API 570 Piping Inspection Support in California

Short answer: API 570 piping inspection in California is directed and signed by the owner's API 570 Authorized Inspector (AI), inside a mechanical integrity programme that, at refineries, must also satisfy Cal/OSHA's refinery process safety rule. Atlantis NDT performs the nondestructive examinations behind the inspection: CML thickness surveys, automated corrosion mapping, profile RT, guided-wave screening, PAUT and TOFD. Atlantis performs the NDE; your API 570 Authorized Inspector remains inspector of record and signs the inspection report.

California is a different piping market from the Gulf Coast. It has fewer refineries than a decade ago, but the ones that remain run under the most prescriptive refinery safety regime in the United States, in a seismic zone, next to dense cities and ports. Two large refineries stopped producing fuels between late 2025 and early 2026, others have converted to renewable fuels, and the remaining plants are being asked to document damage mechanisms, inspection practice and hazard controls in more detail than federal rules require. This page maps where API 570 piping sits in California, how the code and the state rules combine, which NDE methods fit, and how Atlantis supports your AI. To start, request an NDE scope for your AI's plan.

Where API 570 piping is in California

Direct answer: California's API 570 piping sits in four regions: the Los Angeles Basin refineries and the Ports of Los Angeles and Long Beach; the San Francisco Bay Area refineries and renewable-fuel plants on the Carquinez Strait; the Kern County oil fields and gas plants around Bakersfield; and a scattered base of chemical, industrial gas, power and terminal piping statewide.

Los Angeles Basin: El Segundo, Carson, Wilmington and Torrance

The South Bay holds most of Southern California's refining: Chevron El Segundo, Marathon's Los Angeles refinery spanning Carson and Wilmington, PBF's Torrance refinery and Valero Wilmington. Phillips 66 ended fuel production at its Los Angeles refinery in the fourth quarter of 2025, which leaves idle and decommissioned piping on one side of the fence and active units on the other in the same neighbourhood. Process piping here includes crude and vacuum overheads, FCC and alkylation piping, hydroprocessing effluent with ammonium bisulfide, sour water and amine systems, and long product lines to the marine terminals and tank farms of the twin ports. Marine-terminal piping on the wharves brings salt exposure, support corrosion and its own state standard (see the regulations section).

Bay Area: Richmond, Martinez, Benicia and Rodeo

Chevron Richmond and PBF Martinez remain conventional refineries, while the Rodeo and Martinez sites of Phillips 66 and Marathon have been converted to renewable diesel. Valero stopped producing fuels at Benicia after idling units in the first quarter of 2026. Renewable-feed conversions matter for API 570: feedstocks such as vegetable oils, tallow and used cooking oil bring different corrosion and fouling behaviour (organic acids, chlorides and other contaminants), so converted circuits need fresh damage mechanism reviews and often new CMLs rather than a copy of the old refinery plan. Bay fog and marine air keep CUI and external corrosion on the agenda.

Kern County and the San Joaquin Valley

Around Bakersfield, the Kern River, Midway-Sunset, Belridge and Elk Hills fields carry gathering systems, gas plants, produced-water handling and the steam distribution networks used for thermal enhanced oil recovery. Steam lines bring high-temperature insulated piping, thermal cycling and CUI at shutdown-restart cycles; produced water brings CO2 and under-deposit corrosion; small refineries and renewable-fuel plants in the valley add their own process piping.

Chemical, industrial gas, power and specialty piping

Statewide, hydrogen plants, industrial gas facilities, chemical distribution, power stations and semiconductor, biotech and pharmaceutical plants carry ASME B31.3 process piping. API 570 lists some services, such as water, steam, condensate and Category D services, as optional, and many non-refining owners adopt it selectively; whether a given system is in scope is the owner's decision. San Diego's port, fuel terminals and military-adjacent industry add terminal and transfer piping in the south.

How API 570 and Cal/OSHA's refinery rule fit together

Direct answer: API 570 sets the in-service inspection method: circuits, service classes, CMLs, intervals by class and remaining life, and controlled repairs. At California refineries, Title 8 section 5189.1 adds requirements around it: mechanical integrity inspections must meet or exceed RAGAGEP, and damage mechanism reviews must identify every potential damage mechanism and be revalidated at least every five years.

