API 570 Piping Inspection Support in Alaska

Short answer: In Alaska, API 570 inspection of production-facility, refinery and terminal piping is directed, evaluated and signed by the owner's API 570 Authorized Inspector (AI). Atlantis NDT performs the nondestructive examinations behind that plan: UT thickness at condition monitoring locations (CMLs), automated corrosion mapping, profile radiography through insulation, guided-wave screening, CUI follow-up and PAUT or TOFD on welds. Atlantis performs the NDE; your API 570 Authorized Inspector remains inspector of record and signs the inspection report.

Alaska's piping challenge is unlike any other state's. Much of the process piping sits on gravel pads above permafrost on the North Slope, is insulated against temperatures far below zero, and is reached by the Dalton Highway or by air. The rest is spread between the Valdez Marine Terminal, refineries at Nikiski, North Pole and Valdez, Cook Inlet oil and gas facilities, and fuel terminals that supply a state with few roads. The regulatory picture is distinctive too: Alaska's oil pollution rules name API 570 for facility oil piping, PHMSA regulates every pipeline in the state directly because Alaska has no certified state pipeline-safety partner, and the corrosion failures on North Slope transit lines in 2006 still shape how owners and agencies think about piping integrity. This hub sets out where the piping is, what API 570 requires, which NDE methods work in Alaskan conditions, how the rules fit together and what Atlantis delivers to your AI. To begin, request an NDE scope for your AI's inspection plan.

Where API 570 piping is in Alaska

Direct answer: Alaska's process piping is concentrated in North Slope production and gas-handling facilities around Prudhoe Bay, Kuparuk and the western fields; at the Valdez Marine Terminal; at the Kenai Peninsula refinery and Cook Inlet facilities; at the North Pole and Valdez refineries; and at Anchorage port, airport, military, utility and rural fuel facilities.

North Slope production facilities

Prudhoe Bay, Kuparuk, Alpine and newer western developments have flow stations, gathering centres, central processing and gas-handling plants, water treatment and injection facilities, and the well-pad and flowline piping that connects them. Piping carries multiphase production with CO2, H2S, produced water and sand, plus seawater and produced water for injection, high-pressure gas for reinjection and gas lift, fuel gas, glycol, methanol and diesel. Internal damage mechanisms include CO2 corrosion, microbiologically influenced corrosion, under-deposit corrosion and erosion at elbows and chokes. Most piping is insulated, and North Slope operators have long treated corrosion under insulation as a major programme in its own right, because moisture trapped in insulation during construction or through damaged jacketing stays there for years. Regulatory jurisdiction changes along the way: piping inside facilities and many flowlines are state-regulated or owner-programme piping, while transit lines downstream of the processing centres are PHMSA-regulated pipelines.

Valdez Marine Terminal

At the southern end of the Trans Alaska Pipeline System, the Valdez Marine Terminal holds crude tankage, berths, vapour-control and ballast-water treatment systems and the large-diameter piping that links them. Terminal piping in Valdez sees heavy snowfall, marine air, seismic exposure and intense regulatory and public scrutiny, and the boundary between the PHMSA-regulated pipeline and terminal piping has to be clearly documented.

Kenai Peninsula and Cook Inlet

Marathon's refinery at Nikiski supplies much of Southcentral Alaska with fuels, and the Nikiski industrial area and Cook Inlet onshore facilities handle oil and gas from offshore platforms and onshore fields. Refinery piping follows the familiar API RP 571 list for crude, hydrotreating and sour water service, while coastal exposure, tidal flats and seismic loading drive external inspection. Cook Inlet gas also supplies Southcentral power generation and utilities.

Interior Alaska and Valdez refining

Petro Star operates refineries at North Pole near Fairbanks and at Valdez, drawing crude from TAPS. Interior plants run through some of the coldest winters in the state, where heat tracing, insulation integrity and freeze protection of deadlegs and small-bore connections are as important to piping integrity as internal corrosion. Discontinuous permafrost means piping supports and buried transitions can move years after construction.

