The Named Level III Behind a Corpus Christi Examination Program
A Level III of record is the individual named in your written practice who approves NDT procedures, qualifies techniques, administers certification examinations and signs certificates. In Corpus Christi that authority carries refinery turnarounds, crude and LNG export terminals, the Gregory ethane cracker corridor, Ingleside fabrication yards and Sinton steelmaking — each with a different code and a different regulator.
Corpus Christi does not behave like a generic Gulf Coast market. Three refineries run inside the city limits — CITGO, Valero and Flint Hills Resources — while the Port of Corpus Christi moves more crude for export than any other US port, which puts an unusual share of the examination workload on dock piping, loading arms and storage tank bottoms rather than on process units. North across the harbor, San Patricio County added an ethane cracker at Gregory, LNG liquefaction on the La Quinta Channel, hot briquetted iron at Portland and a flat-roll steel mill at Sinton, all within a few years. Ingleside runs crude export and heavy offshore fabrication. Corpus Christi Army Depot rebuilds rotorcraft under an aviation qualification regime that shares almost nothing with the refineries. One Level III of record has to be fluent across all of it, or honest about which parts he is not.
Source: Scoped against ASNT SNT-TC-1A and ANSI/ASNT CP-189 for personnel qualification; ASME Boiler and Pressure Vessel Code Sections V, VIII and IX; ASME B31.3 and B31.4; API 510, 570, 571, 577, 578, 580/581, 653 and API 1104; AWS D1.1 for structural welding; NFPA 59A and 49 CFR Part 193 for LNG facilities; 49 CFR Parts 192 and 195 for pipelines; OSHA process safety management at 29 CFR 1910.119; NAS 410 where aviation qualification applies. Jurisdiction in the Coastal Bend: federal OSHA (Texas has no state plan for private industry), the Texas Commission on Environmental Quality, the Railroad Commission of Texas for intrastate pipelines, PHMSA for interstate and LNG, the US Coast Guard for waterfront facilities, and the Texas Department of Licensing and Regulation for the state boiler program.
| Sector and local footprint | Typical examination scope | Governing code or regime | What the Level III of record approves |
|---|---|---|---|
| Refining — CITGO, Valero and Flint Hills Resources plants in and around the city | Turnaround weld examination, thickness monitoring, fired heater tubes, wet H2S and amine circuits, tank floors | ASME Section VIII and B31.3 for the equipment; API 510, 570, 653, 571 and 577 in service; OSHA PSM | Procedures for UT, RT, MT, PT and VT; damage-mechanism-specific techniques; certification of examiners; acceptance of contractor certifications before mobilization |
| Crude and product export — inner harbor docks, Ingleside terminals, Harbor Island | Dock and jetty piping, loading arms, manifolds, above-ground storage tanks, marine loading structures | API 570 and 653; ASME B31.4; US Coast Guard waterfront facility rules | Thickness survey procedures that survive coating, tank floor scanning technique qualification, structural VT procedures for marine loading structures |
| LNG liquefaction — La Quinta Channel trains | Cryogenic austenitic stainless piping, 9% nickel steel tankage, aluminium cold-box internals | 49 CFR Part 193, NFPA 59A, ASME Section VIII and B31.3 | Procedures qualified on cryogenic materials, not carbon steel; personnel demonstrated on austenitic and 9% nickel weld metal |
| Petrochemical — ethane cracking and derivatives at Gregory and San Patricio County | Furnace tubes, transfer line exchangers, high-temperature circuits, polymer trains | ASME Section VIII, B31.3, API 571 and 579 | Creep and high-temperature damage examination techniques, procedure revision control across construction-to-operations handover |
| Steel and iron — flat-roll mill at Sinton, hot briquetted iron at Portland | Plate lamination checks, crane and structural welds, pressure equipment supporting the mill | ASTM A435 and A578 for plate; AWS D1.1 for structure; ASME for pressure equipment | Straight-beam lamination procedures, structural UT and MT procedures, examiner certification for mill conditions |
| Offshore and marine fabrication — Ingleside yards | Thick-section complete-joint-penetration welds, node and tubular joints, heavy lifts | AWS D1.1; owner and classification requirements; API structural practice | Ultrasonic procedures for thick section and tubular geometry, technique qualification on representative mockups, welder-supporting examination records |
| Midstream — Eagle Ford gathering and export pipelines into the port | Girth weld radiography and ultrasonics, in-service piping, station facilities | API 1104; 49 CFR Parts 192 and 195; Railroad Commission or PHMSA depending on jurisdiction | Girth weld examination procedures, automated ultrasonic technique qualification, certification of NDT personnel to the standard API 1104 invokes |
| Rotorcraft depot maintenance — Corpus Christi Army Depot at NAS Corpus Christi | Fluorescent penetrant, eddy current on aluminium structure, bond and composite inspection | NAS 410 and government technical publications, not SNT-TC-1A | A different qualification regime entirely; treated as separate authority and never blended into an industrial written practice |
What a Level III of record does, and what the title does not include
The appointment is continuing. A Level III of record is written into the employer's practice by name, with the methods their authority covers stated explicitly, and from that point every procedure revision, every technique qualification, every examination administered and every certificate issued in those methods traces back to them. It is materially different from commissioning a Level III to review a procedure once. A review produces an opinion; an appointment produces accountability that persists between engagements and survives staff turnover.
