42
n TEMPORARY REFUGE
51
n HVAC
52
41
53
n HOTEL FACILITIES
54
n DIRAVENT SYSTEMS
61
n SURVIAL SUITS
71
72
81
82
n POTABLE WATER
n
n
n
n
n
n
n
PLANT AIR
INSTRUMENT AIR
INERT GAS
SEAWATER
DIESEL
FUEL GAS
TURBINE IGNITION GAS
n WASH WATER
CHEMICALS n DEMULSIFIER
n CORROSION INHIBITOR
n SCALE INHIBITOR
n
n
n
n
32
n FOAM
n BLOW-OUT PANELS
98
FLUIDS
31
33
34
EXPLOSION PROTECTIONn BLAST WALLS
HEAT TRACING/INSULATION/CLAD
PRIMARY SYSTEM 0
(PLATFORM FABRIC)
ASSOCIATED SECONDARY SYSTEMS
02
PERSONNEL PROTECTIONn B.A. SETS
January 2001 / 01
(UTILITIES)
01
n MEDICAL SUITE
PLANT VENTILATION
PRIMARY SYSTEM 8
(DRILLING SYSTEM)
n HELIDECK
n LIFEBOATS
n OTHER ESCAPE
n HYDRANT/MONITORS
FIRE PROTECTION
(PASSIVE)
PRIMARY SYSTEM 7
DRAINS
OXYGEN SCAVENGER
CHLORINATION
BIOCIDE
HYDRATE REMOVER/INHIB
01
02
03
04
05
06
07
08
POWER
GENERATION
09
MEDIUMS
11
12
13
COMMS
14
15
16
17
n HAZARDOUS CLOSED DRAINS 21
n SAFE CLOSED DRAINS
n HAZARDOUS OPEN DRAINS
n SAFE OPEN DRAINS
n STORM DRAINS
22
23
24
25
ASSOCIATED SECONDARY SYSTEMS
31
n MAIN GENERATION
n HV MAIN GENERATION DIST. 32
n MV MAIN GENERATION DIST. 33
n LV MAIN GENERATION DIST.
34
n STANDBY GENERATION
35
n STANDBY GENERATION DIST. 36
n LIGHTING & SMALL POWER 37
n WELDING SOCKETS
n HEATING MEDIUMS
n COOLING MEDIUMS
38
41
42
51
SANITARY
n TELEPHONES
n NETWORKS
n SEWAGE
HELICOPTER
n TBA
52
61
71
SUPPORT FACILITY
n MATERIAL HANDLING
81
n WORKSHOP/LABORATORIES 82
SWITCHGEAR
01
ACCOMMODATION
02
HELIDECK
03
FLARE TOWER
04
DRILLING DERRICK
05
GAS COMPRESSION
06
ARCHITECTURAL
07
PAINTING/PROTECTIVE COATING
08
SYSTEM MNEMONICS - ETAP
HANDOVER NUMBER
Example
2 1 0 2 1 8 C 9 9 9 9
SEQUENTIAL NUMBER
FACILITY
IDENTIFIER
ETAP (General)
PdR
QU
MACHAR
MUNGO
MONAN
HERON
EGRET
SKUA
MARNOCK
MIRREN
SCOTER
PIPELINE - OIL
PIPELINE - GAS
PRIMARY SYSTEMS
210
211
212
221
231
232
241
242
243
251
252
253
271
281
WELLS
SECONDARY SYSTEM
HANDOVER TYPE IDENTIFIER
1
OIL SYSTEM
2
GAS SYSTEM
3
WATER SYSTEM
4
FLARE & VENT SYSTEMS
5
SAFETY SYSTEMS
6
DRILLING SYSTEMS
7
UTILITIES
8
PLATFORM FABRIC
9
DESCRIPTION
(LISTED UNDER RESPECTIVE PRIMARY SYSTEM)
LETTER
CONSTRUCTED/COMMISSIONED
C
DESTRUCT
D
TEMPORARY
T
RE-INSTATEMENT/REFURBISHMENT
R
SHUTDOWN DEPENDANT
S
EQUIPMENT OUTAGE
E
PRIMARY SYSTEM 1
(WELLS)
ASSOCIATED SECONDARY SYSTEMS
SLOT
MORAN
MACHAR
PRODUCTION
MARNOCK
WELL
WELL SLOT
WELL SLOT
WELL
HERON/EGRET/SKUA
SLOT
MIRREN/SCOOTER
WELL SLOT
MACHAR WATERFORD
MUNGO
WELL SLOT
WELL SLOT
WELL
SLOT
WELL
WELL SLOT
WELL
SLOT
01
11
20
30
40
50
60
70
80
86
96
02
03
12
13
21
22
31
32
41
42
51
52
61
62
71
72
81
82
87
88
97
98
04
14
23
33
43
53
63
73
83
15
24
34
44
54
64
74
84
90
16
25
35
45
55
65
75
85
91
07
17
26
36
46
56
66
76
92
08
09
18
19
27
28
37
38
47
48
57
58
67
68
77
78
93
94
29
39
49
59
69
79
95
-
PRIMARY SYSTEM 3
PRIMARY SYSTEM 4
PRIMARY SYSTEM 5
(GAS SYSTEMS)
(WATER SYSTEMS)
(FLARE AND VENT SYSTEMS)
MACHAR
00
MUNGO LIQUIDS
01
MUNGO/MONAN GAS
02
HERON CLUSTER (PIPELINE A) 03
HERON CLUSTER (PIPELINE B) 04
FUTURE A
09
FUTURE B
10
MIRREN
11
SCOTER
12
60
70
71
72
73
79
80
82
- HERON CLUSTER
20
OIL METERING - (FISCAL)
83
- SCOTER
30
OIL EXPORT COOLING
84
SLUGCATCHERS
-
MACHAR
MUNGO/MONAN
HERON CLUSTER
MIRREN
SCOTER
40
41
42
44
45
OIL EXPORT PUMPING
85
EXPORT PIPELINE (INCLUDING OIL PIGGING) 86
- HERON CLUSTER
51
L.P. GAS MANIFOLD
L.P. COMPRESSION
- TRAIN 1
- TRAIN 2
- DISCHARGE COOLING
00
11
12
13
H.P. GAS
- MANIFOLD
- GAS COOLING
- KNOCK OUT
30
31
32
GAS DEHYDRATION
GAS CHILLING
40
45
GAS EXPORT
- COMPRESSION TRAIN 1
- COMPRESSION TRAIN 2
51
52
GAS METERING (FISCAL)
60
GAS EXPORT PIPELINE
(INCLUDING GAS SPHERING/PIGGING)
61
GAS INJECTION COMPRESSION
MUNGO GAS INJECTION PIPELINE
GAS INJECTION MANIFOLD
RISER GAS LIFT
MARNOCK CONDENSATE
BANKING COMPRESSION
70
71
72
90
93
HYDROCYLONES
- H.P. PRODUCTION
- H.P. TEST
- L.P.
10
11
12
PRODUCED WATER
- DEGASSER VESSEL
- DISPOSAL
- RE-INJECTION RECYCLE COOLER
- RE-INJECTION PUMPS
- RE-INJECTION MANIFOLD
14
15
21
22
23
WATER INJECTION
- DEAERATION
- BOOSTER PUMPS
- PUMPS
- VACUUM PACKAGE
- PIPELINE - CPF TO MUNGO
- PIPELINE CPF TO MACHAR
- MANIFOLD
- WASHDOWN SUPPLY/DISTRIBUTION
50
51
52
53
54
55
56
57
WASH WATER
- BOOSTER PUMPS
- SULPHATE REDUCTION
- CRUDE WASHING PUMPS
- PIPELINE TO HERON CLUSTER
60
61
62
63
PRIMARY SYSTEM 6
PRIMARY SYSTEM 7
PRIMARY SYSTEM 8
(SAFETY SYSTEMS)
(DRILLING SYSTEM)
(UTILITIES)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
EVACUATION SYSTEMS
-
HELIDECK
LIFEBOATS
OTHER ESCAPE
MUSTER AREAS
01
02
03
04
PLATFORM CONTROLS
-
EMERGENCY SHUTDOWN
FIRE & GAS
TELECOMS
GENERAL ADDRESS
11
12
13
14
- PLATFORM ADDRESS
- NAVAIDS
15
16
- INTEGRATED CONTROLS
- CONTROL NETWORKS
- COMMUNICATIONS
17
18
19
DRILLING
BULK MUD HANDLING
BULK CEMENT HANDLING
MUD MIXING - ACTIVE AND RESERVE
MUD MIXING - DEGASSING/DESANDING
MUD PUMPS
RIG UTILITIES
CEMENT UNIT
CUTTINGS RE-INJECTION
01
02
03
04
05
06
07
08
09
FLUIDS
- POWER GENERATION
- POWER DISTRIBUTION
- UPS / BATTERIES
21
22
23
FIRE PROTECTION
(ACTIVE)
-
31
32
33
34
35
36
37
41
42
43
44
45
46
47
48
49
FIRE PUMPS
HYDRANT / MONITORS
FIRE LOOP
FOAM
HALON
SPRINKLERS
EXTINGUISHERS
DELUGE SYSTEM 1
DELUGE SYSTEM 2
DELUGE SYSTEM 3
DELUGE SYSTEM 4
DELUGE SYSTEM 5
DELUGE SYSTEM 6
DELUGE SYSTEM 7
DELUGE SYSTEM 8
DELUGE SYSTEM 9
- COATINGS
- FIREWALLS
50
51
EXPLOSION PROTECTION - BLAST WALLS
- BLOW-OUT PANELS
52
53
ACCOMMODATION
54
55
56
57
58
PLANT VENTILATION
-
LIVING QUARTERS
TEMPORARY REFUGE
HVAC
MEDICAL SUITE
HOTEL FACILITIES
- DIRAVENT SYSTEMS
59
POWER
GENERATION
-
INDUSTRIAL WATER
POTABLE WATER
PLANT AIR
INSTRUMENT AIR
INERT GAS
SEAWATER
DIESEL
FUEL GAS
TURBINE IGNITION GAS
HELIFUEL
-
INJECTION (COMMON)
10
DEMULSIFER
11
CORROSION INHIBITOR
12
SCALE INHIBITOR
13
OXYGEN SCAVENGER
14
HYPOCHLOITE
15
BIOCIDE
16
POLYELECTROLYTE
17
WAX INHIBITOR
18
REVERSE EMULSION BREAKER 19
H2S SCAVENGER
20
CHILORINATION
21
METHONNOL STORAGE/HAND. 22
METHONNOL INJECTION
23
ANTIFOAM
24
THI
25
BIOCIDE
26
HGI
27
-
MAIN POWER GEN 1
MAIN POWER GEN 2
WELDING SOCKETS
LIGHTING & SMALL POWER
AUXILIARY GENERATOR
AUXILIARY GEN DIST.
HV MAIN GEN. DIST.
MV MAIN GEN. DIST.
LV MAIN GEN. DIST.
ANCILLARIES
00
01
02
03
04
05
06
07
08
09
60
61
TOPSIDE HYDRAULICS (EXCLUDING WELLHEADS)
SUB-SEA HYDRAULICS
91
92
10
30
50
70
(PLATFORM FABRIC)
ASSOCIATED SECONDARY SYSTEMS
MEDIUMS
- HEATING MEDIUMS
- COOLING MEDIUMS
41
42
JACKET APPURTENANCES
(CASSONS ETC.)
00
COMMS
- TELEPHONES
- NETWORKS
51
52
SANITARY
DRAINS
- SEWAGE
61
- CLOSED
62
- HAZARDOUS OPEN
63
- NON-HAZARDOUS OPEN 64
- STORM
65
SWITCHGEAR
ACCOMMODATION
HELIDECK
FLARE TOWER
DRILLING DERRICK
GAS COMPRESSION
BRIDGE
ARCHITECTURAL
PAINTING/PROTECTIVE/COATINGS
01
02
03
04
05
06
07
08
09
SUPPORT FACILITY
- MATERIAL HANDLING
& LIFTING EQUIPMENT
- WORKSHOPS/LAB
66
GLYCOL
- STORAGE & HANDLING
- REGENERATION
- LEAN CONDITIONING
70
71
72
BRIDGE
- INTERFACES
89
UMBILICALS
-
90
91
92
93
94
95
96
97
98
99
MACHAR
MUNGO
MONAN
EGRET - HERON
SKUA - EGRET
CPF - SKUA
FUTURE ‘A’
FUTURE ‘B’
MIRREN
SCOTER
67
31
32
33
34
35
36
37
38
39
n HYDRAULIC SYSTEMS
80
n CONTROL ROOMS/PANELS
n MULTICORE CABLES
96
97
n HEAT TRACING/INSULATION/CLAD
98
99
n COMMON
PERSONNEL PROTECTION - B.A. SETS
- SURVIVAL SUITS
H.P. PROCESS RELIEF
L.P. PROCESS RELIEF
ATMOSPHERIC VENTING
FLARE IGNITION
PRIMARY SYSTEM 9
ASSOCIATED SECONDARY SYSTEMS
CHEMICALS
EMERGENCY POWER
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
REFERENCE OIL ALLOCATION METERING
PRODUCTION MANIFOLD
TEST MANIFOLD
PRODUCTION SEPARATION
TEST SEPARATION
NODE OIL HEATER
L.P. SEPARATION
OIL BOOSTER PUMPING
SUB-SEA MULTIPHASE
FIRE PROTECTION
(PASSIVE)
99
PRIMARY SYSTEM 2
PIGGING OIL
TEST SEPARATION
SLOT
(LIQUID STABILISATION, PUMPING & EXPORT)
ASSOCIATED SECONDARY SYSTEMS
BULK IMPORT PIPELINE
WELL
89
05
06
10
GENERAL
WELLHEAD SERVICES
OVERFLOW/SPARE
SLOT
ANCILLARIES ARE COMMON TO PRIMARY SYSTEMS 1 - 8
January 2001 / 01
Source: Legend Sheet 6 Numbering B-210X-48-18-0001.6 Rev Z1
SYSTEM MNEMONICS - HARDING
HANDOVER NUMBER
Example
H 2 2 1 C 9 9 9 9
SEQUENTIAL NUMBER
FACILITY
IDENTIFIER
HARDING
H
PRIMARY SYSTEMS
SECONDARY SYSTEM
WELLS
1
OIL SYSTEM
2
GAS SYSTEM
3
WATER SYSTEM
4
FLARE & VENT SYSTEMS
5
SAFETY SYSTEMS
6
DRILLING SYSTEMS
7
UTILITIES
8
PLATFORM FABRIC
9
HANDOVER TYPE IDENTIFIER
(LISTED UNDER RESPECTIVE PRIMARY SYSTEM)
LETTER
DESCRIPTION
CONSTRUCTED/COMMISSIONED
C
DESTRUCT
D
TEMPORARY
T
RE-INSTATEMENT/REFURBISHMENT
R
SHUTDOWN DEPENDANT
S
EQUIPMENT OUTAGE
E
PRIMARY SYSTEM 1
(WELLS)
ASSOCIATED SECONDARY SYSTEMS
WELL
SLOT
DESCRIPTION
WELL
SLOT
DESCRIPTION
PN 1
1
2
SPARE
OIL PRODUCTION
101
102
PIC3
13
FUTURE
113
AQ1
14
AQUIFER
114
PC1
3
OILPRODUCTION
103
PNE1
4
FUTURE
104
AQ2
PIC1
15
16
AQUIFER
OIL PRODUCTION
115
116
WC1
5
WATER INJECTION
105
WS1
17
WATER INJECTION
117
PC5
6
OIL PRODUCTION
106
PS2
18
OIL PRODUCTION
118
PC2
IC2
7
8
OIL PRODUCTION
OIL PRODUCTION
107
108
PSE3
19
OIL PRODUCTION
119
-
20
SPARE
120
WC2
9
WATER INJECTION
109
PC4
10
OIL PRODUCTION
110
SE2
PS1
21
22
FUTURE
OIL PRODUCTION
121
122
PC3
11
OIL PRODUCTION
111
PSE1
23
OIL PRODUCTION
123
GI1
12
CAP GAS
112
-
24
SPARE
124
MNEMONIC
PRIMARY SYSTEM 2
PRIMARY SYSTEM 3
PRIMARY SYSTEM 4
PRIMARY SYSTEM 5
(OIL PROCESSING)
(GAS SYSTEM)
(WATER SYSTEM)
(FLARE AND VENT SYSTEMS)
ASSOCIATED SECONDARY SYSTEMS
TEST SEPARATION
- PARENT
-TEST MANIFOLD
-TEST SEPARATOR
210
211
212
- PARENT
- PROD MANIFOLD
- HP SEPARATOR
220
221
222
-
230
231
232
233
234
TANKER EXPORT
TANKER LOADING
PIPELINE EXPORT
LP SEPARATION/
WATER REMOVAL
OIL PRODUCTION
- SAMPLING
PARENT
LP SEPARATOR
COALESCER
CRUDE TRANSFER PUMP
PROD WATER PUMP
- PARENT
- FAST LOOP
- METERING
- PIPELINE EXPORT
- OIL TO STORAGE
240
241
- CRUDE EXPORT
- CRUDE
250
251
252
COMPRESSOR COMMON EQUIP
- COMPRESSOR DRIVE
- COMPRESSOR LUBE OIL
- COMPRESSOR SEAL GAS
- COMPRESSOR BUFFER GAS
310
311
312
313
314
L.P. COMPRESSION
320
H.P. COMPRESSION
330
340
341
342
343
253
- PARENT
- MOL PUMPS
- EXPORT PIPELINE
260
261
262
METERING PROVER
270
SAND REMOVAL PUMPS
280
GAS TREATMENT
- GAS CONDITIONING
- DEHYDRATION
- GLYCOL REGENERATION
STL SUBSEA SYSTEMS
290
GAS LIFT
350
CAP GAS TREATMENT
360
LP COMPRESSOR (GREEN)
370
242
243
PRIMARY SYSTEM 6
PRIMARY SYSTEM 7
PRIMARY SYSTEM 8
(SAFETY SYSTEMS)
(DRILLING SYSTEM)
(UTILITIES)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
EVACUATION
SYSTEMS
PLATFORM
CONTROLS
-
PARENT
HELIDECK
LIFEBOATS
OTHER ESCAPE
MUSTER AREAS
610
611
612
613
614
RIG
710
WELL CONTROL SYSTEM
720
MUD
730
-
PARENT
EMERGENCY S/D
FIRE & GAS
TELECOMS
G.A./P.A.
620
621
622
623
624
CEMENT
740
- NAVAIDS
- INTEGRATED CONTROL
625
626
- CONTROL NETWORKS
- HYDRAULICS
627
628
EMERGENCY POWER -
PARENT
POWER GENERATION
POWER DISTRIBUTION
UPS / BATTERIES
630
631
632
633
FIRE PROTECTION
(ACTIVE)
PARENT
FIRE PUMPS
FIRE LOOP
HYDRANT / MONITORS
FOAM
HALON
SPRINKLERS
EXTINGUISHERS
DELUGE SYSTEM
640
641
642
643
644
645
646
647
648
-
FIRE PROTECTION
(PASSIVE)
- PARENT
- COATINGS
- FIREWALLS
650
651
652
ACCOMMODATION
-
660
661
662
663
664
PLANT VENTILATION
- PARENT
- DIRAVENT SYSTEM
670
671
EXPLOSION
PROTECTION
- PARENT
- BLAST WALLS
- BLOW-OUT PANELS
680
681
682
- PARENT
- B.A. SETS
- SURVIVAL SUITS
690
691
692
PERSONNEL
PROTECTION
PARENT
TEMPORARY REFUGE
HVAC
MEDICAL SUITE
HOTEL FACILITIES
PROD WATER HYDROCYCLONES
410
H.P. FLARE
510
WATER INJECTION
420
L.P. FLARE
520
AQUIFER SYSTEM
- AQUIFER MANIFOLD
- AQUIFER DRUM
430
431
432
ATMOSPHERIC VENT
530
MAINTENENCE VENT
540
FLARE IGNITION
550
PRIMARY SYSTEM 9
(PLATFORM FABRIC)
ASSOCIATED SECONDARY SYSTEMS
PROCESS
UTILITIES
-
PARENT
POT / FRESH WATER
PLANT AIR
INSTRUMENT AIR
-
SEA WATER
DIESEL
FUEL GAS
ATK
810
811
812
813
814
815
816
817
818
-
PARENT
DEMULSIFIER
CORROSSION INHIB
SCALE INHIBITOR
OXY SCAVENGER
CHLORINATION
BIOCIDE
METHANOL
ANTIFOAM
820
821
822
823
824
825
826
827
828
DRAINS
-
PARENT
HAZ CLOSED DRAINS
HAZ OPEN DRAINS
NON HAZ OPEN DRAINS
830
831
832
833
POWER
GEN.
-
PARENT
MAIN GENERATION
MAIN GEN DIST (HV)
MAIN GEN DIST (MV)
MAIN GEN DIST (LV)
STANDBY GENERATION
STANDBY GEN DIST
LIGHTING/ SMALL SOCKETS
840
841
842
843
844
845
846
847
CHEMICALS
HEATING MEDIUM
COOLING MEDIUM
HVAC
ASSOCIATED SECONDARY SYSTEMS
- PARENT
8 70
SANITORY SERVICES - PARENT
- SEWAGE
880
881
SUPPORT FACILITIES -
890
891
892
893
PARENT
MATERIAL HANDLING
WORKSHOP / LAB
BILGE / BALLAST
850
851
ANCILLARIES
n HYDRAULIC SYSTEMS
80
n CONTROL ROOMS/PANELS
n MULTICORE CABLES
96
97
n HEAT TRACING/INSULATION/CLAD 98
99
n COMMON
ANCILLARIES ARE COMMON TO PRIMARY SYSTEMS 1 - 8
January 2001 / 01
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
- PARENT
- BASE STORAGE
TANKER METERING
HP SEPARATION
MNEMONIC
UTILITIES AREA COMP
- LEGS
- UTILITY AREAS
- HELIDECK
910
911
912
913
LIVING QUARTERS
920
DRILLING STRUCTURE
- DERRICK
- SUB STRUCTURE
930
931
932
PROCESS & DRILLING AREA
- PROCESS AREA
- FLARE BOOM
940
941
942
GRAVITY BASE TANK
950
MARINE
- JACKING AND LOCKING SYS
- ROV
960
960
960
SYSTEM MNEMONICS - NORTH EVEREST
HANDOVER NUMBER
Example
E R 2 2 1 C 9 9 9 9
SEQUENTIAL NUMBER
FACILITY
PRIMARY SYSTEMS
IDENTIFIER
NORTH EVEREST
LOMOND
ERSKINE
ARMADA
EV
LO
ER
AR
SECONDARY SYSTEM
WELLS
1
OIL SYSTEM
2
GAS SYSTEM
3
WATER SYSTEM
4
FLARE & VENT SYSTEMS
SAFETY SYSTEMS
6
DRILLING SYSTEMS
7
UTILITIES
8
PLATFORM FABRIC
9
(WELLS)
ERSKINE
LOMOND
ASSOCIATED SECONDARY SYSTEMS
D
TEMPORARY
T
RE-INSTATEMENT/REFURBISHMENT
R
SHUTDOWN DEPENDANT
S
EQUIPMENT OUTAGE
E
(WELLS)
ASSOCIATED SECONDARY SYSTEMS
ASSOCIATED SECONDARY SYSTEMS
MNEMONIC
01
101
01
101
SLOT
11
11
111
02
102
02
102
12
112
02
102
12
112
03
103
103
104
113
03
103
104
03
04
13
04
14
114
04
104
13
14
113
114
05
06
105
106
05
105
15
115
05
105
15
115
06
106
07
107
116
117
06
07
106
107
116
107
16
17
16
07
17
117
08
108
08
108
18
118
08
108
18
118
09
10
109
110
19
119
09
109
20
120
10
110
19
20
119
120
21
121
21
121
OIL PROCESSING
-
SEPARATION
WELL
SLOT
MNEMONIC
WELL
MNEMONIC
111
WELL
PRIMARY SYSTEM 3
(OIL PROCESSING)
(GAS SYSTEM)
PARENT
TEST SEPARATION
TEST MANIFOLD &
TEST SEPARATOR
CONDENSATE EXPORT
- PARENT
- PIPELINE PUMPS
- CONDENSATE EXPORT
250
251
252
- PARENT
- PRODUCTION MANIFOLD &
HP SEPARATOR
- IP SEPARATOR
- LP SEPARATOR
- CONDENSATE HEATER
220
221
COMMON CONDENSATE
EXPORT
- PARENT
260
222
223
224
ERSKINE SEPARATION
- PARENT
- SURGE VESSEL
- SURGE VESSEL BOOSTER
PUMPS
230
231
232
-
270
271
272
273
274
275
276
PARENT
SAMPLING
METERING
METER PROVER
PARENT
PIG RECEIVER
HP SEPARATOR
SEPARATOR
COOLER & EXPORT PUMPS
METERING
EXPORT
- PARENT
-
WELL
(WATER SYSTEM)
350
351
352
353
354
355
TRAIN 1 COMPRESSOR COMMON EQUIPT
- GAS TURBINE
- LUBE OIL
- SEAL GAS
320
321
322
323
ERSKINE COMPRESSOR
COMMON EQUIPMENT
- GAS TURBINE
- COMPRESSOR LUBE IOL
- COMPRESSOR SEAL GAS
360
GAS PROCESSING
330
331
332
333
GAS EXPORT
- SAMPLING
- GAS METERING
- GAS EXPORT
- ARMADA GAS EXPORT
- COMMON GAS EXPORT
370
371
372
373
374
375
VR COMPRESSION
- LP VR COMPRESSOR
- IP VR COMPRESSOR
380
381
382
GLYCOL REGENERATION
- GLYCOL REGENERATION SYSTEM
390
391
PRIMARY SYSTEM 6
PRIMARY SYSTEM 7
(SAFETY SYSTEMS)
(DRILLING SYSTEM)
ASSOCIATED SECONDARY SYSTEMS
340
341
342
343
361
362
363
(UTILITIES)
SAFETY SYSTEMS
- PARENT
600
RIG
710
UTILITES
- PARENT
800
510
EVACUATION
SYSTEMS
720
PROCESS
UTILITIES
520
MUD
730
ATMOSPHERIC VENT
530
610
611
612
613
614
WELL CONTROL SYSTEM
LP FLARE
-
CEMENT
740
-
PARENT
POT / FRESH WATER
PLANT AIR
INSTRUMENT AIR
SEA WATER
DIESEL
FUEL GAS
ATK
NITROGEN
810
811
812
813
814
815
816
817
818
CHEMICALS
-
PARENT
DRA
CORROSSION INHIBITOR
SCALE INHIBITOR
OXY SCAVENGER
CHLORINATION
BIOCIDE
METHANOL
DEMULSIFER
SOLVENT/DISPERANT
820
821
822
823
824
825
826
827
828
829
DRAINS
- PARENT
- HAZ CLOSED DRAINS
- HAZ OPEN DRAINS
- NON HAZ OPEN DRAINS
830
831
832
833
540
PIPELINE FLARE
550
PLATFORM
CONTROLS
-
PARENT
EMERGENCY S/D
FIRE & GAS
TELECOMS
G.A./P.A.
NAVAIDS
INTEGRATED CONTROLS
CONTROL NETWORKS
HYDRAULICS
620
621
622
623
624
625
626
627
628
EMERGENCY POWER -
PARENT
POWER GENERATION
POWER DISTRIBUTION
UPS / BATTERIES
630
631
632
633
FIRE PROTECTION
(ACTIVE)
PARENT
FIRE PUMPS
FIRE LOOP
HYDRANT / MONITORS
FOAM
HALON
SPRINKLERS
EXTINGUISHERS
DELUGE SYSTEM
640
641
642
643
644
645
646
647
648
-
FIRE PROTECTION
(PASSIVE)
- PARENT
- COATINGS
- FIREWALLS
650
651
652
ACCOMMODATION
-
660
661
662
663
664
PARENT
TEMPORARY REFUGE
HVAC
MEDICAL SUITE
HOTEL FACILITIES
PLANT VENTILATION
- PARENT
- DIRAVENT SYSTEM
670
671
EXPLOSION
PROTECTION
-
680
681
682
690
691
PERSONNEL
PROTECTION
PARENT
BLAST WALLS
BLOW-OUT PANELS
PARENT
B.A. SETS
ANCILLARIES
n HYDRAULIC SYSTEMS
POWER GENERATION - PARENT
- MAIN GENERATION - A
- MAIN GENERATION - B
- MAIN GENERATION - C
- STANDBY GENERATION
- STANDBY GENERATION DIST.
- LIGHTING/ SMALL SOCKETS
- WELDING SOCKETS
840
841
842
843
844
845
846
847
HEATING MEDIUM
COOLING MEDIUM
850
851
COMMUNICATIONS
- PARENT
- TELECOMS
- NETWORKS
860
861
862
HVAC
- PARENT
870
SANITORY SERVICES - PARENT
- SEWAGE
- SEWAGE CAISON
880
881
882
SUPPORT FACILITIES -
890
891
892
893
80
n CONTROL ROOMS/PANELS
n MULTICORE CABLES
96
97
n HEAT TRACING/INSULATION/CLAD 98
99
n COMMON
January 2001 / 01
ANCILLARIES ARE COMMON TO PRIMARY SYSTEMS 1 - 8
PARENT
MATERIAL HANDLING
WORKSHOP / LABORATORIES
BILGE & BALLAST
ERSKINE PRODUCED WATER
- HP HYDROCYCLONES
- LP HYDROCYCLONES
- PRODUCE WATER DEGAS
420
421
422
423
ASSOCIATED SECONDARY SYSTEMS
500
FLARE IGNITION
400
410
411
412
413
(PLATFORM FABRIC)
ASSOCIATED SECONDARY SYSTEMS
HP FLARE
PARENT
HELIDECK
LIFEBOATS
OTHER ESCAPE
MUSTER AREAS
WATER PROCESSING
- PRODUCED WATER(EV & LO)
-TILTED PLATE SEPARATOR
- REJECT OIL PUMPS
- PRODUCE WATER DUMP
PRIMARY SYSTEM 9
PRIMARY SYSTEM 8
ASSOCIATED SECONDARY SYSTEMS
MNEMONIC
ASSOCIATED SECONDARY SYSTEMS
ERSKINE GAS PROCESSING
- GAS TREATMENT
- EXPORT COMPRESSOR
- FLASH GAS COMPRESSOR
- EXPORT GAS METERING
- GAS EXPORT
TRAIN 2
GAS TREATMENT
DENSE PHASE COMP
REINJECTION COMP
SLOT
PRIMARY SYSTEM 4
300
301
310
311
312
313
-
PARENT
GAS COOLERS
TRAIN 1
GAS TREATMENT
DENSE PHASE COMP
REINJECTION COMP
TRAIN 2 COMPRESSOR COMMON EQUIPT
- GAS TURBINE
- LUBE OIL
- SEAL GAS
PRIMARY SYSTEM 5
ASSOCIATED SECONDARY SYSTEMS
GAS PROCESSING
TRAINS 1 & 2 FEED
GAS PROCESSING
280
240
241
242
243
(FLARE & VENT SYSTEMS)
MNEMONIC
101
ASSOCIATED SECONDARY SYSTEMS
200
210
211
CONDENSATE METERING & SAMPLING
-
SLOT
01
PRIMARY SYSTEM 2
ARMADA IMPORT
FLARES & VENTS
C
DESTRUCT
EVEREST
ASSOCIATED SECONDARY SYSTEMS
CONDENSATE SURGE
LETTER
CONSTRUCTED/COMMISSIONED
PRIMARY SYSTEM 1
PRIMARY SYSTEM 1
(WELLS)
SLOT
DESCRIPTION
5
PRIMARY SYSTEM 1
WELL
HANDOVER TYPE IDENTIFIER
(LISTED UNDER RESPECTIVE PRIMARY SYSTEM)
UTILITIES AREA COMP
- LEGS
- UTILITY AREAS
- HELIDECK
910
911
912
913
LIVING QUARTERS
920
DRILLING STRUCTURE
- DERRICK
- SUB STRUCTURE
930
931
932
PROCESS & DRILLING AREA
- PROCESS AREA
- FLARE BOOM
940
941
942
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
SYSTEM PRINCIPLES - APPENDICES
APPENDIX 1.1
System Handover Limit Examples
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SECTION 1
REVISION: 1
PAGE: ii
GUIDANCE ON CERTIFICATION
SECTION 1.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
APPENDIX 1.1 – LOSH LEGEND
PAGE: 1
LOSH Legend
Each handover by default would contain a green LOSH drawing, the Handover
Authority may then decide to include additional drawings highlight accordingly to
give the different phases the appropriate profile and visibility.
If a Handover was phased as below each phase would be represented by an
MC1, for example if the handover was for the Bruce Platform, the SH1 number
could be: - BRU 212C0158 would be made up from the following MC1’s;
SH1: - BRU 212C0158 (Limit of System Handover - Green Highlighted Drawing)
MC1: - BRU 212C0158+01 (Pre-Shutdown Scope – Blue Highlighted Drawing)
MC1: - BRU 212C0158+02 (Shutdown Scope – Yellow Highlighted Drawing)
MC1: - BRU 212C0158+03 (Post-Shutdown Scope – Red Highlighted Drawing)
Limits of System Handover
Pre-Shutdown Scope
Shutdown Scope
Post-Shutdown Scope
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas Revision 1
Limits Of System Handover (Forties)
SYSTEM "BATTERY LIMITS"
210
UPSTREAM
TECHNOLOGY
212
V01
203
203
HV
LCV
245
245
210
ESDV
1858
A
210 212
ESDV
1858
ESDV
1858
A
B
LCV
1827
212
V601
212
215
215
214
T601
215
W38
214
V02
204
212
20
4
210
W600
215
214
211
210
T602
214
HV
LCV
ESDV
ESDV
PCV
275
275
1822
A
1822
B
1815
V160
211
212
215
OVERBOARD
211
205
212
TO
SEADUMP
213
V03
205
212
ESDV
ESDV
LCV
1912
A
1912
B
215B
ESDV
ESDV
LCV
1913
A
1913
B
215A
214
213
PROD WATER
205
211
PRODUCED WATER DISPOSAL SYSTEM
INJECTION
PUMPS
PRODUCED
WATER
TO
WELLHEADS
PACKAGE 1
ECP3003
U.P.S.
SUITE
A.C. DIST
SECTION
EMERGENCY
STOP
PB 1
EMERGENCY
STOP
PB 2
11 KV SUPPLY
CB 4
PACKAGE IX
RED
SHUTDOWN
SYSTEM
V.S.D.
TRANSFORMER
T 3008
V.S.D.
CUBICLES
K 3000 VSD - CP
REMOTE EMERGENCY
STOP
HEAT
EXCHANGE
FAN
K 3000 & K 3001
INTERPOSING
RELAY PANEL
COMPRESSOR
CONTROL PANEL
AUX. MCC 12
NGL CONTROL ROOM
SOUTH WEST CANTILEVER
MB-AL-E-006
TRACE HEATING
PANEL ‘D’
TO GAS LIFT
MANIFOLD
COMPRESSOR SKID
MOTOR
PACKAGE LIMITS
SYSTEM LIMITS
Figure 9
PROCESS SKID
FROM SOURCE
GAS SUPPLY
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
SYSTEM PRINCIPLES - APPENDICES
APPENDIX 1.2
GOC "Carrier" Certificate Example
Technical Integrity Assurance Flowcharts
Functional Certification Flowchart
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SECTION 1
REVISION: 1
PAGE: iii
SAMPLE
Project Title: AFA 2424 (ESCAPE TO SEA)
Maintenance No:
Work Pack No: No 1
SH1 No: C620C0586
MC1 No: C620C0586+01
MECHANICAL HANDLING INSTALLATION CERTIFICATE
FORM MH1
SITE:
FORTIES CHARLIE
SHT
1
EQUIPMENT No. LIFERAFT No 4
LOCATION NE CORNER
WIN No. 5129-1890 & 5129-1891
DRAWING No 2424-03-01-53-109-015
OF
1
SERIAL No. N/A
DESCRIPTION LIFERAFT PAINTER PADEYE/DONUT
G.A. No
STATION No 4
ITEM/DESCRIPTION OF CHECK
SIGNATURE
1. TRANSIT DAMAGE CORRECT
N/A
2. FIXED EQUIPMENT INSTALLED IN ACCORDANCE WITH APPROVED DRG's AND SPEC.
20/04/01
3. TRAVEL & OPERATION OF EQUIP. UNRESTRICTED & IN ACCORDANCE WITH DESIGN SPEC.
4. ASSOCIATED ALIGNMENT CHECKS COMPLETE ON:
20/04/01
------------------------
(a)
RUNWAY BEAMS
N/A
(b)
GANTRIES
N/A
(c)
BEAM TRANSFER AND LATCH MECHANISMS
N/A
(d)
ASSOC. MECH. EQUIP. i.e. WINCHES, HOISTING MECHANISMS
N/A
(e)
OTHER:
N/A
5. ASSOCIATED LIFTING APPLICANCES CORRECTLY INSTALLED, TAGGED AND CERTIFIED:
(a)
DATE
BEAM TROLLIES
------------------------
--------------
--------------
N/A
(b)
COMBINED TROLLEY HOISTS
N/A
(c)
CHAIN HOISTS
N/A
(d)
OTHERS:
N/A
6. ASSOCIATED DESIGNATED LIFTING TACKLE CORRECTLY INSTALLED, TAGGED & CERTIFIED:
------------------------
(a)
WIRE ROPES
N/A
(b)
SHEAVE BLOCKS
N/A
(c)
SHACKLES
N/A
(d)
BEAM CLAMPS
N/A
(e)
SLINGS
N/A
(f)
EYEBOLTS
N/A
(g)
OTHERS:
N/A
--------------
7. CHECK S.W.L.S. IF ALL EQUIP, WITHIN AN INSTALLED LIFTING SYSTEM ARE COMPATIBLE
20/04/01
8. PERSONNEL PROTECTION AND SAFETY DEVICES CORRECTLY INSTALLED
20/04/01
9. EQUIPMENT IDENTIFICATION AND S.W.L. CLEARLY MARKED
10. CHECK THAT ALL MATERIAL AND FABRICATION REQUIREMENTS AS PER SPECIFICATION
AND APPROVED DRAWING HAVE BEEN MET AND ALL CERTIFICATION IS RECORDED.
(APPLICABLE TO INSTALLATION OF FIXED EQUIPMENT)
11. ALL EQUIPMENT CORRECTLY INSTALLED AND AVAILABLE FOR PROOF LOAD TEST
SEE PUNCH LIST
20/04/01
20/04/01
20/04/01
COMMENTS
COMPLETED BY
APPROVED BY
AMEC
BP
PRINT NAME
A.SERVICE
A.CLIENT
DATE
20/04/01
20/04/01
COMPANY
SIGNATURE
GOC
© BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title: AFA 2424 (ESCAPE TO SEA)
Maintenance No:
Work Pack No: No 1
SH1 No: C620C0586
MC1 No: C620C0586+01
SAMPLE
MECHANICAL HANDLING ACCEPTANCE CERTIFICATE
FORM MH2
(SIDE 1)
SITE:
FORTIES CHARLIE
SHT
1
OF
1
ITEM LIFERAFT PAINTER PADEYE/DONUT
LOCATION NE CORNER DONUT STATION No 4
EQUIPMENT No LIFERAFT No 4
S.W.L. 300 KG & 333 KG
WIN No 5129-1890 & 5129-1891
PROOF LOAD 600 KGS & 666 KGS
SERIAL No N/A
PROOF LOAD CERTIFICATE No 940414
CERTIFYING AUTHORITY BIS
DRAWING No 2424-03-01-53-109-015
MAKER & DATE OF MAKE
DATE FIRST PUT INTO USE
DATE OF LAST RECORD EXAMINATION (IF SEEN). NAME OF
PERSON WHO CONDUCTED LAST EXAMINATION AND OF HIS
EMPLOYER.
FIRST EXAMINATION
PARTS NOT ACCESSIBLE FOR THOROUGH EXAMINATION
NONE
PARTS THAT REQUIRE OPENING UP AT THE NEXT EXAMINATION
NONE
PARTICULARS OF DEFECTS AND REMEDY PARTICULARS OF ANY
DEFECT FOUND IN THE LIFTING APPLICANCE AND THE REPAIRS
(IF ANY) REQUIRED, EITHER ;
i IMMEDIATELY OR,
ii WITHIN A SPECIFIED TIME (WHICH MUST BE STATED) TO
ENABLE THE LIFTING APPLICANCE OR LIFTING GEAR TO
CONTINUE TO BE USED WITH SAFETY. (IF NO SUCH REPAIRS ARE
REQUIRED, THE WORK 'NONE' IS TO BE ENTERED)
NONE
SAFE WORKING LOAD SUBJECT TO THE REPAIRS, RENEWALS
AND ALTERATIONS (IF ANY) SPECIFIED ABOVE IN THE CASE OF A
CRANE WITH A VARIABLE OPERATING RADIUS, INCLUDING A
CRANE WITH DERRICKING JIB, THE SAFE WORKING LOAD AT
VARIOUS RADII OF THE JIB, TROLLEY OR CRAB TO BE STATED
NONE
SECTION 1 (TO BE COMPLETED WHERE APPROPRIATE TO PERMANENT LIFTING TACKLE INCLUDED IN PROOF LOAD TEST)
ITEM DESCRIPTION
TAG/IDENTIF. No
S.W.L.
CERTIFICATE No
5129-1890
5129-1891
333 KG
300 KG
940414
940414
1. DONUT POST PADEYE
2. PAINTER PADEYE
3.
4.
5.
6.
SECTION 2:
IF APPLICABLE, STATE ANY SPECIFIC LIFTING RESTRICTIONS WHICH MAY APPLY TO THE LIFTING EQUIPMENT OR
SYSTEM AND WHICH IS REQUIRED TO BE CLEARLY MARKED ON THAT EQUIPMENT
SECTION 3:
IF APPLICABLE, REFERENCE ANY FABRICATION, NDT, MATERIAL CONTROL CERTIFICATION AND INSPECTION
REPORTS RELATING TO THE CONSTRUCTION INSTALLATION ACTIVITIES
COPIES OF ALL PROOF LOAD CERTIFICATION LISTED ABOVE TO ACCOMPANY THIS CERTIFICATE
COMPANY
SIGNATURE
PRINT NAME
DATE
COMPLETED BY
BIS
BP
A.SERVICE
25/04/01
A.CLIENT
25/04/01
GOC
APPROVED BY
© BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
MECHANICAL HANDLING EXAMINATION REPORT
EQUIPMENT No. LIFERAFT No 4
SH1 No
WIN No.
MC1 No. C620C0586+01
1529-1890 & 1529-1891
FORM MH2
(SIDE 2)
C620C0586
SERIAL No. N/A
S.W.L. 300 KGs & 333 KGs
DRAWING No 2424-03-01-53-109-015
PROOF LOAD TEST CERTIFCATE No 940414
EXAMINATION REPORT
5129-1890 - ACCEPTABLE
5129-1891 - POST TO BE STENCILLED WITH WIN NUMBER AND SWL. THIS HAS BEEN RECORDED ON THE
HANDOVER PUNCH LIST.
COMMENTS
REFER TO ATTACHED BUCHAN INSPECTION SERVICES (BIS) TEST CERTIFICATE No 940414
PUNCH LIST NO.
COMPLETED BY
APPROVED BY
BIS
BP
PRINT NAME
A.SERVICE
A.CLIENT
DATE
24/04/01
25/04/01
COMPANY
SIGNATURE
GOC
© BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
Technical Integrity Assurance
Rev 03
Documentation requirements for Systems to be Handed Over or returned to the Operator for Operational use
Mechanical Discipline - Vessels & Piping
No
Yes
Project or
Modification?
Yes
No
Hydro-Carbon, Hydraulic
or Methanol Systems?
No
Water or Air / Nitrogen System? No
(including Potable or Foul)
Yes
No
Has the Item
been Strength
Tested?
Yes
Operating Pressure
No
over 100 psig (Water)
or 15 psig (Air)?
Yes
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Will Integrity (Containment) be broken?
Yes
Has the Item Yes
been Strength
Tested?
No
Is a Major
No
Components
Involved?
Yes
Strength-test(MP1) &/or Leak
Test (SL1) &/or Joint Service
Test (JI1) - Implement GOC
process to demonstrate TI.
High Risk
Leak Test(SL1) & Joint Service
Test (JI1) - raise SH1and
Record in Maintenance
Management System.
Medium/High Risk
Strength-test (MP1) & / or
Joint Service Test (JI1).
Record in Maintenance
Management System.
Medium/Low Risk
No Formal Testing,
Certification or
Documentation
Required.
Low Risk
Rev 03
Technical Integrity Assurance
Documentation requirements for Systems to be Handed Over or returned to the Operator for Operational use
Electrical and Control Disciplines
Will Integrity (Circuitry) be broken? (This Includes Software Modifications)
No
GOC©
Yes
Yes
Does the
Activity involve
No
Temporary
Portable
Equipment?
Yes
Implement GOC to Demonstrate
Technical Integrity of Project or
Modification
High Risk
BP Exploration 1989 – 2001 All Rights Reserved
Is the Activity a
new Project or
Modification to a No
Facility?
Does the Repair /
Does the Repair /
Maintenance involve
Maintenance involve
Major Components of No Major Components of No
the Plant or Electrical
the ESD or Fire & Gas
Systems?
Systems?
Yes
Raise appropriate GOC Certificates
to ensure TI is maintained, record
in the Maintenance Management
System
Medium/High Risk
Yes
No Formal Testing Certification or
Documentation Required.
Update Maintenance Management
System
Medium/Low Risk
No Formal Testing,
Certification or
Documentation
Required.
Low Risk
Functional Certification Flowchart
WESTERN HEMISPHERE
FABRICATION ACTIVITIES
MECHANICAL - GOC 2 - 7
FUNCTIONALITY CHECKING ACTIVITIES
JI1 PART A COMPLETE – DATA CARRIED FORWARD
MW1
MP1
JI1 PART B COMPLETE
DATA CARRIED FORWARD
JI1
PIPING
SF1
VESSELS
MV1
JI1
MACHINERY
MM1
JI1
HANDLING EQUIPMENT
MH1
MH2
HVAC
MM1
SP2
MM2
SL1
JI1
SL1
JI1
SL1
JI1
JI1 Part B
JI1 Part A
1
SS1
AS1
JI1 Part C
AS2
Non -Fabrication Activities
SYSTEM SAFE
CERTIFICATE
CONTROL - GOC 8
INSTRUMENTS
FIRE & GAS
TELECOMS
ELECTRICAL - GOC 9
1
JOINT
INTEGRITY
CERTIFICATE
MS1
ARCHITECTURAL
SERVICES
IRN
JI1
MW1
STRUCTURAL
INSPECTION
RELEASE NOTE
3
Note on SS1Certificate
THE SYSTEM SAFE CERTIFICATE
(SS1) FACILITATES THE HANDOVER
OF THE SYSTEM FROM THE
OPERATING AUTHORITY TO THE
CONSTRUCTION AUTHORITY TO
CONFIRM THE SYSTEM IS ISOLATED
AND IS IN A SAFE CONDITION
READY FOR CONSTRUCTION TO
COMMENCE.
MECHANICAL
COMPLETION
CERTIFICATE
MC1
CC1
PP1
SYSTEM
HANDOVER
CERTIFICATE
PLANT
PERFORMANCE
CERTIFICATE
PL1
NP1
PUNCH LIST
NONPERFOMANCE
SC1
EE1
2
PL1
EE2
PUNCH LIST
2
EE3
EE4
EE14
3
Note on JI1Certificate
ALL FLANGES, JOINTS, COMPRESSION FITTINGS
OR PLUGS IN PORTED BLANKS, IN PIPEWORK
CONTAINING PROCESS HYDROCARBONS, DIESEL,
PROCESS CHEMICALS, HYDRAULIC FLUIDS,
LUBRICATION OIL SYSTEMS, WATER INJECTION,
WATER RE - INJECTION. MUST BE TAGGED AND
RECORDED ON A JI1 CERTIFICATE.
APPLY SL1 & JI1 CERTIFICATES.
EE16
EE7
EE17
EE8
REFER TO GOC PIPING SECTION FOR FULL DETAILS
EE18
EE9
EE11
EE13
EE15
EE6
EE10
SC1
Note on PL1Certificate
AS PART OF THE
CONTINUAL REVIEW &
CLEARANCE PROCESS
OF AGREED PUNCH LIST
ITEMS. CARRY EXISTING
‘B’ ITEMS FORWARD TO
PC1 & SH1 STAGE
EE5
VENDORS/
SUPPLIERS
WORKS
SP1
SH1
CONSTRUCTION
POWER
DOWN
OPERATIONAL
PHASE
COMMISSIONING
POWER
UP
EE12
IRN
SS1
MC1
PL1
SH1
PP1
NP1
MW1
MP1
MV1
MM1
MH1
MS1
AS1
AS2
HANDOVER MANAGEMENT
: INSPECTION RELEASE NOTE
: SYSTEM SAFE CERTIFICATE
: MECHANICAL COMPLETION CERTIFICATE
: PUNCH LIST
: SYSTEM HANDOVER CERTIFICATE
: PLANT PERFOMANCE CERTIFICATE
: NON-PERFORMANCE CERTIFICATE
MECHANICAL INSTALLATION
: WELDING COMPLETION SUMMARY
: PIPING COMPLETION
: PRE-OPERATIONS INSPECTION
: MACHINERY INSTALLATION
: MECHANICAL HANDLING INSTALLATION
: STRUCTURAL COMPLETION
: FINAL PAINT COMPLETION
: FINAL COATING/INSULATION COMPLETION
CONTROL INSTALLATION
CC1 : CONTROL COMPLETION CERTIFICATE
ELECTRICAL INSTALLATION
EE1 : LV & MV CABLE TEST CERTIFICATE
EE2 : SWITCHGEAR, MCC, BUS DUCT TEST CERTIFICATE
EE3 : LV & MV CIRCUIT BREAKERS
TEST CERTIFICATE
EE4 : CONTACTOR STARTER & VSD TEST
EE5 : MV FUSED AIR SWITCH INSPECTION CERTIFICATE
EE6 : POWER TRANSFORMER TEST
EE7 : NEUTRAL GROUNDING RESISTOR TEST
EE8 : HEAT TRACE TEST
EE9 : ELECTRICAL GROUNDING
EE10 : HAZARDOUS LOCATIONS
EE11 : INSTRUMENT TRANSFORMER TEST
EE12 : PRIMARY & SECONDARY INJECTION RELAY TEST
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
MECHANICAL TESTING
: SYSTEM FLUSH
: SYSTEM LEAK OR SERVICE TEST
: JOINT INTEGRITY CERTIFICATE
: PRE-OPERATIONS ALIGNMENT
: MECHANICAL HANDLING LOAD TEST
: SYSTEM PERFORMANCE TESTS
CONTROL TESTING
SC1 : SYSTEM CONTROL (FUNCTION) TEST(s)
SP1 : SYSTEM PERFORMANCE TEST (HIPS)
SF1
SL1
JI 1
MM2
MH2
SP2
EE13
EE14
EE15
EE16
EE17
EE18
:
:
:
:
:
:
ELECTRICAL TESTING
ELEC. MOTOR/ROT. MACHINERY TEST
BATTERIES/BATTERY CHARGER TEST
U.P.S. TEST
GENERAL TEST CERTIFICATE **
** CAN BE USED IN BOTH
NAV - AIDS TEST
CONSTRUCTION &
AC GENERATOR TEST
COMMISSIONING PHASES
Western Hemisphere Revision 1
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
SYSTEM PRINCIPLES - APPENDICES
APPENDIX 1.3
Typical Basis of Design Contents
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SECTION 1
REVISION: 1
PAGE: iv
BP Exploration
Typical 'BASIS OF DESIGN' Contents Sheet
Section
1
2
3
4
5
6
7
8
9
10
11
12
-
GOC©
Content
Introduction
Current Status
Proposed Solution
Scope of Work
Design Data
Weight Impact
Safety Aspects
Handover Strategies
Constructability/Commissionability
Drawings
Data Capture
Manuals and Training Requirements
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
SYSTEM PRINCIPLES - APPENDICES
APPENDIX 1.4
Asset Nomination of Authorities
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SECTION 1
REVISION: 1
PAGE: v
Asset Nomination of Authorities
Activity Area
Signatory Body
Engineering
• Discipline - Mechanical
- Piping
- Structural
- HVAC
- Architectural Services
- Electrical
- Instruments
- Fire & Gas
- Telecoms
- Civil
• Handover Management
• EQ Management
• CA Co-ordination
• As-Build Co-ordination
• Master Records Update / Close-out
• Approval Authority
Construction
• Discipline - Mechanical
- Piping
- Structural
- HVAC
- Architectural Services
- Electrical
- Instruments
- Fire & Gas
- Telecoms
- Civil
• Approval Authority
Maintenance
• Discipline - Mechanical
- Piping
- Structural
- HVAC
- Architectural Services
- Electrical
- Instruments
- Fire & Gas
- Telecoms
- Civil
• Approval Authority
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Asset Nomination of Authorities
Activity Area
Signatory Body
Commissioning
• Discipline - Mechanical
- Piping
- Structural
- HVAC
- Architectural Services
- Electrical
- Instruments
- Fire & Gas
- Telecoms
- Civil
• Approval Authority
Operations
• Discipline - Mechanical
- Piping
- Structural
- HVAC
- Architectural Services
- Electrical
- Instruments
- Fire & Gas
- Telecoms
- Civil
• Approval Authority
Site Handover Management
• Handover Control
• Drawing / Documentation Control
• EQ Control
• Punch List Control
• Approval Authority
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
GUIDANCE ON CERTIFICATION
GOC © AMERICAS EDITION
SUBJECT:
SYSTEM PRINCIPLES - APPENDICES
APPENDIX 1.5
Glossary of Terms
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SECTION 1
REVISION: 1
PAGE: vi
SUBJECT:
GUIDANCE ON CERTIFICATION
APPENDIX 1.5
GOC© AMERICAS EDITION
REVISION: 1
GLOSSARY OF TERMS
PAGE: 1
GLOSSARY OF TERMS
It is appreciated that staff who have worked and are familiar with the Guidance
On Certification© (GOC©) will understand the abbreviations used, and so will
not need to use this glossary. However, in the case of new staff, they may not
understand the terminology and so this maybe a useful reference.
Incidentally, it will also serve to restrict the number of abbreviations which are
used for any one piece of information i.e. Drawing Number should be DRG NO
or DRW NO and NOT both.
ABS
American Bureau of Standards
AFA
Approved For Alteration
ACC
Accepted
AFC
Approved For Construction (Drawing)
AS1
Final Paint Completion Certificate
AS2
Final Coatings/Insulation Completion Certificate
BOD
Basis of Design
CA
Certifying Authority
CBT
Computer Based Training
CC
Commissioning Controller
CE
Certification Engineer
CC1
Control Completion Certificate
CCO
Commissioning Co-ordinator
CMP
Commissioning Management Process
COF
Certificate of Ftness certifies that the installation is fit to be
the established/stationed and maintained in the relevant
waters.
CS
Commissioning Superintendent
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
APPENDIX 1.5
GOC© AMERICAS EDITION
REVISION: 1
GLOSSARY OF TERMS
DC
Document Control
DCR
Design Construction Regulations
DIS
Data Input Sheet
DRW No
Drawing Number
DP
Dye Penetrate
DTI
Department of Trade and Industry (UK)
PAGE: 2
EE1
SHT 01
02
03
04
Shielded Instrument Cable, Insulation Resistance
Cable and Wire Insulation, Insulation Resistance
Cable D.C. High Potential Step Voltage
Insulation Resistance and DC Hi-Pot Graph
EE2
SHT 01
02
Switchgear Bus Insulation and Phasing
MCC Bus Insulation and Phasing
EE3
SHT 01
02
03
04
L.V. Power Circuit Breaker
Molded Case Breakers
Med. Voltage Circuit Breaker
High Voltage Limited Oil Interrupter
EE4
SHT 01
02
03
Contact Type Starter
Motor Thermal Overload Relay
Variable Speed Drives
EE5
SHT 01
Medium Voltage Air Switch Inspection
EE6
SHT 01
02
03
Two Winding Power Transformer
Transformer Turns Ratio (Requires Sketch on Back)
Three Winding Power Transformer
EE7
SHT 01
Neutral Grounding Resistor
EE8
SHT 01
02
Heat Trace Tape Inspection (Electrical)
Heat Trace Performance (Electrical)
EE9
SHT 01
02
Electrical Ground System Test
Grounding Resistance Test (Individual Electrodes)
EE10
SHT 01
Hazardous Location Certificate
EE11
SHT 01
Instrument Transformer Ratio Tests
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
EE12
SHT 01
02
03
GUIDANCE ON CERTIFICATION
APPENDIX 1.5
GOC© AMERICAS EDITION
REVISION: 1
GLOSSARY OF TERMS
PAGE: 3
Primary Injection Test
Secondary Injection Test
Relay Inspection (Individual units)
04
05
06
Over Current Relay Test
Instantaneous Over Current Relay Test
Over/Under Voltage Relay Test
07
08
09
Power Factor Relay Test
Frequency Relay Test
Transformer Differential Relay Test
10
Reverse Power Relay Test
EE13
SHT 01
02
Motors and Motor Circuits, Phase Rotation & Tests
Rotating Machinery
EE14
SHT 01
02
Battery Load Test (Bank)
Individual Battery Test Log
EE15
SHT 01
UPS Power Supply
EE16
SHT 01
General Test Certificate
EE17
SHT 01
Navigational Aids
EE18
SHT 01
02
AC Generator and Generator Circuits Test
Rotating Machinery (AC Generator) Test
(Individual Unit P.F. and PDA tests)
E&ID
Electrical * Instrumentation Diagram
EQUIP No
Equipment Identification Number
EQ
Engineering Query aka Request For Information (RFI)
ESD
Emergency Shutdown
F&G
Fire & Gas
FLOW DIAG
Flow Diagram
FCO
Functional Check Out (commissioning activities)
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
APPENDIX 1.5
GOC© AMERICAS EDITION
REVISION: 1
GLOSSARY OF TERMS
PAGE: 4
GA No
General Arrangement Drawing Number
G/L DRW
Green Lined Drawing (Commissioning As Built)
GOC
©
Guidance On Certification©
HCP
Handover Certification Pack aka Turnover Pack
HCR
Handover Change Request
HIPS
High Integrity Performance System
HSE
Health & Safety Executive
HVAC
Heating, Ventillation, Air Conditioning
IA
Integrity Authority
ICS
Instrument Contol System
IFC
Issued For Construction (Drawing)
IRN
Inspection Release Note is issued by an approved vendor to
demonstrate item(s) are to the required specification
I&T
Inspection and Test
ITS
Inspection and Test Summary defines the minimum
Inspection and Test requirements for a system, part system
or workpack.
IVA
Independent Verification Authority
JI1
Joint Integrity Installation Certiticate
JB
Junction Box
JP No
Job Pack Number
LAD
List of As-Built Drawings
LOSH
Limits of System Handover describes the boundries of a
particular Handover (single or multi-disciplinary) from within
which all the appropriate I&T activites can be established.
LTO
Licence to Operate gives the operator the authority to
operate the plant within defined parameters.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
APPENDIX 1.5
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
©
GLOSSARY OF TERMS
PAGE: 5
©
MANCON
MANagement CONtrol
MAOP
Maximum Allowable Operating Pressure
MAWP
Maximum Allowable Working Pressure
MC1
Mechanical Completion Certificate is the formal handover
from
the
construction/maintenance
authority
to
the
commissioning authority.
MDR
Material Data Reports
ME
Maintenance Engineer
MH1
Mechanical Handling Installation & Acceptance Certificate
MH2
Mechanical Handling Load Test Certificate
MICC
Mineral Insulated Control Cable
MM1
Machinery Installation Certificate
MM2
Machinery Alignment Certificate
MMS
Mineral Management System
MP1
Piping Completion Certificate
MPI
Magnetic Particle Inspection
MS1
Structural Completion Certificate
MV1
Mechanical Vessel/Tank/Cassion Installation & PSV/RD - Pre
Operations Inspection Certificate
MW1
Weld/Bolt-Up Summary
MPI
Magnetic Particle Inspection
MT
Magnetic Particle Testing
NCR
Non-Conformance Report
NDE
Non-Destructive Examination
NP1
Non-Performance Certificate
NRV
Non-Return Valve
OIE
Offshore Inspection Engineer
OM
Operations Manager
OIM
Offshore Installation Manager
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
APPENDIX 1.5
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
GLOSSARY OF TERMS
PAGE: 6
PE
Production Engineer
PFD
Process Flow Diagram
PI
Polarization Index
P&ID
Piping and Instrument Diagram
P&ID No
See P&ID
PL1
Punch List Form
PP1
Plant Performance Certificate
PSV
Pressure Safety Valve
PT
Liquid Penetrant Testing
QA Eng
Quality Assurance Engineer
QC
Quality Control
QP
Quality Plan
RD
Rupture Disk
RE
Resident Engineer
R/L DRW
Red Lined Drawing (Construction As Built)
RO
Repair Order
RFI
Request (Raise) For Information
aka Engineering Query
(EQ)
SCE
Senior Commissioning Engineer
SC1
System Control Certificate
SF1
System Flush Certificate
SH1
System Handover Certificate is the formal handover from the
commissioning authority to the operating authority.
SL1
System Leak /ServiceTest
SLD
Single Line Diagram
SOW
Scope of Work
SP1
System Performance Test (HIPS)
SP2
System Performance Test(s) (HVAC)
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
APPENDIX 1.5
GOC© AMERICAS EDITION
REVISION: 1
GLOSSARY OF TERMS
PAGE: 7
SQAE
Senior Quality Assurance Engineer
SS1
System Safe Certificate
SSK No
Site Sketch Number
SWL
Safe Working Load
TAG No
Identification Number
TI
Technical Integrity ; The condition of a PLANT that meets its
design criteria and intended purpose. Where deviation from
these exist they have been identified and assessed and any
changes necessary to ensure continued safe, efficient
operation have been implemented.
TIAF
Technical Integrity Assurance Flowchart helps the user to
evaluate the level of documentation/certification required
commensurate with the risk.
