What does a pipeline inspection checklist cover?

A pipeline inspection checklist covers right-of-way patrol observations (marker posts, encroachments, ground disturbance), above-ground section condition (corrosion, coating, pipe supports), valve station inspections (valve operation, actuators, leak checks), cathodic protection surveys (pipe-to-soil potentials, rectifier readings), pipeline marker and signage verification, instrumentation checks and third-party activity monitoring. The checklist is aligned with AS 2885 Part 3 (Operation and Maintenance) and API 1160.

What is AS 2885 and how does it relate to pipeline inspections?

AS 2885 is the Australian standard for pipelines transporting gas and liquid petroleum. Part 1 covers design and construction, Part 2 covers welding, and Part 3 covers operation and maintenance. Part 3 requires operators to maintain a pipeline integrity management system that includes scheduled inspections, condition monitoring, anomaly management and emergency response procedures. Inspection intervals and scope must be justified through a safety management study that identifies threats and determines appropriate risk controls. AS 2885 is referenced by all state and territory pipeline regulators in Australia.

What is API 1160 and why is it used alongside AS 2885?

API Recommended Practice 1160 provides a framework for managing the integrity of hazardous liquid pipelines, including threat identification, risk assessment, inspection planning and anomaly evaluation. While AS 2885 is the governing Australian standard, API 1160 is widely referenced by Australian pipeline operators as a complementary framework, particularly for integrity assessment methodologies, fitness-for-service evaluations and inline inspection (ILI) data interpretation. Using both standards together provides a comprehensive approach to pipeline integrity management.

What cathodic protection readings should I take during a pipeline inspection?

At each CP test point along the pipeline, measure the pipe-to-soil potential using a portable Cu/CuSO4 (copper/copper sulphate) reference electrode and a high-impedance voltmeter. An adequate protection level is typically more negative than minus 850 mV. Record the on-potential and, where possible, the instant-off potential (which removes IR drop error). For impressed current systems, also record the rectifier output voltage and current. For sacrificial anode systems, check anode consumption and bond wire continuity. Compare all readings against the previous survey to identify trends or areas of declining protection.

What should I do if I find third-party activity within the pipeline easement?

Third-party damage is a leading cause of pipeline incidents. If you observe any unauthorised excavation, construction, vehicle crossings or other activity within the pipeline easement, record the location (GPS coordinates and KP reference), the nature of the activity, photographs and contact details for the party involved if safely obtainable. Report the finding immediately to the pipeline operations centre and the land management team. If the activity poses an imminent risk to the pipeline, request that the work be stopped until a safe work plan is established, which may include locating and exposing the pipeline, establishing safe separation distances and providing standover supervision.

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Free pipeline inspection checklist aligned to API 1160 and AS 2885 (PDF-ready). Covers external condition, CP, coating, valves and ROW checks.

Jarrod Milford

Commercial Director

Updated 3 May 2026

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What is a pipeline inspection checklist?

A pipeline inspection checklist is a structured form used to assess the external condition, integrity and operational readiness of pipelines that transport hydrocarbons, water or other fluids. Pipelines are long-life infrastructure assets that face degradation from external corrosion, third-party damage, ground movement, coating breakdown and internal erosion or corrosion. This checklist is aligned with both API Recommended Practice 1160 (Managing System Integrity for Hazardous Liquid Pipelines) and AS 2885 (Pipelines - Gas and Liquid Petroleum), which is the primary Australian standard for pipeline design, construction and operation. It covers right-of-way (ROW) patrol observations, above-ground pipeline sections and fittings, valve station inspections, cathodic protection system checks, coating condition assessment, pipeline marker and signage verification, encroachment and third-party activity monitoring, and emergency equipment access. In Australia, pipelines are regulated under state and territory pipeline legislation, with AS 2885 forming the technical basis for safety management plans. Operators are required to maintain a pipeline integrity management system (PIMS) that includes scheduled inspections at defined intervals. Using a standardised checklist ensures every inspection follows the same scope, findings are recorded consistently for trending and regulatory reporting, and corrective actions are tracked to completion. This supports both the risk-based assessment requirements of AS 2885 Part 3 (Operation and Maintenance) and the hazard identification framework of API 1160.

