API 510 Pressure Vessel Inspection Support in Texas

Short answer: In Texas, API 510 in-service inspection of a pressure vessel is planned and signed by the owner's API 510 Authorized Inspector (AI), usually working inside an owner-user inspection organisation at a refinery, chemical plant or gas processor. Atlantis NDT performs the nondestructive examinations that inspection plan calls for: UT thickness at CMLs, automated corrosion mapping, PAUT and TOFD weld examination, WFMT for wet H2S cracking, RT, MT, PT and VT. Atlantis performs the NDE; your API 510 Authorized Inspector remains inspector of record and signs the inspection report.

Texas is the largest pressure-vessel market in North America, and it is also one of the few large industrial states where the state boiler law does not cover unfired pressure vessels. That combination matters. Most of the columns, drums, reactors, separators and exchanger shells along the Houston Ship Channel, in the Golden Triangle, on the Coastal Bend and across the Permian are inspected because federal process safety rules, insurers and the owners' own mechanical-integrity programmes require it, and API 510 is the recognised and generally accepted good engineering practice (RAGAGEP) those programmes cite. This page maps where that vessel population sits, what API 510 asks for in plain terms, which NDE methods fit Texas service conditions, and exactly where Atlantis fits. If you already have a scope, request an NDE scope for your AI's plan.

Where API 510 pressure vessels are in Texas

Direct answer: Texas API 510 work clusters in five places: the Houston Ship Channel and Galveston Bay refining and petrochemical belt, the Beaumont-Port Arthur-Orange corridor, Corpus Christi and the Coastal Bend, the Permian Basin and Eagle Ford gas-processing plants, and the Freeport-Brazosport chemical complex. Each brings different vessel types, damage mechanisms and turnaround rhythms.

Houston Ship Channel, Pasadena, Deer Park, Baytown and Texas City

The Ship Channel holds a dense cluster of refining and chemical capacity: ExxonMobil Baytown, the Deer Park refinery, Valero Houston, and the Marathon Galveston Bay and Valero refineries at Texas City, surrounded by olefins crackers, polymer plants and specialty chemical units. A single refinery here can carry thousands of registered vessels in its inspection database: crude and vacuum towers, hydrotreater and hydrocracker reactors, FCC regenerators and fractionators, amine contactors and regenerators, sour water strippers, alkylation settlers and acid drums, and the knock-out drums and flare drums that tie it all together. Hydroprocessing reactors bring high-temperature hydrogen attack (HTHA) and weld-overlay disbonding questions; amine and sour water units bring wet H2S cracking; FCC equipment brings creep and thermal fatigue in hot sections. Mont Belvieu, east of Houston, adds NGL fractionators and very large storage bullets and spheres.

Beaumont, Port Arthur and Orange

The Golden Triangle hosts the Motiva Port Arthur refinery, ExxonMobil Beaumont, Valero Port Arthur and the TotalEnergies Port Arthur complex, plus chemical plants along the Neches River and LNG export capacity at Golden Pass and the Port Arthur LNG project. Coker drums, hydrotreaters and sulfur recovery units are typical refinery API 510 scope here, while LNG trains add cryogenic separators, molecular-sieve dehydration vessels and amine pre-treatment, where stainless and low-temperature carbon steels change the method mix toward PT, PAUT and careful UT on austenitic welds.

Corpus Christi, Ingleside and the Coastal Bend

Corpus Christi combines refineries operated by Flint Hills Resources, Valero and Citgo with the Cheniere Corpus Christi LNG terminal and crude export infrastructure at the port and Ingleside. Hot, humid and salty coastal air makes external corrosion and corrosion under insulation (CUI) on insulated vessels a standing item in external inspections, so profile RT, pulsed eddy current screening by specialists and UT prove-up at insulation breaks are common supplements to the AI's visual external inspection.

Permian Basin, Eagle Ford and East Texas gas processing

Around Midland, Odessa, Pecos and in the Eagle Ford, cryogenic gas processing plants, amine treaters, glycol dehydrators, slug catchers, inlet separators and compressor-station scrubbers form a large, geographically spread vessel population. Sour gas and produced water mean wet H2S damage and CO2 corrosion are typical concerns, and many smaller operators run API 510 programmes with a lean inspection team. That is where packaged, code-traceable NDE data saves the AI the most time.

