asset integrity management approach to achieve excellence in process safety
TRANSCRIPT
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Technical Paper Presentation:
Case Study: Asset Integrity Approach to Achieve excellence in Process Safety
Ashish Kulkarni
Technical Centre HeadB.E. Petrochemical, TUV Certified CFSE Bell Energy Middle Eastwww.bell-energy.com
Energy assurance for future generations
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Energy assurance for future generationsTable of Contents
Introduction
Process Safety Excellence through Asset Integrity Management
Asset Integrity Risk Management Process
Asset Integrity Framework
Phase wise Integrity Assurance
Case Study: Hydrocarbon Gas Processing Plant
Scope of the Case Study
Methodology
Identification of HSECES Category & Tag Level
Establishing Performance Standards
Updating Maintenance Job Plans
Summary
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Introduction
Sources:
1. UK HSE Key Programme 3 Asset Integrity Programme,
2. NASA System Failure Case Study, May 2013, Vol 7, Issue 4
Energy assurance for future generations
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Energy assurance for future generations
Process Safety Excellence through Asset Integrity Management
Piper Alpha disaster acted as the catalyst for development of
Safety Case regulations.
The Safety Case regulations emphasize the need to maintain
integrity of HSE critical equipment and systems throughout
the asset lifecycle.
It puts the responsibility of demonstrating that all risks are
reduced to as low as reasonable practicable (ALARP) on the
owner / operator.
And requires that all those activities that prevent, mitigate or control major accidents at each phase are
identified, performed and verified.
These requirements are fulfilled through the Asset Integrity Management Programme and Assurance is
provided through the Safety Case.
Asset Integrity can be defined as the ability of an Asset to perform its required function effectively and
efficiently whilst protecting health, safety and environment.
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Asset Integrity Risk Management Process
Sources:
1. OGP Report No. 415 Asset Integrity Key to Managing Major Incident Risks
2. ADNOC CoP V1-02 HSEIA Requirements
3. ADNOC CoP V6-01 Identification & Integrity Assurance of HSE Critical Equipment & Systems
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Energy assurance for future generations
Asset Integrity Risk Management Framework
1. Laws, Regulation & Company StandardsWhat Drives the Requirement for Asset Integrity? National Laws, International Codes & Standards Company Regulations.
2. Communication & Consultation: Who all should be involved in this Process? All stakeholders Projects, Operations, Maintenance, Shareholders Content of communication based on the type & role of stakeholder
and according to the codes and standards
3. Risk Assessment What Can Happen? Identify the risks, Analyse the consequences and frequency Evaluate the risk acceptability
4. Risk TreatmentWhat do we do? Involves considering all feasible solutions (engineering & procedural
controls) to reduce risk to ALARP
5. Monitoring and ReviewWhat could we do better? Lessons Learnt Update in Technology
1. Laws, Regulations & Company Standards
3.1 Risk Identification
3.2 Risk Analysis
3.3 Risk Evaluation
4. Risk Treatment
2. C
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5. M
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3. R
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Phase Wise Integrity Assurance
ConceptEngineer, Procure & Construct
Install & Commission Operation
Modify / Decommission
Phases in Asset Lifecycle
Phase 1: Design Integrity Phase 2: Technical Integrity Phase 3: Operational Integrity
Identify Barriers at System Level Process Containment Safety Instrumented Systems Fire Protection Equipment
Define Design Performance Standards for each Barrier Max. Pressure, Temperature,
Stresses Time Factors Failure Modes & Effects
FEED
Identify Barriers at Equipment Level Pressure Vessel: V-101 Pumps: P-206 Fire Detector: F-001
Define EPC Performance Standards for each Barrier Loading / Unloading method Storage / Stacking method Commissioning Procedure
Identify Barriers at Functional Location Parent / Child Relationship or Geographical Location
Define Operate Performance Standards for each Barrier Inspection requirements Maintenance requirements Frequencies
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Case Study: Hydrocarbon Gas Processing Plant
Source:
1. ADNOC GC Procedure for determining HSECES Ver 2, 2014
2. NOPSEMA Guidance Notes Rev 4, 2012
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Energy assurance for future generations
Scope of the Case Study
Facility Description
The Project consisted of three primary components:
New facilities at an offshore Island to compress and dry hydrocarbon gases.
