Technical authority for NDT programmes on the Houston Ship Channel
A Level III of record is the individual named in your written practice who approves procedures, writes and grades examinations, certifies your technicians, and answers to a client auditor. Deer Park work means Ship Channel refining, olefins and terminal storage, where the practical authority over a vessel or tank is OSHA process safety management and API code, not a Texas vessel inspector.
Deer Park sits on the Houston Ship Channel between Pasadena and La Porte: a refinery of roughly a third of a million barrels a day now operated by Pemex, an adjacent olefins and chemicals complex, and one of the densest concentrations of bulk liquid storage terminals in North America, including the Intercontinental Terminals site whose 2019 tank fire reset how Harris County and federal OSHA look at terminal mechanical integrity. Texas licenses boilers through the Department of Licensing and Regulation, but it does not run a general in-service pressure vessel jurisdiction. That absence matters. For a Deer Park vessel or tank, the enforceable standard is the process safety management rule's mechanical integrity element and the API codes it points to, which means the defensibility of your inspection data rests on the written practice, the procedures, and the Level III who approved both.
Source: Positioned against OSHA 29 CFR 1910.119 process safety management, including the mechanical integrity element and its reliance on recognised and generally accepted good engineering practice; API 510, API 570 and API 653 with supporting recommended practices API RP 571, 575, 577 and 580/581; ASME Boiler and Pressure Vessel Code Sections V, VIII and IX; ASNT SNT-TC-1A and ANSI/ASNT CP-189 for personnel qualification and certification; the National Board Inspection Code NB-23 for repair and alteration; the Texas Boiler Law administered by the Texas Department of Licensing and Regulation; and AWS D1.1 where structural welding is in scope. Jurisdictional statements describe Texas practice and should be confirmed for each specific asset.
| Duty | Code or client driver | Evidence produced | Finding that recurs in Deer Park audits |
|---|---|---|---|
| Approve NDT procedures and techniques | ASME Section V personnel and procedure requirements, plus the owner specification in the contract | Signed and dated revision-controlled procedure with the essential variables separately tabled | Procedure signed by a Level III who has never seen the equipment, the access, or the surface condition involved |
| Own and maintain the written practice | ASNT SNT-TC-1A or CP-189 as invoked by the client contract or the repair organisation quality manual | Current revision with stated exceptions, distribution list and revision history | The revision on site is older than the one filed with the client during prequalification |
| Write, administer and grade examinations | SNT-TC-1A or CP-189 examination requirements for general, specific and practical parts | Controlled question bank, graded papers, practical checklist against a representative specimen | Grading performed by an administrator and countersigned by the Level III weeks later |
| Certify Level I and II personnel | Employer certification under the written practice, verified by the client before site access | Certificates naming method, level, stated limitations and expiry date | Thickness-limited UT certificates used for weld shear wave scanning during a turnaround |
| Independent review of inspection data | API 510, 570 and 653 inspection plans, and OSHA process safety management mechanical integrity | Documented data review, resolution of indications, retained scan files and radiographs | Nobody above Level II ever reviewed the outage data set before it went into the equipment file |
| Represent the programme in client and third party audits | Contractor prequalification and client QA audit of the NDT programme | Attendance record, corrective action responses, closure evidence with dates | The named Level III is unreachable during turnaround season, which is exactly when audits happen |
Deer Park: what the industrial base actually is
Deer Park is a small city in Harris County wedged between Pasadena and La Porte on the south bank of the Houston Ship Channel, and its industrial base is out of all proportion to its size. The anchor is the Deer Park refinery, a facility of roughly a third of a million barrels per day that Shell built and operated for decades and that has been wholly owned and operated by Pemex since 2021, alongside an adjacent olefins and chemicals complex that has run as a separate operating entity from the fuels refinery.
The second layer is storage and marine transfer. Deer Park and the surrounding channel frontage hold one of the densest concentrations of bulk liquid terminals in North America, handling refined products, petrochemical intermediates, aromatics and blendstocks. The Intercontinental Terminals Company site in Deer Park is the best known of them for the wrong reason: the March 2019 tank fire that burned for days, drew federal investigators, and permanently changed how Harris County agencies, insurers and federal OSHA regard terminal mechanical integrity and tank inspection records in this corridor.
The third layer is everything within a short drive. Pasadena and La Porte carry refining, chemicals and container terminal operations; Baytown across the channel holds one of the largest integrated refining and chemical complexes in the country; Texas City sits further down the bay. For an NDT service company, this is not a market with one anchor client. It is a market where a single crew can work a refinery turnaround, a terminal tank floor and a chemical plant piping circuit inside one month, under three different owner specifications.
Who has jurisdiction here, and who does not
Texas has a boiler law. The Texas Department of Licensing and Regulation administers it, requires certificate inspections at set intervals, and expects repairs and alterations to follow the National Board Inspection Code, normally by an organisation holding the appropriate National Board certificate of authorisation. If your Deer Park scope includes boilers, that programme is the jurisdictional hook and it is real.