The scope of the authority is technical and documentary. The Level III decides whether the ultrasonic procedure will actually find the damage mechanism the corrosion engineer is worried about, whether a technique needs demonstration before it is used on the production geometry, whether a candidate's practical examination was a pass, and whether an outside certification can be accepted or has to be re-examined on site. Where a client's technical auditor challenges an examination record, the Level III is who answers on the technical question.
Three roles get conflated constantly on the Gulf Coast, and the distinction is worth stating plainly. The API 510, 570 or 653 inspector authorizes and signs the in-service inspection. The NDT technician is certified under the employer's written practice to SNT-TC-1A or CP-189 and performs the examination. The ASNT Level III approves the procedures the technician works to and the written practice itself. Atlantis supplies the third role. It does not act as the API inspector of record and it is not a process safety management auditor.
Refining and the inner harbor: what the examination workload actually looks like
Corpus Christi carries three refineries — CITGO, Valero and Flint Hills Resources — sitting close to the inner harbor rather than scattered across a coastal plain. The consequence for an examination program is that turnaround labour, inspection contractors and scaffolding capacity are competed for locally and seasonally. When two of the three run outages in the same spring window, contractor technicians circulate between them, and every one of those technicians arrives holding a certificate issued by an employer that is not you.
The technical scope in these units is familiar in kind and specific in detail: wet hydrogen sulfide circuits demanding examination for hydrogen-induced and stress-oriented hydrogen-induced cracking, amine service, sulfidation on hot circuits, corrosion under insulation on intermittent and dead-leg service, fired heater tubes, and the crude-slate shifts that this port has seen since light shale barrels started moving through it — a change of feedstock changes the damage mechanism list, and the examination program should change with it rather than a year later.
The Level III's contribution here is not doing the scanning. It is deciding that a damage mechanism the corrosion engineer has flagged in an API 571-informed review requires a technique the current procedure does not describe, writing that procedure, qualifying it if the code or the owner specification demands demonstration, and certifying that the technicians on site can execute it. Done late, that sequence collides with the outage. Done early, it is quiet work in an office.
North of the harbor: cracker, LNG, steel and iron
San Patricio County has been rebuilt industrially inside a decade. The ExxonMobil–SABIC Gulf Coast Growth Ventures ethane cracker at Gregory, LNG liquefaction on the La Quinta Channel, voestalpine's hot briquetted iron plant at Portland and the Steel Dynamics flat-roll mill at Sinton together represent an examination population that did not exist in the region before, and one whose materials are not the carbon steel a refinery program is written around.
LNG is the clearest example. Cryogenic service means austenitic stainless piping, 9 percent nickel storage tankage and aluminium cold-box internals, all governed by 49 CFR Part 193 and NFPA 59A on top of the ASME construction codes. An ultrasonic procedure qualified on carbon steel is not evidence of anything on austenitic weld metal, and personnel who have only examined carbon steel welds have not demonstrated the ability to interpret indications where coarse columnar grain scatters and skews the beam. That has to be resolved in the procedure and the certification file, not on the pipe rack.