Anchorage, military bases and rural Alaska

The Port of Alaska and Ted Stevens Anchorage International Airport handle large fuel volumes, and Joint Base Elmendorf-Richardson, Eielson and other installations operate fuel systems and central heat and power plants. Coastal hubs such as Dutch Harbor, Kodiak, Bethel and Nome run fuel terminals and seafood processing plants with ammonia refrigeration piping. Many of these are not API 570 refinery populations, but owners often apply its principles to fuel and ammonia systems. Whether a line is in scope is the owner's decision.

What API 570 requires, in plain terms

Direct answer: API 570 is the in-service inspection, repair, alteration and rerating code for metallic process piping and its relief devices. The owner divides piping into circuits, classes them by consequence of a leak, places CMLs where damage is expected, and sets thickness and external intervals by class and remaining life or through a qualifying RBI programme. The AI evaluates and signs.

The current edition is API 570 fifth edition, published February 2024 with a reissued API RP 574. API summarises the update as a defined Inspection Supervisor role, stronger requirements for pressure-relieving devices and new rules on deferring inspection repair recommendations. Alaska has a particular reason to watch editions: its own regulation still cites the 1998 second edition (see below). Use a licensed current copy for your programme. In our words, the points that shape an NDE scope:

• Roles. The code is intended for owners with access to an authorized inspection agency, a repair organisation and qualified piping engineers, inspectors and examiners. The authorized piping inspector evaluates; NDE examiners such as Atlantis technicians measure and report.
• Scope. Hydrocarbon, chemical and similar flammable or toxic process services are in scope; water, steam and condensate are optional. API 570 does not replace the construction code for new piping before service.
• Service classes and intervals. Class 1 covers services where a leak could quickly become an emergency, Class 2 most unit piping, Class 3 lower-consequence flammable and off-site lines, and later editions add Class 4. Thickness inspection is due at the shorter of half the remaining life or the class maximum. Industry summaries of current editions give five years for Class 1 thickness and external, ten and five for Class 2, and ten and ten for Class 3; the 1998 edition used the same Class 1 to 3 values. Confirm with your AI against the current edition.
• Buried piping. API 570 has a separate section for buried process piping not regulated by the US Department of Transportation, covering above-grade surveillance, cathodic protection, excavation, pigging and leak testing. The 2016 fourth edition tied inspection intervals for buried piping without effective cathodic protection to soil resistivity; check the current edition for the values.
• CMLs and special locations. More CMLs go where consequences or rates are higher and at injection points, deadlegs, small-bore connections, CUI areas and soil-to-air interfaces.
• Rates, repairs and rerating. Long-term and short-term rates come from CML history, with the governing rate setting remaining life; the inspector authorises repairs and the piping engineer is involved in alterations and rerates.

Atlantis can calculate corrosion rates and remaining life from its data for the AI's review, but the interval is the AI's and owner's decision under the code and Alaskan rules. Background reading: API 570 code requirements, what triggers an internal piping inspection and API 510 vs API 570.

Cold, insulation and remoteness: the Alaska damage and access picture

Direct answer: Alaskan piping programmes are shaped by CUI in long-insulated systems, internal CO2, microbial and erosion damage in production piping, brittle-fracture and freeze concerns at extreme low temperatures, ground movement on permafrost, and the cost of getting people and equipment to site, which rewards methods that cover more piping per mobilisation.

CUI. North Slope experience showed that insulated lines can corrode out of sight for years when water gets into the insulation system. The 1998 edition of API 570 gave target follow-up percentages for damaged and suspect insulation by class, and API RP 583 now gives broader guidance; check the current edition for the approach your AI uses. Profile radiography through insulation, UT at inspection ports and screening methods the AI accepts all reduce the amount of insulation that has to be removed in a place where reinstating it properly is slow and expensive.

Internal corrosion in production piping. CO2 corrosion, MIC and under-deposit attack concentrate at low points, in stagnant sections and where water drops out, while sand erodes elbows, tees and choke outlets. Corrosion mapping at those locations finds localised attack that a single spot reading misses.

Low temperature and freeze damage. Piping that is depressurised and cold, or that sees auto-refrigeration during blowdown, raises brittle-fracture questions that the owner's engineers assess. Water left in deadlegs, drains and dead-ended instrument connections freezes and splits pipe. Post-winter walkdowns and freeze-damage checks belong in every spring plan.

