Lyntas/mining_domain_knowledge_reference_dataset huggingface dataset:
Area: Plant Integrity
PERSONNEL, COMPETENCY & TRAINING
Definitive job profiles
Recruitment & selection of appropriately qualified and suitable staff
Development of criteria that defines the Person Profile
Competence Assessment
Training and plans for new & existing facilities
Certification e.g. Survival
Personal & Career Development
HSE Awareness and training
Area: Plant Integrity
OPERATIONS
Operating Plant & equipment examinations, inspection & test management of the operating envelope.
PFDs and P&IDS
Original design flow rates (Oil, Water, Gas)
Current flow rate (Oil, Water, Gas)
A copy of Process simulation, Process monitoring & data capture e.g. production reporting
Operating Procedures for, inter alia, starting & stopping
Inlet design condition (pressure, temperature at the wellhead and topside)
Number of processing trains and separation stages for each train on the topsides
Design parameter for sizing the separators such as retention time and dimensions and operating conditions
Original Fluid composition
Current Fluid composition
Fluid specific gravity original and current
Chemical injection rates for Emulsion, wax/paraffin, scale inhibitor Anti-foam 
Use of chemicals
Alarm management including overrides and trips
Handovers, crew changes
Isolations standards, valve control, custody arrangements
Sampling
Standing documentation
Compilation of Operations Integrity Management System (OIMS)
Produced water specification (is produced water re-injected or sent overboard?)
Gas product specification
Natural gas flared or sent to the pipeline for sale or compressed and re-injected
Sand production
Salt produced and if so is crude being desalted?
Area: Plant Integrity
ASSET INTEGRITY MANAGEMENT
Communication between onshore support staff and offshore inspection and maintenance technicians
Competence assurance of inspection technicians and their supervisors
Documented management system, including Written Schemes of Examination (WSoE)
Identification of Safety Critical Elements (SCE)
Corrosion identification and rectification
Corrosion Under Insulation (CUI)
Deadleg register
Risk assessment / mitigation
Risk Based Inspection (RBI) Process
Recording of inspection work
Deferrals and Backlogs
Measuring the effectiveness of the inspection regime
Inspection and System test of SCE
Condition of plant
Examples of Best Practice
Measuring compliance with performance standards / verification schemes
Measuring the quality of inspection work
Verification
Review of recommendations
Reporting to senior management on integrity status
Key Performance Indicators (KPIs) for inspection effectiveness
Offshore AIM processes
Onshore AIM processes
Area: Plant Integrity
MAINTENANCE
Competence assurance of maintenance technicians and their supervisors
Interface with Computerized Maintenance Management Systems (CMMS) including register of assets
Maintenance plans and schedules for equipment and execution
Maintenance of safety critical elements
Measuring the quality of maintenance work
KPIs for maintenance effectiveness
Critical and non-critical spares management
Supervision
Recording of completed maintenance work
Deferrals and Backlogs
Corrective Maintenance
Defined Life Repairs
Measuring the effectiveness of the maintenance system
Life Saving Appliances
Pipework of all diameters  including small bore and pipelines
Heat exchangers
Pressure vessels and their relief devices
Electrical
Lifting & loading equipment
Rotating equipment  pumps, compressors, fans
Process control and Emergency Shutdown Devices (ESD)
Instruments  including fire & gas
Tanks
Fire Protection  active and passive
Structures
Navigation aids & Communications equipment
Fired boilers
Temporary Equipment
Area: Plant Integrity
MANAGEMENT OF CHANGE (MOC)
Engineering changes, including maintenance, inspection & testing
Process changes  including changes in flow stream components
Changes to procedures
Changes to software (but not to standard office based IT systems)
Organizational changes
Formal documentation of these processes
Area: Plant Integrity
INTERFACE MANAGEMENT
Contracts & Procurement  the process, authority levels and execution
The provision of 3rd party services, their control, utilization and deliverables
Facilities interfaces where they are an integral part of the Operation e.g. pipelines
Appointment of Company Designated Site Representatives for every contract
Shutdown Development, Management & Coordination
Transfer of knowledge from one phase of a project to another
Transfer of ownership of assets inter & intra company
Area: Plant Integrity
WELL ENGINEERING
Compliance with relevant legislative environment
Full Well Life Cycle involvement
Clear, accountable leadership
Clearly defined roles and responsibilities
Documented Management system, including Written Schemes of Examination (WSoE)
Interface with related Asset Integrity Management systems eg Pressure Systems
Identification of Safety Critical Elements (SCEs)
Performance Standards
KPIs - technical and business
Risk assessment / mitigation
Maintenance plans and schedules for equipment and execution
Appropriate SCE / barrier test and inspection frequencies
