API 653 Tank Inspection Support in British Columbia

Short answer: In British Columbia, API 653 is the standard owners use to inspect in-service atmospheric steel storage tanks, and the inspection is evaluated and signed by the owner's API 653 Authorized Inspector. No single BC body regulates all tanks: the BC Fire Code, BC Energy Regulator rules for oil and gas facilities, Environmental Management Act spill rules and, on federal land and at federally regulated pipeline terminals, federal rules each apply. Atlantis performs the NDE behind the inspection and reports to your inspector.

British Columbia's tank population is shaped by geography. Burrard Inlet holds the province's last coastal refinery, the end of the Trans Mountain pipeline and its marine terminal, and a ring of fuel, chemical and bulk-liquid terminals inside one of Canada's busiest ports. The interior adds a refinery at Prince George, pipeline terminals at Kamloops and Sumas, pulp mills and mines. The north-east holds the Montney gas fields and their condensate storage, and the north coast now hosts LNG and propane export. Rain, seismic risk, wildfire and atmospheric-river floods all bear on how BC tanks are inspected and when. This page covers where the tanks are, what API 653 asks, which BC and federal rules apply, how examiner certification is handled and what Atlantis does. Atlantis performs the NDE; your API 653 Authorized Inspector remains inspector of record and signs the inspection report. To start, send us your BC tank list.

Where API 653 tanks are in British Columbia

Direct answer: BC's field-erected steel tanks are concentrated around Burrard Inlet and the Fraser River in Metro Vancouver, at the Prince George refinery, at pipeline terminals at Kamloops and Sumas, at north-east BC gas plants and batteries around Fort St. John and Fort Nelson, at pulp and paper mills and mines across the interior, and at north-coast industrial sites near Kitimat and Prince Rupert.

Burnaby, Burrard Inlet and the Port of Vancouver

The Burnaby refinery on Burrard Inlet, owned by Sunoco since it completed its acquisition of Parkland in October 2025, supplies a large share of the Lower Mainland's gasoline and of Vancouver International Airport's jet fuel. Next door in Burnaby, the Trans Mountain pipeline's Burnaby Terminal stores crude in a large tank farm on Burnaby Mountain and feeds the Westridge Marine Terminal, where tankers load. Elsewhere on the inlet and the Fraser River sit petroleum product terminals, chemical and bulk-liquid terminals at North Vancouver and Port Moody, and the airport's fuel system, which now receives jet fuel through a marine terminal and tank farm on the Fraser River in Richmond. Many tanks here are old, close to the water and close to neighbours.

The interior: Prince George, Kamloops and the Fraser Valley

Prince George has the interior's only refinery, processing crude from north-east BC and Alberta. Trans Mountain operates a terminal at Kamloops and a terminal at Sumas near Abbotsford, where a connecting pipeline carries crude south to refineries in Washington State. Interior pulp and paper mills store chemicals such as caustic and process liquors in large field-erected tanks, and copper and metal mines in the Thompson-Nicola region and the north store diesel, reagents and process water.

North-east BC: Montney and Horn River

Around Fort St. John, Dawson Creek and Fort Nelson, gas plants, compressor stations and oil batteries store condensate, natural gas liquids, produced water and methanol. Many of these tanks are built to API 12-series specifications or shop-fabricated rather than to API 650, and they sit under the BC Energy Regulator. Whether API 653 is the right yardstick depends on how each tank was built and what the regulator and owner's program require.

North coast, Vancouver Island and remote storage

LNG Canada at Kitimat, which began exporting in 2025, stores liquefied natural gas in full-containment refrigerated tanks built to different standards from API 650, so they are outside API 653's scope, but the site's ordinary atmospheric tanks for diesel, water and chemicals are not. Propane and butane export at Prince Rupert relies on pressurised or refrigerated storage, which also sits outside API 653. Vancouver Island fuel terminals, an aluminium smelter at Kitimat, coastal fuel depots and island and remote-community diesel storage complete the map.

What API 653 requires, in plain terms

Direct answer: API 653 covers inspection, repair, alteration and reconstruction of in-service atmospheric steel tanks built to API 650 or API 12C. Owners check tanks routinely, an Authorized Inspector performs a formal external inspection at least every five years, shell UT follows a corrosion-based interval, and internal inspections are timed by measured floor corrosion and the tank's safeguards.