Ground movement and seismic loading. Supports on permafrost and in discontinuous permafrost zones can heave or settle, and Southcentral Alaska is seismically active, as the 2018 Anchorage earthquake showed. Visual examination of supports and guides, and NDE at points of concentrated strain, help the AI decide whether movement has done damage.

NDE methods for API 570 work in Alaska

Direct answer: UT thickness at CMLs carries the programme; profile RT and screening reduce insulation removal; corrosion mapping finds localised internal attack in production piping; guided-wave screening covers long or elevated runs; PAUT or TOFD examines welds; and VT documents supports, insulation and freeze damage.

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. RT is performed only by crews properly licensed for work in Alaska; confirm the current licensing authority before RT is planned, and allow extra lead time for shipping sources to remote sites. Ultrasonic work at very low temperatures needs couplants and transducers rated for the conditions and temperature correction of readings; our Level III addresses this in the procedure rather than on the day. See our API 571 damage mechanisms guide for how methods follow mechanisms.

How Atlantis supports your Authorized Inspector

Direct answer: We perform the NDE in the AI's plan and return data the AI can evaluate without a second trip: Level III-reviewed procedures for Alaskan conditions, ASNT SNT-TC-1A certified technicians, on-site QA against history, and a digital report organised by circuit and CML. We are not an Authorized Inspection Agency and we do not supply API-certified inspectors.

1. Scope from the plan. Circuits, isometrics, CMLs, damage mechanisms, methods and coverage come from the AI's plan, along with which lines are facility oil piping under ADEC rules and which are PHMSA pipelines.
2. Procedures. An ASNT NDT Level III prepares or reviews each technique against the owner's specification, including low-temperature UT, profile RT through insulation and high-temperature UT on hot lines.
3. Logistics and fieldwork. Crews are mobilised to your site with equipment shipped ahead; the schedule is agreed during scoping around camp space, site orientation, flights or road travel and the work season.
4. Data QA before demobilising. Readings are compared with the previous survey while the crew is still on site, because a return trip to the Slope costs far more than an extra hour of checking.
5. Report. CML readings, C-scans, radiographs, screening results with follow-up, calibration records and technician certifications in our digital reporting platform.
6. AI evaluation and sign-off. The AI reviews rates, remaining life and next dates, decides on repairs and signs.
7. Next interval. CML identifiers and reading patterns carry forward for like-for-like comparison.

Risk-based inspection programmes and fitness-for-service assessments are carried out by the owner's engineers or a specialist using our data; Atlantis does not offer them. More on our scope: API 570 piping NDE support and piping circuit and CML inspection.

Alaska regulations that sit on top of API 570

Direct answer: ADEC's oil pollution prevention rules at 18 AAC 75.080 set requirements for facility oil piping at oil terminals, crude oil transmission pipelines and exploration and production facilities, and they cite API 570. PHMSA regulates all pipelines in Alaska directly. AKOSH enforces process safety management under Alaska's State Plan. Confirm current requirements with each agency.

ADEC: facility oil piping under 18 AAC 75.080

The Alaska Department of Environmental Conservation's Spill Prevention and Response programme administers 18 AAC 75. Section 18 AAC 75.080 applies to facility oil piping at oil terminals, crude oil transmission pipelines, and exploration and production facilities. In the rule text we reviewed, it requires metallic facility oil piping containing oil to be maintained under a written corrosion control programme; sets design and installation requirements for buried piping, including protective coating, cathodic protection under a cited NACE standard and welded construction; requires periodic electrical inspection of buried metallic piping that lacks cathodic protection; requires frequent visual checks of aboveground piping for leaks; and refers to API 570, citing the October 1998 edition with its addenda, for the inspection programme, including examining buried piping for damaged coating and corrosion whenever a segment is exposed. The rule also recognises API 570 inspection isometrics as one way to provide the facility piping diagrams it requires. Because the cited edition is decades old, owners generally write programmes that satisfy both the rule's reference and the current edition; ADEC is the authority on how its reference applies, and your approved oil discharge prevention and contingency plan records the commitments. Confirm the current rule text and which facilities are in scope with ADEC.