Steelmaking brings a third population again — plate lamination examination to ASTM A435 or A578, structural welding under AWS D1.1, crane and runway structure, and the pressure equipment supporting the mill. The mistake in a multi-asset region is a single generic procedure set stretched across all of it. The right structure is one written practice with method scopes annexed by asset class, so that the same document governs a cracker furnace, an LNG train and a mill without pretending they are the same job.
Ingleside, Harbor Island and the export docks
The Port of Corpus Christi is the largest crude export gateway in the United States, and that fact reshapes the inspection portfolio. A refinery program is dominated by process equipment; an export terminal program is dominated by piping runs to the dock, loading arms and manifolds, above-ground storage tanks, and the marine structures that carry them. The codes shift accordingly — API 570 and 653 dominate, ASME B31.4 governs much of the liquid pipeline scope, and the US Coast Guard has an interest in the waterfront facility that the refinery inspector never has to think about.
Dock piping is the quiet problem. It is coated, it is in a marine atmosphere carrying salt, and it is often the least accessible pipe on the site. Thickness surveys taken through heavy coating with a single-echo gauge overstate remaining wall by the coating thickness, and the error compounds across a monitoring history until a circuit that looked stable is not. A procedure that specifies echo-to-echo measurement and states how coating is handled is a small clause that protects a large decision.
Ingleside also runs heavy fabrication. Thick-section complete-joint-penetration welds, tubular and node geometry and heavy structural assemblies bring AWS D1.1 and owner structural specifications into the same regional market as the process codes. Fabrication ultrasonics on thick sections and complex geometry is a distinct competence — the technique qualification on representative mockups is not optional in the way people sometimes treat it, and the Level III who signs it should have set up those mockups before.
Who regulates what in Nueces and San Patricio counties
Texas has no state OSHA plan covering private industry, so process safety management enforcement is federal, and the refining and chemical national emphasis activity has been a real presence on this coast. Mechanical integrity is the element that reaches the NDT program: records of who performed each inspection, under what qualification, following what recognised practice. That is a written practice question presented as a regulatory one.
Environmental permitting, including leak detection and repair obligations that intersect with inspection scheduling, sits with the Texas Commission on Environmental Quality. Pipeline jurisdiction splits — the Railroad Commission of Texas takes intrastate lines, PHMSA takes interstate transmission and LNG facilities, and a gathering system feeding an export terminal can touch both. Waterfront facilities answer to the US Coast Guard sector. The state boiler program is administered by the Texas Department of Licensing and Regulation, with certificate inspections performed by authorized or National Board commissioned inspectors.
None of these agencies certifies NDT personnel, and that is exactly why the written practice matters so much here. There is no state licence to fall back on. The qualification of the person who took the reading is established by your document and nothing else, which is why an examination record with no traceable certification behind it is not a paperwork problem but an evidentiary one.
Turnaround cadence: engaging the authority at the right time
The economics of a Gulf Coast outage are brutal and well understood, and they distort how technical authority gets bought. Sites budget for the outage window and engage everyone inside it. But the work only a Level III can do is nearly all pre-mobilization: reviewing and revising procedures against the current damage mechanism list, qualifying any technique that will be used for the first time, administering specific and practical examinations to contractor technicians whose certifications you intend to accept, and closing the acceptance records for the ones you do not intend to re-examine.
Eight to twelve weeks ahead is the workable window. It allows a mockup to be fabricated if a technique demonstration is required, it gives time for a procedure revision to move through document control and actually reach the field copies, and it means the first day of the outage begins with a certified crew rather than a queue at the training trailer. Sites that compress this into the outage itself end up accepting certifications they have not evaluated, which is the exact finding a client's technical audit will pick up six months later.
There is a second cadence in this region: hurricane season. Post-storm condition assessment on tankage, dock structures and insulated circuits generates a burst of examination demand with no planning runway at all. A program with current procedures and a certified roster absorbs that. A program that is already behind does not, and improvises — which is how methods enter a site without ever entering the written practice.
Coastal Bend failure modes that shape procedure approval
Salt-laden marine air is the region's signature. External corrosion under insulation on cold and intermittent service is the highest-value inspection problem on most Coastal Bend sites, and it is one where the technique choice is genuinely contested — insulation removal, profile radiography, real-time radiography, pulsed eddy current, or a risk-informed sampling plan built on API 580/581 thinking. Whichever route is chosen, note the trap: pulsed eddy current is not one of the methods most written practices list, so certifying anyone to use it requires the practice to define it first.