TIPS
Technical Integrity Performance Standards
TP
Turnover Pack aka Handover Certification Pack (HCP)
TQ
Technical Query
USCG
United States Coast Guard
WIN No
Works Inspection Number
WP No
Work Pack Number
WPS
Welding Procedure Specification
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
SECTION 2.0
WELDING AND NDE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
PAGE: 1
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
2.1
ACTIONS
2.1.1
General
PAGE: 2
Construction Management responsibilities and associated Quality
Planning for welding activities is normally categorized and managed
as follows:
a)
On-Site Work. The Construction Authority is responsible for ensuring
that the Inspection & Test requirements are carried out and for
management of the construction Contractor who provides labor and
equipment only.
b)
Off-Site Work. The Construction Authority monitors the performance of
the Management Contractor who is directly responsible for fabrication
and Inspection and Test activities.
c)
For on-site work, those Inspection and Test activities that require to be
performed and recorded to fulfill the minimum quality requirements are
clearly defined on the specific Inspection & Test Summary (ITS) for the
Project.
d)
For off-site work, those inspection and test activities performed by the
Managing Contractor that are deemed by BP or their Delegated
Authority to be at critical stages in the fabrication process and require to
be witnessed before the contractor can proceed, will be clearly defined
within the Contractor's Quality Plan (QP) or the supplied ITS.
e)
The term “construction” within this section should imply both on-site and
off-site fabrication.
f)
All welding activities shall be checked for compliance and other
requirements as detailed in, but not limited to:
•
•
The latest revision of Issued For Construction (IFC) or Approved
For Construction (AFC) Drawings and Schedules
Codes and standards reference in this section
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
2.1.2
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
PAGE: 3
•
•
•
•
Plant and Project Specifications
Equipment Specifications and Data sheets
BP Engineering Installation and Design Specifications
Local, state, country and international standards, codes, and
regulations as appropriate
•
Offshore - Special Standards, i.e. USCG, ABS and MMS
Welders Qualifications
All welders or welding operators shall have passed a welder qualification
test to a code or standard as specified in the appropriate Specification.
Such qualification tests shall have been witnessed by an approved
independent third party inspector, acceptable to BP or their delegated
authority. All records shall be endorsed by the Third Party Inspector and
the authorized Welding Inspector whose decision on acceptance shall
be final.
Note: Where appropriate, for off-site work, the Senior Welding Inspector
authorized by BP or its Delegated Authority may transfer the
responsibility for witnessing welder qualifications
Management Contractors Welding Inspector.
to
the
2.1.3
Prior Qualifications
Prior qualifications of welders may be considered where the integrity of
the records can be demonstrated and any such qualifications are
current.
2.1.4
NDE Qualifications
Qualifications and Certifications for Non-destructive examination (NDE)
personnel shall be per the requirements listed in:
ASNT-TC-1A: Recommended Practice for Personal Qualification &
Certification in Nondestructive Testing
AWS-QC1: Standard for AWS Certification of Welding Inspectors
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
2.2
Weld Inspection
2.2.1
General
a)
Guidelines For Weld Inspection
PAGE: 4
An essential requirement for the implementation of a simple control
system for weld identification by utilizing the structural fabrication or
isometric drawings, prior to the commencement of work. These drawings
should detail the full weld history by identifying each weld and welder
identification symbol.
Material traceability falls within the following categories:
b)
For onsite fabrication BP operates secured materials storage system
with approved auditable suppliers re materials certification and the level
of traceability is appropriate to ensure materials meet the required
project codes and specifications.
c)
For off site fabrication BP or their delegated authority ensures the
fabricator has the appropriate and approved audible materials control
system and warehousing procedures in operation.
d)
The following activities shall be performed by the Welding Inspector
authorized by BP or Delegated Authority for onsite work, the
Management Contractors Welding Inspector for offsite work and the
Third Party Inspectorate, where applicable.
e)
Prior to commencement of welding activities the Welding Inspector shall
ensure that:
A procedure for cold and hot cutting and weld preparation, inclusive of
material identification transfer, has been approved by BP or Delegated
Authority;
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
PAGE: 5
A BP or Delegated Authority approved WPS is available to the
welder/welding operator in written form or displayed prominently at the
welding location;
Welders/welder operators understand all requirements of the approved
procedures and are qualified to carry out the work;
A system to control the issue and use of welding consumables, as
required by project specifications has been agreed by BP or Delegated
Authority Welding Engineer and is in operation;
Appropriate measures for the protection against inclement weather
conditions have been taken;
All welding equipment, where applicable, is certified as fit for use. All
pre-heat and post weld heat treatment equipment has current calibration
report and is certified for use.
All weld preparations shall be in accordance with the specification
requirements and be clean and free of contaminants;
All fit-ups are within the weld procedure tolerances.
f)
During Welding operations, the Welding Inspector shall monitor that:
The relevant weld procedure as required by the applicable scope of work
is in place and that the operator is suitably qualified;
The issue of consumables and their control conforms to the applicable
weld and control procedure;
Pre-heat and interpass temperature levels are maintained in accordance
with approved WPS;
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
PAGE: 6
Runout tabs on critical pipe fabrication comply with the applicable
welding procedure.
Specified inspection hold points have been preformed by the
appropriate NDE examiner or Welding Inspector.
g)
On completion of welding operations, the Welding Inspector shall:
Visually inspect all welds to ensure compliance with the specification
and good workmanship, and confirm that the welder's identification is
marked adjacent to the weldment;
Ensure that, where applicable, post weld heat treatment is carried out as
per the specification, endorsing the heat treatment record charts
accordingly;
Ensure that where specified, a delay prior to NDT for ferritic steels is
enforced.
Verify that specified NDE inspections have been preformed prior/during
the welding process (i.e.: MT or root pass).
h)
Prior to NDE operations the Welding Inspector should check that:
All NDE procedures are approved by BP or delegated authority, to
ensure that they conform to the requirements of the fabrication
specification;
All NDE operators’ qualifications and certifications are acceptable and
are to the appropriate certification levels;
All NDE equipment and consumables are certified and fit for use and
certified as applicable;
UT equipment should have current annual calibration sticker;
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
PAGE: 7
Inspection hold point areas that require crack detection to be witnessed
by BP or Delegated Authority have been specified.
i)
Post NDE operations the Welding Inspector should check that:
For ultrasonic, liquid penetrant or magnetic particle testing, the test has
been carried out using the correct equipment, consumables and
technique, and that results have been reported correctly and interpreted
to the specification limits;
For radiographic testing, the test has been carried out using the correct
procedure, films have been developed in a correct manner and
interpreted to the applicable code.
j)
All NDE operations should be monitored throughout fabrication and
construction work as part of the overall quality control system. The
above is the minimum requirement but is not exclusive and may be
modified and categorized by the authorized Senior Welding Inspector or
authorized Welding Engineer.
k)
The performance of each welder/welder operator should be assessed to
ensure that his work meets minimum specification requirements with the
minimum repair rate while meeting production milestones.
Welder/welding operators who produce consistently bad workmanship
shall be subject to retesting before being allowed to continue. The
decision as to whether such a welder/welding operator can be allowed to
restart welding operations is at the sole discretion of the Welding
Inspector.
l)
Each weld examination record should be endorsed by the Welding
Inspector to signify acceptance of the results.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
2.2.2
Use Of Forms
a)
General Requirements
PAGE: 8
For on-site work, all reporting and recording of the results of Inspection
©
and NDE Tests shall be on the GOC standard form MW1 - Welding
Completion Summary.
For off-site, and on-site NDE, reporting and recording of results may be
on the Contractor's standard NDE forms when approved by BP or
Delegated Authority.
Brief details of the various forms are given below.
NDE reports can be used for recording the results of testing of more
than one acceptable weld provided that:
i.
The welds are all on a single piping isometric or structural assembly
drawing;
ii.
All parameters of the testing technique are identical for each weld;
iii.
Rejectable welds and any associated repairs are separately
reported.
NB: This extension of the use of NDE reports does not extend
to pipe-line riser welds, which shall be individually reported.
b)
Ultrasonic Inspection Report
To record the findings of the ultrasonic inspection and the techniques,
equipment, and parameter(s) used.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
PAGE: 9
Where necessary, a sketch showing reportable defect area dimensions
and locations, or outlining limited examination circumstances, shall be
attached to the parenting form.
c)
Magnetic Particle/Dye Penetrant Report
To record the results of magnetic particle or liquid penetrant
examinations and the parameters used.
Where necessary, a sketch showing reportable defect area dimensions
and locations, or outlining limited examination circumstances, shall be
attached to the parenting form.
d)
Radiographic Report
To record the results of radiographic examination of a weld, equipment,
and the parameters used.
Generally each report shall cover all of the parameters for the same
spool, i.e. wall thickness, diameter, exposure time, density, radiation
source type, film type, procedure number, etc., the report can cover
more than one weld.
e)
MW1 - Welding/Bolt-up Completion Summary
To record report numbers, including repairs for all visual examinations,
NDE and post weld heat treatment carried out on each weld on a subassembly or pipe spool and bolted connections in order to provide a
summary and allow easier retrieval of the back-up certificates.
The MW1 can effectively be used as an acceptance document to front
all weld inspection records within a Handover Certification Pack.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
f)
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
PAGE: 10
Heat Treatment Report
To record the parameters used for the heat treatment of a component or
weldment.
The temperature-time record at the beginning of the heat treatment
process should be "signed on" by the Welding Inspector and "signed off"
when the process is complete.
On completion of the heat treatment, the equipment calibration report
and the printout from the temperature and time recorder shall be
attached to the report for final acceptance.
Where items have been post weld heat treated as a batch, all item
numbers should be endorsed on the original temperature time record
and the individual heat treatment reports (if more than one is required),
should cross refer to the heat treatment report to which the original
certifications is attached.
g)
Qualification Test Record
All Welding Procedure Specifications and the results of monitoring weld
deposits and the laboratory test results shall be on the Contractors preapproved standard forms.
Welding Procedure Specification (WPS)
Welding Procedure Qualification Test Report
Macro Survey Test Results
Charpy Impact Test Results
Hardness Survey Test Results
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
h)
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
PAGE: 11
Welder Approval Test Certificate
All welders/welding operators shall be qualified to the approved WPS for
the work to be carried out. All such welder/welding operators’ tests shall
be recorded on the Contractors pre-approved standard form(s).
i)
Summary of Approved Welders
A summary of all welders/welding operators, including Sub-contractors
shall be maintained by the Welding Inspector and shall fully reference
welder’s identification, procedures, positions, thickness and diameters,
they are qualified to perform.
j)
Summary of Approved Weld Procedures
A summary of all weld procedures including qualifying positions and
reports, including Sub-contractor's, shall be maintained by the Welding
Inspector.
k)
Summary of Approved NDE Technicians
A summary of all NDE technicians, including Sub-contractor's, shall be
fully referenced by type of NDE and shall be maintained by the Welding
Inspector.
l)
Summary of Approved NDE Procedures
All NDE procedures, including Sub-contractor's, shall be fully referenced
on the NDE Procedure Register, which shall be maintained by the
Welding Inspector.
m)
Weld Repair Register
To be completed by particular structural assembly, construction
isometric or spool piece drawing.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
PAGE: 12
All repairs, including those performed prior to PWHT shall be recorded
on the MW1 and the Weld Repair Register.
Weld repairs shall be indicated as follows:
R1 = First Repair
R2 = Second Repair
C1 = Re-weld
These indicators shall be recorded as suffix to both the weld and
inspection report numbers.
Where welds are repaired or re-welded they shall retain their original
weld number. Inspection reports for weld repairs or re-welds shall retain
their original report number.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
PAGE: 13
MECHANICAL- WELDING AND NDE
FLOWCHART 2
•
Functional Certification Flowchart
•
Discipline: Mechanical (Welding)
MW1
MC1
SH1
MW1: Welding Completion Summary
MC1: Mechanical Completion Certificate
SH1: System Handover Certificate
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 2.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- WELDING AND NDE
EXHIBIT 2
STANDARD FORMS
Form No.
Title
MW1
Weld/Bolt-up Completion Summary
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
PAGE: 14
Project Title:
Description:
FORM MW1
Work Pack No:
SITE:
Maintenance No:
Line No:
WELD / BOLT-UP COMPLETION SUMMARY
DRAWING
NUMBER
WELD CATEGORIES
Insp.
Initials
WELD
NUMBER
S - SHOP WELD
WELDERS
IDENT
W - FIELD WELD
COMPILED BY
WPS
SH1 No:
VISUAL
INSPECT
X - BRANCH
NDE
TYPE
NDE
ACCEPT
DATE
SW - SOCKET WELD
SHT
MC1 No:
GASKET
TYPE
TORQUE
Ft-Lbs
R1 - FIRST REPAIR
OF
COMMENTS
R2 - SECOND REPAIR
C1 - RE-WELD
APPROVED BY
COMPANY
SIGNATURE
NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 1
SECTION 3.0
PIPE TESTING
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
3.1
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 2
ACTIONS
3.1.1
General
a) The acceptance of off-site fabricated and on-site installed pipework is a
composite function of Welding and Weld Inspection (Section 2.0), Pipe
Testing (Section 3.0), and Architectural Services (Section 7.0). Input by
the relevant discipline engineers is required during quality planning and
subsequent development of an Inspection & Test Summary.
All Pressure Testing shall be undertaken when suitable barriers and
notices are in place around the test area.
b)
Pipework shall be checked for compliance and other requirements as
detailed in, but not limited to:
•
•
•
•
•
•
•
c)
The latest revision of Issued For Construction (IFC) or Approved
For Construction (AFC) Drawings and Schedules
Codes and standards reference in this section
Plant and Project Specifications
Equipment Specifications and Data sheets
BP Engineering Installation and Design Specifications
Local, state, country and international standards, codes, and
regulations as appropriate
Offshore - Special Standards, i.e. USCG, ABS and MMS
Within the system limits or boundaries specified the piping shall be
assembled into Test Packs to facilitate Pressure testing (strength-testing
of welds), or the installation of pre-hydro tested and pre-certified flanged
piping, that will only require to be leak-tested or service-tested postinstallation.
The Piping Test Pack number will be pre-fixed with a two letter ID to
indicate the type of test required. Below is listed the three most common
Piping Test Pack prefixes.
HT – Hydro test (strength-testing of welds, raise MP1)
LT – Leak Test (leak test pre-certified/tested pipework, raise SL1)
ST – Service-test (service-test pre-certified/tested pipework, raise JI1)
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The contents of Test Packs index, as a minimum, shall be as follows:
i)
Work Package Number, and/or Maintenance ID No., and Test Pack No;
ii)
Hydrotest Schematic where applicable;
iii)
Isometric drawings or site sketches, where applicable;
iv)
v)
Flange make-up tagging procedure and /or Flange Check register;
P&ID.
d) The Engineering authority shall produce clear means of identifying the
limits of test to reflect the simplicity or complexity, as appropriate, of the
hydrotest scope.
e)
A safety valve shall be fitted to the test equipment or to the
equipment/plant being tested, set to relieve at a pressure to prevent the
test pressure being exceeded. The safety valve shall be capable of
discharging the capacity of the charging system at the test pressure.
f)
The flowchart contained within this document gives guidelines on quality
planning for both on-site and off-site pipe fabrication.
3.1.2
Use Of Forms
a)
General Requirements
For on-site fabrication and installation, all reporting and recording of the
results of inspections and tests shall be on the GOC© standard forms,
listed in Exhibit 3 (at the end of this section), as specified by the
Engineering Authority.
For off-site fabrication, reporting and recording of the results of
inspections and tests may be on the Contractor's standard forms when
recommended by the authorized Mechanical Engineer and approved by
the Engineering Technical Authority.
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MP1: Piping Completion Certificate
To record that piping has been satisfactorily pressure tested and
reinstated.
It is also used to record the following:
That flushing/blowing has been carried out to the required cleanliness
following completion of Procedures 3.1 and 3.2;
In the case of hydrotesting, that the requirements of Procedure 3.1
(3.1.43), should be used. The associated pressure, temperature and
time records should be attached to form MP1;
When carrying out pneumatic testing, Procedure 3.1, (3.1.5) shall be
used;
That piping has been satisfactorily reinstated in accordance with
Procedure 3.1, (3.1.6).
In the case of Fire and Gas piping, that the essential checks have been
carried out, ensuring that the piping associated with the fire water
mains, sprinkler, deluge and fire suppression systems have been
satisfactorily reinstated, in accordance with Procedure 3.1, (3.1.7).
c)
SF1: System Flushing Certificate
To be used by the Commissioning/Operations Authority to denote that a
complete system has been flushed prior to leak testing (or completion of
witnessed joint as appropriate) and prior to the affected line or system
being brought into service. System flushing is to be carried out in
accordance with Procedure 3.2, (3.2.1.).
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SL1: Leak Test Certificate
To be used to acknowledge system reinstatement post flushing.
To record and formalize the leak-testing of all flanges, joints,
compression fittings or plugs in ported blanks, in piping containing, but
not limited to: Process Hydrocarbon, Diesel, Process Chemicals,
Hydraulic Fluids, Lubricant Oil Systems, Water Injection and Produced
Water Re-Injection, or any piping that the facility deems to have a ‘high
risk potential’.
All Witness Joints will be checked and "signed in" on the SL1 certificate
by the Commissioning/Operations representative.
Restriction orifice plates and flow orifice plates shall be inspected and
measured
for
size
and
confirmed
Commissioning/Operations Authority and
installed
certificates
by
the
approved
accordingly. The leak test certificate will be supported by a marked up
P&ID, clearly defining the test limits, readily identifying the system tested
and recording the test pressure, duration and detailing any exclusions or
exemptions.
Where applicable Fire & Gas reinstatement will be recorded, reference
Procedure 3.1 (3.1.7).
Vendor leak tests, Vendor Companies, Services tests will also be
recorded on this certificate.
All such piping will be subject to leak-testing and service-testing, Pre and
Post SH1 Handover. SL1 System Leak Test Certificate & JI1 (Joint
Integrity Certificate) to be raised accordingly. Refer to Procedures 3.2
(3.2.2) and 3.2 (3.2.4).
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JI1: Joint Integrity Certificate
i)
High Risk
To record and formalize the installation/making and/or remaking of
all flanges, joints, compression fittings or plugs in ported blanks, in
piping containing, but not limited to; Process Hydrocarbon, Diesel,
Process Chemicals, Hydraulic Fluids, Lubricant Oil Systems, Water
Injection and Produced Water Re-Injection, or any piping that the
facility deems to have a ‘high risk potential’. All such pipework will
be subject to Leak-testing and service-testing, Pre and Post SH1
Handover.
To record information relating to the pulling-up and tightening of
certain flanged joints on critical duties, when specified by the
Commissioning/Operations Authority. Such joints will normally be,
but will not be limited to, piping carrying hydrocarbons which cannot
be subject to a strength and/or leak-test, but will generally be
subject to Critical Joint Installation, Procedure 3.2 (3.2.3) and
Service-Test, Procedure 3.2.4.
All such joints will be checked and "signed-in" on the JI1 (Joint
Integrity
Certificate)
by
the
Commissioning/Operations
representative.
•
Part A of the Joint Integrity Certificate must be completed by the
Installation Authority.
•
Part B of the Joint Integrity Certificate must be completed by the
Commissioning Authority.
•
Part C must be completed by the Operating Authority, Post SH1
acceptance.
Note: Parts A & B must be completed prior to SH1 acceptance.
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The JI1 (Joint Integrity Certificate) records that the Post SH1 ‘StartUp’ and ‘Warm Up’ service-tests have been carried out, and that
each joint has been subject to one service-test at ‘Start-Up’ and
‘Warm-Up’ and one service-test every 12 hours thereafter, for a
period of 7 days.
Reference to Safe Isolation and Re-instatement of Plant (SIRP)
UKCS-SSW-001, is recommended.
ii)
Low Risk
For piping with low-risk potential, containing, but not limited to:
Seawater, Firewater, Plant Air, Instrument Air, Domestic Waste,
Potable Water/Towns Water and Industrial Water, may not be
subject to the Flange/Joint Tagging Procedure, but will be subject
to Inspection and/or service-testing, where appropriate, to ensure
Technical Integrity has been achieved and/or maintained.
The JI1 (Joint Integrity Certificate) will record that the Post SH1
‘Start-Up’ and ‘Warm-Up’ service-tests, where appropriate, have
been carried out.
Where low-risk piping is recorded on the JI1 (Joint Integrity Certificate),
columns that are not applicable, such as Tag Number, Joint Installed
By, Date of Installation, Leak-tested By and SL1 Leak Test Number, are
to be marked N/A.
A marked-up P&ID will be attached to the JI1 (Joint Integrity Certificate)
highlighting the service-test limit.
The JI1 (Joint Integrity Certificate) requires signatures confirming the
appropriate GOC© Procedures have been complete for high risk and
low-risk pipework, as appropriate.
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3.1.3
Calibration
a)
It is imperative for both off-site and on-site testing that methods are
established to ensure that the inspection and test equipment contained
in Figure 1 are properly controlled and calibrated.
b)
The Contractor responsible for the testing activities contained within this
Procedure shall have an established system for the control of this
equipment. It shall be the responsibility of the BP or Delegated
Authority's representative to ensure that the system is maintained.
c)
Such systems shall as a minimum address the following:
i)
Responsibility for control and maintenance of the system
inclusive of care and use of each instrument type and
performance of calibration activities;
ii)
Identification of instruments;
iii)
Calibration Procedures for each instrument type;
iv)
Frequency and accuracy of calibration;
v)
Traceability of calibration to a recognized national standard or
against a secondary or in-house standard as appropriate;
vi)
Records of instrument calibrations and system review;
vii)
Out-of-calibration Procedure addressing both instruments
overdue for calibration and those found to be inaccurate.
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TEST EQUIPMENT CALIBRATION CHART
Equipment
Calibration
Tolerance
Recommended
Associated
Method
Standard
Interval
Pressure Chart
Every 90 Days
+/- 1%
Recorders
Dead-Weight
National
Tester
Bureau of
Notes
Standards
Thermo-couples
Every 90 Days
+/- 5%
Temperature
Every 90 Days
+/- 1%
Volumeters
1 Month
+/- 1%
Pressure Gauges
Every 30 Days
+/- 1%
Dead-Weight
If Not Used
API
Tester
Every 12
Recorders
RP1110
Months
Figure 1
General Requirements:
i)
All Inspection equipment should be suitable for the purpose intended
and regularly maintained and serviced.
ii)
Details above are for guidance and may be superceded by Project
Specifications/Data Sheets.
iii)
In addition to the above the contractor shall calibrate any other
inspection, measuring or test equipment identified by BP or their
Delegated Authority.
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PAGE: 10
PIPE TESTING PROCEDURES
Procedure No. 3.1
Installation - Pressure Test Procedure
3.1.1 – Joint Integrity Installation Procedure
3.1.2 - Piping Pre-test Inspection
3.1.3 - Hydrotest Cleaning & Flushing
3.1.4 - Hydrostatic Testing
3.1.5 - Pneumatic Testing
3.1.6 - Piping Completion
3.1.7 - Piping Completion (F&G)
Procedure No. 3.2
Operability - Leak Test Procedure
3.2.1 - System Flushing Procedure
3.2.2 - Leak Test Procedure
3.2.3 - Witness Joint Procedure
3.2.4 - Service Test Procedure
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SUBJECT:
Procedure No. 3.1
3.1.1
Joint Integrity
a)
High Risk
The purpose of the Joint Integrity installation procedure is to provide a
process by which all risk-potential piping that has been installed and/or
broken during construction/maintenance activities can be identified and
recorded, so that joint integrity can be checked during leak-testing and
maintained during Post SH1 ‘Start-Up’ and ‘Warm-Up’ service-tests.
The JI1 (Joint Integrity Certificate) records that the Post SH1 ‘Start-Up’
and ‘Warm Up’ service-tests have been carried out, and that each joint
has been subject to one service-test at ‘Start-Up’ and ‘Warm-Up’ and one
service-test every 12 hours thereafter, for a period of 7 days.
Reference to Safe Isolation and Re-instatement of Plant (SIRP) UKCSSSW-001, is recommended.
The procedure detailed below shall be followed for maintenance
activities when containment is broken or in the absence of an approved
Flange/Joint Tagging procedure for construction activities during projects
or modifications.
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If the Construction Authority has a procedure that meets the
requirements and intent of this procedure then the Construction
Authority’s procedure, will be reviewed and approved for use accordingly.
i)
Each tag will have a unique identification number. A supply of
flange/joint tags shall be readily available at a number of location
on the facility, i.e. the CCR, instrument and mechanical
workshops.
ii)
All flanges, joints, compression fittings or plugs in ported blanks, in
piping containing, but not limited to; process hydrocarbons, diesel,
process chemicals, hydraulic fluids, lubrication oil systems, water
injection and produced water re-injection must be tagged when
installed or re-installed following maintenance.
iii)
Tag numbers must be marked-up on both a copy of the relevant
P&ID and the corresponding JI1 (Joint Integrity Certificate) by the
person who make or breaks the pipework joint integrity.
iv)
When the pipework is finally made up, the authorised and
competent pipe fitter/technician carrying out the task must sign
and date the appropriate box on the JI1 (Joint Integrity
Certificate).
v)
The P&ID and JI1 (Joint Integrity Certificate) will form part of the
Handover Certification Pack (HCP), to demonstrate joint integrity
and technical integrity have been achieved and/or maintained.
vi)
On completion of a successful leak-test/service-test, the SL1/JI1
(Joint Integrity Certificate)s will be signed by the competent
person carrying out the test.
vii)
In all new and/or disturbed piping where Post SH1 ‘Start-Up and
‘Warm-Up’ Service-testing is applicable, each joint will be
monitored after the equipment has been brought into or returned
to service and will be subject to one service-test at ‘Start-Up’ and
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SUBJECT:
‘Warm-Up’ and one service-test every 12 hours thereafter, for a
period of 7 days after the ‘Warm-Up’ service-test date, before the
tags are removed.
viii)
During the monitoring period, all tagged piping must be inspected
and this will be recorded on the JI1 (Joint Integrity Certificate).
When the tags are removed this shall also be recorded on the JI1
(Joint Integrity Certificate), and the tags collected and returned to
the Operating Authority.
ix)
When a number of new joints or breakages of containment are
localized, one tag may be raised to control a number of items, e.g.
within a lube oil skid, a number of instrument tapping’s around a
pump.
In these cases, the provision of leak-testing monitoring
and recording are still required and break-points should be
marked with a unique identification Number, e.g 1666A, 1666B etc
on a P&ID or other such drawing.
Low Risk
b)
For piping with low-risk potential, containing but not limited to: Seawater,
Firewater, Plant Air, Instrument Air, Domestic Waste, Potable Water ,
Towns Water and Industrial Water, may not be subject to the
Flange/Joint Tagging Procedure, or a system leak test.
Quality of work is still important on low-risk systems and, as such, will be
subject to inspection and/or service testing, where appropriate, to ensure
Technical Integrity has been achieved and/or maintained.
i)
A service-test will be required for systems where the operating
pressure is above 100 psig for water and 15 psig for air and a JI1
(Joint Integrity Certificate) will be raised accordingly. Refer to 3.1.2
Use of Forms e) Joint Integrity Certificate for full details. (Refer to
Mechanical Technical Integrity Flowchart in Section 1, Appendix
1.2)
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When the operating pressure is below 100 psig for water and 15
psig for air, then no formal testing or certification is required and
the activity shall be recorded in the Maintenance Management
System when applied to maintenance activities or on the MC1 and
SH1 when applied to projects or modifications.
(Refer to
Mechanical Technical Integrity Flowchart in Section 1, Appendix
1.2)
iii)
For Maintenance work, when plugs for instrumentation or piping in
hydrocarbon systems are broken, for example; or when sampling or
blowing-down instruments, there is no requirements to implement
the formal Joint Integrity/ Certification Process providing that:
-
The work is carried out by a competent and authorized person.
-
The original compression fittings are re-made.
-
Service-test is carried out by the technician carrying out the
work.
-
All tasks, including the service-test, are completed within one
shift.
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3.1.2
GUIDANCE ON CERTIFICATION
SECTION 3.0
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REVISION: 1
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PAGE: 15
Pre-Test Inspection
The procedure detailed below shall be followed, for each line included in
a test pack, prior to flushing and hydro-testing.
The line(s) to be tested shall be "walked" by the Construction Authority's
Representative to:
a) Check all weld inspection and NDT is completed and form MW1 is
completed.
b) Check that installed piping complies with the P&ID(s), and piping
specification(s).
c) Check that the Joint Integrity Procedure and/or Flange Check List
Register is complete.
d) Check that the flange alignment is correct and that the correct bolts
and gaskets are installed at all mechanical joints to the correct
torque setting. For joints requiring bolt tensioning, that this has been
carried out to the correct bolt tensioning procedures and results
recorded.
e) Check that all vents and drains are installed (add temporary vents
and drains for testing as required).
f) Check that the valve materials are correct - use code tagging. If tags
are removed, check nameplate.
g) Check that the rating of forged steel fittings is correct.
h) Check that branch reinforcement is correct as per isometric / design.
i) Visually check that pipe compound on screwed connections is to
specifications. (Note that the use of PTFE tape on screwed
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connections on Hydrocarbon service is NOT permitted unless
specifically stated in the installation procedure and agreed by BP).
j) Check that all pipe joints are installed correctly and to specification.
k) Check that the orientation of filters and strainers, traps, check
valves, globe valves and control valves is correct for fluid flow.
l) Check that all instrument connections are installed correctly to
specification and that any delicate in-line instrumentation has been
excluded from the test.
m) Check that the orifice valve tap orientation is correct, also that taps
and plugs have been seal welded.
n) Check that orifice flanges have required upstream and downstream
clearances, and orifice plates are removed after trial fitting.
o) Check that all instrument thermowells have been installed.
p) Ensure that all orifice plates, within the test limits, have been
checked in accordance with control procedures.
q) Check that all pipe supports are completely installed to the drawings
and schedules.
r) Check that all temporary pipe supports installed during fabrication
have been removed, except those required to support gas lines etc.,
if those lines are to be hydro-tested.
s) Check that stop limits on spring supports are in position, and that
sleeved and bellow joints are adequately restrained.
t) Check that there is no spring in the piping affecting pumps or vessel
nozzles.
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u) Check that all NDT/stress relieving requirements are to specification
and have been met and recorded.
v) Check all chain wheels and hand wheel extensions to specified
valves have been installed.
w) Check all locking devices and interlocks to valves are installed.
x) Check all pipe penetration seals have been installed.
y) Check all relief valves and bursting discs have been removed.
z) Check that where required, control valves have been removed from
the test system. If control valves are being included in a test they
may require air on the diaphragm to keep them open and other
internal trim removed. No flushing allowed through control valves
with “low noise” trim. In general, flashing through control valves shall
be avoided, if practical and if so, will require company approval.
aa) Check that the system and all line items or equipment, i.e.
exchangers, drums etc. can safely withstand the system line
specification test pressure and weight when full with test media.
Note:
Attention must be given to the differential pressure limitations across
exchanger tube plates.
i)
Vessels and heat exchangers may only be included in a system test
if the item has previously been pressure tested in accordance with
the relevant code at a pressure not less than the piping system
pressure test. Approval is required from Engineering Technical
Authority.
Check that manufacturer's and/or site test certificates endorsed by
an independent inspectorate are available on site before approving
inclusion within the test system of these items.
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Before proceeding with system flushing, any defects noted as part of
this Procedure must be corrected.
iii)
Satisfactory installation completion is to be specified by signing the
relevant section of the Piping Completion Certificate MP1.
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3.1.3
Cleaning and Flushing
a)
The Construction Authority shall ensure that the following controls are
applied for flushing:
i)
Flushing is not to be carried out through machinery or any other
equipment which may be damaged by the procedure. Control valves
and soft-seated valves should be removed during the flushing
operation, but where this is not possible the internal fittings are to be
removed. If flushing must be done through a pump, temporary
strainers must be installed. Otherwise, ensure that piping spools or
valves are dropped out and deflectors provided to prevent refuse
from entering the pump.
ii)
Orifice plates, flow nozzles, pressure relieving devices, etc. are to be
removed during flushing and testing. To avoid straining the piping
while these items are removed, temporary spacers or spool pieces
are to be installed.
iii)
These temporary fittings must conform to the specification of the
system being tested.
iv)
Precautions are to be taken to ensure that water is safely drained
away while flushing is being carried out. Deflectors should be
provided, when necessary, to prevent refuse from entering open
equipment or machinery.
b)
Prior to testing, each piping system or part system, as identified in the
test pack, is to be cleared of debris by flushing with water or blowing
with steam or air as appropriate to prove that it is clear from end to end.
All flushing-out connections are to be provided with a basket for trapping
debris.
c)
Flushing should be carried out using clean fresh water, potable water,
treated sea water, air or steam as appropriate. For systems containing
austenitic stainless steel piping and fittings the chloride ion content of
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the water shall be less than 50ppm. Carbon steel pipework flushed with
sea water should be dried immediately after flushing to prevent
corrosion.
d)
Systems open to atmosphere which do not require flushing should be
blown down to ensure that lines are not restricted.
e)
On piping systems where the flushing medium is water, flow velocities of
1.5 to 2 times the normal operating velocity or 10 - 13 feet/sec. (3-4
meters/sec.), whichever is greater, should be achieved wherever
possible.
f)
On piping systems where the flushing medium is air (oil free and dry) or
steam, the flow velocity should not be less than 65 feet/sec. (20
meters/sec.). Records of flushing should be maintained by color
marking of P&ID's to define the system flushing circuits, direction of
flow, scope, equipment isolation and prime mover used.
g)
Flushing/blowing is to be carried out until the required cleanliness of the
system is attained, after which Certificate MP1 will be signed in the
appropriate box.
h)
Ensure any in-line service strainers are removed prior to flushing and
that they are replaced after the flushing operation has been accepted as
complete.
Additional pre-test requirements from Asset specific and/or design
house/engineering support and/or BP specifications and/or International
Standards such ASME B31.3 (345) may have to be considered and
referenced over and above the requirements detailed above.
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3.1.4
Hydrostatic Testing
a)
After flushing is satisfactorily completed, pressure testing may proceed.
b)
Testing must be carried out in accordance with the requirements
specified on line test and piping line specification or otherwise must take
into account the duty of the system, namely the process fluid and the
operating pressures and temperatures.
Note:
i)
All in-line valves shall be in the fully open position during the
pressure test.
Pressure tests shall not be made against closed
block valves; Blinds shall be used with valves in the open position.
Non Return Valves shall have either the disc removed or the jacket
open for flushing and pressure testing.
ii)
Some in-line valves, notably, ball valves, must be tested with the
valve in the half open position to ensure the seals are not exposed
excessive differential pressure and to allow the valve stem and body
to be pressured tested.
iii)
c)
The Construction Authority's representative shall ensure that
hydrostatic test requirements shown on isometric, P&ID, Line List
and general arrangement drawings are compatible with the
applicable codes and specifications.
It should be noted that the design of piping systems for BP is generally
based on the requirements of the ASME B31.3 chemical plant and
petroleum refinery piping, which details the parameters for hydrostatic
testing, as 1.5 x MAWP (Maximum Allowable Working Pressure), with
variations to be considered as detailed in ASME B31.3 (345.4.2).
d)
The testing medium may be clean fresh water, potable water, 60/40%
water/glycol treated inhibited sea water, oils, air or inert gases. Typically
hydraulic oil and instrument air systems should only be tested using the
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specified operating medium.
For austenitic stainless steel piping the
chloride ion content of the water shall not be more than 50 ppm.
e)
Prior to filling a system with fluid, it may be prudent to carry out a low
pressure air test under controlled conditions to ensure that there are no
major leakages present. ASME B31.3 (345.2.1) limits the preliminary test
pressure to 25 psig.
f)
Calibrated test gauges of suitable pressure indication range are to be
installed at high/low/entry locations with individual isolation valves in the
open position. The gauge at the highest point shall indicate the required
test pressure. Pressure, temperature, recorders, and dead weights should
be used on all hydrostatic tests for ASME B31.3, B31.4, B31.8 and API
1104 piping systems.
g)
All test gauges are to be given an individual reference number, calibrated
on a regular basis and a calibration record maintained.
h)
All vents and other high point connections which can serve as vents shall
be open during filling so that all air is vented prior to pressurization.
i)
Piping designed for vapor or gas shall be provided with additional
temporary support, where necessary, to support the weight of the test
liquid.
j)
When the test system is filled with the testing medium and the
Construction Authority's representative is satisfied that air pockets have
been removed, the pressure shall be gradually increased to the required
test pressure as specified on the relevant line schedules.
k)
When pressurizing any test system continuous attendance and supervision
must be maintained at the test pump. At all times during the test the
pressure gauges should be monitored. Hydrostatic head on the gauge
shall be taken into account, depending on the location of the gauge.
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SUBJECT:
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GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 23
On achieving the required test pressure, the test pump shall be
disconnected physically from the test system. Piping and equipment
subjected to the test shall be held at the test pressure for at least 30
minutes before a detailed inspection is started.
m)
The system under test shall then be visually inspected over its entire
length by the Construction Authority's representative and each mechanical,
welded joint, attachment etc. checked. The duration of the test shall be a
minimum of 30 minutes, or the time taken to inspect the system under test,
whichever is greater.
n)
Due attention must be paid to the effects of high/low ambient temperatures
occurring during the test. The temperature of material under test must be
safely above that at which brittle fracture may be initiated.
o)
If program requirements render it necessary to conduct testing during
periods of ambient temperatures below or likely to be below 35°F (5°C),
prior approval from BP or their Delegated Authority must be obtained for
use of anti-freeze solution, or alternative testing media such as gas oil or
Kerosene. Any flammable liquids used for testing should have a flash
point above 149°F (65°C). Attention is drawn to the danger of brittle
fracture occurring in carbon and low alloy steels below 60°F (15.5°C)
unless the materials have adequate notch toughness. Prior to granting
approval the BP or their Delegated Authorities' Specialist Vessel and
Piping Engineer should be consulted regarding the pressurizing of systems
and vessels at temperatures below 32°F (0°C). A separate test Procedure
outlining storage and recovery facilities for the alternative test medium will
require approval from BP or their Delegated Authority.
p)
If visual inspection over the entire length of the test system is not possible
i.e. in partially buried or underground sections, then a 24 hour holding test
shall be applied.
Test gauges for this type of operation shall be of the dead weight chart
recorder type producing both pressure and simultaneous temperature
records over the 24-hour test period.
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MECHANICAL- PIPE TESTING
PAGE: 24
This type of holding test is to be avoided whenever possible and
preference should always be given to inspect the system visually as
defined in l) above.
q)
If leaks are discovered, the necessary repairs or replacements shall be
made until items being tested pass the test, and that the Construction
Authority has been notified that the items being tested have passed the
test.
r)
After satisfactory completion of the pressure test the Construction
Authority's representative shall witness the gradual release of pressure
and drain down. Test systems shall be de-pressurised by opening the depressurising valve in the test rig and drained by opening all vents and low
point drain valves; adequate venting should be effected to avoid vacuum
conditions occurring.
s)
All drained lines should be dried by purging with dry, oil free air.
t)
Pipeline pigging and gauging must be carried out in accordance with the
applicable BP specification. Construction Authority’s representative shall
verify pipeline dewatering and inspect and approve gauge plate condition.
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SUBJECT:
3.1.5
a)
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 25
Pneumatic Testing
The following Procedure shall be followed for pneumatic testing, which
may only be carried out if specified.
Pneumatic testing may only be carried out when agreed in writing with:
On-site - The Operator
Off-site - BP or their delegated Authority
Pneumatic Testing using pressures > 100psi should be avoided.
b)
The Construction Authority's representative shall be in charge of all
activities associated with Pneumatic Testing.
c)
Testing should not be carried out at ambient temperatures below 60°F
(15.5°C). If it is required to perform tests at ambient temperatures below
60°F (15.5°C), prior agreement shall be sought from BP or their Delegated
Authority.
d)
The air for purging and testing shall be clean, dry and oil free.
e)
Access to pneumatic test areas shall be restricted solely to those persons
required to conduct the test. Barriers shall be installed to prevent access
to others.
f)
Test pressures will be 1.1 x MAWP (Maximum Allowable Working
Pressure).
g)
Butt welds shall be 100% radiographed and all socket welds to be "NDE'd"
before commencing pneumatic testing.
h)
A preliminary check shall be made at not more than 10 psig (0.70 bar
gauge) pressure.
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MECHANICAL- PIPE TESTING
PAGE: 26
The system shall be gradually pressurized to 60% of the indicated test
pressure, and held at the pressure for a sufficient length of time to allow
the piping to equalize strains, but not less than ten (10) minutes.
j)
The pressure shall then be reduced to 50% of the indicated test pressure
and all joints re-tested for leaks.
k)
The pressure shall be raised in steps of not more than 10%, until the
required test pressure has been reached. The pressure shall be held at
each step during the pressurizing sequence (to allow the piping to equalise
strains) for a period of not less than ten (10) minutes. The required test
pressure shall be held for sufficient length of time to permit the testing of
all joints, but under no circumstances shall this period be less than thirty
(30) minutes.
l)
When the system has been brought up to test pressure, leak test solution
shall be applied completely around all connections and welded joints in
order to detect any leaks.
m)
Flanged joints shall be completely taped and small holes punched at the
top or side to detect leaks.
n)
If leaks are discovered, the system shall be de-pressurised and the leaks
repaired.
o)
The test solution (soapsuds) shall consist of a simple mixture of liquid
detergent and water and shall be prepared not more than 24 hours in
advance of the test. Throughout the test period, the bubble formation
properties of the solution shall be checked.
p)
While the system is under test pressure, the test equipment shall be
isolated from the system.
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SUBJECT:
3.1.6
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 27
Piping Completion
On each line the following checks are to be carried out by the Construction
Authority's representative, to ensure satisfactory re-instatement of the piping
under test:
a)
Check that the Construction Joint Integrity and/or Flange Check List
Register is complete, where applicable, and that all piping has been
installed/re-instated and flushing and hydrostatic testing has been
satisfactorily completed and recorded.
b)
Check that the flange alignment is correct and that the correct bolts and
gaskets are installed at all mechanical joints to the correct torque setting
and that the bolts have been lubricated.
For joints requiring bolt
tensioning, that this has been carried out to the correct Bolt Tensioning
Procedure and the results recorded accordingly.
c)
Check that the compound on screwed connections is to specification.
(Note that the use of PTFE tape on screwed connections on Hydrocarbon
service is NOT permitted unless specifically stated in the installation
procedure and agreed by BP).
d)
Check that all vents and drains are correctly installed with plugs or blind
flanges.
e)
Check that all temporary vents and drains have been seal welded where
applicable.
f)
Check that all process blinds and spacers have been correctly installed as
indicated on the P&ID.
g)
Check that all the spectacle blinds are in the correct (open or closed)
position.
h)
Check that all pipe cleaning and pickling has been satisfactorily
completed and recorded.
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REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 28
i)
Check that all control valves have been installed in the correct flow
direction.
j)
Check that the specified block valves have their locking devices correctly
installed.
k)
Check that all valves are functioning properly and that they are correctly
lubricated and installed in the correct flow direction.
l)
Check that all temporary pipe spools have been removed and all control
valves and internals have been re-instated in the correct flow position.
m)
Check that all Non Return Valve internals have been re-instated, and the
valve has been installed in the correct flow direction, and any ‘jack open’
devices have been removed. Ensure the valve is functioning properly and
that the spindles are lubricated.
n)
Check that all relief valves and rupture (bursting) discs have been
correctly installed.
o)
Check that all gauges have been correctly installed.
p)
Check that all pump suction strainers have been correctly installed or
temporary test strainers removed.
q)
Check that all chain wheels and hand wheel extensions to specified
valves have been installed.
r)
Check that all locking devices and interlocks to valves are installed.
s)
Check that all pipes, including supports, have been installed as per
design.
t)
Identify all piping that requires vibration tests when operational and record
on the MP1 and on the Handover Punch List as outstanding
Commissioning/Operations Item.
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SUBJECT:
u)
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 29
Upon completion of the above and where appropriate, the Joint Integrity
Procedure and/or or Flange Check List Register and conformation that all
the appropriate joints have been tagged and the relevant tag I.D. is
detailed on the appropriate drawings, the Construction Authority's
representative and the Contractors authorized Representative, shall sign
form MP1 Piping Completion Certificate
v)
Verify that all test blinds and filling liners are rated equal to or greater than
that of the line class to be tested.
w)
Check that all flow meters have been installed in the correct flow direction.
x)
Check that orifice plates on flow meter runs are correctly installed.
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SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 30
3.1.7
Fire and Gas Piping Completion
a)
For piping associated with the fire water mains, sprinkler and deluge
systems, the following checks are to be carried out to ensure the return
of piping under test to a state of mechanical completion.
b)
Check that all sprinkler heads, sprinkler rosettes and sprinkler nozzles
have been correctly installed.
c)
Check that all hose couplings have been correctly installed.
d)
Check that all discharge heads on (non-Halon) fire suppression systems
have been correctly installed.
e)
Confirm with Mechanical Group that:
i) All fire hydrants/monitors have been correctly installed.
ii) All foam monitors have been correctly installed.
iii) All fire suppression (non-Halon) cylinder locations and fixings are
correctly installed.
Note: The use of Halon as a fire suppressant is being phased out by BP to
comply with the Environmental Protection Regulations 1996 S.I. 506
Form MP1 shall be completed upon completion of this Procedure.
Note: Painting, insulation and trace heating have not been included on
the piping Procedures 3.1 & 3.2, as they will be covered by
Certifications raised by other disciplines.
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BP Exploration 1989 - 2001 All Rights Reserved
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SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 31
SUBJECT:
3.1.8
Certification
a)
The Construction Authority's representative who executed the system
test shall sign the piping completion certificate Form MP1. Pressure,
temperature, and time recorder charts shall be attached to Form MP1.
b)
The Construction Authority's representative shall ensure that the
Construction Documentation Packages are progressively compiled and
that pressure test certificates and associated documents fully define the
results, the scope of test, isolated equipment, and date executed.
c)
On completion of test, the system shall be reinstated in accordance with
requirements and the appropriate section of the piping completion
certificate MP1.
d)
The Construction Authority’s representative shall ensure, where
applicable, that the Joint Integrity Procedure and/or or Flange Check
List Register is complete and that all the appropriate joints have been
duly tagged and the relevant tag I.D. is detailed on the appropriate
drawings.
The flange/joint tags will remain in place until all Post Start-Up Integrity
checks (service-tests) are carried out and the completion and
acceptance of the JI1 (Joint Integrity Certificate) by Operations.
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SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 32
Procedure No. 3.2
3.2.1
System Flushing
a)
The purpose of flushing is to ensure that systems to be handed over are
clean and free from debris which may damage system equipment.
b)
Flushing Guidelines
The system should be assessed and best flushing medium (air, water or
a combination of both) selected taking into consideration safety,
efficiency and convenience.
c)
System/lines to be flushed are to be checked against P & ID's to identify
items that require removal prior to flushing.
d)
Flushing must not be via: Orifice Plates, Non-Return Valves, filters,
machinery, vessels, control valves or speciality items (Thermowells,
sampling/chemical injection quills, corrosion coupons, etc.).
e)
Where specialty items/fittings etc. are removed, they are to be wrapped
in protective material and securely tied to their location with a
commissioning label attached.
f)
If removal of equipment necessitates spool pieces to be inserted, the
spool pieces must be of the same internal diameter as the piping.
g)
When flushing systems fitted with wafer type check valves, every effort
should be made to remove these valves. If this is not possible the
internal flap is to be removed (not tied back). On re-instatement the
internals of the valves are to be checked for cleanliness/damage.
h)
Battery limits/off takes are to be isolated by blinding or locked closed
valves with hazardous signs posted.
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i)
GUIDANCE ON CERTIFICATION
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GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 33
All temporary blinds, spectacle blinds or orifice plates installed, turned or
removed must be entered in the respective registers.
j)
Flushing of interconnecting piping should be in the direction of fall (high
to low point) and from smaller piping into larger piping ensuring no
debris is left trapped in dead legs.
k)
Flush rates must be high enough to remove heavy debris.
l)
The flush should be to an open end if possible. In the event of a flexible
hose/pipe being required to route the medium away it should be of, at
least, the same diameter or larger.
m)
The area of flush discharge should be cordoned off and hazardous
signs posted.
n)
Where pipe sections/systems are sufficiently small and pipe diameters
sufficiently large enough to allow visual inspection, then this can replace
the requirement to flush.
o)
A combination of flushing and visual inspection can be accepted, and
will be indicated on the SF1 certificate.
p)
On reinstatement, the system must be checked against P&ID's, the
blinding/orifice register and the master P&ID's updated.
q)
The certificate SF1 shall be signed on completion of this Procedure.
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BP Exploration 1989 - 2001 All Rights Reserved
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GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 34
SUBJECT:
3.2.2
Leak Testing
a)
The purpose of the leak test is to ensure the integrity of the system prior
to handover.
b)
Safe System of Work
i) A safe system of work will form part of the commissioning Procedure
and be in place before the start of testing. This will ensure that after
completion of pressure/leak testing, the pressure inside the system is
reduced to atmospheric level, or as justified by a risk assessment, to
an appropriate safe level before any work starts on that system.
ii) The safe system of work to include the verification by the performing
authority that on every occasion the system has safe working
conditions, before work commences.
iii) The valve on the pneumatic (e.g. nitrogen) supply line to the system
should be locked in the closed position and blinded off when work is
to be carried out on the system to which it is connected.
Disconnection of the line to the system is preferred. This action
should be a prerequisite of the permit to work. It should be signed as
completed prior to the issue of the start of work on the system.
iv) During any pneumatic test, if the test pressure is above the MAWP, or
the pressuring source could exceed MAWP, a pressure relief valve shall
be fitted to the test equipment, set to relieve marginally above the test
pressure, and of adequate discharge capacity to relieve the volume
supplied by the pressuring source to a safe area.
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SUBJECT:
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REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 35
Note! ASME B31.3, Process Piping, paragraph 345.5.2, titled “Pressure Relief
Device” states: “A pressure relief device shall be provided, having a set
pressure not higher than the test pressure plus the lesser of 50 psi (3.5 bar) or
10% of the test pressure.”
v)
The Performing Authority will ensure adequate training of all
personnel involved in leak testing and provide test personnel with
approved written Procedures.
Note! Clamps or bolts on bolted flanges must not be loosened while the
system is under pressure. When required the system should be isolated
from pressure sources, depressurised and vented. The clamps should then
be removed strictly in accordance with the manufacturer’s Procedures.
Clamps should only be removed by competent persons who have been
trained in manufacturers assembly/disassembly Procedures.
It is important that items b) to p) are checked for completeness prior to leak
testing.
c)
All outstanding items on punch list that would affect integrity of leak test
have been cleared.
d)
Limits as defined in Commissioning Procedure are set on plant.
e)
All adjoining systems have been isolated by blindings or vented to
prevent any pressure build up.
f)
All valves have been checked for freedom of movement.
g)
All valves internal to system are open.
h)
Instrumentation has been installed and is opened up to the leak test.
i)
Atmospheric vents/drains have been valve isolated or blanked.
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SUBJECT:
j)
GUIDANCE ON CERTIFICATION
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REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 36
Insulation/cladding or blankets has been removed from flanges, valves,
etc.
k)
All test equipment and system pressure limiting devices, such as
pressure relief valves, should be set to the correct pressure. Sufficient
pressure monitoring to avoid test pressure remaining undetected behind
check valves and similar equipment should be incorporated.
l)
A fully operational newly calibrated PI of a suitable range should be
fitted at or near each venting position, injection positions and whenever
possible near to the places where work is to be carried out Pressure
readings should be recorded as detailed in Procedure 8.3, Section 3.1.6.
m)
Pressuring point has been selected to ensure that the entire system is
pressured. (Do not attempt to back flow through non-return valve; i.e.,
check valves).
n)
Ensure area-surrounding system under test is suitably cordoned off, and
designated a “Keep Out Area” by erecting warning signs and barriers.
Note! Only personnel essential for the operation of test equipment are to
be allowed in the test area during pressurization and de-pressurization.
o)
Where appropriate, make a radio or P.A. announcement that a "Leak
Test" is ongoing in the area. Testing should not start until all nonessential personnel are in a safe area.
p)
Under no circumstances shall the system under test be left unattended
once the system is pressurized.
r)
As with any "Pressure" test, the system shall be pressured slowly, and in
stages, the pressure of the system to be recorded at the various stages.
The system is now ready for leak testing.
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SUBJECT:
s)
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 37
Piping 'Under Test'
i)
Leak Testing is performed at 110% of Maximum Allowable Working
Pressure (MAWP) or, if a relief valve which has a set pressure below
110% MAWP is included in the system under test, the test is
conducted at 95% of the system relief valve set pressure. A leak test
(hydraulic where practicable) is performed to prove the pressure
tightness (i.e. fitness for service) of joints, seals and glands, etc.
each time the integrity of containment systems is broken, either at
hook-up/commissioning or post operations phase. The prevention of
even minor leaks is particularly important where flammable or toxic
fluids are concerned.
ii)
Pneumatic Leak Tests using an inert gas are used extensively on
piping systems which are predominantly gas producing and some offsite sites both during commissioning and post operation phases,
prior to the introduction of hydrocarbons. The accepted norm for
these tests is to pressurize, using 99% nitrogen with a 1% helium
tracer gas, up to a maximum of 110% MAWP. A specialist leak test
contractor is normally employed for such tests. A typical target
leakage rate of 20 scf/annum up to a maximum of 80 scf/annum,
measured by means of equipment sensitive to the tracer gas, or by
sonic or ultrasonic detector devices, should be used as the
acceptable leakage range.
Note! Pneumatic leak testing should not be carried out before the
integrity of the equipment has been confirmed by a standard pressure
test.
iii)
There should be sufficient venting positions to prevent fluid being
trapped behind non-return check valves in dead legs or between
isolation valves. Instruction will be required on how the system can
be safely tested and vented in discrete sections. If this is the
intended method of testing then all piping should be adequately
marked so that each test can be identified. Where the section under
test terminates at a valve, an assessment should be carried out to
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MECHANICAL- PIPE TESTING
PAGE: 38
SUBJECT:
determine if a block & bleed or blind arrangement should be used to
prevent a build up of pressure inside an adjacent section.
iv)
Gross (Preliminary) Air Leak Tests, using instrument air up to a
maximum of 100 psig (8 barg), are often used at an early stage of
hook-up/commissioning as a means of identifying large leaks, prior to
performing the standard pressure tests.
Note: ASME B31.3 paragraph 345.1.2 (c) recommends that no more
than 25 psig air test shall be made prior to a hydrostatic test to locate
major leaks.
v)
Service Leak Tests, using the service fluid rather than 110% MAWP
tests, are acceptable methods of testing for leaks during the post
operations phase on low pressure systems such as instrument air,
potable water and diesel distribution systems. (Category D fluid
service).
vi)
Raise, check and record pressure in increments (check flanges,
valve glands, etc.), for leaks at each stage.
vii)
In water filled systems, it is important to ensure all air is vented and
system is completely water filled.
viii)
Hold the final test pressure for at least 30 minutes with no visible
leaks to atmosphere before a detailed inspection is started.
(Use soapy water to bubble check for AIR/N2 TESTS).
ix)
Pressures should always be checked and recorded the following:
• Completion of Test
• Isolation from the pressure source
• When de pressurization/venting has taken place
The above should always be done immediately prior to the start of
any further work on the system.
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REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 39
SUBJECT:
t)
Test Medium
Select test medium from:
•
Air
•
Potable Water
• WI Water
• N2
•
N2/Helium
Test pressure as specified in the Commissioning Procedure.
Note! Consideration should be given to ensure that during Nitrogen
injection and bleeding the temperature does not fall to a level where a
loss of structural integrity could occur in the test piece.
u)
Post Test Requirements
On completion of Tests the following action is to be taken:
• Slowly de-pressure the system.
•
•
•
•
•
•
Make a radio or P.A. announcement that Leak Testing is complete.
Remove
the
pressuring
connection,
remembering
to
include/indicate joints on connection, vents, etc., that will become
witness joints and require inclusion in the certification (Service
test), if applicable.
Remove barriers and warning signs.
Return the work permit.
Mark up a relevant P&ID indicating the system limits and complete
the SL1 certificate, refer to 3.2.2.
Ensure JI1 certificate is available for post test integrity service
tests.
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BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
3.2.3
a)
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 40
Critical Joint Installation
The following Procedure, in conjunction with the Joint Integrity Procedure 3.1
(3.1.1), shall be followed for the preparation, pulling up and tightening of certain
flanged
joints
on
critical
duties,
when
specified
by
the
Commissioning/Operations Authority. Such joints will normally be, but will not
be limited to, pipe carrying hydrocarbons which will not be subject to a pressure
and/or leak test.
b)
Advise Commissioning/Operations Authority prior to joint(s) installation to
enable assessment for requirement to witness joint installation.
c)
Flange faces to be examined and visually inspected to ensure they are clean
and damage free.
d)
Gasket to be examined and visually inspected to ensure it is new, damage free,
and of correct specification and size.
e)
Nuts and stud bolts to be examined and visually inspected to be damage free
and of correct specification (material) and size.
f)
Check flange faces are parallel and alignment is in accordance with
specification.
g)
Check that joint is progressively tensioned evenly using a "criss-cross" bolt
tightening sequence as required in the BP specification.
h)
All nuts to be pulled up to the required torque tightness, a minimum of one
thread should be seen protruding through each nut, no excessive length of
stud bolt should protrude through each nut.
i)
Check that there is no visible damage to the gasket when joint is compressed.
j)
Mark up a relevant P&ID indicating the appropriate joint(s) and complete the
relevant section of the JI1 (Joint Integrity Certificate), refer to 3.1.2. Use of
Forms e) Joint Integrity Certificate.
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SUBJECT:
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REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 41
3.2.4 Service Testing Procedure
a)
The "Service Test" is required in conjunction with the critical joint
installation Procedure and Joint Integrity Procedure, on high risk piping or
when it would be impracticable to leak test the system on completion of
workscope. The service test will utilize the process fluid to test the piping
for leaks.
b)
After all stages of the critical joint(s) installation and the Joint Integrity
Procedure 3.1 (3.1.1) have been completed, and ensuring all outstanding
items on Punch List that would affect system integrity have been cleared.
c)
Joints that have been split are closely scrutinised for leaks (i.e. fluid
leakage, soapy bubble in gas systems and gas detection for hydrocarbons)
during early stages of pressurization.
d)
Observe all joints that are under scrutiny for leaks until desired pressure
(i.e. normal operating pressure) is achieved.
e)
The relevant parts of the JI1 (Joint Integrity Certificate) should be signed
off on completion, refer to 3.1.2 Use of Forms e) Joint Integrity Certificate
for full details.
f)
When a service-test in lieu of a Leak Test is carried out a waiver or
concession has been granted, by the Approving Authority and/or the
Operating Authority. As a result of the wavier/concession a SL1 System
Leak Test Certificate will not be raised. The JI1 (Joint Integrity Certificate)
will detail in the ‘Leak-tested by’ and ‘SL1 Leak Test Number’ boxes that a
waiver/concession has been given, by entering the Engineering Query
(EQ) or Operating Query (OQ) or Technical Query (TQ) identification
number in these boxes.
NOTE: A critical joint installation will ALWAYS be
followed by a Service Test.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
g)
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 42
Service-test on piping with low-risk potential, containing, but not limited to:
Seawater, Firewater, Plant Air, Instrument Air, Domestic Waste, Potable
Water/Towns Water and Industrial Water, will not be subject to the
Flange/Joint Tagging Procedure, or a system Leak Test.
Quality of work is still important on low-risk systems and as such will be
subject to inspection and/or service testing, where appropriate, to ensure
Technical Integrity has been achieved and/or maintained.
A service test will be required for systems where the operating pressure is
above 100 psig for water and 15 psig for air and a JI1 (Joint Integrity
Certificate)s will be raised accordingly.
Refer to Use of Forms e) Joint
Integrity Certificate for full details of the intent of the JI1 (Joint Integrity
Certificate). (Refer to Mechanical Technical Integrity Flowchart in Section
1, Appendix 1.2)
Where the operating pressure is below 100 psi for water and 15 psi for air
then no formal testing or certification is required and the activity will be
recorded in the Maintenance Management System when applied to
maintenance activities or on the MC1 and SH1 when applied to Projects or
Modifications. (Refer to Mechanical Technical Integrity Flowchart in
Section 1, Appendix 1.2)
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 43
SUBJECT:
3.2.5
Certification
a)
Complete the SL1 or JI1 certificates including the following information:
(Wherever applicable)
i)
ii)
MC1/SH1 numbers
All line numbers
iii)
Vessel numbers
iv)
v)
Tie-in numbers
Valve numbers at test limits
vi)
Test medium
vii)
viii)
Test pressure
Test duration
b)
ix)
Service test pressure
x)
xi)
xii)
Exclusions or exemptions
Commissioning or completing assignee signature
Operations or testing approval signature
Attach a B size copy of the relevant P&ID's to the SL1 and/or JI1 with
the system leak test/witness joints/service test limits highlighted and
clearly identified.
c)
For N2/Helium testing the contractors certificate is to be attached to the
SL1.
d)
The original SL1 and the marked up P&ID's are to be passed to the
Certification Engineer or the Delegated Authority nominated by BP.
e)
Mark up the master System P&ID.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 44
FLOWCHART 3
•
•
Functional Certification Flowchart
Discipline: Mechanical (Piping)
MP1
MC1
MP1:
MC1:
SF1:
SL1:
SH1:
JI1:
SF1
SL1
SL1
SH1
JI1
Piping Completion Certificate
Mechanical Completion Certificate
System Flushing Certificate
Leak Test Certificate
System Handover Certificate
Joint Integrity Certificate
Note! Where Welding is carried out an MW1 - Welding Completion
©
Summary is required - Refer to GOC Section 2
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 3.0
GOC © AMERICAS EDITION
REVISION: 1
MECHANICAL- PIPE TESTING
PAGE: 45
EXHIBIT 3
STANDARD FORMS
Form No.
Form Title
MP1
Piping Completion Certificate
SF1
System Flushing Certificate
SL1
JI1
Leak Test Certificate
Joint Integrity Certificate
DIS1
Data Input Sheet 1 – Section 3 Pipe Testing
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
PIPING COMPLETION
CERTIFICATE
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM MP1
Test Pack No:
SHT
SITE:
LOCATION:
OF
P & ID No:
SCOPE OF TEST:
TEST PACK LIMIT FLUSHED PRIOR TO STRENGTH TEST?
MW1 Complete
Welding & NDE
Pro 3.1.1 Complete
Joint Integrity
Pro 3.1.2 Complete
Pre-Test Inspection
Pro 3.1.3 Complete
Cleaning & Flushing
YES/NO*
SIGNATURE:
YES/NO*
SIGNATURE:
YES/NO*
SIGNATURE:
YES/NO*
SIGNATURE:
OPERATING PRESSURE
PSIG
STRESS RELIEVED*
YES/NO*
N.D.E. MEDIUM: *
M.P.I* / D.P.*
TEST PRESSURE
PSIG
YES/NO *
FLUSHING MEDIUM:
Pro 3.1.4 Complete
Hydrostatic Testing
Pro 3.1.5 Complete
Pneumatic Testing
Pro 3.1.6 Complete
Piping Completion
Pro 3.1.7 Complete
Piping Completion (F&G)
OPERATING TEMP
INTERNAL LINING*
100%* / 10%*
ISO No
SIGNATURE:
YES/NO*
SIGNATURE:
YES/NO*
SIGNATURE:
YES/NO*
SIGNATURE:
DEG F
YES/NO*
U.T* / RAD*
TEST MEDIUM:
YES/NO*
FLOW MEDIUM:
EXTERNAL FINISH*
100%* / 10%*
NDE ACCEPT.