API 570 in brief. The current edition is the fifth, published February 2024, with API RP 574 reissued alongside it. API notes that the fifth edition adds an Inspection Supervisor role, strengthens requirements for pressure-relieving devices and adds rules for deferring inspection repair recommendations. The code groups piping into circuits, assigns each a service class reflecting the consequence of a leak (the top class is for services where a leak could create an immediate emergency, such as rapidly vaporising light hydrocarbons, high-H2S gas, hydrofluoric acid or piping over public roads), and places CMLs according to the damage mechanisms expected. Thickness intervals are the shorter of half the remaining life or the class maximum in the code's table; external visual inspections are set by class; a documented RBI programme meeting the code's conditions can set intervals instead. Injection points, deadlegs, CUI, small-bore piping, soil-to-air interfaces and buried piping get special treatment. API 570 does not replace ASME B31.3 for new construction.

Section 5189.1 on top. Cal/OSHA's Process Safety Management for Petroleum Refineries, effective 1 October 2017, applies to every California refinery. Relevant to piping:

• Mechanical integrity: inspections and tests must use procedures that meet or exceed RAGAGEP, at frequencies consistent with manufacturers' recommendations, RAGAGEP or more protective internal practice. For piping, API 570 and RP 574 are the RAGAGEP most refiners name.
• Damage mechanism review (DMR): required for each process where a damage mechanism exists; covers process flow diagrams, identification of all potential damage mechanisms, whether materials of construction suit their service, methods to prevent or mitigate damage, and review of operating parameters; revalidated at least every five years, reviewed for major changes and reviewed when an incident investigation identifies a damage mechanism as contributing.
• Hierarchy of hazard controls analysis and other enhanced elements that can change piping design and materials, and therefore the inspection plan.

The practical link is direct. A DMR that identifies, say, ammonium bisulfide corrosion in a hydroprocessing effluent circuit or naphthenic acid attack in a crude unit transfer line should be visible in that circuit's CMLs and NDE methods. When we receive a scope, we ask which DMR findings drove each item, so that the NDE coverage matches the mechanism and the AI can show auditors the connection. Non-refinery processes follow the general PSM standard, Title 8 section 5189, which tracks the federal mechanical integrity element; California is a state-plan state, so Cal/OSHA rather than federal OSHA enforces both.

Corrosion rates come from CML readings; remaining life is the thickness above the required minimum divided by the governing rate. Atlantis can calculate both from its data for the AI's review; the interval decision belongs to the AI and the owner. More: API 570 code requirements, what triggers an internal piping inspection and API 571 damage mechanisms.

NDE methods for API 570 work in California

Direct answer: CML thickness UT remains the core method. California programmes lean heavily on automated corrosion mapping for localised mechanisms flagged in damage mechanism reviews, profile RT for small-bore and insulated piping, guided-wave screening on racks and terminal headers, and PAUT or TOFD for weld cracking.

Industrial radiography in California is licensed by the California Department of Public Health's Radiologic Health Branch (California is an NRC Agreement State); RT is performed by crews licensed in the state, and dense urban sites usually push us toward lower-activity sources, shielding or digital RT, and off-shift shots. Guided wave tells the AI where to look; quantitative UT or RT then measures what is there.

California regulations around API 570 piping

Direct answer: At the plant: Cal/OSHA PSM (sections 5189 and 5189.1) and CalARP. On the wharf: the State Lands Commission's marine oil terminal standards. Beyond the fence: the State Fire Marshal for intrastate hazardous-liquid pipelines and the CPUC for gas. Air districts add leak rules. Confirm details with each agency.

CalARP. The California Accidental Release Prevention programme implements the federal Risk Management Program with state additions, including a Program 4 for petroleum refineries that parallels section 5189.1, administered locally by Certified Unified Program Agencies. Program 4 was created after the 2012 Chevron Richmond refinery fire, which began with a leak from a corroded crude-unit line, and its damage mechanism hazard review is expressly conducted on all PSM-covered process piping circuits and process equipment as part of the process hazard analysis cycle. For an API 570 programme that is significant: every circuit should have a documented mechanism review, and the CMLs and NDE methods should visibly follow from it. Refineries also report annual process safety performance indicators to their CUPA.