Freeport, Brazosport, Victoria and the chemical belt

Dow's Freeport complex, Freeport LNG, and chemical plants around Victoria, Point Comfort and Chocolate Bayou carry chlor-alkali, ethylene, polymer and specialty units. Caustic service brings caustic stress corrosion cracking concerns; chlorinated service brings stainless pitting and chloride cracking; heat exchanger shells and bundles add ET tube examination where it is in scope. Power plants across the ERCOT grid add deaerators, feedwater heaters and air receivers that often sit under the same owner programme as their boilers.

What API 510 requires, in plain terms

Direct answer: API 510 is the in-service inspection, rating, repair and alteration code for pressure vessels. It requires an inspection plan for each vessel, external inspections, internal or on-stream inspections at intervals tied to corrosion rate and remaining life, pressure-relief device inspection and testing, and controlled repairs, alterations and rerating authorised by the Authorized Inspector.

API 510 is published by the American Petroleum Institute (see api.org; the current edition is the one your programme should adopt, and older editions circulating online are not current). Paraphrased, the code frames intervals as follows. External inspection intervals do not exceed the lesser of five years or the required internal/on-stream interval. Internal or on-stream inspection intervals do not exceed the lesser of one-half the remaining life, calculated from the corrosion rate, or ten years. Where the remaining life is less than four years, the interval may be the full remaining life up to a maximum of two years. Where an owner runs a documented risk-based inspection (RBI) programme meeting the code's conditions, intervals can be set by that assessment instead of the fixed limits. Pressure-relief devices are inspected and tested at intervals that typically do not exceed five years in typical process service and ten years in clean, non-fouling, non-corrosive service, unless documented experience or an RBI evaluation supports longer intervals, following API RP 576.

API 510 also lets an on-stream inspection substitute for an internal inspection when conditions in the code are met, for example when the damage mechanisms are understood, the corrosion is general rather than localised, and the NDE techniques chosen can find the damage that matters. That decision belongs to the AI and the owner's engineers. It is also the main reason NDE quality decides whether a vessel stays on line: the AI can only accept an on-stream inspection if the examinations are well planned, well executed and well documented.

Corrosion rates come from thickness data at condition monitoring locations (CMLs): short-term rates between the last two readings and long-term rates from the baseline. Remaining life is the difference between the actual thickness and the required thickness, divided by the governing rate. Atlantis can calculate those figures from its thickness data for the AI's review, but the interval decision is the AI's and the owner's under the code. The detailed calculation is walked through in our explainer on API 510 interval calculation. For sour service, note that API 510 has no separate wet H2S interval; how damage mechanisms change the plan is covered in API 510 intervals in wet H2S service.

Repairs and alterations must be authorised by the AI, performed by a qualified repair organisation and, where the jurisdiction requires, carried out under the National Board Inspection Code with an R stamp. Because Texas does not regulate unfired vessels, many Texas owners still choose NBIC and R-stamp repairs as their RAGAGEP and as an insurer expectation; your contract and insurer usually settle that.

NDE methods for API 510 work in Texas

Direct answer: UT thickness at CMLs is the backbone of every Texas API 510 programme. Automated corrosion mapping, PAUT and TOFD, WFMT, RT, MT, PT, VT and ET are added where the vessel's damage mechanisms (per API 571) call for them. The table matches each method to the Texas service where it is most often used.

Method selection follows the damage mechanisms the owner's engineers have identified. Our API 571 damage mechanisms guide explains why a sour water stripper and a deaerator, both carbon steel vessels at similar pressures, end up with completely different NDE scopes. For a deeper look at the construction side of vessel NDE, see ASME Section VIII Division 1 NDT. Radiography in Texas is done by crews licensed for industrial radiography with the Texas Department of State Health Services radiation control programme, and Atlantis coordinates RT scope with that in mind rather than relying on a single licence.

How Atlantis supports your Authorized Inspector

Direct answer: We take the vessel scope from the AI's inspection plan, write or review the NDE procedures under ASNT Level III oversight, perform the examinations with ASNT SNT-TC-1A certified technicians, QA the data, and hand the AI a digital report organised by vessel and CML. The AI evaluates, accepts and signs. We are not an Authorized Inspection Agency and we do not supply API-certified inspectors.