Chloride stress-corrosion cracking on austenitic stainless is the second. It is initiated by chlorides and heat, and the marine environment supplies the chlorides free of charge; so, occasionally, does a couplant chosen for price. A procedure that specifies halide-controlled couplant on austenitic surfaces is cheap insurance against a failure that will be blamed on everything except the inspection consumable.
Wet hydrogen sulfide damage in refining, high-temperature damage in cracking furnaces, and fatigue in marine loading structures round out the list. Each drives a different examination approach, and the coherent way to run a program is to let the damage mechanism review drive the procedure set rather than letting a generic procedure set define what gets looked for. That inversion — mechanisms first, methods second — is the single most useful thing an experienced Level III brings to a first engagement.
Structuring the engagement
A Level III of record arrangement is normally a retained appointment: the written practice names the individual and the methods, a defined response commitment covers procedure approvals and examination administration, pre-turnaround work is scheduled to the outage calendar rather than to the outage, and on-site presence is arranged where mockup qualification, practical examinations or audit representation require it. Remote work covers more of it than people expect; procedure development, record review and examination grading do not require standing in the unit.
Atlantis NDT is founder-led — ASNT NDT Level III in multiple methods and API 653 Authorized Inspector — and works as an independent technical authority: written practice ownership, procedure development and qualification, personnel certification within the practice, technical representation in audits, and independent review of inspection data where a result is contested. It does not act as the API inspector of record and does not perform PSM audits.
Affordable, accessible and fully customizable, mobilised to the Coastal Bend for the work that needs to be on site and handled remotely for the work that does not. To discuss an appointment, a written practice review or turnaround readiness, write to info@atlantisndt.com and ask for a consultation. Bring your current practice revision, the method list you actually run, and your outage calendar.
What does 'of record' actually mean in a written practice?
It means a named individual, identified by name and certification, whom the document holds responsible for approving procedures, qualifying techniques, setting and grading examinations, and signing certifications in stated methods. It is a continuing appointment, not a review. The practical test: if an auditor asks who approved revision 4 of your UT procedure and why, the Level III of record is the person who has to answer.
Can the Level III of record be a contractor rather than an employee?
Yes, and in most Coastal Bend operations that is the normal arrangement — few sites carry a staff Level III in every method they run. SNT-TC-1A contemplates an outside Level III used by the employer. What matters is that the written practice names the person, defines the scope of methods, and shows the employer retains responsibility for the program rather than outsourcing accountability along with the signature.
Which regulators have jurisdiction over Corpus Christi inspection work?
Several, and they do not overlap neatly. Federal OSHA runs process safety management in Texas, since Texas has no state plan covering private industry. TCEQ handles air and environmental permits, including leak detection and repair. The Railroad Commission of Texas regulates intrastate pipelines while PHMSA takes interstate and LNG. The US Coast Guard governs waterfront facilities, and TDLR administers the state boiler program.
When in the turnaround cycle should a Level III be engaged?
Eight to twelve weeks before mobilization, not during. The work that only a Level III can do — approving revised procedures, qualifying a technique on a representative mockup, examining and certifying contractor technicians, accepting outside certifications — all has to be finished before the first scaffold goes up. Sites that call in the authority on day three of the outage buy availability, not readiness, and pay for both.
Does the Level III of record sign the API 510 or 653 inspection report?
No. The API 510, 570 or 653 inspector authorizes and signs the in-service inspection and the fitness decision. The NDT technician performs the examination under a certification issued through the written practice. The Level III approves the procedure the technician followed and the practice the certificate came from. Three roles, three signatures, and audits go badly when one person's name is used for all three.
Is API 510, 570 or 653 inspector certification training part of a Level III of record engagement?
No — that certification comes from API's own examination program and sits outside this scope entirely. A Level III of record engagement covers the NDT program: the written practice, procedure development and qualification, technique sheets, examination and certification of technicians, and technical representation when a client or auditor questions the examination record. The API inspector remains your employee or your contracted inspector, unaffected by this arrangement.