API 653 Tank Inspection Support in Alaska

Short answer: In Alaska, an API 653 tank inspection is evaluated and signed by the owner's API 653 Authorized Inspector, and at oil terminals, crude oil pipelines and exploration and production facilities the Alaska Department of Environmental Conservation's oil pollution rules (18 AAC 75) require field-constructed tanks to be maintained and inspected consistent with API 653. Atlantis performs the NDE behind those inspections, floor MFL with UT prove-up, shell UT, weld examination and settlement data, and delivers it to your inspector in a structured digital report.

Alaska's tanks live in conditions few other states share: permafrost and frost-heave foundations in the Interior and on the North Slope, some of the strongest earthquakes ever recorded in North America, long dark winters with extreme cold, short construction seasons and sites that can only be reached by air, barge or ice road. The state also handles its own pipeline-safety arrangement differently from almost everywhere else, because PHMSA oversees both interstate and intrastate pipelines in Alaska directly. This page explains where Alaska's tanks are, what API 653 asks for, how ADEC's rules and federal rules fit together, how the climate shapes inspection planning, 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 Alaska tank list.

Where API 653 tanks are in Alaska

Direct answer: Alaska's field-constructed tanks are concentrated at the Valdez Marine Terminal at the end of the Trans Alaska Pipeline System, on the North Slope production fields, at the Kenai Peninsula refinery and Cook Inlet facilities, at the Interior and Valdez refineries, at Anchorage's port and airport fuel terminals, at military fuel farms, and at fuel terminals and community tank farms serving coastal and rural Alaska.

Valdez and the Trans Alaska Pipeline System

The Trans Alaska Pipeline System carries North Slope crude about 800 miles from Prudhoe Bay to the Valdez Marine Terminal on Prince William Sound, where large crude tanks hold oil before it is loaded onto tankers. These are some of the most closely watched tanks in the country: regulated by ADEC, subject to federal oversight and scrutinised by citizen advisory groups since the Exxon Valdez spill. Floor condition, secondary containment, seismic performance and leak detection all feature in their inspection programmes.

North Slope production fields

Prudhoe Bay, Kuparuk and the newer western developments include production facilities with tanks for crude, produced water, diesel and process fluids. ADEC and EPA regulate production facilities and their lines upstream of the processing centres, while PHMSA regulates the transit lines downstream. Tanks here sit on gravel pads over permafrost, often on elevated or thermally protected foundations, and see temperatures far below those most tank steels were originally specified for.

Kenai Peninsula and Cook Inlet

The refinery at Nikiski on the Kenai Peninsula, operated by Marathon, processes crude and supplies much of Southcentral Alaska with fuels, and Cook Inlet oil and gas facilities include onshore tank farms. Coastal exposure, tidal flats and seismic risk drive the inspection focus.

Interior Alaska and Valdez refining

Petro Star operates refineries at North Pole near Fairbanks and at Valdez, drawing crude from TAPS and returning residual streams to the pipeline. Fairbanks and the Interior also hold fuel terminals for heating oil, jet fuel and diesel. Discontinuous permafrost in the Interior means foundation movement can appear years after construction, so settlement history matters as much as floor thickness.

Anchorage, ports and military fuel farms

The Port of Alaska in Anchorage receives most of the fuel shipped into Southcentral Alaska, and terminals near the port and at Ted Stevens Anchorage International Airport, one of the world's busiest cargo airports, hold large volumes of jet fuel. Joint Base Elmendorf-Richardson, Eielson Air Force Base and other installations maintain their own fuel farms. The 2018 magnitude 7.1 Anchorage earthquake was a reminder that tanks in Southcentral Alaska need post-event checks as part of normal practice.

Coastal and rural Alaska

Fuel terminals at Dutch Harbor, Kodiak, Bethel, Nome, Kotzebue and Southeast Alaska ports support fishing fleets, communities and utilities, and hundreds of villages depend on community tank farms filled by barge during the short ice-free season. Many rural tanks are shop-built or small field-erected tanks; which code applies, API 653, STI SP001 or an owner programme, depends on the tank's construction and the facility's regulatory status.

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. It calls for monthly owner checks, a formal external inspection by the Authorized Inspector, shell UT thickness surveys and an out-of-service internal inspection, with intervals tied to measured corrosion inside code ceilings. The current Fifth Edition has addenda through Addendum 4 (July 2025).

Routine in-service checks. Owner personnel inspect each tank at least monthly for leaks, shell distortion, settlement, coating and roof damage, and foundation problems. In Alaska that list naturally extends to frost heave, snow and ice loading on roofs and platforms, and damage from ice falling off the shell.