That last sentence is deliberate. Many firms in the Houston market sell the API 510 inspector and the NDE crew as one package. Atlantis sells the NDE behind the inspection, so your AI, whether employed by the owner, the owner-user inspection organisation or a third-party agency you already use, gets independent, procedure-controlled data that can be evaluated without wondering who checked whom. The workflow is the same on a single separator in Reeves County or a hundred vessels in a Pasadena turnaround:

1. Scope from the plan. The AI's inspection plan or work list defines vessels, CMLs, inspection type (external, internal, on-stream) and the damage mechanisms of concern. We do not decide what to inspect; we confirm how.
2. Procedures. Written techniques for UT thickness, corrosion mapping, PAUT/TOFD, WFMT and other methods are prepared or reviewed by an ASNT NDT Level III, with calibration blocks and acceptance or reporting criteria taken from the owner's specification.
3. Examinations. Crews mobilise to your site; the schedule is agreed during scoping around permits, isolation and unit status.
4. Data QA. Readings are checked against previous data, anomalies (unexpected thickness gain, sudden rate changes) are flagged for re-shoot before we demobilise.
5. Digital report. CML IDs, readings, C-scan maps, indications with location and size, calibration records, equipment serials and technician certifications, delivered in Atlantis's digital reporting platform.
6. AI evaluation and sign-off. The AI reviews the results, determines corrosion rates, remaining life and the next interval, and signs.
7. Reuse at the next interval. The same CML structure is reused next time, so rates are calculated like-for-like.

Where the owner's engineers run an RBI programme or need a fitness-for-service assessment, our thickness maps and flaw sizing feed those studies; the assessments themselves are performed by the owner's engineers or a specialist. More detail is on our API 510 pressure vessel NDE support and pressure vessel inspection services pages.

Texas regulations that sit on top of API 510

Direct answer: Texas regulates boilers through the Texas Department of Licensing and Regulation (TDLR) Boiler Program, but the Texas boiler law excludes most unfired pressure vessels. For process vessels, the controlling requirement is usually federal: OSHA Process Safety Management, 29 CFR 1910.119(j), with API 510 as the RAGAGEP. Confirm any vessel-specific question with TDLR.

TDLR and the Texas boiler law. Chapter 755 of the Texas Health and Safety Code gives TDLR jurisdiction over boilers. According to the National Board's jurisdictional synopsis, the objects subject to inspection are boilers, and pressure vessels and process steam generators are excluded, except the steam collection or liberation drums of process steam generators. That exception matters in refineries and chemical plants: steam drums on waste-heat and process steam generators come under TDLR's certificate inspection regime and are inspected by commissioned inspectors, while the adjacent unfired vessels follow the owner's API 510 programme. Boilers themselves receive certificate inspections by TDLR deputy inspectors or by commissioned authorized inspectors employed by accredited inspection agencies.

OSHA PSM 1910.119(j). For a process covered by PSM (highly hazardous chemicals above threshold quantities, or flammable liquids and gases above 10,000 pounds), the mechanical integrity element requires written procedures, inspection and testing following RAGAGEP, frequencies consistent with manufacturers' recommendations, good engineering practice and prior operating experience, documentation of every inspection and test, and correction of deficiencies. OSHA enforcement in Texas is federal (Texas has no state OSHA plan for private employers), and the agency's refinery and chemical National Emphasis Programs have repeatedly examined whether vessel inspections follow the API 510 intervals the employer adopted. EPA's Risk Management Program (40 CFR Part 68), Program 3, mirrors the same mechanical integrity requirements.

National Board, NBIC and R stamps. Even without state jurisdiction over vessels, the National Board Inspection Code (NB-23) is widely used in Texas as the repair and alteration standard, and many owners and insurers require repairs by an R-stamp holder. Our explainer API 510 vs NBIC commissioned inspector describes how the two inspector roles differ.

Other bodies at the fence line. The Railroad Commission of Texas regulates intrastate pipelines and gas plants' pipeline connections; the Texas Commission on Environmental Quality handles air permits that drive vessel emissions controls and tank rules. Neither sets API 510 intervals, but both influence turnaround timing and permit conditions. Insurers and their engineering consultants frequently request evidence of API 510 compliance as part of underwriting surveys.

