Outsourced ASNT Level III Support for Tulsa Pipeline Inspection Contractors
Federal pipeline rules do not name an ASNT level. 49 CFR 192.243 and 195.234 require NDT under written procedures by people trained and qualified in them. Tulsa operators — ONEOK, Williams, Explorer — close that gap in their contract specs, and an outsourced Level III supplies the written practice, procedures and exams those specs demand.
Tulsa is not a construction town; it is a specification town. ONEOK runs roughly 60,000 miles of pipe from ONEOK Plaza on West Fifth Street. Williams sits in BOK Tower with about 32,000 miles of infrastructure and Transco, a 10,000-mile system reaching from south Texas to New York City. Explorer Pipeline moves refined products across more than 1,800 miles from a Tulsa control center. HF Sinclair's Tulsa refinery runs 125,000 barrels a day of crude. Every one of them writes specs that a contractor's NDT programme has to satisfy. The federal rules underneath are thinner than most firms expect: 49 CFR 192.243 asks for written procedures and personnel trained and qualified in them, and 195.234 asks for the same. Neither names ASNT. The contract does, and that is where an unqualified programme gets caught.
Source: Verified against the published text of 49 CFR 192.241, 192.243, 192.801 and 192.805, and 49 CFR 195.234, as carried on Cornell LII — including the class-location testing percentages, the tie-in and crossing requirements, the life-of-pipeline records obligation, the API Std 1104 acceptance reference and the prohibition on using Appendix A to accept cracks, the four-part covered task test, and the nine required elements of an operator qualification programme. Company facts verified against ONEOK's corporate about page (Tulsa headquarters at ONEOK Plaza, 100 West Fifth Street; approximately 60,000 miles of pipeline; natural gas, NGLs, refined products and crude), williams.com (32,000 miles of infrastructure, about one third of the nation's natural gas, Transco described as a 10,000-mile system from south Texas to New York City), Explorer Pipeline's about page (1,800+ miles of refined products pipeline, Tulsa), HF Sinclair's Tulsa refinery page (125,000 bpd crude capacity, integrated base oil and lubricants production, Catoosa terminal), and the completion of ONEOK's acquisition of Magellan Midstream on 25 September 2023 with headquarters remaining in Tulsa. No Atlantis fee, rate or price is stated anywhere on this page.
| Requirement | Gas lines, 49 CFR 192 | Liquid lines, 49 CFR 195 | What the federal rule names as the qualification | What the operator specification adds |
|---|---|---|---|---|
| Share of girth welds nondestructively tested | At least 10% in Class 1 (non-offshore), at least 15% in Class 2 (192.243) | At least 10% of each welder's and welding operator's girth welds each welding day, over the entire circumference (195.234) | No level or certification scheme named | 100% volumetric coverage on the whole spread |
| Crossings, offshore and populated areas | 100% in Class 3 and 4, at river crossings, offshore and on railroad and highway rights-of-way — at least 90% where 100% is impracticable (192.243) | 100% of the day's girth welds near water bodies, railroad and public road rights-of-way, overhead crossings, tunnels, incorporated subdivisions and populated areas, with a limited impracticability allowance (195.234) | No level or certification scheme named | A shot-by-shot location log tying every film or scan to a station |
| Tie-in welds | 100% (192.243) | 100%, plus 100% of old girth welds in used pipe (195.234) | No level or certification scheme named | Independent second review before acceptance |
| NDT personnel | Testing performed "by persons who have been trained and qualified in the established procedures" (192.243) | Testing performed with "personnel that have been trained" in the written procedures (195.234) | Trained and qualified in the procedures — no ASNT level cited | SNT-TC-1A Level II certification issued by a named certifying Level III |
| Procedures | Written procedures, plus established procedures for the proper interpretation of each test (192.243) | "A written set of procedures" (195.234) | No approval authority named | Level III approval signature and a documented demonstration |
| Visual inspection and acceptance | Visual inspection by an individual qualified by appropriate training and experience; acceptance to API Std 1104 section 9 or Appendix A, and Appendix A may not be used to accept cracks (192.241) | Acceptance governed by the operator's specification, API 1104 based | Qualified welding inspector for the visual step | Named third-party film and data review |
| Records | Girth welds made, tested, rejected and the disposition of rejects, by location, retained for the life of the pipeline (192.243) | Test records retained under the operator's programme | No custodian named | Turnover package format, indexing and handover deadline |
| Operator Qualification | Subpart N; covered tasks identified and evaluated under the programme elements of 192.805 | Subpart G | Evaluation of the individual, not certification of a method | Third-party OQ provider evaluations and a task-to-person matrix |
Tulsa specifies pipe; it does not only lay it
The reason Tulsa matters to an inspection contractor is that the buying decisions get made here. ONEOK operates from ONEOK Plaza at 100 West Fifth Street across roughly 60,000 miles of pipeline moving natural gas, natural gas liquids, refined products and crude, with gathering, processing, fractionation, transportation, storage and marine export in one footprint — a scale reached through the $18.8 billion acquisition of Magellan Midstream that closed on 25 September 2023 and kept the combined headquarters in Tulsa.