What Texas does not operate is a general in-service jurisdiction over process pressure vessels, piping and storage tanks of the kind that fill a refinery or a terminal. There is no state inspector coming to look at a coker drum or a floating roof tank. That absence is the single most important local fact for an NDT programme, because it means the enforceable requirement comes from somewhere else entirely: federal OSHA, under the process safety management standard at 29 CFR 1910.119, and specifically its mechanical integrity element, which requires inspection and testing to follow recognised and generally accepted good engineering practice and to be performed by trained and qualified personnel.
In practice that routes straight to the API codes. API 510 for vessels, API 570 for piping, API 653 for aboveground storage tanks, with API RP 571 for damage mechanisms and API RP 580 and 581 where risk based inspection is in use. The consequence for you is direct: when an OSHA compliance officer or a client's process safety group asks how you know the person who took that thickness reading was qualified, the answer is your written practice and the Level III who signed it. There is no state certificate to point at instead.
What being of record commits the Level III to
The phrase of record means the name appears in the written practice as the individual holding technical authority for the NDT programme, and it carries a defined set of obligations rather than a general willingness to help. Procedures are approved with a signature and a date, against a stated code basis, with essential variables identified so that later changes route correctly. Examinations are authored, controlled, administered and graded. Practical examinations are conducted on representative specimens. Certification is recommended on evidence, not on tenure.
Beyond the paperwork there is judgement work that only a Level III can do. Technique selection when the standard approach will not reach: an insulated line that cannot be stripped, a weld with a counterbore that generates a geometric echo at exactly the wrong place, an overlay that kills a shear wave, a nozzle where the scan surface simply does not exist. Resolution of indications where a Level II has called something the client disputes. Review of an outage data set before it becomes the baseline for the next inspection interval.
And there is representation. When a client's QA group audits your NDT programme, or a third party surveys your repair organisation, the Level III is the person who answers. That is not an administrative appearance; the auditor will ask why a particular exception to SNT-TC-1A was taken, why a technique was demonstrated the way it was, and what happened to the finding raised last year. Someone has to be able to answer those questions from knowledge.
The absentee Level III, and how an audit exposes it
There is a well known arrangement in this market where a Level III certificate is rented. A name goes on the written practice, procedures arrive by email and come back signed, and nobody sets foot on site. It is cheap, it is common, and it collapses the first time a serious client audits the programme, because the audit does not test the paperwork in isolation. It tests whether the authority the paperwork claims was actually exercised.
The tells are consistent. Procedures signed on dates when the Level III was demonstrably elsewhere and describing equipment the company does not own. A question bank that has not changed in years, with a specific examination that asks about instruments nobody on the crew has seen. Practical examination records with no specimen described and no grading checklist. Certificates issued in the Level III's name, printed and signed by an administrator. A Level III whose own certification has lapsed in one of the methods he is approving procedures in.
The consequence is not just a finding. On the Ship Channel, a client QA group that concludes your technical authority is nominal will suspend you from the approved bidder list, and reinstatement takes a corrective action programme and an on-site follow-up. Losing a turnaround window because your programme could not survive a two-hour audit is a far larger cost than the engagement that would have prevented it.
Turnaround season and the availability problem
Gulf Coast turnaround work concentrates in spring and autumn, and Deer Park sits at the centre of it. A refinery turnaround runs continuously, with NDT crews on shift around the clock, hundreds of welds and thousands of thickness locations, and a schedule where a day of delay is measured against lost production. This is the environment in which the questions that genuinely need a Level III arrive, and they arrive at inconvenient hours.
A typical night shift call: a technician has an indication in a weld that does not fit the geometry, the client's inspector wants a call before the joint is buried behind insulation, and the alternative to a decision is stopping the critical path. Another: access has changed since the scan plan was written and the approved procedure no longer covers the scan surface available, which is an essential variable change requiring a documented revision rather than an informal nod. Another: a subcontracted crew has arrived with certificates the site has never verified.
So availability is a contract term, not a soft commitment. An engagement worth having states a same day response for technical calls, defines what counts as an emergency, sets a window for attending a client audit in person, and specifies a minimum number of site visits and examination sessions per year so that certification and practical assessment work does not pile up into an unworkable block in December.
Tanks and terminals: where NDT programmes usually fail here
Terminal work in this corridor is dominated by aboveground storage tanks, and API 653 out-of-service inspection generates a specific set of NDT problems that a general refinery programme handles badly. Floor scanning by magnetic flux leakage covers large areas quickly, but the number that matters is the detection threshold, and that threshold has to be established on a calibration plate with machined defects of known depth, in plate of the same thickness and coating condition, and re-verified during the scan. A procedure without a stated and verified threshold produces a floor map that means nothing.