TEST DURATION:
LINE No
VIBRATION
TEST REQ
PAINT*
WRAP*
YES/NO*
INSULATE*
LINE SPEC:
TEST DATE:
EQUIPMENT NUMBER
(FROM)
(TO)
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
ALL LINES REQUIRING VIBRATION TESTS MUST BE DETAILED ON THE HANDOVER PUNCH LIST
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas Rev. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
SYSTEM FLUSHING CERTIFICATE
FORM SF1
SITE:
SHT
OF
TITLE:
Procedure 3.1.3 Complete
Cleaning & Flushing
FLUSH MEDIUM
√ FLUSH
* YES/NO/NA
√ VISUAL
Signature:
P&ID DRAWING & LINE No(s)
SIGN
DATE
REMARKS:
√ CHECK AS APPROPRIATE
SYSTEM WALKED AND CHECKED AGAINST P&ID(s) AND INTEGRITY CHECK COMPLETE
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas Rev. 1
***NOTE ! ONE (1) SF1 TO BE RAISED PER HANDOVER CERTIFICATION PACK (HCP) ***
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM SL1
SITE:
LEAK TEST CERTIFICATE
SHT
LOCATION:
SL1 REF:
SCOPE OF TEST:
SYSTEM:
FLUSH MEDIUM:
Pro. 3.1.1 Complete
Joint Integrity
Pro. 3.1.6 Complete
Piping Completion
Pro. 3.2.1 Complete
System Flushing
OF
JI1 REF:
FLUSH DETAILS COLUMN: MARK ‘F’ FOR LINE FLUSHED OR ‘V’ IF VISUAL ONLY
* YES/NO/NA
SIGNATURE:
* YES/NO/NA
SIGNATURE:
* YES/NO/NA
SIGNATURE:
Pro.3.2.2 Complete
Leak Test
Pro.3.2.3 Complete
Witness Joint
Complete
Reinstatement
OPERATING PRESSURE:
PSIG
OPERATING TEMP:
TEST PRESSURE:
PSIG
TEST DURATION:
P & ID No
LINE No
DEG F
* YES/NO/NA
SIGNATURE:
* YES/NO/NA
SIGNATURE:
* YES/NO/NA
SIGNATURE:
FLOW MEDIUM:
TEST MEDIUM:
FLUSH
DETAILS
VIBRATION
TEST REQ
EQUIPMENT NUMBER
(FROM)
(TO)
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
* YES/NO
REMARKS
ALL LINES REQUIRING VIBRATION TESTS MUST BE DETAILED ON THE HANDOVER PUNCH LIST
PIPING INSTALLATION IN ACCORDANCE WITH RELEVANT CONTRACT SPECIFICATIONS, AND GOC SECTION 3 - PIPE TESTING.
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas Rev. 1
Procedure 3.1.1 Complete
Joint Integrity
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
JOINT INTEGRITY CERTIFICATE
* YES/NO/NA
SIGN:
Procedure 3.1.3 Complete
Cleaning & Flushing
* YES/NO
SIGN:
Procedure 3.1.6 Complete
Piping Completion
* YES/NO
SIGN:
Procedure 3.2.3 Complete
Witness Joint
* YES/NO/NA
SIGN:
Procedure 3.2.4 Complete
Service Test
* YES/NO
SIGN:
LOCATION :
Tag
Number
FORM JI1
SITE:
SHT
of
SYSTEM :
Part A
Part B
Part C
Installation Phase
Commissioning Phase
Operational Phase
Location
(P&ID and Description)
Joint
Installed
by
Date of
Installation
Leak
Tested by
Parts A & B
To be completed before the SH1 can be signed and the equipment safely operated
COMPLETED BY
APPROVED BY
SL1 Leak
Test
Number
Service
Test after
start up
Service
Test after
warm up
Service
Test
Period
Service
Test
Period
Service
Test
Period
Service
Test
Period
Tag
Removal
Date
Complete Post SH1 acceptance - the equipment can be operated safely without
jeopardizing plant, personnel or the environment
REMARKS:
COMPANY
SIGNATURE
PRINT NAME
DATE
* DELETE AS APPLICABLE
GOC ©
BP Exploration 1989 - 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas Rev. 1
JOINT INTEGRITY CERTIFICATE
Form JI1 SHT
of
Part A
Tag
Number
Location
(P&ID and Description)
* DELETE AS APPLICABLE
Part B
Joint
Installed
by
Date of
Installation
GOC ©
Leak
Tested by
SL1 Leak
Test
Number
Part C
Service
Test after
start up
Service
Test after
warm up
BP Exploration 1989 - 2001 All Rights Reserved
DOUBLE SIDED FORM
Service
Test
Period
Service
Test
Period
Service
Test
Period
Service
Test
Period
Tag
Removal
Date
Americas Rev. 1
JI1 Certificate How To…….
Box 1 to 5:
To be completed by Certification Administrator, this will contain Project Title
workpack information and the SH1 No.
Box 6:
Will have the flange tag number inserted by the person who makes up or breaks
the joint and tags the flange. This person will also mark up the P&ID that
accompanies the certificate.
Box 7:
Detailed location of the flange.
Box 8:
Initialed by the person installing the joint (only personnel who are on the joint
installation register can sign here).
Box 9:
Date of joint installation.
Box 10:
To be initialed by the person carrying out the leak test on completion.
Box 11:
Leak test number, this information will be taken from the SL1 Certificate on
equipment that requires more than one leak test.
Box 12:
Service Test after start up to be carried out on all tagged joints.
Box 13 to 17: Are checks to be carried out over the next 7 days as detailed on Procedure 3.1.1.
Joint Integrity Installation Procedure.
Box 18:
The tag removal date.
Box 19:
To be completed by the person removing the tag and confirming the integrity of
the joint.
Box 20:
To be signed by the operating authority.
Notes
Boxes 6 to 9 are Part A items and must be completed by the Installation Authority for piping
with High risk potential. For Low risk potential joints refer to Procedure 3.1.1. Joint Integrity
Installation Procedure.
If a joint is broken on more than one occasion then a line is put through boxes 6, 7 and 8 and a
new entry is put on the certificate using the original tag number. This will reduce confusion on
the accompanying marked up P&ID.
Boxes 10 and 11 are Part B items and the SH1 cannot be completed until they are all signed
up. There will be circumstances where boxes 10 & 11 are not covered by a leak test, in these
occasions NA will be entered.
Boxes 12 to 18 are Part C items and will be completed after the SH1 has been signed and the
equipment returned to service.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas Rev 1
DIS1 SHEET
LOCATION : __________________
DATA INPUT SHEET 01
PROJECT : __________________
SECTION 3 - PIPE TESTING
JP
NO.
HANDOVER ID
RAISED BY:
TEST PACK No
P&ID No
__________________________________
NOTE: JP No FOR HYDROTESTING
LINE No
DATE:
ISO No
______________
GOC
ASBUILT
REQ'D
(LAD)
OF
WORKSCOPE ID : ____________________
MAINTENANCE ID No : ____________________
TEST
PRESSURE
(PSIG)
PIPING CERTIFICATES REQUIRED
MW1
MP1
AS1
AS2
SF1
DATA ENTERED BY : ____________________
© BP Exploration 1989 - 2001 All Rights Reserved
SL1
REMARKS
DATE:___________
Americas Rev. 1
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
SECTION 4.0
MECHANICAL EQUIPMENT
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
PAGE: 1
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
4.1
ACTIONS
4.1.1
General
PAGE: 2
This document covers only the installation and pre-handover activities
and does not specify requirements for suppliers of equipment.
Mechanical Equipment shall be checked for compliance and other
requirements as detailed in, but not limited to:
•
•
•
•
•
•
•
4.1.2
The latest revision of Issued For Construction (IFC) or Approved
For Construction (AFC) Drawings and Schedules
Codes and standards reference in this section
Plant and Project Specifications
Equipment Specifications and Data sheets
BP Engineering Installation and Design Specifications
Local, state, country and international standards, codes, and
regulations as appropriate
Offshore - Special Standards, i.e. USCG, ABS and MMS
Pumps & Compressors
a) Machinery Procedure No. 4.1 lays down the checks that are required to
ensure that the equipment is correctly installed. On completion of
installation, the Construction Authority Mechanical Engineer will be
required to complete the Mechanical Installation form MM1.
b)
4.1.3
a)
Machinery Procedure No. 4.2 lays down the method to adopt for
alignment checks, which will be recorded on Certificate form MM2, and
accepted by the Commissioning Authority Mechanical Engineer.
Submersible pumps will not require an MM2 Alignment Certificate.
Skid Mounted Units
These will generally consist of vessels, pumps, compressors, drivers,
piping, instrumentation, etc., mounted on a common frame. As
equipment gets larger, there will usually be two frames, one for the
driver and one for the driven equipment. Other disciplines will carry out
their respective checks as required. The Construction Authority
Mechanical Engineer will be required to carryout Machinery Procedure
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 3
4.2 for the units and record this fact on the Mechanical Installation
Certificate form MM1.
b)
The Mechanical section of Handover Certification Packages for the units
will typically contain:
1 - MM1 Certificate for the installation of the skid unit.
1 - MM1 Certificate for each pump or compressor.
1 - MM2 Certificate for each pump or compressor and associated driver
unit.
4.1.4
Vessels And Tanks
a) Vessels and tanks fabricated off and on-site will be installed in accordance
with the following procedures:
Procedure No 4.3 - General Requirements & Pressure Safety Relief Devices
Procedure No 4.4 - Vessels & Tanks Fabricated (Off-Site)
Procedure No 4.5 - Vessels & Tanks Modified (Off-Site)
b)
Each vessel installed shall be identified by the Construction Authority to
ensure the installation conforms to drawings and specifications. Each
installation shall be approved by acceptance of the certificate form MV1.
Final closure shall be witnessed and accepted by the client/operations
representative.
c)
4.1.5
a)
Base line thickness checks, prior to insulation, where applicable, shall
be performed and recorded on the approved BP forms.
Mechanical Handling
Introduction
This section gives the recommended minimum requirements to show
that the Mechanical Handling Equipment is installed, and ready to be
handed over to Commissioning for proof load testing.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 4
Installation, test and inspection of lifting appliances shall comply with the
statutory and mandatory requirements and, as appropriate, and specific
requirements for individual items described in the BP Standards and
Supplier documents for those items.
With respect to site inspection and testing of the Totally Enclosed Motor
Propelled Survival Craft (TEMPSC) Davits, reference shall be made to
the appropriate regulations and laws of the country or state whose
jurisdiction the off-shore installation is subject.
b)
General
Certain classes of lifting equipment will require the attendance of a third
party to review/witness the design and/or fabrication and/or testing. BP
will lay down the full range of lifting equipment requiring third party
involvement.
Certain classes of lifting equipment may require the completion of the
proof-load testing program to be carried out on-site and these are
highlighted in the relevant procedures, e.g. Main Deck Cranes, Lifeboat
Davits..
All Mechanical Handling Equipment will be required to undergo the
inspections and tests as described here-in. The resulting certificates are
required as part of the System Test Dossier and are mandatory.
c)
Mechanical Procedures
Mechanical Handling Procedures lay down the checks that are required
to ensure that the equipment is correctly installed and have been
subjected to a proof-load testing program.
Installation completion checks will culminate in the raising of a
Mechanical Handling Installation Certificate - MH1.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 5
The successful completion of the MH1 releases the subject mechanical
handling equipment for start of the proof load testing program.
Proof load testing shall be recorded on the mechanical Handling
Acceptance Certificate - MH2.
If load testing of a fabrication yard installed lifting appliance has been
completed at fabricator’s/vendor’s site, then the testing will not normally
be repeated on-site. This does not apply to "man-riding" equipment.
Lifting Appliances shall be load tested prior to:
i) Access being restricted, e.g. by the installation of the facility
equipment (pumps, skids etc.) they are associated with;
ii) Painting or coating of themselves or the structure they are attached to.
d)
Applicable to all Lifting Appliances
During the examination of lifting appliances, the following must be
recorded on the reverse side of the MH2. A Third Party Certificate
Examination of Lifting Appliances, recording the load testing of
appliances witnessed by the "Competent Person" is considered
acceptable.
i) Parts not accessible for thorough examination.
ii) Parts that require opening up at the next examination.
iii) Particulars of defects and remedy, particulars of any defect found in
the lifting appliance of lifting gear which affects the safety of the
appliance, and the repairs (if any) required, either immediately or
within a specified time (which must be stated), to enable the lifting
appliance to continue to be used with safety.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 6
iv) Safe Working Load (SWL) subject to the repairs, renewals and alterations
(if any) specified in (c) above. In the case of a crane with a variable
operating radii, including a crane with a derricking jib, the safe working at
various radii of the jib, trolley or crab is to be stated.
The Mechanical Handling section contains the following procedures:
Procedure No 4.6 - Cranes
Procedure No 4.7 - Hoists, Trolleys & Gantries
Procedure No 4.8 - Trolley Beams & Pad Eyes
Procedure No 4.9 - Lifeboats & Davits
e)
Painting & Marking of Lifting Appliances
i) Trolley Beams, lifting points (including associated supporting
steelwork) and other pertinent appliances shall be painted safety
yellow.
ii) The Safe Working Load (SWL) and Equipment Tag numbers shall be
painted onto the appliances in black letters, minimum 4 inches tall.
The lettering shall be legible from the ground and operating position
and routinely applied on both sides. For beams of greater lengths
than 15 feet the SWL shall be applied at each end.
iii) The SWL and Equipment Tag numbers shall be stamped into the
appliance at the end adjacent to the operating position.
iv) For lifting points, the requirements described in i) & ii) above shall
apply to the associated supporting steelwork
f)
Lifeboats and Davits (if applicable)
i) Where lifeboats (TEMPSC) are installed offshore, an MH1 certificate
shall be raised to show correct installation of the lifeboat davits, and
an MH2 for the load testing. Welding and NDE shall be recorded on
the appropriate forms and reports, refer to Section 2.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 7
ii) An MH1 certificate will be raised to show correct installation of the
lifeboats and launch/retrieval system.
iii) The complete system must be tested to the satisfaction of the
approving authority, regulations and laws of the country or state
whose jurisdiction the offshore installation is subject.
4.1.6
a)
Use of Forms
MM1: Mechanical Installation Certificate:
Used to record that the installation of pumps, compressors and skid
mounted units has been carried out in accordance with Machinery
Procedure 4.1.
The form shall be signed by the Construction and
Commissioning Authorities.
Any outstanding items shall be identified on the standard GOC©
punchlist form PL1.
b)
MM2: Machinery Alignment Certificate:
Used to record that pumps, compressors and other mechanical
equipment have been aligned to interfacing equipment, such as motors,
gears, turbines, etc., in accordance with Machinery Procedure 4.2.
This shall be completed as part of MM1 above and signed by
the Construction and Commissioning Authorities.
c)
MV1: Vessel/Tank/Caisson Installation & PSV/RD Inspection Certificate:
MV1 Side 1 is used to record that all checks and tests have been
carried out prior to closing the vessel, tank or caission as described in
Section 4.1.5 and in accordance with Vessel Procedures No's 4.3, 4.4 and 4.5.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 8
MV1 Side 2 is used to record that the pressure safety relief devices
have been inspected and tested to the requirements of Section 3.2 of
Vessel General Requirements Procedure 4.3.
The form shall be signed by the Construction, Commissioning, Platform
and Vendor Authorities, as applicable, to indicate satisfactory completion
of modification, testing and inspection.
The back up documentation shown in the flowchart contained in this
document should be checked for availability and completion.
Any outstanding work shall be punchlisted and recorded on the PL1
form.
c)
MH1: Mechanical Handling Installation Certificate:
Used as a checklist to record that the lifting appliance has been installed
correctly. This shall be signed by the Construction Authority prior to
proof load testing being carried out.
d)
MH2: Mechanical Handling Acceptance Certificate:
Used to record the proof load test and that the installation is
mechanically complete.
e)
MH2: Mechanical Handling Acceptance Certificate (Cont. Sht):
Record any defects, remedies, and recommendations from examination
of lifting appliances on the reversed side of the MH2.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 9
MECHANICAL PROCEDURES
Machinery
Procedure No. 4.1
-
Pump/Compressor/Skid Mounted Unit Installation
Procedure No. 4.2
-
Machinery Alignment
-
General Requirements & Pressure Safety Relief
Procedure No. 4.4
-
Devices
Vessel & Tanks Fabricated (Off-Site)
Procedure No. 4.5
-
Vessel & Tanks Modified (On-Site)
Procedure No. 4.6
Procedure No. 4.7
Procedure No. 4.8
-
Cranes
Hoists, Trolleys and Gantries
Trolley Beams and Pad Eyes
Procedure No. 4.9
-
Lifeboat Davits and Lifeboat
Vessels
Procedure No. 4.3
Mechanical Handling
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 10
Procedure No. 4.1
1.1
1.1.1
Pumps and Compressors
General
The following points are to be checked on all pumps, compressors and
skid-mounted units:
a)
Check that the pump/compressor or skid unit is correct in all aspects to
the drawings and data sheets, and has been installed to the
manufacturer's recommendations and engineering design installation
requirements.
b)
Check that the pump/compressor or skid unit is free from mechanical
damage and is internally clean.
c)
Check that the holding down bolts of the skid unit, pump/compressor
and driver to the base plate and the base plate to the floor are correctly
installed and tightened.
d)
Check that the unit is level, correctly shimmed and fixed to the base.
e)
Check dissimilar metals isolation is achieved.
f)
Check that all ancillary equipment is installed and operational.
g)
Check that all drains and vents - including bedplate drains are
connected and clear of obstruction.
h)
Check that all mechanical seals are clean and completed.
i)
Check that all piping is complete and correctly aligned, e.g. seal and
lube oil systems are flushed correctly (pickled where necessary) and
filled with the correct oil.
j)
Check that all interface points are correct to the vendor’s drawing(s).
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k)
Check that all ladders and walkways are complete.
l)
Check that all the painting, heat tracing and insulation is completed and
the appropriate certificates are approved.
m)
Check that all bearings have correct lubrication.
n)
Check that all gearboxes and fluid couplings, where fitted, are filled with
the correct lubrication.
o)
Check that all instrumentation, including PSV's, is correctly fitted, visible,
accessible for maintenance purposes and tested.
p)
Check that all suction and discharge piping is completed, correctly
aligned with the correct gaskets installed. Pipe strain induced on
equipment shall not effect the alignment more than 0.002 inch from the
12:00 or 3:00 o’clock dial indicator position.
q)
Check that all temporary and permanent strainers are fitted and easily
identified.
r)
Check that all rotating equipment is free to turn by hand.
s)
Prior to installation of coupling, check that the driver is in the correct
direction of rotation.
t)
Check that the drive couplings, belts and guards are correctly fitted.
u)
Check that the machinery Alignment and Certificate MM2 is completed.
v)
Check that the mechanical Punchlist is raised, (form PL1).
Refer to project specific requirements for rotating equipment (inspection,
pre-commissioning, installation) and API RP 686 Recommended
Practices for Machinery Installation and Installation Design.
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1.1.1
Certification
a)
Mechanical Installation Certificate MM1 and/or the Machinery Alignment
Certificate MM2 will be completed as appropriate by the Construction
Authority Mechanical Engineer when the above checks have been
carried out.
Note: Paint, insulation and trace heating have not been included in this
procedure as they will be covered by certification raised by other
disciplines, i.e. (Architectural Services Section 7.0, and Electrical
Section 9.0).
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Procedure No. 4.2
2.1
Machinery
2.1.1
Machinery Alignment
a)
The following Procedures are to be performed in conjunction with the
Machinery Alignment Certificate Form MM2.
b)
Abbreviations:
DTI
= Dial Test Indicator
DBSE = Distance Between Shaft Ends
TDC
TIR
c)
= Top Dead Center
= Total Indicated Runout
All machinery will have the alignment checked by one of the following
methods described below. Tolerances shall be within the manufacturers
standard requirements or ± 0.002 inch TIR, whichever is less.
d)
Always rotate the shafts in the direction of rotation, and view the
readings from the Driver to the Driven equipment.
e)
Enter the type of Alignment Procedure to be used on Form MM2 i.e.
Reverse/Optical/Rim & Face. If Rim & Face is to be used, delete the
titles Driver Hub & Driven Hub and insert the titles Face and Rim.
f)
Enter the target alignment that is to be achieved in the Required
Alignment section.
g)
Always verify that equipment bearings are lubricated. Rotate the
equipment by hand a couple of rotations, just prior to taking alignment
readings.
h)
Prior to any of the following methods of alignment being undertaken, the
concentricity checks must be carried out.
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2.1.2
Concentricity Checks, Coupling Hub Run-Out
a)
Mount 2 Nos. DTI off the shaft of the driven machine, and place the
pointers in their mid positions, one on the rim and one on the face of the
Driver hub, and zero the clocks.
Note: When taking the face readings ensure the end float in the shafts
does not give inaccurate readings, i.e. push end float all one way.
b)
Rotate the Driver hub in the direction of rotation at least twice, at 90
degree intervals take the actual rim and face run-out, and enter readings
on the Form MM2.
c)
Repeat above for the Driven hub.
2.1.3
Rim and Face Alignment
a)
Rim - Mount a DTI support bar on the Driver hub, place the pointer in its
mid position on the Driven hub, and zero the clock at TDC (0 degrees).
b)
Turn the shaft in the direction of rotation, at least twice, and neter
readings taken at 90 degree intervals on the Form MM2.
c)
Face - Mount a DTI between the faces of the Driver and Driven coupling
hubs, ensuring that the shafts end float does not have any inaccuracies,
i.e. push end float all one way.
d)
Set the DTI pointer in the mid range and zero the clock.
e)
Turn the shaft in the direction of rotation, at least twice, and enter
readings taken at 90 degree intervals on the Form MM2.
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2.1.4
Reverse Alignment
a)
Using offset DTI supports, mount the support for the DTI on the Driver
hub and DTI on the Driven hub rim. Vice versa for Driven hub to Driver
hub.
b)
Set the DTIs in mid range, and zero the clocks when both clocks are at
TDC (0 degrees).
c)
Turn both shafts together in the direction of rotation, take reading
simultaneously off both DTI's at 90 degree intervals, and enter them on
the Form MM2.
2.1.5
Optical Alignment
a)
Complete the alignment using the Optical Manufacturers Alignment
Procedure.
b)
Enter all readings on to the Optical Manufacturers Alignment sheet and
attach it to the Form MM2.
2.1.6
Distance Between Shaft Ends (DBSE)
a)
Using an internal micrometer or vernier calliper, check the required
DBSE between the driver and driven hubs, and enter on the Form MM2,
taking into consideration any end float in the driver or driven equipment.
Rotors for horizontal motors shall be set on their magnetic center prior to
measuring and setting the DBSE.
2.1.7
Soft Footings
a)
Both driven unit and driver shall be checked for a "soft foot" condition.
With the equipment final aligned and all the hold down bolts properly
torqued, install two dial indicators from the driver shaft to the driven
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equipment coupling hub.
PAGE: 16
Position the indicators at 12:00 and 3:00
o’clock.
b)
Loosen one of the driver hold down bolts one at a time and verify that
neither indicator moves more than 0.002 inch.
c)
Repeat step (b) until all driver and driven equipment hold down bolts
have been checked.
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Procedure No. 4.3
3.1
Vessels General Requirements
3.1.1.
General
The following points are to be checked on vessels and tanks, both fabricated offsite or modified on-site, and are in addition to any other specific procedure.
a)
All inspections will be in accordance with applicable codes, standards
and Specifications.
b)
All vessel platforms, ladders and access arrangements will be inspected
by the Construction Authority Mechanical Engineer to ensure
compliance with design drawings, specifications, standards and safety
aspects.
c)
The Construction and Commissioning Authorities will conduct an internal
inspection of the vessel, to confirm cleanliness, damage free condition,
and completion of internals installation to specification, including but not
limited to the following:
i)
ii)
iii)
iv)
v)
vi)
vii)
viii)
Demisting Pads
Trays
Coils
Baffles
Vortex Breaker
Lining
Packing
Internal nuts suitably locked.
d)
Internal coating to be checked by a Paint Inspector.
e)
Check all insulation is correct and complete.
f)
Check all instrumentation is visible and accessible.
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g)
Check grounding and bonding is correct to specification.
h)
Check all piping connections, and manways are bolted up correctly and
that the correct specification gaskets have been installed.
i)
Check that the holding down bolts are correctly tightened and/or
torqued.
j)
Check that the details of vessel identification plate are correct.
k)
Check that the state registration has been completed and number
assigned.
l)
Prior to final closure of the vessel/tank, the Construction and
Commissioning Authorities shall inspect it internally. Discipline punch
listing shall be carried out, as applicable, and the relevant PL1 forms
raised.
m)
Vessel manufacturers data Material Data Reports (MDR’s) are available.
3.2
Pressure Safety Relief Devices
3.2.1
Pressure Safety Valves - General
At site, pressure safety valves will be checked for freedom from damage
and deterioration and the lifting pressure shall be tested on a suitable
pressure rig.
The testing authority will be subject to BP approval.
All test methods must be agreed with BP before being put into operation.
The following standard is applicable to this procedure:
•
API 510 - Requirements for Inspection & Repair of Pressure
Relieving Devices
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•
API RP 576 - Inspection of Pressure Relieving Devices
•
•
API RP 527 - Seat Tightness of Pressure Relief Valves
ANSI B147.1 - Commercial Seat Tightness of Safety Relief Valves
with Metal to Metal Seats (formerly API Standard 527).
It is important that Pressure Safety Valves are stored in a secure
warehouse with the valves standing vertically. When received, the valve
blanking plates should be checked for damage, which could have
allowed the passage of foreign material into the inlet nozzle and the
body cavity.
If Pressure Safety Valves are shipped without test-gags in place, then it
will be necessary to strip down every valve to ensure that there has
been no damage on seats or discs during transit and to remove any
loose material.
A Relief Valve shall be put into service within 60 days of being tested,
calibrated and re-set.
3.2.2
a)
Test Procedure
Pressure safety valves shall be tested immediately prior to installation.
If installation is deferred, the protective flange covers shall be refitted
and the valve stored in a vertical position. When required for service,
the valve must be re-tested. The pressure safety valve should be
initially bench tested and then tested in-place prior to start-up. There
may be some specific test requirements required by the regulatory
agency that is in authority.
All tests on pressure safety valves shall be the responsibility of the
Construction Authority, and shall be recorded on certificate MV1 (Side
2). Tests shall be witnessed by the Commissioning or Integrity
Authority, who shall countersign the MV1 to indicate witnessing. All
pertinent data relating to PSV calibration shall be recorded on MV1
(Side 2).
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The safety valves tests are in two stages:
b)
i)
Popping and reseating.
ii)
Seat leakage test.
Popping and Reseating
Before popping the safety valve, the outlet flange shall be removed.
The inlet nozzle should be wiped clean prior to testing.
The safety valve 'cold set pressure' shall be ascertained and entered on
the test record sheet. This pressure should be found on the valve data
plate or on the valve data sheet.
The test pressure shall be increased slowly until the safety valve is
observed to pop and the pressure (as indicated by the 'maximum'
pointer on the test gauge) shall be noted on the test record sheet. If the
difference between the measured popping pressure and the cold set
pressure is outside acceptable tolerances, the valve setting shall be
adjusted in accordance with the manufacturer's instructions.
The test pressure shall then be lowered and the reseating pressure
noted and checked that it agrees with the safety valve specification.
c)
Seat Leakage Test
Unless otherwise specified, the seat leakage rate shall be tested in
accordance with ANSI B147.1. This test procedure is summarized as
follows:
Immediately after the popping the test pressure shall be lowered and
held at 10% below the set pressure (5 psig or 0.35 bar g minimum) for
the duration specified in ANSI B147.1.
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The outlet flange shall be refitted complete with safety plug and the
open end of the bleed pipe shall be immersed in water to a depth of 0.5
inches (13 mm) below the surface. The leakage rate in bubbles per
minute will then be checked in accordance with ANSI B147.1.
Should the leakage rate exceed the permitted tolerance, the popping
and leakage tests shall be repeated to ensure that foreign particles are
not preventing complete closure.
Failure of the leakage test shall be corrected by dismantling the valve
and lapping the disc and seat in accordance with the manufacturer's
instructions.
After testing, the valve shall be identified by a suitable color sticker.
The bonnet cap shall be firmly secured and locked using a metal link
and lead seal.
Note: During testing to API 527 using the cap method, it is possible for
air leakage to occur around the top bonnet flange; the outlet
flange made off for the test; and the cap. These should be soap
tested during the test to prove that there is no leakage.
Alternatively, a flooded seat test should be nominated for valve
discharge flanges greater than 2 inches and, after such test; the
body cavity shall be thoroughly dried with instrument air.
3.2.3
Pilot Operated Safety Relief Valves
A variety of Pressure Safety Valves operate with pilots and in every case
pressure in the system activates a mechanism that is independent of the
basic Relief Valve, which opens the valve to full capacity.
Inspection, testing, maintenance and setting of the Pilot-Operated Relief
Valves may be divided into two separate phases; the pilot mechanism
phase and the basic relief valve phase. With test connections, the set
pressure of some types of valve may be accurately tested while the
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valve is in service. (If there is no isolation block valve under the relief
valve, it may be inspected and repaired only while the vessel is out of
service.)
Because of the many varied types of Pilot-Operated Relief Valves
available, the valve manufacturers recommendations for inspection and
repair should be consulted and followed, along with API RP 576
Inspection of Pressure Relieving Devices.
3.2.4
Rupture Discs (RD)
Rupture Discs (Bursting Discs) are pressure containing devices that are
used in service where a large relieving capacity is required to give a
rapid drop in pressure.
A rupture disc is the pressure-containing and pressure-sensitive element
of a rupture disc device. Rupture Discs maybe designed in several
configurations, such as flat, domed (pre-bulged), or reverse acting.
Most discs may require a rupture holder to enclose, seal, and clamp the
rupture disc in position. This combination of the disc and holder is called
a rupture disc device.
Because rupture discs cannot be tested, they should be replaced on a
regular schedule based on their application, manufacturer’s
recommendations and past experience.
Reference should be made to API RP 576 Inspection of Pressure
Relieving Devices and API RP 520 Parts 1 and 2 on rupture discs.
Care should be taken on installation, to ensure that the data and
material specifications stamped on the data plate or tab handle agrees
with the required specification and recorded on form MV1 (Side 2) by the
Construction Authority. During installation, the Commissioning Authority
will check to ensure the correct direction of flow.
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3.3
Certification
a)
Form MV1 (Side 1) shall be completed by the Construction,
Commissioning Authorities to record that the vessel checks have been
carried out satisfactorily, to the requirements of the following Vessel
Procedures:
Procedure No. 4.3 - General Requirements
Procedure No. 4.4 - Vessels and Tanks Fabricated (Off-Site)
Procedure No. 4.5 - Vessels and Tanks Modified (On-Site)
b)
Form MV1 (Side 2) shall be completed by the Construction,
Commissioning Authorities to record that the pressure safety relief
devices have been inspected and tested to the requirements of Section
3.2 of Vessel General Requirements Procedure 4.3.
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Procedure No. 4.4
4.1
Vessels and Tanks Fabricated (Off-Site)
4.1.1.
General
This section covers the inspection procedures to be carried out on pressure
vessels and atmospheric tanks fabricated and tested in vendors facilities and
should be carried out in conjunction with Vessel Procedure No. 4.3 - General
Requirements.
The following points are to be checked:
a)
Ensure the vessel is correct in all respects to the vendor drawings and
data sheet.
b)
Prior to vessel placement, the foundation/structural support construction
is to be checked for compliance with design drawings, specifications and
for completion.
c)
The vessel is to be initially inspected for transit damage, and after
placement for installation damage.
d)
Check PSV's have been installed correctly and are still in certification.
e)
Check "expansion end bolting to be loose".
f)
If it is intended to include the vessel within a piping pressure test pack,
the Construction Authority Mechanical Engineer shall verify the
existence on site of the dedicated vessel test certificate, and sight the
Inspection Release Note.
g)
The piping system test pressure shall be compared with the vessel
pressure, and the Construction Authority Mechanical Engineer will
ensure that the pressure ranges are compatible, before authorizing the
inclusion of the vessel in the piping system test.
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4.1.2
Certification
a)
Form MV1 shall be completed by the Construction and Commissioning
Authorities, to record that the vessel checks and documentation are
complete, and that the requirements of Vessel Procedure No. 4.3 General Requirements, and Vessel Procedure No. 4.4 - Vessels and
Tanks Fabricated (Off-site), have been carried out satisfactorily.
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Procedure No. 4.5
5.1
Vessels and Tanks Modified (On-Site)
5.1.1
General
This section covers the inspection procedures to be carried out during the on-site
modification of vessels and tanks, in addition to the inspection activities outlined
in the design specifications and drawings, and should be carried out in
conjunction with Vessel Procedure No. 4.3 - General Requirements.
a)
All materials employed for the fabrication are to have passed inspection
on receipt at stores operated by BP or their Delegated Authority.
b)
Before authorizing release of the vessel/tank for pressure testing, the
Construction Authority Mechanical Engineer must be satisfied that the
following inspection functions have been satisfactorily executed:
i.
All NDE requirements and welding must have been completed
to the satisfaction of the Construction Authorities Welding
Inspector and all welded attachments completed.
ii.
All temporary dog clips and plate alignment brackets shall have
been removed, and weld deposits ground off, to the satisfaction
of the Construction Authorities Welding Inspector, prior to stress
relieving, if required.
iii.
Stress relieving, if a requirement, must be completed prior to
pressure testing, and dedicated documentation certifying this
activity completion made available.
iv.
Internal vessel inspection conducted to ensure completion of all
works and applicable certification completed made available.
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The vessel is correct in all respects to the fabrication drawings
and data sheets, and that all necessary fabrication records are
available and correct.
c)
When the Construction Authorities Mechanical Engineer is satisfied that
all construction activities in the modification of the vessel have been
completed, a vessel release authorization is to be issued for
commencement of the pressure test to an agreed procedure.
d)
The vessel will then be released by the Construction Mechanical
Engineer for any internal lining/painting and external insulation/painting
work. Inspections will be executed by the Construction Authorities
Mechanical Engineer/Inspectors during and after completion of these
work activities.
e)
Vessel/Tank/equipment shall be re-certified and stamped by the
Certifying Authority prior to being returned service, if so designated.
5.1.2
Certification
a)
Form MV1 shall be completed by the Construction, Commissioning and
Platform Inspection Authorities, to record that the vessel checks,
fabrication documentation and testing records are complete, and the
requirements of Vessel Procedure No. 4.3 - General Requirements, and
Vessel Procedure No. 4.5 - Vessels and Tanks Modified (On-Site), have
been carried out satisfactorily.
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Procedure No. 4.6
6.1
Cranes
6.1.1
General
This procedure lays down the checks that are required to ensure that the subject
crane is correctly installed and has been subjected to a full proof - load and
function testing.
Site inspection and testing of cranes will comply with the requirements of BP
specifications and federal and state requirements or the appropriate regulations
and laws of the country or state whose jurisdiction the installation is subject.
Cranes will be erected and tested in accordance with the Vendors approved
procedures and under the supervision of their representative. "On-site" welding
or any modification to the crane is subject to authorization by the Vendors design
office, the BP Site Engineers and CA approval.
The following points are to be checked on all cranes and are in addition to the
applicable text in the Mechanical Handling section 4.1.5.
a)
All mountings (turret/slewing ring, etc.) are to be checked against
Vendor Drawings for correct installation, and all major fixing bolts
checked for correct grade and torque setting.
b)
The settings and function of all safety devices are to be checked and
tested or certified.
c)
All wire rope systems are to be checked to ensure that they are reeved
in accordance with the Vendors instructions, that the wire rope remains
captive within the sheave and drum and does not foul the crane during
operation.
d)
All lubricants and coolants shall be checked for correct grade and
quantity.
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Check that the Vendor has provided certification that will cover but not
be limited to the following:
i.
Crane as a whole Including Statutory requirements
ii.
Hooks
iii.
Snatch blocks
iv.
Wire ropes, hoist and boom hoist
v.
Special tackle, lifting, beams etc. for crane maintenance
vi.
Pressure vessels (air receiver for diesel air start)
vii.
All electrical/instrument items including hazardous area certificates
viii. Structural steel and NDE reports
ix.
Slewing rings and fastenings
x.
All loose equipment for handling the crane (spreader beams, slings
etc.)
f)
If load testing of a crane has only been partially achieved off-site, the
testing will be completed when the crane is installed in its permanent
location on-site.
g)
Cranes (pedestal and non-pedestal) are to be proof load tested to
Statutory requirements with certified test weights and/or calibrated load
cell, in the presence of a third party inspector as assigned by BP.
h)
All fabrication certification and load test certification of any supporting
structure is available in addition to the crane load test.
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On completion of the tests, a thorough examination of the crane will be
undertaken by the inspector to ensure no damage or permanent strain
has occurred. Some spot checking by NDT may be required at the
discretion of the Inspector. Hooks shall be NDT after load test.
6.1.2
Certification
a)
Form MH1 - Mechanical Handling Installation Certificate, is to be used
to record the satisfactory completion of the checks which are to be
carried out, and requires endorsement to confirm that the required
vendor certification is correct and available on-site, that the
requirements of this procedure have been carried out, and that the
crane has been installed in accordance with the specified design
requirements.
The successful completion of the MH1 releases the crane for start of
the proof load-testing program.
b)
Form MH2 - Mechanical Handling Acceptance Certificate is to be used
to record the proof load testing certificates and any other relevant
certificates and/or restrictions.
The MH2 requires endorsement to
confirm the completion and witness of the proof load testing and will
have attached the third party reports and test certificates.
c)
The Crane can be commissioned in advance using temporary supplies
and be used as an installation aid during construction and
commissioning of the facility.
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Procedure No. 4.7
7.1
Hoists, Trolleys & Gantries
7.1.1.
General
This procedure lays down the checks that are required to ensure that the Hoists,
Trolleys & Gantries are per specification, correctly installed and have been
subjected to a full proof-load testing program.
Site inspection and testing of this lifting equipment will comply with the
requirements of BP specifications and federal and state requirements or the
appropriate regulations and laws of the country or state the installation is subject.
The following are to be checked on all hoists, trolleys & gantries and are in
addition to the applicable text in the Mechanical Handling section 4.1.5.
a)
All lifting equipment has been installed in accordance with the Vendors
approved procedures and drawings.
b)
Mounting beams, rails and guides must be inspected to ensure that the
installation complies with the specified geometrical tolerances.
c)
The lifting devices themselves must be checked against vendor and/or
design drawings for correct assembly and installation.
d)
All wire rope or chain systems are to be checked to ensure they are
reeved in accordance with the vendors instructions and that the wire
rope or chain remains captive within the sheave and drum and does not
foul the lifting elements during operation.
e)
Safety catches on hooks must be checked for correct function.
f)
Check that the lifting equipment vendor, and Third Party Inspection
Authority have provided the necessary load test certification for the
equipment.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 32
g)
Trolleys and gantries must be travelled over all working conditions to
ensure there are no interferences with other equipment.
h)
When the equipment has been partially dismantled to aid installation,
those bolts removed must be replaced and torqued correctly. If the
bolts were load bearing then the equipment must be tested as described
in Mechanical Handling Procedure No. 4.8
7.1.2
Certification
a)
Form MH1 - Mechanical Handling Installation Certificate, is to be used to
record the satisfactory completion of the checks which are to be carried
out, and requires endorsement to confirm that the required certification
is correct and available on site, that the requirements of the relevant
procedure have been carried out, and that the lifting equipment has
been installed in accordance with the specified design requirements.
The successful completion of the Mechanical Handling Installation
Certificate Form MH1 releases the installation for the start of the proofload testing program.
b)
Form MH2 - Mechanical Handling Acceptance Certificate, is to be used
to record the proof-load testing certificates and any other relevant
certificates and/or restrictions. The MH2 requires endorsement to
confirm the completion and witness of the proof-load testing, and will
have attached the Third Party Reports if the installation has been
subjected to Third Party Inspection.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 33
Procedure No. 4.8
8.1
Trolley Beams and Pad Eyes
8.1.1 General
This procedure describes the checks that are required to ensure that the Trolley
Beams and Pad Eyes are per specification, correctly installed and have been
subjected to a full proof-load testing program.
Site Inspection and testing of this lifting equipment will comply with the
requirements of BP specifications and federal and state requirements or the
appropriate regulations and laws of the country or state whose jurisdiction the
installation is subject.
The following are to be checked on all Trolley Beams and Pad Eyes and are in
addition to the applicable text in the Mechanical Handling section 4.1.5.
a)
All lifting equipment has been installed in accordance with approved
procedures and drawings.
b)
The Trolley Beams and Pad Eyes must be checked against design
drawings for correct assembly and installation.
c)
All bolts are to be checked to ensure the correct grade and torque
setting.
d)
All site fabricated Trolley Beams, main attachment points, Pad Eyes and
other lifting appliances shall be considered primary structure with
respect to material traceability, welding and NDE.
e)
Where a dedicated trolley is specified for a Trolley Beam, it is preferred
to test using the trolley. Hoists should be trial erected on trolleys and
Pad Eyes.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
f)
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 34
Lifting equipment is to be proof-load tested to Statutory requirements,
with certified test weights or calibrated load cell, in the presence of Third
Party Inspector as assigned by BP.
g)
Trolley Beams should have the Safe Working Load (SWL) traversed
along the beam, deflections should be checked at the greatest span of
the beam. The deflection should not exceed 1/500th of the span, for
cantilever sections 1/250th at the SWL.
An overload of 1.25 x SWL
should be applied at the point of maximum deflection. Measure and
record this deflection, remove all load and ensure the deflection returns
to zero.
The design contractor will specify pad eye design and test loads.
h)
All items must be stamped with TAG No. and SWL to show dedication to
a particular Mechanical Handling Installation.
i)
Trolley Beams without dedicated trolleys will be proof-load tested using
a "test” trolley. This must be clearly stated on the Mechanical Handling
Acceptance Certificate Form MH2.
j)
The Safe Working Load, TAG No. and any limiting conditions shall be
clearly painted on the Trolley Beam or adjacent to Pad Eye so as to be
clearly visible to the operator.
k)
On completion of each proof-load test, a thorough examination of the
tested lifting equipment shall be undertaken by the Inspection Authority,
to ensure no damage or permanent strain has occurred. Checking by
NDT will be required.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 35
8.1.2
Certification
a)
Form MH1 - Mechanical Handling Installation Certificate, is to be used to
record the satisfactory completion of the checks which are to be carried
out, and requires endorsement to confirm that the required certification
is correct and available on site, that the requirements of the relevant
procedure have been carried out, and that the lifting equipment has
been installed in accordance with the specified design requirements.
The successful completion of the Mechanical Handling Installation
Certificate Form MH1 releases the installation for the start of the proofload testing program.
b)
Form MH2 - Mechanical Handling Acceptance Certificate, is to be used
to record the proof-load testing certificates and any other relevant
certificates and/or restrictions.
The MH2 requires endorsement to
confirm the completion and witness of the proof-load testing, and will
have attached the Third Party Reports if the installation has been
subjected to Third Party Inspection.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 36
Procedure No. 4.9
9.1
Lifeboat Davits and Lifeboat
9.1.1 General
This procedure lays down the checks that are required to ensure that the
Lifeboat Davits and Lifeboats for offshore use are per specification, correctly
installed and have been subjected to a full proof-load testing program.
Site inspection and testing of the Lifeboat and Davits will comply with the
appropriate regulations and laws of the country or state whose jurisdiction the
offshore installation is subject.
The Lifeboat and Davits will be installed off-site and tested in accordance with
the Vendors approved procedures, under the supervision of their representative
and the Third Party Inspector. Additional on-site welding or any modification to
the Davits is subject to authorization of the Vendor’s design office and the BP
Site Engineer’s approval.
The following points are to be checked on all Lifeboat installations and are in
addition to the applicable text in the Mechanical Handling section 4.1.5.
a)
The Davits and Lifeboat are correct in all respects to the Vendors
drawings.
b)
The Davits and Lifeboat are free from damage.
c)
The Davits and Lifeboat have been installed as required by Vendors
design drawings and procedures.
d)
The settings and function of all safety devices are to be checked and
proved.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
e)
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 37
Check that the Vendor has provided certification that will cover but not
be limited to the following:
i) Davits and Lifeboat as a whole including Statutory requirements.
ii) Wire ropes, shackles, pulleys and hoist.
iii) All electrical and instrumentation cables and equipment.
iv) Structural steel and NDE reports.
v) All life support equipment.
f)
The Lifeboat and Davits, as a single unit, will be proof-load tested after
installation and shall be witnessed by a third party inspection as
assigned by BP.
g)
Further testing and drops to sea level will be carried out on-site in line
with (f) above.
h)
On completion of each part of the proof-load testing program, a
thorough examination of the Davits, Lifeboats and support structure will
be carried out to ensure no damage or permanent strain has occurred.
Checking by NDT will be required.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
9.1.2
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 38
Certification
Form MH1 - Mechanical Handling Installation Certificate is to be used to
record the satisfactory completion of the checks which are to be carried
out, and requires endorsement to confirm that the required Vendor
Certification is correct and available on site, that the requirements of the
procedure have been carried out, and the Davits and Lifeboat have been
installed in accordance with the specified design requirements.
The successful completion of the Mechanical Handling Installation
Certificate Form MH1 releases the Davits/Lifeboat installation for the
start of the proof-load testing program.
If the Davits have been part proof-load tested prior to the installation of
the Lifeboat, then a second MH1 will be raised for checking and
approving this subsequent installation.
Form MH2 - Mechanical Handling Acceptance Certificate is to be used
to record the proof-load testing certificates and any other relevant
certificates. The MH2 requires endorsement to confirm the completion
and witness of the proof-load testing.
If the Davits have been part proof-load tested prior to installation of the
Lifeboat then the MH2 must be clearly marked to reflect this.
Standard Proformas
Form No
MH1
MH2
Proforma Description
Mechanical Handling Installation Certificate
Mechanical Handling Acceptance Certificate
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 39
FLOWCHART 4.1
• Functional Certification Flowchart
• Discipline: Mechanical
MM1
MC1
MM2
SL1
SH1
MM1: Machinery Installation Certificate
MC1: Mechanical Completion Certificate
MM2: Pre-Operations Alignment Certificate
SL1: System Leak or Service Test / Witness Joint Certificate
SH1: System Handover Certificate
Note! Where Welding is carried out, an MW1 - Welding Completion
Summary is required - Refer to GOC© Section 2
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
PAGE: 40
MECHANICAL- MECHANICAL EQUIPMENT
FLOWCHART 4.2
•
•
Functional Certification Flowchart
Discipline: Mechanical (Vessels)
MV1
MC1
SL1
SH1
MV1: Pre-Operations Inspection
MC1: Mechanical Completion Certificate
MM2: Pre-Operations Alignment Certificate
SL1:
SH1:
System Leak or Service Test / Witness Joint Certificate
System Handover Certificate
Note! Where Welding is carried out, an MW1 - Welding Completion
Summary is required - Refer to GOC© Section 2
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
PAGE: 41
MECHANICAL- MECHANICAL EQUIPMENT
FLOWCHART 4.3
•
•
Functional Certification Flowchart
Discipline: Mechanical (Handling Equipment)
MH1
MH2
MC1
SH1
JI1
MH1: Mechanical Handling Installation Certificate
MH2: Mechanical Handling Load Test Certificate
MC1: Mechanical Completion Certificate
SH1:
JI1:
System Handover Certificate
Joint Integrity Certificate
Note! Where Welding is carried out, an MW1 - Welding Completion
Summary is required - Refer to GOC© Section 2
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 4.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- MECHANICAL EQUIPMENT
PAGE: 42
EXHIBIT 4
STANDARD FORMS
Form No.
Form Title
MM1
Mechanical Installation Certificate
MM2
Machinery Alignment Certificate
MV1
MH1
MH2
Vessel/Tank/Cassion Installation & PSV/RD Inspection Certificate
Mechanical Handling Installation Certificate
Mechanical Handling Acceptance Certificate
DIS2
Data Input Sheet 2 - Section 4 Mechanical
Note:
Final acceptance of each report as complete and correct shall be
authorization by the Construction and Commissioning Group, and
other approved authorities.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM MM1
SITE:
MECHANICAL INSTALLATION CERTIFICATE
PACKAGE NO:
SYSTEM:
EQUIPMENT NO:
LOCATION:
SHT
* PROCEDURE 4.1 Complete : Unit Installation
SIGNATURE
DATE
/
/
* PROCEDURE 4.2 Complete : Machinery Alignment
SIGNATURE
DATE
/
/
OF
P&ID NO:
REMARKS
PUNCH LIST NO.
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* DELETE AS APPLICABLE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM MM2
SITE:
MACHINERY ALIGNMENT CERTIFICATE
SHT
PACKAGE NO:
LOCATION:
P&ID No:
GA No:
PROCEDURE 4.1 Complete : Unit Installation
EQUIP No
SIGNATURE:
DATE:
/
OF
/
DESCRIPTION
INSPECTION No
SERIAL No
MANUFACTURER
DESCRIPTION
INSPECTION No
SERIAL No
MANUFACTURER
ALIGNMENT TO
EQUIP No
REQUIRED ALIGNMENT
0°
DRIVER HUB
DRIVEN HUB
D.B.S.E.
COUPLING HUB
RUN OUT
90°
DRIVER
RIM
FACE
ACTUAL ALGINMENT WITH PIPING FREE
0°
DRIVER HUB
DRIVEN HUB
D.B.S.E.
ACTUAL ALGINMENT WITH PIPING CONNECTED
0°
DRIVER HUB
DRIVEN HUB
D.B.S.E.
0O
180 O
90O
270 O
DRIVEN
270°
RIM
FACE
90°
180°
270°
90°
180°
270°
READINGS VIEWED DRIVER TO DRIVEN
0O
90O
270 O
180°
DRIVER
DRIVEN
D.B.S.E.
180 O
COMMENTS
Reverse Alignment attach Graph
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* DELETE AS APPLICABLE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM MV1
(Side 1)
SITE:
VESSEL/TANK/CAISSON INSTALLATION & PSV/RD
INSPECTION CERTIFICATE
EQUIP TAG No:
PSV / RD TAG No:
DESCRIPTION:
LOCATION
OPERATING PRESSURE:
PSIG
SYSTEM:
OPERATING TEMPERATURE:
DEG F
PACKAGE No:
SERIAL No:
P&ID No:
MANUFACTURERS TEST CERT No:
DRAWING No:
SHT
OF
(see Side 2)
INSPECTION No:
TEST PRESSURE:
PSIG
TEST DURATION:
MINS / HRS
TEST MEDIUM:
TEST DATE:
THIS CERTIFICATE SHALL BE COMPLETED BY THE VENDOR, CONSTRUCTION AND COMMISSIONING AUTHORITIES
TO RECORD THAT THE VESSEL CHECKS, FABRICATION DOCUMENTATION AND TESTING RECORDS ARE
COMPLETE, AND THAT THE REQUIREMENTS OF THE FOLLOWING PROCEDURES HAVE BEEN CARRIED OUT
SATISFACTORILY WHERE APPLICABLE.
YES
NO
N/A
1. VESSEL PROCEDURE 4.3 - GENERAL REQUIREMENTS
2. VESSEL PROCEDURE 4.4 - VESSELS & TANKS FABRICATED (OFF-SITE)
3. VESSEL PROCEDURE 4.5 - VESSELS & TANKS MODIFIED
(ON-SITE)
COMMENTS
NOTES
WHERE THESE TANKS FORM PART OF MODULE STRUCTURES, THIS INSPECTION MAY DUPLICATE PARTS OF THE
MAIN MODULE ACCEPTANCE PROCEDURES.
INSPECTION TO BE CONDUCTED IN ACCORDANCE WITH APPLICABLE CONTRACT SPECIFICATIONS AND DESIGN
CODES.
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
FORM MV1
PSV/RD INSPECTION
(SIDE 2)
PSV / RD TAG No:
INSPECTION No:
P&ID No:
REPORT NO:
LOCATION:
SYSTEM:
EQUIPMENT / LINE NO.
SERVICE DUTY
TYPE INSPECTION:
INSPECTED BY
DATE LAST INSPECTION:
DATE OF INSPECTION:
NAMEPLATE DETAILS
MANUFACTURER
INLET SIZE / CLASS / TYPE
/
/
MODEL NO./TYPE
OUTLET SIZE / CLASS /TYPE
/
/
SERIAL NO.
ORIFICE
PSV COLD SET PRESS.
PSV COLD DIFF. SET PRESS.
o
o
RD BURST PRESS @ 72 F/22 C
BACK PRESS.
PSIG
SPRING RANGE
PSIG
RD HOLDER SIZE / CLASS
PSIG
RD FLANGE ASSY. NO.
/
PSI
INSPECTION
SPRING DETAILS
BELLOWS FITTED
LENGTH
TRIM MATERIAL
DIAMETER
VALVE OVERHAULED
NO. OF COILS
BONNET CONDITION
MATERIAL
BODY CONDITION
MAT. DIAMETER
SPRING CONDITION
COLOR CODE/NO.
RD DISK MATL. / COATING
YES / NO
/
TEST DETAILS (PSV ONLY)
PRE POP PRESSURE
PSIG
TEST MEDIUM
ACTUAL SET PRESSURE
PSIG
ADJUSTING BOLT MEASUREMENT
BELLOW/BODY TEST
BLOW DOWN RING SET
ins or mm
NOTCHES DOWN
REMARKS/RECOMMENDATIONS
INSPECTION PERIOD
LIMITATIONS
DATE OF NEXT INSPECTION
MAJOR INSPECTION:
SPECIAL INSPECTION:
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM MH1
SITE:
MECHANICAL HANDLING INSTALLATION CERTIFICATE
EQUIPMENT No:
SHT
OF
LOCATION:
INSPECTION No:
DRAWING No:
SERIAL No:
DESCRIPTION:
GENERAL ARRANGEMENT No:
PUNCH LIST No:
ITEM/DESCRIPTION OF CHECK
SIGNATURE
DATE
-----------------------
--------------
-----------------------
--------------
-----------------------
--------------
1. TRANSIT DAMAGE CORRECT
2. FIXED EQUIPMENT INSTALLED IN ACCORDANCE WITH APPROVED DRAWINGS AND SPEC.
3. TRAVEL & OPERATION OF EQUIP. UNRESTRICTED & IN ACCORDANCE WITH DESIGN SPEC.
4. ASSOCIATED ALIGNMENT CHECKS COMPLETE ON:
(a)
RUNWAY (TROLLEY) BEAMS
(b)
GANTRIES
(c)
BEAM TRANSFER AND LATCH MECHANISMS
(d)
ASSOC. MECH. EQUIP. i.e. WINCHES, HOISTING MECHANISMS
(e)
OTHER:
5. ASSOCIATED LIFTING APPLICANCES CORRECTLY INSTALLED, TAGGED AND CERTIFIED:
(a)
BEAM TROLLIES
(b)
COMBINED TROLLEY HOISTS
(c)
CHAIN HOISTS
(d)
OTHERS:
6. ASSOCIATED DESIGNATED LIFTING TACKLE CORRECTLY INSTALLED, TAGGED & CERTIFIED:
(a)
WIRE ROPES
(b)
SHEAVE BLOCKS
(c)
SHACKLES
(d)
BEAM CLAMPS
(e)
SLINGS
(f)
EYEBOLTS
(g)
OTHERS:
7. CHECK S.W.L. IF ALL EQUIP, WITHIN AN INSTALLED LIFTING SYSTEM ARE COMPATIBLE
8. PERSONNEL PROTECTION AND SAFETY DEVICES CORRECTLY INSTALLED
9. EQUIPMENT IDENTIFICATION AND S.W.L. CLEARLY MARKED
10. CHECK THAT ALL MATERIAL AND FABRICATION REQUIREMENTS AS PER SPECIFICATION
AND APPROVED DRAWING HAVE BEEN MET AND ALL CERTIFICATION IS RECORDED.
(APPLICABLE TO INSTALLATION OF FIXED EQUIPMENT)
11. ALL EQUIPMENT CORRECTLY INSTALLED AND AVAILABLE FOR PROOF LOAD TEST
COMMENTS
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM MH2
(SIDE 1)
SITE:
MECHANICAL HANDLING ACCEPTANCE CERTIFICATE
SHT
ITEM :
LOCATION:
EQUIPMENT No:
SAFE WORKING LOAD (S.W.L.):
INSPECTION No:
PROOF LOAD:
SERIAL No:
PROOF LOAD CERTIFICATE No:
VERIFING AUTHORITY:
DRAWING No:
MAKER & DATE OF MAKE:
DATE FIRST PUT INTO USE:
OF
DATE OF LAST RECORD EXAMINATION (IF SEEN). NAME OF
PERSON WHO CONDUCTED LAST EXAMINATION AND OF THE
EMPLOYER.
PARTS NOT ACCESSIBLE FOR THOROUGH EXAMINATION
PARTS THAT REQUIRE OPENING UP AT THE NEXT EXAMINATION
PARTICULARS OF DEFECTS AND REMEDY PARTICULARS OF ANY
DEFECT FOUND IN THE LIFTING APPLICANCE AND THE REPAIRS
(IF ANY) REQUIRED, EITHER ;
i IMMEDIATELY OR,
ii WITHIN A SPECIFIED TIME (WHICH MUST BE STATED) TO
ENABLE THE LIFTING APPLICANCE OR LIFTING GEAR TO
CONTINUE TO BE USED WITH SAFETY. (IF NO SUCH REPAIRS ARE
REQUIRED, THE WORK 'NONE' IS TO BE ENTERED)
SAFE WORKING LOAD SUBJECT TO THE REPAIRS, RENEWALS
AND ALTERATIONS (IF ANY) SPECIFIED ABOVE IN THE CASE OF A
CRANE WITH A VARIABLE OPERATING RADIUS, INCLUDING A
CRANE WITH DERRICKING JIB, THE SAFE WORKING LOAD AT
VARIOUS RADII OF THE JIB, TROLLEY OR CRAB TO BE STATED
SECTION 1 (TO BE COMPLETED WHERE APPROPRIATE TO PERMANENT LIFTING TACKLE INCLUDED IN PROOF LOAD TEST)
ITEM DESCRIPTION
TAG/IDENTIF. No
S.W.L.
CERTIFICATE No
1.
2.
3.
4.
5.
6.
SECTION 2:
IF APPLICABLE, STATE ANY SPECIFIC LIFTING RESTRICTIONS WHICH MAY APPLY TO THE LIFTING EQUIPMENT OR
SYSTEM AND WHICH IS REQUIRED TO BE CLEARLY MARKED ON THAT EQUIPMENT
SECTION 3:
IF APPLICABLE, REFERENCE ANY FABRICATION, NDT, MATERIAL CONTROL CERTIFICATION AND INSPECTION
REPORTS RELATING TO THE CONSTRUCTION INSTALLATION ACTIVITIES
COPIES OF ALL PROOF LOAD CERTIFICATION LISTED ABOVE TO ACCOMPANY THIS CERTIFICATE
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
MECHANICAL HANDLING EXAMINATION REPORT
FORM MH2
(SIDE 2)
EQUIPMENT No.
SH1 No
INSPECTION No.
MC1 No.
SERIAL No.
S.W.L.
DRAWING No.
PROOF LOAD TEST CERTIFCATE No.
EXAMINATION REPORT
COMMENTS
PUNCH LIST NO.
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
DIS2
LOCATION : __________________
DATA INPUT SHEET 2
PROJECT : __________________
NO.
HANDOVER ID
EQUIP No
WIN No
RAISED BY: __________________________________
NOTE: JP No FOR INSTALLATION / TESTING EQUIPMENT
SWL
LOAD
TEST
P&ID No
DATE : ________________
GOC
DRG No
OF
WORKSCOPE ID : ___________________
SECTION 4 - MECHANICAL
J.P
SHEET
MAINTENANCE ID No : ______________
ASBUILT
REQ'D
(LAD)
MECHANICAL CERTIFICATES REQUIRED
MW1
MM1
MM2
DATA ENTERED BY : _________________________
© BP Exploration 1989 - 2001 All Rights Reserved
MV1
MH1
MH2
SL1
DATE : ___________
Americas Rev. 1
AS2
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 5.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- STRUCTURAL
PAGE: 1
SECTION 5.0
STRUCTURAL
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
5.1
ACTIONS
5.1.1
General
GUIDANCE ON CERTIFICATION
SECTION 5.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- STRUCTURAL
PAGE: 2
Construction Management responsibilities and associated quality
planning for structural activities, is normally categorised and managed
as follows:
a)
On-Site. The Construction Authority is responsible for the inspection and
test activities and management of the construction Contractor who
provides labor and equipment only;
b)
Off-Site. The Construction Authority monitors the performance of the
Management Contractor who is directly responsible for the fabrication
and Inspection and Test activities.
c)
For on-site, those inspection and test activities that require to be
performed and recorded to fulfil the minimum quality control
requirements, are clearly defined on the specified Inspection and Test
Schedule (ITS) for the work.
d)
For off-site, those Inspection and Test activities performed by the
Managing Contractor that are deemed by BP or their delegated authority
to be at critical stages in the fabrication process and require to be
witnessed before the Contractor can proceed, will be clearly defined
within the Managing Contractor's quality plan (QP), and/or the supplied
ITS.
e)
The acceptance of structural work is a composite function of Fabrication,
N.D.E. and Inspection (Section 2) and Architectural Services (Section 7).
Input by the relevant discipline engineers is required in quality planning
and subsequent development of an ITS for both off-site and on-site
Work.
f)
Flow charts give guidelines on handover of on-site work.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
g)
GUIDANCE ON CERTIFICATION
SECTION 5.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- STRUCTURAL
PAGE: 3
All reporting and recording of inspection and acceptance of structural
work shall be on the GOC© standard forms or alternatives where agreed
by BP or the delegated authority.
h)
The Construction Authority shall exercise sufficient dimensional control
over the Work and shall monitor or conduct surveys throughout
prefabrication, fabrication, construction and installation stages of the
Work to ensure that the specified design tolerances are achieved. The
fabricator prior to installation shall establish reference marks and levels
required to assist fit-up.
i)
The Construction Authority shall prepare, maintain and issue reports,
which describe the extent, and contain the results, of all dimensional
surveys carried out on-site and shall monitor reports produced by the
fabricator off-site.
5.1.2
Installation
The installation of Structural Items shall be checked for compliance and
other requirements as detailed in but not limited to:
•
•
•
•
•
•
•
The latest revision of Issued For Construction (IFC) or Approved
For Construction (AFC) Drawings and Schedules
Codes and standards reference in this section
Plant and Project Specifications
Equipment Specifications and Data sheets
BP Engineering Installation and Design Specifications
Local, state, country and international standards, codes, and
regulations as appropriate
Offshore - Special Standards, i.e. USCG, ABS and MMS
5.1.3
Use of Forms
a)
Off-Site Structural Acceptance
The MS1 will certify that all offsite fabrication activities for a discrete
structure or its component parts, complies in all particulars with the
required Design and that all specified Inspection and Testing is
completed and accepted.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 5.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- STRUCTURAL
PAGE: 4
The Structural Engineer authorised by BP or their Delegated Authority
shall break down all discrete structures into the following classifications
for certification purposes:
•
Discrete Structure (i.e. Module, Jacket, Module Support Frame, etc.)