Routine in-service checks. At least monthly, owner personnel look for leaks, shell distortion, settlement, roof and seal problems, coating breakdown and foundation damage. On the wet coast, roof drains, ponding on cone and floating roofs, and water ingress at the chime get particular attention.

External inspection. The Authorized Inspector carries out a formal external inspection at least every five years, or sooner when shell corrosion is rapid, because API 653 also caps the interval at a quarter of the remaining shell corrosion life.

Shell UT thickness. Where UT readings are used, they are due within five years of commissioning while the corrosion rate is unknown, then at the lesser of half the remaining shell corrosion life or fifteen years.

Internal inspection. A new tank's first internal inspection is generally due within ten years, and owners may extend it within API 653's ceilings by crediting safeguards such as release prevention barriers, linings and cathodic protection. Later intervals are calculated from measured floor corrosion and the minimum remaining bottom thickness, or set by a qualifying risk-based assessment carried out by the owner's specialists.

Settlement, seismic and edition. Many BC tanks sit on fill, river deltas and soft marine soils, so the settlement annex is central to the inspector's evaluation. When a tank is altered or reconstructed, API 653 points back to API 650 design rules, which include seismic design, so changes in Metro Vancouver and on Vancouver Island bring anchorage and seismic questions to the engineer of record. API 653 is in its fifth edition with addenda; Addendum 4 (July 2025) revised the text on bottom thickness measurement, so check procedures against the current edition from api.org. See API 653 tank inspection intervals explained and the API 653 tank inspection guide.

British Columbia regulations that sit on top of API 653

Direct answer: BC splits tank oversight. The BC Fire Code, enforced through the Office of the Fire Commissioner and local fire services, covers flammable and combustible liquid storage; the BC Energy Regulator oversees oil and gas facilities and provincial pipelines; the Ministry of Environment and Climate Change Strategy runs spill rules under the Environmental Management Act; and federal rules apply on federal land and at CER-regulated terminals. Technical Safety BC regulates pressure equipment, not atmospheric tanks.

BC Fire Code

The BC Fire Code 2024, based on the National Fire Code of Canada 2020, took effect on 8 March 2024, and the Fire Safety Act came into force on 1 August 2024. Part 4 regulates flammable and combustible liquids, including tank storage, containment, venting, leak detection and fire protection, and the code is enforced by the Office of the Fire Commissioner and local assistants to the fire commissioner. The code's tank-storage section allows a used tank to be refurbished for aboveground service in conformance with good engineering practice such as API 653, which is one place the provincial code names the standard (we verified this wording in the 2018 edition; confirm it in the current edition). For in-service tanks, the inspection program itself is the owner's, and API 653 is the practice most owners adopt.

BC Energy Regulator

The BC Energy Regulator, formerly the Oil and Gas Commission, regulates oil and gas facilities, gas plants and provincially regulated pipelines under the Energy Resource Activities Act (renamed from the Oil and Gas Activities Act by the Energy Statutes Amendment Act, 2022). Storage at north-east BC gas plants, batteries and compressor stations falls under its regulations and permit conditions. Confirm the storage and integrity requirements for your permitted facility with the BCER.

Environmental Management Act and spill rules

The Ministry of Environment and Climate Change Strategy administers the Environmental Management Act. Its spill regulations, in force since October 2017, require spills of reportable quantities to be reported and set preparedness, response and recovery duties for regulated persons, a group that includes owners of pipelines transporting liquid petroleum products and rail and highway transporters carrying ten thousand litres or more. Refineries and major terminals also hold waste discharge authorisations, and the Contaminated Sites Regulation drives investigations when a tank floor leaks. Tank integrity is the first line of defence for all of these obligations.

Federal rules: tank regulations, ports, airports and First Nations land

The federal Storage Tank Systems for Petroleum Products and Allied Petroleum Products Regulations (SOR/2008-197) apply to systems on federal land and Indigenous land, systems operated by federal bodies and systems serving federal works and undertakings such as airports and railways. In BC that can include First Nations reserve lands, airport fuel systems and some port facilities; confirm applicability with Environment and Climate Change Canada. For older vertical aboveground tanks without secondary containment, the regulations require continuous leak detection or monitoring, or a tank or floor inspection every ten years, and tank inspections must follow the version of API 653 in effect at the time.

