Using API 510, 570 and 653 in Canada: Provincial Regulators and Adoption

Short answer: API 510, 570 and 653 are not national law in Canada. Pressure equipment is regulated province by province under CSA B51, and each regulator treats the API codes differently. British Columbia adopts API 510 and API 570 by name. Alberta applies them through ABSA's AB-506. Saskatchewan and Manitoba work through approved owner programmes. Ontario and Quebec do not list them. API 653 tanks fall under fire, environmental and energy rules, not pressure equipment law.

That split matters to anyone running a Canadian refinery, gas plant, upgrader, chemical site or terminal, and to US operators with sites on both sides of the border. The API codes are the same document everywhere. What changes is whether the regulator has adopted them, who signs the legally required inspection, how often that inspection is due, and which NDE certification the regulator expects. This guide sets out each of those for the main provinces, using the regulators' own documents. API codes are copyrighted, so we describe requirements in our own words and point you to the official sources. Current editions are API 510, 11th edition (October 2022), API 570, 5th edition (February 2024), and API 653, 5th edition with addenda (Addendum 4 was issued in July 2025). Always confirm which edition your regulator names.

Three ways the API codes enter Canadian practice

Direct answer: There are three routes. Some provinces adopt the codes directly in regulation. Others reference them in regulator policy documents that carry the force of the regulator's authority. Elsewhere, owners apply them voluntarily as engineering practice on top of the provincial periodic inspection. Every province has adopted CSA B51 itself, so registration, repairs and the jurisdictional inspection cycle follow provincial law in all three cases.

• Direct adoption. The regulation lists API 510 and API 570, with editions, as adopted codes. British Columbia does this. Owners are expected to comply with the named edition.
• Adoption through policy. The regulator issues its own requirements document, which references the API codes as recognised good practice. Alberta's AB-506 says expressly that the API and National Board publications it references are not adopted directly under Alberta regulation. They apply because AB-506 and other ABSA policy documents reference them. AB-512H, a harmonised integrity management document issued jointly by Alberta, Saskatchewan and Manitoba, also expects authorised organisations to have API 510 and API 570 available.
• Owner practice. The provincial rules set periodic inspection by a provincial, insurer or recognised inspector at fixed maximum intervals. They do not list API 510 or 570, but refiners and chemical plants run API programmes anyway, usually because corporate mechanical-integrity standards and process safety rules call for recognised and generally accepted practice. Ontario and Quebec work this way.

Storage tanks under API 653 sit outside all three routes. Atmospheric tanks are not pressure vessels, so boiler and pressure vessel regulators generally do not cover them. Fire codes, environmental rules and energy regulators do. Some of those instruments mention API 653 directly, as shown below.

Province-by-province summary

Direct answer: The table shows how API 510 and API 570 apply, who performs the legally required inspection, and where API 653 tanks are regulated, for the provinces with the most refining and process plant. Regulations change, so treat it as a starting point and confirm with the regulator before acting on it.

In every province, NDE technicians are not on the list of who performs the jurisdictional inspection. They produce the data the inspector relies on. That includes Atlantis.

British Columbia: direct adoption

Direct answer: Technical Safety BC adopted CSA B51 2024 Edition, the 2023 NBIC, API 510 Eleventh Edition and API 570 Edition 5 effective 31 December 2024. BC is therefore one of the few Canadian jurisdictions where API 510 and API 570 are named in pressure equipment law. The ASME codes referenced in B51:24 also apply because of that reference.

Technical Safety BC's information bulletin also explains that the ASME codes were taken out of the direct schedule to simplify administration. They still apply because B51:24 references them. BC deferred enforcement of some B51:24 impact-testing clauses when it adopted the edition. For owners of refinery, LNG, gas-processing and pulp-mill vessels, two things follow:

• Edition control matters. The regulation names the edition. If API publishes a new edition or addendum before BC updates its schedule, check with Technical Safety BC which edition governs a particular decision.
• API 570 piping programmes are part of the regulated scope. Process piping circuits, CMLs and inspection intervals under API 570 are no longer only an internal company standard. See piping circuit and CML inspection.

Repairs and alterations still go through BC's own controls, including registration of alterations with supporting calculations and NDE, in addition to API 510's repair rules. API 653 is not in BC's boiler and pressure vessel adoption.