•
Assembly (i.e. Module Truss or Jacket Truss, deck extension, etc.)
Sub-Assembly (i.e. Truss Node or Tubular, etc.)
•
As a minimum, all sub-assemblies will require an MS1 certificate before
they can be installed in to an assembly. All assemblies will require an
MS1 certificate before they can be installed into the discrete structure.
All discrete structures will require an MS1 certificate before they can be
released for shipment onsite for installation.
b)
On-Site Structural Acceptance
The MS1 will certify that all onsite activities relating to the on-site
fabrication and installation of structural work have been completed and
comply in all particulars with the approved design, fabrication and
installation specifications and that all specified Inspection and Testing is
completed.
c)
Concealed Area Acceptance
When subsequent work creates concealed areas and prohibits further
access for re-inspection of structural steel, the Construction Authority
must note on the MS1 certificate that the concealed areas were
inspected, prior to boxing in of stiffners or covering the deck area or
cladding, etc.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 5.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- STRUCTURAL
PAGE: 5
FLOWCHART 5
• Functional Certification Flowchart
• Discipline: Mechanical (Structural)
MS1
MC1
SH1
MS1:
Structural Completion Certificate
MC1:
Mechanical Completion Certificate
SH1:
System Handover Certificate
Note! Where Welding is carried out on MW1 - Welding Completion
Summary is required - Refer to GOC© Section 2
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 5.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL- STRUCTURAL
PAGE: 6
SUBJECT:
EXHIBIT 5
STANDARD FORMS
FORM NO.
TITLE
MS1
STRUCTURAL COMPLETION CERTIFICATE
DIS3
Data Input Sheet 3 – Section 5 Structural
Note: Final acceptance of the MS1 - Structural Completion Certificate will be by
the Structural Engineer authorized by BP or their Delegated Authority.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
STRUCTURAL COMPLETION CERTIFICATE
FORM MS1
(SIDE 1)
SITE:
SHT
OF
THIS CERTIFICATE VERIFIES THAT THE WORKS SHOWN ON THE LISTED DESIGN DRAWINGS HAVE BEEN
FABCRICATED, INSTALLED AND TESTED IN CONFORMANCE WITH THE APPROVED DESIGNS, SPECIFICATIONS AND
PROCEDURES.
STRUCTURE/FABRICATION DESCRIPTION
DRAWINGS
REV
ITEM
DESCRIPTION OF ACTIVITY
SIGNATURE
*1
*2
*3
MATERIAL TRACEABILITY VERIFIED
MATERIAL LOCATION PLAN APPROVED
MATERIAL TRACEABILITY CONTROL SYSTEM VERIFIED
Q.C. INSPECTOR
*1
*2
*3
WELDING INSPECTOR
*4
*5
NDE RESULTS SATISFACTORY
PWHT RESULTS SATISFACTORY
WELDING TRACEABILITY VERIFIED (WELDER IDENTS &
PROCEDURES)
WELD/NDE TRACEABILITY LOCATION DRAWING APPROVED
WELD COMPLETION SUMMARY APPROVED
3
*1
*2
DIMENSIONAL CONTROL CHECKS SATISFACTORY
DIMENSIONAL AS-BUILT SURVEYS APPROVED
Q.C. INSPECTOR
4
*1
WEIGHT CONTROL AND C of G CHECKS COMPLETE
Q.C. INSPECTOR
5
*1
FINAL VISUAL INSPECTION SATISFACTORY
Q.C. INSPECTOR
6
*1
PAINTING/COATINGS & INSULATION SATISFACTORY
Q.C. INSPECTOR
1
2
ENSURE THAT THE STRUCTURAL ACTIVITY CHECK LIST, ON THE REVERSE SIDE OF THIS FORM, IS COMPLETED
AND APPROVED BY THE STRUCTURAL ENGINEER
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
*DELETE AS APPLICABLE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
STRUCTURAL ACTIVITY CHECK LIST
STRUCTURAL ENGINEER
SH1 NUMBER
ITEM
DESCRIPTION OF ACTIVITY
1
ERECTION & FIT-UP OF STRUCTURAL MEMBERS OR FRAME COMPLETE
2
ALL BOLTS, NUTS & WASHERS INSTALLED & TIGHTENED
3
DECK PLATE INSTALLED
4
DECK GRATING INSTALLED & FULLY SECURED
5
HANDRAILS INSTALLED & FULLY SECURED
6
KICK PLATE INSTALLED & FULLY SECURED
7
VERTICAL LADDER ASSEMBLIES INSTALLED & FULLY SECURED TO STRUCTURE
8
ACCESS STAIR ASSEMBLIES INSTALLED & FULLY SECURED TO STRUCTURE
9
DOOR FRAMES INSTALLED AND FULLY SECURED TO THE STRUCTURE
10
DOORS HUNG, ALL FITMENTS FITTED & DOORS FULLY OPERATIONAL
11
ELECTRICAL / INSTRUMENT TRANSIT FRAMES INSTALLED
12
PIPE PENETRATIONS INSTALLED
13
EXTERNAL BULKHEAD CLADDING INSTALLED
14
ALL WELDING COMPLETE
15
ALL TEMPORARY INSTALLATION AIDS REMOVED
AND REMAINING STRUCTURE DRESSED & MADE GOOD
16
P.W.H.T. COMPLETE
17
N.D.E. COMPLETE
18
PASSIVE FIRE PROTECTION COMPLETE
19
ENVIRONMENTAL INSULATION COMPLETE
20
PAINTING COMPLETE
21
VERIFICATION OF REVIEW & APPROVAL OF CONTRACTORS/SUBCONTRACTORS
FABRICATION, INSPECTION & TEST DOSSIER
COMPLETED BY
YES
NO
N/A
COMMENTS
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
DIS3 SHEET
LOCATION : __________________
DATA INPUT SHEET 3
PROJECT : __________________
J.P
NO.
RAISED BY:
HANDOVER ID
DRAWING No
DATE : __________________
____________________________________
NOTE: JP No FOR INSTALLATION / WELDOUT
WORKSCOPE ID : ___________________
SECTION 5 - STRUCTURAL
DESCRIPTION
GOC
OF
MAINTENANCE ID No : ______________
AS-BUILT
REQ'D
(LAD)
MW1
STRUCTURAL
AS1
AS2
MS1
DATA ENTERED BY : ____________________
© BP Exploration 1989 - 2001 All Rights Reserved
COMMENTS
DATE : ___________
Americas Rev. 1
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
SECTION 6.0
HVAC
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
PAGE: 1
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
6.1
ACTIONS
6.1.1
General
PAGE: 2
a) Input by the relevant discipline engineers is required during Quality
Planning and the subsequent development of the Inspection Test
Summary.
b) HVAC shall be checked for compliance and other requirements as
detailed in, but not limited to:
•
The latest revision of Issued For Construction (IFC) or Approved
For Construction (AFC) Drawings and Schedules
•
•
Codes and standards reference in this section
Plant and Project Specifications
•
Equipment Specifications and Data sheets
•
•
BP Engineering Installation and Design Specifications
Local, state, country and international standards, codes, and
regulations as appropriate
•
Offshore - Special Standards, i.e. USCG, ABS and MMS
6.1.2
Installation
a)
Equipment/Material shall be inspected on receipt on site. Any remedial
work carried out on site by the vendor to correct transit damage or faulty
workmanship will be supervised by the Construction Authority.
b)
Installation shall be carried out under supervision of the Construction
Authority.
c)
On completion of construction activities, the Construction Authority shall
advise the Technical Integrity Authority accordingly. Where required, the
Technical Integrity Authority shall witness all inspections and tests which
are to be recorded, unless the Technical Integrity Authority waives this
requirement.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 3
The Technical Integrity Authority shall monitor construction activities
wherever possible, so that inspection and testing can be carried out as
work proceeds.
d)
Following the satisfactory completion of inspection and testing, the
Construction Authority shall complete the relevant records, which shall
be witnessed by the Technical Integrity Authority as appropriate.
No further work shall be carried out by construction on this completed
plant unless by agreement with the Technical Integrity Authority.
e)
Vendor’s assistance may be required during the pre-commissioning
and/or commissioning of HVAC systems.
f)
Where required testing of HVAC systems will be witnessed by the
Technical Integrity Authority.
6.1.3
Use Of Forms
a)
General Requirements
For all HVAC works, all recording of inspection and tests shall be on the
©
In addition to the SP2 HVAC System
GOC standard forms.
Performance Test Certificate, the Technical Integrity Authority is
particularly interested in the following test recording sheets and they will
have to be retained and attached to the SP2 - System Performance Test
Certificate.
i)
ii)
iii)
iv)
TR1
TR2
TR16
TR17
HVAC System Installation & Function Test Certificate
Fire Dampers Tests.
Smoke Test.
Room Pressurization Test (Part 1).
All remaining rest record sheets are completed and used as part of the
assessment process to establish if the HVAC system as a whole meets
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 4
design criteria. When this is established and the SP2 is approved then
the TR’s are superfluous and may be discarded with the exception of the
TR1, TR2, TR16 and TR17.
b)
SP2: System Performance Test Certificate
To be used by the Technical Integrity Authority to record satisfactory
completion of HVAC installation and tests by individual sections.
c)
PL1: Punchlist
To be used by Construction/Technical Integrity Authority by discipline, to
record outstanding items/defects on installation
Construction, prior to any Commissioning activities.
d)
completion
by
Test Recording Sheet No. 1: TR1
To be used by the Technical Integrity Authority for collating instrument
installation and function test data.
e)
Test Recording Sheet No. 2: TR2
To be used by the Technical Integrity Authority for collating Damper Test
data.
f)
Test Recording Sheet No. 3: TR3
To be used by the Technical Integrity Authority for collating Filter/
Coalescer/ Separator Test data.
g)
Test Recording Sheet No. 4: TR4
To be used by Technical Integrity Authority for collating Heating Coil test
data.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
h)
MECHANICAL - HVAC
PAGE: 5
Test Recording Sheet No. 5: TR5
To be used by the Technical Integrity Authority for collating Centrifugal
Fan Test data.
i)
Test Recording Sheet No. 6: TR6
To be used by the Technical Integrity Authority for collating Humidifier
Test data.
j)
Test Recording Sheet No. 7: TR7
To be used by the Technical
Integrity Authority for collating Constant Volume/ Terminal Re-Heat Unit
Test data.
k)
Test Recording Sheet No. 8: TR8
To be used by the Technical Integrity Authority for collating Terminal Air
Conditioning Unit Test data.
l)
Test Recording Sheet No. 9: TR9
To be used by the Technical Integrity Authority for collating Air Handling
Unit Test Unit Test data.
m)
Test Recording Sheet No. 10: TR10
To be used by the Technical Integrity Authority for collating Cooling Coil
Test data.
n)
Test Recording Sheet No. 11: TR11
To be used by the Technical Integrity Authority for collating Cooling
Tower Test data.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
o)
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 6
Test Recording Sheet No. 12: TR12
To be used by the Technical Integrity Authority for collating Grille &
Diffuser Test data.
p)
Test Recording Sheet No. 13: TR13
To be used by the Technical Integrity Authority for collating Ductwork Air
Leakage’s Rate Test data.
q)
Test Recording Sheet No. 14: TR14
To be used by the Technical Integrity Authority for collating System
Balance Test data.
r)
Test Recording Sheet No. 15: TR15
To be used by the Technical Integrity Authority for collating Internal
Conditions Test data.
s)
Test Recording Sheet No. 16: TR16
To be used by the Technical Integrity Authority for collating Smoke Test
data.
t)
Test Recording Sheet No. 17: TR17
To be used by the Technical Integrity Authority for collating Room
Pressurization data.
u)
Test Recording Sheet No. 18: TR18
To be used by the Technical Integrity Authority for collating
Pressurization Unit Test data.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 7
6.1.4
Calibration
a)
Any test equipment, whether in-house or vendor supplied, used in the
pre-commissioning and/or commissioning of HVAC systems, shall be
accompanied by current Calibration Certificate stating that the test
equipment has been calibrated to specified limits within the specified
time limits.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
HVAC PROCEDURES
Procedure No. 6.1 - General Requirements
Procedure No. 6.2 - Dampers
Procedure No. 6.3 - Filtration
Procedure No. 6.4 - Heating and Cooling Coils
Procedure No. 6.5 - Centrifugal Fans and Drivers
Procedure No. 6.6 - Humidifiers
Procedure No. 6.7 - Terminal Units, Grills & Diffusers
Procedure No. 6.8 - Air Conditioning Units
Procedure No. 6.9 - Air Handling Unit
Procedure No. 6.10 - Ductwork
Procedure No. 6.11 - Sound Attenuators
Procedure No. 6.12 - Cooling Towers
Procedure No. 6.13 - Areas Receiving HVAC Supply
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
PAGE: 8
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 9
Procedure No. 6.1
1.1
General Requirements
1.1.1
General
This Procedure lays down the checks that are required to ensure that the overall
system is per project specifications and correctly installed prior to carrying out
specific checks on individual parts of the installation.
The Following points are to be checked:
a)
Check supplied equipment for damage.
b)
Check that nameplate is in a readable location and that the data
corresponds with the relevant equipment index/specification/data
sheet/drawing with regard to identification/tag number ratings and other
data.
c)
Check that equipment has been installed as per the specifications,
Issued for Construction (IFC) drawings and vendors instructions.
d)
By reference to the area classification drawing, check the classification of
locations where electrical equipment is installed and ensure that
equipment installed in hazardous locations carries the appropriate
certification.
e)
Ensure that the applicable installation procedures, inspections, and tests
have been carried out for mechanical, electrical and control equipment,
compressors, fans, pumps, motors, cabling switchgear, instruments, etc.
Refer to the appropriate section of the GOC© for guidance i.e.,
Mechanical Section 3.0, Control Section 8.0 and Electrical Section 9.0.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
f)
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
Ensure that equipment is properly grounded:
PAGE: 10
measure ground path
resistance in accordance with the relevant Electrical Procedures
reference in Section 9.0.
g)
Ensure that painting (Section 7) has been carried out in accordance with
the project painting specification or to the manufacturers own agreed
application, and that no damage has occurred during installation.
h)
Check that there is adequate space to maintain/inspect the equipment.
i)
Check that the equipment is internally and externally clean.
1.1.2
Certification
a)
With reference to e) above the relevant discipline inspection and test
certificates shall be used to record that the applicable installation
procedures, inspection and tests have been carried out and are
acceptable.
The SP2 Test Certificate shall be used for all HVAC procedures as
detailed in this section, any items of non-conformance should be
indicated on the particular certificate, relating to that part of the
installation concerned, and also be fully identified on the relative
discipline punchlist, Form PL1.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 11
Procedure No. 6.2
2.1
Dampers
2.1.1
General
This procedure lays down the checks/tests that are required to ensure that all
types of dampers in the HVAC system are per project specifications, correctly
certified and installed correctly.
Although the Technical Integrity Authority (TI) may demand additional tests for
fire dampers, the following points are to be checked:
a)
Carry out the relevant checks listed in Procedure No. 6.1 - General
Requirements.
b)
Check that access doors adjacent to the dampers are installed where
applicable.
c)
Check that the damper blade clearance and sealing is satisfactory.
d)
Check that the damper blades move freely.
e)
Check that the blade position external indicator is fitted and gives correct
indication.
f)
Check that the blade position locking quadrant is satisfactory.
g)
Check that movement of the damper corresponds to the type of control
called for in the specification.
h)
Check that the damper blades are adequately supported where damper
width exceeds 40 in.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
i)
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 12
Check that the blades are enclosed within the casing with the damper in
the fully open position.
j)
Check that the damper actuators are free to move and suitably enclosed.
k)
Ensure that damper controls move freely and are unobstructed for the
purpose of routine maintenance and periodic certification inspections.
l)
Check that the local hand lever moves freely.
m)
Check visually that the damper is adequately supported and that the
correct specification gaskets are fitted to the connecting ductwork.
Ensure that the damper is bolted correctly and that any dissimilar metal
isolation is achieved.
n)
Ensure that where required, the integrity of the bulkhead penetration is
maintained. Ensure penetration has been properly sealed with fire
stopping.
o)
Ensure that the tension spring is fitted, and that there is adequate space
via the enclosure access plate to maintain tension spring adjustment for
pressure setting.
p)
Check that the damper is internally clean and is left in the fully open
position.
q)
Check that the access cover to the enclosure has been replaced.
r)
Check that the limit switches actuation is satisfactory.
s)
Check that instrument air supply tubing & piping is correctly fitted and
function correctly.
t)
Check that the mechanical reset mechanism re-opens electric dampers.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
u)
MECHANICAL - HVAC
PAGE: 13
Check that a fusible link of the correct rating is fitted and accessible, and
that the damper closes and seals correctly.
Caution: Dampers are typically spring loaded and rapid closing!
v)
Check that the insulation, fire rated where specified, has been correctly
fitted after ensuring that the damper material and finish are to
specification and undamaged.
w)
Ensure that the fire dampers carry appropriate fire resistance test
certificates and UL/NRTL listing and label.
x)
Ensure that where appropriate, dampers carry Technical Integrity
Authority (TI) certification.
2.1.2
Damper Test
a)
Test recording sheet No. 2 (TR2) is provided for collation of test data, to
enable subsequent signing of the applicable part of the SP2 Test
Certificate.
2.1.3
Certification
a)
Form HVAC; TR2 shall be completed by the BP HVAC Representative
and/or Vendor as appropriate, to record that all necessary inspections
and tests relevant to either type of damper, have been carried out
satisfactorily, to the requirements of HVAC Procedures 6.1 & 6.2. Any
deviation to Design/Operating Parameters and Vendor instructions shall
be recorded on the Test Record Sheet.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 14
Procedure No. 6.3
3.1
Filtration
3.1.1
General
This procedure lays down the checks/tests that are required to ensure that the
air filters and filter/coalescers are per project specifications and are correctly
installed.
The following points are to be checked as appropriate to the subject item of
equipment.
a)
Carry out the relevant checks listed in Procedure 6.1 - General
Requirements.
b)
Check visually that the equipment is adequately supported and that the
correct specification gaskets are fitted to the connecting ductwork.
Ensure that the equipment is bolted correctly and that any dissimilar
metal isolation is achieved.
c)
Check that the filter elements and removal guide rails have been
properly installed and ensure that there is adequate space to
maintain/remove filters.
d)
Check that access doors adjacent to the unit have been installed where
applicable.
e)
Check that the differential pressure indicator is located in a readable
position and that all associated pipework is installed correctly.
f)
Check that the spray nozzles are clean.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
g)
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 15
Check that drain connections and traps are located correctly and free of
blockages and restrictions, and that traps can be visually checked for
water level.
h)
Check that heat trace has been installed if required and that it has been
inspected in accordance with the relevant Electrical Procedures (Section
9.0).
3.1.2
Filter/Coalescer/Separator Test
a)
Test recording sheet No. 3 (TR3) is provided for collation of test data, to
enable subsequent signing of the applicable part of the SP2 Test
certificate.
3.1.3
Certification
a)
Form HVAC; TR3 shall be completed by the BP HVAC Representative
and/or Vendor as appropriate, to record that all necessary inspections
and tests relevant to the subject equipment type have been carried out
satisfactorily, to the requirements of HVAC Procedures 6.1 & 6.3. Any
deviation to the Design/Operating Parameters and Vendor instructions
shall be recorded on the Test Recording Sheet.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 16
Procedure No. 6.4
4.1
Heating and Cooling Coils
4.1.1
General
This Procedure lays down the checks/tests that are required to ensure that the
Heating and Cooling Coils are per project specifications and correctly installed.
The following points are to be checked as appropriate to the subject item of
equipment:
a)
Carry out the relevant checks listed in Procedure 6.1 - General
Requirements.
b)
Check visually that the Heating and Cooling Coils are adequately
supported and that correct specification gaskets have been fitted to
connection ductwork. Ensure that components are bolted/fixed correctly
and that any dissimilar metal isolation is achieved.
c)
Check that heating elements are clean, undamaged and readily
accessible, and ensure that adequate space has been provided for
element withdrawal/maintenance.
d)
Check that the cooling coil has been correctly installed, is undamaged,
and that it is level and complete with guide rails to slide the coil section
out of its holding frame. Ensure that adequate space is provided for coil
withdrawal.
e)
Ensure that the high air temperature and high element temperature cutout thermostats are of the correct type and are accessible for
resetting/maintenance where applicable.
f)
Check that all electrical connections to the heater have been terminated
correctly and that all associated cables have been inspected and tested
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 17
in accordance with the Electrical Procedures (Section 9.0). Ensure that
the terminal box access cover is readily accessible.
g)
Check access cover installed in ductwork adjacent to heater.
h)
Check that distributors and all pipework has been correctly connected
and that all interior connections are clean.
i)
Check that drain pan is correctly fitted, and if the coil is split vertically,
ensure that both sections have pans fitted.
j)
Check that interconnecting pipework between upper and lower drain
pans is installed and that a drain trap is correctly fitted with pipework
routed to a suitable discharge.
k)
Check air venting facility if fitted.
4.1.2
Heating and Cooling Coil Tests
a)
Test recording sheet No. 4 (TR4) is provided for collation of Heating Coil
test data, and No. 10 (TR10) for Cooling Coil test data, to enable
subsequent signing of the applicable parts of the SP2 Test Certificate.
4.1.3
Certification
a)
Form HVAC; TR4 shall be completed by the BP HVAC Representative
and/or Vendor as appropriate, to record that all necessary inspections
and tests relevant to the subject equipment type have been carried out
satisfactorily, to the requirements of HVAC Procedures 6.1 & 6.4. Any
deviation to the Design/Operating Parameters and Vendor instructions
shall be recorded on the Test Recording Sheet.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 18
Procedure No. 6.5
5.1
Centrifugal Fans and Drivers
5.1.1
General
This procedure lays down the checks/tests that are required to ensure that the
centrifugal fans and their drivers are per project specifications and have been
correctly installed.
a)
Carry out the relevant checks listed in Procedure No. 6.1 - General
Requirements.
b)
Check visually that the fan assembly is adequately supported and that
the correct specification gaskets are fitted to the connecting ductwork.
Ensure that all components are bolted/fixed securely and that any
dissimilar metal isolation is achieved.
c)
Check that fan and motor are correctly mounted in the right angular
position, and that the motor is level and aligned with the specified drive
fitted. Ensure that the motor has been inspected in accordance with the
Electrical Procedures (Section 9.0).
d)
Check that vibration isolators are installed and adjusted correctly for the
specified deflection. Make sure shipping locks are removed.
e)
Check that inlet/outlet flexible connections are correctly fitted and do not
take up offsets.
f)
Check that all internal shipping brackets/packings have been removed
and that fan is internally and externally clean.
g)
Check that fan and motor bearings are lubricated and that the grease
nipples are accessible.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
h)
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 19
Remove fan belt drive guard and visually check fan shaft level and
bearing alignment. Ensure that belts are correctly tensioned.
i)
Check free rotation of fan impeller, key secure and clearance
satisfactory.
j)
Check that there is adequate space to withdraw impeller or motor
assembly for maintenance.
k)
Check that fan belt guard is lined with nonferrous material.
l)
Check that fan guards are fitted securely.
m)
Check that the manually operated inlet guide vane control damper has
been correctly fitted and that it has been inspected in accordance with
Procedure 6.2.
n)
Check that the outlet non-return damper has been correctly fitted and
that it has been inspected in accordance with Procedure 6.2.
o)
Check direction of rotation is correct.
p)
Verify AMCA B non-sparking construction, as applicable. Confirm
absence of rubbing parts and/or possible contact between moving and
stationary parts.
5.1.2
Centrifugal Fans and Drivers Test
a)
Test recording sheet No. 5 (TR5) is provided for collation of test data, to
enable subsequent signing of the applicable part of the SP2 Test
Certificate.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 20
5.1.3
Certification
a)
Form HVAC; TR5 shall be completed by the BP HVAC Representative
and/or Vendor as appropriate, to record that all necessary inspections
and tests relevant to the subject equipment type have been carried out
satisfactorily, to the requirements of HVAC Procedures 6.1 & 6.5. Any
deviation to the Design/Operating Parameters and Vendor instructions
shall be recorded on the Test Recording Sheet.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 21
Procedure No. 6.6
6.1
Humidifiers
6.1.1
General
This procedure lays down the checks/tests that are required to ensure that the
humidifiers are per project specifications and correctly installed.
The following points are to be checked on all humidifiers:
a)
Carry out the relevant checks listed in Procedure 6.1 - General
Requirements.
b)
Check visually that mounting arrangements and supports to the
humidifier and steam injection duct are adequate.
c)
Check that steam injection duct is installed to the manufacturers
recommendations and that it drains back to the humidifier.
d)
Check that all ductwork is bolted correctly and that flanged connections
have correct specification gaskets fitted.
e)
Check that balance pipe from humidifier to ductwork is installed and
properly sealed.
f)
Check that utility pipework connections to humidifier are correctly
installed and adequately supported.
g)
Check that the water inlet valve is fitted and operating correctly.
h)
Ensure that drain and overflow are fitted and piped to a suitable drain.
i)
Ensure that there is adequate space to maintain humidifier internals (i.e.
water storage tank/steaming chamber etc.)
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
j)
MECHANICAL - HVAC
PAGE: 22
Check that the heating elements are clean, undamaged and readily
accessible.
k)
Check that the water and heater thermostats are fitted within the
humidifiers integral electrical compartment and that a removable access
cover is provided.
l)
Check that the water level in the storage tank is correct and that the level
gauge reads correctly.
m)
Ensure that adjacent ductwork connections and traps are located
correctly, are free of blockages and restrictions, and traps can be visually
checked for water level.
n)
Check that the humidifiers are operable for the duct pressure (water
lock).
6.1.2
Humidifier Test
a)
Test recording sheet No. 6 (TR6) is provided for collation of test data, to
enable subsequent signing of the applicable part of the SP2 Test
Certificate.
6.1.3
Certification
a)
Form HVAC; TR6 shall be completed by the BP HVAC Representative
and/or Vendor as appropriate, to record that all necessary inspections
and tests relevant to the subject equipment type have been carried out
satisfactorily, to the requirements of HVAC Procedures 6.1 & 6.6. Any
deviation to the Design/Operating Parameters and Vendor instructions
shall be recorded on the Test Recording Sheet.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 23
Procedure No. 6.7
7.1
Constant Volume/Terminal Re-Heat Units, Grills & Diffusers
7.1.1
General
This Procedure lays down the checks/tests that are required to ensure that the
units are per project specifications and correctly installed.
The following points are to be checked on all Terminal Units, Grilles and
Diffusers:
a)
Carry out the relevant checks listed in Procedure No. 6.1 - General
Requirements.
b)
Check visually that the Terminal Re-Heat Unit is properly aligned,
adequately supported, and that the correct specification gaskets have
been fitted to the connecting ductwork, ensuring that components are
bolted/fixed correctly and that any dissimilar metal isolation is achieved.
c)
Check the free movement of valve linkage mechanism and ensure it is
pre-set for the correct pressure drop rating.
d)
Check that there is adequate space to maintain the constant volume
control valve via the access cover to damper section.
e)
Check that internal acoustic lining has been installed to prevent noise
breakout.
f)
Check that heating elements are undamaged, readily accessible, and
ensure that adequate space has been provided for element
withdrawal/maintenance.
g)
Ensure that the high air temperature and high element temperature
cutout thermostats are accessible for resetting/maintenance.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 24
h)
Check that the unit is internally clean and free from moisture.
7.1.2
Constant Volume/Terminal Re-Heat Units Test
a)
Test recording sheet No. 7 (TR7) is provided for collation of test data, to
enable subsequent signing of the applicable part of the SP2 Test
Certificate.
7.1.3
Grilles and Diffusers Test
a)
Test recording sheet No. 12 (TR12) is provided for collation of test data,
to enable subsequent signing of the applicable part of the SP2 Test
Certificate.
7.1.4
Certification
a)
Form HVAC; TR7 and TR12 for Constant Volume/Terminal Re-Heat
Units and Grilles and Diffusers shall be completed by the BP HVAC
Representative and/or Vendor as appropriate, to record that all
necessary inspections and tests relevant to the subject equipment type
have been carried out satisfactorily, to the requirements of HVAC
Procedures 6.1 & 6.7.
Any deviation to the Design/Operating
Parameters and Vendor instructions shall be recorded on the Test
Recording Sheet.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 25
Procedure No. 6.8
8.1
Air Conditioning Units
8.1.1
General
This procedure lays down the checks/tests that are required to ensure that Air
Conditioning Units are per project specifications and correctly installed.
The following points are to be checked on all Air Conditioning Units:
a)
Carry out the relevant checks listed in Procedure No. 6.1 - General
Requirements.
b)
Check visually that the unit is adequately supported and that the correct
specification gaskets are fitted to the connecting ductwork. Ensure that
the equipment is bolted correctly and that any dissimilar metal isolation is
achieved.
c)
Check that the fans and compressors are installed correctly with
reference to Procedure 6.5 - Centrifugal Fans and Drivers (in the case of
compressors - for fan read compressor).
d)
Check that the filters are installed correctly with reference to Procedure
6.3 - Filtration.
e)
Check that all pipework connections are correct and adequately
supported.
f)
Check that the drain pan and drain pipes are installed correctly and that
the drains are routed to a suitable location.
g)
Ensure that all inspection doors, hatches and locks are operable.
h)
Ensure that all valves are operable.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
i)
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 26
Check that all insulation is to specification and correctly fitted and free of
damage.
j)
Check that refrigeration charge is within specifications.
8.1.2
Terminal Air Conditioning Unit Test
a)
Test recording sheet No. 8 (TR8) is provided for collation of test data, to
enable subsequent signing of the applicable part of the SP2 Test
Certificate.
8.1.3
Certification
a)
Form HVAC; TR8 shall be completed by the BP HVAC Representative
and/or Vendor as appropriate, to record that all necessary inspections
and tests relevant to the subject equipment type have been carried out
satisfactorily, to the requirements of HVAC Procedures 6.1, 6.3 & 6.5.
Any deviation to the Design/Operating Parameters and Vendor
instructions shall be recorded on the Test Recording Sheet.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 27
Procedure No. 6.9
9.1
Air Handling Unit
9.1.1
General
This procedure lays down the checks/tests that are required to ensure that Air
Handling Units are per project specifications and correctly installed.
The following points are to be checked on all Air Handling Units:
a)
Carry out the relevant checks listed in Procedure No. 6.1 - General
Requirements.
b)
Check that the Air Handling Units skid base holding down arrangement is
correct.
c)
Check visually that all components are properly fitted together and that
any dissimilar metal isolation is achieved.
d)
Check that all equipment installed within the Air Handling Unit is checked
against the following procedures:
i)
ii)
Fans
Shut-off Dampers
HVAC Procedure No. 6.5
HVAC Procedure No. 6.2
iii)
iv)
Heating and Cooling Coils
Filters
HVAC Procedure No. 6.4
HVAC Procedure No. 6.3
e)
Check that all Ductwork connections to unit have the correct specification
gasket fitted.
f)
Check that the Air Handling Unit equipment compartment sections are
fitted with light fixtures as indicated in the project specification, and
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 28
ensure the cabling and fittings are tested and inspected in accordance
with the Electric Procedures.
g)
Check that inspection/access doors have been provided for the individual
equipment compartments and that all handles, catches and locks are
operable.
9.1.2
Air Handling Unit Test
a)
Test recording sheet No. 9 (TR9) is provided for collation of test data, to
enable subsequent signing of the applicable part of the SP2 Test
Certificate.
9.1.3
Certification
a)
Form HVAC; TR9 shall be completed by the BP HVAC Representative
and/or Vendor as appropriate, to record that all necessary inspections
and tests relevant to the subject equipment type have been carried out
satisfactorily, to the requirements of HVAC Procedures 6.1, 6.2, 6.3, 6.4,
6.5 & 6.9. Any deviation to the Design/Operating Parameters and
Vendor instructions shall be recorded on the Test Recording Sheet.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 29
Procedure No. 6.10
10.1
Ductwork
10.1.1 General
This procedure lays down the checks and tests that are required to ensure that
the system ductwork is per project specifications and correctly installed.
The following points are to be checked on all system ductwork:
a)
Carry out the relevant checks listed in Procedure 6.1 - General
Requirements.
b)
Ensure that ductwork systems are clearly identified and marked with
directional flow arrows.
c)
Check flexible connections have been fitted and sealed correctly.
Ensure that no flexible connection has been used to take up misalignment between sections of ductwork or connections to plant
equipment.
d)
Check that the correct jointing and sealants have been used as specified
in the project specification.
e)
Check that all flanged ductwork joints are bolted correctly and correct
specification gaskets fitted.
f)
Check that location of ductwork doors/panels/hatches are correct and
that they are properly fastened and sealed.
g)
Check that all stiffening and turning vanes have been correctly installed.
h)
Check that instrument test holes have been drilled and suitably plugged.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
i)
MECHANICAL - HVAC
PAGE: 30
Check that ductwork is supported correctly and that all ductwork is
insulated from supports. Ensure insulator blocks are fitted to all supply
ductwork.
j)
Ensure any dissimilar metal isolation is achieved.
k)
Check that all diffusers and grilles are installed and sealed correctly, and
that diffusers/grilles and their associated volume control dampers are left
in the open position.
l)
Check that all intake and discharge louvers have been installed correctly
and that any necessary bird mesh protection screens have been fitted.
m)
Check that ductwork systems are internally clean and that no internal
damage exists.
n)
Check that the air filter racks are fitted.
o)
Check that the fire dampers are installed in their correct location and that
the correct fusible links have been fitted.
p)
Check that the filter/coalescer is loaded, separators clean, drains piped
and traps functioning.
q)
Check that all sound attenuators are correctly installed.
r)
Ensure that the material, protective coatings/finish of ducting is in
accordance with project specifications and in an undamaged condition.
s)
Ductwork systems shall be leak tested in accordance with the HVAC test
classes as laid down in the project specifications and HVAC Procedure
6.13.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
t)
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 31
Ductwork shall be insulated in accordance with project specifications.
External insulation should be applied only after ensuring that a duct
leakage rate test certificate has been accepted and signed.
10.1.2 Certification
a)
Form SP2 shall be completed by the BP HVAC Representative and/or
Vendor as appropriate, to record that all necessary inspections and tests
relevant to system Ductwork have been carried out satisfactorily, to the
requirements of HVAC Procedures 6.1, 6.10 & 6.11, and within the
Design/Operating Parameters and Vendor instructions.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 32
Procedure No. 6.11
11.1
Sound Attenuators
11.1.1 General
This procedure lays down the checks that are required to ensure that the Sound
Attenuators are per project specifications and correctly installed.
The following points are to be checked on all Sound Attenuators:
a)
Carry out the relevant checks listed in Procedure 6.1 - General
Requirements.
b)
Check location and orientation of the Sound Attenuator is correct, and
ensure that the unit is installed for the correct air flow direction.
c)
Check that the Sound Attenuator is adequately supported, that the
correct specification gaskets are fitted to the connecting ductwork,
ensuring that the unit is bolted correctly and that any dissimilar metal
isolation is achieved.
d)
Check that the Sound Attenuator is internally clean. Ensure that no
damage exists to the acoustic lining or splitters, and that no moisture has
entered the unit.
e)
Check that the fire/thermal insulation has been correctly fitted after
ensuring that the Sound Attenuator material and finish are to
specification, and that no damage has occurred during installation.
f)
Verify that installation configuration complies with manufacturer’s
instructions and airflow direction.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 33
11.1.2 Certification
a)
Form SP2 shall be completed by the BP HVAC Representative and/or
Vendor as appropriate, to record that all necessary inspections and tests
relevant to the Sound Attenuators have been carried out satisfactorily, to
the requirements of HVAC Procedures 6.1 & 6.11, and within the
Design/Operating Parameters and Vendor information.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 34
Procedure No. 6.12
12.1
Cooling Tower
12.1.1 General
This Procedure lays down the checks/tests that are required to ensure
that the Cooling Towers are per project specifications and are correctly
installed.
The following points are to be checked on all Cooling Towers:
a)
Carry out the relevant checks listed in Procedure 6.1 - General
Requirements.
b)
Fan Section: Refer to HVAC Procedure No. 6.5 - Centrifugal Fans and
Drivers.
c)
Coil Section: Check that the spray nozzles are clean and that the
eliminators are undamaged.
d)
Pan Section:
undamaged.
e)
Check that spray pump is aligned and rotation is correct.
f)
Check that water level is correct.
g)
Check that the bleed line is operational.
h)
Check that strainer is clean.
i)
Check that corrosion inhibitor is installed.
j)
Check that the water make-up valve is open and float operational.
GOC©
Check that the immersion heater is installed and
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 35
12.1.2 Cooling Tower Test
a)
Test recording sheet No. 11 (TR11) is provided for collation of test data,
to enable subsequent signing of the applicable part of the SP2 Test
Certificate.
12.1.3 Certification
a)
Form SP2 shall be completed by the BP HVAC Representative and/or
Vendor as appropriate, to record that all necessary inspections and tests
relevant to the Cooling Towers have been carried out satisfactorily, to the
requirements of HVAC Procedures 6.1, 6.5 & 6.12, and within the
Design/Operating Parameters and Vendor information.
12.1.4 Pipework
a)
Ensure that all associated pipework has been fabricated, inspected and
tested in accordance with the project specification. Refer to the Pipe
Testing Section 3.0.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
MECHANICAL - HVAC
PAGE: 36
Procedure No. 6.13
13.1
Areas Receiving HVAC Supply
13.1.1 General
The following HVAC tests will be required to be carried out by an HVAC
Vendor/Engineer and the results recorded, to ensure that all necessary
inspections and tests have been carried out. Any deviation to the
Design/Operating Parameters and Vendor instructions shall be recorded
on the appropriate Test Record Sheet.
13.1.2 Ductwork Leakage Rate Test
Test recording sheet No. 13 (TR13) is provided for collation of test data,
to enable subsequent signing of the applicable part of the SP2 Test
Certificate.
13.1.3 System Balance Test
Test recording sheet No. 14 (TR14) is provided for collation of test data,
to enable subsequent signing of the applicable part of the SP2 Test
Certificate.
13.1.4 Grille and Diffuser Test
Test recording sheet No. 12 (TR12) is provided for collation of test data,
to enable subsequent signing of the applicable part of the SP2 Test
Certificate.
13.1.5 Internal Conditions Test
Test recording sheet No. 15 (TR15) is provided for collation of test data,
to enable subsequent signing of the applicable part of the SP2 Test
Certificate.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
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PAGE: 37
13.1.6 Smoke Test of Pressurized Room & Areas Protected by a Gaseous
Inerting Agent
Test recording sheet No. 16 (TR16) is provided for collation of test data,
to enable subsequent signing of the applicable part of the SP2 Test
Certificate.
13.1.7 Room Pressurization Tests (Parts 1 & 2)
Test recording sheet No. 17 (TR17) is provided for collation of test data,
to enable subsequent signing of the applicable part of the SP2 Test
Certificate.
13.1.8 Room Pressurization Unit Test
Test recording sheet No. 18 (TR18) is provided for collation of test data,
to enable subsequent signing of the applicable part of the SP2 Test
Certificate.
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
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PAGE: 38
Flowchart 6
•
•
Functional Certification Flowchart
Discipline: Mechanical (HVAC)
MM1
MM1:
MC1:
SP2:
SH1:
MC1
SP2
SH1
Machinery Installation Certificate
Mechanical Completion Certificate
System Performance Test(s)
System Handover Certificate
Note! Where Welding is carried out an MW1 - Welding Completion
Summary is required - Refer to GOC© Section 2
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 6.0
GOC© AMERICAS EDITION
REVISION: 1
MECHANICAL - HVAC
PAGE: 39
EXHIBIT 6
STANDARD FORMS
Form No.
Form & Test Record Title
SP2
System Performance Test
TR1
Control Installation & Function Test Certificate
TR2 - 18
HVAC Installation & Test Record
(General HVAC Certificate to cover activities TR2 - TR18)
DIS4
Data Input Sheet 4 – Section 6 HVAC
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM SP2
SITE:
HVAC - SYSTEM PERFORMANCE CERTIFICATE
EQUIPMENT No :
SHT
OF
EQUIPMENT DESCRIPTION :
LOCATION :
SYSTEM :
TEST
RECORDING
SHEET No
TESTS
APPLICABLE
INSTRUMENTATION
TR1
YES/NO *
YES/NO *
6.1 & 6.2
DAMPERS
TR2
YES/NO *
YES/NO *
6.1 & 6.3
FILTRATION
TR3
YES/NO *
YES/NO *
6.1 & 6.4
HEATING & COOLING COILS
TR4
YES/NO *
YES/NO *
6.1 & 6.5
CENTRIFUGAL FANS
TR5
YES/NO *
YES/NO *
6.1 & 6.6
HUMIDIFIERS
TR6
YES/NO *
YES/NO *
6.1 & 6.7
TERMINAL RE-HEAT UNITS
TR7
YES/NO *
YES/NO *
6.1,6.3, 6.5 & 6.8
AIR CONDITIONING UNITS
TR8
YES/NO *
YES/NO *
1, 2, 3, 4, 5 & 9
AIR HANDLING UNITS
TR9
YES/NO *
YES/NO *
6.1,6.10 & 6.11
DUCTWORK & ATTENUATORS
YES/NO *
YES/NO *
PROCEDURE
Nos.
SECTION 8.0
6.1 & 6.4
DESCRIPTION
CONFORMITY ACCEPTANCE
CHECK
REVIEWED
DATE
COOLING COILS
TR10
YES/NO *
YES/NO *
6.1 -6.5 & 6.12
COOLING TOWERS
TR11
YES/NO *
YES/NO *
6.1 -6. 7 & 6.13
GRILLES & DIFFUSERS
TR12
YES/NO *
YES/NO *
6.13
AIR LEAKAGE RATE
TR13
YES/NO *
YES/NO *
6.13
SYSTEM BALANCE
TR14
YES/NO *
YES/NO *
6.13
INTERNAL CONDITIONS
TR15
YES/NO *
YES/NO *
6.13
SMOKE TEST
TR16
YES/NO *
YES/NO *
6.13
ROOM PRESSURIZATION
TR17
YES/NO *
YES/NO *
6.13
PRESSURIZATION UNIT
TR18
YES/NO *
YES/NO *
THIS CERTIFICATE SHALL BE COMPLETED BY THE BP HVAC COMMISSIONING REPRESENTATIVE AND/OR VENDOR
AS APPROPRIATE, TO RECORD THAT ALL NECESSARY INSPECTIONS AND TESTS HAVE BEEN CARRIED OUT
SATISFACTORILY, TO THE REQUIREMENTS OF THE HVAC PROCEDURES AND WITHIN DESIGN/OPERATING
PARAMETERS AND VENDOR INSTRUCTIONS. ANY VARIANCE SHALL BE DETAILED ON THE APPROPRIATE TEST
RECORD SHEET AND ATTACHED TO THIS CERTIFICATE.
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* DELETE AS APPLICABLE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
Work Pack No:
FORM TR1
Maintenance No:
(SIDE 1)
FUNCTION TEST REQUIRED? *YES / NO
SH1 No:
SITE:
(IF YES, COMPLETE SIDE 2)
MC1 No:
HVAC SYSTEM - CONTROL COMPLETION CERTIFICATE & FUNCTION TEST CERTIFICATE
SHT
P&ID No:
OF
YES
NO
Loop Diagram Drawing No:
Equipment Installed as per Design (If No, Raise an EQ)
Area Classification Check - Electrical Procedure 9.15 Complete
YES
NO
N/A
Process Hook-Up Drawing No:
Junction Box Inspection
YES
NO
N/A
Pneumatic Hook-Up Drawing No:
Orifice Plate Measurement Completed (where appropriate)
YES
NO
N/A
Instrument Tie-in Point Number:
Orifice Plate Measurement : Diameter
NDE Location Drawing No:
YES
NO
Impulse Line Welding *YES/NO if YES - is MW1 Complete? *YES/NO
- Electrical Procedure 9.19 Complete
ins /
Check Flatness
Record All Deviations/Comments:
Loop Number
Tag Number
Procedure No.
8.1
Completed By
Procedure No. 8.1
8.2
Manufacturer
Model & Serial No
Data Sheet No
Calibrated
Range/Setting
Procedure No. 8.3
Asset Specific Procedure
Approved By
8.3
Procedure No. 8.2
Company
Signature
Print Name
Date
•
DELETE AS APPLICABLE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
HVAC - SYSTEM CONTROL FUNCTION TEST RECORD
EQUIPMENT No :
FORM TR1
(SIDE 2)
EQUIPMENT DESCRIPTION :
LOCATION :
SYSTEM :
COMMISSIONING PROCEDURE NO :
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM TR 2 - 18
SITE:
HVAC - INSTALLATION & TEST RECORD
EQUIP / TAG No :
SHT
OF
LOCATION:
CIRCLE BELOW THE TEST RECORDS (TRs) THIS REPORT COVERS
TR2 TR3 TR4 TR5 TR6 TR7 TR8 TR9 TR10 TR11 TR12 TR13 TR14 TR15 TR16 TR17 TR18
DESCRIPTION :
REPORT AND TEST RESULT:
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
DIS4 SHEET
J.P
NO.
LOCATION : __________________
DATA INPUT SHEET 4
PROJECT : __________________
SECTION 6 - HVAC
HANDOVER ID
DESCRIPTION
EQUIP
NUMBER
TAG
NUMBER
DRAWING
NUMBER
RAISED BY: __________________________________
DATE : ____________________
NOTE: JP No FOR INSTALLATION / TESTING
GOC
OF
WORKSCOPE ID : ___________________
MAINTENANCE ID No : ______________
ASBUILT
REQ'D
(LAD)
SPECIFY
SP2
TEST
RECORD
SPECIFY
SP2
TEST
RECORD
SPECIFY
SP2
TEST
RECORD
SPECIFY
SP2
TEST
RECORD
SPECIFY
SP2
TEST
RECORD
DATA ENTERED BY : ____________________
© BP Exploration 1989 - 2001 All Rights Reserved
SPECIFY
SP2
TEST
RECORD
SPECIFY
SP2
TEST
RECORD
DATE : ___________
Americas Rev. 1
GUIDANCE ON CERTIFICATION
GOC© AMERICAS EDITION
SUBJECT:
MECHANICAL - ARCHITECTURAL SERVICES
(PAINTING, COATING AND INSULATION)
SECTION 7.0
ARCHITECTURAL SERVICES
(PAINTING, COATING AND INSULATION)
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
SECTION 7.0
REVISION: 1
PAGE: 1
GUIDANCE ON CERTIFICATION
GOC© AMERICAS EDITION
SUBJECT:
MECHANICAL - ARCHITECTURAL SERVICES
(PAINTING, COATING AND INSULATION)
SECTION 7.0
REVISION: 1
PAGE: 2
7.1
ACTIONS
7.1.1
General
a)
This section summarizes the recording procedure for certification
relating to the surface preparation, internal and external paint coatings,
linings, spray applied fire-proofing applications and all types of
insulation.
The construction or maintenance authority is responsible for issue of the
work scope to the painting/insulation and protective coating contractor(s)
who shall be responsible for management and inspection requirements.
The contractor shall maintain reports which describe the preparation and
environmental conditions during construction activities.
b)
Architectural Services (surface preparation, internal and external paint
coatings, linings, spray applied fire-proofing applications and all types of
insulation) shall be checked for compliance and other requirements as
detailed in, but not limited to:
•
•
•
•
•
•
•
The latest revision of Issued For Construction (IFC) or Approved
For Construction (AFC) Drawings and Schedules
Codes and standards reference in this section
Plant and Project Specifications
Equipment Specifications and Data sheets
BP Engineering Installation and Design Specifications
Local, state, country and international standards, codes, and
regulations as appropriate
Offshore - Special Standards, i.e. USCG, ABS and MMS
7.1.2
Use Of Forms
a)
All reporting and recording of results of inspection shall be on the GOC©
standard forms - see Exhibit 7 on the last page of this section.
b)
AS1: Final Paint Acceptance Certificate.
Used to record acceptance on completion of painting.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC© AMERICAS EDITION
SUBJECT:
c)
MECHANICAL - ARCHITECTURAL SERVICES
(PAINTING, COATING AND INSULATION)
SECTION 7.0
REVISION: 1
PAGE: 3
AS2: This is a two-part certificate.
Final Insulation/Coating Acceptance Certificate
Covering Architectural and Structural Acceptance, (Paint, Linings and
Fire Proofing) and is used for recording acceptance of fire proofing and
related activities. The State Fire Marshall or authorized representative of
the country or state whose jurisdiction the installation is subject, may be
required to endorse this document for Passive Fire Protection.
Piping/Equipment Insulation Acceptance Certificate
Used to record insulation acceptance on completion of insulation applied
to piping systems, mechanical equipment and vessels.
Prior to
acceptance of insulation, it shall be confirmed that all corrosion
monitoring pockets have been identified and correctly installed.
Note:
Prior to acceptance of insulation, it shall be confirmed that all corrosion
monitoring pockets have been identified and correctly installed.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
SECTION 7.0
GUIDANCE ON CERTIFICATION
GOC© AMERICAS EDITION
SUBJECT:
REVISION: 1
MECHANICAL - ARCHITECTURAL SERVICES
(PAINTING, COATING AND INSULATION)
PAGE: 4
Flowchart 7
•
•
•
Functional Certification Flowchart
Discipline: Mechanical (Architectural Services)
(Painting, Coatings and Insulation)
AS1
MC1
SH1
AS2
AS1:
AS2:
MC1:
SH1:
Final Paint Certficiate
Final Coating / Insulation Certificate
Mechanical Completion Certificate
System Handover Certificate
Architectural Services covers the following Sections:
Section 3
Section 4
Section 5
Section 6
Pipe Testing
Vessels and Tanks
Machinery
Mechanical Handling
Structural
HVAC
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
GOC© AMERICAS EDITION
SUBJECT:
MECHANICAL - ARCHITECTURAL SERVICES
(PAINTING, COATING AND INSULATION)
SECTION 7.0
REVISION: 1
PAGE: 5
EXHIBIT 7
STANDARD FORMS
Form No.
Form Title
AS1
Final Paint Acceptance Certificate
AS2
Covering Architectural and Structural Acceptance
Certificate, (Paint, Linings and Fire Proofing) and
Piping/Equipment Insulation Acceptance Certificate.
Note:
Final acceptance of each report as complete and
correct shall be authorized by the painting/insulation
foreman or dedicated painting inspector.
The AS2 may require to be endorsed by the State Fire
Marshall or authorized representative of the country or
state whose jurisdiction the installation is subject.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM AS1
SITE:
FINAL PAINT ACCEPTANCE CERTIFICATE
CONTRACTOR:
SHT
OF
CONTRACT NO:
SCOPE OF CERTIFICATE
REMARKS
THIS IS TO CERTIFY THAT ALL PAINTING AS DEFINED ABOVE HAS BEEN COMPLETED IN ACCORDANCE WITH
PAINT SPECIFICATION.
INSPECTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM AS2
(SIDE 1)
SITE:
ARCHITECURAL INSULATION / COATINGS
ACCEPTANCE CERTIFICATE
AREA:
SYSTEM:
GRID REF:
LOCATION:
ELEVATION:
P & I.D. NO:
DRAWING NO:
TEST PACK NO:
SHT
OF
P & ID NO:
PIPING/EQUIPMENT SPECIFICATION NO:
LINE NUMBER OR EQUIPMENT
NO. & DESCRIPTION
FINAL PAINT
ACCEPTED
*YES/NO
INSULATION
TYPE
(FIREPROOFING
THERMAL,
ACOUSTIC)
INSULATION
THICKNESS
(Inches)
INSULATION
INSTALLED IN
ACCORDANCE WITH
SPECIFICATION
YES
NO
FOR ITEMS MARKED 'NO' RAISE PUNCH LIST
INSPECTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* DELETE AS APPLICABLE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
ARCHITECTURAL INSULATION / COATINGS
ACCEPTANCE CERTIFICATE
NORTH
PROJECT TITLE:
MAINTENANCE ID No:
WORKPACK No:
SH1 No:
MC1 No:
FORM AS2
(SIDE 2)
SHT
OF
STRUCTURAL AND ARCHITECTURAL
PRIMARY AND SECONDARY STEELWORK MODULE WALLS
SOUTH
EAST
WEST
ROOF
DECK
COATING
DESCRIPTION
SPECIFICATION
LINING
DESCRIPTION
SPECIFICATION
FIRE PROOFING
DESCRIPTION
SPECFICATION
SURFACE
PREPARATION &
FINAL THICKNESS
AVERAGE dft
COMMENTS
INSPECTED BY
APPROVED BY
AREA LOCATION
GRID REF.
ELEVATION
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
SECTION 8.0
CONTROL
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
PAGE: 1
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 2
8.1
ACTIONS
8.1.1
General
a)
This document details the certification requirements for the installation
and testing of standard process control equipment as used in the
petrochemical industry, including Fire & Gas detection/ protection and
Telecommunications.
Any special tests required to show conformance to specifications for
specialized systems shall be agreed between the Supplier and BP or
their Delegated Authority.
The procedural requirements detailed herein are the recommended
minimum requirements for the inspection and testing for Control
including that used for Instrumentation, Fire and Gas detection/
protection and Telecommunications and must be carried out with due
regard to the relevant manufacturers instructions.
Full reference shall be made to Section 9.0 Electrical with respect to
Equipment Classification (Electrical Procedure 9.15), Electrical
Inspection (Electrical Procedure 9.19) and where the voltage
demarcation between Control/Electrical is reached.
For active fire protection, reference shall be made to Section 3 "Pipe
Testing", refer to Procedure 3.1.7 Piping Completion (Fire & Gas).
For passive fire protection, reference shall be made to Section 7
"Painting, Coating and Insulation", form AS2, "Architectural and
Structural Acceptance Certificate, Paint, Lining, and Fire Proofing."
b)
Installation
Process control equipment including Fire & Gas detection / protection
and Telecommunications shall be checked for compliance and other
requirements as detailed in but not limited to:
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
•
•
•
•
•
•
•
c)
PAGE: 3
The latest revision of Issued For Construction (IFC) or Approved
For Construction (AFC) Drawings and Schedules
Codes and standards reference in this section
Plant and Project Specifications
Equipment Specifications and Data sheets
BP Engineering Installation and Design Specifications
Local, state, country and international standards, codes, and
regulations as appropriate
Offshore - Special Standards, i.e. USCG, ABS and MMS
Inspection
Package units and loose equipment received are to be visually
inspected for damage and shortages.
Any equipment/device not accompanied by the appropriate certification,
or referenced as being reviewed and accepted on the appropriate
Inspection and Test Summary (ITS), shall be quarantined until such time
as the certification is available.
d)
Damage
Any shipping damage shall be recorded and the condition of packaging
noted by the Materials/Stores Department. Equipment, which is
damaged or suspected to be faulty as a result of damage to either
equipment or packaging, shall be quarantined pending assessment by
the appropriate authority.
The Engineering Authority shall determine whether the equipment may
be:
i)
ii)
iii)
released without further action;
returned to the vendor for repair;
repaired, if possible without invalidating the vendor's warranty;
The Engineering Authority will advise the materials department
accordingly.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
e)
PAGE: 4
Storage
Devices and materials, as received, shall be stored as recommended by
the supplier and protected against adverse weather conditions. Where
special storage requirements are stipulated, they shall be stored under
cover or in air-conditioned stores etc., with shipping stops and protective
devices in place. Devices shall be examined, on receipt, to check that
they are correctly tagged.
To ensure early detection of damage, all equipment inherently suitable
shall be calibrated in the workshop as soon as practicable after receipt
into store and a calibration sticker showing calibrated range/setting; the
date and responsible person attached to the equipment. The material
control department shall be responsible for co-ordinating this activity.
Refer to Project Procurement Plan for any deviations to above activities
or for special storage requirements.
8.1.2
Use Of Forms
a)
General Requirements
For on-site works, all reporting and recording of the results of
inspections and tests shall be on the GOC© standard forms, listed in
Exhibit 8 at the end of this section.
b)
Roles and Responsibilities
Construction/Maintenance Authority
The construction/maintenance authority will be responsible for the
calibration and installation of all devices, their associated piping,
pneumatic and electrical hook-up and all powered down loop checks
relevant to the device, and completion of the relevant certificates.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 5
Commissioning Authority
The commissioning authority will be responsible for powering up and
completing the loop checking and all associated Function Testing.
c)
CC1 Control Acceptance Certificate
The CC1 form is used to by the construction dept to confirm and record
the following:
That the Device(s) and the associated hook-up(s) have been supplied,
calibrated, installed and tagged correctly as per relevant design
drawings and specifications.
Relevant Electrical certification has been completed.
Pneumatic / Impulse lines have (where applicable) been blown through
and pressure tested.
Orifice plate inspection and dimensional checks carried out.
d)
SC1: System Control (Function Test) Certificate
The SC1 form is used by Commissioning to record:
i)
ii)
All powered loop tests and the associated function testing.
Detail and record the test requirements for Programmable Logic
Controller Panels as detailed on Procedure 8.7.
Function testing will be carried out on all critical/complex loops (refer
to Procedure 8.4).
Items not requiring function testing which are solely covered by the CC1
form and Testing are typically: PI's, TI's and RO's i.e. completely local
non-interactive items
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
e)
PAGE: 6
SP1: System Performance Certificate (HIPS)
The SP1 form is used by Commissioning to record High Integrity
Performance System (HIPS) Test(s).
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 7
CONTROL PROCEDURES
Procedure 8.1
Impulse Line Pressure Testing
Procedure 8.2
Control Cable & Fiber Optic Cable
Procedure 8.3
General/Calibration/Installation/Cold Loop Checking
Procedure 8.4
Powered Up Loop and Function Testing
Procedure 8.5
System Control (Function) Testing
Procedure 8.6
System Performance "HIPS" Tests
Procedure 8.7
Programmable Logic Controller Panels (PLCP)
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
Testing
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 8
PROCEDURE 8.1
1.1
Impulse Line Pressure Testing
1.1.1
General
Ensure all air supply/transmission/process/hydraulic lines are correctly
hooked up, as per relevant drawing.
a)
Instrument Air Distribution Systems
Instrument air systems shall be checked for air leakage using dried,
filtered, oil free air or N2 from a compressor or storage cylinder. Main
air headers and branch lines to individual instrument isolating valves
shall be tested to 110% of maximum working pressure. Devices should
not be connected during this test. Service test the last joint after
reconnection.
Apply the required input pressure to the process connection, close the
inlet and disconnect the pressure source. Observe the gauge on the
inlet and ensure that there is no fall-off of pressure. Where leaks are
evident these shall be eliminated and the test repeated.
Tests shall have a duration of at least 10 minutes and a test gauge shall
be observed to detect leakage. All joints shall be leak tested with a soap
and water (bubble) solution, should the above test fail.
Testing of pneumatic piping with liquids is not permitted.
Instrument air tubing downstream of pressure regulators and instrument
pneumatic signal lines shall be blown clear and leak tested using bubble
solution.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
b)
PAGE: 9
Instrument Piping/Tubing Systems
Instrument piping/tubing systems may be categorised as either "Impulse
Lines" or "Process Piping" as follows:
"Impulse Line" (intermittent flow) means the whole of the instrument
piping/tubing downstream of the process line isolating valve, but not
instrument piping through which continuous process flow occurs, such
as for on-stream analysers, which shall be treated as "Process Piping"
(continuous flow) for the purposes of inspection and testing.
Instrument piping classed as:
i)
"Process Piping" shall require full welding traceability, and form
MW1 and associated NDT certificates completed where welding
activities are performed (refer GOC© Manual Section 2.1);
ii)
"Impulse Piping" socket weld activities only require Magnetic
Particle Inspection (MPI) or Dye Penetrant (DP) to be performed;
all butt-welds require Ultrasonic Testing (UT) or radiographic testing
and shall have full traceability as per process piping.
conformation of completion of MW1 on the CC1;
iii)
Record
Hydraulic Piping IP12 shall be cleaned in accordance with NAS
1638, “Cleanliness Requirements of Parts Used in Hydraulic
Systems.”
All instrument piping/tubing shall be flushed. Prior to flushing main
process lines, all displacement meters, turbine meters, control valves
soft-seated valves, orifice plates, etc., should be removed from the
process lines and suitable spool pieces inserted.
Instrument piping/tubing, during the testing of main process lines, should
be positively isolated or removed from the device downstream of the first
isolation valve. In the case of hydro testing against a positive isolation
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
PAGE: 10
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
of an instrument, the instrument should be equalized and/or vented, or
removed.
All the instrument piping/tubing and manifold shall be tested separately
from the process piping using a suitable test pump and calibrated test
gauge. Testing of pneumatic piping with liquids is not permited.
Instrument piping/tubing categorised as "Impulse Piping" shall be leak tested using a suitable test medium at 110% of the maximum working
pressure, for a minimum period of 15 minutes, the limits of which will be
indicated on the appropriate hook-up drawing.
Where an “instrument manifold” valve is employed for primary isolation,
the pressure test source shall be connected to the vent of the
"instrument manifold" valve. The instrument piping shall be capped at
the instrument end and vent valves shall be opened with the outlets
blanked off.
All
pressure
testing
is
the
responsibility
of
the
Construction/
Maintenance Authority, who shall sign as satisfactorily tested on the
Final Control Completion Certificate CC1.
For pressure testing of instrument piping and design requirements, refer
to BP RP32-2 “Site Inspection, Testing & precommissioning of New
Plant, BP RP42-1 “Piping Systems” and ANSI B31.3 “Process Piping”
respectively.
Where tubing and compression fittings are used (as opposed to Nominal
Bore pipe), the Inspection and Test requirements in BP RP30-10,
“Selection Suply & Installation of Compression Fittings”, shall be
followed.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 11
The additional and specific requirements of testing instrument
compression fittings on process pipe work are:
i)
100 % inspection of fittings.
ii)
Training and Qualifications of installers.
iii)
iv)
Maintain Training and Qualifications of qualified installers.
Hydrostatic test pressure shall be 150% MAWP, which is the same
v)
as process pipe work, ANSI B31.3.
Any equipment removed (breaking containment) and re-instated
shall be subject to a formal Leak Test at 110% MAWP.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 12
PROCEDURE 8.2
2.1
Control Cable & Fiber Optic Cable Testing
2.2.1
General
The following inspection and test procedures are applicable to all cable sizes and
types.
2.2
Post - Installation Inspection
a)
Compare the cable size, type, routing and numbering with the cable
schedule and relevant electrical drawings, paying particular attention to
any special requirements, e.g. toxicity. Ensure that the core identification
agrees with the connection diagrams.
b)
Ensure that the termination fitting certificates meet the area classification
and specification requirements.
c)
Inspect the cable termination fitting for tightness and good workmanship.