A 30" high-pressure 120 km offshore pipeline to transport dried gas to processingsite.
Processing site includes: Inlet separation and Stabilization unit, Debutanizer and Expanded storage facility, Tie in to existing system and Export pipeline
Scope:
To identify HSECES at tag level
Define Performance standards for each HSECES category.
Updating Maintenance Job Plans
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Methodology
Review of COMAH / Bowtie Analysis
Classify Equipment in to HSECES Category
Updating HSECES Maintenance Job Plans
Develop HSECES Performance Standards
Outcome: HSECES Categories
Outcome: Potential for Optimization
Outcome: Tag Level Demarcation
Risk Ranking
Outcome: Examination Rigour
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Energy assurance for future generationsIdentification of HSECES Categories
Ignition Control1. Hazardous Area
Classification2. Certified Electrical
Equipment3. Earthing & Bonding4. Fuel Gas Purge
Process Containment1. Pressure Vessels2. Heat Exchangers3. Rotating Equipment4. Piping5. Relief System
Detection Systems1. Fire & Gas
Detectors2. Pipeline Leak
Detectors3. H2 Detectors
Protection Systems1. Active Fire
Fighting2. Passive Fire
Protection3. Firewater ring
main
Shutdown Systems1. ESD System2. Blowdown3. HIPPS
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Energy assurance for future generationsIdentification of HSECES at Tag Level
1. Decision Tree applied to each equipment tag
2. Classify equipment into HSECES and Non HSECES
3. Route Numbers 1, 3, 4, 6, 8 and 9 are HSECES
4. Route Numbers 2, 5, 7 and 10 are Non HSECES
5. Create Spreadsheet and list classification for each equipment tag
6. Link each equipment with Category based on the Function of the HSECES
7. HSECES Functions are: 1. Prevention, 2. Control / Alarm,3. Mitigation & 4. Emergency Response
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Energy assurance for future generationsRisk Ranking
An HSECES is associated with prevention, control, mitigation or recovery of a potential accident that is classified into Severity
4 Severe or Severity 5 Catastrophic or Severity 3 Critical with Probability E Frequent 1 in 10 years.
The criticality is purely the risk if the HSECES fails to operate on demand. The higher the risk, higher the criticality.
For e.g. A pressure vessel that ruptures catastrophically has severity 5 with a frequency determined from a QRA study or past
incidents to be Occasional. In this case its criticality is 5C and is more critical than an Atmospheric Tank that leaks with
severity 4 with similar probability.
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Energy assurance for future generationsHSECES Identification Spreadsheet
Sr. No. EQUIP. No EQUIP. No. Description HSECES(Y/N) Reason for HSECESHSECES
Route
IMPACT CRITERIA ADNOC RISK MATRIX
P A E R Risk Ranking
1 41104052 ABSORBER COLUMN Y Element contains flammable hydrocarbon. A catastrophic release from this element could lead to injury to personnel 1 2C 4B 4C 2C 4C
2 41205733 GLYCOL STILL Y Element contains flammable hydrocarbon. A catastrophic release from this element could lead to injury to personnel 1 2C 4B 4C 2C 4C
3 41104053 STRIPPER COLUMN Y Element contains flammable hydrocarbon. A catastrophic release from this element could lead to injury to personnel 1 2C 4B 4C 2C 4C
8 70201863 DIFF PRESSURE TRANSMITTER (FLOW) YThe element is part of shutdown / mitigation system designed for emergency situations 3 4C 4B 2C 2C 4C
12 70230413 LEVEL TRANSMITTER (DISP/GWR) YThe element is part of shutdown / mitigation system designed for emergency situations 3 4C 4B 2C 2C 4C
9 70230410 LEVEL TRANSMITTER (DISP/GWR) YThe equipment is designated to protect process equipment in order to avoid catastrophic failure/injury 4 2D 4B 2C 1A 4B
14 70230415 LEVEL TRANSMITTER (GWR) Y The equipment is designated to protect process equipment in order to avoid catastrophic failure/injury 4 4C 4B 2C 2C 4C
20 44408125 1" x 2" PRESSURE SAFETY VALVE YThe failure of element can cause Major Accident or it prevents, controls, or mitigate a Major Accident 8 1B 4C 2C 2B 4C
21 44408126 1" x 2" PRESSURE SAFETY VALVE YThe failure of element can cause Major Accident or it prevents, controls, or mitigate a Major Accident 8 1B 4C 2C 2B 4C
22 44408127 1" x 3" PRESSURE SAFETY VALVE YThe failure of element can cause Major Accident or it prevents, controls, or mitigate a Major Accident 8 1B 4C 2C 2B 4C
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Energy assurance for future generationsDeveloping Performance Standards
Parameters which are measured or assessed so that the suitability and effectiveness of each HSECES can be assured or verified.