Control systems equipment testing
Defects identification, repair and reporting
Corrosion identification and rectification
Annulus pressure monitoring and reporting
Annulus liquid level top up
Knowing the difference between annulus Maximum Allowable Annulus Surface Pressure (MAASP) and
Maximum Allowable Surface Pressure (MASP)
Well control during well intervention operations
Well Handover through life cycle phases
Well Handover between well intervention and production operations
Management of abnormal conditions e.g. High Pressure High Temperature / H2S
Integrated web based management tool suite
Real time integrated data collection that is globally available
Trend recognition / analysis
Record keeping and results appropriately documented
Well equipment status files
Well anomaly reporting, review and remedial actions
Understanding of the Well Examination / Verification Interface
Continued education and engagement of staff in Well Integrity delivery
Area: Plant Integrity
Pipeline System means:
Pipework (including associated risers), valves, pressure vessels e.g. pig traps, control & measurement systems, cathodic protection, support structures, inspection provision, connections and injection points included in the pressure containing envelope peculiar to a pipeline system as distinct from similar equipment found on offshore and onshore installations: a system for the conveyance of the designated pipeline contents.
Pipeline safety
Pipeline design and construction
Risk Based Inspection (RBI)
Pipeline operating codes and standards
Emergency shutdown valves requirements
Inspection, testing, maintenance and cleaning of pipelines
Pressure systems safety
Corrosion management of subsea pipelines
Change management
Anomaly management
Verification procedures
Area: Plant Integrity
Practice
Before embarking on any course of action, the present status needs to be determined. That involves asking questions of the heads of inspection / maintenance departments, inspection contractors and Offshore Installation Managers (OIM)s. The most fundamental ones are:
What are the biggest worries / fears you have with regard to the Asset Integrity of XYZ Oil and Gass offshore, and onshore facilities?
What is your top 10 bad stuff list and what keeps you awake at night?
Do you have enough resources and budget to do the work that you feel necessary?
It is recommended that the Assets are visited to assess the condition of the facilities and the inspection / maintenance programs.

There are a number of areas which need to be reviewed and analyzed when assessing an existing asset integrity system. Not all of the following 24 areas will be relevant in every situation but they make a good starting point.


Next up would be a complete review of historical data and trend analysis and assessing whether that information is being acted on to rationalize the inspection and maintenance programs. Again prioritization of the threats to the Assets would be top of the list.
A major consideration would be to perform a Risk Based Inspection assessment on the systems in operation. Is there already an RBI system in place? If so, the questions would be; what happened regarding the outcomes and how did they affect the inspection frequencies / regimes for the Assets and is it now time to revisit that RBI because it was done (for example) 5 years ago

Next to look at would be the Performance Standards and Verification Schemes that are in place.

The problem with an Asset Integrity system is that it cannot be static. It has to be a living, breathing thing that changes over time. It is important that it changes to reflect the age and operational characteristics of the facilities.
The inspection regime for a 3 year old platform is different to one that is 30 years old.

Next would be budgeting and resources

This last point is very important. Many a system falls over because of the people operating it. Have they the right qualifications and experience?
Area: Plant Integrity
Asset Integrity Management (AIMS)
Asset Integrity Management System (AIMS) is the systematic implementation of activities such as inspection, tests and maintenance task necessary to ensure that important equipment will be suitable for intended application throughout its service life
Area: Plant Integrity
AIMS Framework
As a management process, AIMS process shall include policy development; organizing; planning and implementation; measuring performance; and audit and review
Asset Integrity Toolkit is a guideline to develop AIMS for offshore production facilities. It was published in 2006, developed by a joint industry project between UK Offshore Operators Association (UKOOA)
Area: Plant Integrity
Asset Integrity Toolkit defines 32 elements of AIMS into 6 six groups as follows:
1. Assurance and Verification;
Facility Owner shall define safety critical element (SCE) within the facility. SCE is a term in Safety Case (UK Offshore Installation Safety Regulations SI 2005 No 3117) to refer to:
- Parts of an installation and such of its plant or any part thereof, the failure of which could cause or contribute substantially to a major accident; or
- A purpose of which is to prevent or limit the effect of a major accident.