Williams runs from BOK Tower with about 32,000 miles of infrastructure and handles roughly a third of the nation's natural gas. Its Transco system alone is a 10,000-mile interstate line reaching from south Texas to New York City and carrying around 15% of US natural gas. Explorer Pipeline moves refined products across more than 1,800 miles from a Tulsa control center. HF Sinclair refines 125,000 barrels a day in Tulsa with integrated base oil and lubricants production and a water terminal at Catoosa.
An hour west, Cushing does what nowhere else does. It is the delivery and pricing point for West Texas Intermediate, with tank farms south of town holding tens of millions of barrels across roughly 300 above-ground tanks operated by ONEOK, Enbridge and others. In mid-2026 those tanks ran close to bottom, with stocks near 21.6 million barrels in early June — a reminder that this is working infrastructure under constant turnover, not storage of last resort.
What the federal rules actually say about your technicians
Most pipeline inspection contractors believe 49 CFR mandates ASNT certification. It does not, and knowing that precisely is what lets a firm build a defensible programme instead of a mythological one. 192.243 requires that nondestructive testing of welds be performed by persons who have been trained and qualified in the established procedures. 195.234 requires that testing be conducted in accordance with a written set of procedures and with personnel that have been trained in those procedures and in the use of the equipment employed.
Neither rule names SNT-TC-1A. Neither names a level. What both do is anchor competence to your written procedures — which means the procedures have to exist first, have to be specific enough to be trained against, and have to include, under 192.243, established procedures for the proper interpretation of each test so that the acceptability of the weld is determined.
The practical consequence is inverted from what firms expect. The federal floor is procedural, not credential-based. But because the floor is procedural, everything rests on documents someone competent has to author and approve — and the person the industry recognises as competent to author and approve NDT procedures is a Level III. The credential arrives through the back door, which is why the procedure work at /consulting/ndt-technical-procedure-development is the load-bearing part of a pipeline engagement.
Where the operator specification raises the bar
Contract specifications are where ASNT appears. Operators write bid packages that require Level II certification in the applicable method, issued under a written practice, with a named certifying Level III, and they audit against that requirement rather than against the CFR. They do it because the CFR's procedural floor gives them no comparable basis for evaluating one bidder against another before work starts.
The gap between rule and contract is where firms lose bids they were technically capable of performing. A crew that has radiographed thousands of girth welds competently, with no written practice and no certifying authority behind the certifications in their files, is non-responsive on paper. The correction is not more field experience. It is the document set: a written practice built against what the firm performs, examinations administered and graded, and certifications signed by someone qualified to sign them. That build is described at /consulting/written-practice-development.
The same specification stack governs coverage. Federal minimums start at 10% of girth welds in Class 1 gas locations, but operators routinely specify full volumetric coverage across the spread and expect a location log tying every image to a station. Bidding to the CFR minimum when the specification says 100% is a pricing error that surfaces after award.
Class location, crossings and the coverage arithmetic
The coverage rules deserve to be read literally because they drive crew sizing. Under 192.243, non-offshore Class 1 requires at least 10% of girth welds nondestructively tested; Class 2 requires at least 15%; Class 3 and Class 4, plus river crossings, offshore areas, and railroad and highway rights-of-way, require 100%, with relief to at least 90% only where 100% is impracticable. Tie-ins are 100% without qualification.