FUNCTIONALITY
RELIABILITY
AVAILABILITY
SURVIVABILITY
Intended purpose of the HSECES in terms of its role in preventing, controlling ormitigating the event in protecting people and assets.
The likelihood that a HSECES will perform its function on demand or when calledupon to do so.
Conditions necessary for a HSECES to remain functional during an incident until it hasperformed its function.
INTERACTION / DEPENDENCIES Relationship between HSE Critical Equipment and Systems
Best Practices in Developing Performance Standards:
1. Performance Criteria shall cover all foreseeable operating parameters that can cause failures
2. It shall cover Failure Modes including common causes due to failure of other HSECES
3. Define Minimum Acceptance Criteria for each function that can be measured
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Energy assurance for future generationsPerformance Standard Template
Risk Reduction Measure: Prevention Control Mitigation Life Cycle PhaseHSECES Group: Structural Integrity Detection Systems Shutdown Systems Phase 1:
Ignition Control Protection Systems Emergency Response Phase 2:Process Containment Life Saving Phase 3:
HSECES Reference No.:HSECES Criticality:
Doc Ref.
Doc Ref.
Doc Ref.
Inter DependencySystem Reason
Task Task
Survivability
Event Criteria Assurance Verification
Reliability / Availability
Function No. Functional Criteria / Guidance Assurance VerificationTask / Confirmation Task
HSECES Extent:
Function No. Function Functional Criteria / Guidance Assurance VerificationTask / Confirmation Task
System: Revision No.:
HSECES Goal: To provide an early warning of drifting flammable gas clouds in the Storex Tank farm area.
HSECES Performance Standard TemplateHSECES: Performance Standards Ref.:Site: Performance Standards Owner:Plant: Signed off:
Risk Reduction Measure: Prevention Control Mitigation Life Cycle PhaseHSECES Group: Structural Integrity Detection Systems Shutdown Systems Phase 1:
Ignition Control Protection Systems Emergency Response Phase 2:Process Containment Life Saving Phase 3:
HSECES Reference No.:HSECES Criticality:
Doc Ref.
Doc Ref.
Doc Ref.
Inter DependencySystem Reason
Task Task
Survivability
Event Criteria Assurance Verification
Reliability / Availability
Function No. Functional Criteria / Guidance Assurance VerificationTask / Confirmation Task
HSECES Extent:
Function No. Function Functional Criteria / Guidance Assurance VerificationTask / Confirmation Task
System: Revision No.:
HSECES Goal: To provide an early warning of drifting flammable gas clouds in the Storex Tank farm area.