The assurance process is the duty holders responsibility to set out an assurance scheme that defines and manages the activities which ensure required performance standards of SCE are sustainable. While the verification process is the duty holders responsibility to develop verification scheme that provides the evidence to demonstrate the assurance scheme is operating effectively. Independent reports and comments shall be able to define clearly SCE list, assurance activities applied to SCE, and any failures and or anomalies are in communication with the duty holders
Area: Plant Integrity
2. Assessment/Control and Monitoring
The process of assessment/control and monitoring should include the following key elements:
- Rigorous risk assessment of potential major hazards and threats from plant equipment and operations to the personnel, the environment, and the asset;
- Identification necessary mitigation and controls in order to lower each of the risks to a level which is 
As Low as Reasonably Practical (ALARP);
- Recognition of which of these controls takes the form of SCE and assurance that the associated performance standards are continually maintained. Main issue in this element is engineering integrity. The duty holders should develop strategy to maintain the integrity of plant equipment against mechanical failure, fatigue, corrosion, throughout asset lifecycle.
Activities ruled under this AIMS element are: Asset register (asset information system); Risk Assessment (risk based inspection); Mitigation Plan (repair, replace,re-engineering); Inspection and monitoring (NDT, vibration analysis); and Integrity assessment (fitness for service, defect assessment).
Area: Plant Integrity
3. Competence
Personnel with the required levels of competence should be supported by commitment of senior management. Duty holders should develop competence system that should: be able to verifiable by audit of training, recruitment process, formal assessment, provides demonstrable capability within their pre-defined and agreed job description, be in accordance with national or equivalent standards, cover third party contractors.
Area: Plant Integrity
4. Planning
AIMS should be comprehensively planned for successful implementation. The planning and implementation of an Integrity Management System should includes:
- Processes definition required to manage the integrity of asset;
- Resources and Responsibility Allocation;
- Identification performance against the plan;
- Identification SCE should be included;
 - Identification business element should be included; and
- Effective prioritization of activities
5. Maintenance Management System
Maintenance Management System (MMS) provides the process for managed and control of maintenance program including set of maintenance task and their schedules. Target object of MMS include the following:
- Maintaining the condition, functionality, operability of equipments;
- Reducing failure incidence or mean time between failures, downtime after failures or mean time to repair;
- Reducing critical incidents or near miss accidents;
Area: Plant Integrity
6. Quality and Audit
Quality management and audit should be integrated and aligned in every process embedded in every aspects of asset integrity management through out six lifecycle stages. Quality and audit system as to senior management framework to guide organization toward performance improvement can encompass the four Cs of control (defined roles and responsibilities), communication (clear reporting and record keeping), competence (training and supervision), and co-operation (interface management). Intercorrelation AIMS to Other Corporate Process
Area: Plant Integrity
AIMS related to OE
Correlation AIMS with Corporate Process called Operational Excellence Management System (OEMS) start from quote of Element 5, Reliability Expectations 5.1  5.7, which states: Organizations are expected to Operate and maintain wells and facilities to ensure asset integrity and prevent incidents.
Area: Plant Integrity
AIMS related to SERIP
In PT. CPI, AIMS is a sub process of another bigger Chevrons Process called Surface Equipment Reliability and Integrity Process (SERIP). AIMS is covered in Stages 3, 4 and 5. Until now, most Business Units are in SERIP stage 1 or 2.