The prove-up step is where programmes come apart. MFL identifies areas of interest; ultrasonic prove-up establishes remaining thickness at those areas; and the two data sets have to be reconciled by someone competent to do it before a floor is accepted, patched or replaced. If the prove-up procedure does not specify probe type, gate setting, surface preparation and the rule for reporting a minimum from a cluster of readings, two technicians will produce two different answers on the same plate.
Shell course work adds its own traps: settlement survey arithmetic, roof and shell thickness at courses that were never uniform to begin with, and vacuum box testing of lap welds where the soap solution and the vacuum level are rarely specified. The Level III of record's job is to make sure these procedures exist, are demonstrated, and are actually the ones on the tank floor rather than a generic document in the office.
Contractor gates: prequalification, client QA and the written practice
Getting onto a Ship Channel site is a documented process before it is a commercial one. Contractor prequalification platforms of the sort headquartered in Houston and used across this corridor grade safety, insurance and programme documentation, and the NDT programme surfaces there as well as in the client's own QA review. A low grade or an open finding can keep a crew off site regardless of the contract.
Client QA reviews go deeper than the platform questionnaire. Expect them to ask for the written practice with its revision history, a sample of procedures with signatures and dates, the certification records of named individuals, the calibration status of the equipment, and evidence that the Level III named in the practice is currently certified in every method claimed. Where the work touches a National Board repair, the survey team will want the same documents tied to the quality manual.
The efficient move is to prepare that package once and keep it current, rather than assembling it under pressure each time a new client asks. A well maintained programme answers a prequalification request in a day. A neglected one turns every new client into a two-week scramble, which is itself a signal auditors read accurately.
How the Atlantis Level III of record engagement works
We begin with a gap review: the written practice against the work actually performed, procedures against the referencing codes and the owner specifications you are contractually exposed to, the certification population against expiry dates and stated limitations, and the examination material against the equipment in your store. That review produces a dated finding list you can act on before anyone else audits you.
We are then named in the written practice, with the methods stated explicitly, and we do the work: procedure development and revision under control, examination authorship and grading, on-site practical examinations against representative specimens, certification recommendations, independent review of outage data sets, and attendance at client and third party audits with corrective action responses tracked to closure. Scope, response times and site visit frequency are written into the agreement rather than assumed.
The boundaries are stated plainly. Atlantis is not a process safety management auditor and does not act as the API inspector of record; those are separate roles held by separately certified individuals. What we supply is NDT technical authority: the practice, the procedures, personnel certification within the practice, independent data review, and someone who can answer a technical question at three in the morning during a Deer Park turnaround. To discuss a Level III of record engagement or a programme gap review, contact info@atlantisndt.com for a consultation.
What does being the Level III of record actually oblige someone to do?
Being named in the written practice as the individual responsible for the NDT programme, and doing the work that goes with the name: approving procedures and techniques with a signature and a date, writing and grading examinations, conducting practical examinations, recommending certification, reviewing inspection data, keeping the practice current, and appearing when a client audits the programme. If none of that happens, the name on the document is a liability.
Does the Level III of record sign off inspections as the API inspector?
No. The API 510, 570 or 653 inspector authorises and signs the in-service inspection of the vessel, piping or tank, and Atlantis does not take that role and is not a process safety management auditor. The Level III of record supplies the NDT technical authority underneath it: the written practice, the procedures, personnel certification within the practice, independent review of inspection data, and support on technical questions during an audit.
Is API 510, 570 or 653 inspector training part of this offer?
No. API 510, 570 and 653 are inspector certifications administered by API, with their own examination and experience routes, and that certification training is not part of what Atlantis supplies. What is supplied is the NDT side: written practice, procedure development and qualification, examinations and certification of NDT personnel under the practice, and technical review of the data an API inspector then relies on.
Which regulator has jurisdiction over a Deer Park pressure vessel?
For a boiler, the Texas Department of Licensing and Regulation administers the state boiler programme and certificate inspections. For an in-service process vessel, tank or piping circuit, Texas does not operate a general jurisdiction, so the enforceable requirement is federal OSHA's process safety management rule and the recognised good engineering practice it points at, which for a Deer Park refinery or terminal means API 510, 570 and 653.
Can one Level III cover several methods and several sites?
Yes, within limits that should be written down. A Level III can only hold authority in methods in which he is himself certified, and the practice should name the methods explicitly rather than say NDT. Across sites, the constraint is availability rather than paperwork: examinations, practical assessments and audit attendance have to happen on site, so the agreement should state response times and a minimum number of site visits.
How quickly should a Level III of record respond during a turnaround?
That is a contract term, not a courtesy, and it should be written into the engagement. Turnaround work on the Ship Channel runs continuously and the questions that need a Level III arrive at three in the morning: an unexpected indication, a technique that will not reach, a client auditor at the gate. Agree a same day response for technical calls and a defined window for attending an audit in person.