HSECES Performance Standard TemplateHSECES: Performance Standards Ref.:Site: Performance Standards Owner:Plant: Signed off:
Draft - HC-D01Design
ADGAS HSECES Performance Standard
HSECES: HC Gas Detectors (IR Type)Performance Standards Ref.: Fire & Gas Detection Systems - D01
Site: Das IslandPerformance Standards Owner: HOM (S)
Plant: ADGAS OAG PLANTSigned off:
System: AllRevision No.: 0
Package / Skid: AllDate: 21 June 2014
Risk Reduction Measure: PreventionControlMitigationLife Cycle Phase
HSECES Group:Structural IntegrityDetection SystemsShutdown SystemsPhase 2: EPC*
Ignition ControlProtection SystemsEmergency ResponsePhase 3: Operation
Process ContainmentLife Saving
HSECES Reference No.:*Engineering, Procurement and
HSECES Criticality: Construction
HSECES Goal: To provide an early warning of drifting flammable gas clouds in the Storex Tank farm area.
HSECES Extent: This performance standard covers HC gas detectors (IR type) in all Trains and the Storex Tank farm area.
Function No.FunctionFunctional Criteria / GuidanceAssuranceVerification
Task / ConfirmationDoc Ref.Task
11.1 Provide warning of presence of flammable gas. 1.2 Gas detector heads to detect the presence of flammable gas at 10% of the lower explosive level (LEL) of methane or other combustible gases. 1.3 System to provide a response to low and high gas detection signals. 1.4 System to automatically activate visual and audible alarms. 1.5 Detector design in accordance withaccepted codes and standards. .1.1.1 Fixed toxic and flammable gas detectors, which will monitor H2S over a wide concentration range are provided at the boundary limit affecting the ADGAS Plant area and they will be liked to alarm/siren system.1.1.2 ADGAS sites have multigas detectors. Detectors will be of the infra red type sensor calibrated for methane. 1.3.1 Flammable gas detectors shall alarm at multiple points. The first alarm shall be initiated at 10% of the lower flammability limit (LFL). The sensor system shall be designed to alarm again at 40% of LFL.1.4.1 The audible and visual alarm devices shall be actuated automatically in the event of flammable gas release being detected. 1.4.2. Control Room Operator shall confirm the authenticity of the alarm. 1.5.1 Existing HC detectors (cataytic type) are replaced with IR type detectors based on best industry practice per IR detector design in accordance with accepted codes and standards; CSA C22.2 #152, FM 6310 / 6320, ANSI / ISA-12.13.01 1.5.2. Detector has self diagnostics feature (at every 60 seconds) and any failure will be alarmed in the DCS and local LED indication on the detector.1.3.1. ADGAS Maintenace to calibrate the detector on quarterly basis using calibration kit. 1.4.2. Field Operator shall confirm the authenticity of the alarm by hand held gas monitors and the correct setpoints of the sensors.1.4.1. Records of any alarm (including detector failure alarms) initiated by the system shall be verified by Maintenance Team. Detection and actions initiated are logged in F&G detction system (Honeywell Safety Manager Sequence of Events) and are recorded in DCS (Historian Sever).1.5.1. Diagnostic and response function test. (BP-ETP GIS 30-851) 1.1.1.1. SC-100-A4J-0-09841, SC-100-A4J- 0-02823, SC-100-A4Z-99974, ADGAS ERP. BP-ETP GIS 30-851, IEC 61511, GOP 2.6. 1.2.1.1. OEM Manual 1.3.1.1. Alarm history record. DCS Historian server. 1.3.1.2. Set points (10%LEL) as per existing detector data sheets. 1.4.1.1. Control Room Log books. Refer to Sections 7.5 and 7.8 of Fire Protection Basis of Design. Refer to Section 2 of Specification for Fire and Gas System. 1.4.2.1. Control Room Operator Log book entries. 1.5.1.1. CSA C22.2 #152, FM 6310 / 6320, ANSI / ISA-12.13.011.1.1.1 Calibration log records 1.2.1.1. Alarm confirmation/cross check records. 1.3.1.1. Maintenance alarm response records. DCS Historian Server.1.4.1.1. Review Control Room Log book entries. 1.5.1.1. Functional diagnostics test record.