Area: Plant Integrity
References
- API RP 2A: Recommended Practice for Planning, Designing and Constructing Fixed Offshore Platforms
- API RP 75: Recommended Practice for Development of a Safety and Environmental Management Program (SEMP) for Offshore Operations and Facilities
- API 510: Pressure Vessel Inspection Code-lnspection, Repair, Alteration, and Rerating
- API 570: Piping Inspection Code-Inspection, Repair, Alteration, and Rerating of Inservice Piping Systems
- API RP 571: Damage Mechanisms Affecting Fixed Equipment in the Refining lndustry
- API 579: Fitness for Service
- API RP 580: Risk Based Inspection
- API RP 581: Risk Based Inspection Technology
- API 653: Tank Inspection, Repair Alteration, and Reconstruction
- ASME B31.3: Process Piping Code
- ASME VII: Boiler and Pressure Vessel Code
- Capabilities and Limitations of Nondestructive Evaluation Methods for Inspecting Components beneath Thermal Protection Systems  The Aerospace Corporation (free to download)
- DNV-RP-G101: Risk Based Inspection of Offshore Topsides Static Mechanical Equipment (free to download)
- DNV-RP-G103: Non-intrusive Inspection (free to download)
- Energy Institute: Corrosion Threat Handbook
- Guide to the Offshore Installations (Safety Case) Regulations 2005 (free to download)
- Guidebook for the Fabrication of Non-Destructive Testing (NDT) Test Specimens  International Atomic Energy Agency (2001) (free to download)
- Handbook of Non-destructive Evaluation  Charles J. Hellier
- International Association of Oil and Gas producers: Asset Integrity - The Key to Managing Major Incident Risks (free to download)
- NORSOK Standard N001  Integrity of Offshore Structures (free to download)
- Norwegian Oil and Gas Recommended Guidelines: The Assessment and Documentation of Service Life Extension of Facilities (free to download)
- Oil & Gas UK: Guidance on the Management of Ageing and Life Extension for UKCS Oil and Gas Installations (free to download)
- ISO 55000 (formerly PAS 55:2008): Asset Management
- Step Change to Safety: Asset Integrity Lifecycle Checklist (free to download)
- Step Change to Safety: Asset Integrity Toolkit (free to download)
- UK HSE: A guide to the Offshore Installations (Safety Case) Regulations 2005 (free to download)
- UK HSE: Guidance on Risk Assessment for Offshore Installations (free to download)
- UK HSE: Key Programme 3 (KP3) Asset Integrity Programme (free to download)
- UK HSE: Key Programme 4 (KP4) Ageing and Life Extension (free to download)
- UK HSE: Offshore External Corrosion Guide (free to download)
Area: Plant Integrity
SERIP Stage 3 - AIM Phase 1 (2011-2013)
Baseline procedures are applicable to the entire Asset Integrity Management System (AIMS). Specific procedures applicable to fixed equipment and critical structures. Focus on equipment that prevents Health, Safety, Environment, or Asset consequences of 1 or 2 from being realized.
- SERIP Stage 4 - AIM Phase 2 (2013-2015)
Specific procedures applicable to machinery, electrical equipment and power systems, instrumentation and control systems, safety systems including fire fighting and fire suppression, subsea systems/equipment, and floating systems . Focus on equipment that prevents Health, Safety, Environment, or Asset consequences of 1 or 2 from being realized.
- SERIP Stage 5 AIM Phase 3 (2015+)
Expanding the focus to all equipment, defining Technical Authorities, standardize methods, and establish mature Communities of Practice (COP). Escalation/Governance only applies equipment that
Area: Plant Integrity
Located some 240 kilometers west of Abu Dhabi City, the Ruwais Industrial Complex was developed as a major contributor to the national economy and represents a series of multi-million dollar investments.
The Ruwais story began in the 1970s, when plans were laid to transform a remote desert site into a self-contained industrial town, geared to fulfilling the down stream requirements of Abu Dhabi's booming oil and gas industry.
Centered around Ruwais Refinery, the complex was officially inaugurated in 1982 by the late Sheikh Zayed bin Sultan Al Nahyan âMay Almighty Allah rest his soul in eternal peaceâ , former President of the UAE and the visionary behind Abu Dhabi's remarkable development and prosperity.
Soon after commissioning the original 120,000 barrels per day (bpd) Hydro skimming refinery in June 1981, plans were drawn up to add a 27,000 bpd Hydro cracker complex that was started in 1985. To consolidate operations, the General Utilities Plant, set up in 1982 to provide electricity and water for the area, was merged with the Refinery in 1986.
In support of the company's HSE policy, a central Sulphur Handling and Granulation Plant was established in 1991 to handle all the liquid Sulphur recovered in the GASCO and ADGAS Natural Gas Liquefaction facilities. Its operations were also integrated with the Ruwais Refinery Division in 1992. After its expansion in early 2001, the granulation capacity, at 7,650 tons per day, has become one of the largest in the world.
Two 140,000 bpd condensate processing trains were commissioned in year 2000 - 2002 to process condensate produced in the on-shore gas fields of Abu Dhabi. Currently these are two of the largest such condensate splitters in the world. Meanwhile, support facilities such as berths, power generation and water production facilities continued to be expanded to meet the growing needs of the industrial area.