Ensure that the correct type of termination fitting has been used for the
size and type of cable installed, and that, where specified, insulating
termination fitting adapters have been installed.
d)
Ensure that the termination fitting plates for single-core cables have
been manufactured from non-magnetic materials, where this is
applicable.
e)
Where conductors have been terminated using crimped connections,
ensure that the correct size and type of crimped connection has been
used.
f)
Inspect the ground connections.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
g)
PAGE: 13
For MI (mineral insulated) control cables, the additional inspection as
listed below should be carried out:
i)
Check that the termination fittings is in accordance with the
manufacturers' instructions and that grounding tails have been
terminated at a suitable grounding terminal.
ii) Check that surge suppression voltage dependent resistors, where
specified, are correctly fitted and that the correct type has been
fitted.
iii) Where applicable, ensure the appropriate requirements of Electrical
Procedures 9.15 and 9.19 are carried out.
2.3
Fiber Optic Cable Testing
a)
Check that the interconnection devices and passive components are
installed as per the Manufacturer’s instructions and procedures. Fiber
Optic Specialists will perform all the testing to the approved Vendor
and/or Manufacturer’s specifications and procedures.
b)
Every strand of fiber shall be tested for attenuation, length and
continuity. An Optical Time Division Reflectometer (ODTR) shall be
performed to determine length and continuity. Hard copy plots of the
tests results shall be printed and attached to Form EE16 Sheet 01.
Attenuation tests shall be conducted by injecting a stabilized light source
into one end of the fiber and measuring the optical loss with an optical
power meter at the other end. Both sets of tests shall be performed at
the 850 nanometer (nm) window in both directions.
c)
The fiber optic cable shall be pretested using optical power meters at
850 and 1300 nm to ensure that all fibers are acceptable and have not
been damaged during shipping. A subsequent reading shall be taken
with an OTDR, also at 850 and 1300 nm prior to installation of the cable.
After installation is complete and connectors have been attached to
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 14
each fiber, all links shall be tested and certified for attenuation utilizing
the above two methods.
d)
The fiber optic cable testing shall verify that the minimum power budget
requirements and maximum distance requirements for the installed fiber
meet the manufacturer’s requirements and the listed standards
requirements.
e)
Fiber Optic Specialists shall submit as part of the final documentation
package test results taken before the installation (bare method) and
after the installation (connectorized fiber cable). The date/time of the
fiber optic installation/termination/testing, along with the testing
equipment used (make, model, date of calibration) and the names of the
person(s) doing the testing shall be included.
f)
Fiber Optic Specialists shall provide a sample results sheet for all tests.
g)
References:
Electronic Industries Association (EIA)/Telecommunication Industry
Association (TIA) EIA/TIA-526-7 Measurement of Optical Power Loss of
Installed Single-Mode Fiber Cable Plant, EIA/TIA-526-14 Optical Power
Loss Measurements of Installed Multi-Mode Fiber Cable Plant, EIA/TIA568 Commercial Building Telecommunications Cabling Standard and
EIA/TIA-569 Commercial Building Standard for Telecommunications
Pathways and Spaces.
h)
Form EE16 will be used as a carrier certificate for the Specialist’s
installation, inspection, testing and certification of Fiber Optic Cables.
The EE16 will be endorsed by the Fiber Optic Specialist’s representative
and BP Commissioning and/or Operating Authority.
i)
In addition specifications, methods of test and certification, risk analysis
statements should be understood with particular notice to the Material
Safety Data Sheets (MSDS) relating to fiber shards and hazardous
substances.
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PAGE: 15
2.4
Insulation Resistance Testing
a)
Before any cables are tested, check cables for damage during
installation, and make sure all clamps, supports, etc. are completed.
Intermediate insulation resistance tests shall be carried out before
clamping. Before making any measurements, the inspector should
ensure that one termination fitting of the cable has de-terminated and is
clear of any metal. After measurements have been taken, a final test
should be made when the termination fitting in question has been reterminated;
i.e. conductor-to-conductor,
conducto-to-shield,
and
conductor-to-ground.
Measure the insulation resistance of the cable and record on the
appropriate EE1 Sheet 1 or 2 test certificate. The table below gives the
test voltages and minimum acceptable values of insulation resistance.
Where necessary measure the conductivity of the ground conductor.
For all multicore cables, insulation resistance should be measured
conductor to conductor, conductor to ground and shield to armor. Only
the lowest figure obtained shall be recorded.
Cable
Voltage
(Working
Range)
Test Voltage
(between
Conductor
and to ground)
Minimum
Insulation
Resistance
Volts
24
240/440
Volts
500
500
Meg-Ohms
10
10
After the above tests each cable shall be discharged and the
conductors earthed until the cable is put into service.
The test voltage are as tabulated above.
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2.5
Certification
a)
All cable testing is the responsibility of the Construction/Maintenance
authority who shall sign Form EE1 Sheet 1 or 2.
Form EE1 Sheet 1 or 2 is to be used to record the results of the testing
and to confirm that all the requirements of this procedure, and Electrical
Procedures 9.15 and 9.19, if appropriate, have been carried out.
b)
Form EE16 Sheet 01 is to be used as a carrier certificate for Fiber Optic
Cables.
The EE16 Sheet 01 will be endorsed by the Fiber Optic
Specialists and BP Commissioning and/or Operating Authority.
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FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 17
PROCEDURE 8.3
3.1
General Calibration / Installation / Cold Loop Checking
3.1.1
General
Device calibration shall be carried out in a calibration workshop, except
where devices form a part of an integrated system, in which case they
shall be calibrated in place. Calibration shall be completed with due
regard to the specific requirements of each type of device.
A suitable means shall be made available for simulating the required
process conditions and that test equipment is available with sufficient
accuracy for the test to be performed. Construction/Maintenance shall
provide current test certificates for all calibration equipment.
Before calibration, all devices shall be visually inspected for damage
(any damage being rectified before any tests are attempted). The data
plate on the device, and the available power source, whether electric or
pneumatic shall agree with that called for on the device specification
sheet.
The Supplier's Instruction Manual shall be made available.
A label shall be attached to the device, giving details of the calibration
check, including date test completed and the name of tester.
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3.1.2
Energy Supply Source and Output
a)
This procedure applies to all devices requiring a power supply and which
generate a signal output.
b)
Pneumatic
i)
The air supply to pneumatic instruments shall be clean, dry and oil
free.
ii)
Connect the air supply and adjust the air supply regulator to the
correct setting, e.g. 20 psig for an operating range of 3-15 psig; 1.4
bar gauge for an operating range of 0.2 – 1.0 bar gauge.
iii)
Connect the output to a suitable test gauge via a capacity chamber.
iv)
Care should be taken to ensure that all pneumatic connections are
leak free. If in doubt, leak test joints with soap and water (bubble)
solution.
c)
Electronic
i)
Connect a suitable power supply. Electronic devices shall be
energized for the minimum period as stated by manufacturers
recommendations. Correct polarity of supply should be maintained
at all times.
ii)
Connect the output to a suitable test meter.
3.1.3
Transmitters/Receivers
a)
This procedure applies to all transmitting, receiving and direct reading
devices, other than local pressure/temperature gauges, and switches.
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b)
PAGE: 19
Leak Test
i)
Apply the maximum signal input pressure to the process
connection, close the inlet and disconnect the pressure source.
Observe the gauge on the signal inlet and ensure that there is no
fall-off of pressure over a given period. Where leaks are evident,
these shall be eliminated and the test repeated.
c)
Calibration Test
Check device at 'ZERO' reading and adjust if necessary.
i)
Raise the process input signal and record the corresponding output
signal and/or scale readings at 0-25-50-75-100% of the device
range. Differential pressure devices shall be subject to a static
alignment check.
Note: The readings should always be taken when the signal is
in the 'rising' state.
ii)
Lower the process input signal and record the corresponding output
signal and/or scale readings at 100-75-50-25-0%.
Note: The readings should always be taken when the signal is
in the 'falling' state.
iii) The percentage error calculated for the above tests should not
exceed the manufacturer's stated limits for accuracy and hysteresis.
iv) Where necessary, adjustments should be made according to the
manufacturer's instructions and the tests repeated. Accuracy of
reading should be better than or equal to the accuracy limits stated
in the manufacturer's specification.
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3.1.3
Controllers
a)
This procedure applies to conventional analog, field or panel mounted
controllers, and would not apply to micro processor type controllers
which form part of an integrated system. Such systems would usually
be factory calibrated and any field tests or adjustment would be subject
to special agreement with the engineer.
3.1.4
Receiver Controller (Closed Loop Method)
a)
Receiver controllers, either pneumatic or electronic should be tested by
the closed loop method. This entails connecting the controller output to
the process input connection and the following performed.
i)
Place controller action in reverse (decreasing output for increasing
input), set Proportional Band to a low value, set Integral or
Derivative action (if fitted) to minimum time values.
ii)
Check that the settings of any limit stops allow full scale pointer
movement.
iii)
Adjust the set point to 50% of scale and set the Auto/Manual
transfer switch to Auto. The controller output should now read
50%, if there is a deviation scale, it should be a null balance point
(center scale).
iv)
Move the set-point upscale and down scale while observing the
output meter. The output meter should continuously track the set
point and deviation point should always read null. Always allow
time at each set-point setting to permit the controller to balance
correctly.
v)
With the controller set-point and output at 50% move the
Proportional Band setting from minimum to maximum. During this
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movement, the output or null balance pointer should remain
stationary.
vi)
Change the Auto/Manual transfer switch to ‘Manual’; it should be
possible to vary the output manually from 0 to 100% of the output
scale.
In the event of the controller performing incorrectly adjustments should
be made in accordance with the manufacturers' instructions until
satisfactory test results are obtained.
NOTE:
The above procedure may vary from one manufacturer to
another.
3.1.5
Direct Connected Controllers (Open Loop Method)
a)
For controllers connected directly to the process, connect a suitable
signal generating source to the process connection together with a
means of isolating and regulating the same, with a suitable accurate
indicator. A power supply should be connected and an output gauge
provided if one does not already exist on the controller.
Checks should be made for controller alignment and synchronisation as
follows.
i)
Controller Alignment
Set the controller action to 'Direct', the Auto/Manual transfer switch
to 'Auto', and the Proportional Band to a low value. Adjust the
Integral and Derivative settings (if fitted) to minimum values.
Set the set-point to 50% (mid-scale) and increase the process
variable to mid-scale at which point the controller output should
change from minimum to maximum. If this does not occur, make
adjustments in accordance with manufacturers' instructions.
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When correct change-over occurs, reverse the controller action and
re-check the operation to ensure the controller is correctly aligned.
ii)
Controller Synchronization
Having checked the alignment set the controller action to the
required mode for operation and set the Proportional band to 100%
with the process variable and set point at 50% (mid-point).
The controller is normally synchronized at 50% of the output range
and should therefore indicate mid-output range when the set-point
and process variables are at mid-scale.
With the controller set up at mid-scale, adjust the Proportional
Band setting from minimum to maximum, during which the output
pointer should remain stationary.
If the controller performs
incorrectly, adjustment should be made in accordance with the
manufacturers instructions, and the test repeated.
Change the Auto/Manual transfer switch to 'Manual'; it should be
possible to vary the output manually from 0 to 100% of the output
scale.
3.1.6
Pressure Gauges
a)
Pressure gauges should be checked by means of a Hydraulic Pressure
Gauge Comparator. The standard pressure gauge shall be calibrated
on site against a Dead Weight Tester before initial use and then
periodically. The date for such tests shall be recorded.
The Gauge Comparator should be firmly fixed to a bench, and a test
gauge of range comparable to the gauge being tested is fitted to the
other branch with the hand pump on the comparator operated in order to
check the gauge against the reading of the test gauge.
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Reading should be checked for pressure corresponding to 0-50-100% of
the range of the gauge under test. Actual gauge readings shall be noted
for both rising and falling signals. Gauges for use on oxygen service
must be tested by oil-free means.
3.1.7
Pressure Switches
a)
Pressure switches shall be tested at their operating point using either a
compressed air source or a dead-weight tester depending upon the
range of the switch under test. A continuity test-circuit should be
connected across the contacts to ensure correct operation.
Care should be taken to ensure the switch operation is in the correct
mode, i.e. with a rising or falling signal according to the device
specification.
When stated in the specification, the switching differential should also be
checked and recorded.
3.1.8
Temperature Indicators
a)
Local temperature indicators (dial thermometers) shall be checked using
a temperature bath. They should normally be checked at approximately
50% of the range unless otherwise agreed. During the test both shall be
continuously stirred to ensure even temperature throughout.
3.1.9
Temperature Switches
a)
Temperature switches shall be tested at their operating point using a
temperature bath. During the test both shall be continuously stirred to
ensure even temperature throughout. A continuity test-circuit should be
connected across the contacts to ensure correct operation. Care should
be taken to ensure the switch operation is in the correct mode, i.e. with a
rising or falling signal according to the device specification.
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Where the switching differential is stated in the specification, this should
also be checked.
3.1.10 Level Switches
a)
Float switches should be tested mechanically prior to installation with a
continuity test-circuit connected across the contacts to ensure correct
operation. Care should be taken to ensure the switch operation mode is
correct.
Where possible all float or displacer elements shall be checked for pin
hole leaks i.e. immerse element in bath of clear hot water and inspect
for Air Bubble Streams.
Before commissioning, water should be used to check the operation of
the switch in place.
3.1.11 Solenoid Valves
a) Connect an appropriate power supply via a switch and connect an air
supply to the appropriate port or ports. The operation of the valve shall be
checked by operating the switch and observing the change-over action.
Tightness of shut-off shall be checked by connecting a flexible tube to the
outlet port or ports and immersing the free end in water to ensure that the
valve closure is bubble-tight at the stated design pressure.
Where applicable, check electrical and manual reset, over-ride and time
delay features as called for in the specification; that the coil resistance is
correct and any bridge rectification is intact. Also check any internal
suppression diodes.
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PAGE: 25
3.1.12 Flow Elements
a)
Flow elements, e.g. orifice plates, venturies, variable area meters,
turbine meters etc., should not be installed until line flushing has been
completed.
Flow elements such as turbine meters, magnetic flow meters etc.,
cannot usually be tested in the field and manufacturers test certificates
are normally accepted.
Before installation, the flow element shall be inspected to ensure that
the data and material specification stamped on the data plate or tab
handle agrees with the specification.
b)
Orifice plates should be examined for flatness and to ensure that they
are undamaged. The dimensions should be checked against the
relevant data sheet with a Vernier and recorded on form CC1 by
Construction/Maintenance, and upon installation
Commissioning to ensure correct direction of flow.
checked
by
Inspection of orifice flange installation shall be carried out to ensure
adequate weld dressing and orientation of flange taps. Pipeline internal
dimension measurement certificates shall be inspected.
3.1.13 Control Valves
a)
Diaphragm Valves (Without Positioner)
Note the bench setting operating range of the diaphragm actuator from
its data plate or specification sheet.
Connect a suitable regulated air supply with an accurate test gauge to
the diaphragm case connection. Increase the air pressure to load the
diaphragm and check the valve spindle position from the valve stem
position indicator. The travel should be checked at the following
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positions 0-25-50-75-100% of valve stroke. Where necessary, adjust
the valve spring tension nut to obtain the correct start point and retest.
When tight shut-off is specified, a test rig should be fabricated
comprising of a blind flange on the valve outlet, fitted with a bleed pipe
and a suitable rated isolation valve. The open end of the bleed pipe
should be immersed in water so that discharge bubbles can be
observed. The valve inlet should be connected to a source of pressure
equal to the valve shut-off pressure.
The specified signal corresponding to the valve closed position under
normal operating conditions should be applied to the valve actuator and,
if necessary, adjustments made to the valve, until the leakage bubblerate is within the specified tolerance.
b)
Diaphragm Valves (With Positioner)
Note the bench setting operating range of the diaphragm actuator from
its data plate or specification sheet, i.e. bench-set of actuator
irrespective of positioner.
Note the operating range of the positioner input and output. Where the
positioner is fitted with a by-pass valve (omitted in split-range service)
switch the valve to the signal input connection. If a positioner by-pass is
not fitted, disconnect the air connection from the actuator case and
connect the variable air supply, with test gauge, direct to the diaphragm
head.
The actuator should then be checked for travel, independent from
positioner with rising and falling signals at 0-25-50-75-100% of valve
stroke.
After checking the valve stroke without positioner, the stroke should be
checked with the positioner in service. Connect an air supply to the
Positioner 'supply' connection and adjust to 5 psig above the maximum
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operating range of the actuator. Switch the positioner by-pass valve to
the 'on' position. If no by-pass is fitted, re-connect the positioner output
to the actuator and connect the variable air supply to the positioner
signal connection.
If necessary, adjust in accordance with manufacturers instructions and
then re-test.
Control valves with other types of actuator, e.g. piston operators, air
cylinder operators, electro/hydraulic or electric motor operators should
be tested for stroking and failure action in accordance with the
manufacturer's instructions.
All valve accessories shall be checked for correct function, this shall
include limit switches, solenoid valves and any associated test over-ride
facilities.
c)
Electrically Actuated Valve Testing
Where actuators have not been tested with the valves in the Vendors'
Works, consideration shall be given to testing the combined valve and
actuator unit to demonstrate that the actuator will open the valve with the
specified differential pressure in the associated pipework.
Initial testing shall be performed by winding the valve by hand to the
mid-position before operating the actuator to check that the motor phase
rotation is correct, noting that incorrect rotation will damage the valve.
The settings of torque and limit switches, valve position indicators,
indicating lights and remote/locate controls shall be checked by a full
operation test, using both the medium and low voltage supplies.
Where more than one electrically operated valve is associated with a
system of interlocks, all valves shall be operational to ensure that the
required valves only are affected.
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Field installed powered -up testing shall only be carried out with the full
involvement of the Operating Authority.
3.2
Fire & Gas and Telecommunications
a)
Due to the diverse nature of Fire & Gas and Telecomms equipment
general calibration procedures are not recommended. Calibration were
applicable shall be carried out in accordance with the individual
manufactures instructions and conjunction with the relevant specialised
vendor where applicable.
3.3
Certification
a)
Calibration Checks
All calibration checks are the responsibility of the Construction /
Maintenance, and shall be recorded on Form CC1. All devices are to be
calibrated on receipt (refer to 8.1.1. d).
b)
Inspecting & Tests
The following inspections and tests shall be completed the Construction
/ Maintenance before a loop is offered for acceptance.
i)
All supports for piping, tubing and cabling have been fitted.
ii)
Hydraulic/hydrostatic pressure testing (Procedure 8.1) has been
completed.
iii) All field/panel cabling has been installed as per appropriate drawing.
Instrument (Procedure 8.2) completed.
iv) General calibration/installation (Procedure 8.3) complete, where
appropriate, and recorded on the CC1.
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v)
PAGE: 29
All equipment is installed, tagged and located, as per design.
vi) All equipment certification is correct for area classification. Electrical
(Procedure 9.15) has been completed and recorded on the CC1.
vii) All "cold" powered down continuity loop checks are completed inline with the relevant design drawings.
viii) All associated junction boxes have been checked and electrical
(Procedure 9.19) has been completed and recorded on form CC1.
ix) Mechanical protection of equipment, particularly Fire and Gas,
critical to the overall completion of the detection and protection
systems the necessary precautions shall be taken to ensure the
integrity of the installed equipment and systems is maintained.
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PROCEDURE 8.4
4.1
Powered Up Loop And Function Testing
4.1.1
General
Loop Testing shall be completed for Control, Fire & Gas and
Telecommunications
Loop testing will be carried out by the Commissioning Authority.
Prior to commencing with powered-up loop checks confirm the
completion of Procedures 8.1, 8.2 & 8.3.
Confirm all relevant
certification is complete and available for inspection.
Full regard shall be taken of all relevant documentation prior to
commencing loop function testing including: manufacturers instructions,
O & M manuals, Control and Shutdown Philosophy, Cause and Effect's,
and specialised vendor input that may be required.
4.1.2
Loop Categories
a)
Loops are basically divided into 4 categories:
i) Local non-interactive, e.g. PI, TI. This category does not require
function testing; calibration and installation are covered by the CC1
as completed by Construction.
ii) Local control and indication with no local/remote panel interaction,
e.g. PT & PCV. This category requires loop function testing.
iii) Control and Detection/Indication with local/remote interaction, no
complex control functions or shutdown interface, e.g. PT-PIC-PCV
and/or PT-PSL-PSH-PAL-PAH. This category requires loop function
testing.
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iii)
PAGE: 31
Control and Detection/indication with local/remote interaction,
complex control functions or shutdown interface, e.g. from any
High High / Low Low initiating devices, Fire & Gas detection &
Executive action. This category initially requires the standard
loop function test and then the system function test for the
control/shutdown interfaces and should be tested in accordance
with the relevant commissioning procedure, control philosophy
and cause and effect.
For instruments connected to the Distributed Control System (DCS) or
safety systems, the loop shall include system measurement, processing,
control action and display. This shall be achieved utilising the control
system monitoring facilities provided for the purpose.
The overall testing of the instrumentation system, which includes
DCS/safety systems, shall be carried out in conjunction with the Vendor
of the control system, under the supervision of the Construction control
engineer and the Commissioning Authority.
4.1.3
Loop Function Testing Control
a)
General
Loop testing is applicable to all devices: Control, Fire & Gas and
Telecommunications, except were specialized vendor involvement is
required; in these instances testing will be at the discretion of the
Commissioning Authority.
Ensure devices are powered-up and tested in accordance with
manufacturers procedures.
b)
For Fire & Gas devices.
i)
Ensure correct operation of fire area override.
ii)
Ensure the area around the detector is free of gas.
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iii)
PAGE: 32
Ensure that any optical surfaces and mirrors are clean.
iv) Check alignment of detectors and reflector plates.
c)
Apply an appropriate signal to the device, i.e. typical but not limited to:pressure/temperature/digital/analog/UV-IR source/test sheet or injection
of test gas. Check each loop component for correct action/operation. A
check calibration/performance test shall be carried out over the range of
each loop device.
d)
Check / set any trip / alarm in the loop, simulate process signal to initiate
the transmitter/device and check the action, check for correct LEL
readings, check zero readings, including displays, alarms etc. at
operator console. All trips shall be set to the value on the data sheet.
e)
Check the action of the annunciator/LED or other indication against the
specification i.e. momentary or maintained. The correct sequence of
operation and all outputs shall be proven to work satisfactorily including
audible and visible alarms.
f)
Thermowells shall be visually inspected for correct insertion depth.
Thermal elements shall be inspected for damage and correct element
length to ensure contact with the base of the well.
g)
Resistance thermometer elements and thermocouples should be
checked at ambient, and at differing temperatures using suitable test
equipment connected at the field terminals, and the corresponding
output display and recorders checked over their range.
h)
Burn out features shall be checked where provided.
i)
Stroke valves by varying controller output. Check valve fail action and
positioner action.
j)
Ensure devices are powered up in accordance with manufacturers
procedures.
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k)
All individual devices shall be checked as part of the loop function test.
l)
Shutdown input signals should be checked initially to the input LEDs and
associated annunciator.
m)
Outputs from the shutdown system should be simulated initially from the
output terminals to the field device.
n)
Shutdown inputs/outputs, Electrical, Fire & Gas, HVAC and Vendor
packages interfaces should be checked to ensure system compatibility
and correct function with the associated department in question.
o)
Analytical and special installations shall be tested in accordance with the
manufacturers recommendations.
p)
Reference Procedure 8.5 for shutdown/complex loop functions
q)
Owing to the diversity of equipment involved in Telecommunications
systems e.g. satellite communications, aeronautical radios, beacons,
MF, HF, VHF, UHF communications equipment, antennae, TV, video,
etc., it is impractical to produce in-house test record proformas to cover
the full range of different manufacturers specialized equipment. The
objective of providing the diverse range of telecommunications systems
(Radio, Satellite, PA/GA, Telephone, etc.) is to ensure the operational
integrity of the platform or facility.
The basis for procuring the relevant telecommunications systems is to
use appropriate proprietary systems, and system testing is carried out
using manufacturer's procedures, with certification based on relevant
industry standards.
A system test is to be carried out for each system and all the devices
connected to it, and a summary of the results recorded on Form SC1System Control Certificate.
Telecom equipment can be placed in one of three categories for
inspection and test purposed.
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I.
PAGE: 34
General Bulk Field Equipment
i) P.A. Speakers
ii) P.A. Visual Lamps
iii) Telephone Sockets
iv) Exe Telephone Installation
v) Data Sockets
vi) Entertainment Distribution Components
vii) Entertainment Office and Cabin Units
viii) Fiber Optic Cable
II.
Specialist Field Equipment
i) Muster Intercom Units
ii) Operational Intercom Units
iii) Hotline Telephones
iv) CCTV Cameras and Monitors
v) Meteorological Sensors
vi) Antennas
vii) Clocks
viii) Drillers Intercom Units
ix)
x)
xi)
xii)
xiii)
xiv)
xv)
xvi)
xvii)
III.
Crane Radios
Aeronautical Non Directional Beacon
Local Area Network (LAN) & Data Network
Entertainment System
Survival Craft Radios and Beacons
P.A. Access Units
PMS
Line of Sight Radio Link
Satellite System
Central Telecoms Equipment - Located in Equipment Rooms, Radio
Rooms and the CCR
i) Public Address & General Alarm System
ii) SITCOM Terminal
iii) VHF Marine and Aeronautical Fixed Radios
iv) MF/SSB Equipment
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 35
v) NDB Beacon and Monitor
vi) UHF Radio and Paging Equipment
vii) Hotline Central Equipment
viii) Telex
ix) Inmarsat
x) Meteorological Master and Salve Units
xi) Weatherfac/Navfax/Fax
xii) Shutdown System
xiii) Master Supervisory
xiv) Data Central Racks and Master Clock
xv) Telephone Exchange System
xvi) Emergency Muster Point System
4.1.4
General
The foregoing requirements for equipment loop function testing by
commissioning shall apply to Control, Instrumentation, Fire & Gas,
Telecommunications equipment and systems as appropriate. Form SC 1 shall
be used for this purpose.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 36
PROCEDURE 8.5
5.1
System Control (Function) Testing
a)
Function testing of the system control scheme and the shutdown system
will be completed by Commissioning in accordance with relevant
commissioning procedure, control philosophy and cause and effect for
the system or part system, and SC1 certificate raised accordingly.
System function testing will be carried out on receipt and acceptance of
the Mechanical Completion Certificate (MC1).
Programmable Logic Control Panel inspections, as detailed in
Procedure 8.7, must be completed prior to the commencement of
system control function testing.
The SC1 shall be raised by the testing authority or nominated delegate.
The originator and technical authority shall be detailed on the SC1.
All relevant details of associated drawings and software that the system
has been tested to shall be recorded on the SC1.
The shutdown logic should be checked by the commissioning authority
as a separate exercise and an SC1 raised to cover all actions as
detailed in the associated Cause and Effect or logic diagram.
All trip and interlock devices, system inhibits and over-rides shall be
function tested. The function test will be simulated from the field in an
end-to-end test. Signals will not be simulated by disconnection or by
shorting; the control device in the field will be used to generate the trip
signal.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 37
PROCEDURE 8.6
6.1
System Performance HIPS (High Integrity Performance System)
Tests
6.1.1
Trip Testing Routine
a)
It is of paramount importance that systems installed for the protection of
plant and personnel will operate correctly and reliably when a potentially
dangerous condition is approached. Systems may remain static and
may not be called on to operate for long periods of time. Failure of a
component part of a system may not be apparent to the plant operator
since the system does not play any part in the normal routine control of
the plant. Trip testing routines shall be carried out for the following:
6.1.2
Category 1 Systems
If testing of the system is required on-line, a complete system of at least
single sensor, logic system, actuator and trip valve shall remain in
commission during testing.
Test facilities that prevent the system fulfilling its intended function
should be avoided.
The frequency and method of testing should be those, which have been
shown by reliability analysis to give acceptable integrity.
The trip testing routine shall be provided as part of the system design /
commissioning procedure and shall be ratified by the relevant
authorities, any required deviation from the routine due to operational
circumstances should first be authorized by the engineering authority.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 38
6.1.3
Category 2A
a)
Category 2A systems with multiple sensors, logic and trip valves should
be tested as for the Category 1 system. For 2A systems using single
sensors and logic, the testing will be determined by the reliability
requirements.
The trip testing routine shall be provided as part of the system design /
commissioning procedure and shall be ratified by the relevant
authorities, any required deviation from the routine due to operational
circumstances should first be authorized by the engineering authority.
Form SP1 to be used to record the completion of the routine.
6.1.4
Category 2B
a)
Testing on line of the final actuator device may not be required. An
adequate level of integrity may be achieved by testing at plant or spared
equipment shutdown.
The trip testing routine shall be provided as part of the system design /
commissioning procedure and shall be ratified by the relevant
authorities, any required deviation from the routine due to operational
circumstances should first be authorized by the engineering authority.
HIPS Testing
6.1.5
ESD Valve (Emergency Shutdown)
a)
Inspection and testing of primary platform isolations ESD valves shall be
checked for correct position and orientation. Function Testing of these
valves should be carried out using the platform ESD system.
Form SP1 to be used to record the completion of the routine.
Refer to SI 825 Pipeline and Safety Regulations.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
b)
PAGE: 39
Offshore ESDV’s must be inspected and function tested to assets and
statutory requirements of SI 1996 No 825 (formally SI 1029).
SI 1996 No 825 details the intervals between partial and full closure test,
for planned full closure tests it is recommended that a seal leak test,
wherever possible, is conducted at the pipeline Maximum Allowable
Operating Pressure (MAOP). If the MAOP cannot be achieved then an
estimate of the leak rate at the MAOP should be made using the actual
test pressure achieved.
Form SP2 (side 2) to be used to record the valve closure test results.
Refer to SI 1996 No 825 Pipeline Safety Regulations. Although SI 1996
No 825 does not apply to onshore ESDV’s it is recommended that
onshore valves are also inspected and tested in accordance with this SI.
6.1.6
SSIV (Subsea Intervention Valve)
a)
Subsea Intervention Valves (SSIV) are not directly referred to in SI 825,
however the following guidelines should be considered.
i)
SSIV testing should be scheduled to coincide with SI 825 closure
tests.
ii)
Where the plant operability and control system design allows partial
and full closure tests should be carried out including seat leakage
rate test.
iii)
The time interval in seconds from the initiation of the shutdown
sequence for the SSIV to travel to the closed position should be
recorded and developed into a trend for use as a fault finding tool.
The frequency and type of function testing should be determined
based on the SSIV system reliability analysis, vendors
recommendations, operational experience and in accordance with
the Pipeline Operators Requirements.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
6.1.7
PAGE: 40
ESDV (Emergency Shutdown Valve)
Topside facility ESDV's as used for primary facility isolation shall be
checked in accordance with the relevant Asset specific, Prevention of
Fire and Explosion, and Emergency Response (PFEER) requirements.
Full closure testing, partial closure testing and seat leakage testing shall
be carried out in accordance with the relevant Commissioning /
Maintenance Procedure.
The time taken for ESD valves to stroke to their shutdown position shall
be recorded.
Valve installation shall be checked for correct position and orientation.
Form SP1 should be used to record the completion of the routine.
6.1.8
a)
Miscellaneous (Analysers, Special Installations)
Analysis and sampling equipment shall be checked against their
specification on receipt and shall be carefully examined for damaged
glassware and other easily breakable components. Any defects shall be
reported to the Technical Integrity Authority.
Construction shall not attempt any analysis testing without prior
consultation with the Integrity Authority. Commissioning in accordance
with specific procedures.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 41
PROCEDURE 8.7
7.1
Programmable Logic Controller Panels (PLCP)
These panels generally fall into three categories:
i)
ii)
Emergency and Process Shutdown Systems (ESD / PSD)
Distributed Control Systems (DCS)
iii)
Fire and Gas
This is a generic procedure for the above systems, and covers the panel
inspection / testing at the vendors prior to delivery (if applicable), preinstallation checks on site, and post installation checks and tests.
Due to the wide variety of PLCPs, i.e. simplex, duplex etc., it is not
possible to be specific as to the tests requirements. The procedure should
be treated as a guide as to the test requirements, and it will be the
responsibility of the construction and commissioning engineers, in liaison
with the panel vendor as to what level of testing is required. Details of
these test requirements should be listed on the relevant SC1 certificate.
Test requirements for such generic panels should include as a minimum,
but not limited to the following checks and tests.
7.1.1 Pre-Delivery Inspection / Testing at Vendors
a) Ensure the panel conforms to the specified design drawings and
documentation.
b) Ensure that the panel certificates meet the area classification and
design specification requirements.
c)
Compare the panel equipment with the equipment schedule and
vendor documentation. Ensure that all power supply circuit ratings are
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 42
as specified. Note any circuit or hardware changes, and ensure that
they are covered by a project change notice, EQ, or similar.
d) Vendor documentation shall be reviewed and validated against panel
equipment.
e) Produce a detailed commissioning and /or test procedure to cover the
functionality of the panel equipment, taking into account:
i)
Power supply segregation / fusing
ii)
All inputs and outputs
iii)
iv)
Controller functionality
Full Cause and Effect testing
7.1.2 Pre installation and Inspection
a) Remove any temporary weatherproofing and silica gel drying agents
from the panel. Inspect the inside of the panel for cleanliness paying
particular attention to the PLC racks and terminations.
b) Check internal hardware is fixed securely, and adequate access is
available to all panel equipment.
c)
Ensure panel is not damaged and all connection hardware and cables
are included.
7.1.3 Post-Installation
a)
Inspect the entire panel assembly for alignment, level, tightness of
anchor bolts and fastening in general.
b)
Ensure that all panel doors, racks and are bonded to panel structure.
c)
Ensure that all equipment installed in the panel is in good order and
in clean condition. Verify bolt connections for tightness.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 43
d)
Inspect panel grounding and earth connections for mechanical and
e)
electrical continuity.
Ensure all single core panel wiring pins /crimps are secure. Check all
terminals for tightness post field cable termination.
7.1.4 Panel Testing
Before the function testing of any field device as detailed in Procedure 8.5
can be carried out, panel functionality tests must be completed.
The detail and extent of such tests are the responsibility of the
commissioning engineer, who should liase with the panel vendor to ensure
adequate test requirements.
Panel functionality testing can only commence on receipt and acceptance
of the Mechanical Completion Certificate MC1 from the construction
group.
All AC / DC power supplies to the panel, including UPS supplies, are to be
connected and operational and terminated within the panel, with their
relevant cable test certificates completed and signed off.
i)
Ensure all breakers are switched off, and all main fuses are removed
with-in the panel, switch on each power supply in turn and check for
correct voltage and polarity.
ii)
Power-up the panel equipment in turn for each of the power supplies
and ensure stable operation. If necessary current measurements are
to be taken to ensure no overload condition exists.
iii)
Check all PLC LEDs for correct status, and confirm PLC healthy
indication. Establish communications between the processor and the
I/O racks and check that correct data is flowing. In the case of a dual
redundant communication system, fail each comms link in turn and
check for auto change-over.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 44
iv)
Power-up the system monitors and confirm satisfactory operation.
v)
Examine the system status pages, and confirm that all PLC system
alarms and faults are genuine and accounted for.
vi)
Select a random number of digital and analogue inputs and operate.
Observe correct PLC I/O rack LED indication, and correct status on
the system monitors.
Note: These tests need not include full application logic tests as per the
cause and effects. Full cause and effect function testing will be performed
during each of the system control function tests as detailed in Procedure
8.5.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 45
Flowchart 8
•
•
Functional Certification Flowchart.
Discipline: Control ( Includes Instrumentation, Fire & Gas
and Telecoms)
SP1
CC1
MC1
SH1
SC1
CC1 : Control Completion Certificate.
MC1 : Mechanical Completion Certificate.
SC1 : System Control (Function Test) Certificate
SP1 : System Performance Certificate (HIPS)
SH1 : System Handover Certificate.
Note! Where Welding is carried out an MW1 - Welding Completion Summary
is required - Refer to GOC Section 2
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 8.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT: CONTROL, INCLUDING INSTRUMENTATION
FIRE AND GAS AND TELECOMMUNICATIONS
PAGE: 46
EXHIBIT 8
Standard Forms
CC1
Control Completion Certificate
SC1
System Control (Function Test) Certificate
SP1
System Performance Certificate (HIPS)
DIS5
Data Input Sheet 5 – Section 8 Controls
Note: Final acceptance of each form as complete and correct shall be approved
by the Construction and/or Commissioning Authority as appropriate.
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
Project Title:
FORM CC1
Work Pack No:
Maintenance No:
SITE:
SH1 No:
MC1 No:
SHT
CONTROL COMPLETION CERTIFICATE
P&ID No:
OF
Equipment Installed as per Design (If No, Raise an NCR or EQ )
Area Classification Check - Electrical Procedure 9.15 Complete
YES
NO
Loop Diagram Drawing No:
YES
NO
N/A
Process Hook-Up Drawing No:
Junction Box Inspection
YES
NO
N/A
Pneumatic Hook-Up Drawing No:
Orifice Plate Measurement Completed (where appropriate)
YES
NO
N/A
Instrument Tie-in Point Number:
Orifice Plate Measurement : Diameter
NDE Location Drawing No:
YES
NO
Impulse Line Welding *YES/NO if YES - is MW1 Complete? *YES/NO
- Electrical Procedure 9.19 Complete
ins /
Check Flatness
Record All Deviations/Comments:
Loop Number
Tag Number
Procedure No.
8.1
Completed By
Procedure No. 8.1
8.2
Manufacturer
Model & Serial No
Data Sheet No
Calibrated
Range/Setting
Procedure No. 8.3
Asset Specific Procedure
Approved By
8.3
Procedure No. 8.2
Company
Signature
Print Name
Date
* DELETE AS APPLICABLE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM SC1
Sheet 01
SITE:
SYSTEM CONTROL FUNCTION TEST CERTIFICATE
EQUIPMENT No :
SHT
OF
EQUIPMENT DESCRIPTION :
LOCATION :
SYSTEM :
COMMISSIONING PROCEDURE NO :
IS RUNNING LOG
REQUIRED?
* YES
* NO
IF "YES" ATTACH THE APPROPRIATE COMMISSIONING RUNNING LOG
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* DELETE AS APPLICABLE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM SC1
Sheet 02
SITE:
SYSTEM CONTROL FUNCTION TEST
INSTRUMENT TUBING LEAK TEST CERTIFICATE
SHT
EQUIPMENT No :
EQUIPMENT DESCRIPTION :
LOCATION :
TYPE OF TEST :
SYSTEM :
TYPE OF TUBING :
COMMISSIONING PROCEDURE NO :
TEST MEDIUM :
TAG No.
INSPECTED
DATE
INITIAL
TEST
PRESSURE
COMPLETED BY
LEAK TESTED
DATE
DURATION
OF
INSPECTION COMPLETE
INITIAL
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* DELETE AS APPLICABLE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM SP1
(SIDE 1)
SITE:
HIPS PERFORMANCE CERTIFICATE
(CONTROL FUNCTION TEST)
EQUIPMENT No :
SHT
OF
EQUIPMENT DESCRIPTION :
LOCATION :
SYSTEM :
COMMISSIONING PROCEDURE NO :
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
FORM SP1
HIPS PERFORMANCE CERTIFICATE
(VALVE CLOSEURE/LEAK TESTS)
(SIDE 2)
Name and Identification of Installation:
SHT
0F
Name and Identification of Pipeline:
TAG Identification:
Actuator Identification:
Name of Installation Owner:
Description Of Test
Select & Date
INSPECTION RECORD
LEAKAGE RATE RECORD
PARTIAL CLOSURE RECORD
FULL CLOSURE RECORD
TRIP TESTING ROUTINE RECORD
Particulars Of Procedures Used
External Leaks Revealed
External Damage Revealed
External Corrosion Revealed
Closure Time (actual mechanical movement time)
Seat Leakage Rate
Sec’s
Oil
lb/min or gal/min
Gas
SCF/Min
Trip Testing Routine Carried Out
Other Observations
Recommended Remedial Work
I Certify the Above Particulars Are Correct
Technician Who Carried Out
Test & Inspection
Control Supervisor
Production Supervisor
OIM or Nominated
Authority
Signature
Name
Date
Designation
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
DOUBLE SIDED FORM
Americas REV. 1
DIS5
HANDOVER No : _______________
PROJECT : ___________
J.P
NO.
TAG No
LOCATION : _______________
LOOP DIAGRAM No
RAISED BY: ___________________________________
NOTE: JP No FOR (LOOP) TESTING
DATA INPUT SHEET 5
P&ID No
WELL No
LOOP No
DATE : _________________________________
GOC©
OF
WORKSCOPE ID : ______________________
SECTION 8 - CONTROL
SLOT No
SHEET
MAINTENANCE ID No : ______________________
CC1
SP1
SC1 *
SC1
REF
DRGS TO BE AS-BUILT
(LAD)
COMMENTS
DATA ENTERED BY : ________________ DATE : __________
BP Exploration 1989 - 2001 All Rights Reserved
Americas Rev. 1
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
SECTION 9.0
ELECTRICAL
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
PAGE: 1
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
9.1
ELECTRICAL
PAGE: 2
ACTIONS
9.1.1 General
a)
This document details the on-site and off-site inspection and
testing procedures for the Electrical Discipline and includes
standard forms which are to be used to accurately record the
results of the inspection and tests. It also provides written
evidence that all electrical equipment and circuits comply with
design parameters, and will function correctly.
b)
The procedures cover the inspection of electrical equipment prior to
installation
and
the
inspection
and
testing
of
installed
equipment and circuits before and after energization.
Although the inspection and test procedures in this section are
comprehensive, they may not necessarily cover all electrical
equipment and circuits included in the design.
It is the
responsibility of the Construction/Commissioning Group to confirm
all electrical inspections and tests. Also, it is to ensure that any
further procedures, additional to those included in this document,
are developed in order to give complete coverage and confirm that
electrical circuits in all respects are fit for energization and service.
c)
The Engineering & Procurement Group shall ensure that prior to
inspection and testing activities, a comprehensive component or
equipment list and cable schedule is available. All the required test
certificates will be checked against this list to give a concise cross
reference for the completion of system testing. These lists will form
the index of the Certification Database for the electrical discipline.
(Refer to Section 1.0).
d)
The Supplier may be required to carry out final inspection and
functional testing on-site after installation. Such inspection and
tests are to be recorded on GOC© test certificates unless specific
test certificates are prepared by the Supplier and agreed by the
Witnessing Authority prior to use.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
e)
ELECTRICAL
PAGE: 3
The requirements described herein which apply to equipment
specified to be installed in ‘Class 1 Division 1 hazardous locations,
shall also apply to equipment specified suitable for use in ‘Class 1
Division 1 hazardous locations but to be installed in ‘Class 1
Division 2 or non-hazardous areas, at the approval of BP or the
Delegated Authority.
9.1.2 Installation
a)
The installation of electrical equipment and circuits will be checked
for
compliance
with
good
engineering practice
and
other
requirements as detailed in:
•
The latest revision of IFC Drawings and Schedules
•
•
•
Plant and Project Specifications
Equipment Specifications and Data sheets
National Electrical Code (NFPA-70)
•
National Electric Safety Code (ANSI C-2)
•
NFPA 70E, Standard for Electrical Safety Requirements for
Employee Workplaces
•
NFPA 72, ANSI / IEEE Standards and NEMA Standards
•
API RP 14F, Recommended Practice for Design & Installation
of Electrical Systems for Fixed and Floating Offshore Petroleum
Facilities for Unclassified and Class I, Division 1 and 2
Locations
API RP 540, Electrical Installations in Petroleum Processing
Plants
Nationally Recognized Testing Lab Standards, e.g. UL, FM,
CSA
BP Engineering Installation and Design Specifications
Offshore - Special Standards of ABS and USCG in addition to
those above
•
•
•
•
b)
Electrical equipment and the electrical content of mechanical
equipment packages will be inspected on receipt on-site. Any
remedial work carried out on-site by the supplier to correct transit
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 4
damage or faulty workmanship not previously detected, will be
supervised by the Construction Authority.
c)
Any final inspection and testing of electrical equipment and
systems carried out on-site by the supplier’s representatives will be
witnessed
and
formally
accepted
by
the
Construction/Commissioning Group Electrical Engineer. Prior to
performing the above inspections or tests, the Witnessing Authority
shall be informed and shall identify those inspections and tests that
are required to be witnessed.
9.1.3 Pre-Acceptance Procedure
a)
Prior to energizing, when Construction considers that the
installation of an electrical circuit or parts thereof is complete, and
is of such a standard that pre-acceptance inspection and testing
can commence, he shall advise The Witnessing Authority
accordingly.
Unless said Authority gives a specific waiver, a representative of
The Witnessing Authority shall witness all inspection and tests,
which are to be recorded in the HCP. Construction must provide
adequate notice of their intention to commence these activities so
that The Witnessing Authority has time to allocate necessary
personnel.
b)
The Witnessing Authority shall monitor construction activities so
that inspection and testing can be carried out as work proceeds.
The need for disconnecting of cables for testing purposes after the
installation has been completed, is to be avoided.
c)
Wherever possible, final inspection and testing should be carried
out immediately prior to acceptance for energization. Where this is
not possible, The Witnessing Authority may call for re-inspection
and re-testing.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
d)
ELECTRICAL
PAGE: 5
Following the satisfactory completion of the inspection and testing
of a system or circuit, Construction or the Witnessing Authority
shall complete the appropriate test certificate(s). These shall be
witnessed as appropriate by The Witnessing Authority, and
submitted prior to formal notification that work on the circuit is
complete.
No further work whatsoever shall be carried out on a completed
circuit by Construction, subsequent to this certificate submittal,
unless The Witnessing Authority or the Commissioning authority
agrees in writing to full details of all such works. The further work
description shall contain full details of all branch circuits not
covered, and include the means by which not covered circuits will
be isolated during this added work.
e)
Equipment used for testing such as meggers, DC high potential
test sets and current injection test sets shall be calibrated every six
months. Certificates of calibration shall be included with the SH1
package and identified to matching serial numbers on the
equipment used for the tests.
f)
Module or work enclosure internal ambient temperature shall be
maintained at 40oF to 80oF during all testing. The ambient
temperature shall be recorded at the beginning of each test, along
with the percent relative humidity.
g)
The Commissioning and Witnessing Authority Tests (Items Marked
**)
Certain Certificates shown at the end of each Procedure, detail
tests that are to be carried out after energization.
The
Commissioning & Witnessing Authorities will therefore complete
these Certificates.
The areas to be completed by The
Commissioning & Witnessing Authorities will be indicated by a
double asterisk (**).
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 6
The Construction work scope will therefore be completed where the
non-asterisks part of the form is indicated. See the following listing:
The sheets affected by this work delineation are:
EE2 Sheet 01 & 02
−
EE3 Sheet 01
EE4 Sheet 01
−
−
MCC Inspection for Bus Duct Phase rotation
Circuit Breaker Tests for Trip circuit operation
Contactor Starter for Trip circuit operation
and breaker status remote indication
EE4 Sheet 03
−
Load testing Variable Speed Drives
EE13 Sheet 01
−
Phase rotation and run testing of motors
EE15 Sheet 01
−
UPS performance testing
EE8 Sheet 02
−
Heat Trace performance test
EE16 Sheet 01
−
General Test Certificate & Attachments
(when required)
h)
The Witnessing Authority Tests (Electrical Procedures Marked
“Witnessing Test”)
The electrical procedures also detail tests that are to be carried out
after energization and will therefore be completed by The
Witnessing Authority. These tests have been indicated by placing
“Witnessing Authority” at the end of the test clause on the
appropriate certificate.
i)
The Witnessing Authority (Electrical Procedures Marked
“Witnessing Authority to Verify”)
The electrical procedures detail required witnessing points during
construction/pre-commissioning. The witnessing points have been
indicated by placing “Witnessing Authority to Verify” at the end of
the test description clause on the appropriate procedure.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 7
9.1.4 Energization and Commissioning
a)
Construction will notify The Witnessing Authority that work is
complete; arrangements will be made to energize the circuit at a
mutually convenient time. The energization and commissioning of
the circuit will be carried out by, and be the responsibility of, The
Commissioning Authority and the Operator’s Electrical Supervisor
as shown below:
Up to 480VAC, by the Commissioning Authority.
Over 480VAC, by the Operator’s Electrical Supervisor
b)
Under
no
circumstances
may
a
circuit
be
energized
or
commissioned prior to it being inspected and tested, and the
relevant certificate as identified on the appropriate Inspection and
Test Summary (ITS), has been completed and approved. Prior to
initial energizing, a Unit Work Permit shall be obtained.
c)
Under no circumstances may any test be carried out on cables or
equipment without the agreement and in the presence of a
representative of the Construction Authority or The Witnessing
Authority.
If the results of the tests and checks carried out after energization
are not satisfactory, the circuit will be de-energized, locked-out and
handed back to the Construction for remedial action.
d)
If the results of the energization tests are satisfactory, the circuit will
be accepted by the Witnessing Authority, subject to any minor
modifications specified by them. Thereafter, the circuit will become
the responsibility of The Commissioning Authority or Operations
and no further work may be carried out on it without their prior
approval. Access to live parts or the energization of branch circuits
must thereafter have the express approval of The Operating
Authority by means of the Permit to Work system.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 8
9.1.5 Permit to Work Procedures
In order to achieve a safe coordinated approach to electrical
commissioning, the following procedural steps shall be followed:
i)
All commissioning will be carried out in accordance with the
Operator’s HSE Regulations and Permit to Work requirements.
ii)
All feeders to switchgear and motor control centers will always be
the responsibility of the Operation’s Electrical Supervisor as the
Facility Authorized person.
iii)
Before disconnecting any feeder cables to switchgear and motor
control centers, the Construction Authority, must provide the
Electrical Supervisor with a full scope of work including procedures
on re-instatement as well as effects on equipment in service or
being disconnected.
iv)
Energization of pre-commissioned equipment up to 480VAC, such
as MCC’s and distributing panels for lighting and heating, shall only
be approved by mutual consent of the Construction Authority and
Commissioning Authority.
v)
The custody of energized pre-commissioned equipment shall be
with the Commissioning Authority. All feeder and branch circuit
breakers not in use shall be locked-out and tagged-out.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 9
9.1.6 Safety Precautions
a)
In no circumstances may any test be carried out in such a manner
as to cause danger to personnel. All due safety precautions must
be taken.
b)
No test should be undertaken until it has been confirmed that the
equipment to be tested is properly isolated, has been effectively
discharged, and a UNIT WORK PERMIT obtained.
c)
Areas where High Voltage (HV) testing is to take place must be
roped off prior to and during testing. Cautionary notices shall be
displayed at all points of access. Similar precautions are to be
taken in all other instances where danger could arise, e.g. motor
running tests.
d)
All equipment is to be effectively discharged at the completion of
testing; where necessary, e.g. in the case of large cables and
motors. A grounding jumper shall be applied, and left connected
until any residual voltage is fully discharged. In no case is this to
be less than 5 minutes.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 10
Electrical Procedures List
9.1
Power, Control and Instrument Cables
9.2
Switchgear, Motor Control Centers and Metal Enclosed Bus
Duct
9.3
Circuit Breakers - Air, Molded Case and Vacuum Oil
Immersed
9.4
Contactor Starters and Variable Frequency Drives
9.5
9.6
Medium Voltage Air Switches
Power Transformers; Oil Filled and Dry Type
9.7
Motors, A.C. Induction
9.8
9.9
Batteries and Battery Chargers
U.P.S.
9.10
Lighting and Small Power Distribution System
9.11
9.12
9.13
Navigation Aids (Nav-aids)
Neutral Grounding Resistors
Heat Trace Cables and Circuits
9.14
9.15
9.16
Grounding/Bonding
Equipment for use in Hazardous Locations
Oil Insulation Tests
9.17
9.18
Drying of Electrical Rotating Machinery
Instrument Transformer Verfications
9.19
9.20
9.21
Junction Box Inspection
Protective Relay Testing and Metering Circuits
A.C. Generators
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BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 11
ELECTRICAL PROCEDURES
Procedure No. 9.1
1.1 Power, Control and Instrument Cables
1.1.1
General
The following inspection and test procedures are applicable to all
cable sizes and types.
1.1.2
Inspection
1.1.2.1 Pre-Installation
Verify the cable to be installed is of the proper type, size and rating
for the designated application.
Also verify that all required
manufacturing data and standards labeling are clearly visible on
the cable per NEC.
1.1.2.2 Post-Installation
a)
Compare the cable size, type, routing and numbering with the cable
schedule and relevant electrical drawings. Pay particular attention
to any special requirements noted, such as: chemical environment,
voltage of service, or area classification. Verify that the color code
and wire numbers match connection diagrams and phase
sequence.
b)
Ensure that cable termination and fittings meet area classification
and specification requirements.
c)
Inspect the cable termination fittings for tightness and good
workmanship. Ensure that the correct type of termination fitting
has been used for the size and type of cable installed and the
connection landed.
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GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
d)
ELECTRICAL
PAGE: 12
Where 3 phase loads are served by either single conductor or
parallel conductors for each phase, all phase conductors shall be
grouped (A, B, C, N) per NEC. [Prevents induction heating of
conduit or enclosure.]
e)
Where conductors have been terminated using compression
connectors, check that the correct size and type of connector has
been used.
The crimp tool and dies used must be listed and
labeled for the particular connector, and must be of the type
requiring a full compression stroke before release. Ensure cable
connections are tight and torque values verified with a calibrated
torque wrench.
f)
Inspect all grounding connections, for control as well as power
cables. Refer to manufacturers instructions for proper ground
connections for the type of cable in use.
g)
For MV cables, be sure that the cables have been terminated in
accordance with the cable manufacturer’s instructions, including
shield grounding. In particular, check that any support or clamping
measures required have been incorporated for strain relief. Note
stress cones may be required depending on voltage and type of
cable.
h)
For Mineral Insulated Cable (type MI):
i)
Check that all termination fittings are per the manufacturer’s
instructions and that insulating sleeves are undamaged.
ii)
Verify pigtails are stranded wire and that pigtail length and
root length meet drawing requirements per NEC.
iii)
Megger test insulation resistance on individual MI cable sets.
iv)
Verify MI cable is installed with vibration suppression loops.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
i)
ELECTRICAL
PAGE: 13
Inspect conduit, cable trays and cabling systems for NEC
compliance and installation in accordance with Issued For
Construction (IFC) drawings. Record inspection data on the
applicable conduit, cable or cable tray checkout forms per
pages 14 thru 17 following.
j)
Inspect cable blocking kit installation where required in
hazardous locations. Record data on the Cable Blocking Kit
Inspection Checkout form (page 18) and attach to EE16
Sheet 1.
k)
Ensure cable installation bends meet the manufacture’s and
NEC minimum allowable bending radius. Pay particular
attention to such standards for cables pulled into or through
pull boxes and panels.
l)
Note and be certain the installation complies with the
requirements for Hazardous Locations (Procedure 9.15) and
Junction Box Standards (Procedure 9.19) for conduit seals
and other details.
m)
Inspection Checkout
Refer to Inspection Checkout forms on following pages 1418. These forms are to be attached to the EE16 Sheet 1
Certificate. These will assist in the organization of data and
acceptance of the EE16 Sheet 1, General Test Certificate:
• Conduit Installation Inspection
• Conduct or Cable Seal Inspection
• Cable Inspection
• Cable Tray Installation Inspection
• Cable Blocking Kit Installation Inspection
Note: Complete conduit, cable and cable tray Inspections prior to
executing insulation tests (megger or H.V. DC). Insulation tests
(beginning with Part 1.1.3 following) are to be conducted with
cables installed, but with end terminals still open.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
CONDUIT INSTALLATION
INSPECTION CHECKOUT (Procedure 9.1)
PAGE: 14
SLD No
SHT
DATE:
JOB NO:
LOCATION:
MODULE:
CONDUIT NO:
SIZE:
FROM:
TO:
of
Initials/Date
1. Conduit fittings and junction boxes correct type for area of classification.
1
2. Aluminum or galvanized steel conduit installed where specified on drawings.
2
3. Supports installed and spacing as per drawings/specs/NEC.
3
4. Supports adjacent to terminal boxes/devices as per NEC.
4
5. Conduit is correct size per drawings/NEC fill requirements.
5
6. Conduit field cut is correctly threaded per NEC.
6
7. Conduit installed wrench tight with minimum 5 threads engaged.
7
8. Conduit installed plumb and level, at right angles to structure.
8
9. Conduits clean, stub-ups protected, open ends plugged, and free of obstructions.
10. Conduit bending radius is correct as per specs and NEC. Bends free of deformities with
full diameter throughout.
9
11. Installation is neat and conduct runs evenly spaced.
11
12. Spacing between instrument and power conduits is per project specs.
12
13. Spacing from hot piping/equipment is in accordance with project specs.
13
14. Adequate clearance maintained from walls, ladders, railings, ceilings, etc.
14
15. Conduit is permanently and effectively grounded per NEC and Procedure 9.14.
15
16. Threaded Bushings installed on all conduits entering boxes, fittings per NEC.
16
17. Seals and drains installed as per drawings/specs/NEC.
17
18. Union installed between seal and devices or boxes.
18
19. No fittings installed between seals and crossover area classification boundaries.
20. Junction boxes level and supported per drawings with proper hubs, locknuts and
bushings installed.
19
21. Junction boxes properly labels and grounded.
22. Number of pulling points adequate; number of bends does not exceed NEC. Flexible
conduit installed with correct bending radius.
21
10
20
22
REMARKS
REV. 1
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BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
CONDUIT OR CABLE SEAL INSTALLATION
INSPECTION CHECKOUT (Procedure 9.1)
DATE:
JOB NO:
PAGE: 15
SLD No
LOCATION:
Conduit or Cable number and Location
SHT
MODULE:
Type (eys, stx, ect)
Size
Verify
Initials/Date
1. Temperature suitable for pour __________ Record # degrees °C or °F.
1
2. Temperature maintained for seal cure as per manufacturers requirements.
2
3. Seal(s) properly sized as per specifications and codes.
3
4. Seal(s) properly located per code.
4
5. Packing material type & installation per vendor required.
5
6. Conductors properly separated.
6
7. Proper compound type and mixed per manufacturers requirements.
7
8. Seals checked for leak through after pour.
8
9. Seals plugs painted red.
9
10. Seal or STX initialed and dated by BP QA.
of
10
REMARKS
REV. 1
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BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
CABLE (INSTALLED WITHOUT CONDUIT)
INSPECTION CHECKOUT (Procedure 9.1)
PAGE: 16
SLD No
SHT
DATE:
JOB NO:
LOCATION:
MODULE:
CABLE NO:
SIZE:
FROM:
TO:
Verify
of
Initials/Date
1. Cable, fittings and junction boxes labeled/listed for the area classification.
1
2. Supports installed as per drawings/specs/NEC.
2
3. Supports installed at terminal boxes/devices as per NEC.
3
4. Cable is sized as per drawings.
4
5. Cable terminators packed and sealed as required.
5
6. Terminators are wrench tight with minimum 5 threads engaged.
6
7. Cables are installed plumb and neatly arranged.
7
8. Cable bending radius is correct as per specs and NEC.
8
9. Cable installation is neat and evenly spaced.
9
10. Spacing between instrument and power cables is as per project specs.
10
11. Spacing from hot piping/equipment is in accordance with project specs.
12. Adequate clearance maintained from walls, ladders, railings, ceilings and any sharp
edges.
11
13. Cable is permanently and effectively grounded/bonded as per NEC.
13
14. Hubs/bushings installed for cable terminations as required.
14
15. No fittings installed between seals and area classification boundaries.
16. Junction boxes properly installed with proper hubs, bushings installed, labeled and
grounded.
15
12
16
REMARKS
REV. 1
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
CABLE TRAY INSTALLATION
INSPECTION CHECKOUT (Procedure 9.1)
PAGE: 17
SLD No
SHT
DATE:
JOB NO:
LOCATION:
MODULE:
TRAY NO:
SIZE:
FROM:
TO:
Verify
of
Initials/Date
1. All braces and supports installed are as per drawing/specs/NEC/VE-1.
1
2. Aluminum or galvanized conduit attachments are installed when specified on drawings.
2
3. Tray size and fill in accordance with specs/NEC/VE-1.
3
4. Tray hold downs and guides properly installed/located as per design, NEMA and NEC
requirements.
4
5. No sharp edges left and round carriage bolts are installed with head to inside of tray.
5
6. Field bends/transitions provide continuous bonding for ground path and proper support
for cables.
6
7. Bonding jumpers installed as required at all sections junction points.
7
8. All non-conductive coatings removed at ground/bond connections as required.
8
9. Cable tray grounded/bonded as required.
9
10. Proper clearances provided as required for installing cable runs in tray.
10
11. Expansion joints located as required properly installed and bonded.
11
12. Damaged coatings repaired as required.
12
13. Spacing between power and instrument trays maintained as per specs.
13
14. Proper spacing from heat sources as per specs.
14
15. All dividers, covers and fire stops installed as required by specs and NEC.
15
REMARKS
REV. 1
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BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
CABLE BLOCKING KIT INSTALLATION
INSPECTION CHECKOUT (Procedure 9.1)
PAGE: 18
SLD No
SHT
DATE:
JOB NO:
LOCATION:
MODULE:
TRAY NO:
SIZE:
FROM:
TO:
Verify
of
Initials/Date
1. Cable jacket and shield(s) properly prepared for blocking.
1
2. Aluminum or galvanized conduit fittings installed when specified on drawings.
2
3. Drain wire(s) insulated with clear heat-shrink tubes.
3
4. Proper gap (1/2”) between drain heat-shrink tubing and end of shield foil.
4
5. Proper number of sealant sleeves used as per vendor requirements.
5
6. Individual drain wires grouped in common with their conductors.
6
7. No visible cracks or defects in sleeves or fittings.
7
8. No share bends at block mounting.
8
9. Hot melt sealant evenly distributed.
9
10. Hot melt sealant visible at both ends.
10
11. No individual conductors or shield wire showing.
11
12. Overall heat shrink is properly positioned.
12
13. Overall heat shrink length is per manufacturer’s specification.
13
14. Check cable type(s) to be compatible with blocking.
14
REMARKS
REV. 1
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BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 19
1.1.3 Testing Cables
a)
Before any cables are tested, all cable supports, strain reliefs or
clamping blocks and pull box or termination cabinets must be
installed.
All final cable tests are to be made with cable runs
essentially in place, and before final terminations are made up.
b)
Prior to final megger test application, the inspector should ensure
that the open end of the cable is isolated from conducting material,
and all three phases (plus neutral if used) are prepared and
accessible at the testing end.
c)
Perform the megger test on one phase conductor to ground with
other conductors grounded, and shields (if used) grounded. Rotate
test conductor so as to test all three phases individually in the
same manner.
d)
On multi-conductor cables, insulation resistance tests are to be
from conductor to other conductors - grounded one at a time with
shields grounded, similar to c) above. An additional test is to
confirm isolation between shield and armor where both are in the
same cable. Record the lowest test value obtained on each of
these tests.