Liquid lines under 195.234 run a different structure. At least 10% of the girth welds made by each welder and welding operator during each welding day must be tested over the entire circumference. Old girth welds in used pipe get 100%. Tie-ins get 100%. And the day's girth welds get 100% where the line runs near water bodies, along railroad or public road rights-of-way, at overhead crossings, in tunnels, through incorporated subdivisions, and in populated areas including residential, commercial, industrial, school and public assembly locations.
Those percentages are per welder and per day on liquid lines, not per project. A spread that reallocates welders mid-week without recalculating coverage generates a compliance gap that only shows up in the records review. The interpretation procedure and the shot log have to be built to track it, which is a Level III design question before it is a field question.
API 1104 acceptance and the interpretation problem
192.241 makes the acceptance question concrete. Each weld must be inspected to ensure it was made per the procedure and meets the acceptance standards in section 9 or Appendix A of API Std 1104 — and Appendix A may not be used to accept cracks. Visual inspection must be performed by an individual qualified by appropriate training and experience. Welds on lines producing hoop stress of 20% or more of SMYS require nondestructive testing, with narrow exceptions for pipe under 6 inches nominal diameter that a qualified welding inspector has visually inspected and approved, and for lines under 40% SMYS where the welds are so limited in number that testing is impractical.
That crack carve-out is where interpretation disputes concentrate. Alternative acceptance criteria under Appendix A permit larger planar indications than section 9 workmanship criteria, and technicians who learn Appendix A as a general relaxation apply it where the rule forbids it. The interpretation procedure has to state the boundary explicitly.
A Level III writes that boundary into the procedure, trains the Level IIs against it, and reviews the disputed calls. Firms that need that authority without adding headcount use /consulting/asnt-level-iii-consulting-services, and the limits of what an external Level III can and cannot sign are set out plainly at /consulting/outside-ndt-level-3-can-and-cannot-do.
Operator Qualification is a separate system, and it is not NDT certification
Subpart N of Part 192 and Subpart G of Part 195 prescribe minimum requirements for operator qualification of individuals performing covered tasks on a pipeline facility. A covered task meets a four-part test: it is performed on a pipeline facility, it is an operations or maintenance task, it is performed as a requirement of the part, and it affects the operation or integrity of the pipeline. All four have to be true.
192.805 lists what the written programme must do: identify covered tasks; ensure through evaluation that individuals performing them are qualified; allow unqualified individuals to perform a covered task only when directed and observed by someone qualified; evaluate an individual whose performance contributed to an incident; evaluate when the operator believes someone is no longer qualified; communicate changes affecting covered tasks; identify the intervals at which re-evaluation is needed; provide training; and notify the Administrator or state agency of significant programme modifications.
Contractors conflate this with NDT certification constantly, and it costs them. An OQ evaluation covering a covered task does not certify anyone in radiography. An SNT-TC-1A Level II certification does not qualify anyone for a covered task. A Tulsa contractor working operator sites needs both systems running in parallel, with a matrix showing which person holds which, and neither system feeding the other.
Records that outlive the contract by decades
192.243 requires the operator to maintain a record showing, by location, the number of girth welds made, how many were nondestructively tested, how many were rejected and the disposition of the rejects — for the life of the pipeline. That obligation belongs to the operator, but the source data is the contractor's, and a turnover package assembled loosely becomes an operator problem that traces straight back to the firm that produced it.
This is why operators write turnover format into the bid package: indexing scheme, image or data file naming, technician identification on every report, calibration traceability, and the deadline for handover. A package that satisfies the technical requirement but arrives in an unusable structure generates rework nobody priced.
Firms that keep technician certifications, calibration due dates, procedure revisions and job records in spreadsheets discover the cost during an operator audit, when producing the certification status of a specific technician on a specific date in a specific year takes days. Holding that record set in one auditable system is what /erp addresses, and it is a straightforward fix compared with reconstructing history after a finding.