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Benefits of using this pipeline inspection checklist

Integrity assurance: structured checks of coating, corrosion, cathodic protection and valve condition detect degradation before it leads to leaks or ruptures.
Dual-standard alignment: the checklist maps to both AS 2885 (the Australian pipeline standard) and API 1160, supporting compliance with local regulations and international best practice.
Right-of-way monitoring: documenting encroachments, third-party activities and ground disturbance near the pipeline easement helps prevent third-party damage, which is a leading cause of pipeline incidents.
Regulatory compliance: documented patrol and inspection records satisfy the requirements of state pipeline legislation and the AS 2885 safety management study process.
Trending and analytics: consistent data capture across inspections enables condition trending, supports risk-based inspection interval adjustments and feeds into the pipeline integrity management system.
Emergency preparedness: verifying valve access, emergency equipment and communication points during routine inspections ensures the pipeline can be isolated quickly in an emergency.

Benefits of digitising forms in MapTrack

When you digitise pipeline checklists in MapTrack, you get:

Field users can easily scan a QR code to complete a form on mobile. Unlimited users.
Automatically get alerts when faults are identified.
Link every form digitally as a PDF to the relevant asset, location or person.
Receive a digital PDF copy with every submission to your email.
Ability to share forms digitally.
Build conditional logic (show or hide questions based on answers).
Take pictures or attach photos. Not possible with a paper-based form.
Electronic signatures.
Edit forms later without reprinting.
Restrict permissions (who can view, complete or approve).
Build forms with AI (describe what you need and MapTrack suggests the form).
Trigger work orders automatically when a fault is logged during an inspection.
Track service intervals by hours, kilometres or calendar date in one place.
Attach supplier invoices and parts receipts to each maintenance record.

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What to include in a pipeline inspection checklist

This pipeline inspection checklist covers 9 key areas:

Pipeline identification: pipeline name or licence number, section or kilometre point (KP) range, product transported, diameter and wall thickness, MAOP (maximum allowable operating pressure), date, inspector name.
Right-of-way (ROW) patrol: easement markers visible and legible, no unauthorised encroachment or construction within the easement, no evidence of ground disturbance, erosion or washout over the pipeline, vegetation managed per the ROW management plan.
Above-ground sections: visual condition of risers, bends and exposed pipe, no external corrosion, mechanical damage or coating damage, pipe supports and saddles secure, no sagging or movement.
Coating condition: no disbondment, cracking, holidays or mechanical damage visible on above-ground or recently exposed sections, coating type and condition recorded.
Cathodic protection: CP test points accessible and cables intact, pipe-to-soil potential readings taken and recorded, rectifier output current and voltage within target range (impressed current systems), sacrificial anodes not fully consumed.
Valve stations: each valve operates fully open and fully closed, valve actuators functional, no external leaks at gland packing or flanges, valve pit clean and drained, valve identification tags legible.
Pipeline markers and signage: marker posts at correct intervals, pipeline warning signs at road crossings, railway crossings and waterway crossings legible and in place, emergency contact number displayed.
Instrumentation: pressure and temperature transmitters reading within expected range, flow metering functional, SCADA communication confirmed.
Third-party activity: any current or planned third-party works within the pipeline corridor documented, dial-before-you-dig (DBYD) compliance verified, standover supervision requirements confirmed.

How to use this pipeline inspection checklist

Review the pipeline integrity management plan, previous inspection records and any active anomaly reports before commencing the patrol.: Check the pipeline schematic, AS 2885 safety management study findings, known anomaly locations, previous inspection defects and any outstanding corrective actions. Confirm the inspection scope: ROW patrol, valve station inspection, CP survey or a combination. Ensure you have the required equipment (reference electrode, multimeter, camera, GPS).
Conduct the right-of-way patrol along the defined pipeline route, recording observations at each kilometre point.: Walk or drive the easement, checking for marker post condition, vegetation encroachment, ground disturbance, erosion, third-party activity and any new structures or excavations within the corridor. Photograph and GPS-tag any findings. Note whether the pipeline centreline is clearly identifiable from the surface markers.
Inspect above-ground sections, including risers, bends, exposed pipe and pipe supports.: Check for external corrosion, mechanical damage, coating disbondment or cracking, pipe support condition and any evidence of movement or sagging. Record the coating type and overall condition rating. If ultrasonic thickness testing is in scope, take readings at specified grid points and compare against the minimum wall thickness for the operating pressure.
Inspect valve stations: operate each valve, check actuators, flanges and valve pits.: Operate each mainline valve from fully open to fully closed and back, confirming smooth travel and correct position indicator alignment. Check for leaks at gland packing, flanges and bonnet bolts. Verify that valve pits are clean, drained and free of debris. Confirm valve identification tags are legible and match the pipeline schematic.
Perform cathodic protection checks, record instrument readings and complete the sign-off.: At each CP test point, measure and record the pipe-to-soil potential using a Cu/CuSO4 reference electrode. For impressed current systems, check rectifier output current and voltage against the target range. For sacrificial anode systems, confirm anode consumption is within acceptable limits. Complete all checklist items, record defect descriptions and corrective actions, sign and date the form, and submit to the pipeline integrity management system.

