asset integrity management approach to achieve excellence in process safety

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

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

Introduction

Sources:

1. UK HSE Key Programme 3 Asset Integrity Programme,

2. NASA System Failure Case Study, May 2013, Vol 7, Issue 4



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.

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



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

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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

Case Study: Hydrocarbon Gas Processing Plant

Source:

1. ADNOC GC Procedure for determining HSECES Ver 2, 2014

2. NOPSEMA Guidance Notes Rev 4, 2012



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


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

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

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

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.

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



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

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


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 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 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.


Function No.Functional Criteria / GuidanceAssuranceVerification


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 Extent:

Function No.FunctionFunctional Criteria / GuidanceAssuranceVerification


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.


Function No.Functional Criteria / GuidanceAssuranceVerification


Survivability

EventCriteriaAssuranceVerification

TaskDoc Ref.Task

Inter Dependency

SystemReason

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.

Summary


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.

About Us


Energy assurance for future generationsAbout Us

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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