Formal external inspection. The Authorized Inspector performs an external inspection at least every five years, or sooner where shell corrosion is rapid, because the code ties the interval to a quarter of the remaining shell corrosion life.

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

Internal inspection. For a new tank, the first internal is due within ten years, extendable through credited safeguards to a ceiling of twenty years, or thirty with a release prevention barrier. Later intervals are calculated from measured bottom corrosion within the same ceilings, or set by a qualifying risk-based assessment by the owner's specialists.

Brittle fracture and settlement. API 653 contains a procedure for assessing the risk of brittle fracture, which depends on plate thickness, material toughness and the lowest metal temperature a tank will see, and an annex for evaluating settlement. Both carry more weight in Alaska than almost anywhere else. Addendum 4 revised the text on measuring tank-bottom plate thickness, so check procedures against the current edition and addendum from api.org. These evaluations belong to the owner and the inspector. See API 653 tank inspection intervals explained and the API 653 tank inspection guide.

Alaska regulations that sit on top of API 653

Direct answer: ADEC's oil pollution prevention rules at 18 AAC 75 require field-constructed aboveground oil tanks at oil terminals, crude oil pipelines and exploration and production facilities to be maintained and inspected consistent with API 653 (or API RP 12R1 for production tanks). PHMSA directly regulates all pipelines in Alaska, including breakout tanks under 49 CFR 195.432, and EPA SPCC and OSHA PSM also apply. Confirm current requirements with ADEC.

ADEC: 18 AAC 75.065 field-constructed tank requirements

The Alaska Department of Environmental Conservation's Spill Prevention and Response programme administers 18 AAC 75, which includes requirements for facilities that must hold oil discharge prevention and contingency plans. Section 18 AAC 75.065 sets the requirements for field-constructed aboveground oil storage tanks at oil terminals, crude oil pipelines and exploration and production facilities. The key points, in summary:

• API 653 by reference. Each field-constructed tank must be maintained and inspected consistent with API 653; the current rule cites a specific earlier edition (the 2014 Fifth Edition with early addenda in the current text), and production tanks may follow API RP 12R1. Older versions of the rule cited the 2001 Third Edition, so confirm which edition applies in your approved plan.
• ADEC can shorten intervals. The department may reduce inspection intervals for tanks older than 30 years, riveted or bolted tanks, tanks with known structural or corrosion problems, and tanks affected by a seismic event.
• Extending the first internal. A request to extend the initial internal inspection beyond ten years must be submitted to ADEC for review and approval, documented against the code's safeguard table.
• Risk-based inspection. Risk-based scheduling under API 653 is allowed, but the assessment must be signed by a registered engineer and the interval may not exceed 30 years.
• Cathodic protection, leak detection and overfill. The rule sets requirements for cathodic protection on newer tanks (unless a corrosion expert finds it unnecessary), leak detection for the tank bottom and overfill protection.
• Notification and records. Owners must notify ADEC before a major repair or alteration and before returning the tank to service, and keep inspection records for the service life of the tank, with routine in-service inspection records kept for five years.

That combination makes Alaska different from states with no tank rule at all and from states such as New Jersey that ban risk-based intervals: here RBI is allowed under conditions, but ADEC can also tighten intervals after an earthquake or for old tanks. Confirm the details for your facility with ADEC and in your approved contingency plan.

PHMSA: no state pipeline-safety partner

Alaska is one of the very few states that has not taken on PHMSA certification for intrastate pipelines, so PHMSA's Office of Pipeline Safety inspects and enforces federal rules on both interstate and intrastate gas and hazardous-liquid pipelines in Alaska, including TAPS, Cook Inlet lines and North Slope transit lines downstream of the processing centres. Under 49 CFR 195.432, steel breakout tanks on regulated hazardous-liquid pipelines operating at atmospheric or low pressure must be inspected in accordance with API 653, excluding the code's alternative risk-based internal interval, while pressurised breakout tanks follow API 510. A tank that is both a PHMSA breakout tank and an ADEC-regulated tank therefore cannot use RBI for its internal interval even though ADEC's rule would allow it, and the federal rule incorporates its own, older edition of API 653.

EPA SPCC and OSHA PSM

Facilities subject to EPA's SPCC rule (40 CFR Part 112) must test or inspect aboveground oil containers for integrity on a regular schedule and after material repairs, following industry standards: API 653 for field-erected tanks and STI SP001 for shop-built tanks. That matters for rural utilities, airports and distributors that fall outside 18 AAC 75.065. Alaska runs a State Plan for occupational safety through the Alaska Department of Labor and Workforce Development, which enforces process safety management, including the mechanical-integrity element mirrored from 29 CFR 1910.119(j), at the refineries and covered processing facilities.