22.1 Gas detectors located in Control Rooms (Storex Control Room, Plant 28 Sulphur Control Room), LNG Jetty Plant, and General Plant Areas shall detect the presence of flammable gas at 10% lower explosive level (LEL) of combustible gases and subsequently triggers the audible and visual alarms with closing of HVAC inlet dampers (circulation mode) in Control Rooms.
2.2 Gas detectors located in Control Rooms (Storex Control Room, Plant 28 Sulphur Control Room), LNG Jetty Plant, and General Plant Areas shall detect the presence of flammable gas at 40% lower explosive level (LEL) of combustible gases and subsequently triggers the audible and visual alarms with shutdown of HVAC systems in Control Rooms. It will also intiate the shutdown through plant ESD system (stop all loading pumps and close all loading valves). 2.3 To provide warning of presence offlammable gas in the construction area. Boundary (worksite) flammable gas detection and alarms are provided to warn of any incident affecting the ADGAS Plant area.2.1.1. Existing HC detectors (cataytic type) are replaced with IR type detectors based on best industry practice. The IR detector design is in accordance with accepted codes and standards; CSA C22.2 #152, FM 6310 / 6320, ANSI / ISA-12.13.01
2.1.2. Set points (10%LEL and 40% LEL) as per existing detector data sheets.
2.1.3. Control Room Operator shall confirm the authenticity of the alarm.
2.1.4. HVAC inlet damper shall be closed at 10% LEL detected by the HVAC inlet HC detectors and HVAC shall run in circulation mode.
2.2.1. HVAC system shall shutdown on detection of 50% LEL by the HVAC inlet HC detectors.
2.2.2. Detection and actions initiated are logged in F&G detction system (Honeywell Safety Manager Sequence of Events) and are recorded in DCS (Historian Sever).
2.2.3. New detector has self diagnostics feature (at every 60 seconds) and any failure will be alarmed in the DCS and local LED indication on the detector. 2.3.1 During construction of ADGAS Plants site boundary flammable & toxic detectors are linked to an alarm siren.2.1.2. ADGAS Maintenace to calibrate the detector on quarterly basis using calibration kit. 2.1.3. Control Room Operator Log book entries. 2.1.4 & 2.2.1. Damper closure Test 2.2.2. Records of any alarm (including detector failure alarms) initiated by the system shall be verified by Maintenance Team. Detection and actions initiated are logged in F&G detction system (Honeywell Safety Manager Sequence of Events) and are recorded in DCS (Historian Sever).2.2.3. Diagnostic and response function test. 2.2.4. Field Operator shall confirm the authenticity of the alarm by hand held gas monitors and the correct setpoints of the sensors.2.1.1. SC-100-A4J-0-09841, SC-100-A4J- 0-02823, SC-100-A4Z-99974, ADGAS ERP. BP-ETP GIS 30-851, IEC 61511, GOP 2.6. 2.1.2/2.1.4/2.2.1. Maintenance routines and records. 2.1.3. Control Room Log books. 2.2.2. Alarm history record. DCS Historian server. 2.2.3. OEM Manual, Maintenance routines and records. 2.2.4.1. Control Room Operator Log book entries. 2.1.1.1 Relevant Standards available. 2.1.2.1. Maintenance alarm response records. DCS Historian Server. 2.1.3.1. Review Control Room Log book entries. 2.1.4.1/2.2.1.1. HVAC inlet damper close alarm in the DCS. HVAC system shutdown alarm in the DCS.2.2.3.1. Functional diagnostics test record.2.2.4.1 Field Operator shall confirm the authenticity of the alarm by hand held gas monitors.