PHMSA: no state pipeline-safety partner

Alaska is one of very few states without a PHMSA-certified state programme 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. The 2006 crude releases from corroded North Slope transit lines, previously treated as low-stress lines outside federal rules, led PHMSA to extend its hazardous-liquid regulations to rural low-stress pipelines, and they prompted the State to create the Petroleum Systems Integrity Office within the Department of Natural Resources in 2007 to coordinate oversight of oil and gas facility integrity. The federal hazardous-liquid rule (49 CFR Part 195) excludes in-plant piping at processing and storage facilities and certain transfer piping, so facility piping stays with API 570, ADEC and the owner's programme, while the pipeline follows Part 195 and gas lines Part 192. Boundaries at launchers, receivers and processing-centre outlets should be documented by the operator. Pipeline-side NDE is on our pipeline inspection page.

AKOSH process safety management

Alaska runs its own occupational safety State Plan through the Department of Labor and Workforce Development, which enforces process safety management, including the mechanical-integrity element that mirrors 29 CFR 1910.119(j), at refineries and covered processing facilities. That element requires piping systems to be inspected and tested following recognised and generally accepted good engineering practice, with documented results and correction of deficiencies; API 570 is the practice most owners cite. EPA's Risk Management Program applies where listed substances exceed thresholds.

Other overlays

The Department of Labor and Workforce Development's mechanical inspection section covers boilers and pressure vessels, not process piping, and ADEC's field-constructed tank rule requires API 653 for covered tanks; see the companion hubs for API 510 pressure vessel inspection in Alaska and API 653 tank inspection in Alaska. The Alaska Oil and Gas Conservation Commission regulates wells and reservoirs rather than facility piping.

Planning around seasons, camps and turnarounds

Direct answer: Plan insulation removal, repairs and outage NDE for the summer season, keep on-stream UT and RT going through the year where conditions allow, and book early: camp beds, flights, site orientation and equipment shipping set the real schedule in Alaska.

• Summer season: insulation removal and reinstatement, recoating, CUI follow-up and most outage work, because open insulation in winter is a hazard to both people and piping.
• Winter: UT and profile RT can continue indoors and in heated enclosures, and some exterior work is practical with the right procedure; darkness, wind chill and ice limit productivity, which the scope should reflect.
• Access and orientation: North Slope sites require operator-specific safety orientation and camp arrangements, and Valdez and the Interior add their own site rules; build these into the dates.
• Shipping: scanners, sources and consumables travel by road, air or barge; plan lead times and spares so a failed cable does not end a campaign.
• After events: walkdowns and targeted NDE after earthquakes, flooding or unusual thaw.

API 570 piping inspection support across Alaska

Direct answer: Atlantis supports API 570 programmes in Anchorage and the Mat-Su, on the Kenai Peninsula, at Valdez, in Fairbanks and North Pole, on the North Slope and at coastal hubs. Crews are mobilised to your site and the schedule is agreed during scoping.

• Anchorage and Southcentral: port, airport, military and utility piping; see third-party inspection in Anchorage for wider support in the region.
• Kenai Peninsula and Cook Inlet: refinery and onshore oil and gas facility piping around Nikiski and Kenai.
• Valdez: marine terminal and refinery piping.
• Fairbanks, North Pole and the Interior: refinery, terminal and central heat and power piping.
• North Slope: production, gas-handling and injection facility piping, scheduled with the operator's access arrangements.
• Coastal and rural Alaska: fuel terminals and ammonia refrigeration piping at seafood plants.

Statewide services are on NDT inspection services in Alaska; Level III procedure support on NDT consulting in Alaska; technician skills on ASNT NDT training in Alaska.

Keeping piping history usable

Direct answer: We keep your circuit and CML numbering, record the reading pattern, instrument and calibration for each CML, and deliver data that loads into your inspection database, so corrosion rates stay valid across campaigns that may be years apart. Optional digital twin and ERP views help remote teams plan.