1.1.4
Insulation Resistance Test for Installed Cable
a)
Measure insulation resistance of the cable and record data on the
proper EE1 Test Certificate located in Exhibit 9 at the end of this
section. [EE1-SHT01 and SHT02.]
b)
See Table 1.1.4 a) for test voltage and minimum resistance
acceptable. (This is a one minute test to verify cable minimum
insulation prior to any further HV tests required.)
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 20
Witnessing Authority to Verify
Table 1.1.4 a)
Cable AC
Test Voltage*
Minimum Insulation
Voltage Rating
(Between Conductors
Resistance
(Operating Range)
and to Ground)
(60 seconds)
Volts
Volts DC
Meg-Ohms
300V
500
50
600V
5KV
600
2500
50
5
15KV
5000
15
* Test time is one minute at these voltages
1.1.5
High Voltage Acceptance Test (DC) for MV and HV Cable
[See IEEE-576-1989, “Recommended Practice for Installation,
Termination and Testing of Insulated, Power Cable for use in the
Petroleum Chemical Industry]
a)
Perform insulation resistance test as described in section 1.1.4,
prior to high voltage testing. Ground and discharge residual
voltage from those tests prior to applying HV test voltages.
b)
Per Table 1.1.5 a), apply a DC high voltage test between each
conductor and ground, with other conductors and all shields
grounded. Record test voltage, time and value of test voltage,
record the leakage current and compute resistance from measured
V/I. Repeat the test for each conductor of each cable and record.
This test also confirms resistance of conductor to conductor and
conductor to shield as being satisfactory. Should any readings be
unsatisfactory, it will be necessary to selectively test each
conductor to its shield and conductor to conductor to isolate the
fault. [See Certificate EE1 - SHT03 and SHT04].
c)
For acceptance of newly installed cable systems, apply full test
voltage per Table 1.1.5 a).
Subsequent re-tests due to failure
and after repair, or tests made on a cable system consisting of new
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 21
and previously in-service cable, shall be made at 80% of the
acceptance test values. Each cable shall be discharged after the
above tests, and the conductors grounded and tagged until the
cable is ready to be terminated on both ends.
Witnessing Authority to Verify
Table 1.1.5 a)
Cable
System
Acceptance
Voltage
(Operating
BIL
Range)
Maintenance
Step
Test
Test Voltage Test Voltage
(Conductor
(Conductor to
Duration
(5KV
Voltage
Duration at
to Ground)
Ground)
Steps)
Max
Volts
Volts
Volts DC
Volts DC
Minutes
Minutes
5KV
15KV
75KV
110KV
25KV
55KV
20KV
40KV
1
1
15
15
35KV
200KV
100KV
75KV
1
15
Record all readings for each step and at Max Volts. Procedure
shall be per IEEE-400, 1991 Edition. [NOTE: If Doble Power
Factor Testing is to be conducted, it should be done after all high
potential testing is completed and the cables are fully discharged.]
d)
For cable systems with a number of splices, each cable segment
between splices shall be tested as an individual cable before
making up splices. Each splice shall then be individually tested at
the rated operating voltage of the cable for one minute, or until the
leakage current stabilized, to ensure splice integrity.
e)
The completed cable run, including the end service terminations
shall be tested at 100% of cable rated voltage (the acceptance test)
for 15 minutes. [Load circuit must be open for this test.]
GOC©
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SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
1.16
a)
ELECTRICAL
PAGE: 22
Conductor Continuity Test
Perform a precision continuity test on all conductors including
medium voltage shield with a volt-ohm meter or potentiometer to
ensure conductor integrity.
b)
Measure shield resistance by looping shield on two adjacent
conductor shields together at one end. Measure and record the
loop resistance with an accurate volt-ohm meter. Repeat for each
conductor pair combination and record.
Witnessing Authority to Verify
1.1.7
Where Cable Blocking kits are required to seal cables leaving
hazardous locations; the kits shall be inspected for correct
installation.
Witnessing Authority to Verify
1.1.8
Where conduit seals are required in hazardous locations, the
correct materials and methods for installing, sealing and packing
shall be verified prior to pouring of any seals. Poured seals shall
be inspected, then, if satisfactory, marked by painting seal plugs
red with plugs tight.
Witnessing Authority to Verify
1.1.9
Certification
Attached Certificate Forms:
EE1, Sheets 01 & 02,
EE1, Sheets 03 & 04 and
EE16, Sheet 01
are to be used to record the results of the inspections and testing.
These Sheets must be endorsed by the Witnessing Authority to
confirm all the requirements of this procedure, and 9.15 (HAZ Area)
and 9.19 (Junction Boxes) if applicable, have been satisfactorily
carried out.
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BP Exploration 1989 - 2001 All Rights Reserved
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SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
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PAGE: 23
ELECTRICAL PROCEDURES
Procedure No. 9.2
2.1
(A) Switchgear , (B) Motor Control Centers and (C) Metal Enclosed
Bus Duct
2.1.1
a)
Inspection
Pre-Installation - All items (A), (B) and (C)
i)
Ensure the equipment documents certify that the area
classification and specification requirements have been met.
ii)
Remove any temporary weatherproofing and silica gel drying
materials from enclosures.
Inspect the inside of the
equipment for cleanliness and signs of moisture, paying
particular attention to insulators and bus bracing.
iii)
Compare the equipment with drawing schedules, paying
particular attention to ratings and circuit designations.
iv)
Ensure that the equipment meets environmental
specifications, including weather, dust and vermin-proofing.
v)
Ensure equipment is not damaged, and any required
connection and detail hardware is included in the shipment.
(See shipping documents.)
b)
Post Installation (See Inspection check out Sheets following)
i)
Inspect the switchgear and MCC assemblies for alignment,
plumb and level. Check tightness of anchor bolts. Se that
assembly hardware is installed and torqued to specified
values per vendor drawings.
GOC©
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REVISION: 1
SUBJECT:
ii)
ELECTRICAL
PAGE: 24
Ensure that all panel doors and termination plates are
bonded to their enclosure structures.
iii)
Ensure that all equipment installed in the enclosure is new
and in good, clean condition.
Verify bolt torque at bus
connection points with calibrated torque wrench.
Witnessing Authority to Verify
iv)
Inspect the equipment grounding bus and grounding
electrode conductors for electrical and mechanical
continuity. Verify connections meet NEC requirements.
v)
Inspect bus, insulation and supports for tightness. Ensure
joint insulation is in place where specified. Verify housing
and bus connections are in proper alignment. Check bolts
at bus connection points with calibrated torque wrench.
Witnessing Authority to Verify
vi)
Verify proper operation of any interlock system (Kirk Key or
Electrical) between main and tie circuit breakers on installed
switchgear or transfer schemes in MCCs.
vii)
c)
Ensure the appropriate requirements of Procedure 9.15
(Hazardous Locations) are carried out as applicable.
Inspection Check Out
The following inspection check out lists are to be followed to assist
in completing the requirements for acceptance certificates:
A)
B)
C)
Electrical Switchgear
Motor Control Center
Bus Duct
GOC©
Certificate EE2, Sheet 01
Certificate EE2, Sheet 02
Certificate EE16, Sheet 01
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
ELECTRICAL SWITCHGEAR
INSPECTION CHECKOUT (Procedure 9.2.1 (A))
DATE:
JOB NO:
TAG NO.
PAGE: 25
SLD No
LOCATION:
SHT
of
MODULE:
SYSTEM VOLTAGE
Initials/Date
1. Remove shipping supports.
1
2. Check phasing of bus connections prior to assembly.
2
3. Check and inspect for completeness of all components.
3
4. All devices are installed such as: ground fault relays, volt meters, ammeters, breakers.
4
5. Inspect control wiring, especially field connections at shipping splits.
5
6. Insulation Resistance Test buses and DC Proof Test buses per 9.2.1.1 (d).
6
7. Insulation Resistance Test control and potential transformer primary windings.
7
8. Verify control transformer fuses, type and size per drawings.
8
9. Verify potential transformer fuses, type and size per drawings.
9
10. Check primary and secondary ratings of all transformers including control transformers.
10
11. Check for proper equipment grounding connections at both ends of assembly.
12. Check ground bus bar continuity and ensure connection has been made at shipping split
points.
11
13. See that nameplates and device tags are complete and correct.
13
14. Cubicles clean, dry and dust free.
14
15. Space heaters are connected and operable, including thermostat controls.
15
16. Terminals and connections tight and secure.
16
17. Main bus and taps sized per vendor drawings.
18. Insulation Resistance Test the DC and AC controls circuits, with main and outgoing
control disconnect devices open [Caution: check electronic device limitations].
19. Check incoming power cables insulation Resistance Test prior to connection to
switchgear [See Section 9.1.1.2 (l)].
17
20. Check DC High Potential Testing Data for incoming power cables [See Section 9.1.1.4].
21. Incoming feeder terminations properly made-up, after cable insulation tests are
completed.
22. Vendor Representative provided service/supervision for this equipment. Vendor
certified test reports are to be attached to this Inspection Report.
20
23. Final inspection complete. Punch list items cleared, see Certificate required.
23
24. Verify protective relay testing requirements per 9.20, if applicable.
24
12
18
19
21
22
REMARKS
REV 1
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
MOTOR CONTROL CENTER
INSPECTION CHECKOUT (Procedure 9.2.1(B))
DATE:
JOB NO:
TAG NO:
PAGE: 26
SLD No
LOCATION:
SHT
MODULE:
VOLTAGE:
1. Inspect assembly for damage and missing parts. Remove shipping blocks and/or
of
INITIAL/DATE
1
supports.
2. All changes recorded for as-built drawings.
2
3. Inspect bus taps and torque connection bolt joints per manufacturer’s instruction.
3
4. Check equipment nameplate data in accordance with manufacturer’s drawings and per
4
job specifications.
5. Check for correct ratings of circuit breakers, switches, fuses, contactors, protective
5
relays, other components against one line diagrams and Manufacturer’s drawings.
6. Inspect equipment grounding, connections and conductor sizes, including internal
6
grounds for plug-in units.
7. Megger main bus, phase to phase and phase to ground, per 9.2.1.1 (d).
7
8. ** Check phase sequence across the tie breaker connected between the normal bus
8
and the emergency bus. [Verify before buses are energized.]
9. ** Check that overload reset button is functional on each starter.
10. Perform manual operation of breakers, switches, and contactors in accordance with
9
10
Manufacturer’s instructions.
11. Three-phase connections and phasings are in accordance with drawing color code
11
requirements.
REMARKS
** Witness Authority to Verify
REV 1
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
BUS DUCT
INSPECTION CHECKOUT (Procedure 9.2.1(C))
DATE:
JOB NO:
PAGE: 27
SLD No
LOCATION:
SHT
of
MODULE:
INITIAL/DATE
1. Inspect entire assembly, including auxiliary equipment, for any apparent damage or
1
missing parts.
2. Remove shipping blocks and supports.
2
3. Torque bus segment connections per manufacturer recommendations. NOTE: bus
3
insulation tests must be completed prior to bolting connector at either end.
4. Drain holes unplugged? See manufacturer drawings and instructions.
4
5. Gaskets installed? (if required). Check wall and/or vapor seal offs to be properly
5
installed.
6. Megger bus, and record on Field Inspection Record. See 9.2.1.1 (d).
6
7. **Check for proper phasing after installation.
7
8. Connect space heaters and check operability (where applicable), including temperature
8
controls.
REMARKS
** Witnessing Authority to Verify
REV. 1
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
d)
ELECTRICAL
PAGE: 28
Testing
Note: Inspection checkout sheets require following tests for data to
be entered:
i)
Test the Switchgear (A) and MCC (B) Ground system for electrical
and mechanical continuity. Measure the ground path resistance
from each equipment ground bus to earth ground or the grounding
electrode.
Witnessing Authority to Verify
ii)
Check to see that all metering and protective relaying devices have
been tested in accordance with the requirements of the appropriate
E12 test certificate, supplier’s instructions and Procedure 9.20.
Witnessing Authority to Verify
iii)
Measure the insulation resistance of the main bus section. Also,
test the control wiring, after ensuring any sensitive equipment has
been disconnected, and insuring control wiring is not subjected to
bus test voltages. This test should be carried out prior to the
Dielectric withstand voltage testing and before energizing the
equipment. The minimum acceptable resistance together with the
relevant test voltage is given in the table below.
Switchgear or
MCC Voltage
Test Voltage
Minimum Insulation
Resistance
Meg-Ohms
Volts
Volts
Meg-Ohms
600V
5KV
15KV
1000
5000
5000
10
200
200
Witnessing Authority to Verify
iv)
Perform a Dielectric Withstand voltage test (pressure test) on each
bus section when required, between phases and phase to ground.
The following conditions must be adhered to for the tests:
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 29
All current transformer secondaries will be short-circuited for the
test.
All voltage transformers shall be disconnected by removal of
primary and secondary fuses for the duration of the test.
One pole of the testing supply shall be grounded and bonded to the
frame of the assembly, for the phase to ground test.
v)
For low voltage switchgear (600V), refer to ANSI/IEEE C37.20.
Section 5.5,”Field Tests.” The switchgear shall not be tested at
greater than 75% of the test values in the table below.
*Voltage and Insulation Levels, AC LV Switchgear
Rated Maximum
Voltage Volts (rms)
Insulation Levels
Low-Frequency AC
Reference DC
Withstand KV
Withstand KV (rms)
600
* NOTE:
2.2
3.1
See Table in paragraph 9.2.1.1 d)iii for minimum insulation
resistance acceptable.
vi)
For medium voltage switchgear (1000 volts or greater), refer to
ANSI/IEEE C37.20.2, Section 5.5 “Fields Test.“ The switchgear
shall not be tested at greater than 75% of the test values given in
the table below.
Voltage and Insulation Levels, MV Switchgear
Rated
Maximum
Voltage Volts
(rms)
Insulation
Levels
Low-Frequency
AC Withstand
KV (rms)
Impulse
Withstand
(KV)
Reference DC
Withstand
(KV)
4.76
19
60
27
15
36
95
50
38
80
150
*
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 30
vii)
Repeat step (i)
viii)
Upon the completion of all tests, reconnect all cables and ensure
that shorting links are removed and fuses are replaced.
Witnessing Authority to Verify
ix)
Carry out any required testing of protective relaying and/or meter
circuitry in accordance with Procedure 9.20 using primary and
secondary injection methods as appropriate.
Witnessing Authority to Verify
x)
Measure and record the closing and tripping supply voltages.
Witnessing Authority to Verify
xi)
Energize switchgear or MCC and verify correct phase rotation.
Verify phase sequence across tie circuit breaker to normal and
emergency bus when required.
Witnessing Authority to Verify
xii)
For Bus Duct (C), prior to making up final end connections, and
assembly of covers, measure the insulation resistance of each run,
phase to phase and phase to ground. Test each phase to ground
with other two-phases grounded, then test each phase to the other
two phases. Test values shall be in accordance with the following
table:
Insulation Resistance Test Voltage
Bus Duct Voltage Rating
DC Test Voltage
150-600
1000
601-5000
2500
& Above
5000
Witnessing Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
xiii)
ELECTRICAL
PAGE: 31
When required, perform a DC over-potential test on each run of
Bus Duct, phase to phase and phase to ground.
Potential
application shall be in accordance with the following table:
Over-potential Test Voltage
Rated kV
DC Test Voltage KV
5
20.0
15
37.5
35
55.0
Witnessing Authority to Verify
Test results are evaluated on a pass/fail basis by slowly raising the
test voltage to the required value and holding the final test voltage
for one minutes, then reducing test voltage slowing to zero. Record
data.
2.1.2
Certification
Certificates EE2 Sheet 01 and 02 and EE16 Sheet 01 are to be
used for recording the results of the testing and requires
endorsement to confirm that all the requirements of this procedure,
and Procedure 9.15 if appropriate, have been performed
satisfactorily.
Originals of test certificates generated by implementing Procedure
9.20 (Protective Relay Testing) must be attached to EE2 Sheet 01.
NOTE: See Bus Duct Inspection Checkout Sheet for megger test and bus
phasing required for Witnessing Authority to Verify.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 32
ELECTRICAL PROCEDURES
Procedure No. 9.3
3.1
Circuit Breakers - Air, Molded Case, Vacuum and Oil Immersed
3.1.1
General
a)
Refer to manufacturer’s test specs.
b)
The following procedures are applicable to circuit breakers in metal
clad switchgear, Motor Control Centers, or dedicated enclosures.
This procedure should follow after Procedure 9.2 tests are
completed so main bus and control circuits can be safely
energized.
3.1.2
a)
Inspection
Pre-Installation
i)
Carry out the Pre-installation checks of Procedure 9.2, to be
sure all required materials and parts required have been
accounted for and installed.
b) Inspection Check Out
The following inspection check out for Draw-out Air Circuit Breaker
can assist in the realization and acceptance of the EE3 Sheet 01
Certificate.
NOTE: The Inspection Checkout must be completed prior to final
tests under EE3 Sheet 01 Certificate, for all draw-out circuit
breakers.
c)
Testing required by EE3 Sheet 01 must be completed on every
draw-out breaker and trip unit prior to placing same in service.
Witnessing Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 33
DRAW-OUT AIR CIRCUIT BREAKER
INSPECTION CHECKOUT (Procedure 9.3)
DATE:
PROJECT NO:
SLD No
LOCATION:
SHT
MODULE:
INITIAL/DATE
TAG NO: __________________________________________________
One at a time, insert breakers into their respective cubicles and check the following:
(TURN ON CONTROL POWER SOURCE)
1. Roll breaker into the “TEST” position. The spring charging mechanism should engage
1
to charge the closing spring (on electrically operated mechanisms).
2. Withdraw breaker to the “DISCONNECT” position.
2
3. Roll breaker into the ‘TEST” position. Close breaker using door switch and check
3
indication light for operation. Close breaker from remote control station where
applicable, using “Local/Remote” switch set to “Remote.”
4. ** Trip breaker and check indication light. Trip from door switch and remote control
4
station.
5. ** Trip each breaker from each protective device and check relay targets for operation.
5
Test proper operation of lockout device in closing circuit.
NOTE: Observe manufacturer’s instructions on limiting consecutive close operations.
6. ** Trip each breaker with its mechanical trip device.
6
7. Check contact alignment and wipe clean (air break only).
7
8. Perform Insulation Resistance Test (megger) between each phase and across open
8
pole to frame and ground with breaker withdrawn. Repeat test between each phase
with breaker closed. Record below. Ground all poles not being tested.
9. Perform contact resistance test and record below.
9
10. Roll breaker into “CONNECTED” position and test operation of latch check switch, if
10
provided, and verify control interlocks are operable.
11. Verify nameplate data is in accordance with vendor drawing (continuous amperes,
11
interrupting amps, insulation resistance, contact resistance, etc.).
Insulation Resistance:
∅A to G (closed)
∅B to G (closed)
∅C to G (closed)
A
B
∅AA to A (open)
∅BB to B (open)
∅CC to C (open)
AA
BB
∅A to ∅B
∅B to C
∅C to ∅A
∅A
∅B
∅C
C
Contact Resistance:
CC
(Micro Ohms)
REMARKS: This inspection and test checkout is required for every draw-out breaker installed in an operating assembly.
** See Certificate Required (EE3 Sheet 01) and Witnessing Authority to Verify.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
of
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 34
Post-Installation (After all breakers have been inspected and tested per the checkout
sheet.)
*NOTE: Carry out mechanical operation checks to ensure:
i)
Correct contact alignment and all breaker stab or cluster
connections to the power bus for in-service positioning;
Witnessing Authority to Verify
Correct alignment and connection of all main and secondary
plug and socket connectors for control and/or interlocking
circuits;
Correct operation of bus shutters and energy isolation
mechanism;
Correct fitting and operation of any special grounding
features for the breaker frame.
ii)
Check operation of circuit breaker close and trip mechanism,
manually and electrically.
Witnessing Authority to Verify
iii)
Check the operation of all local and remote, mechanical and
electrical interlocks and trip systems, including functions of
selector switches.
Witnessing Authority to Verify
* NOTE: Some power breakers may not be draw-out type.
ALL breakers except molded case require mechanical
operation checks. Use D.O. Checkout List for guidance.
iv)
Ensure the appropriate requirements of Procedure 9.15
(Hazardous Locations) have been carried out if applicable.
Witnessing Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
v)
ELECTRICAL
PAGE: 35
Check operation of grounding switch if this forms a part of
the circuit breaker assembly.
Witnessing Authority to Verify
vi)
Verify tightness of cable and bus connections with a
calibrated torque wrench.
Witnessing Authority to Verify
vii)
e)
Check arc chute alignment and grounding
Witnessing Authority to Verify
Testing-Low Voltage (Molded Case)
i)
Refer to UL 489 “Circuit Breakers, Molded Case, and Circuit
Breaker Enclosures,” and NEMA AB2 “Procedures for Field
Inspection and Performance Verification of Molded Case
Circuit Breakers Used in Commercial and Industrial
Applications” for testing guidelines.
ii)
The following tests are to be performed as required by BP
and per Certificate EE3 Sheet 02.
• Contact resistance shall be measured. Resistance shall
be compared to adjacent poles and similar breakers.
Deviations of more than 50% shall be investigated.
•
Time-current characteristic tests shall be performed by
passing 300% rated current through each pole
separately, except wherein breaker is equipped with
ground fault protection. (See manufacturer’s information
for test method for breakers with built-in GFP.) Trip
times shall fall within the values in the table below:
Witnessing Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 36
Values for Overcurrent Trip Test
(at 300% of rated continuous current of breaker)
Tripping Time, Seconds
Minimum
Maximum
Range or
Voltage,
Volts
∗
Rated
Cont.
Thermal
Breakers
Magnetic
Breakers
Maximum
Maximum
Trip Times
Current
for Cable
Amperes
Protection*
240
15-45
3
-
50
100 sec
240
50-100
5
-
70
200 sec
600
15-45
5
5
80
100 sec
600
50-100
5
5
150
200 sec
240
110-225
10
5
200
300 sec
600
110-225
10
-
200
300 sec
600
250-450
25
-
250
300 sec
600
500-600
25
10
250
350 sec
600
700-1200
25
10
450
600 sec
600
1400-2500
25
10
600
750 sec
These values are based on heat tests conducted by circuit breaker
manufacturers on conductors in conduit. NEMA Reference.
•
Instantaneous pickup current shall be determined by
pulse method. Clearing times should be within four
cycles. Instantaneous pickup current levels should be
within 20% of manufactures published values.
Witnessing Authority to Verify
•
Insulation resistance tests shall be performed pole to
pole, across open pole and pole to ground. Test voltage
shall be 1000VDC.
Witness Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
f)
ELECTRICAL
PAGE: 37
Testing - Low Voltage (Air)
Refer to ANSI/IEEE C37.13, “IEEE Standard for Low-Voltage AC
Power Circuit Breakers Used in Enclosures” for testing guidelines.
Also, see Certificate EE3 Sheet 01.
The following tests are to be performed as required by BP:
•
Contact resistance shall be measured.
Resistance
values greater than 200 micro-ohms or any value
deviating from adjacent poles or similar breakers more
than 50% should be investigated.
Witnessing Authority to Verify
•
Insulation resistance tests shall be performed from pole
to pole, pole to ground and across the open contacts of
each phase at 1000VDC. Insulation resistance shall not
be less than 50 megohms.
•
Minimum pick-up current shall be determined by primary
current injection.
Witnessing Authority to Verify
•
Long time delay shall be determined by primary injection
at 300% of pick-up current.
Witnessing Authority to Verify
•
Short time pick-up and time delay shall be determined by
primary injection at intended settings per specs.
Witnessing Authority to Verify
•
Instantaneous pick-up current shall be determined by
primary injection.
Witnessing Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
•
PAGE: 38
Trip unit reset characteristics shall be verified by test per
manufacturer’s instructions.
Witnessing Authority to Verify
•
Auxiliary protective devices, such as ground fault or
under voltage relays, shall be activated and simulate
operation of shunt trip devices to verify operation.
Witnessing Authority to Verify
•
Minimum pickup current, trip times and instantaneous
pick-up values shall be set per the settings reflected by
the IFC data sheets. Test values should fall within the
Manufacturer’s published time-current characteristic
tolerance band for all settings and curves applicable.
Witnessing Authority to Verify
g)
Testing - Medium Voltage (Air)
i)
Refer to ANSI/IEEE C37.09 “Test Procedures for AC HighVoltage Circuit Breakers Rated on a Symmetrical Current
Basis” for testing guidelines. Also, see Certificate EE3
Sheet 03 required.
ii)
The following tests are to be performed as required by BP:
•
Measure contact resistance. Resistance values shall not
exceed 500 micro-ohms. Consult the manufacturers
recommendations for acceptable range.
Witnessing Authority to Verify
•
Perform minimum pick-up voltage tests on trip and close
coils with calibrated voltmeter and adjustable source.
Record data.
Witnessing Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
•
PAGE: 39
Circuit breaker shall be tripped by operation of each
protective device by simulation.
Witnessing Authority to Verify
•
Perform insulation resistance test pole-to-pole, pole-toground and across the open contacts of each phase.
Use 2500 V.D.C. megger.
Witnessing Authority to Verify
•
Perform insulation resistance test at 1000VDC on all
control wiring.
Use care to isolate electronics as
necessary per manufacturer instructions.
Witnessing Authority to Verify
•
Perform over-potential tests, or power factor test with
breaker in the open and closed position. All arc chutes
shall be tested for watt loss. Power factor and arc chute
watt loss must be no greater than manufacturers
allowable values. (see Section 9.2.1.c) ii) for overpotential test voltages)
Witnessing Authority to Verify
h)
Testing - Medium Voltage (Oil)
The following tests are to be performed as required by BP: (Refer
to N.E.T.A. Acceptance Testing Specs for M.V. Oil breakers. Also
refer to Certificate EE3 Sheet 04 required.)
•
Measure contact resistance on each breaker pole.
Contact resistance shall not be greater than 500 microohms.
Witnessing Authority to Verify
•
Perform insulation resistance test pole to pole, pole to
ground and across the open contacts of each phase.
Witnessing Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
•
PAGE: 40
Perform over-potential tests, or power factor test with
breaker in the open and closed position. All arc chutes
shall be tested for watt loss. Power factor and arc chute
watt loss must be no greater than manufacturers
allowable values.
(See Section 9.2.1.c)ii) for over-
potential test voltages.)
Witnessing Authority to Verify
•
Draw oil samples. Perform dielectric strength tests. The
dielectric strength of each sample shall not be less than
26KV when tested with the 0.1 inch gap in accordance
with ANSI/IEEE Standard C-57.106 (Guide for
Acceptance and Maintenance of Insulating Oil in
Equipment).
Witnessing Authority to Verify
•
Circuit breaker shall be tripped by manual and/or
electrical operation of each protective device.
Witnessing Authority to Verify
i)
Testing - Medium Voltage (Vacuum)
i)
Refer to ANSI/IEEE C37.09 “Test Procedures for AC HighVoltage Circuit Breakers Rated on a Symmetrical Current
Basis” for testing guidelines. NOTE: recommended checks
for proper contact travel and perform same.
ii)
The following tests are to be performed as required by BP:
•
Measure contact resistance. Resistance values shall not
exceed 500 micro-ohms. Consult the manufacturers
recommendations for acceptable range.
Witnessing Authority to Verify
•
Perform minimum pick-up voltage tests on trip and close
coils.
Witnessing Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
•
PAGE: 41
Circuit breaker shall be tripped by operation of each
protective device.
Witnessing Authority to Verify
•
Perform insulation resistance test pole-to-pole, pole-toground and across the open contacts of each phase.
Witnessing Authority to Verify
•
Perform insulation resistance test at 1000VDC on all
control wiring.
Witnessing Authority to Verify
•
Perform over-potential tests, with breaker in the open
and
closed
position.
Apply
test
voltages
per
manufacturer’s recommendations.
Witnessing Authority to Verify
•
3.1.3
Perform vacuum integrity tests per manufacturer’s
specifications.
Witnessing Authority to Verify
Certification
a)
Form EE3 Sheets 1 - 4 are to be used for recording the
results of the testing and requires endorsement to confirm
that all the requirements of this procedure and Procedures
9.3 and 9.15, if appropriate, have been performed
satisfactorily.
Originals of test certificates generated by implementing
Procedure 9.20 for protective relays must be attached to
EE3.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 42
ELECTRICAL PROCEDURES
Procedure No. 9.4
4.1 (a) Contactor Starters and (b) Variable Frequency Drives
4.1.1
Inspection
4.1.1.1 Pre-Installation (After Shipping Inspection)
a)
Remove packing material from contactors and drives, including
silica gel, taping and /or binding materials from moving
parts/assemblies.
b)
Inspect and clean out enclosures.
Initiate damage repairs if
required.
c)
Locate and check parts, devices, instructions and/or special tools
required for assembling equipment or installation in assigned
enclosures.
4.1.1.2 Post-Installation
a)
Compare unit descriptions with the IFC data sheets and Vendor
drawings, and perform the following inspections:
i)
Ensure that the isolating switch can be locked in the ‘off’
position and that operating handle is mechanically
interlocked with the door.
ii)
Inspect and check the operation of the isolator and any
auxiliary switches or contacts mounted with it.
iii)
For draw-out or plug-in starters, check the fit of the
withdrawal unit and alignment of main and auxiliary circuit
contacts, including plug-ins.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
iv)
ELECTRICAL
PAGE: 43
Test the mechanical operation of all contactors and relays
including alignment of moving contacts.
v)
Compare the main and control fuse ratings with the drawings
and/or fuse tables in the equipment specs.
vi)
Examine the internal wiring for security and ensure that it is
not being caught or damaged by the door or draw-out unit.
vii)
Make sure that the door is bonded to the enclosure and the
enclosure is properly grounded.
viii)
Ensure the position and operation of control switches, lamps
and push buttons is satisfactory and that the colors are per
code.
ix)
Check any meters for correct/suitable scales.
x)
Ensure that any space heaters, if required, are in the correct
position, not too close to any internal wiring or heat sensitive
devices. Verify voltage and wattage rating.
xi)
Examine arc chutes, phase separators and other insulating
components to be clean and in good condition.
xii)
Ensure the appropriate requirements of Procedure 9.15 for
Hazardous Locations have been met (if required).
xiii)
Perform inspection of associated field equipment.
xiv)
Check VSD equipment for any special devices or auxilliary
requirements needed.
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BP Exploration 1989 - 2001 All Rights Reserved
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SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
4.1.1.3
ELECTRICAL
PAGE: 44
Testing
a)
Contactor Starters
i)
Test overloads by primary injection through the load bus and
monitoring trip time. Overload test should be performed at
300% of motor full load current.
Trip times shall be in
accordance with manufacturer’s tolerances. Record the
results on the relevant Test Certificate EE4 Sheet 01.
Witnessing Authority to Verify
ii)
Test the overload relay for single phasing by passing 80% of
full load current through two phases only and record the
result on Test Certificate EE4 Sheet 01.
Witnessing Authority to Verify
iii)
Test the calibration of any local/remote ammeters by primary
injection; secondary injection shall only be used for circuits
outside the range of primary injection sets. Record on Test
Certificate EE4 Sheet 01.
Witnessing Authority to Verify
iv)
v)
Test and record the starter insulation resistance using:
•
1000V test for power wiring - minimum value should be
10 Megohms. Use same technique as in 9.1.1.d.
•
500V test for control wiring - minimum value should be
5 Megohms.
(Isolate electronic devices per
manufacturer’s instructions).
Witnessing Authority to Verify
Function test control circuit operations and indications from
local and remote locations.
Witnessing Authority to Verify
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vi)
ELECTRICAL
PAGE: 45
Perform any required testing of protective relaying or meter
circuitry in accordance with Procedure 9.20 - attach test
sheets to EE4 Sheet 01.
Witnessing Authority to Verify
vii)
Where test certificates are available for tests performed by
the vendor, these should be attached to the EE4
Certificates, or identified as being performed with comments
in the appropriate ITS against the EE4 requirement. The
original vendor test certificate remains in the vendor dossier.
In cases where vendor testing was not performed, the
following should be completed:
•
Check the thermal overloads and ground fault relays
against the starter tabulations to ensure that the installed
relays have the correct setting range and set point
adjustments.
•
The setting range and set point should be noted on
Certificate EE4 Sheet 01 in the “overload trip setting”
column.
•
Where changes to the overloads have been made, or the
markings have been lost, a complete re-test shall be
performed.
•
In other cases sample points can be performed to ensure
the device is still within manufacturers tolerances.
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SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
b)
ELECTRICAL
PAGE: 46
Variable Speed Drive (VSD) Tests
For new installations involving VSDs, motors and drives should be
tested at the Manufacturer’s shop in accordance with a testing
program which is required by the Project specifications.
Including any tests appropriate to the VSD in the Manufacturer’s
shop, Variable Speed Drives incorporating solid state variable
speed controllers should be tested together with their motors as
installed/applied. Tests must include driven equipment at either the
driven equipment manufacturer’s shop or other suitable location,
after completion of the individual component tests.
In some cases, if approved by Project specifications, VSD protype
testing may be allowed to demonstrate an acceptable application.
This does not eliminate the need for field testing with the driven
equipment.
Additional tests should include:
i)
Motor temperature rise test under load, across the specific
speed range required. (BP shall, subject to approval of the
testing methods by an Independent Certifying Authority,
approve certification of the motor for variable speed duty in a
hazardous area.
The VSD unit itself must also be
considered.)
Witnessing Authority to Verify
ii)
Motor vibration test across the required speed range at no
load.
Witnessing Authority to Verify
iii)
Motor noise test across the speed range shall be in
accordance to BP’s RP 14-1 Guide to Noise Control.
Witnessing Authority to Verify
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SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 47
Prior to On-site test runs, the installation checks for the fixed power
supply portion of the VSD should be completed as required by
Procedure 9.4.
Form EE4 - Sheet 03 to cover additional Vendor checks for On-site
testing of the motor with the VSD permanent controller.
NOTE:
Load banks may be required for complete VSD testing.
Reference to Amoco’s A EL-VFD-00-G Electrical - AC Variable
Frequency Drives Guide and/or BP’s RP 12-12 Electrical
Vazriable Speed Drives should be made for additional
information on installation and testing requirements.
4.1.2
Certification
Form EE13 and EE4 Sheet 03 shall be used for recording the
results of the testing and requires endorsement to confirm that the
requirements of this procedure, (and Procedure 9.15 if
appropriate), have been performed satisfactorily. If applicable, the
results of the drying out motor windings, Procedure 9.17, are to be
attached to Form EE13, together with any certificates generated by
implementing Procedure 9.20.
For Variable Speed Drives, EE4 for power supply refer to
Procedure 9.4 and Form EE16 to cover additional Vendor checks
for On-site testing of the motor with the VSD permanent controller.
Originals of test certificates generated by implementing Procedure
9.20 (Protection Relay and Metering Circuit Testing) must be
attached to EE4.
NOTE: Form EE4 verifies that the contactor/starter circuit
including remote field equipment forming part of the circuit is
installed and tested satisfactorily.
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BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 48
ELECTRICAL PROCEDURES
Procedure No. 9.5
5.1
Medium Voltage Air Switches
5.1.1
a)
Inspection
Pre-Installation
i)
Note the nameplate ratings of the air switch. Compare
these ratings with those on the approved drawings, and be
sure the switch installation instructions are included.
ii)
Remove any transit packing materials (where used).
iii)
Ensure that the fuse switch unit has been labeled correctly.
iv)
Check that the interior of the unit has been cleaned and any
silica gel drying agents have been removed.
v)
b)
Verify shipment includes all necessary field assembly parts
and detail items.
Post-Installation
Refer to ANSI/IEEE C37.34 “American National Standard Test
Code for High-Voltage Air Switches” for testing guidelines.
i)
Verify switch unit is mounted level and plumb, and inspect
the air switch compartment for any signs of damage during
installation. [Initiate any necessary repair action, check and
torque bus connections.]
ii)
Inspect the mechanical operation of the air switch. Check
for any required, mechanical or key interlocks installed in the
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SECTION 9.0
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SUBJECT:
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PAGE: 49
air switch cubicle or cover. Inspect the equipment lock-out
mechanism for proper operation.
iii)
Verify external wiring for electrical interlocks, remote
indications, and/or electric space heater power is installed.
iv)
Verify the contact alignment of the air switch and the
mechanical operation of the on-off indication.
Make any
adjustment checks per manufacturer’s instructions.
v)
Verify all necessary operating handles are provided, and
properly stowed or retracted.
vi)
Ensure all necessary grounding bus and/or cables are
installed and properly connected.
vii)
Measure one minute insulation resistance through the
closed switch (phase to phase and each phase to ground),
and pole to pole across the open switch. [Use megger
voltage per 9.2.1.1 d).]
Witnessing Authority to Verify
viii)
Perform DC contact resistance test across each switch
blade (closed), when directed by BP. Any value exceeding
50 micro-ohms or any values that deviate from adjacent
poles or similar switchs by more than 50% shall be
investigated.
Witnessing Authority to Verify
ix)
Verify the bus connections and mechanical throat alignment
from switch to load (i.e., transformer) are properly made up
after all switch testing is completed.
Witnessing Authority to Verify
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SUBJECT:
x)
ELECTRICAL
PAGE: 50
Perform any required testing of associated protective
relaying and/or meter circuitry in accordance with Procedure
9.20. If switch is supplied with internal C.T.’s, verify ratings
and test as done for MV switchgear C.T.’s
5.1.2
a)
xi)
Ensure the appropriate requirements of Procedure 9.15 are
performed if applicable, for Hazardous Locations.
xii)
Check to see correct MV fuses are available per circuit
requirements on approved drawings.
Certification
Form EE5 Sheet 01 is to be used for recording the results of the
testing and requires endorsement to confirm that the requirements
of this procedure, and Procedure 9.15 if appropriate, have been
performed satisfactorily.
Originals of test certificates generated by implementing Procedure
9.20 must be attached to EE5 Sheet 01.
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GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 51
ELECTRICAL PROCEDURES
Procedure No. 9.6
6.1
Power Transformers; Oil Filled and Dry Type
6.1.1
a)
Inspection
Pre-Installation (Oil Filled and Dry Type)
i)
Inspect unit for any physical damage including dents or
scraped paint. If unit is shipped with an impact recorder,
check data before unloading transformer.
ii)
Ensure
equipment
certification
meets
the
area
and
specification requirements. Review nameplate data and
information on special attachments or auxiliary devices.
Compare all with approved drawings.
b)
Post-Installation (Oil Filled)
i)
Inspect the transformer and auxiliary equipment for
alignment and tightness of anchor bolts and fasteners in
general. Inspect the installation and weatherproofing of the
terminal boxes. Verify auxiliary device operation (fans,
pumps, sudden pressure device, indicators, tap changer and
gas pressurization system).
Complete all items on
Inspection Checkout sheets.
ii)
Inspect the lock out provisions for unit mounted disconnect
switches and tap change.
iii)
Inspect the grounding pads and the grounding connections
to the ground grid per installation drawings, verifying proper
bolts, cable size and type, and connectors.
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iv)
ELECTRICAL
PAGE: 52
Inspect the “XO” connection. If neutral grounding resistors
have been installed, refer to Procedure 9.12 for detailed
requirements. If no resistor, ensure that grounding cable or
straps from “XO” to grid are per specifications.
v)
Check for proper oil level at ambient temperature. Check
gasketed covers, radiator flanges and plugs, and auxiliary
devices for any sign of leaks or seepage.
vi)
Check tank pressure/vacuum relief device (if supplied).
Inspect the inert gas alarm device (i.e. nitrogen regulator for
tank pressure) if used.
vii)
Inspect the mechanical pressure relief device (required on
oil filled units).
viii)
Inspect tightness of bus bar connections and bracing from
bushing terminals to bus bars of switchgear. Ensure
adequate separation distances between high voltage cables
for the terminal box connections. Verify terminations are per
unit manufacturer’s drawings and installation specifications.
c)
Inspection Check Out
The following Inspection Check Out for Liquid Filled Transformers
is to assist in the realization and acceptance of the EE6 Sheets 01
& 03 Certificates.
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SECTION 9.0
GOC© AMERICAS EDITION
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SUBJECT:
ELECTRICAL
LIQUID FILLED TRANSFORMER
INSPECTION CHECKOUT (Procedure 9.6)
DATE:
JOB NO:
PAGE: 53
SLD No
LOCATION:
SHT 1 of 2
MODULE:
INITIAL/DATE
TAG NO: __________________________________________________
1. Receiving Operations / Inspection complete, including any required details shipped with
1
the ordered unit.
2. Verify tag number, HV/LV ratings and KVA rating per plant drawings and one-line
2
diagram.
3. Check transformer nameplate against the purchase order and specifications.
3
4. Verify location, mountings and bushing orientation per drawings.
4
5. Visually inspect for cleanliness. No chips, cracks or other apparent damage to
5
bushings, radiators and tanks. Any paint scuffs or scratches must be repaired with
approved methods and materials.
6. Check lubrication and freedom of operation and rotation of cooling fans.
6
7. Check lubrication and freedom of motion of no-load tap changers and control
7
accessories.
8. Inspect fuses, disconnect switches and lightning arrester installations as required.
8
9. Inspect for liquid leakage around tank, radiators and accessories.
9
10. Collect samples of insulating liquid per manufacturer’s instructions and verify dielectric
10
strength of insulating liquid. Take laboratory samples for complete analysis of
insulating liquid.
11. Check for nameplate winding continuity between bushings.
11
12. Verify neutral wire size, insulation and color per drawings / schedule.
12
13. Verify case ground (and grounding resistor if required) correctly installed. Measure,
13
bonding resistance of connections and record a Test Certificate.
14. Check that incoming feeders have had all insulation Resistance Tests performed, and
14
verify test data as acceptable per Certificate.
15. Check inert gas pressure gauge (pressure should be in accordance with manufacturers
15
instructions), and verify pressure relief settings.
16. Check temperature gauge for proper operation.
16
17. Check liquid level gauge for proper operation and proper level of liquid in all oil filled
17
compartments.
REV. 1
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BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
LIQUID FILLED TRANSFORMER
INSPECTION CHECKOUT (Procedure 9.6)
DATE:
JOB NO:
PAGE: 54
SLD No
LOCATION:
SHT
2 of 2
MODULE:
INITIAL/DATE
18. Measure primary and secondary voltages with tap changer in each position and verify
18
that voltage ratios are per transformer nameplate. [Apply 480V construction power to
transformer primary (HV) connections and measure secondary (LV) voltages. Primary
voltage rating shall not be exceeded.]
19. Record transformer tap setting below. Set at mid-tap unless otherwise directed.
19
20. Check sudden pressure relay and connections (if supplied).
20
21. Verify alarm and control circuits connected and complete. Verify alarm, trip, and fan
21
start contacts are operational. High winding and/or liquid temperature alarm set at
90°C, or in accordance with manufacturer’s instructions.
22. Primary/secondary cables/bus duct properly supported, insulated and protected against
22
mechanical damage. Bolted connections torqued in accordance with manufacturer’s
recommendations.
23. Check conductor size, insulation class and type for incoming/outgoing cables.
23
24. Check conductor phasing and identification.
24
25. Check conduit connections - need to be tight, sealed and oriented properly.
25
26. Perform Insulation Resistance Test of transformer primary and secondary windings,
26
and record reading on Test Record (Megger tests). (See 6.1.1.d).
27. Perform Insulation Power Factor Test, required by specifications (Doble or equal).
27
28. Check to assure connections are tight and secure after testing.
28
29. Verify mechanical relief device is reset.
29
30. Verify spare control/alarm conductors taped or capped, and tagged.
30
31. Verify spare hubs or knockouts plugged with seals intact.
31
32. Verify paint scratches refinished.
32
33. Verify access covers tightly secured, with gaskets all in place.
33
34. Vendor Representative provided service supervision for this equipment Vendor test
34
reports attached to this Inspection Record.
35. Final inspection complete. Punch list items cleared.
Transformer Tap
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35
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
d)
ELECTRICAL
PAGE: 55
Testing (Oil Filled)
i)
Test the alarm and trip circuits of all protective devices on
the unit.
Witnessing Authority to Verify
ii)
Ensure that all cables have been tested and checked in
accordance with the cable Certificate required (See EE1
Sheets 01 thru 03)
Witnessing Authority to Verify
iii)
Measure ground continuity, XO, Resistor and tank to ground
grid.
Witnessing Authority to Verify
iv)
Breakdown Voltage tests, when required, shall be made on
two oil samples from each transformer and each barrel,
container or fraction thereof used to fill the transformer with
oil. The dielectric strength of each sample shall not be less
than 26KV when tested with the 0.1 inch gap in accordance
with ANSI/IEEE Standard C-57.106, “Guide for Acceptance
and Maintenance of Insulating oil in Equipment.”
Witnessing Authority to Verify
v)
Measure the insulation resistance for both the HV and LV
windings. Test primary (HV) winding insulation to ground
with the tank and secondary (LV) winding grounded using a
battery or motor operated megger. Test secondary winding
insulation to ground with the tank and primary winding
grounded. Test the primary winding to secondary winding.
The minimum acceptable insulation resistance in megohms
is 8 times the KV rating of the winding under test. Megger
test voltages shall be in accordance with the values for bus
duct in the table in section 9.2.1.c).i) and corrected for
ambient temperature in accordance with the conversion
table at the end of this section. Ground all terminals to fully
discharge any residual voltage after completing tests.
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SUBJECT:
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PAGE: 56
Witnessing Authority to Verify
vi)
A dielectric absorption test, when required, shall be made
winding-to-winding and winding to ground for 10 minutes.
The polarization index shall be computed. Test voltage and
minimum acceptance values shall be in accordance with the
Manufacturer’s recommendations and corrected for ambient
temperature in accordance with the conversion table at the
end of this section. The absorption test polarization index
should be above 2.0 unless the scale value on the available
test equipment prevents a meaningful ratio.
Witnessing Authority to Verify
vii)
An AC over-potential test, when required, shall be made on
all high and low voltage windings to ground. The AC high
potential test voltage shall not exceed 75% of the factory
test voltage for a one minute duration. (See following table
for factory test voltages).
Witnessing Authority to Verify
NOTE: When performing all high voltage insulation tests, a
regulated power supply for the test equipment shall be
provided and used. Variations in operating power during
test runs may result in exceeding the recommended high
limit for testing.
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SUBJECT:
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PAGE: 57
Over-Potential Test Voltage for Power and Distribution Transformers
Nominal System Voltage*
Insulation Class
AC Factory Test (KV) Oil
(KV)
Immersed **
1.2
1.2
10
2.4
2.5
15
4.8
5.0
19
8.32
8.7
26
14.4
15.0
34
18.0
18.0
40
25.0
25.0
50
34.5
34.5
70
46.0
46.0
95
69.0
69.0
140
* Intermediate voltage ratings are placed in the next higher insulation class.
** Also Applies to silicone or other liquid immersed, following manufacturer’s
recommendations.
viii)
No-load tap changer settings on all transformers shall be set
in accordance with the engineers instructions, or on mid-tap
if not otherwise instructed.
Witnessing Authority to Verify
ix)
Power factor test results corrected to 20° C should not
exceed:
1 percent for distribution transformers (up to 500 KVA).
½ percent for power transformers of 500 KVA and above.
Bushing P.F. tests results (hot collar or ungrounded tests) should
be within manufacturers published tolerances.
x)
Turns ration test results (required for each tap position)
should not deviate more than ½
percent from the
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SUBJECT:
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PAGE: 58
calculated ratio, and phases should all correlate for each tap
setting.
Witnessing Authority to Verify
e)
Post Installation (Dry Type)
i)
Note the nameplate ratings of the transformers, and any
special
instructions
concerning
auxiliary
apparatus.
Compare these ratings with those on the approved
drawings. Inspect for any internal damage.
ii)
Ensure equipment certification
specification requirements.
meets
the
area
and
iii)
Verify proper auxiliary device operation such as fans,
indicators and tap changer are provided per specifications.
iv)
Check tightness of accessible bolted electrical joints with a
calibrated torque wrench.
v)
Verify ‘clear space’ requirements for proper cooling provided
on transformer nameplate with measured clearances as
installed.
f)
Testing (Dry Types)
Refer to ANSI/IEEE C57.12.01, “General requirements for DryType Distribution and Power Transformers” for testing guidelines.
i)
Measure the insulation resistance for both the HV and LV
windings. Test primary winding insulation to ground with the
tank and secondary winding grounded using a 1000V
(battery or motor operated), megger.
Test secondary
winding insulation to ground with the enclosure and primary
winding grounded. Test the primary winding to secondary
winding.
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PAGE: 59
The minimum acceptable insulation resistance in megohms
is 8 times the KV rating of the winding under test. Test
voltages shall be in accordance with the values for bus duct
in the table in section 9.2.1.c).i) and corrected for ambient
temperature in accordance with the conversion table at the
end of this section. Winding resistance test results should
compare within 1% of adjacent windings.
Witnessing Authority to Verify
ii)
A dielectric absorption test, when required, shall be made
winding-to-winding and winding to ground for 10 minutes.
The polarization index shall be computed. Test voltage and
minimum acceptance values shall be in accordance with the
Manufacturer’s recommendations.
Test voltages shall be in accordance with the values for bus
duct in the table in section 9.2.1.c).i) and corrected for
ambient temperature in accordance with the conversion
table at the end of this section. The absorption test
polarization index should be above 2.0 unless an extremely
high value is obtained at the end of one such that additional
time value will not yield a meaningful result with the available
test equipment.
Witnessing Authority to Verify
iii)
When required, a turns ratio test shall be performed
between windings for all tap positions. The final tap setting
to be left is to be determined by the engineer. Turns ratio
test results should not deviate more than (½ %) from the
calculated ratio. Phase test data should agree also.
Witnessing Authority to Verify
iv)
An AC over-potential test, when required, shall be made on
all high and low voltage windings to ground. The AC high
potential test voltage shall not exceed 75% of the factory
test voltage for a one minute duration. Evaluation shall be
on a go no-go basis. NEMA Standard ST-20.
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GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
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PAGE: 60
Witnessing Authority to Verify
Applied Potential Test Voltages
Nameplate Winding
v)
Factory Test
Voltage Rating
Potential
Volts A.C.
(KV) A.C.
0
-
250
2.5
251
1201
2501
-
1200
2500
5,000
4.0
10.0
12.0
5001
8661
-
8660
15,000
19.0
31.0
As an alternative to the AC over-potential test, when
required, insulation power factor tests shall be made from
each winding to each other winding and from each winding
to ground. Power factor test values in excess of 3% should
be investigated. (Test equipment must be Doble type or
equivalent.)
vi)
6.1.2
Winding resistance tests, when required, shall be made for
each winding at full turns.
Witnessing Authority to Verify
Certification for Transformers
Forms EE6 sheets 1 thru 3 are to be used for recording the results
of the testing and requires endorsement to confirm that the
requirements of this procedure have been performed satisfactorily.
All supplementary procedures should be completed as reference
on the appropriate Certificates EE6 Sheet 01 , 02 & 03 and EE7
Sheet 01, namely neutral grounding resistors Procedure 9.12,
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GOC© AMERICAS EDITION
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SUBJECT:
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PAGE: 61
transformer and link box oil testing Procedure 9.16 and Certificates
generated by implementing Procedure 9.20 for protective relays.
Witnessing Authority to Verify
Insulation Resistance Conversion Factors
for Conversion of Test Temperature to 20°°C
Transformer
Temperature
°C
0
°F
32
Oil
0.25
Dry
0.40
5
41
0.36
0.45
10
50
0.50
0.50
15
59
0.75
0.75
20
68
1.00
1.00
25
77
1.40
1.30
30
86
1.98
1.60
35
95
2.80
2.05
40
104
3.95
2.50
45
113
5.60
3.25
50
122
7.85
4.00
55
131
11.20
5.20
60
140
15.85
6.40
65
149
22.40
8.70
70
158
31.75
10.00
75
167
44.70
13.00
80
176
63.50
16.00
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REVISION: 1
SUBJECT:
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PAGE: 62
ELECTRICAL PROCEDURES
Procedure No. 9.7
7.1
Motors, A.C. Induction
7.1.1
a)
Inspection
Pre-Installation
i)
Check nameplate data on the motor(s) and compare with
approved drawings and motor schedule. Tag motors for
location code.
ii)
Ensure requirements for Hazardous Locations, per 9.15
have been meet, as indicated on motor nameplate.
iii)
Inspect for shipping damages and take any necessary
corrective action.
b)
Post-Installation
i)
Ensure that any shaft blocking or shipping packing has been
removed. Rotate shaft by hand to check freedom of
movement.
ii)
Without dismantling the motor, inspect as far as possible, oil
rings, oil levels, grease packing and bearings. Inspect for
signs of leakage. Note manufacturer’s instructions may
require flushing bearings prior to start up.
iii)
Inspect the paint finish of the motor for damage during
installation. Any damage areas are to be repainted with
compatible to original paint.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
iv)
ELECTRICAL
PAGE: 63
Inspect the weatherproofing and bolting of the connection
boxes. This must not be dependent upon the application of
paint, tape or plastic compounds for any sealing of the
covers. Confirm conduit entry provisions are per installation
drawings and schedules.
v)
Inspect the stator winding connection leads and verify star or
delta terminals are per system supply.
vi)
Inspect frame grounding terminal and the connection to the
ground grid system, including terminal lug and cable inside
the connection box.
c)
Inspection Check Out
The following inspection check out for Electric Motor Inspection is
to be done to assist in the realization and acceptance of the EE13
Sheet 01 Certificate.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
ELECTRIC MOTOR
INSPECTION CHECKOUT (Procedure 9.7)
DATE:
JOB NO:
PAGE: 64
SLD No
LOCATION:
SHT
of
MODULE:
INITIAL/DATE
MOTOR TAG NO: ______________________ FUNCTION: __________________________
1. Nameplate data agrees with motor list, plan drawings and one-line diagram.
1
2. Motors type is suitable for use in area classification.
2
3. Maximum Temperature Code, Per nameplate:
3
4. Check that the power and control cable insulation resistance tests are complete prior to
4
connection to motor. (See 9.2.1 d)).
5. For induction motors, perform insulation resistance test, using battery or motor operated
5
megger, 1000 V.D.C.
6. Grounding conductors installed, connected and bonded to frame, terminal box and grid.
6
7. Motor splices and terminations complete. Spare wires (pigtails) on multiple voltage
7
motors are properly insulated and tagged.
8. Motor electrical accessories are properly connected, such as space heaters,
8
thermocouples, vibration switches, RTDs.
9. Maximum overtemperature switch (such as a Klixon switch) is wired into the control
9
circuit, where such is required by drawings.
10. Ground bonding jumper installed, bolts and nuts are tightened at terminals.
10
11. Control station and motor lockout switch are installed and nameplate supplied.
11
12. Covers are installed, bolts and nuts are tightened.
12
13. Rotation checks OK.
13
14. Final inspection Complete. Punch list items cleared.
14
REMARKS
REV. 1
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
d)
ELECTRICAL
PAGE: 65
Testing Procedures
i)
Refer to NEMA MG-1, Latest version, “Motors and
Generators” for testing guidelines.
ii)
Ensure that all motor power cables have been certified in
accordance with the cable test procedures. Check phase
sequence and polarity of all connections for correct shaft
rotation.
iii)
Motor insulation resistance shall be megger tested for one
minute, and the values as calculated below shall be
recorded per Checkout Sheet:
•
The minimum acceptable insulation resistance shall
be determined by the formula:
o
C
RM40
= kV + 1 megohm
o
Where RM40 C = minimum insulation resistance of the entire
o
machine winding in megohm at 40 C and kV = Rated
machine potential in kilo-volts.
Measure and record motor winding temperature by portable
RTD meter, or by enclosure temperature by
thermometer if no RTD’s are provided. Convert to
40°C value.
•
The observed resistance reading may be corrected to
40oC by applying the following formula and
temperature coefficients:
RM40oC = RM x T x Tc
Where
RM = insulation resistance in megohm, by test
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
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SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
T=
Tc =
T
Tc
•
PAGE: 66
winding temperature coefficient in oC, as measured
temperature coefficient for the winding temperature
30
0.5
40
1.0
50
2.0
60
4.0
70
8.0
=
=
Temp. of winding
Temp. Coefficient
o
Cold coil resistance (20 C and below) shall not be
used. If winding is 20 oC or below, a heat source shall
be used as hereinafter described to raise the internal
temperature to 20 oC+.
Witnessing Authority to Verify
iv)
If the insulation resistance is below the minimum value, the
machine shall be dried out or replaced. Machine windings
can be dried out by supplying heat from electric strip
heaters, from heat lamps or by passing current through
machine windings. Heat and some circulating air should be
maintained until insulation resistance is acceptable - as
corrected to 40oC. The winding temperature maintained
during the drying-out process shall not exceed the following:
•
Class A Insulation (Class A is no longer in use.) Use
Class B, F or H as applicable
o
By thermometer
80 C
By resistance bridge or thermal sensing
o
resistor circuit (RTD)
90 C
•
Class B or F Insulation
By thermometer
90 oC
By resistance bridge or thermal sensing
resistor circuit (RTD)
110 oC
•
GOC©
The insulation resistance shall be taken at intervals of
2-3 hours during the drying-out process until a fairly
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 67
constant value is reached.
This value shall be a
o
minimum of, at 40 C:
1 Megohm per RATED
KV of Motor +1
Witnessing Authority to Verify
v)
If special motor thermal sensing devices (e.g. RTD’s) have
been installed, test their circuit continuity with a portable
meter and record.
Megger tests on RTD insulation
resistance shall not exceed 250 V.D.C. for 15 seconds.
NOTE:
Thermocouples may be continuity checked by
multi-meter battery only.
permitted.
vi)
No ringer type testers are
Measure the resistance and insulation resistance of motor
winding space heaters and circuits (where specificed).
Witnessing Authority to Verify
vii)
Verify that the motor starter, or variable frequency drive and
associated protective relaying have been tested in
accordance with Procedure 9.4.
Witnessing Authority to Verify
viii)
Start the motor to determine the direction of rotation and
compare this with the required rotation of the driven unit.
Switch leads to correct if necessary, and record data.
Witnessing Authority to Verify
ix)
Have the coupling open to separate the motor from the drive
unit or the belts removed from the belt driven equipment.
Ensure that the motor rotates freely by hand. Manually turn
the shaft and check end play to be within tolerance. Motors
shall be started and “run-in” uncoupled for 30 minutes for
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 68
motors rated 200 horsepower and below, and for 2 hours for
motors above 200 horsepower. Perform vibration tests on
all 460V and higher voltage motors rated 200 horsepower
and larger. Vibration amplitude values shall not exceed the
values reflected by the NEMA Standard.
Witnessing Authority to Verify
NOTE:
In some cases it may be impractical to run the
motor uncoupled. Verify if the motor can be run driving the
equipment, (e.g., flange mounted motors, axial fans, etc.)
and run for the requested length of time if ok.
x)
Measure and record the line current of the free running
motor.
Readings taken on load to be noted on the
Certificate applicable.
Witnessing Authority to Verify
xi)
Have the coupling reassembled and the alignment of the
coupling and end play checked (or have the belts put back
on if belt driven) after the run test. Tag unit completed.
Witnessing Authority to Verify
7.1.2
Certification
Form EE13 Sheets 01 & 02 are to be used for recording the
results of the testing and require endorsement to confirm that the
requirements of this procedure and Procedure 9.15, if appropriate,
have been performed satisfactorily. If applicable, the results of
drying out motor windings, Procedure 9.17, are to be attached to
Form EE13, together with any certificates generated by
implementing Procedure 9.20.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 69
ELECTRICAL PROCEDURES
Procedure No. 9.8
8.1
Batteries and Battery Chargers
8.1.1
a)
Inspection
Pre-Installation
i)
Note the nameplate rating of the charger(s), and number,
type and rating of the batteries supplied. Compare with the
ratings stated on the approved drawings for the equipment.
ii)
Ensure that the equipment Certificates meet the area
classification and specification requirements, including any
ventilation required.
iii)
Inspect the chargers and battery hardware for completeness
of materials for assembly required.
b)
Post-Installation
i)
Inspect battery racks and batteries for proper assembly per
manufacturer’s instructions.
ii)
Check grounding cables and terminations from charger
frame to grid, and assembled racks to grid and bonding
between per NEC and approved drawings. Torque all rack
assembly bolts and grounding connections.
iii)
Ensure that all site installed cables have been tested in
accordance with the Cable Test Certificate, see Procedure
9.1, EE1 Sheet 01 & 02.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
iv)
ELECTRICAL
PAGE: 70
Check cleanliness of battery rooms. Inspect and clean the
interiors of all control panels and chargers. Remove any
temporary silica-gel drying agents from panels and/or
enclosures.
v)
Note the type, size and rating of all associated fuses and
protective devices, and compare with those shown on the
approved drawings and schedules.
vi)
Inspect all batteries for cracks, leaks or other damage.
Check
tightness
and
cleanliness
of
terminals,
and
connection, jumpers and straps.
vii)
Remove any shipping supports and store with the battery
tools for possible future use. Maintain secure storage for all
such items.
viii)
Inspect all bolted connections between individual cells in
each bank of batteries. Ensure that all battery terminals,
straps, posts, bolts, nuts, washers and cable lugs have been
coated with anti-oxidizing compound.
c)
ix)
Where applicable, inspect the battery electrolyte level in all
cells after filling. Verify specific gravity and adjust electrolyte
per manufacturer’s instructions.
x)
Where sealed, gas recombination, lead acid cells are used,
check that cells have been trickle charged in accordance
with manufacturers recommendations during storage.
xi)
Ensure that battery spaces are well ventilated and ventilation
systems are operating properly where applicable.
Inspection Check Out
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 71
The following inspection check out for Battery and Battery Charger
Inspection can assist in the realization and acceptance of EE14
Sheets 01 & 02 Certificates.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
BATTERY AND BATTERY CHARGER
INSPECTION CHECKOUT (Procedure 9.8)
DATE:
JOB NO:
PAGE: 72
SLD No
LOCATION:
SHT
of
MODULE:
INITIAL/DATE
TAG NO: ______________________ SYSTEM VOLTS: ____________________________
1. Receiving Inspection complete.
1
2. Batteries and racks installed and checked for proper mechanical installation, including
2
connections and number of cells.
3. Grounding connection checked. (
MFS/
FCO)
4. Battery charger checked for proper installation, wiring complete and properly
3
4
connected.
5. Check charger nameplate against approved vendor drawings and site specific
5
specifications.
6. Accessory equipment accounted for, and itemized.
6
7. Batteries, battery racks and charger cleaned.
7
8. Terminals and interconnectors covered with protective compound.
8
9. Connection nuts and bolts torqued to XX foot pounds, per vendor instructions.
9
10. Fuses and circuit breakers in accordance with vendor drawings.
10
11. Final inspection complete. Punch list items cleared.
11
REMARKS
REV. 1
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
d)
ELECTRICAL
PAGE: 73
Testing Battery Systems
Refer to NEMA PE-1-1983, “Uninterruptible Power Systems” and
NEMA PW-5-1985 “Utility Type Battery Chargers” for performance
and testing guidelines.
i)
Measure the ground path resistance from the main ground
terminal to the ground grid electrode.