Alberta: AB-506 and the owner's integrity management system

Direct answer: ABSA's AB-506 (Edition 4, Revision 0, issued 21 October 2025) requires owners to maintain an effective integrity-assessment programme. It points to API 510 and RP 572 for vessels, API 570 and RP 574 for piping, and NBIC Part 2, especially for boilers. Inspection is evaluated and approved by an In-Service Pressure Equipment Inspector (ISI) certified under AB-526. Intervals follow ABSA's grading system unless an approved alternative applies.

Several points in AB-506 matter directly for API 510 and API 570 work:

• The ISI approves the work. Inspection and examination records must be evaluated and approved by the ISI, whose certificate of competency is covered by AB-526. People who only perform NDE do not need ISI certification.
• Piping gets particular attention. AB-506 notes that most recorded catastrophic failures on process plants started in piping systems, and it asks owners to pay particular attention to piping in their in-service programmes.
• Grading and maximum intervals. AB-506 assigns equipment inspection grades with maximum intervals in its appendix tables, and it sets rules for deferring or revising due dates. Owner-users with adequate engineering, corrosion and inspection resources and documented risk analysis can justify longer intervals within the limits AB-506 allows.
• Upstream vessels. An appendix lets owners of upstream oil and gas vessels use API 510's alternative rules for exploration and production vessels to group vessels into higher-risk and lower-risk classes, subject to ABSA's conditions.
• NDE examiners. AB-506 requires the examiner's employer to keep certification records and make them available to the owner, the inspector and ABSA. Ultrasonic shear-wave examiners need Level 2 certification to CAN/CGSB-48.9712. SNT-TC-1A Level 2, to the edition referenced by the current ASME Section VIII Division 1, is permitted if the owner accepts it. Contractor examiners doing UT thickness, MT or PT need Level 1 or 2 under either scheme.

For Alberta in more detail, see ABSA requirements.

Saskatchewan and Manitoba: approved programmes and harmonised rules

Direct answer: In Saskatchewan, a pressure vessel is inspected either at intervals the chief inspector sets, up to a maximum in the regulations, or at the frequency in an owner's approved quality management system (QMS) of inspection, by a licensed pressure equipment inspector. Manitoba adopted B51:24 from 1 January 2025. Both provinces, with Alberta, endorsed AB-512H, the harmonised integrity management document.

Saskatchewan's Boiler and Pressure Vessel Regulations, 2017 add three points that matter to API users:

• Internal inspection preference. Where construction and service conditions allow, a periodic inspection of a pressure vessel must be an internal inspection. That makes any API 510 on-stream substitution something to agree explicitly with the inspector and, where needed, TSASK.
• NDE as a component of the inspection. The regulations allow a component that needs specialist expertise, such as radiographic or ultrasonic examination, to be performed by a suitably qualified person, provided the results are covered by the inspection report of the licensed pressure equipment inspector responsible. This describes the role of an NDE contractor precisely.
• API certification as a licensing route. One of the qualifications accepted for a pressure equipment inspector's licence is a certificate issued under API's API 510 Pressure Vessel Inspector Certification Program. The regulation names a specific edition of the programme, so check the current wording.

TSASK's QMS of inspections lets owners and insurers hold certificates of authorization (Class A and B for owners, Class C for insurers) and inspect at intervals set through risk management principles in their approved system. AB-512H (Edition 1, October 2025), endorsed by ABSA, TSASK and Manitoba's ITS, sets common elements for a pressure equipment integrity management system and requires organisations authorised for integrity assessment to have access to the NBIC, API 510, API 570 and the relevant ASME sections. Manitoba's adoption of B51:24 excludes certain design and impact-testing clauses, and it does not automatically adopt informative annexes.

Ontario and Quebec: provincial inspection first, API as practice

Direct answer: In Ontario, TSSA's Code Adoption Document requires a periodic inspection at a maximum of three years for a general pressure vessel, done by an Ontario Certificate of Competency holder working for TSSA or the insurer. API 510 is not among its adopted references. In Quebec, periodic inspection is done by persons recognised by the RBQ, and API 510 is not among the RBQ's listed codes. In both provinces, API codes are applied as owner practice.