The original Hydro skimming complex was designed to process 120,000 bpd of crude oil, mainly for the export market. Growth in demand for Abu Dhabi's high quality refined products spurred the continuous expansions at Ruwais. Today the range of refined products includes Liquefied Petroleum Gas, Premium Unleaded Gasoline (98 Octane), Special Unleaded Gasoline (95 Octane), Naphtha grades, Jet-A1 and Kerosene grades, Gas Oil grades, Straight run Residue, Bunker grades 180 and 380 cst and Granulated Sulphur. 

For more details please go through the below links
-Processing Units.
- Refinery Utilities.
-Tank farm & offsites.
-Marine Terminal.
- Sulphur Handling Terminal & Granulation plant.
-General Utilities Plant.
Area: Plant Integrity
These are produced by the following primary and secondary processing units:
Crude oil Distillation (120,000 bpd): After desalting, crude oil is distilled to produce full-range naphtha, kerosene, light gas oil, heavy gas oil and straight run residue, which are further processed in downstream units.
Area: Plant Integrity
Naphtha Hydrodesulphurization (34,350 bpd): The full-range naphtha from the crude oil unit and heavy naphtha from the Hydro cracker unit is hydro treated to remove the Sulphur compounds and then LPG is stripped from whole naphtha. After dehydration, the raw LPG is sent to the GASCO-NGL plant for further processing while the whole naphtha is split into light naphtha, used for gasoline blending, and heavy naphtha, used as feedstock for the Catalytic Reformer Unit.
Area: Plant Integrity
Atalytic Reformer (19,150 bpd): The heavy naphtha is processed to improve its anti-knock properties by using a bimetallic platinum-based catalyst. The Reformate obtained is used as the main blend component for gasoline production. The hydrogen-rich gas is used in the reaction sections of the hydrotreaters and the remaining gas goes to Refinery Fuel Gas system.
Area: Plant Integrity
Kerosene Hydrotreater (20,780 bpd): The unit improves the burning quality of kerosene by desulphurization and saturation of aromatics required to meet international specifications for jet fuel.
Area: Plant Integrity
Gas Oil Hydrodesulphurization (21,850 bpsd): The unit removes Sulphur compounds in the heavy gas oil from the crude oil unit using a cobalt/molybdenum oxide-based catalyst. The hydrotreated heavy gas oil is used as a blending component to produce different grades of gas oil.
Area: Plant Integrity
Vacuum Unit (46,000 bpd): The Vacuum Unit processes atmospheric residue from the crude oil unit to produce heavy vacuum gas oil as feedstock for the Unibon unit. Ruwais residue is supplemented by residue from Abu Dhabi Refinery.
Area: Plant Integrity
Unibon Unit/Hydro cracker (27,000 bpd): The Unibon Unit converts the heavy vacuum gas oil feed into lighter products in the reactor section by passing the feed, plus hydrogen, over catalysts under high temperature and pressure. The products from this reaction are then separated in the fractionation section to yield high value finished products ranging from LPG to gas oil.
Area: Plant Integrity
Hydrogen Plant (60,000 Nm3/hr): The Hydrogen Unit converts natural gas and steam into hydrogen with the aid of catalysts. Propane can also be used as an alternative feed.
Area: Plant Integrity
Two Sulphur Recovery Plants (44/49 tons per day): These units recover sulphur from hydrogen sulphide-rich gas produced in the Hydrodesulphurization and Unibon units by converting it into elemental sulphur through a thermal and catalytic reaction. The liquid sulphur is then sent to the Sulphur Handling Terminal for granulation and export.
Area: Plant Integrity
Two Condensate Splitters (2x140,000 bpd): Each splitter is designed to process condensate from the On-shore Gas Development and Asab Gas Development fields. The splitters fractionate the condensate into unstabilized light naphtha, medium naphtha, heavy naphtha, kerosene, light gas oil (LGO), heavy gas oil (HGO), and atmospheric residue, which are further processed in downstream units.
Area: Plant Integrity
Two Naphtha Stabilizers (2x27,500 bpd): Each Stabilizer is designed to process 27,500 bpd of unstabilized light naphtha from the condensate splitters. LPG after treatment is sent to GASCO while stabilized light naphtha is routed to storage and blending.