Marine oil terminals. Piping on marine oil terminal wharves falls under the State Lands Commission's Marine Oil Terminal Engineering and Maintenance Standards (MOTEMS), adopted in the California Building Code, which require periodic audits and inspections of terminal structures and pipelines. Owners typically coordinate MOTEMS inspections with their API 570 programme for the onshore piping behind the wharf; we can supply UT, guided-wave and VT data to whichever engineer of record leads each part.

Pipelines. The Office of the State Fire Marshal's Pipeline Safety Division holds PHMSA certification for intrastate hazardous-liquid pipelines (about 5,500 miles) and acts as PHMSA's agent on interstate lines in the state; the CPUC handles intrastate natural gas and LPG pipelines. 49 CFR Part 195 excludes in-plant piping at refining, manufacturing and storage facilities, so the plant-side piping stays under API 570 and PSM. Oilfield production facilities and their pipelines in Kern County are regulated by the California Geologic Energy Management Division (CalGEM); confirm which rules apply to a given line. Our pipeline inspection page covers the pipeline side.

Air districts. South Coast AQMD and the Bay Area AQMD run refinery leak detection and repair rules and fenceline monitoring; they do not set inspection intervals but they influence when lines can be opened and how leaks are reported. The Cal/OSHA Pressure Vessel Unit regulates boilers and unfired pressure vessels, not process piping.

How Atlantis supports your Authorized Inspector

Direct answer: We execute the NDE scope from the AI's inspection plan, under ASNT Level III-reviewed procedures, with ASNT SNT-TC-1A certified technicians, and deliver a digital report organised by circuit and CML that traces each examination back to its damage mechanism. We are not an Authorized Inspection Agency and we do not supply API-certified inspectors.

1. Scope and DMR link. The AI provides circuits, isometrics with CMLs, methods and the DMR findings behind them.
2. Procedures. An ASNT NDT Level III prepares or reviews each technique, with coverage and reporting criteria from the owner's specification.
3. Fieldwork. Crews mobilise to your site; the schedule is agreed during scoping around permits, unit status, radiography windows and community notifications.
4. Data QA. Readings are compared with history before demobilising; implausible changes and inaccessible CMLs are re-shot or explained.
5. Report. Readings, C-scans, RT images, guided-wave results with follow-up, calibration and instrument records, procedure references and technician certificates in our digital reporting platform, structured so the PSM and CalARP documentation elements (date, examiner, equipment, description, results) are easy to show.
6. AI sign-off. The AI evaluates rates, remaining life and next dates, and signs.

RBI programmes and fitness-for-service assessments are performed by the owner's engineers or a specialist using our data; Atlantis does not offer them. See API 570 piping NDE support and piping circuit and CML inspection.

Planning around turnarounds, conversions and earthquakes

Direct answer: Do thickness, mapping and screening on-stream ahead of turnarounds; treat renewable-fuel conversions and unit idling as changes that need new baselines; and keep a post-earthquake piping walkdown procedure ready. California's mild climate removes hurricane and freeze windows, but permitting and community notification lengthen lead times.

• Ahead of turnarounds: on-stream CML surveys and injection-point mapping, so repair spools and procedures are approved before shutdown.
• Conversions: baseline thickness on circuits changing service, extra CMLs where the DMR expects new mechanisms, and examination of new tie-in welds.
• Idled and decommissioned units: where piping is being mothballed rather than removed, owners often want a documented baseline before preservation; the AI decides what the code requires.
• After earthquakes: VT of supports, guides, anchors and flanged joints, with UT or PT at suspected damage, following the owner's post-event procedure.

Radiography near residential neighbourhoods and port operations needs extra planning, so we often propose UT-based alternatives where the AI accepts them.

API 570 piping inspection support across California

Direct answer: Atlantis supports API 570 programmes across California, with city pages for Los Angeles, San Francisco, San Diego and Bakersfield. Crews are mobilised to your site; the schedule is agreed during scoping.