Radiography in Alaska

Alaska is not an NRC Agreement State, so radioactive-materials licences for industrial radiography in Alaska have been issued by the US Nuclear Regulatory Commission. Repair-weld radiography is performed only by crews properly licensed for work in Alaska; confirm current licensing authority before planning RT, and remember that shipping sources to remote sites adds lead time.

NDE methods for API 653 work in Alaska

Direct answer: Alaska tank work relies on floor MFL with UT prove-up, shell and annular-plate UT using cold-weather procedures, corrosion mapping, visual examination of roofs, foundations and secondary containment, MT, PT and vacuum-box testing after repairs, PAUT or RT on new welds, and settlement surveys on permafrost and seismic sites.

Procedures are reviewed by an ASNT NDT Level III and technicians are certified to an SNT-TC-1A written practice. Cold-weather work needs couplants rated for low temperatures, temperature-corrected thickness readings and equipment that tolerates condensation when moved between heated enclosures and outdoor steel. Every reportable MFL indication is proved up with UT. For method trade-offs see MFL versus UT for tank floors, and for scope detail 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 before the crew leaves what may be a fly-in site, and delivers a digital report the inspector can evaluate and sign. We are not an Authorized Inspection Agency and we do not supply API-certified inspectors. Our job is the examinations and the data.

1. Scope from the inspector's plan: floor coverage, shell and annular-plate locations, roof, foundation and containment examinations, weld examinations and settlement points.
2. Procedure review by an ASNT NDT Level III, including cold-weather UT procedures and temperature correction.
3. Examinations by technicians certified to an SNT-TC-1A written practice: MFL and UT prove-up, shell and annular UT, corrosion mapping, visual, surface and volumetric methods.
4. Data QA on site: readings checked against calibration records and the previous inspection before demobilising, because returning to a remote site for missing data can mean another barge or charter flight.
5. Digital report in our reporting platform: floor maps, prove-up readings, shell readings by course and location, weld records, photographs, calibration data and technician certifications, using report templates matched to your inspector's file and the service-life records ADEC expects.
6. Inspector evaluation and sign-off: the inspector evaluates, decides on repairs and sets the next dates, and the owner handles any ADEC notifications.
7. Reuse at the next interval: the same locations next time, tracked in our inspection-management ERP or 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 belongs to the inspector and the owner under API 653, 18 AAC 75 and any federal rule that applies. 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 see API 653 tank inspection support.

Planning around the season, the cold and logistics

Direct answer: In Alaska the calendar decides most tank inspection plans. Internal inspections and repairs cluster in the late-spring-to-early-autumn window, remote sites depend on barge and flight schedules, and winter work is limited to external examinations under cold-weather procedures. Plan cleaning, NDE and repairs as one mobilisation.

The summer window. Long daylight and milder temperatures make May to September the practical time for internal inspections, coating work and repairs. At community tank farms, the inspection also has to fit between fuel barge deliveries, because a tank emptied for inspection must be back in service before the annual fill.

Cold and brittle fracture. Low metal temperatures affect both safety and code decisions. The inspector's brittle-fracture assessment considers the tank's lowest design metal temperature, and repairs or changes of service in winter conditions need extra care. Cold also affects UT accuracy, couplant behaviour, battery life and technician safety, so external surveys in winter are planned with heated shelters and shorter work periods.

Logistics. Many Alaskan sites are reached only by air or water. Equipment, consumables and any radiography sources must be shipped ahead, and crews need accommodation and site access arranged early. Combining several tanks, or several facilities in one region, into one campaign makes the most of each mobilisation.

After an earthquake. Following a significant seismic event, the owner and inspector may call for external visual examination, settlement surveys and checks on piping connections and containment, and ADEC may shorten intervals for affected tanks. Atlantis can collect that data once the site is safe to access. Book a scoping call for your next season.

API 653 inspection support across Alaska

Direct answer: Atlantis mobilises crews to tank sites throughout Alaska on a schedule agreed during scoping: Anchorage and the Mat-Su, the Kenai Peninsula, Valdez, Fairbanks and North Pole, the North Slope, Southeast Alaska, Kodiak, the Aleutians and western Alaska hubs.