Pipelines and terminal tanks

Trans Mountain's terminals at Burnaby, Westridge, Kamloops and Sumas belong to an interprovincial pipeline regulated by the Canada Energy Regulator, so their tanks sit within the operator's CER-regulated management system, with CSA Z662 as the pipeline standard. Pipelines wholly within BC are regulated by the BCER. Confirm with the relevant regulator how tank inspections are documented; our CSA Z662 overview gives context.

Technical Safety BC and radiography

Technical Safety BC regulates boilers, pressure vessels and other pressure equipment. LPG bullets, propane and butane spheres and other pressurised storage are pressure equipment inspected under API 510 and Technical Safety BC's program, not under API 653; see our Technical Safety BC overview. Industrial radiography is licensed federally by the Canadian Nuclear Safety Commission and exposure devices are operated by CNSC-certified operators; Atlantis uses only crews holding the required licence and certifications. Confined-space entry for internal inspections follows WorkSafeBC's Occupational Health and Safety Regulation and site permits.

NDE examiner qualifications in British Columbia

Direct answer: For atmospheric tanks, the owner's specification decides which NDE certification scheme is accepted. Many BC owners accept ASNT SNT-TC-1A, some require CAN/CGSB-48.9712 (ISO 9712), and many write either. Atlantis technicians are certified to an ASNT SNT-TC-1A written practice under ASNT Level III oversight, and we confirm acceptance during scoping.

CAN/CGSB-48.9712 is Canada's national scheme for NDT personnel, aligned with ISO 9712 and administered by Natural Resources Canada's NDT Certification Body. The Canadian General Standards Board, which published the standard, closed on 1 April 2026; NRCan's certification body continues and CAN/CGSB-48.9712 remains valid, according to NRCan and CWB Group notices. Confirm the current certification body when you update a specification. See CAN/CGSB-48.9712 and the NRCan NDT Certification Body.

The honest position: Atlantis is an ASNT-based NDE contractor. Our technicians are certified to an SNT-TC-1A written practice, an ASNT NDT Level III reviews our procedures, and each proposal names the certification basis method by method. Owners with US parent companies, US-code engineering or API-based corporate programs commonly accept SNT-TC-1A; owners whose specification requires CGSB only will hear that from us at scoping, not after a crew arrives. Atlantis does not provide CGSB or ISO 9712 training or certification. Our training is ASNT SNT-TC-1A only, through NDT training in British Columbia and across Canada.

NDE methods for API 653 work in British Columbia

Direct answer: BC tank work relies on floor MFL scanning proved up with UT, shell and annular-plate UT thickness, corrosion mapping where coatings or insulation are removed, visual examination of roofs, seals, drains and foundations, MT, PT and vacuum-box testing after repairs, PAUT or radiography of new welds, and settlement data for the inspector.

Every reportable MFL indication is proved up with UT, and every procedure is reviewed by an ASNT NDT Level III. Coastal humidity and condensation affect couplant, surface preparation and coating-related readings, so our procedures address them explicitly. For floor-method trade-offs see MFL versus UT for tank floors, and for the full scope see aboveground storage tank inspection.

How Atlantis supports your Authorized Inspector

Direct answer: Atlantis takes the scope from your API 653 inspector's plan, performs the NDE, checks the data on site and delivers a digital report your inspector can review, accept and sign. We are not an Authorized Inspection Agency and we do not supply API-certified inspectors. We do the examinations and stand behind the data.

1. Scope from the inspector's plan: floor coverage, shell and annular-plate locations, roof, seal, drain, anchorage and foundation examinations, weld examinations and settlement points.
2. Certification check: we confirm which examiner certifications your specification requires before booking a crew.
3. Procedure review by an ASNT NDT Level III, including wet-weather surface preparation and couplant selection.
4. Examinations by technicians certified to an SNT-TC-1A written practice: MFL with UT prove-up, shell and annular UT, corrosion mapping, visual, surface and volumetric methods.
5. Data QA on site: readings checked against calibration records and the previous inspection, with anomalies flagged to the inspector immediately.
6. Digital report in our reporting platform: floor maps, prove-up readings, shell readings by course and location, weld records, photographs, calibration data and technician certification records, on report templates matched to your inspector's file.
7. Inspector evaluation and sign-off, then reuse of the same locations at the next interval, tracked in our inspection-management ERP or visualised on a digital twin of the tank farm.