Reliability / Availability
Function No.Functional Criteria / GuidanceAssuranceVerification
Task / ConfirmationDoc Ref.Task
11.1. To detect the presence of flammable gas at given LEL % and initiation of alarm (visual and audible) in the operation of a single portable detector system or a boundary flammable gas detection and alarm system.1.1.1. Probability of successful operation of system on demand is 99% -HSEIA. 1.1.2. New detector has self diagnostics feature (at every 60 seconds) and any failure will be alarmed in the DCS and local LED indication on the detector, and it has an automated self check. 1.1.3. Vendor advised maintenance schedule is 3 months (quarterly).As per Manufacturer recommendations.1.1.1. Detector failure alarms are logged in F&G detction system (Honeywell Safety Manager Sequence of Events) and are recorded in DCS (Historian Sever). 1.1.3. ADGAS Maintenace to calibrate the detector on quarterly basis using calibration kit.1.1.1.1. SAP Alarm records - DCS Historian. BP-ETP GIS 30-851 , IEC 61511 1.1.3.1. OEM manual, Maintenance Routines.1.1.1.1.1. Records of any alarm (including detector failure alarms) initiated by the system shall be verified. 1.1.3.1.1. ADGAS Preventive Maintenance Program and periodic auditing.
Survivability
EventCriteriaAssuranceVerification
TaskDoc Ref.Task
11.1 Fire/Explosion1.1.1. Having detected the presence of gas and initiated appropriate alarm signals, gas detectors are not required to survive any subsequent major accident events.
Inter Dependency
List other equipment that depends on the continuing operation of this equipment to function safely and correctly. List other equipment that THIS equipment requires to be operating for this equipment to function properly.
SystemReason
Emergency Response E03The confirmed detection of fire will initiate emergency response actions as defined in the Emergency Response Plan (ERP).
Emergency Shut Down C01The confirmed detection of fire will initiate emergency shut downs and alarms.
Emergency Alarms E04The confirmed detection of the fire will initiate emergency alarms.
Emergency Communications E01The release of sour gases will be communicated for various emergency actions such as response, control or evacuation as necessary.
Certified Electrical Equipment & High Voltage Supply P10The flame detectors shall be certified to be used in hazardous areas.
Draft - HC-D01Design (2)
HSECES Performance Standard Template
HSECES:Performance Standards Ref.:
Site:Performance Standards Owner:
Plant:Signed off:
System:Revision No.:
Risk Reduction Measure: PreventionControlMitigationLife Cycle Phase
HSECES Group:Structural IntegrityDetection SystemsShutdown SystemsPhase 1:
Ignition ControlProtection SystemsEmergency ResponsePhase 2:
Process ContainmentLife SavingPhase 3:
HSECES Reference No.:
HSECES Criticality:
HSECES Goal: To provide an early warning of drifting flammable gas clouds in the Storex Tank farm area.
HSECES Extent:
Function No.FunctionFunctional Criteria / GuidanceAssuranceVerification
Task / ConfirmationDoc Ref.Task
22.1 Gas detectors located in Control Rooms (Storex Control Room, Plant 28 Sulphur Control Room), LNG Jetty Plant, and General Plant Areas shall detect the presence of flammable gas at 10% lower explosive level (LEL) of combustible gases and subsequently triggers the audible and visual alarms with closing of HVAC inlet dampers (circulation mode) in Control Rooms.
2.2 Gas detectors located in Control Rooms (Storex Control Room, Plant 28 Sulphur Control Room), LNG Jetty Plant, and General Plant Areas shall detect the presence of flammable gas at 40% lower explosive level (LEL) of combustible gases and subsequently triggers the audible and visual alarms with shutdown of HVAC systems in Control Rooms. It will also intiate the shutdown through plant ESD system (stop all loading pumps and close all loading valves). 2.3 To provide warning of presence offlammable gas in the construction area. Boundary (worksite) flammable gas detection and alarms are provided to warn of any incident affecting the ADGAS Plant area.2.1.1. Existing HC detectors (cataytic type) are replaced with IR type detectors based on best industry practice. The IR detector design is in accordance with accepted codes and standards; CSA C22.2 #152, FM 6310 / 6320, ANSI / ISA-12.13.01
2.1.2. Set points (10%LEL and 40% LEL) as per existing detector data sheets.
2.1.3. Control Room Operator shall confirm the authenticity of the alarm.
2.1.4. HVAC inlet damper shall be closed at 10% LEL detected by the HVAC inlet HC detectors and HVAC shall run in circulation mode.