• Anchorage and Southcentral: port, airport and military fuel terminals; see third-party inspection in Anchorage for the wider inspection support we offer in the region.
• Kenai Peninsula and Cook Inlet: refinery tankage at Nikiski and onshore oil and gas facilities.
• Valdez: crude storage at the marine terminal and refinery tankage.
• Fairbanks, North Pole and the Interior: refinery, terminal and military tanks on discontinuous permafrost.
• North Slope: production-facility tanks, scheduled with the operator's camp and access arrangements.
• Coastal and rural Alaska: fuel terminals and community tank farms, scheduled around barge seasons.

The piping, manifolds and pressure vessels at the same sites follow their own codes; see our companion hubs for API 570 piping inspection in Alaska and API 510 pressure vessel inspection in Alaska, and the statewide NDT inspection services in Alaska page. Pipeline operators can also see pipeline inspection services.

What to send us for a quote

Direct answer: Send your tank list, the last API 653 reports, your inspector's plan, site access and logistics details, and your season window. We return a scoped NDE quote within 24 hours.

1. Tank list and drawings: tank IDs, diameter, height, roof type, product, year built, plate material and thicknesses, design metal temperature, foundation type, bottom history, cathodic protection and leak detection, and whether the tank is an ADEC-regulated or PHMSA breakout tank.
2. Previous reports: external and internal API 653 reports, floor maps, shell readings and settlement surveys, plus any approved interval extensions or RBI assessments.
3. The inspector's plan: examinations, coverage, acceptance references and report format, with the name of your Authorized Inspector or agency.
4. Logistics: how the site is reached, accommodation, shipping lead times, site orientation and permit requirements.
5. Dates: regulatory due dates, cleaning schedule, barge or production constraints and the season window you are targeting.

Get a quote within 24 hours.

Frequently asked questions: API 653 tank inspection in Alaska

Who can perform an API 653 inspection in Alaska?

An API 653 Authorized Inspector, employed by the owner or 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 ADEC require API 653 inspections?

For field-constructed aboveground oil tanks at oil terminals, crude oil pipelines and exploration and production facilities, 18 AAC 75.065 requires maintenance and inspection consistent with API 653, or API RP 12R1 for production tanks. Confirm which edition and which requirements apply to your facility with ADEC.

Can Alaska tanks use risk-based inspection intervals?

Under 18 AAC 75.065, yes, if a registered engineer signs the assessment and the interval does not exceed 30 years. A tank that is also a PHMSA breakout tank cannot use API 653's risk-based internal interval under 49 CFR 195.432.

Who regulates pipelines and breakout tanks in Alaska?

PHMSA does, directly. Alaska has not accepted certification for intrastate pipelines, so PHMSA's Office of Pipeline Safety inspects both interstate and intrastate lines. ADEC and EPA regulate production facilities and lines upstream of the North Slope processing centres.

Can ADEC shorten my inspection interval?

Yes. The rule lets ADEC reduce intervals for tanks over 30 years old, riveted or bolted tanks, tanks with known structural or corrosion problems, and tanks affected by a seismic event.

Do I have to tell ADEC before repairing a tank?

The rule requires notification before a field-constructed tank undergoes a major repair or alteration and before it returns to service. The owner handles that notification; we supply the NDE data for the repair and the post-repair examinations.

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 evaluates it and signs.

Can you inspect in winter?

External shell UT, corrosion mapping and visual examination can be done in winter with cold-weather procedures and heated shelters. Internal inspections, floor scanning and repairs are normally planned for the summer window.

What certifications do your technicians hold?

Technicians are certified to an ASNT SNT-TC-1A written practice for each method, with procedures reviewed by an ASNT NDT Level III. Radiography is performed only by crews properly licensed for industrial radiography work in Alaska.

Do you perform RBI or fitness-for-service assessments?

No. Those are performed by the owner's engineers or specialist consultants, and in Alaska an RBI assessment under 18 AAC 75.065 must be signed by a registered engineer. Atlantis supplies the floor, shell and weld data those assessments use.

Do you offer API 653 certification training?

No. Atlantis provides ASNT SNT-TC-1A NDT training only, including NDT training in Alaska. For the API certification route, see our API inspector career guide.

How soon can a crew reach Valdez, the Kenai or the North Slope?

Crews are mobilised to your site on a schedule agreed during scoping, built around access, shipping and the season window. Send tank details for a quote within 24 hours.

Plan your Alaska tank inspections

From a floor scan on a Valdez crude tank to a shell survey at an Anchorage fuel terminal or a settlement check on a permafrost foundation in the Interior, start with your inspector's plan and your season window. Send us your tank list, or see NDT consulting in Alaska for Level III procedure support.

More Atlantis NDT services in Alaska

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

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