When an AI in Anchorage plans work at a facility hundreds of miles away, good data is what saves a trip. We photograph and describe new CMLs, record insulation-port locations and flag readings that do not match history rather than letting them distort a rate. Results can be shown in a digital twin of the facility, and certificates, calibrations and work orders can be tracked in our inspection-management ERP. Sample layouts are on NDT report templates, and construction-code background is in ASME B31.3 explained.

What to send us for an Alaska quote

Direct answer: Send the circuit list and isometrics, the last API 570 report, the AI's plan, insulation and access details, logistics constraints and your season window. We reply with questions or a scope, and a quote within 24 hours of having what we need.

1. Circuit list with service class, material, size, schedule, temperature and pressure, and whether lines are ADEC facility oil piping or PHMSA pipelines.
2. Isometrics with CMLs, insulation ports, injection points, deadlegs and small-bore connections marked.
3. The last API 570 report and thickness history, or confirmation of a baseline survey.
4. The AI's plan and damage mechanisms of concern, such as CO2 corrosion, MIC, erosion or CUI.
5. Logistics: road, air or barge access, camp space, site orientation and shipping lead times.
6. Dates and the work season you are targeting.

Send us your circuit list and we will scope the NDE against your AI's plan.

Frequently asked questions: API 570 in Alaska

Who does API 570 piping inspection in Alaska?

The owner's API 570 Authorized Piping Inspector, employed by the owner or an inspection agency, directs, evaluates and signs. Qualified NDE examiners take the measurements. Atlantis performs that NDE and delivers the data to your AI, who remains inspector of record.

Does Alaska require API 570 by regulation?

For facility oil piping at oil terminals, crude oil transmission pipelines and exploration and production facilities, 18 AAC 75.080 cites API 570 (the 1998 edition in the text we reviewed). Elsewhere, AKOSH's PSM rule requires recognised good engineering practice, usually API 570. Confirm with ADEC and AKOSH.

Who regulates pipelines in Alaska?

PHMSA, directly, for both interstate and intrastate pipelines, because Alaska has no certified state pipeline-safety programme. Facility piping excluded from the federal rules stays under API 570 and ADEC.

How often does process piping need inspection under API 570?

Thickness at the shorter of half the remaining life or the class maximum, external visual by class, unless a qualifying RBI programme applies. The 1998 edition gave five years for Class 1 thickness; confirm current values with your AI.

How do you inspect insulated piping without stripping it all?

Profile RT through insulation, UT at inspection ports and screening the AI accepts, followed by targeted removal where results or the plan require it. The AI sets the extent of follow-up.

Can UT be done at North Slope winter temperatures?

Yes, with couplants and transducers suited to the temperature and corrected readings, written into the Level III-approved procedure. Productivity is lower, so most owners schedule insulation work for summer.

Is Atlantis an Authorized Inspector?

No. We are not an Authorized Inspection Agency and we do not supply API-certified inspectors. We supply independent NDE data to the AI who signs.

Who licenses industrial radiography in Alaska?

Alaska is not an NRC Agreement State, so radiography licences have been issued by the NRC. RT is performed only by properly licensed crews; confirm current licensing before planning RT.

What certifications do your technicians hold?

ASNT SNT-TC-1A certification under our written practice, with ASNT NDT Level III oversight; certificates and calibration records come with each report.

Do you provide RBI, fitness-for-service or API 570 training?

No. RBI and FFS are performed by the owner's engineers or specialists using our data, and we train only to ASNT SNT-TC-1A. See the API inspector career guide or ASNT Level III training.

How quickly can you mobilise to Prudhoe Bay or Nikiski?

We quote within 24 hours of receiving scope information; mobilisation is agreed during scoping around orientation, camp space, travel and the work season.

Next step

For a summer CUI campaign, CMLs coming due or outage NDE, get a quote within 24 hours or book a scoping call. Atlantis performs the NDE; your API 570 Authorized Inspector remains inspector of record and signs the inspection report.

More Atlantis NDT services in Alaska

• NDT training and certification in Alaska
• Level III consulting in Alaska
• NDT inspection services in Alaska
• API 653 storage tank inspection support in Alaska
• API 510 pressure vessel inspection support in Alaska
• NDT ERP software in Alaska
• Practical NDT simulator in Alaska

Part of the wider piping circuit inspection service at Atlantis NDT.