Ontario. Operating a regulated boiler or pressure vessel without a current TSSA Certificate of Inspection is an offence. The current CAD amendment (BPV-25-01 Revision 1, effective 15 June 2026) adopts CSA B51-24 with amendments. It sets maximum intervals by equipment type and states that engineering assessments do not override TSSA's minimum periodic cycle. Ontario owners running API 510 therefore plan to two calendars and work to whichever date comes first. For the full cycle, see TSSA periodic inspection in Ontario.

Quebec. The Regulation respecting pressure installations (chapter B-1.1, r. 6.1) has applied since 8 March 2018. It sets obligations for manufacturers, installers, repairers, owner-operators and the persons the RBQ recognises to inspect pressure installations. The RBQ's code list for pressure installations includes CSA B51, the ASME codes and ANSI/NB-23. A draft amendment published for consultation in November 2025 proposes, among other changes, replacing the BNQ 3650-900 installation code with NBIC Part 1 once a French version is available. Check the regulation in force before scoping work. Documentation in Quebec is usually expected in French.

API 653 and storage tanks in Canada

Direct answer: Atmospheric storage tanks are not pressure equipment, so API 653 is applied through fire codes, environmental and energy regulation and owner practice, not through B51. Some instruments name it directly. Ontario's Liquid Fuels Handling Code adoption document calls for API 653 external inspection of certain vertical fuel tanks, and Alberta's Directive 055 refers to API 653 for upstream tank inspections.

• Ontario. The TSSA Liquid Fuels Handling Code adoption amendment we reviewed (FS-235-18, dated July 2018) requires aboveground vertical tanks built to API 650 or CAN/ULC-S601 to have an in-service external inspection to API 653 at intervals not exceeding five years. Tanks without double bottoms need periodic internal inspection on a schedule set in the same document or by API 653 criteria. Confirm against the current Fuels Safety adoption document.
• Alberta. The AER's Directive 055 (June 2026 edition) covers storage in the upstream petroleum industry. Its leak-detection guidance says external and internal tank inspections should be performed in conformance with API Standard 653.
• Elsewhere. Provincial fire codes based on the National Fire Code of Canada, environmental approvals, and federal storage tank rules on federal land and at federally regulated facilities each apply where relevant. Most large terminal and refinery owners apply API 653 as company practice whatever the instrument.

The NDE behind API 653 work in Canada is the same as in the US: shell and floor UT, tank-floor MFL scanning, weld examination and settlement surveys. Winter scheduling and access are usually the bigger practical difference. See aboveground storage tank inspection.

Who signs: API-certified inspectors and provincial inspectors

Direct answer: On many Canadian sites, two kinds of inspector sign different documents. The owner's API-certified inspector signs the API 510, 570 or 653 inspection and sets intervals under the code. The provincially certified inspector, whether an ISI, a Certificate of Competency holder, an RBQ-recognised person or a licensed inspector, signs the legally required inspection. Sometimes one person holds both qualifications.

API certifications (API 510, 570 and 653 under API's Individual Certification Programs) are earned by examination. API delivers the exams through Prometric. Provincial certification is separate, and each province sets its own route. Ontario's Certificate of Competency, for example, requires a TSSA examination and the National Board In-service Commission examination. Saskatchewan accepts an API 510 certificate as one route to a pressure equipment inspector's licence. Alberta certifies ISIs under AB-526. So an API certificate on its own does not authorise anyone to sign a provincial inspection, and a provincial certificate does not replace the owner's API programme where the owner's standards require one.

For the API certification side, see the API inspector career guide. Atlantis does not offer API certification training. Our training is in NDT methods to ASNT SNT-TC-1A, including ASNT Level III preparation, which complements an inspector's code knowledge.

NDE for API programmes in Canada: certification, radiography and winter

Direct answer: Canadian NDE uses the same methods as US work, with three differences. Several regulators and owners expect CAN/CGSB-48.9712 certification, now administered by NRCan. Radiography is licensed federally by the Canadian Nuclear Safety Commission. Cold weather changes how and when external work can be done.