Cushing tankage and where the inspection scope crosses over
Cushing changes the work mix for Tulsa contractors. Above-ground storage tanks bring in shell and floor scanning, weld examination on repairs and alterations, thickness surveys and settlement work — a different method profile from girth weld radiography on a spread, and one that pulls in tank inspection programme requirements alongside NDT method qualification.
Atlantis does not sell API 510, 570 or 653 certification training, and there is no point pretending otherwise. What it does is audit and design the inspection programmes those certifications operate inside: interval justification, damage mechanism coverage, evidence quality and record structure. Firms carrying pressure equipment programmes alongside pipeline work use /consulting/api-510-program-audit, and those replacing calendar intervals with risk-based ones use /consulting/rbi-program-design.
On the NDT side, the crossover is the method qualification. A technician certified for girth weld RT is not thereby qualified for tank floor MFL or shell UT. The written practice has to enumerate each method the firm performs against each level it certifies, which is exactly the reconciliation most templates skip. Broader sector context for that buyer sits at /consulting/oil-gas-ndt-consulting.
Getting a Tulsa contractor bid-ready
The sequence is short. Read the current written practice against the methods the firm actually performs and the operator specifications it wants to bid. Reconcile the technician files against that practice. Build or repair the NDT procedures, including the interpretation procedure 192.243 requires. Administer the examinations the practice specifies. Sign the certifications. Then structure the records so an operator audit is a lookup rather than an excavation.
Method training for technicians who need to reach Level II sits separately at /corporate-ndt-training, and the certification landscape those technicians are moving through is mapped at /asnt-certification. Contractors working the chemical and refining side of the same client base will find the parallel audit-clearance page for the Gulf Coast at /consulting/petrochemical-ndt-consulting-baton-rouge.
Atlantis provides outsourced ASNT Level III coverage, written practice development, NDT procedure development and examination oversight for pipeline inspection contractors across Oklahoma and the midcontinent. Positioning is affordable, accessible and fully customisable to the methods and specifications a firm actually works to. Scope and a quote are available on request at /contact.
Does 49 CFR require ASNT-certified NDT technicians on a pipeline?
No. 192.243 requires nondestructive testing be performed by persons who have been trained and qualified in the established procedures, and 195.234 requires a written set of procedures and trained personnel. Neither cites SNT-TC-1A, CP-189 or any ASNT level. The requirement reaches contractors through operator specifications and through API 1104 based acceptance work, not through the federal text itself.
How much of a gas girth weld spread must be nondestructively tested?
192.243 scales it to class location: at least 10% in Class 1 outside offshore areas, at least 15% in Class 2, and 100% in Class 3 and 4, at river crossings, offshore and on railroad and highway rights-of-way — dropping to at least 90% only where 100% is impracticable. Tie-in welds are 100% regardless. Liquid lines under 195.234 start at 10% of each welder's daily girth welds.
What is the difference between Operator Qualification and NDT certification?
Operator Qualification under Subpart N evaluates an individual against a covered task — one performed on a pipeline facility, that is an operations or maintenance task, required by the part, and affecting operation or integrity. NDT certification under SNT-TC-1A qualifies a person in a method at a level, issued by the employer's Level III. An OQ card does not certify anyone in ultrasonics, and a Level II certificate does not qualify anyone for a covered task.
What acceptance standard governs pipeline girth welds?
192.241 makes weld acceptability a question of API Std 1104 section 9 or its Appendix A, with one hard carve-out: Appendix A may not be used to accept cracks. That single sentence decides a large share of interpretation disputes on Oklahoma spreads, and it is why the interpretation procedure a Level III approves matters as much as the scanning procedure.
How long must pipeline weld records be kept?
192.243 requires the operator to maintain records showing the number of girth welds made, the number nondestructively tested, the number rejected and the disposition of the rejects, by location, for the life of the pipeline. That is longer than any contractor's document retention policy. The turnover package a Tulsa contractor hands over becomes a permanent operator record and is read decades later.
What does a Tulsa contractor need before bidding ONEOK or Williams work?
A written practice naming a real certifying Level III, technician files that trace to it, NDT procedures approved against API 1104 and the operator's supplement, calibration records, and a records format matching the turnover package. Operator Qualification evaluations for covered tasks sit alongside those, not inside them. Missing any one of those turns a technically capable crew into a non-responsive bid.