We can calculate corrosion rates and remaining life from our thickness data for the inspector's review; the interval decision remains with the inspector and the owner under API 653 and the rules that apply. Atlantis performs the NDE; your API 653 Authorized Inspector remains inspector of record and signs the inspection report. Request an NDE scope for your inspector's plan, or read about API 653 tank inspection support.

Planning around rain, fire season, floods and turnarounds

Direct answer: On the coast, the drier months from late spring to early autumn are preferred for internal inspections, coating work and repairs. In the interior and north-east, wildfire season and winter cold set the window. Plan cleaning, NDE and repairs as one mobilisation around turnarounds and terminal rotation, with contingency for road closures.

Coastal rain. Metro Vancouver and Vancouver Island winters are mild but wet. Rain and condensation complicate floor drying after cleaning, surface preparation for UT, coating repairs and vacuum-box testing, so internal work is usually scheduled for drier months, or under temporary covers where it cannot wait.

Wildfire season. Interior and north-east sites can face smoke, evacuation orders and highway closures from late spring through summer. Plans for Kamloops, Prince George and the Montney need flexible dates and an agreed decision point.

Atmospheric rivers and floods. The November 2021 floods cut highways between the coast and the interior and forced the Trans Mountain pipeline to shut down for weeks. Autumn storms can still close the Coquihalla and Fraser Canyon routes, so mobilisation to interior sites carries road-closure contingency, and flooded tank sites need visual, settlement and foundation checks before the inspector can clear them.

North-east winters. Around Fort St. John and Fort Nelson, deep cold limits external UT and makes heated hoarding necessary; winter access is sometimes easier than spring breakup on lease roads.

Turnarounds and rotation. The Burnaby and Prince George refineries plan turnarounds well ahead, and terminals rotate tanks around tanker schedules and pipeline nominations. NDE should start as cleaning finishes so the inspector's evaluation is complete before repair crews mobilise. Book a scoping call for your next season.

API 653 inspection support across British Columbia

Direct answer: Atlantis mobilises crews to tank sites throughout BC on a schedule agreed during scoping, covering Burnaby, Vancouver, Richmond, North Vancouver and Port Moody, the Fraser Valley, Kamloops and the interior, Prince George, north-east BC from Fort St. John to Fort Nelson, Vancouver Island and the north coast at Kitimat and Prince Rupert.

• Burnaby, Vancouver and Burrard Inlet: refinery, pipeline terminal, port and chemical tanks. Related pages: ultrasonic testing in Vancouver, radiographic testing in Vancouver, NDT consulting in Vancouver, NDT training in Vancouver and digital twins in Vancouver.
• Richmond and the Fraser River: airport fuel storage and marine fuel terminals.
• Fraser Valley and Kamloops: pipeline terminal tanks, scheduled around pipeline operations.
• Prince George and the north interior: refinery tanks, pulp-mill chemical tanks and mine storage; for technician development see practical NDT in Prince George.
• Fort St. John, Dawson Creek and Fort Nelson: condensate, NGL and produced-water tanks at BCER-regulated facilities.
• Kitimat, Prince Rupert and Vancouver Island: atmospheric utility and fuel tanks at export and industrial sites, island fuel terminals and remote diesel storage.

Pressure vessels and process piping at the same sites follow their own codes and, for pressure equipment, Technical Safety BC's program; see our companion hubs for API 510 pressure vessel inspection in British Columbia and API 570 piping inspection in British Columbia. For Level III procedure and written-practice support see NDT consulting in British Columbia and NDT consulting across Canada; for inspection data and certification tracking see NDT ERP in British Columbia.

What to send us for a quote

Direct answer: Send your tank list and drawings, the last API 653 reports, your inspector's plan and examiner-certification requirements, cleaning and access status, and your preferred window. We return a scoped NDE quote within 24 hours.

1. Tank list and drawings: tank IDs, diameter, height, roof type, product, year built, construction standard, plate thicknesses, anchorage, foundation type and soil conditions, floor design, cathodic protection and leak detection.
2. Regulatory context: whether the site falls under the BC Fire Code, BCER permits, federal tank rules or a CER-regulated pipeline system, and any due dates.
3. Previous reports: external and internal API 653 reports, floor maps, shell readings, settlement surveys and any post-earthquake or post-flood checks.
4. The inspector's plan: examinations, coverage, acceptance references, report format and required examiner certifications, with your Authorized Inspector's name or agency.
5. Access and logistics: in service or cleaned and gas-free, weather protection, permits, site orientation, ferry or camp logistics for island and remote sites.
6. Dates: turnaround or rotation windows, and fire-season or road constraints for interior and northern sites.