• Certification scheme. CSA B51 points NDE personnel to CAN/CGSB-48.9712 or another standard the regulator accepts. Ontario names ASNT SNT-TC-1A as acceptable, and Alberta's AB-506 accepts SNT-TC-1A on conditions. Since the Canadian General Standards Board closed on 1 April 2026, NRCan's NDT Certification Body continues to certify to CAN/CGSB-48.9712. Specifications should name NRCan, not CGSB. See NRCan NDT certification.
• Radiography. Exposure devices are licensed by the CNSC, and operators must be CNSC-certified exposure device operators, in every province.
• Methods. UT thickness at CMLs, corrosion mapping, phased array and TOFD for welds and heavy wall, wet fluorescent MT for cracking in amine, caustic and sour services, CUI screening, guided wave on piping, and MFL on tank floors. See pressure vessel inspection.
• Winter. Low temperatures affect couplant, batteries and people. External and CUI work is often planned for warmer months, with heated hoarding where it cannot wait.

How Atlantis supports API programmes in Canada

Atlantis NDT performs the NDE that API 510, 570 and 653 programmes and provincial inspections rely on: UT thickness and CML surveys, corrosion mapping, phased array, TOFD, MT, PT, VT, tank-floor MFL and guided-wave screening. The work is done by ASNT SNT-TC-1A certified technicians under ASNT NDT Level III oversight. Results go to your API-certified inspector and to the provincially certified inspector, who remain inspectors of record and sign. We are not an Authorized Inspection Agency and we do not issue provincial certificates or set intervals. We do not perform RBI or fitness-for-service assessments, though your engineers can use our data for them. If your province or specification requires CAN/CGSB-48.9712 for a method, tell us at scoping and we will confirm what we can staff. We have completed 1,500+ inspection activities and trained 1,000+ technicians. For programme-level help, see NDT consulting in Canada. Send your equipment list for a quote within 24 hours.

Frequently asked questions: API codes in Canada

Is API 510 mandatory in Canada?

Not nationally. British Columbia adopts API 510 Eleventh Edition in regulation, and Alberta applies it through AB-506. Saskatchewan and Manitoba bring it in through approved programmes and AB-512H. Ontario and Quebec do not list it, although many owners there use it as their engineering practice.

Is API 510 mandatory in Alberta?

AB-506 says the API publications it references are not adopted directly under Alberta regulation. They apply because AB-506 and other ABSA policy documents reference them. In practice, owners following AB-506 use API 510 and RP 572 for vessels.

Does Technical Safety BC require API 570 for piping?

Yes. BC adopted API 570 Edition 5 alongside API 510 and CSA B51:24, effective 31 December 2024, so in-service piping inspection in BC is expected to follow it.

What are the API 570 requirements in other Canadian provinces?

Alberta references API 570 and RP 574 in AB-506, and AB-512H expects authorised organisations to have it. Ontario and Quebec do not list it, but process plants usually apply it. Each province's piping registration and repair rules apply on top.

Is API 653 tank inspection required in Canada?

It depends on the tank and the instrument. Ontario's Liquid Fuels Handling Code adoption requires API 653 external inspection of certain fuel tanks, and Alberta's Directive 055 refers to API 653. Elsewhere, fire codes, environmental rules and owner practice decide.

Can an API 510 inspector sign a provincial pressure vessel inspection?

Not on API certification alone. Each province certifies its own inspectors: an ISI in Alberta, an Ontario Certificate of Competency holder, an RBQ-recognised person, or a licensed inspector in Saskatchewan, where an API 510 certificate is one accepted qualification route.

Which edition of API 510 applies in Canada?

BC names the Eleventh Edition (October 2022), which is also the current edition. Where API codes apply through policy or owner practice, use the edition the regulator document or your programme names, and track API addenda.

Do Canadian regulators accept ASNT SNT-TC-1A NDE technicians?

Often, with conditions. Ontario's adoption names SNT-TC-1A as acceptable, and Alberta's AB-506 permits it for several methods, requiring Level 2 and owner acceptance for UT shear wave. Some owners and pipeline specifications require CAN/CGSB-48.9712 through NRCan.

Who licenses industrial radiography in Canada?

The Canadian Nuclear Safety Commission licenses exposure devices and certifies exposure device operators, in every province.

Does Atlantis provide API inspectors in Canada?

No. Atlantis performs NDE. Your API-certified inspector and the provincially certified inspector stay inspectors of record. Ask us to scope NDE for your Canadian sites.

Related: CSA B51 and how it relates to API 510. Ready to plan the next outage? Request a quote for Canadian pressure equipment NDE.