• Los Angeles Basin and the ports: piping inspection in Los Angeles, pipeline inspection, corrosion inspection and third-party inspection.
• Bay Area: piping inspection in San Francisco and corrosion inspection for Richmond, Martinez, Benicia and Rodeo sites.
• San Diego: piping inspection in San Diego and corrosion inspection for terminals and industrial plants.
• Kern County: third-party inspection in Bakersfield for gas plants, steam and produced-water piping.

Sibling hubs: API 510 pressure vessel inspection in California, API 653 tank inspection in California and NDT inspection services in California. For NDE skills, see ASNT NDT training in California.

Data that stands up to an audit

Direct answer: California auditors ask how each inspection traces to a damage mechanism and a RAGAGEP. We keep your circuit and CML numbering, link each examination to the mechanism it targets, and record instrument, calibration and examiner for every reading, with optional digital twin and ERP views.

Data handed over as loose spreadsheets makes that trace hard to show. We deliver structured data that loads into your inspection database, flag CMLs that could not be read and why, and note where readings moved because of repairs or new spools. Owners can view results in a digital twin of the unit and manage certificates, calibrations and work orders in our inspection-management ERP. Layouts are on NDT report templates; for construction context see ASME B31.3 explained.

What to send us for a California quote

Direct answer: Send circuits and isometrics, the last API 570 report, the AI's plan with the DMR findings behind it, access details and dates. 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 and operating conditions.
2. Isometrics with CMLs, injection points, deadlegs and small-bore connections.
3. Last API 570 report and thickness history.
4. The AI's inspection plan and relevant DMR findings.
5. Access, insulation, temperature and radiography constraints, including community notification needs.
6. Dates, turnaround or conversion schedule, and site requirements (TWIC for port facilities, refinery orientation).

Send us your circuit list for a scope and quote.

Frequently asked questions: API 570 in California

Who does API 570 piping inspection in California?

An API 570 Authorized Piping Inspector employed by the owner or an inspection agency directs and signs it. Qualified examiners perform the NDE. Atlantis performs that NDE and delivers documented results to your AI, who stays inspector of record.

Does Cal/OSHA require API 570?

Not by name. Section 5189.1 requires refinery inspections and tests to meet or exceed RAGAGEP, and section 5189 sets similar mechanical integrity duties for other PSM processes. API 570 is the piping RAGAGEP most California owners adopt.

What is a damage mechanism review and how does it affect piping inspection?

A DMR under section 5189.1 identifies every potential damage mechanism in a refinery process, checks materials and mitigation and is revalidated at least every five years. Its findings should drive CML placement and NDE method choice in the API 570 plan.

How often is piping inspected 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 sets intervals. The historical 1998 edition gave five years for Class 1 thickness; confirm fifth-edition values with your AI.

Can you inspect piping on-stream?

Yes. CML surveys, corrosion mapping, guided-wave screening, profile RT and external VT are normally done on-stream, with high-temperature probes where needed.

Is Atlantis an Authorized Inspector?

No. We are not an Authorized Inspection Agency and we do not supply API-certified inspectors. That keeps the NDE independent of the evaluation.

Where does API 570 stop and pipeline regulation start in California?

49 CFR Part 195 excludes in-plant piping at refineries and storage facilities, so that piping stays under API 570 and Cal/OSHA. Intrastate hazardous-liquid pipelines are regulated by the State Fire Marshal, gas pipelines by the CPUC. The operator documents the boundary.

Do renewable diesel conversions change the piping inspection plan?

Usually. New feedstocks bring different corrosion and fouling mechanisms, so the DMR is revisited and new CMLs and baselines are often needed. The AI and the owner's engineers decide; we provide the baseline data.

What certifications do your technicians hold?

ASNT SNT-TC-1A certification under our written practice, with ASNT NDT Level III oversight; certificates accompany every report.

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

No. RBI and FFS are performed by the owner's engineers or specialists using our data, and Atlantis trains only to ASNT SNT-TC-1A. For the API route see the API inspector career guide, and for NDE skills ASNT Level III training.

How quickly can you mobilise in Los Angeles or the Bay Area?

We quote within 24 hours of receiving the scope information; mobilisation is agreed during scoping around permits and unit schedules.

Next step

For CML surveys, conversion baselines or turnaround 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 California

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

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