Get a quote within 24 hours.

Frequently asked questions: API 653 tank inspection in British Columbia

Who can perform an API 653 inspection in British Columbia?

An API 653 Authorized Inspector engaged by the owner, directly or through an inspection agency, is responsible for the inspection and signs the report. Qualified NDE technicians collect the data. Atlantis performs that NDE with ASNT-certified technicians under Level III oversight and delivers the results to your inspector.

Does BC law require API 653 inspections?

No single BC law mandates API 653 for every tank. The BC Fire Code covers flammable and combustible liquid storage and names API 653 as good practice for refurbishing used tanks, the BCER regulates oil and gas facility storage, and federal rules can require API 653-based inspections on federal land. Most owners adopt API 653 in their integrity programs. Confirm with the authority for your site.

Does Technical Safety BC regulate storage tanks?

Technical Safety BC regulates pressure equipment such as boilers, pressure vessels and pressurised storage. Atmospheric storage tanks are not pressure equipment; their oversight comes from the fire code, the BCER, environmental rules and federal rules.

Are the LNG tanks at Kitimat inspected to API 653?

No. Refrigerated LNG tanks are built to different standards and fall outside API 653, as do pressurised propane and butane storage. Ordinary atmospheric fuel, water and chemical tanks at those sites can fall within it.

Is Atlantis an Authorized Inspector?

No. We are not an Authorized Inspection Agency and we do not supply API-certified inspectors. We perform and document the NDE; your inspector reviews it, accepts it and signs.

Are your technicians CGSB certified?

No. Atlantis technicians are certified to an ASNT SNT-TC-1A written practice under ASNT Level III oversight. For atmospheric tanks the owner's specification decides which scheme is acceptable, and we confirm it during scoping. CAN/CGSB-48.9712 remains valid after the Canadian General Standards Board's closure on 1 April 2026; confirm the current certification body.

Do federal tank rules apply in British Columbia?

They can, on federal land, First Nations reserve land and at systems serving federal works such as airports and railways. Older vertical tanks without secondary containment then need continuous leak monitoring or a tank or floor inspection every ten years, with tank inspections following API 653.

How often does a storage tank need an API 653 inspection?

Monthly owner checks, an external inspection at least every five years, shell UT on a corrosion-based interval, and an internal inspection first due within ten years, then on a calculated interval within the code's ceilings. Your inspector sets the dates.

Should tanks be checked after an earthquake or flood?

Owners commonly ask their inspector to evaluate tanks after significant seismic or flood events. Atlantis can supply visual, settlement, shell and weld examination data for that evaluation; the inspector and the owner's engineers decide whether the tank stays in service.

Who licenses radiography on BC tank repairs?

The Canadian Nuclear Safety Commission licenses industrial radiography federally, and exposure devices are operated by CNSC-certified operators. PAUT is often chosen on port and urban sites where exclusion zones are hard to manage.

Do you perform RBI or fitness-for-service assessments, or teach API 653?

No to both. RBI and fitness-for-service assessments are performed by the owner's engineers or specialists using our data. Atlantis offers ASNT SNT-TC-1A training only; for the API certification route see our API inspector career guide.

How soon can a crew reach Burnaby, Prince George or Fort St. John?

Crews are mobilised to your site on a schedule agreed during scoping, built around cleaning, turnaround, weather and access constraints. Send tank details and we return a quote within 24 hours.

Plan your British Columbia tank inspections

From a floor scan on a Burrard Inlet crude tank to a shell survey at a Montney gas plant, begin with your inspector's plan, your examiner-certification requirements and a weather-realistic window. Send us your tank list, see what an API 653 program involves, or explore practical NDT in British Columbia for technician development.

More Atlantis NDT services in British Columbia

• NDT training and certification in British Columbia
• Level III consulting in British Columbia
• API 510 pressure vessel inspection support in British Columbia
• API 570 piping inspection support in British Columbia
• NDT ERP software in British Columbia
• Practical NDT simulator in British Columbia

Part of the wider aboveground storage tank inspection service at Atlantis NDT.