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How often should you complete this checklist?

Pipeline inspection frequency should be determined by a risk-based assessment as required by AS 2885 Part 3. As a general guide, right-of-way patrols should be conducted monthly for pipelines in high-consequence areas (near populated zones, waterways or environmentally sensitive areas) and quarterly for pipelines in remote or low-consequence areas. Valve station inspections should be performed at least quarterly, with full valve operation tests at least annually. Cathodic protection surveys (pipe-to-soil potential readings) should be taken at least annually at all test points, with more frequent monitoring at locations with known CP issues. Comprehensive in-line inspections (ILI / smart pigging) are typically performed every five to ten years depending on the pipeline threat profile. Any reported third-party activity, ground disturbance, natural disaster or pressure excursion should trigger an immediate ad-hoc inspection of the affected section.

Frequently asked questions

What does a pipeline inspection checklist cover?: A pipeline inspection checklist covers right-of-way patrol observations (marker posts, encroachments, ground disturbance), above-ground section condition (corrosion, coating, pipe supports), valve station inspections (valve operation, actuators, leak checks), cathodic protection surveys (pipe-to-soil potentials, rectifier readings), pipeline marker and signage verification, instrumentation checks and third-party activity monitoring. The checklist is aligned with AS 2885 Part 3 (Operation and Maintenance) and API 1160.
How often should pipelines be inspected in Australia?: AS 2885 Part 3 requires inspection intervals to be justified by a risk-based assessment. As a general guide, right-of-way patrols are monthly in high-consequence areas and quarterly in low-consequence areas. Valve station inspections are at least quarterly, with full valve operation tests annually. Cathodic protection surveys are at least annual. In-line inspections (smart pigging) are typically every five to ten years. Any third-party activity, ground disturbance or pressure excursion triggers an immediate ad-hoc inspection.
What is AS 2885 and how does it relate to pipeline inspections?: AS 2885 is the Australian standard for pipelines transporting gas and liquid petroleum. Part 1 covers design and construction, Part 2 covers welding, and Part 3 covers operation and maintenance. Part 3 requires operators to maintain a pipeline integrity management system that includes scheduled inspections, condition monitoring, anomaly management and emergency response procedures. Inspection intervals and scope must be justified through a safety management study that identifies threats and determines appropriate risk controls. AS 2885 is referenced by all state and territory pipeline regulators in Australia.
What is API 1160 and why is it used alongside AS 2885?: API Recommended Practice 1160 provides a framework for managing the integrity of hazardous liquid pipelines, including threat identification, risk assessment, inspection planning and anomaly evaluation. While AS 2885 is the governing Australian standard, API 1160 is widely referenced by Australian pipeline operators as a complementary framework, particularly for integrity assessment methodologies, fitness-for-service evaluations and inline inspection (ILI) data interpretation. Using both standards together provides a comprehensive approach to pipeline integrity management.
What cathodic protection readings should I take during a pipeline inspection?: At each CP test point along the pipeline, measure the pipe-to-soil potential using a portable Cu/CuSO4 (copper/copper sulphate) reference electrode and a high-impedance voltmeter. An adequate protection level is typically more negative than minus 850 mV. Record the on-potential and, where possible, the instant-off potential (which removes IR drop error). For impressed current systems, also record the rectifier output voltage and current. For sacrificial anode systems, check anode consumption and bond wire continuity. Compare all readings against the previous survey to identify trends or areas of declining protection.
What should I do if I find third-party activity within the pipeline easement?: Third-party damage is a leading cause of pipeline incidents. If you observe any unauthorised excavation, construction, vehicle crossings or other activity within the pipeline easement, record the location (GPS coordinates and KP reference), the nature of the activity, photographs and contact details for the party involved if safely obtainable. Report the finding immediately to the pipeline operations centre and the land management team. If the activity poses an imminent risk to the pipeline, request that the work be stopped until a safe work plan is established, which may include locating and exposing the pipeline, establishing safe separation distances and providing standover supervision.

Applicable regulatory standards

This template aligns with the following regulations and standards:

AS 2885.3:2012 - Pipelines: Gas and Liquid Petroleum, Part 3: Operation and Maintenance
AS 2885.1:2018 - Pipelines: Gas and Liquid Petroleum, Part 1: Design and Construction
API Recommended Practice 1160 - Managing System Integrity for Hazardous Liquid Pipelines
Relevant state Pipeline Acts and Regulations (e.g. Pipelines Act 2005, VIC; Petroleum and Gas (Production and Safety) Act 2004, QLD)

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