2.2.1. HVAC system shall shutdown on detection of 50% LEL by the HVAC inlet HC detectors.
2.2.2. Detection and actions initiated are logged in F&G detction system (Honeywell Safety Manager Sequence of Events) and are recorded in DCS (Historian Sever).
2.2.3. New detector has self diagnostics feature (at every 60 seconds) and any failure will be alarmed in the DCS and local LED indication on the detector. 2.3.1 During construction of ADGAS Plants site boundary flammable & toxic detectors are linked to an alarm siren.2.1.2. ADGAS Maintenace to calibrate the detector on quarterly basis using calibration kit. 2.1.3. Control Room Operator Log book entries. 2.1.4 & 2.2.1. Damper closure Test 2.2.2. Records of any alarm (including detector failure alarms) initiated by the system shall be verified by Maintenance Team. Detection and actions initiated are logged in F&G detction system (Honeywell Safety Manager Sequence of Events) and are recorded in DCS (Historian Sever).2.2.3. Diagnostic and response function test. 2.2.4. Field Operator shall confirm the authenticity of the alarm by hand held gas monitors and the correct setpoints of the sensors.2.1.1. SC-100-A4J-0-09841, SC-100-A4J- 0-02823, SC-100-A4Z-99974, ADGAS ERP. BP-ETP GIS 30-851, IEC 61511, GOP 2.6. 2.1.2/2.1.4/2.2.1. Maintenance routines and records. 2.1.3. Control Room Log books. 2.2.2. Alarm history record. DCS Historian server. 2.2.3. OEM Manual, Maintenance routines and records. 2.2.4.1. Control Room Operator Log book entries. 2.1.1.1 Relevant Standards available. 2.1.2.1. Maintenance alarm response records. DCS Historian Server. 2.1.3.1. Review Control Room Log book entries. 2.1.4.1/2.2.1.1. HVAC inlet damper close alarm in the DCS. HVAC system shutdown alarm in the DCS.2.2.3.1. Functional diagnostics test record.2.2.4.1 Field Operator shall confirm the authenticity of the alarm by hand held gas monitors.
Reliability / Availability
Function No.Functional Criteria / GuidanceAssuranceVerification
Task / ConfirmationDoc Ref.Task
Survivability
EventCriteriaAssuranceVerification
TaskDoc Ref.Task
Inter Dependency
SystemReason
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Energy assurance for future generationsUpdating Maintenance Job Plans
Align Assurance Tasks with Maintenance Strategy
HSECES performance assurance tasks can be integrated with normal Maintenance Job Plans
where applicable / logical.
HSECES performance assurance task frequency is derived from Risk & Reliability
Management Results, where RRM results are not available, Design Standards or formal safety
studies requirements are followed.
Optimization Techniques:
Performance assurance tasks can be combined in the same Planned Maintenance Routine but
the operation shall be identified as an assurance task.
Performance assurance tasks on several HSECESs can be combined into the same Planned
Maintenance Routine to optimise planning and execution effort.
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Summary
Energy assurance for future generations
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Energy assurance for future generationsSummary
Advantages
Approach focusses on prevention of Major Accident Hazards;
Prioritizes on critical equipment & systems;
Integrates with Maintenance Strategies and makes for a robust maintenance regime;
Optimizes planning & execution efforts.
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About Us
Energy assurance for future generations
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Energy assurance for future generationsAbout Us
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Thank you
Technical Paper Presentation:Case Study: Asset Integrity Approach to Achieve excellence in Process SafetyTable of ContentsIntroductionProcess Safety Excellence through Asset Integrity ManagementAsset Integrity Risk Management ProcessAsset Integrity Risk Management FrameworkPhase Wise Integrity AssuranceCase Study: Hydrocarbon Gas Processing PlantScope of the Case StudyMethodologyIdentification of HSECES CategoriesIdentification of HSECES at Tag LevelRisk RankingHSECES Identification SpreadsheetDeveloping Performance StandardsPerformance Standard TemplateUpdating Maintenance Job PlansSummarySummaryAbout UsAbout UsSlide Number 22