Planning around turnarounds, hurricanes and operations in Texas

Direct answer: Plan internal inspections around turnaround windows, push as much as possible into on-stream NDE beforehand, and keep the Gulf hurricane season (June to November) in mind for coastal sites. Pre-turnaround corrosion mapping often decides which vessels must be opened.

Gulf Coast refiners traditionally cluster turnarounds in the spring and autumn shoulder seasons, when gasoline and heating demand are lowest. That compresses demand for NDE crews, scaffolding, confined-space attendants and radiography into a few weeks, so the plants that win are the ones that move scope out of the turnaround. A practical sequence for a Texas unit:

• Six to twelve months out: on-stream UT and corrosion mapping on vessels whose internal inspection is due, so the AI can decide whether an on-stream inspection can substitute or whether the vessel must be opened.
• During pre-turnaround planning: PAUT or TOFD on welds of concern from outside, so repair materials and procedures are ready before the unit comes down.
• During the turnaround: internal VT by the AI, WFMT on internal welds in wet H2S and amine service, thickness verification at internal CMLs, ET on bundles pulled to the pad, and RT or UT of repair welds.
• After start-up: baseline readings at new CMLs and on repaired areas so the next interval starts with good data.

Coastal plants also need to plan around tropical storms: unit shutdowns ahead of a storm, flood exposure of insulation and supports, and post-storm external inspections of vessels that were submerged or struck by debris. Permian and Eagle Ford gas plants have a different constraint: distance and summer heat, which makes efficient mobilisation and well-packaged reporting more valuable than speed of a single shot. Winter freeze events, as in February 2021, are an argument for checking deadleg-type nozzles and instrument connections on vessels after a hard freeze.

API 510 inspection support across Texas

Direct answer: Atlantis supports API 510 programmes across Texas, with city pages for Houston, Beaumont, Corpus Christi and Dallas. Crews are mobilised to your site; the schedule is agreed during scoping.

• Houston and the Ship Channel: see pressure vessel inspection in Houston, with related piping, tank and third-party inspection support. Nearby refining towns: Deer Park, Baytown and Galveston.
• Beaumont and Port Arthur: pressure vessel inspection in Beaumont, plus corrosion inspection, piping and third-party inspection.
• Corpus Christi and the Coastal Bend: pressure vessel inspection in Corpus Christi, corrosion inspection, weld inspection and third-party inspection.
• Dallas-Fort Worth: pressure vessel inspection in Dallas for manufacturing, power and chemical distribution, plus Fort Worth third-party inspection.
• Permian Basin: gas-plant and compressor-station vessels around Midland; Central Texas through Austin.

The same Texas sites usually need piping and tank work too. The sibling hubs API 570 piping inspection in Texas and API 653 tank inspection in Texas cover those codes, and NDT inspection services in Texas covers the full method range. For crews who want to grow their own NDE capability, see ASNT NDT training in Texas.

Data that outlasts the turnaround

Direct answer: API 510 depends on trends, so the report format matters as much as the readings. Atlantis delivers vessel data in a structured digital platform, with optional inspection-management ERP and a digital twin view, so the next interval starts from a clean baseline.

Texas owners often inherit vessel files from several previous contractors: spreadsheets with renamed CMLs, PDFs with handwritten readings, film in storage. Corrosion rates computed across inconsistent CML names are where interval errors begin. We keep the owner's CML numbering, record the probe, instrument and calibration for each reading, and flag any location where the reading could not be taken and why. Owners who want a visual model can link results to a digital twin of the unit, and teams tracking certificates, calibration and work orders can use our inspection-management ERP. Report formats are described on NDT report templates, and the API 510 workflow inside a twin is explained in digital twin for pressure vessels.

What to send us for a Texas quote

Direct answer: Send the vessel list, the AI's plan or CML map, the last inspection report, access status and target dates. We return questions or a scope, and a quote within 24 hours of having what we need.

1. Vessel list with tag numbers, U-1 data reports or nameplate data, drawings and materials.
2. The most recent API 510 inspection report and thickness history.
3. The AI's inspection plan, CML map and the damage mechanisms of concern (wet H2S, amine, caustic, HTHA, CUI).
4. Inspection type: external, internal or on-stream; whether the vessel will be cleaned, gas-freed and open.
5. Access: scaffolding, rope access, insulation removal, surface temperature.
6. Dates, turnaround window and site safety requirements (TWIC for port facilities, site orientation).