Note that special care must be taken when making tests
with charger electronics connected, due to susceptibility to
damage by over-voltages, and/or harmonics in test power
supply.
ii)
For non-sealed cells, measure and record the specific
gravity of the electrolyte in each cell and compare this with
the recommended values. Inspect the closing plugs to
ensure the vent holes are able to vent properly.
Witnessing Authority to Verify
iii)
Measure the voltage at the terminal of each cell and
compare with the recommended values. Tabulate the
results and ensure that a copy of the checklist remains with
the batteries. (See Certificate EE14 Sheet 01.)
Witnessing Authority to Verify
iv)
When all inspection and tests have been performed, the
batteries may be given their initial charge. This may be
performed under the supervision of the vendor’s
representative on site. (Vendor’s set-up charge instructions
must be followed.) The boost and float charge voltage
settings should be noted. Confirm the current limit settings
and record values.
Witnessing Authority to Verify
Note: Under NO circumstances whatsoever are sealed
cells to be boost charged.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
v)
ELECTRICAL
PAGE: 74
Check the operation of the battery ground fault alarm (where
installed), and measure the ground current amperes for a
zero impedance ground fault. Ensure that the measured
value is below the drop off current level for all shutdown
relays.
Witnessing Authority to Verify
vi)
Check the operation of all alarms and trips including the
main supply and charge failure alarms.
Witnessing Authority to Verify
vii)
Check the operation of the battery charger rectifier failure
alarms and trips (where installed).
Witnessing Authority to Verify
viii)
Measure the level of output voltage ripple at normal load.
Check the load manufacturer’s data that this is within
tolerance.
Witnessing Authority to Verify
Note:
Batteries should never be disconnected with
charger(s) on-line, unless charger is approved for such
service.
ix)
Check the operation of the DC over and under voltage
alarms and trips (where installed).
Witnessing Authority to Verify
x)
Perform a battery discharge test using a procedure
acceptable to the Vendor and BP or delegated authority.
Record the results, including decay graphs, on Vendor test
sheets, and log per Certificate EE14 Sheet 01.
Witnessing Authority to Verify
xi)
Recharge the battery at completion of discharge test, record
the SG of the electrolyte (where applicable), and cell volts.
Copies of these records must remain with the battery bank
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 75
for maintenance records. Use Battery Test Certificate EE14
Sheet 02.
Witnessing Authority to Verify
8.1.2
Certification
Form EE14 Sheets 01 & 02 are to be used for recording results of
the testing and require endorsement to signify the inspection
requirements of the procedure have been performed satisfactorily.
Supplier test sheets are to be attached to Form EE14 for filling in
the Handover Certification Pack (HCP) or, where Vendor Data is
provided, it shall form part of the project dossier.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 76
ELECTRICAL PROCEDURES
Procedure No. 9.9
9.1
Uninterruptable Power Supplies
9.1.1
General
The procedure is preliminary to the inspection and test to be
performed by the equipment Vendor on-site.
9.1.2
a)
Inspection
Post-Installation
i)
Note the nameplate ratings of the equipment and any
auxiliary apparatus and compare with the ratings given on
the approved drawings.
ii)
Inspect the installed equipment for alignment, plumb and
level, check tightness of anchor bolts and supports and
verify shims are in place, where needed.
iii)
Inspect the grounding lugs and cables for the connection to
the grounding system(s). Verify continuity to the system
ground grid.
iv)
Ensure that all on-site installed cables have been tested in
accordance with the electrical Procedure 9.1 and
Test Certificates (Forms EE1 Sheet 01 thru Sheet 04).
v)
Note the type, size and rating of all fuses and protective
devices and compare with requirements shown on the
approved drawings.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
vi)
ELECTRICAL
PAGE: 77
Check for cleanliness and where necessary, clean the
interiors of all control panels and enclosures. Remove any
temporary silica-gel drying agents.
vii)
Perform inspection of the battery charger and batteries in
accordance with Procedure 9.8.
b)
Testing
i)
Perform testing of batteries and battery charger in
accordance with Procedure 9.8.
Complete Certificates
EE14 Sheet 01 & 02 prior to placing UPS in service.
Witnessing Authority to Verify
ii)
Connect UPS output for load to be supplied, in order to
verify UPS capabilities and transfer functions. If loads are
not ready, temporary load banks may be necessary for these
tests.
Witnessing Authority to Verify
iii)
Perform all testing required on form EE15 Sheet 01 and sign
off Certificate.
Witnessing Authority to Verify
iv)
9.1.3
Ensure that all vendor site tests have been completed and
all results recorded on vendor test sheets.
Witnessing Authority to Verify
Certification
Form EE15 Sheet 01 is to be used for recording the results of
the testing and required endorsement to signify that the inspection
requirements of the procedure have been performed satisfactorily.
Certificates for batteries and battery charge tests, together with
originals of Vendor test certificates should be attached to EE15
Sheet 01.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 78
ELECTRICAL PROCEDURES
Procedure No. 9.10
10.1
Lighting and Small Power Distribution System
10.1.1
a)
Inspection
Post-Installation
i)
Verify that the equipment meets the area classification and
specification requirements as described in the design
specification and drawings.
ii)
Note the location and elevation of the lighting fixtures,
panelboards, receptacles, and wall switches. Compare with
the approved drawings. Note that wiring may have to be
field verified for multi-voltage rated lighting fixtures (i.e.,
combination 230/277/480 volt sodium vapor fixtures).
iii)
Note distribution panel labeling and circuit numbering.
Check fuse and/or breakers ratings of the circuits and
compare with the approved drawings. Verify the operation
of any safety features such as mechanical interlocks, circuit
lock-out devices and door switches.
iv)
Ensure that the distribution panel and power supply cable
has been tested and relevant test certificates completed.
v)
Check the grounding bus bar and wire and cable grounding
connections inside the distribution panels. Be sure there are
grounding connections from individual items of equipment to
the grounding bus where detailed on drawings. Verify the
grounding bus bar is properly connected to the grounding
grid per NEC.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
vi)
ELECTRICAL
PAGE: 79
Inspect lighting fixtures, receptacles and switches for
neatness, weather-proofing, cable connections, terminations
and general good installation workmanship.
vii)
As each branch circuit from a distribution panel is inspected,
complete an inspection tag and attach it to the branch circuit
over current device where visible. Tag shall contain the
date, circuit number and name of the inspector.
viii)
All equipment in hazardous locations should be inspected in
accordance with the requirements of Procedure 9.15.
ix)
Perform an inspection of junction boxes in accordance with
Procedure 9.19.
b)
Inspection Check Out
The following inspection check out for Panel Board Inspection and
Lighting and Receptacle Inspection can assist in the realization and
acceptance of the EE16 Sheet 01 Certificate.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PANELBOARD
INSPECTION CHECKOUT (Procedure 9.10)
DATE
JOB NO
PAGE: 80
SLD No
LOCATION
SHT
of
MODULE
INITIAL/DATE
TAG NO: ____________________ VOLTS: ________________ AMPS: _______________
1. Receiving Inspection complete.
1
2. Check assembly for any missing parts.
2
3. Enclosure approved for classification of the area installed.
3
4. Panelboard circuit schedule correctly filled out and installed.
4
5. Correct circuit breakers installed (including GFCI) and correct fuse size (if applicable)
5
per drawing schedules.
6. Neutral wire correctly color coded.
6
MFS
Contractors Installation
7. Grounding installed and connected (wiring is green color coded).
MFS
7
Contractors Installation
8. Seals installed (if required).
8
9. Check for breather and drain (if required).
9
10. Check color coding of branch circuit conductors.
10
11. Panel board has been cleaned.
11
12. Mounting and supports adequate per specification and NEC.
12
13. Nameplate, number of circuits and panelboard location in accordance with approved
13
drawings.
14. Final inspection complete. Punch list items cleared.
14
REMARKS – See Lighting & Receptacle Inspection Check Out for additional circuit requirements on Lighting and
Receptacles
REV. 1
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
LIGHTING & RECEPTACLE
INSPECTION CHECKOUT (Procedure 9.10)
DATE
JOB NO
PAGE: 81
SLD No
LOCATION
SHT
of
MODULE
INITIAL/DATE
TAG NO: ____________________ VOLTS: ________________ AMPS: _______________
1. Receiving Inspection complete.
1
2. Check assembly for any missing parts.
2
3. Enclosure approved for classification of the area installed.
3
4. Panelboard and circuit identification referenced.
4
5. Neutral wire correctly color-coded.
5
6. Grounding installed and connected (wiring is green color coded).
6
7. Seals installed (if required).
7
8. Check for breather and drain (if required).
8
9. Check color-coding of branch circuit conductors.
9
10. Mounting and supports adequate per specification and NEC.
10
11. Fixtures and receptacles are correct type and installed in accordance with drawings.
11
12. Fixtures and receptacles on correct circuit and working; receptacle polarity is correct.
12
13. Ensure tight fit of gaskets on lighting fixtures and that guards and reflectors are fitted
13
and securely fastened in place.
14. Verify minimum lighting levels per specification and NEC.**
14
15. Verify emergency lighting is functional per specification.**
15
16. Final inspection complete. Punch list items cleared.
16
REMARKS
REV. 1
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
c)
ELECTRICAL
PAGE: 82
Testing
i)
Measure branch circuit insulation resistance to ground.
Observe manufacturer’s instructions for light fixtures that
incorporate electronic systems.
Witnessing Authority to Verify
ii)
Test the voltage and polarity of each receptacle, and verify
ground continuity.
ground connectors.
All receptacles must have polarized
Witnessing Authority to Verify
iii)
Carry out illumination tests. Illumination levels are to comply
with the NEC code for interior lighting where no other
statutory or contract illumination levels are specified.
Witnessing Authority to Verify
iv)
Carry out any required testing of protection and/or metering
circuitry in accordance with Procedure 9.20.
Witnessing Authority to Verify
v)
Test operation of emergency lighting systems and prove
battery capacity to sustain lighting for the specified period
(i.e. 1 hour).
Witnessing Authority to Verify
10.1.2
Certification
Results of illumination level checks should be recorded on the
electrical layout drawings and attached to form EE16 Sheet 01.
Form EE16 Sheet 01 is to be endorsed to signify that the
requirements of this procedure, and Procedures 9.15 and 9.19 if
appropriate, have been performed satisfactorily.
Witnessing Authority to Verify
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 83
Originals of test certificates generated by implementing Procedure
9.20 must be attached to EE16 Sheet 01.
NOTE: On occasions where additional light fixtures are tied into
existing circuits, an EE16 form may be used to record that
Procedures 9.10, 9.15 and 9.19 have been performed for the new
installed light fixtures. This avoids the need to re-test the whole
circuit.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 84
ELECTRICAL PROCEDURES
Procedure No. 9.11
11.1
Navigation Aids (Navaids)
11.1.1
General
This procedure is preliminary to the inspection and testing
performed by the equipment supplier at the site.
11.1.2
a)
Inspection
Post-Installation
i)
Note the nameplate rating of the supplied equipment and
compare this rating with that on the approved drawings.
ii)
Check the equipment certification meets
classification and specification requirements.
iii)
Inspect the installation of equipment for alignment, level and
plumb. Check tightness of anchors and supports.
iv)
Ensure that the insides of control panels and enclosures
have been cleaned out.
Remove any temporary
weatherproofing and silica gel from the equipment.
v)
Remove any transit blocking or and binding materials from
the contactors and relays supplied with the equipment.
vi)
Inspect the equipment grounding connections.
enclosures are all bonded to the ground grid.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
the
area
Verify the
GUIDANCE ON CERTIFICATION
SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
vii)
ELECTRICAL
PAGE: 85
Note the size, type and rating of all fuses and protective
devices. Compare with the values stated on the approved
drawings.
viii)
Ensure that all site installed cables have been certified in
accordance with the relevant electrical procedure and test
certificate completed. Ensure that the installation is suitable
for the location of the equipment.
ix)
Ensure that the standby power systems have been tested,
and tagged as such.
x)
Inspect the paint finish, paying particular attention to
externally located equipment. Any damaged areas are to be
corrected.
xi)
Inspect the weatherproofing and bolting of the connection
boxes. Weatherproofing should not be dependent upon the
application of paint, tape or plastic compounds.
xii)
Ensure the appropriate requirements of Procedure 9.15 are
carried out if applicable.
xiii)
When floating platform/barge moors up to fixed installation,
Nav-aid lights are to be synchronized (see applicable
Maritime Laws).
b)
Testing
i)
Perform all testing as required by form EE17 Sheet 01.
Witnessing Authority to Verify
ii)
If applicable, perform testing of batteries and battery
chargers in accordance with Procedure 9.8.
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iii)
ELECTRICAL
PAGE: 86
Ensure that all supplier site tests have been completed to
the satisfaction of any appropriate Statutory Authority and all
results recorded on supplier tests sheets.
Witnessing Authority to Verify
11.1.3
Certification
Form EE17 Sheet 01 is to be used for recording the results of the
testing and requires endorsement to confirm that the requirements
of the procedure, and Procedure 9.15 if appropriate have been
performed satisfactorily.
Originals of Vendor test sheets and test records for batteries and
battery chargers shall be attached Certificate EE17 Sheet 01. A
Vendor Data Book is to be provided, this will form part of the project
dossier.
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PAGE: 87
ELECTRICAL PROCEDURES
Procedure No. 9.12
12.1
Neutral Grounding Resistors
12.1.1
a)
b)
Inspection
Pre-Installation
i)
Note the nameplate ratings of the grounding resistors and
compare with the approved drawings.
ii)
Ensure the equipment certificate meet the area classification
and specification requirements.
iii)
Remove any temporary weather-proofing and any drying
agents (e.g. silica-gel).
Post-Installation
i)
Inspect the neutral grounding resistors for alignment,
tightness of anchor bolts and supports.
ii)
Verify stand-off insulators are correct type, clean and
undamaged.
iii)
Inspect the connections to the neutral grounding resistor
being certain cables are correct size; and terminals are
tightly clamped.
iv)
Inspect the equipment grounding conductor connections,
being certain of correct size cable and connections.
v)
Warning labels are required, advising sudden
temperature of the resistor in event of a ground fault.
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c)
ELECTRICAL
PAGE: 88
Testing
i)
Measure the insulation resistance of the resistor to ground
with incoming and outgoing connections disconnected. Use
1000V D.C. megger, one minute reading.
Measure the
value of the neutral grounding resistor.
Witnessing Authority to Verify
ii)
Test the space heater and circuits where installed.
Witnessing Authority to Verify
iii)
If current transformers have been installed, check that
Vendor test certificates and magnetizing curves are
available, if not, perform tests in accordance with Procedure
9.18.
Witnessing Authority to Verify
iv)
Measure the equipment ground path resistance at the main
grounding terminal to the system ground. Value must be
less than 2 ohms from resistor connection to EARTH
including ground electrode.
Witnessing Authority to Verify
v)
Perform required testing of protective relaying and/or meter
circuitry in accordance with Procedure 9.20.
Witnessing Authority to Verify
vi)
12.1.1
Upon completion of tests, reconnect the incoming and
outgoing cables to bushing to resistor, and resistor to ground
grid.
Witnessing Authority to Verify
Certification
Form EE7 Sheet 01 must be endorsed to confirm that the
requirements of this procedure have been carried out satisfactorily.
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PAGE: 89
Any supporting Vendor test certificates for the current transformer
certificates should be supplied in the Vendor Data Book which
forms part of the Project Dossier. If they are shipped loose, they
should be attached to EE7, together with originals of test
certificates generated by implementing Procedure 9.20.
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SUBJECT:
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PAGE: 90
ELECTRICAL PROCEDURES
Procedure No. 9.13
13.1
Heat Trace Cables and Circuits
13.1.1
a)
Inspection
Pre-Installation
i)
Check that the supplied heater cable is correct as noted in
the design drawings and is rated for the area classification
where it is installed.
b)
ii)
Check that the heater cable is of the correct length.
iii)
Check that the circuit is correct for the voltage rating of the
heater cable.
iv)
Perform insulation tests while cable is on the reel. See EE8
Sheet 02.
Post-Installation
i)
Check that the fuse or breaker rating is correct for the total
circuit loading.
ii)
Check that the heater cable is installed correctly, especially
as applied to high point vents, low point drains, dead legs,
flanges and removable items, such as valves and instrument
or control devices.
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iii)
ELECTRICAL
PAGE: 91
Check that the mounting and grounding of the junction
boxes and thermostats are correct.
NOTE: ALL devices such as separately mounted
controllers, sensors and mounting materials must also be
grounded per applicable codes.
iv)
Perform inspection and tests detailed in Procedures 9.1,
9.15 and 9.19 as required. (Cable wiring and testing,
Hazardous Area Classification and J-Box termination.)
v)
Insulation resistance measurements shall be performed
while the heater cable is on the reel, after initial installation
and upon completion of the of piping or vessel insulation.
c)
Inspection Check Out
The following checkout and Inspection sheets for Heat Trace
Components will assist in the realization and acceptance of the
equipment as required by EE8 Sheet 01 & 02.
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ELECTRICAL
HEAT TRACE COMPONENTS
INSPECTION CHECKOUT (Procedure 9.13)
DATE:
JOB NO:
Line Number
Manufacturer
PAGE: 92
SLD No
SHT 1 of 2
LOCATION:
Heater Number
Model/Cat. Number
MODULE:
Service
Voltage
Wattage
Watts/Foot
INITIAL/DATE
Construction Inspection - General
1. Inspect control panel to ensure proper installation per drawings and specifications.
1
Check circuit breaker ratings and fuse ratings.
2. Verify that installation and connection of the temperature controller is in accordance
2
with the manufacturer’s instructions and wiring diagram, and per project approved
drawings.
3. Inspect the entire assembly for damage and/or missing parts.
3
4. Verify that heat tracing cable ends are properly protected from physical damages and
4
moisture contamination.
5. Inspect for apparent damages such as cuts, cracks or moisture spots.
5
6. Verify that all heat tracing cables are provided with tin plated copper grounding braid
6
and Teflon outer jacket, or equal. Verify catalog type, wattage, voltage rating, and area
classification ratings are correct.
7. Verify that all grommets, connection boxes, end seals and other connection hardware
7
are furnished with correct type and size per manufacturer’s drawings, and per project
approved drawings as applicable.
8. Verify heat tracing power connection/splicing and wiring color code to ensure that phase
8
connections are correct as per drawings, proper connection hardware is used as shown
in drawings, all connection boxes are installed on upper quadrant of the pipe, and heat
shrink boots instead of electrical tape are used for insulating the heat trace core
material.
9. Verify that armored cables for power feeders are adequately supported.
9
10. Verify that heat trace power supply panels are equipped with correct breaker ratings
10
including GFCI’s needed.
REMARKS
REV. 1
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SUBJECT:
ELECTRICAL
HEAT TRACE COMPONENTS
INSPECTION SUMMARY (Procedure 9.13)
DATE:
JOB NO:
Line Number
PAGE: 93
SLD No
LOCATION:
Heater Number
Manufacturer
SHT 2 of 2
Model/Cat. Number
MODULE:
Service
Voltage
Wattage
Watts/Foot
Power Connections, Splices and Tees
1. Power to heater connections, heat trace splices and tees per design drawings, and
INITIAL/DATE
1
correct voltage source.
2. All changes recorded on as-built drawings.
2
3. Correct identification tags installed.
3
4. Junction box and lid gaskets correctly installed.
4
5. Proper grommets installed.
5
6. Outer jacket extends completely through grommet (CT heaters).
6
7. Shield pigtail tight (no loose strands or “whiskers”).
7
8. ½ inch minimum distance between shield and inner jacket cutback.
8
9. Heater bus wires properly stripped (no loose or broken strands).
9
10. Heater bus wires insulated up to terminal block (NOTE: Electrical tape is not
10
acceptable, only heat shrink material is acceptable).
11. Three-phase connections in accordance with manufacturers color code.
11
Transmitter, End Terminations
INITIAL/DATE
1. Correct identification tag installed on each unit.
1
2. Proper sealing gasket installed between transmitter box and base.
2
3. Proper grommets installed.
3
4. Outer Jacket extends completely through grommet (CT heaters).
4
5. Bus wires properly connected to transmitter.
5
a) Insulated with heat shrinkable tubing.
b) #14 AWG insulated wire with butt splice properly crimped.
6. ½ inch minimum distance between shield and outer jacket cutback.
6
7. Heater shield properly insulated with heat shrink tubing.
7
8. Heater shield connected to RTD shield (or green wire) with properly crimped wire joint
8
(T&B #RP-12).
9. Monitor wire cutback, if present (not to be utilized).
REMARKS
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SUBJECT:
d)
ELECTRICAL
PAGE: 94
Testing
i)
Each heater cable shall be subject to an insulation
resistance test when installation is complete. (500V. Megger
per Procedure 9.1.)
Witnessing Authority to Verify
ii)
After all the heater cables on a circuit are installed the
complete circuit shall have its insulation resistance tested
and recorded.
Witnessing Authority to Verify
iii)
After completion of the thermal insulation the circuit should
have its insulation resistance re-checked to ensure no
damage has occurred.
Witnessing Authority to Verify
iv)
13.1.1
The Commissioning Authority shall perform functional
Checkout of the heat trace failure alarm and a SC1 form
filled out.
Certification
Form EE8 Sheets 01 & 02 are to be used for recording the results
of the testing, together with Form EE1 Sheet 02 for
cable testing in accordance with Procedure 9.1. The forms require
endorsement to confirm that the requirements of the procedure,
and Procedures 9.1, 9.15 and 9.19 as
appropriate, have
been carried out satisfactorily.
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PAGE: 95
ELECTRICAL PROCEDURES
Procedure No. 9.14
14.1
Grounding / Bonding
14.1.1
a)
Inspection
Post-Installation
i)
Compare the ground connection type and size with the
schedule, drawings and specifications.
ii)
Where conductors have been terminated using crimped
connections ensure that the correct size and type of crimped
connection has been used. The crimp tool must also be
listed for use with the compression lugs, and must be of the
racket type which releases only after complete compression.
b)
iii)
Ensure all connections are tight and anti-oxidizing grease
applied.
iv)
Be sure all metal assemblies, conduits and J-Box are
bonded together and to ground.
Testing
i)
Each separate grounding point, which may consist of one or
more electrodes, shall be verified with a ground resistance
instrument, certified for accuracy down to 1 ohm or less.
The resistance of each point must not exceed, the figures
stated in paragraph 14.1.1 b) iv) following.
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ii)
ELECTRICAL
PAGE: 96
Perform Fall Of Potential test for soil resistance per IEEE
Standard No. 81, Section 9.04, when required by the
Authority in Charge.
Witnessing Authority to Verify
iii)
Perform the two point method test per IEEE No. 81, Section
9.03, to determine the ground resistance between the grid
connected grounding electrode and all major electrical
equipment frames, system neutral or derived neutral points.
iv)
Alternate Method:
Perform ground continuity test, when
required, between grounding electrode and equipment
frame, system neutral and/or derived neutral point. This test
shall be made by passing a minimum of 10 amperes DC
current between the grounding electrode (at system grid)
and the ground point to be tested. Voltage drop shall be
measured and the resistance calculated by voltage drop
method.
v)
The resistance as measured from any part of the system to
the main ground grid shall not exceed the values noted
below and tests shall be carried out to confirm this:
•
•
•
14.1.2
Electrical Grounding - 1 ohm
Lightning Protection - 7 ohms
Static Bonding - 10 ohms
Certification
Form EE9 Sheets 01 & 02, are to be used for recording the results
of the grounding tests.
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PAGE: 97
ELECTRICAL PROCEDURES
Procedure No. 9.15
15.1
Equipment for Use in Hazardous Locations
15.1.1
a)
Inspection
Post-Installation
The following is a general inspection guide for all types of
equipment installed in hazardous locations (or specified and
installed in unclassified locations). The particular requirements for
special equipment used in these locations will be listed individually
hereafter and should be read in conjunction with BP Specification
E-309 and Article 500, 501 and 505 of NFPA-70 (N.E.C.).
i)
Check to see that the equipment is listed and labeled for use
in the installed area classification, the surface temperature
(T rating) is correct and any special considerations on the
Vendor data have been confirmed and accepted by the
Witnessing Authority.
ii)
Ensure that all bolts, cable terminations, conduit seals and
plugs are wrench tight and the enclosure gaskets are
installed in good condition.
iii)
Inspect and clean the interior of the equipment of dust or dirt
accumulation. Ensure that all electrical connections are
tight. A check should also be made that any needed
protection is adequate for the equipment rating.
iv)
Where applicable, ensure that cable and conduit sealing
compound is correctly applied to avoid ingress of hazardous
material.
Inspect seal packing to ensure adequate
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PAGE: 98
separation of conductors, and the compound installed is per
manufacturer’s specifications.
v)
Inspect the equipment grounding for integrity and all joints
are properly tightened.
vi)
Ensure there is no damage to the equipment and it is
adequately protected against corrosion, weather, vibration
and other adverse factors pertaining to the installation.
Check and inspect any electrical cables for sign of distress
or damage.
vii)
Ensure that lamp rating and type are correct for any lighting
fixtures installed.
viii)
Where guards are used, ensure that they are correctly
located and secure. Verify motor fans and/or couplings are
not rubbing or contacting housings or guard covers.
b)
Additional Checks
The following additional checks are required on special equipment
as listed:
Explosion Proof Enclosures (Class 1 Division 1 or “Zone” Equivalent):
i)
Obstructions in the vicinity of the equipment do not block the
path of door openings or impede air ventilation around the
equipment.
ii)
All cover door gaps (per machining tolerance) are correct
and free from corrosion, dirt and paint.
iii)
All conduit runs are wrench tight, free from corrosion, and
meet classification requirements per NEC.
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iv)
ELECTRICAL
PAGE: 99
All unused conduit or fitting openings are plugged and
sealed.
NOTE: Any spare conduits must be sealed off the same as
if there were wiring installed in it.
c)
Intrinsically Safe Installations (See NEC-Article 504)
NOTE: Any equipment used as “Intrinsically Safe” must be
so labeled and certified to meet this standard.
i)
All installations should be inspected to ensure that any cable
or wiring shields are grounded in accordance with the
relevant standard drawings.
No “floating” shields are
permissible.
ii)
All diode safety barrier installations are to be inspected to
ensure that the correct type of barriers have been installed.
They must remain firmly fixed to the barrier ground bus.
iii)
Boxes containing diode safety barriers and junction boxes
must be inspected to make sure that they do not contain
wiring other than that specified in the documentation for the
intrinsically safe system. All such wiring must be segregated
from any non-intrinsically safe wiring.
iv)
All installations should be inspected to ensure that relays
and similar devices, which act as safety barriers between
circuits, have not become damaged by repeated operation
or vibration. Such damage may reduce the segregation
afforded, causing loss of the safety intended.
v)
The ground path resistance must be measured from the
safety barrier to a certified grounding conductor.
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d)
ELECTRICAL
PAGE: 100
Purged Pressurized Equipment (See NEC 500-4, and NFPA-496):
i)
The purge medium must be from an uncontaminated
source, which is isolated from any hazardous material.
ii)
Any filters are clean and accessible, and approved for the
area and enclosure. In-line filters only are permitted.
iii)
The purge system should be thoroughly checked to ensure
that the purge pressure, cycle times, interlocks, lock-out
sequence, and alarm provisions are intact and operating
properly.
iv)
All purged pressurized equipment shall meet the requirements of
NFPA-496.
e)
General
The described grounding requirements of any of the classified
equipment described must meet the requirements of Article 250 of
the National Electric Code, as well as Articles 500-505 as
applicable.
f)
Testing
The diversity of equipment and special components, which are
contained in a particular type of apparatus, does not permit a
generalization of the testing required to demonstrate suitability for
service in a hazardous location. Special requirements for testing
may be contained in BP Specification E-327 or specific IEEE
standards and should be compiled, prior to final energization of the
circuit.
Vendor documentation shall be examined to ensure that electrical
components and equipment are listed and labeled for the use
specified as required by the National Electrical Code, U.L., F.M. or
appropriate NRTL standards.
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SUBJECT:
15.1.1
ELECTRICAL
PAGE: 101
Certification
There is no specific standard form for recording that the
requirements of the procedure have been implemented; Form
EE10 Sheet 01 should be used to record the results of any testing
required by BP Specification E-327, specific IEEE Standards or
applicable NRTL standards.
All Certificates necessary for approval by the Witnessing Authority,
refer to the requirement that all equipment be certified as approved
for the Area Classification in which it is installed.
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PAGE: 102
ELECTRICAL PROCEDURES
Procedure No. 9.16
16.1
Oil Insulation Tests
16.1.1
General
A separate procedure for oil-filled electrical equipment will be
produced, if any new Projects have oil-filled electrical equipment in
their work scope.
Local site procedures will be used when any project interfaces with
existing oil filled equipment.
See Section 9.6 for transformer oil testing requirements.
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PAGE: 103
ELECTRICAL PROCEDURES
Procedure No. 9.17
17.1
Drying of Electrical Rotating Machinery
17.1.1
a)
Drying of Windings in Rotating Electrical Machinery
Following testing per Procedure 9.7.1.1 (d), if motor test data
reveals of P.I. of 2.5 or less, and insulation resistance is less than
(
b)
Rated Volts + 1
megohms, drying out may be necessary.
1000
)
i)
The application of drying heat to the winding must be
carefully controlled. The use of high intensity heat sources
must be avoided at all times due to possible damage to
insulation.
ii)
Heat must be applied gradually, regardless of the method
used.
The internal winding temperature should not be
increased more rapidly than about 5°C per hour. A means
of temperature monitoring, either by thermometer or RTD’s
attached to the winding, (and to bearings to prevent
overtemperatures there!) must be provided. Readings every
30 minutes to 1 hour are to be taken, along with insulation
tests to track improvement. (See typical curve in 17.1.2).
iii)
Internal space heaters for the unit should be energized for
the drying period, but they will not be effective for drying.
The purpose of these heaters is only to inhibit condensation
while the unit is not energized, and they will not provide
sufficient heat for drying out insulation.
iv)
Regardless of the heating method for drying, clean air
circulating through or over the unit is essential for purging
damp air out of the winding.
Drying of Motors Using Internal Heating
i)
Internal heating is obtained by circulating a low voltage AC
or DC current through windings. The circulating current
should not exceed 25% of the rated full load AC current and
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PAGE: 104
the allowable must be adjustable to maintain the desired
level of current.
NOTE: Necessity to monitor winding temperature rise per
17.1.1 a) i).
ii)
If AC is used for drying larger squirrel cage induction motors,
the rotor temperature also shall be monitored. If the rotor
temperature rise is too rapid, it may be advisable to remove
the rotor from the assembly. Wound rotors need not be
removed, but the end turns of the rotor windings shall be
monitored for undue temperature increase.
iii)
When using the current circulated method of drying the
winding, initial measurement of temperature shall be taken
every 15 minutes during the first 2-3 hours to detect any
undue temperature rises before damage occurs. For wound
rotor motors, which are dried by current circulation, the
drying current shall not be applied to the rotor via the
brushes. This could cause hot spots at the contact areas
between the brushes and slip-rings or commutator.
iv)
c)
Dry, clean air must be constantly circulated to assist in
purging moisture.
Witnessing Authority to Verify
Drying of Motors Using Internal Heating
i)
When drying equipment using external heaters, the
machinery should be and clean air ventilated through
appropriate in and out openings.
ii)
The size of the heater used is dependent upon the machine
frame, and surrounding ambient conditions.
As an
approximate guide, the following relationship may be used:
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Heater Size (KW) = Weight of Machine (Kg) or Weight in Pounds
1000
2500
Witnessing Authority to Verify
iii)
It is also acceptable to use baking ovens, such as is
available at motor repair facilities. Heat temperature in a
well equipped, thermally controlled oven with venting and
circulating air can be set to 115°C max. The entire motor
with access covers and plugs removed can be set inside the
oven while drying out.
17.1.2 Typical Drying Curve
R3
Insulation
Resistance
-------------------------
R1
(MEG OHMS)
R2
R1
=
Time (Hours)
Resistance of windings at start of drying out process.
R2
=
Minimum resistance of windings (due to vaporization, etc.).
R3
=
Final resistance of windings.
17.1.3
Certification
Is to be used to record results. All results are to be recorded,
retained with the graphs and attached to the motor test Certificates,
Form EE13 Sheets 01 & 02.
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PAGE: 106
ELECTRICAL PROCEDURES
Procedure No. 9.18
18.1
Instrument Transformer Verifications
18.1.1
a)
Inspection
Post-Installation
i)
Check the nameplates on the current transformers to make
sure they are the correct class, type and ratio for the duty
called for on the IFC and Vendor drawings. Verify they are
mounted in the locations per drawings.
ii)
Inspect the mounting brackets for the C.T.’s insuring that
they are securely fixed. Check to be sure of no damage
during transportation. Also be sure that adequate clearance
is given to the C.T.’s from moving parts of switchgear, and
from possible interference with cables scheduled for
installation in the gear.
iii)
Confirm electrical polarity marks are visible on all current
and potential transformers, or such is shown on transformer
nameplates.
iv)
Verify C.T.’s are equipped with secondary shorting terminal
blocks and they are in the shorted position until circuits are
complete. Also check to be sure the secondary wiring from
the C.T.’s are terminated in short circuiting, type terminal
strips, accessible to technicians.
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b)
ELECTRICAL
PAGE: 107
Testing
i)
Measure insulation resistance of transformer secondary
winding and leads with 1000V megger, with ground lead
lifted and electronic devices protected.
(Both C.T.’s and
P.T.’s)
Witnessing Authority to Verify
ii)
Measure transformer primary insulation with applicable overpotential tests. Consult manufacturer for proper voltage and
procedure.
Witnessing Authority to Verify
iii)
Verify wiring at the C.T. secondary leads by connecting a
low value of current through the leads, and taking readings
at the applicable relaying and metering devices connected to
the transformer secondary circuit. A low range clamp on
ammeter may be used to read currents.
Witnessing Authority to Verify
iv)
After pulling primary P.T. fuses, proceed to verify wiring of
the P.T. secondary leads by applying a low voltage to the
leads and checking for this voltage at the potential input
terminals of metering and/or protective devices.
Witnessing Authority to Verify
v)
Replace P.T. primary fuses after these tests. When P.T.
circuits are fully energized, check for P.T. KVA load with
secondary voltage and current measurements, when
required. Load must be less than the Volt-Amp capacity of
the P.T.
Witnessing Authority to Verify
vi)
Testing, to determine the magnetizing characteristics of
current transformers is performed by the Supplier after
assembly. Supplier test certification should be checked for
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GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
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PAGE: 108
completeness and accuracy. ANSI characteristics must be
supplied by certified test data from the manufacturer.
It is not necessary to perform such testing on-site. If C.T.
test data is not given, the vendor will be responsible to
provide the certified data, or perform the tests, or secure
services of the manufacturer to do so.
Witnessing Authority to Verify
c)
Test Procedure
i)
Any magnetizing curve testing must be done by the
vendor/manufacturer of the transformers. This would only
be required if insufficient certified test date is provided with
the equipment.
ii)
Verifying ratio of P.T.’s and C.T.’s can be done with variable
voltage and/or variable current sources commonly available
with portable test sets for metering and/or protective relay
checks.
18.1.2
Certification
Form EE11 Sheet 01 is to be used for recording the results of
ratio testing, and requires endorsement to confirm that all
requirements of the procedure have been performed satisfactorily.
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BP Exploration 1989 - 2001 All Rights Reserved
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SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 109
ELECTRICAL PROCEDURES
Procedure No. 9.19
19.1
Junction Box Inspection
19.1.1
a)
Inspection
Post-Installation
i)
Ensure that the junction box location is correct as reflected
by IFC drawings.
ii)
Check that the J-Box is suitable for the Area Classification
specified.
iii)
Ensure that the junction box is adequately supported and
permanently labeled for cable i.d., drawing numbers, and
source location.
iv)
Check
internal
terminal
types,
size,
support
and
identification. Be sure all are correct, listed and labeled for
the use specified. Verify all wiring is tagged and color-coded
per specs and/or drawings.
v)
Ensure that the grounding connections, internal and
external, are correct and all connections are tight.
vi)
Inspect to see that cable terminations and accessories are
correctly installed, and any unused cable entries are plugged
and sealed per area classification needs.
vii)
Ensure that gaskets are correctly installed, as required, with
proper lubricant for preserving gasket quality.
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REVISION: 1
SUBJECT:
viii)
ELECTRICAL
PAGE: 110
Check that the box covers are correctly sealed, and all bolts,
latches and/or clamps are in place and tight.
ix)
For hazardous area locations, Procedure 9.15 must be
followed.
b)
Testing
No testing of junction boxes is required, with the exception that a
ground continuity test must be performed, and results logged in
Inspection Check Out.
19.1.1
Certification
There is no specific standard form for recording that the
requirements for the procedure have been implemented.
The following forms however, make reference to relevant
procedures and require endorsement to confirm that the junction
boxes and the standard of installation is suitable for the intended
service:
EE1, EE8 and EE16 Sheet 1 General Test Certificate
(For Panel Board Inspection checkout).
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BP Exploration 1989 - 2001 All Rights Reserved
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SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 111
ELECTRICAL PROCEDURES
Procedure No. 9.20
20.1
Protective Relay and Metering Circuit Testing
20.1.1
a)
General
The equipment covered by the following procedures may require
testing of protective relaying and/or meter circuitry by means of
primary and/or secondary injection, as required by the Witnessing
Authority. Form EE12 Sheet 01 and/or Sheet 02 required.
Procedure:
•
9.2 - Switchgear, Motor Control Centers and Metal Enclosed Bus
Duct
•
•
9.3 - Circuit Breakers - Air, Molded Case and Oil Immersed
9.4 - Contactor Starters
•
9.5 - Medium Voltage Air Switches
•
•
•
•
9.6 - Power Transformers - Oil Filled and Dry Type
9.7 - Motors
9.10 - Lighting and Small Power Distribution
9.12 - Neutral Grounding Resistors
Owing to both the variety of schemes and the diverse types of relays in
use, no attempt has been made to produce a standard testing
procedure. Each relay requires an Inspection Report, Form EE12
Sheet 03.
Witnessing Authority to Verify
b)
Testing
i)
All relay tests shall be made by, or under the supervision of,
a qualified electrical engineer (typically from a specialty
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SUBJECT:
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PAGE: 112
contractor, or technical testing service, equipped and
experience to do this work).
ii)
Every protective relay shall be inspected, tested, tagged and
dated by the service company performing the work.
iii)
Records on all relay and/or meter tests shall be completed
and made a part of the equipment Certificate record for that
equipment.
iv)
Relay test Certificates are required for each protective relay,
according to the application type per Forms EE12 Sheet 04
thru EE12 Sheet 10. If the relay is of a type not covered by
the Forms, the installer/tester is to provide a suitable form
with typical format. It may also be expedient to use one
furnished Form by changing the title and adding new sheet
numbers.
Witnessing Authority to Verify
20.1.2
Certification
i)
Certification of protective relay testing and calibration shall
be documented on forms EE12 Sheet 01 thru EE12 Sheet
10.
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GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
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PAGE: 113
ELECTRICAL PROCEDURES
Procedure No. 9.21
21.1
Generators, AC
21.1.1
a)
Inspection
Pre-Installation
i)
Note the nameplate ratings of the generator(s) and compare
with those given in the approved drawing and generator data
sheets. Note any special instructions regarding auxiliary
equipment. Be sure all material is on hand per the
installation drawings, including any auxiliary items such as
surge packs, terminal boxes, connection lugs and bearing
probes shipped with the unit.
ii)
Ensure equipment certification (nameplate data) meets the
appropriate
area
requirements.
b)
classification
and
specification
Post-Installation
i)
Ensure that any shaft blocking or shipment packing has
been removed. Rotate shaft by hand prior to energizing the
drive unit.
ii)
Without dismantling the generator, inspect as far as
possible: through bearing sight glass for oil rings, oil levels if
required, and other lubricant needs such as grease packing
for bearings. Inspect for any signs of lubricant leakage, and
provide report data on such.
Follow manufacturer’s
instructions for “flushing” bearings prior to starting.
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iii)
ELECTRICAL
PAGE: 114
Inspect the paint finish of the generator for damage during
installation. Any damaged areas are to be repainted, using
the BP approved process per purchase specifications.
iv)
Inspect the weatherproofing and bolting of all connection
boxes. Sealing shall not be dependent upon the application
of paint, tape or plastic compounds. All bolts must be in
place and torqued to the proper tightness, except when
covers need to be open for work in progress. Supervisor is
responsible to see that the covers are all secured and bolts
in place during the time there is no work being done.
v)
Inspect the stator winding connections: Check to see if the
line connections needed are for star or delta connection, and
be sure the correct terminal access is available for that
configuration.
vi)
Inspect the grounding terminals and the connections for the
ground grid system, including those inside the terminal box.
There must be at least two provisions on the generator
frame (on alternate corners) for attaching grounding cables.
Terminal box grounding lugs must be bonded to the frame
ground and incoming line ground conductors.
vii)
Check to see that all requirements of Procedure 9.15
(Hazardous Location Classifications) have been met for the
performing of electrical tests, and will overall satisfy the
installation requirements.
c)
Complete the “AC Generator Inspection Checkout” list after
performing the winding insulation tests in Section 9.21.1.2
following.
21.1.2
Testing Prior to Connecting Power Cables (See IEEE-43, 1991;
Recommended Practices for Testing Insulation Resistance of
Rotating Machinery, and NEMA MG-1 for Factory Test Standards.)
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SUBJECT:
a)
ELECTRICAL
PAGE: 115
Megger test winding by the following table for voltage and minimum
values, holding voltage one minute before reading the final value.
All RTDs should be shorted to ground during these tests.
Generator Volts
Winding Type
Megger Volts
Minimum Megohms
480-600
3ph ungrd. Wye
500v all leads
1.0 at 40°C
2300-4160
3ph ungrd. Wye
1kv, all leads
Kv + 1.0 at 40°C
2300-4160
13.2Kv-13.8Kv
3ph, 6 leads
3ph, 6 leads
1kv, 1ph w/2 gnd*
5kv min, 1ph w/2 g*
Kv + 1.0 at 40°C
Kv + 1.0 at 40°C
* Denotes energizing one phase while grounding the other two. Rotate
connections to finally test all three phases, one at a time. Record each
reading and winding temperature, and correct to 40°C.
b)
Correcting megger readings to 40°C
The observed resistance reading may be corrected to 40°C by
applying the following formula and temperature coefficients:
RM 40°C = RM x Tc
Where
T=
TC=
RM = insulation resistance in megohm as read
winding temperature in °C
temperature coefficient for the winding temperature
Winding Temperature
Temperature Coefficient
(°C)
(T C)
30
0.5
40
1.0
50
2.0
60
4.0
70 **
8.0
** Cold coil resistance (20°C and below) shall not be used, and a
heat source shall be used as hereinafter described to raise the
machine temperature to a minimum of 20°C.
Witnessing Authority to Verify
c)
For large units, performance of an insulation polarization index (PI)
test is advised as part of the procedure for megger testing,
especially if the unit winding has been exposed to moist or
contaminated air. (See Section 4.5 of IEEE 43.) If the insulation
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SUBJECT:
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PAGE: 116
resistance is below the minimum allowed value, the machine shall
be dried out or replaced. Machine windings shall be dried out by:
supplying heat from electric strip heaters, from heat lamps or by
passing current through machine windings until a sufficient
insulation resistance is obtained. It may be necessary to circulate
dry, warm air through the winding or bore during the drying out
process.
d)
The temperature maintained during the drying-out process shall not
exceed the following:
• Class B or F insulation
by thermometer
• By resistance bridge or thermal
sensing resistor circuit (RTD)
90°C
110°C
• The insulation resistance shall be taken at intervals of 4-5 hours
during the drying-out process until an acceptable value is
reached. This value in megohms shall be at least equal to 1
megohm per Kv of voltage rating, with a minimum of 1 megohm.
Witnessing Authority to Verify
e)
If special generator protective devices (e.g. thermo-couples or
RTD’s) have been installed, test their circuit continuity to the
terminal blocks mounted on the frame, or to the connection end of
the wires from each. Verify insulation integrity on ungrounded
leads, by applying resistance-measuring meters.
(Special
precautions are necessary before attempting to apply more than
250V D.C. megger voltage to RTD’s. Never attempt higher than
ohmmeter voltages to check thermocouples.)
Measure the circuit resistance and insulation resistance of
generator space heaters.
Witnessing Authority to Verify
f)
Verify that the excitation system, prime mover protection and
associated protective devices have all been tested in accordance
GOC©
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SUBJECT:
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PAGE: 117
with Procedure 9.20 and industry standards (i.e., NEMA MG-1 &
IEEE).
g)
MV and/or HV generator windings may require Doble (or equal)
power factor testing as part of acceptance. If the manufacturer at
their plant does this, test data must be part of the documents
provided with the unit.
If Doble tests are done in the field, Certificate EE18 Sheet 02 is
required. On units rated at 6000 volts or above, PDA testing is
also required and is tabulated on the same sheet. Special test
equipment and technicians are required for these tests.
21.1.3.
a)
AC Generator Inspection Check
At this point, review the items on the “AC Generator Checkout”
sheet, on the following page and execute the items required to
complete.
Witnessing Authority to Verify
b)
After completion of the Checkout items, proceed with the following:
i)
ii)
Have the coupling disconnected to separate the generator
from the drive unit, or the belts removed from the belt driven
equipment. Ensure that the generator rotor can be turned
freely and the rotor endplay is within tolerance. Verify
alignment to the prime mover is within tolerance.
After the unit is connected and the prime mover running,
perform vibration tests on all 460V and 4000V generators
rated 200 kilowatts and larger. Vibration amplitude values
shall not exceed the values reflected by the NEMA MG-1
Standard.
Witnessing Authority to Verify
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SUBJECT:
c)
ELECTRICAL
PAGE: 118
Certification
Form EE18 Sheets 01 & 02 are to be used for recording the results
of testing. These pages require endorsement to confirm that the
requirements of this procedure and Procedure 9.15, if appropriate,
have been performed satisfactorily. If applicable, the results of
drying out generator windings, Procedure 9.17, are to be attached
to Form EE18 Sheet 01. Also include and attach any certificates
generated by implementing Procedure 9.20 (Metering and Relay
Testing) for generator devices supplied by the vendor.
GOC©
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SECTION 9.0
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
ELECTRICAL
AC GENERATOR
INSPECTION CHECKOUT (Procedure 9.21)
DATE
JOB NO
PAGE: 119
SLD No
LOCATION
SHT
of
MODULE
INITIAL/DATE
GENERATOR TAG NO: ____________________ FUNCTION: ____________________
1. Nameplate data agrees with specifications, plan drawings & one-line diagram.
1
2. Frame type is suitable for use in area classification required.
2
3. Maximum Temperature Code:
3
4. Check that the power and control cables insulation resistance tests are complete prior
4
to connection to generator. (Megger & Hi-Pot as required.) NOTE: If winding hi-pot is
required - follow manufacturer’s recommended procedure to maintain in warranty.
5. Review generator insulation resistance test data at Procedure 21.1.2 .
5
6. Grounding conductors installed, connected and bonded per NEC.
6
7. Generator splices and terminations complete. Unused cables or leads on multiple
7
voltage generators are properly insulated and/or terminated.
8. Generator electrical accessories are properly connected, such as space heaters,
8
thermocouples, RTDs, vibration switches, or auxiliary devices
9. Maximum overtemperature switch (if provided) is wired into control circuit of the
9
generator circuit breaker.
10. Grounding bond jumpers installed, bolts and nuts are tightened. Grounding
10
connections properly made up to equipment and plant grid ring.
11. Control station nameplate installed, including identification of all external wiring sources
11
and power provisions.
12. Covers are installed, bolts and nuts are tightened.
12
13. Final inspection Complete. Punch list items cleared.
13
REMARKS (clarification of instructions or comments):
See 21.1.2 g) for other tests on MV & HV generators.
Add remarks regarding any special tests required (such as EE17 Sheet 01 for example).
REV. 1
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REVISION: 1
SUBJECT:
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PAGE: 120
• Functional Certification Flowchart 9
• Discipline: Electrical Equipment & Cables (includes Control
Cables)
POWER DOWN
POWER UP
EE1
EE2
EE3
EE13
EE4
EE14
EE5
MC1
EE15
SC1
SH1
EE6
EE16
EE7
EE17
EE8
EE18
EE9
EE10
EE11
EE12
For Certificate title refer to Exhibit 9
EE1
EE2
EE3
EE4
EE5
EE6
EE7
EE8
EE9
LV & MV Cables, all
Switchgear, MCC, Bus Duct
LV & MV Circuit Breakers
Contactor Starters & VSD’s
M.V. Fused Air Sws.
Power Transformers
Neutral Grounding Resistors
Heat Trace
Electrical Grounding
EE10 Hazardous Locations
EE11 Instrument Transformers
EE12 Primary & Secondary Injection Relay Tests
EE13 Electrical Motors & Rotating Machinery
EE14 Battery Tests
EE15 UPS Load Test
EE16 General Test Certificate **
EE17 Navigational Aids
EE18 AC Generators
** Can be used in both Construction & Commissioning Phases
GOC©
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SECTION 9.0
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REVISION: 1
SUBJECT:
ELECTRICAL
PAGE: 121
EXHIBIT 9
STANDARD FORMS
Form Number
Test Certificate Description
EE1
LV / Shielded Instrument Cable
Cable and Wire Insulation, Insulation Resistance
EE2
SHT 01
02
03
Cable D.C. High Potential Step Voltage
04
Insulation Resistance and DC Hi-Pot Graph
SHT 01
02
EE3
SHT 01
Switchgear Bus Insulation and Phasing
MCC Bus Insulation and Phasing
LV Power Circuit Breaker
02
Molded Case Breakers
03
04
Med. Voltage Circuit Breaker
High Voltage Limited Oil Interrupter
EE4
SHT 01
02
03
Contactor Type Starter
Motor Thermal Overload Relay
Variable Speed Drives
EE5
SHT 01
Medium Voltage Air Switch Inspection
EE6
SHT 01
02
03
Two Winding Power Transformer
Transformer Turns Ratio (Requires Sketch on Back)
Three Winding Power Transformer
EE7
SHT 01
Neutral Grounding Resistor
EE8
SHT 01
02
Heat Trace Tape Inspection (Electrical)
Heat Trace Performance (Electrical)
EE9
SHT 01
02
Electrical Ground System Test
Grounding Resistance Test (Individual Electrodes)
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SUBJECT:
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PAGE: 122
STANDARD FORMS
Form Number
Test Certificate Descriptoin
EE10
SHT 01
Hazardous Location Certificate
EE11
SHT 01
Instrument Transformer Ratio Tests
EE12
SHT 01
02
Primary Injection Test
Secondary Injection Test
EE13
03
Relay Inspection (Individual units)
04
Overcurrent Relay Test
05
Instantaneous Overcurrent Relay Test
06
Over/Under Voltage Relay Test
07
Power Factor Relay Test
08
09
Frequency Relay Test
Transformer Differential Relay Test
10
Reverse Power Relay Test
SHT 01
02
Motors and Motor Circuits, Phase Rotation & Tests
Rotating Machinery
EE14
SHT 01
02
Battery Load Test (Bank)
Individual Battery Test Log
EE15
SHT 01
UPS Power Supply
EE16
SHT 01
General Test Certificate
EE17
SHT 01
Navigational Aids
EE18
SHT 01
02
AC Generator and Generator Circuits Test
Rotating Machinery (AC Generator) Test (Individual Unit
P.F. and PDA tests)
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SUBJECT:
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PAGE: 123
STANDARD FORMS
DIS6
Data Input Sheet 6 – Electrical Cables
DIS7
Data Input Sheet 7 – Electrical Equipment
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Project Title:
SH1 No:
Maintenance No:
MC1 No:
Work Pack No:
Package No:
FORM EE1 – SHT 01
(SIDE 1)
SITE:
Source/Equipment No:
LV / SHIELDED INSTRUMENT CABLE TEST CERTIFICATE
CABLE VOLTAGE RATING
MEGGER USED/CAL. DATE
MEGER VOLTAGE
ENVIRONMENTAL
CABLE No.
DRAWING REFERENCE(s)
CORES
SIZE
MODEL NO.
TEMP/HUMIDITY/AMB
IR TEST
CABLE SCHEDULE
INFORMATION
SHT
CONTINUITY
CORE
CORE TO
CORE
SCREEN
TO
CORE
ARMOUR
SCREEN
OHMS
ARMOUR
OHMS
MOHMS*
MOHMS*
SCREEN ARMOUR
CONTINUITY
TO EARTH
OHMS
OF
SERIAL NO.
*MINIMUM RESISTANCE VALUE IN MEG OHMS
PROCEDURE COMPLETE
(DELETE AS APPROPRIATE)
9.1
9.15
9.19
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
COMPLETED
BY
DATE
APPROVED BY
DATE
USUALLY INDIVIDUAL CONDUCTORS IN A CABLE WILL HAVE SIMILAR VALUES OF INSULATION RESISTANCE. HOWEVER, WHERE THEY DIFFER, THE VALUE STATED ABOVE SHOULD BE THE
LOWEST. IF THEY DIFFER BY A SIGNIFICANT AMOUNT, THIS COULD BE AN INDICATION OF DAMAGE OR POOR WORKMANSHIP AND SHOULD BE INVESTIGATED.
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DOUBLE SIDED FORM
Americas REV. 1
IR TEST
CABLE No.
DRAWING REFERENCE(s)
CABLE SCHEDULE
INFORMATION
CORES
SIZE
CONTINUITY
CORE
CORE TO
CORE
SCREEN
TO
CORE
ARMOUR
SCREEN
OHMS
ARMOUR
OHMS
MOHMS*
MOHMS*
SCREEN ARMOUR
CONTINUITY
TO EARTH
OHMS
PROCEDURE COMPLETE
(DELETE AS APPROPRIATE)
9.1
9.15
9.19
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
YES/NA
COMPLETED
BY
DATE
APPROVED BY
DATE
USUALLY INDIVIDUAL CONDUCTORS IN A CABLE WILL HAVE SIMILAR VALUES OF INSULATION RESISTANCE. HOWEVER, WHERE THEY DIFFER, THE VALUE STATED ABOVE SHOULD BE THE
LOWEST. IF THEY DIFFER BY A SIGNIFICANT AMOUNT, THIS COULD BE AN INDICATION OF DAMAGE OR POOR WORKMANSHIP AND SHOULD BE INVESTIGATED.
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DOUBLE SIDED FORM
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
CABLE AND WIRE INSULATION
INSULATION RESISTIVITY CERTIFICATE
DATE
JOB NO.
FORM EE1 - SHT 02
SITE:
SHT of
SLD No:
LOCATION
MODULE
CABLE VOLTAGE RATING
MEGGER USED/CAL.DATE
MEGGER VOLTAGE
MODEL NO.
SERIAL NO.
ACCURACY/FULL SCALE READING
REFERENCES:
ENVIRONMENTAL
TEMP.
MINIMUM RESISTANCE VALUE IN MEG OHMS
ONE MINUTE TESTS
SEALS
CABLE BLOCK
CONTINUITY
CABLE/CONDUIT NO./TO-FROM
COMPLETE
COMPLETE
CHECKED
COMPLETED BY
WITNESSED BY
ACCEPTED BY
RACEWAY
SYSTEM
INSPECTED
CONDUCTORS
TO
OVERALL SHIELD
CONDUCTORS
TO
CONDUCTORS
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
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Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE1 - SHT 03
SITE:
CABLE DC HIGH POTENTIAL
STEP VOLTAGE TEST CERTIFICATE
DATE
JOB NO.
LOCATION
CONDUIT CABLE NO.
RATED KV
CABLE INSULATION
SHT of
SLD No
MODULE
CABLE SIZE
MANUFACTURER
REEL NO.
FROM
CABLE LENGTH
TO
EQUIPNT USED (FOR TEST)
AMBIENT TEMPERATURE
SERIAL NO.
MODEL NO.
HUMIDITY
ENVIRONMENTAL CONDITIONS
NO. OF
TYPE OF TERMINATION NO. OF
°F
TYPE OF
SPLICE
TEST KV
5 KV
15 KV
CABLE CABLE
TIME
LEAKAGE CURRENT
TIME VS. CURRENT DATA
INT.
(MICRO-AMPS)
FOR GRAPH
15 MIN.
MAX.
PHASE A
PHASE B
PHASE C
LEAKAGE CURRENT
TO SHIELD TO SHIELD TO SHIELD
PHASE A
5
15
15 SEC.
10
20
30 SEC.
15
25
45 SEC.
20
30
1 MIN.
23
35
2 MIN
25
40
3 MIN.
45
4 MIN.
50
5 MIN.
53
6 MIN.
55
PHASE B
PHASE C
7 MIN.
REMARKS:
8 MIN.
9 MIN.
10 MIN.
11 MIN.
12 MIN.
13 MIN.
14 MIN.
15 MIN.
16 MIN.
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
SH1 No :
Maintenance No:
MC1 No :
FORM EE1 SHT 04
SITE:
Work Pack No:
Source/Equipment No:
INSULATION RESISTANCE AND DC HIGH POTENTIAL GRAPH OF TEST DATA
DATE
MANUFACTURER
CABLE MFR
TEMPRETURE
JOB NO.
LOCATION
MODULE
MODEL NO
CABLE RATING
HUMIDITY
SETTING
INSULATION TYPE
VOLTAGE INCREMENTS
SHT
OF
EQUIPMENT NO
SERIAL NO
CONDUCTOR SIZE
STABILIZATION TIME
ACCURACY
MICROAMPS
M IN U T E S ___ ____ (1 vs. T IM E )
D C T E S T V O LT A G E , K V
COMPILED BY
APPROVED BY
LEAKAGE CURRENT AT FULL TEST
DISCHARGE TIME
VOLTAGE AFTER
COMPANY
DOWN TO ______________KV
DOWN TO ________KV
I MIN. DISCHARGE
SIGNATURE
PHASE A _______________µA
_________________SEC
________________KV
NAME
PHASE B _______________µA
_________________SEC
________________KV
DATE
PHASE C _______________µA
_________________SEC
________________KV
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE2 - SHT 01
SITE:
SWITCHGEAR BUS INSULATION AND
PHASING TEST CERTIFICATE
DATE
JOB NO.
LOCATION
MODULE
EQUIPMENT DESCRIPTION
MANUFACTURER
MODEL NO.
SERIAL NO.
TAG NO.
TYPE
VOLTAGE RATING
SHT of
SLD No
CURRENT RATING
POWER RATING
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
VOLTAGE
SERIAL NO.
ACCURACY/FULL SCALE
ENVIRONMENTAL CONDITIONS
TEMPERATURE
RESISTANCE VALUE IN MEG OHMS
PHASE TO PHASE
A-B
B-C
C-A
EQUIPMENT
INSPECTION
COMPLETED
PHASE TO GROUND
A
B
INSPECTORS INITIALS
MECHANICAL
COMPLETION
NEC
COMPLIANCE
C
DATE
DWG AND STD
COMPLIANCE
VERIFIED
REMARKS:
Check Bus Phasing
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE2 - SHT 02
SITE:
M.C.C. BUS INSULATION AND PHASING
TEST CERTIFICATE
DATE
JOB NO.
LOCATION
MODULE
EQUIPMENT DESCRIPTION
MANUFACTURER
MODEL NO.
SERIAL NO.
TAG NO.
TYPE
VOLTAGE RATING
SHT of
SLD No
CURRENT RATING
POWER RATING
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
VOLTAGE
SERIAL NO.
ACCURACY/FULL SCALE
ENVIRONMENTAL CONDITIONS
TEMPERATURE
RESISTANCE VALUE IN MEG OHMS
PHASE TO PHASE
A-B
B-C
EQUIPMENT
INSPECTION
COMPLETED
PHASE TO GROUND
C-A
A
B
INSPECTORS INITIALS
MECHANICAL
COMPLETION
NEC
COMPLIANCE
C
DATE
DWG AND STD
COMPLIANCE
VERIFIED
REMARKS:
Check Bus Phasing
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE3 - SHT 01
SITE:
CIRCUIT BREAKER, LV POWER
TEST CERTIFICATE
DATE:
JOB NO.
SLD No.
SHT of
LOCATION
Equipment Used (for test)
Manufacturer
Model No.
Setting
Serial No.
Accuracy
MODULE
Feeder Identification
Cubicle Number
Trip Units - Type or Style Number
Substation
Switchgear Unit Number
Trip Coil Rating
Breaker Type
Style or Serial Number
Time Delay Range
Breaker Manufacturer
Instantaneous Setting
Interrupting Capacity
Short Time Delay Setting
Procedure 9.2 Initial:
Pre-Installation Complete
Date:
Long Time Delay Setting
Procedure 9.3 - Drawout Air Initial:
Circuit Inspection Complete
Date:
Published
Trip Time
Min.
Trip Unit Setting
1. Instantaneous Trip Setting
Max.
Phase A
Phase B
Phase C
2. Inverse Time Setting
3. Instantaneous Pick-up (Amps)
4. Normal Pick-Up (Amps)
5. Inverse Time at
% current
Min.
Sec.
Min.
Sec.
Min.
Sec.
Inverse Time at
% current
Min.
Sec.
Min.
Sec.
Min.
Sec.
Inverse Time at
% current
Min.
Sec.
Min.
Sec.
Min.
Sec.
6. Contact Resistance
7. Others:
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
SH1 No :
Maintenance No:
MC1 No :
FORM EE3 SHT 02
SITE:
Work Pack No:
Source/Equipment No:
MOLDED CASE BREAKER TEST REPORT per 9.3.1.2 d
SHT
OF
DATE
JOB NO.
LOCATION
MODULE
MCC TAG NO.
MCC MANUFACTURER
MCC DESCRIPTION
MCC RATINGS
TRIP TIME 300% OF RATED CURRENT
BREAKER NO.
TYPE & MFG.
INFORMATION
POLES/
RATING
SERVICE
PHASE A
PHASE B
PHASE C
INST. TRIP
TIME
REMARKS
COMPILED BY
APPROVED BY
COMPANY
SIGNATURE
NAME
DATE
GOC ©
BP Exploration 1989 – 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE3 - SHT 03
SITE:
MEDIUM VOLTAGE CIRCUIT BREAKER
TEST CERTIFICATE
DATE
JOB NO.
SLD No
LOCATION
MODULE
Equipment Used (for test)
Manufacturer
Model No.
Setting
Serial No.
Accuracy
Switchgear/MCC Tag No.
Switchgear Manufacturer
Switchgear Description
Switchgear Voltage
Circuit Number
Trip Device Type
Circuit Breaker Manufacturer
Circuit Breaker Type
Serial No.
Model No.