Ready? Send us your vessel list and we will reply with questions or a scope.

Frequently asked questions: API 510 in Texas

Who can perform an API 510 inspection in Texas?

The inspection is directed and signed by an API 510 Authorized Inspector employed by the owner-user, an owner-user inspection organisation or an authorized inspection agency. NDE within the inspection is performed by qualified examiners, typically certified to the employer's SNT-TC-1A written practice. Atlantis performs that NDE and hands the results to your AI; we do not act as the inspector of record.

Does Texas require API 510 inspections by law?

Not through the state boiler law: TDLR regulates boilers, and the Texas boiler law excludes most unfired pressure vessels apart from steam drums on process steam generators. In practice, OSHA PSM 1910.119(j), EPA RMP and insurers make API 510 the expected practice for process vessels. Confirm any specific vessel with TDLR and your PSM coordinator.

How often does a pressure vessel need inspection under API 510?

External inspection at the lesser of five years or the internal interval; internal or on-stream inspection at the lesser of half the remaining life or ten years, with a two-year cap when remaining life is under four years. An RBI programme meeting the code's conditions can set different intervals. The AI makes the call.

Is Atlantis an Authorized Inspector?

No. We are not an Authorized Inspection Agency and we do not supply API-certified inspectors. That separation is useful: your AI receives independent NDE data, with procedures and certifications on file, and keeps full control of evaluation and sign-off.

Can you inspect vessels while the unit stays in service?

Yes, many examinations are done on-stream: UT thickness, corrosion mapping, PAUT and TOFD from the outside, profile RT and external VT support. Whether the on-stream inspection can replace an internal inspection is the AI's decision under API 510. Hot surfaces need high-temperature couplant and probes, which we plan during scoping.

What NDE do you use for wet H2S cracking in Texas amine and sour water units?

Internally, WFMT on welds and heat-affected zones after surface preparation; externally, automated UT corrosion mapping to find HIC, blistering and stepwise cracking in plate, and PAUT or TOFD to size weld cracking. The damage mechanism review sets the coverage; we execute and report it.

Can you inspect pressure vessels in the Permian Basin?

Yes. We perform the NDE for your API 510 programme; your API Authorized Inspector remains inspector of record. Gas plants, amine treaters, separators and scrubbers in the Permian and Eagle Ford are well suited to on-stream UT and corrosion mapping. Crews are mobilised to your site and the schedule is agreed during scoping, often combining several plants in one trip.

What certifications do your NDE technicians hold?

Technicians are certified under an ASNT SNT-TC-1A written practice and work under ASNT NDT Level III oversight. Certificates and eye-test records are included with the report so your AI and PSM auditors can verify qualification.

What will the API 510 report contain?

Vessel and CML identifiers matching your database, readings, C-scan maps, indication locations and sizes, photographs, calibration and equipment records, procedure references and technician certifications, delivered digitally. Corrosion rates and remaining life can be calculated from our data for the AI's review.

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

No. We supply the inspection data those studies rely on. RBI (API 580/581) and fitness-for-service (API 579) assessments are performed by the owner's engineers or a specialist firm using that data.

Do you offer API 510 certification training?

No. Atlantis trains NDT personnel to ASNT SNT-TC-1A only. For the API inspector route, see the API inspector career guide; for NDE skills, see NDT training in Texas or ASNT Level III training.

How quickly can you mobilise to Houston, Beaumont or Corpus Christi?

We quote within 24 hours once we have the scope information, and the mobilisation date is agreed during scoping around your permits, unit status and turnaround schedule.

Next step

If your Texas vessels are approaching an internal inspection date, or you want on-stream data before the next turnaround, book a scoping call. For a full turnaround package, get a quote within 24 hours. Atlantis performs the NDE; your API 510 Authorized Inspector remains inspector of record and signs the inspection report.

More Atlantis NDT services in Texas

• NDT training and certification in Texas
• Level III consulting in Texas
• NDT inspection services in Texas
• API 653 storage tank inspection support in Texas
• API 570 piping inspection support in Texas
• NDT ERP software in Texas
• Practical NDT simulator in Texas

Part of the full range of pressure vessel inspection services from Atlantis NDT.