Long Time Range
Short Time Range
SHT of
Instantaneous Range
Environmental Condition
Panel Temp.
Procedure 9.2 Initial:
Pre-Installation Complete
Date:
Procedure 9.3 - Drawout Air Initial:
Circuit Inspection Complete
Date:
SETTINGS
Phase A
S/T
L/T
Phase B
Inst.
L/T
S/T
Phase C
Inst.
L/T
S/T
Inst.
RESULTS
L/T
S/T
Instantaneous
Phase
Current
Current
Current
A
Time
Time
Time
Phase
Current
Current
Current
B
Time
Time
Time
Phase
Current
Current
Current
C
Time
Time
Time
WITNESSED BY
ACCEPTED BY
REMARKS:
COMPLETED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE3 - SHT 04
SITE
HIGH VOLTAGE LIMITED OIL INTERRUPTER
TEST REPORT
DATE
JOB NO.
Equipment (used for tests)
SLD No
SHT of
LOCATION
Manufacturer
MODULE
Model Number
Serial Number
Control Device:
Trip Coil
Ohms
Amps
Close
Ohms
Amps
Motor
Volts
Amps
(normal running current)
Amps
(starting current)
Mechanical Operation
Open and Close operation at Minimum control voltage:
Volts
Open and Close operation at Minimum control voltage:
Volts
Time Test:
A Phase
B Phase
C Phase
Trip Time
MS.
MS.
MS.
Close time
MS.
MS.
MS.
√ _________
√ _________
√ _________
Current Path Resistance
(DC Micro Ohms at 100 Amps minimum)
Low Frequency Withstand (1 Minute)
Major Insulating Components:
kV.
Control Wiring
Volts
Insulation Oil:
Dielectric Breakdown Voltage
kV. at
°C
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE4 - SHT 01
SITE:
CONTACT STARTER
TEST CERTIFICATE
DATE:
SLD No
JOB NO:
SHT of
LOCATION:
MODUL
Switchboard Number:
Location:
Circuit Title:
System:
Win.
Overcurrent Trip Setting
Amps
Seconds
Drive Full Load Current
Amps
Amps
Motor Fuse Ratings
Amps
Volts
System Voltage
Timer T.
Setting
Control Fuse Size
Control Voltage
Insulation Resistance
Megohms
Subsystem:
Volts
Test Volts
Volts
Yes
No
Control Circuits correct to Schematic Diagram Number
Remote Control and Annunciation Tested and Correct * *
Space Heater Circuit Tested
Thermal Overload Test Results
Current
%FLC
Trip Time (secs)
Amp
L1
L2
Single Phase Testing Result (80% FLC)
Remarks
L3
115
No Trips
200
Hot/ Cold
600
Hot/ Cold
Circuit
Amps
L1-L2
L1-L3
L2-L3
Trip Time (Secs)
Ground Fault Test Results
Circuit
L1
L2
L3
Min. Amps to Operate
Trip Time Set
CT Ratio (Protection):
Ammeter Test Results
Location Test Amps
CT Ratio (Metering):
Reading
Reading
Reading
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
** Witnessing Authority to Perform Test
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE4 - SHT 02
SITE:
MOTOR THERMAL OVERLOAD RELAY
TEST CERTIFICATE
Date
Project Number
SLD No
Location
Module
Equipment Used (for test)
Manufacturer
Model Number
Setting
Serial Number
Accuracy
Motor Tag Number
H.P.
Service
MCC Number
Circuit Breaker Trip
Starter Size
SHT of
F.L. Amps
Volts
RPM
Motor Manufacturer
O.L. Heater
Control Device
Interlocks
Mechanical Cond. Motor Bearing
Lube
Contact
Align
Conduit
Rotation
Run
% Rated Current
High Speed
A
B
C
Low Speed
Time At:
Time At:
Should be:
Should be:
Actual:
Actual:
A
B
C
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE4 - SHT 03
SITE:
VARIABLE SPEED DRIVES
TEST CERTIFICATE
DATE:
SLD No
JOB NO:
Manufacturer
Power Semiconductors
Input Diode
SHT of
LOCATION:
Tag Number
MODULE
Model Number
Volts
Amperes
Volts
Amperes
Hz
Running Hours
Volts
Amperes
Hz
Power Factor
dV/dt
dl/dt
Service
PIV
Output Transistor
Complete Controller Unit
Functional Test
Load Test
* * 100% Load
Efficiency
Running Time
* * 50% Load
* * 25% Load
Control Print Circuit Boards Burn-In Test (0ºC - 60ºC - 0ºC 22 Hours Minimum)
One Hour at Each Temperature:
ºC To
ºC Back To
ºC
Total Hours:
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
** Witnessing Authority to perform test.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE5 - SHT 01
SITE:
MEDIUM VOLTAGE AIR SWITCH
INSPECTION CERTIFICATE
Date
SLD No
Project Number
Location
Module
Equipment Used (for test)
Manufacturer
Model Number
Setting
Serial Number
Accuracy
Switchgear Tag Number
SHT of
Feeder Identification
Other Identification
Air Switch Data
Manufacturer
Type
Style/ Serial No.
Current Rating
Fuse Information
Voltage Rating
System Voltage
Inspection
Check Point
Condition
Check Point
Notes
Physical Damage
Contact Alignment
Cleanliness
Contact Wipe
Mechanical Operator
Contact Pressure
Main Contacts
Phase Barriers
Arc Contacts
Hardware Tightness
Arc Chutes
Fuse Holders
Arc Interrupter Sequence
Interlocks
C.T.’s, No ____ Ratio ___:5
Metering
Condition
Notes
Electrical Tests
Contact Resistance in Milliohms
Insulation Resistance:
Ø
AØ
Switch Closed
A-GND B-GND C-GND
A-B
BØ
B-C
CØ
C-A
A
Switch Open
B
C
Volts
REMARKS: Switch assembly to Transformer throat checked.
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE6 - SHT 01
SITE:
TWO-WINDING POWER TRANSFORMER
TEST CERTIFICATE
DATE:
JOB NO:
SLD No
SHT
LOCATION:
Equipment Used (for test)
Model Number
Serial Number
MODULE:
Initial:
Procedure 9.6 - Liquid Filled
Transformer Inspection Complete
Oil
Mineral Oil
Other
Air
Location of Tests
Transformer
Age
Sealed
Gas
Top Oil Temperature
Weather
% Humidity
High Side KV
Low Side KV
Y
Y
Gas Blanketed
B
U
S
H
I
N
G
S
∆
∆
Neutral
Date:
Air Temperature
Type/ Class
Free Breathing
Manufacturer
of
KVA
Conservator
Type Class
Gallons of Oil
DWG. No.
Cat. No.
KV
Year
Date Last Test
Over-All Tests (Doble or Equal)
Equivalent 10 KV Readings
Milliamperes
Watts
Test Connections
Test
Winding
Energized
Winding Grounded
1
High
Low
2
High
3
Low
4
Low
Winding
Guarded
Test KV
Meter
Multiplier
Reading
Meter
Milliampere Reading
Multi-plier
Key to
Insulation Rating
% Power Factor
Watts
Measured Cor. 20°
G=Good
C
I=Investigate
----
----
----
----
Low
D=Deteriorated
B=Bad (remove or
Insulation Rating
CH
High
High
Calculated Results
----
----
----
----
----
----
----
----
CL
CHL
----
(Test 1 minus Test 2)
----
(Test 3 minus Test 4)
-
Bushing Tests (Doble or Equal)
Equivalent 10 KV Readings
Milliamperes
Watts
Test Connections
Line No. Bush. No
Phase
Bushing Serial No.
Test KV
Meter
Multiplier
Reading
Meter
Milliampere Reading
Multi-plier
% Power Factor
Watts
Measured Cor. 20°
C
Collar Tests
(Watts / Current)
Top
Insulation Rating
HIGH SIDE
1
2
3
4
SIDE
6
LOW
5
7
8
9
10
11
12
REMARKS:
Oil Sample Tests:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE6 - SHT 02
(SIDE 1)
SITE:
TRANSFORMER TURNS RATIO
TEST CERTIFICATE
SLD No
JOB No:
DATE:
LOCATION:
Equipment Used (for test)
Setting
Serial Number
Accuracy
Manufacturer
Model Number
Class
Insulation
Type
† Dry
MODULE:
Manufacturer
Model Number
KVA
SHT of
Phase
† Mineral Oil
Serial Number
Hertz
† __________
Temperature
Rise
Voltage
Impedance
% at
H.V.
°C
L.V.
Winding Configuration On Back Of This Sheet
Taps
Available
Tap
Position
Primary
Voltage
As Found Tap:
As Left Tap:
Voltage Measurements
Initial Secondary (Tap
)
Final Secondary (Tap
)
Primary Voltage
A-B
A-N
A-B
A-N
A-B
B-C
B-N
B-C
B-N
B-C
A-C
C-N
A-C
C-N
A-C
Turns Ratio Determination As Left
Primary
Nameplate
Secondary
Calculated
Jumper
Ratio
Tap
Megger Readings
High to Low & Ground
Megohms
Low to High & Ground
Megohms
High to Low
Megohms
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
DOUBLE SIDE FORM
Americas REV. 1
Sketch Winding Configuration
& Vector Diagram Below
GOC ©
BP Exploration 1989 - 2001 All Rights Reserved
DOUBLE SIDE FORM
FORM EE6 - SHT 02
(Side 2)
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE6 - SHT 03
SITE:
3-WINDING POWER TRANSFORMER
TEST CERTIFICATE
DATE
PROJECT No.
Manufacturer
Serial Number
Tag. Number
KVA
SLD No
SHT of
LOCATION
MODULE
Procedure 9.6 - Liquid Filled
Initial:
Date:
Transformer Inspection
Secondary Voltage
Primary Voltage
Test Equipment Type
Manufacturer
Model Number
Serial number
1
2
3
4
Rating
Type
Phase
Frequency Hertz
Temperature Rise
Insulating Liquid
Class
H. Winding
X. Winding
V.
kVA
kVA
kVA
Y. Winding
V.
kVA
kVA
kVA
V.
kVA
kVA
kVA
Additional Tap Voltages
H Winding
X Winding
Connections for Operation
Transformers in Bank To Transformer
Phase
Connected
Transformers in
Performance
Dielectric Tests
Based on a
Applied
Loading of:
H. Winding
X Winding
kVA
kVA
Y Winding
kVA
To Transformer To
Phase
Connected
Insulation
Levels
kV
Basic Lightning
Low Frequency
Voltage** X Winding
kV
Voltage
Y Winding
kV
Impulse
insulation
Level
H. Winding
Items
Insulation Level
-----------
H Line
Induced
Line to Line
kV
H Neutral
Voltage
Line to Ground
kV
X Line
** To other windings and ground
X Neutral
Y Line
COMPLETED BY
WITNESSED BY
ACCEPTED BY
----------------------------------------APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE7 - SHT 01
SITE:
NEUTRAL GROUNDING RESISTOR
TEST CERTIFICATE
DATE:
System
SLD No
JOB NO:
LOCATION:
Subsystem
Location
SHT of
MODULE:
Equipment Description:
Transformer Mount
Switchgear Mount
C.T.
Resistor:
Ratio _________________
OHMS _________________
Stand Alone Mount
Rated
Volts
Rated
Amps
Description of Tests and/or Inspections carried out:
Per Procedure 9.12
_________________
Contin.
10 Sec.
Megger Volts _______________ D.C.
Ohms resistance, to frame and ground with “IN” and
“OUT” leads disconnected ____________________
Verified by _____________________________
Witnessing Authority
Test Certificate Numbers:
For C.T. (If applicable)
REMARKS
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE8 - SHT 01
SITE:
HEAT TRACE TAPE
INSPECTION CERTIFICATE
DATE
SLD No
PROJECT No
Line Number
LOCATION
Heater Number
Manufacturer
SHT of
Model / Cat. Number
MODULE
Service
Voltage
Wattage
Watts/Foot
Equipment Used (for test)
Manufacturer of Megger
Model Number
Serial Number
Setting
Accuracy
Environmental/Area Classification
Temperature
Circuit Breaker Number:
Procedure 9.13 - Heat Trace Component
Inspection Complete
Initial:
Date:
Reading / Remarks
Date
Initials
Megger Test on Reel (Before Installation)
Continuity Test on Reel (Before Installation)
Piping Completed (Ready to Install Heat Tape)
Megger Before Insulation
Continuity Test Before Insulation
General Heat Tape Inspection Complete
(Release for Insulation)
Insulation Completed and Inspected
Megger After Insulation
System Inspection
Conduit Seals
Mechanical
Completion
Code
Compliance
DWG & STD
Compliance
Date Verified
Wire Seals
Power and Splice Connections
Transmitter and RTD
Remarks:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE8 - SHT 02
SITE:
ELECTRICAL HEAT TRACE
PERFORMANCE CERTIFICATE
DATE
SLD No
PROJECT NO.
TEST EQUIPMENT
SHT of
LOCATION
MANUFACTURER
MODULE
MODEL NO.
SERIAL NO.
DIGITAL VOLT-OHM METER
CURRENT PROBE/METER
TEMPERATURE PROBE
HEATER NO.
PANEL NO.
CKT. BKR. NO.
SERVICE DESCRIPTION
END OF LINE LOCATION
EL.
HEATER MFG.
HEATER TYPE
BREAKER TYPE
GND. FLT. DET.
30
10
HEATER SIZE
BREAKER SIZE
TOTAL CKT. LOAD DESIGN
HTR. VOLT DESIGN
FT. HTR. TOT. LGT. INSTALL
VAC INSULATION TYPE
NORM. LINE TEMP.
W/FT.
A. AREA CLASSIFICATION CL.
W. HTR. TOT. LGT. DESIGN
COL.
DIV.
FT.
INSULATION THICKNESS
°F MAINTAIN DESIGN TEMP.
°F MAX. OPER. TEMP.
°F
CONTROL THERMOSTAT
AMBIENT
LINE
MFG.
MOD. NO.
SET
DEC.
°F RESET
INC.
°F
LOW TEMP. ALARM
SW.
MFG.
MOD. NO.
SET
DEC.
°F RESET
INC.
°F
END OF LINE MONITOR
MFG.
MOD. NO.
TYPE
VOLTS A.C.
* * PERFORMANCE DATA
CURRENT AMPS
PANEL E.O LINE
A0
B0
C0
POWER WATTS TEMPERATURE
N
TOTAL PER FT.
PIPE
AMB.
START UP
AFTER 10 MIN
AFTER 4 HRS
REF. DWG. NO'S.
(VOLT)(AMP) HRT.LGT. = WATT / FT
REMARKS
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
** Witnessing Authority to perform test.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
ELECTRICAL GROUND SYSTEM
TEST CERTIFICATE
DATE:
JOB NO.
FORM EE9 - SHT 01
SITE:
SLD No
SHT of
LOCATION
Equipment Used (for test)
Manufacturer
Model Number
Setting
Serial Number
Accuracy
MODULE
Note: This Test and Inspection Report is for the * † Main Electrical Ground System
(*check as appropriate)
* † Isolated Instrument Ground System
Reference Drawings:
1. Verify Primary grid conductors are correct size and type in accordance with
drawings.
2. Verify ground conductor burial depth and routing per drawings and
specifications.
3. Check thermal and/or compression connections checked (no cold joints or burn
outs.)
INITIALS/DATE
1
2
3
4. Check thermal and/or compression connection for application of anti corrosion
compound.
4
5. Verify ground rod locations diameter, length and material and installation per
drawings.
5
6. Check ground rod connections to verify integrity and tightness.
6
7. Verify location, type, size and insulation color of equipment taps per drawings.
Be sure all are protected form physical damage during work.
7
8. Verify system ground rod resistance-to-earth checked and recorded.
8
9. Verify all field revisions are recorded on “as-built” drawings.
9
Connection:
Tag Number or
Ground Point
Conductor Size and
Type
Resistance to
Ground
Ambient
Temperature
Environmental
Conditions
Taps (9)
Initials / Date
ohms
ohms
ohms
ohms
ohms
ohms
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE9 - SHT 02
SITE:
GROUNDING RESISTANCE
TEST CERTIFICATE
DATE:
JOB NO:
SLD No
LOCATION:
Equipment Used (for test)
Manufacturer
Model Number
Setting
Serial Number
Accuracy
Electrode Number & Location
(From Approved Drwgs.)
Ground
Resistance
1.
ohms
2.
ohms
3.
ohms
4.
ohms
5.
ohms
6.
ohms
7.
ohms
8.
ohms
9.
ohms
10.
ohms
11.
ohms
12.
ohms
SHT of
MODULE:
Conductor Size and
Type
Remarks
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE10 - SHT 01
SITE:
HAZARDOUS LOCATIONS
TEST CERTIFICATE
DATE:
System
SLD No
JOB NO:
LOCATION:
Subsystem
Location
SHT of
MODULE:
Equipment Description:
Description of Tests and/or Inspections carried out:
Test Certificate Numbers:
REMARKS: This form is to be used to denote any equipment departure from the standards required. Any such
entry must be resolved with the Witnessing Authority for approval or correction before it is considered for
Certification.
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE11 - SHT 01
SITE:
INSTRUMENTS TRANSFORMER
RATIO TEST CERTIFICATE
DATE:
JOB NO:
SLD No
LOCATION:
MODULE:
Switchboard Number
Location
System
Subsystem
Circuit Title
Data Sheet
Compartment number
Protection Type
Ratio
Class
Line 1
SHT of
Line 2
Line 3
Serial Numbers:
Procedure 9.18 completed:
Signed:
Line 1
Volts
Date:
Line 2
Amps
Volts
COMPLETED BY
WITNESSED BY
Line 3
Amps
Volts
ACCEPTED BY
Amps
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
PRIMARY INJECTION
TEST REPORT
DATE:
FORM EE12 - SHT 01
SITE:
SLD No
JOB NO:
LOCATION:
Switchboard Number:
SHT of
MODULE:
System:
Circuit Title:
Subsystem:
Compartment Number:
Data Sheet:
Serial Number:
Manufacturer:
Location:
Relay Type:
C.T. Ratios:
Protection Type:
C.T. Ratios:
C.T. Serial Numbers:
C.T. Test Certificates Available: † Yes † No
Signature
Date
Primary Injection Test
Phase Injected
Primary Current &
Phase
Secondary Current & Spill Current & Phase
Phase
Comments
Circuit Injected (Sketch: Use Extra Sheet if Necessary)
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE12 - SHT 02
SITE:
SECONDARY INJECTION
TEST REPORT
DATE:
SLD No
JOB NO:
LOCATION:
Switchboard Number:
System:
Circuit Title:
Subsystem:
Compartment Number:
Data Sheet:
Serial Number:
Manufacturer:
Location:
Relay Type:
C.T. Ratios:
Protection Type:
Element
% Setting
P.U.
D.O.
SHT of
MODULE:
Time Set Inj. Sec.Current Curve Time Actual Time
Relay Setting
Current
Volts:
Permanent Aux. Supply:
Sign:
Time
Date:
Circuit Injected (Sketch: Use Extra Sheet if Necessary)
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE12 - SHT 03
SITE:
RELAY
INSPECTION REPORT
DATE:
SLD No
JOB NO:
LOCATION:
SHT of
MODULE:
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
SETTING
SERIAL NO.
ACCURACY
CIRCUIT LOCATON
CIRCUIT DESIGNATION
TYPE
PHASE OR LOCATION INPANEL
MFG
STYLE NO
FUNCTION
C.T. RATIO
P. T. RATIO
SHUNT
TAP RANGE
INSTANTANEOUS RANGE
TIME OPERATIONS INDICATOR
INSTANTANEOUS OPERATIONS INDICATOR
AMPS
RELAY
MODEL NO &
SERIAL NO.
SERIAL OR CIRCUIT
AMPS
RELAY
MODEL NO &
SERIAL NO
CONTACTS
COVER
DIRTY
GLASS TIGHT
PITTED
GLASS CLEAN
OPERATIONS INDICATOR
GASKET TIGHT
ARMATURE FREE
CONDITION
TARGET FREE
DUST
INSTANTANEOUS ATTACHMENT
RUST
ARMATURE FREE
IRON FILINGS
TARGET FREE
GEARINGS / PIVOTS
DISC. OPERATION
SHORTING BARS IN PLACE
OTHERS:
CONNECTIONS TIGHT
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
SH1 No :
Maintenance No:
MC1 No :
FORM EE12- SHT 04
SITE:
Work Pack No:
Source/Equipment No:
OVER CURRENT RELAY TEST REPORT
SHT
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
SETTING
SERIAL NO.
ACCURACY
OF
COMPLETE NAMEPLATE DATA
NUMBER OF POINTS TO BE INSPECTED
LOCATION
SERIAL
NUMBER
STYLE
NUMBER
RELAY VALUES
SETTINGS
TAP
(AMPS)
TIME
DIAL
INST.
PICKUP
AMPS 1.5X
2X
2.5X
3X
5X
7X
INSTRUMENT
(AMPS)
TARGET
OPERATIONS
(AMPS DC)
INSULATION
TEST
(MEGOHMS)
REMARKS
COMPILED BY
APPROVED BY
COMPANY
SIGNATURE
NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE12 - SHT 05
SITE:
INSTANTANEOUS OVER CURRENT
RELAY TEST REPORT
DATE:
JOB NO:
SLD No
LOCATION:
MODULE:
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
SETTING
SERIAL NO.
ACCURACY
EQUIPMENT
BP
RELAY
IDENTIFICATION
IDENTIFICATION
NAME-PLATE DATA
PHASE
DATE
INST. TRIP
AMPS
SETTING
INS. RES.
VOLTS DC
INST.
TRIP
AMPS
OPER.
IND.
AMPS
SHT of
TEST
WITHIN
LIMITS
SERIAL NO.
CURVE
REMARKS
A
B
C
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE12 - SHT 06
SITE:
OVER VOLTAGE OR UNDER VOLTAGE
RELAY TEST REPORT
DATE:
JOB NO:
SLD No
SHT of
LOCATION:
MODULE:
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
SETTING
SERIAL NO.
ACCURACY
EQUIPMENT
BP
RELAY
IDENTIFICATION
IDENTIFICATION
NAME-PLATE DATA
POINTS TO BE TESTED
LOCATION
SERIAL NO.
SETTING
STYLE NO.
TAP
VOLTS
CURVE
RELAY TESTS
TIME
DIAL
PICK-UP
VOLTS
%
%
%
%
%
%
TARGET
OPER.
INSUL.
TEST
AMPS DC
MEGOHMS
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE12 - SHT 07
SITE:
POWER FACTOR RELAY
TEST REPORT
DATE:
SLD No
JOB NO:
SHT of
LOCATION:
MODULE:
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
SETTING
SERIAL NO.
ACCURACY
EQUIPMENT
BP
RELAY
IDENTIFICATION
IDENTIFICATION
NAME-PLATE DATA
SPECIFIED RELAY SETTINGS TAP SETTING
DATE
ZERO
ADJ.
TEST
AMPS
OTHER
INS. RES. POWER FACTOR TO CLOSE CONTACTS
VOLTS AC
AS FOUND
AS LEFT
COMPLETED BY
CURVE
WITNESSED BY
SERIAL NO.
ACCEPTED BY
REMARKS
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE12 - SHT 08
SITE:
FREQUENCY RELAY
TEST REPORT
DATE:
SLD No
JOB NO:
SHT of
LOCATION:
MODULE:
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
SETTING
SERIAL NO.
ACCURACY
EQUIPMENT
BP
RELAY
IDENTIFICATION
IDENTIFICATION
NAME-PLATE DATA
CURVE
SETTING
LOCATION
SERIAL NO.
STYLE NO.
TYPES
SET
FREQ.
TIME
DIAL
FROM
CYCLES
RELAY TESTS
TO
CYCLES
TIME TO
CLOSE
(CYCLE)
OPER. TARGET
INSUL.
FREQ. OPER.
TEST
AMPS MEGOHMS
DC
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE12 - SHT 09
SITE:
TRANSFORMER DIFFERENTIAL
RELAY TEST REPORT
DATE:
JOB NO:
SLD No
SHT of
LOCATION:
MODULE:
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
SETTING
SERIAL NO.
ACCURACY
EQUIPMENT
BP
RELAY
IDENTIFICATION
IDENTIFICATION
NAME-PLATE DATA
LOCATION
SERIAL
NO.
STYLE
NO.
1
TAP
AMPS
2
TAP
AMPS
COMPLETED BY
3
TAP
AMPS
4
TAP
AMPS
WITNESSED BY
MIN.
TRIP
AMP
CURVE
DIFFERENTIAL
CHARACTERISTICS
A
B
ACCEPTED BY
HARMONIC
REST.
TARGET
OPER
INSUL
TEST
CHAR
AMP DC
MEGOHMS
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
SH1 No :
Maintenance No:
MC1 No :
FORM EE12 SHT 10
SITE:
Work Pack No:
Source/Equipment No:
REVERSE POWER RELAY TEST REPORT
DATE
SHT
JOB NO.
LOCATION
EQUIPMENT USED (FOR TEST)
MANUFACTURER
MODEL NO.
SETTING
SERIAL NO.
ACCURACY
EQUIPMENT IDENTIFICATION
BP IDENTIFICATION
NUMBER OF POINTS TO BE INSPECTED
LOCATION
SERIAL
NUMBER
STYLE NUMBER
TAP
(AMPS)
MODULE
RELAY NAME PLATE DATA
SETTINGS
OF
CURVE
RELAY TEST VALUES
PICK-UP
WATTS 2X
4X
6X
8X
10X
12X
TARGET
OPER
(AMPS DC)
INSUL
TEST
(MEGOHMS)
SECONDS-CYCLE
REMARKS
COMPILED BY
APPROVED BY
COMPANY
SIGNATURE
NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE13 - SHT 01
SITE:
MOTORS AND MOTOR CIRCUITS
TEST CERTIFICATE
DATE:
SLD No
JOB NO:
LOCATION:
EQUIPMENT USED (FOR TEST)
MANUFACTURER
SHT of
MODULE:
ELEC. DATA SHEET NUMBER
MODEL NO.
SERIAL NO.
VOLTAGE
ACCURACY (FULL SCALE READING)
MEG OHMS
ENVIRONMENTAL CONDITIONS
TEMP
POWER SYSTEM VOLTS
FREQUENCY & PHASE
°F
AMPS
MOTOR NO.
HP.
FL AMPS
VOLTS
SERVICE
TEMP CODE
MCC NO.
MOTOR MFG
CIRCUIT BREAKER TRIP
STARTER SIZE
C L HEATER
CONTACT
RMP
ALIGN
CONTROL DEVICE
INTERLOCKS
CONDUIT SEALS
MECH COND MOTOR BEARING
LUBE
ROTATION * *
PROCEDURE 9.7 - ELECTRIC MOTOR
INSPECTION COMPLETE
INITIAL:
RUN * *
DATE:
MEGGER
PHASE TO PHASE
DESCRIPTION
AB
BC
CA
PHASE TO
NEUTRAL
A/B/C TO
NEUTRAL
PHASE TO GROUND
A
B
C
NEUTRAL
MOTOR
WINDINGS
POWER LEADS
CONTROL
CIRCUIT
REMARKS: NOTE: Ungrounded Star or Delta wound motors with no access to neutral, require only one megger reading: all 3
phases together to ground. Phase to phase requires precision resistance readings comparison.
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
** Witnessing Authority to perform test.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE13 - SHT 02
SITE:
ROTATING MACHINERY
TEST CERTICATE
DATE:
SLD No
JOB NO:
SHT of
LOCATION:
EQUIPMENT USED (FOR TEST)
MODULE:
MODEL NO.
MANUFACTURER
(Requires Doble or Equiv. Mfr.)
SETTING
SERIAL NO.
ACCURACY
EQUIPMENT TESTED
MANUFACTURER
MODEL NO.
SERIAL NO.
SERVICE FACTOR
STATOR TEMP
KV
RPM
KVA
HP
PF
TYPE
FORM
AGE
MFR.
DATE LAST TEST
LAST TEST SHEET NO. ROTOR
KW
INSULATION
CLASS
STATOR
CORONA CONTROL
CLASS
EQUIVALENT 10 KV READINGS
MILLIAMPERES
LINE
NO.
PHASE
TEST
METER
KV
READING
WATTS
MILLI-
MULTIPLIER
AMPERES
METER
%
%
POWER
PF
TEST
TIP UP
KV
READING MULTIPLIER WATTS FACTOR
RIV MEASUREMENTS
MICROVOLTS
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
SH1 No :
Maintenance No:
MC1 No :
FORM EE14 SHT 01
SITE:
Work Pack No:
Source/Equipment No:
BATTERY LOAD TEST DATA CERTIFICATE
DATE
SHT
OF
JOB NO.
LOCATION
MODULE
Battery Manufacturer
Type
Start Time
Finish Time
Float / Voltage
Discharge Current
Procedure 9.8 - Battery & Battery Charger
Inspection Complete
Initial:
Min. Term. Volts
Min. Volts / Cell
Average Cell Temp.
Date:
Time
Cell
Initial
Volts
Volts
Volts
Volts
Volts
Volts
Volts
Volts
Volts
Volts
Volts
Volts
Volts
Volts
Initial
Hyd. Reading
Final
Hyd. Reading
Remark
Load Current
Terminal Voltage
COMPILED BY
APPROVED BY
COMPANY
SIGNATURE
NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE14 - SHT 02
SITE:
BATTERY
TEST CERTIFICATE
DATE:
SLD No
JOB NO:
SHT of
LOCATION:
MODULE:
Battery Information
Test Cell Number
Number of Cells
Volts
Procedure 9.8 - Battery & Battery Charger
Inspection Complete
Initial:
Type
Sp. Gr.
Date:
Normal Sp. Gr.
Battery Area Ambient Temperature
Manufacturer
Charge Equalized initiated
Type of Cell
Date
Time
Electrolyte Level:
As Found:
Water Added:
Quarts Total:
Battery Term. Volt
Average Volt / Cell
Recorded Date:
Term Float Volts
Cell
Volts
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
14.
15.
16.
17.
18.
19.
20.
Hydro
Meter
Temp Cell
°F
21.
22.
23.
24.
25.
26.
27.
28.
29.
30.
31.
32.
33.
34.
35.
36.
37.
38.
39.
40.
COMPLETED BY
Volts
Hydro
Meter
Temp
°F
Cell
Volts
Volts
Hydro
Meter
Temp
°F
Rem.
41.
42.
43.
44.
45.
46.
47.
48.
49.
50.
51.
52.
53.
54.
55.
56.
57.
58.
59.
60.
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE15 - SHT 01
SITE:
UNINTERRUPTED POWER SUPPLY
(UPS) TEST CERTIFICATE
DATE:
JOB NO:
SLD No
SHT of
LOCATION:
Equipment Number
Location
System
Subsystem
Rating
MODULE:
Data Sheet
K.V.A.
Serial Number
Voltage In
D.C. Volts
Inverter Number
Voltage Out
A.C. Volts
Battery Charger Type
Manufacturer
Static Switch Type
Ground Resistance
Ohms Minimum I.R.
Inverter Test Certificate * *
D.C. Volts In
D.C. Amps In
A.C. Volts Out
A.C. Amps Out
Megohm
s
H2
Output Amps
Limit
Distortion %
Static Switch Test Result* *
Maximum Load Transferred to Mains:
Maximum Load Transferred Mains to Inverter:
Maximum Load Transferred to Bypass Supply:
Amps
Amps
Amps
Control System Function Tested to Drwg. Number:
Revision:
Alarms Completed and Function Tested to Drwg. Number:
Revision:
List Alarms Tested:
Vendors Test Sheet Completed:
Signed:
Date:
Remarks:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
** Witnessing Authority to perform test.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE16 - SHT 01
SITE:
GENERAL TEST CERTIFICATE
DATE:
System
SLD No
JOB NO:
LOCATION:
Subsystem
Location
SHT of
MODULE:
General Electrical Equipment - Procedural Acceptance
Procedure 9.1 - Conduit
Inspection Complete
YES/NO*
Initial
Date
Procedure 9.2 - Bus Duct
Inspection Complete
YES/NO*
Initial
Date
Procedure 9.1 - Cable
Inspection Complete
YES/NO*
Initial
Date
Procedure 9.10 - Panel
Board Insp. Complete
YES/NO*
Initial
Date
Procedure 9.1 - Cable Tray
Inspection Complete
YES/NO*
Initial
Date
Procedure 9.10 – Lighting
& Receptacle Insp. Compl.
YES/NO*
Initial
Date
Procedure 9.1 - Cable Blocking
Inspection Complete
YES/NO*
Initial
Date
Procedure
YES/NO*
Initial
Date
Procedure 9.1 Conduit & Seal
Inspection Complete
YES/NO*
Initial
Date
Procedure
YES/NO*
Initial
Date
Equipment Description:
Description of Tests and/or Inspections carried out:
Test Certificate Numbers:
REMARKS
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
NAVIGATIONAL AIDS
TEST CERTIFICATE
DATE:
FORM EE17 - SHT 01
SITE:
SLD No
JOB NO:
SHT of
LOCATION:
Equipment Number
Location
System
Subsystem
Serial Number
MODULE:
K.V.A. Data Sheet
Model / Type Number
Supply Voltage
Battery Charger Type
Manufacturer
Volts
Procedure 9.11 Completed:
Signature:
Date:
Procedure 9.15 Completed:
Signature:
Date:
Ohms
Ground Path Resistance:
Minimum I.R.
Megohms
Control Circuits Tested to Drwg. Number:
Revision:
Alarm Circuits Tested to Drwg. Number:
Revision:
Procedure 9.8 Completed:
Signature:
Date:
Vendors Test Sheets Completed:
Signature:
Date:
REMARKS:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE18 - SHT 01
SITE:
A.C. GENERATORS AND GENERATOR
CIRCUITS TEST CERTIFICATE
DATE:
JOB NO:
SLD No
LOCATION:
TEST EQUIPMENT USED
MANUFACTURER
SHT of
MODULE:
ELEC. DATA SHEET NUMBER
MODEL NO.
SERIAL NO.
VOLTAGE
ACCURACY (FULL SCALE READING)
MEG OHMS
ENVIRONMENTAL CONDITIONS
TEMP
POWER SYSTEM VOLTS
FREQUENCY & PHASE
GENERATOR SERIAL NO.
KVA/P.F./KW
SERVICE
TEMP CODE (INSULATON) SWGR.
MECH COND GEN BEARING
PROCEDURE 9.7 - ELECTRIC GEN’R.
INSPECTION COMPLETE
AMPS
FL AMPS
CIRCUIT BREAKER TRIP SET BREAKER
°F
VOLTS
RMP
GEN. MFR.
SYNCH.
CONTACT
ALIGN
INTERLOCKS FOR SYNCH’R
CONDUIT SEALS
LUBE TYPE
ROTATION * *
RTDs
RUN * *
DATE:
MEGGER
PHASE TO PHASE
DESCRIPTION
AB
BC
CA
PHASE TO
NEUTRAL
A/B/C TO
NEUTRAL
PHASE TO GROUND
A
B
C
NEUTRAL
GEN. STATOR
WINDINGS
EXCITER LEADS
STATOR
CONTROL
CIRCUIT
REMARKS: Comments on excitation system components/assembly:
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
** Witnessing Authority to Perform Test
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM EE18 - SHT 02
SITE:
ROTATING MACHINERY (GENERATOR)
TEST CERTIFICATE
DATE:
JOB NO:
SLD No
LOCATION:
TEST EQUIPMENT USED
MANUFACTURER
MODEL NO.
SETTING
SERIAL NO.
ACCURACY
EQUIPMENT TESTED
MANUFACTURER
MODEL NO.
SERIAL NO.
SHT of
MODULE:
SERVICE FACTOR
STATOR TEMP
KV
RPM
KVA
HP
PF
TYPE
FORM
AGE
MFR.
DATE LAST TEST
LAST TEST SHEET NO. ROTOR
KW
INSULATION
CLASS
STATOR
CORONA CONTROL
CLASS
EQUIVALENT 10 KV READINGS
MILLIAMPERES
LINE
NO.
PHASE
TEST
METER
KV
READING
WATTS
MILLI-
MULTIPLIER
AMPERES
METER
%
%
POWER
PF
TEST
TIP UP
KV
READING MULTIPLIER WATTS FACTOR
PDA MEASUREMENTS
MICROVOLTS
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
NOTE: THIS IS A DOBLE TEST SHEET!
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
DIS6 SHEET
HANDOVER No : _______________
PROJECT : ___________
JP
No.
CABLE No
EE1
LOCATION : ___________
EE16
RAISED BY : _____________________________
NOTE: JP No FOR TESTING CABLE
DATA INPUT SHEET 6
SECTION 9 ELECTRICAL CABLES
FROM
TO
DATE : _______________________________
GOC©
OF
WORKSCOPE ID : ______________________
MAINTENANCE ID No : ______________________
DRG No
DRGS TO BE AS-BUILT
(LAD)
DATA ENTERED BY : ______________________
BP Exploration 1989 - 2001 All Rights Reserved
COMMENTS
DATE : __________________
Americas Rev. 1
DIS7
HANDOVER No : _______________
DATA INPUT SHEET 7
PROJECT : ___________ LOCATION : ___________
______________________
JP
No
HANDOVER ID
EQUIPMENT
No
EE2
EE3
EE4
RAISED BY: ___________________________________
NOTE: JP No FOR TESTING
EE5
EE6
EE7
EE8
DATE : ________________
GOC©
EE10
EE11
EE12
EE13
EE14
OF
WORKSCOPE ID : ______________________
SECTION 9 - ELECTRICAL EQUIPMENT
EE9
SHEET
EE15
EE16
MAINTENANCE ID No :
EE17
DATA ENTERED BY : ______________________________
BP Exploration 1989 - 2001 All Rights Reserved
EE18
SC1
SC1
REF.
Drawing No
ASBUILT
REQ'
D
DATE : ____________________
Americas Rev. 1
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
CIVIL CONSTRUCTION
SECTION 10
CIVIL CONSTRUCTION
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
PAGE: 1
SUBJECT:
10.1
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
CIVIL CONSTRUCTION
PAGE: 2
ACTION
10.1.1 General
The scope of the Civil Construction covers civil and buildings
(architecture) activities in general and as such may not be applicable to
all project activities, however the applicable requirements of this
procedure shall be included within any procedure for civil or architectural
inspection and acceptance produced by the Construction Authority.
All on-site and off-site activities and operations shall be planned and
performed in accordance with agreed procedures.
The agreed procedures shall define the sequence, methods, controls,
criteria for acceptance, inspection and testing, recording of test results,
and their evaluation.
The frequency of tests should take into account the consistency of test
results and changes in characteristics.
Civil Construction shall be checked for compliance and other
requirements as detailed in but not limited to:
•
•
•
•
•
•
•
The latest revision of Issued For Construction (IFC) or Approved
For Construction (AFC) Drawings and Schedules
Codes and standards reference in this section
Plant and Project Specifications
Equipment Specifications and Data sheets
BP Engineering Installation and Design Specifications
Local, state, country and international standards, codes, and
regulations as appropriate
Offshore - Special Standards, i.e. USCG, ABS and MMS
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
10.2
CIVIL CONSTRUCTION
PAGE: 3
CIVIL WORK
10.2.1 Scope
The civil work scope, as defined by the contract drawings, shall be
divided into discrete civil construction work packages.
Each work package shall cover all civil works within a specified area of
the site and be clearly identified on the applicable drawings.
For convenience of site inspection and testing the work package may be
further sub-divided.
The Construction Authority shall be responsible for raising and
documenting requests for inspection, certificates, with all necessary
supporting documentation, prior to submitting to BP for acceptance.
10.2.2 General
Construction Management responsibilities and associated Quality
Planning for civil activities, is normally categorized and managed, but not
limited to the following:
a)
On-Site:
The Construction Authority is responsible for the
Inspection and Test activities and management of the construction
Contractor who provides labor and equipment only;
b)
Off-Site: The Construction Authority monitors the performance of
the Management Contractor who is directly responsible for the
fabrication and Inspection and Test activities.
c)
For on-site, those Inspection and Test activities that require to be
performed and recorded to fulfill the minimum quality control
requirements, are clearly defined on the specified Inspection and
Test Schedule (ITS) for the work.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
d)
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
CIVIL CONSTRUCTION
PAGE: 4
For off-site, those Inspection and Test activities performed by the
Managing Contractor that are deemed by BP or their delegated
authority to be at critical stages in the fabrication process and
require to be witnessed before the Contractor can proceed, will be
clearly defined within the Managing Contractor's quality plan (QP),
and/or the supplied ITS.
e)
The acceptance of structural works is a composite function of
Fabrication, and Inspection (Section 2). Input by the relevant
discipline engineer is required in quality planning and subsequent
development of an ITS for both off-site and on-site work.
f)
Flow charts give guidelines on handover of on-site work.
g)
All reporting and recording of inspection and acceptance of civil
work shall be on the GOC© standard forms or alternatives where
agreed by BP or their delegated authority.
h)
The Construction Authority shall exercise sufficient dimensional
control over the civil work and shall monitor or conduct surveys
throughout pre-fabrication, fabrication, construction and installation
stages of the work to ensure that the specified design tolerances
are achieved. The contractor, prior to installation, shall establish
reference marks and levels.
i)
The Construction Authority shall prepare, maintain and issue
reports which describe the extent, and contain the results, of all
dimensional surveys carried out on-site and shall monitor reports
produced.
j)
The construction authority shall ensure that all applicable permits
are obtained and approved. The permits may be, but are not
limited to, Area Civil Work Requests (ACWR), Tundra Access
Permits and U.S. Civil Corp. of Engineers Gravel Placement
Permits. The general source shall be an approved and permitted
pit.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
CIVIL CONSTRUCTION
PAGE: 5
10.2.3 Soils and Earthwork
The control of soils and earthwork operations shall ensure that the site
sub-grade is prepared suitably free of extraneous materials, voids,
excess moisture, etc. and that fill operations are not carried out in
inclement weather.
Soil compaction activities should be carried out such that the fill material
will not separate when applied and spread in accordance with specified
lift thickness and appropriate watering and compaction is carried out.
Appropriate tests for compaction, grain size, plasticity, field density, etc.
shall be carried out during the course of construction. The Construction
Authoritys Civil Engineer should ensure that the frequency of the tests is
dependent upon consistency of results and changes in material
characteristics.
10.2.4 Piling Operations
Piling operations shall be subject to controls and inspections that ensure
that the type, location and position of the piles are verified, and pile
hammer, cushion material, and driving procedure and sequence are
adequately described and recorded.
The Construction Authorities Civil Engineer shall ensure that a suitable
record of the number of pile driving strokes for each pile is maintained.
Cast in piles shall be checked to confirm the alignment is correct.
10.2.5 Concrete
Site control procedures shall ensure that adequate inspection and
testing for all aspects of concrete construction are performed.
The extent of control will be dependent upon the structural function of
the concrete structure.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
PAGE: 6
CIVIL CONSTRUCTION
The controls employed for the material storage and handling techniques
should ensure the cement storage facilities are suitably weather tight,
and the type and age of cement is verified.
Aggregates stockpiles should be inspected to ensure temperature and
moisture controls are in operation and that storage and handling
techniques prevent contamination.
facilities should be inspected
contamination are prevented.
These
inspections
should
The admix storage and handling
to
include
verify
water
that
deterioration
quality
and
and
concrete
temperatures.
Measuring and mixing operations should be monitored to ensure
cement, water, and aggregate proportions are checked and recorded.
Aggregate moisture compensation measures,
temperature controls should also be verified.
mixing
time,
and
Placement operations should be monitored to ensure the preparations
are checked to confirm that specified material has been used and the
condition of the material, gradation, and compaction are correct.
Inspections should be carried out prior to concrete placement to confirm
the location and configuration of formwork, and size, orientation and
installation of reinforcing steel is correct.
Concrete placement inspection should confirm that specified testing of
concrete is performed and adequate concrete consolidation equipment
and techniques are used.
Appropriate cube/cylinder testing should be carried out and results
recorded.
Finished construction should be inspected to check for any voids or
contamination. Where the Construction Authorities Civil Engineer
considers it necessary physical removal of concrete may he necessary
to determine the extent.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
10.3
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
CIVIL CONSTRUCTION
PAGE: 7
STEEL CONSTRUCTION
10.3.1 General
Steel construction, including related items, such as anchor bolts and
base plates, forming part of a supporting structure should be inspected
at appropriate stages of construction.
Anchor bolts and base plates should be checked for correct type,
location, orientation, and bolt hole alignment prior to erection.
10.4
PIPING
10.4.1 General
Piping activities associated with civil work shall be subject to controls
and inspections that ensure the location and construction methods
adopted are verified.
Pipe testing (metallic) to be in accordance with Section 3 Pipe Testing.
Work shall be performed in accordance with procedures that adequately
take account of the complexity, uniqueness, or novelty of the item, and
the need for any special controls or surveillance over processes,
methods, or equipment.
Particular attention shall be made to ensure laying, jointing and backfill
operations do not jeopardise the integrity of non-metallic piping.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
10.5
CIVIL CONSTRUCTION
PAGE: 8
Use of Forms
a)
Off-Site Civil Acceptance
The CW6 will certify that all off-site fabrication activities for a
discrete structure or its component parts, complies with the design
requirements and all specified inspection and testing is completed
and accepted.
As a minimum, all sub-assemblies will require a CW6 Civil
Completion Certificate before they can be installed in to an
assembly.
All assemblies will require a CW6 Civil Completion Certificate
before they can be installed into the discrete structure.
All discrete structures will require a CW6 Civil Completion
Certificate before they can be released for shipment onsite for
installation.
b)
On-Site Civil Acceptance
The CW6 Civil Completion Certificate will certify that all on-site
activities relating to the onsite fabrication and installation of civil
work have been completed and comply with the approved design,
fabrication and installation specifications and that all specified
inspection and testing is completed and accepted.
c)
Concealed / Covered Work
Where subsequent work will prohibit further access, all items of
work concealed in finished work, either underground or by closure
or as a result of gravel installation, covering filler fabric, drainage
structures or other work, shall be inspected immediately prior to
being covered/concealed.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
PAGE: 9
CIVIL CONSTRUCTION
The inspection and testing shall be recorded on the CW6 Civil
Completion Certificate, which must identify clearly the area that was
inspected prior to filling and back filling.
“As-built” drawing data will also be recorded and relevant coordinates confirmed.
d)
Protective Coatings
Painting, coating of items or surfaces for which the coating is
essential to the preservation of the item quality, including its safety,
e.g. fire proofing, shall be performed and inspected in accordance
with approved procedures.
Refer to the AS2 Final Coating /
Insulation Certificate as detailed in Section 7.0 - Architectural
Services (Painting, Coating and Insulation).
e)
Civil Work
Civil work shall be accepted by using the forms listed below.
The Construction Authority using their own suite of forms will record
piling activities. The Construction Authorities Civil Engineer will
record acceptance on these forms which will form part of the
permanent Record Documents.
civil standard forms is given over.
GOC©
Guidance on the application of
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
i)
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
CIVIL CONSTRUCTION
PAGE: 10
CW1 - CW4
For Civil Work CW1 to CW4 Inspection Certificates are available:
CW1 - Reinforced Concrete Works
CW2 - Underground Services / Drainage
CW3 - Earthworks, Roads, Flexible Paving
CW4 - Transportation / Placement of Concrete
ii)
CW5 - Concrete Test Cube/Cylinder Summary
CW5 is available for use as a summary record sheet for all
concrete testing results.
iii)
CW6 - Civil Construction Completion Certificate
CW6 certificate to be used for the acceptance of on-site and off-site
work, assemblies, sub-assemblies or discrete structures and/or the
acceptance of areas or sub-areas that are required to be handed
over and made available to another contractor.
The CW6
certificate shall only be accepted when all relevant supporting
documentation is available and accepted.
Acceptance of the CW6 by the Construction Authority,
Commissioning Authority and/or the Operating Authority, only
confirms that the area or collective areas are ready for SH1 System Handover, (refer to Flowchart 10).
The acceptance of the CW6 certificate on its own does not
constitute system handover or acceptance by the operator.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
10.6
10.6.1
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
CIVIL CONSTRUCTION
PAGE: 11
Buildings, Fittings and Furnishings (Architectural)
General
The requirements of this procedure should apply to the architectural
acceptance of areas used as permanent offices, control rooms,
laboratories, or rest rooms. These requirements should be included
within any procedure for inspection and acceptance of architectural
works produced by the Construction Authority.
The acceptance of associated services, e.g. fire and gas detection,
electrical power and lighting, and HVAC is contained within the relevant
sections of the GOC©.
The inspection of the areas should be carried out after installation of all
items and the completion of testing of services and utilities to the area
by the appropriate disciplines.
It should be noted that within control rooms, completion activities will
normally continue until final handover to the operator, and a handover
program should be agreed between the Construction Authority,
Commissioning Authority and Operations.
The overall standard of workmanship of the areas should be considered
in addition to the minimum inspection points contained within this
section.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
CIVIL CONSTRUCTION
PAGE: 12
10.6.2 Inspection Requirements
The Construction Authority shall ensure the following inspections and/or
tests have been completed prior to submitting the building, for approval
to the Commissioning Authority. All inspection and testing to be carried
in accordance with design requirements, specifications, approved
drawings and to national and/or state statutory regulations and codes of
the country or state the facility is subject.
10.6.3 Surface Finish
Surface Finish to be checked to ensure:
a)
The surface finish is as per the design and specification
requirements; e.g. tiled, screeded, aluminium, Formica, wood,
painted, etc.
b)
The surface coating is correct for quality and color of finish, and has
no scratches, blemishes, or defects. Attention should be paid to
recessed items such as light switches, socket outlets, louvers, or
where tiles are fitted.
c)
All access hatches to concealed areas are correctly fixed,
accessible, labelled, including warning notices where necessary.
d)
All mouldings on skirting boards, ceiling, and wall joints are
correctly fitted.
e)
All ceiling tiles are in place and undamaged and for suspended
ceilings, all suspension ties and supports are correctly installed.
f)
Where applicable the floor slope or camber to drains is correct.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
CIVIL CONSTRUCTION
PAGE: 13
10.6.4 Windows and Doors
All Windows and Doors are to be checked to ensure:
a)
The correct fire rated items have been fitted.
b)
The finish around door and window frames is correct and complete.
c)
All doors and opening windows function correctly and when closed
are correctly sealed.
d)
All hinges, locks, handles etc. are fitted and function correctly.
e)
The glazing is not damaged in any way.
10.6.5 Fittings
All permanent fittings, other than control panels, are to be checked to
ensure:
a)
Sanitary ware is undamaged.
b)
Sealant, plugs, covers, taps, handles, etc. are correctly fitted and
operational.
c)
Mirrors are correctly installed and undamaged.
d)
Wardrobe units, cupboards, and working surfaces are correctly
aligned and doors function correctly. All locks, where fitted, have
keys and function correctly.
e)
Edges around wardrobe units, cupboards, and working surfaces are
correctly sealed and undamaged.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
CIVIL CONSTRUCTION
PAGE: 14
10.6.6 Safety Items
All Safety Items are to be checked to ensure:
a)
Fire extinguisher brackets are installed in agreed locations with
unrestricted access at all times, are of the correct type and size,
and correctly marked. It should be noted that the operator may
carry out the installation of the extinguisher.
b)
Deluge, fire water and sprinkler systems will be inspected and
tested in accordance with Section 3 - Pipe Testing.
c)
Hose reels are and associated valves are correctly installed and
operate freely, and correctly tagged. Hoses are to be run out to
ensure they are undamaged. Ensure they are correctly re-rolled
after checking.
d)
All doors, covers etc. associated with the hose reels freely operate.
e)
All emergency exit signs are of the correct type and correctly
located.
f)
All escape routes are clearly marked and maps installed.
g)
Muster point cabinet locations are installed in agreed locations.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
SUBJECT:
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
CIVIL CONSTRUCTION
PAGE: 15
10.6.7 Soft Furnishings
All Soft Furnishings are to be checked to ensure:
a)
All curtain rods, hooks, curtains, blinds are installed and operate
correctly, and are of the correct color.
b)
All carpeting is of the correct color and installed correctly.
c)
Loose furniture, chairs etc. is as per the requirements.
10.6.8 Buildings, Fittings and Furnishings Certificate (Architectural)
BF1 - Building Area Acceptance Certificate - for modules, buildings,
permanent offices, control rooms, rest rooms, medical rooms and
associated facilities shall be used to record the results of inspections
and surveys.
The acceptance of the BF1 by the Construction Authority,
Commissioning Authority and/or the Operating Authority, only confirms
that the area or collective areas are ready for SH1 - System Handover,
(Refer to Flowchart 11).
The acceptance of the BF1 certificate on its own does not constitute
system handover or acceptance by the operator.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
PAGE: 16
CIVIL CONSTRUCTION
FLOWCHART 10
• Functional Certification Flowchart
• Discipline: Civil Construction
CW1
CW2
CW4
CW5
CW6
SH1
CW3
CW1
CW2
:
:
Reinforced Concrete Work
Underground Services/Drainage
CW3
CW4
CW5
:
:
:
Earthwork/Roads/Flexible Paving
Transportation/Placing of Concrete
Concrete Test Cube/Cylinder Summary
CW6
SH1
:
:
Civil Completion Certificate
System Handover Certification
NOTE! Electrical, Control and Mechanical disciplines will be
handed over on system basis. Refer to the appropriate
section for relevant procedures and certificates.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
PAGE: 17
CIVIL CONSTRUCTION
FLOWCHART 11
•
Functional Certification Flowchart
• Discipline: Civil – Buildings, Fittings and Furnishings
(Architectural)
BF1
BF1
SH1
:
:
SH1
Building Area Acceptance Certificate.
System Handover Certificate
Note! Electrical, Control and Mechanical disciplines will be
handed over on a system basis. Refer to the appropriate
section for relevant procedures and certificates.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
GUIDANCE ON CERTIFICATION
SECTION 10
GOC© AMERICAS EDITION
REVISION: 1
SUBJECT:
CIVIL CONSTRUCTION
PAGE: 18
EXHIBIT 10
STANDARD FORMS
Form No.
Form Title
CW1
Reinforced Concrete Work
CW2
Underground Services / Drainage
CW3
CW4
CW5
Earthwork, Roads, Flexible Paving
Transportation / Placement of Concrete
Concrete Test Cube / Cylinder Summary
CW6
BF1
Civil Completion Certificate
Buildings Area Acceptance Certificate
DIS8
Data Input Sheet 08 – Civil Construction
Note:
Final acceptance of the CW6 - Civil Completion Certificate will be by the Civil
Engineer authorized by BP or their Delegated Authority.
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM CW1- SHT 01
SITE:
REINFORCED CONCRETE WORK
INSPECTION REPORT
DATE:
JOB NO.
SHT of
LOCATION
CONTRACTOR
Description:
The works referenced have been inspected in accordance with Contract requirements and are in accordance with the
Project design criteria, drawings and specifications. All outstanding work to be detailed on the agreed joint Punch List.
INITIALS/DATE
INSPECTION STAGE *
1. Excavation
1
2. Formation
2
3. Blinding
3
4. Impermeable membrane
4
5. Reinforcement
5
6. HD Bolts
6
7. Built-in Items (Details)
7
8. Form work
8
9. Line and level
9
10. Cleanliness
10
11. Manholes sealed
11
12. Curing (requirements)
12
13. Water Proofing
13
14. Backfilling
14
15. Testing (Type & Results)
15
16. Piling
16
17. Survey layout
17
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM CW2- SHT 01
SITE:
UNDERGROUND SERVICES/DRAINAGE
INSPECTION REPORT
DATE:
SHT of
JOB NO.
LOCATION
CONTRACTOR
Pipe/Drain: (Size & Type)
Jointing/Fittings:
Manhole/Gully: (Chamber No & Type)
Description:
Service Function:
The works referenced have been inspected in accordance with Contract requirements and are in accordance with the
Project design criteria, drawings and specifications. All outstanding work to be detailed on the agreed joint Punch List.
INITIALS/DATE
INSPECTION STAGE *
1. Excavation
1
2. Formation
2
3. Bedding
3
4. Invert Levels
4
5. Test calculations
5
6. Protective Coatings
6
7. Testing (Type of tests and results)
7
8. Backfill/Surround
8
9. Flushing
9
10. Visual Inspection (Obstructions)
10
11. Manholes sealed
11
12. Gratings fitted
REMARKS
12
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM CW3 - SHT 01
SITE:
EARTHWORK/ROADS/FLEXIBLE PAVING
INSPECTION REPORT
DATE:
JOB NO.
SHT of
LOCATION
CONTRACTOR
Description:
The works referenced have been inspected in accordance with Contract requirements and are in accordance with
the Project design criteria, drawings and specifications. All outstanding work to be detailed on the agreed joint
Punch List.
INSPECTION STAGES *
INITIALS/DATE
1.
Set-out/Grid Reference/ Bench marks
1
2. Excavation/Formation level
2
3. Fill/Formation level
3
4. Impermeable membrane
4
5. Sub-base/Graded fill
5
6. Asphalt/Macadam (pavement)
6
7. Testing (summary of test results)
7
8. Kerbing/Curbing
8
9. Finish level
9
10. Landscaping
Note!
10
Where additional excavation/fill is required because of unsuitable material/soft spots, these areas to be
clearly identified on the drawing and entered on the Punch List proforma.
Drawing Nos.
Drawing Nos.
Drawing Nos.
REMARKS
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC ©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM CW4- SHT 01
SITE:
TRANSPORTATION/PLACING OF CONCRETE
INSPECTION REPORT
DATE:
SHT of
JOB NO.
LOCATION
CONTRACTOR
Central Batching Plant:
In-Situ Batching:
Ticket No/Truck No:
Time of loading:
Time of Arrival: (at Location)
Description:
Ready Mix: (name depot)
Concrete:(Grade & Description): Quantity:
INITIALS/DATE
INSPECTION STAGE *
1. Check delivery details
1
2. Check stage inspection form CW1
2
3. Permission to commence (time and date)
3
4. Testing (type of test)
4
5. Number of cubes/cylinders taken
5
6. Protective Coatings
6
7. Cubes Reference No (tests results)
7
8. Time of Completion
REMARKS
8
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM CW5- SHT 01
SITE:
CONCRETE TEST CUBE / CYLINDER
SUMMARY
DATE:
JOB NO.
SHT of
LOCATION
CONTRACTOR
Description:
Cylinder No.
Location / Identification
COMPLETED BY
Date
Cast
Date
Test
WITNESSED BY
No. of
Days
PSI
Design
ACCEPTED BY
PSI
Actual
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM CW6 - SHT 01
SITE:
CIVIL COMPLETION
CERTIFICATE
DATE:
SHT of
JOB NO.
LOCATION
MODULE
Description:
The works referenced have been inspected in accordance with Contract requirements and are in accordance with
the Project design requirements, drawings and specifications. All outstanding work to be detailed on an agreed joint
Punch List.
Yes No N/A
INSPECTION STAGES *
INITIALS/DATE
1. Site preparation complete, buried utilities located and documented.
1
2. Geotechnical liners/filter/drainage fabrics installed.
2
3. Drainage culverts/structures installed.
3
4. Trenching completed to specified grades.
4
5. Backfill installed and compacted.
5
6. Structural fills installed and compacted.
6
7. Guard rails, fences, gates and bollards installed.
7
8. Finish grading complete to plan.
8
9. Erosion control and re-seeding complete.
10. Piles (USM) installed as per design location and in accordance with
specification.
11. Excess materials returned to warehouse, construction debris properly
disposed and work/site area cleaned up.
9
10
11
12. Roads and kerbing/curbing complete.
12
13. Road markings and road signs complete.
13
14. Landscaping complete.
Drawing Nos.
14
Drawing Nos.
Drawing Nos.
REMARKS
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
Project Title:
Maintenance No:
Work Pack No:
SH1 No:
MC1 No:
FORM BF1- SHT 01
SITE:
BUILDINGS - AREA ACCEPTANCE
CERTIFICATE
DATE:
SHT of
JOB NO.
LOCATION
CONTRACTOR
Description:
Boundary Wall
Disciplines
North
South
East
West
(Initial & Date)
(Initial & Date)
(Initial & Date)
(Initial & Date)
1. Electrical Services
2. HVAC Services
3. Fire & Gas
4. Finish - Walls
5. Finish - Floor
6. Finish - Ceiling
7. Doors & Windows
Complete
Yes
No
Room No: _______
1. Electrical Services
2. HVAC Services
3. Fire & Gas
4. Finish - Walls
5. Finish - Floor
6. Finish - Ceiling
7. Doors & Windows
Yes
No
Yes
No
1.2 Light Fittings
No
Outstanding Work
INSPECTION POINTS *
1.1 Power Points
Yes
(Circle Item Number)
1.3 Ariel Sockets
1.1
1.2
1.3
1.5
1.6
1.4 Trunking
1.5 Telecoms
1.6 Network Sockets
1.4
2.1 H/C Water System
2.2 LTHW System
2.3 Louvers/Vents
2.1
2.2
2.3
2.4 A/C System
2.5 CHW System
2.6 Ducting
2.4
2.5
2.6
3.1 Detectors
3.2 Extinguish System
3.6 Sprinkler System
3.1
3.2
3.6
3.4 Dampers
3.5 Fire
3.4
3.5
3.7
4.1 Paint
4.2
Curtain Rails
4.6 Picture Rails
4.1
4.2
4.6
4.4 Wall Covering
4.5
Coat Hooks
4.7 Skirting
4.4
4.5
4.7
5.1 Paint
5.2 Carpet
5.6 Boards
5.1
5.2
5.6
5.4 Screed/Concrete
5.5 Tiles
5.7 Floor Covering
5.4
5.5
5.7
6.1 Paint
6.2 Suspended
6.6 Hessian Covering
6.1
6.2
6.6
6.4 Tiles
6.5 Boards
6.7 Hatches
6.4
6.5
6.7
7.1 Fittings
7.2 Fastening (Windows) 7.6 Locks (Doors)
7.1
7.2
7.6
7.4 Glazing
7.5 Finish
7.4
7.5
7.7
Water
Hose 3.7 Alarms
7.7 Handles (Doors)
REMARKS
COMPLETED BY
WITNESSED BY
ACCEPTED BY
APPROVED BY
COMPANY
SIGNATURE
PRINT NAME
DATE
* Delete as appropriate
GOC©
BP Exploration 1989 - 2001 All Rights Reserved
Americas REV. 1
DIS8
LOCATION : __________________
DATA INPUT SHEET 8
PROJECT : ____________________
J.P
NO.
RAISED BY:
HANDOVER ID
____________________________________
NOTE: JP No FOR INSTALLATION
DRAWING No
DATE : __________________
GOC
OF
WORKSCOPE ID : ______________________
SECTION 10 CIVIL CONSTRUCTION
DESCRIPTION
SHEET
CW1
MAINTENANCE ID No : ______________________
CW2
CW3
Civil
CW4
CW5
CW6
BF1
DATA ENTERED BY : ____________________
© BP Exploration 1989 - 2001 All Rights Reserved
COMMENTS
DATE : ___________
Americas Rev. 1