Offshore NDT consulting for operators and inspection contractors on the OCS
30 CFR 250.919(a) requires an operator to file an in-service inspection report by 1 November listing every platform inspected in the preceding twelve months, the extent and area inspected above water and below, the method employed, and the corrosion-protection evaluation. That filing is assembled from contractor NDT records. Records that log findings without logging coverage cannot support it.
Offshore differs from maritime in who audits you. Fixed platforms on the US Outer Continental Shelf are regulated by BSEE, not classed, and 30 CFR 250.919(d) ties inspection intervals to the interval table in API RP 2SIM keyed to the exposure category BSEE has accepted and the survey level, without requiring RP 2SIM's risk-based interval option. The technician qualification standard is API RP 2X, which expects Level II certification per SNT-TC-1A or an approved equivalent and then makes a practical on tubular-joint mock-ups decisive. Access adds a second certification stack — SPRAT in the Gulf of Mexico, IRATA in the North Sea, CSWIP grades for diver and ROV inspection — running on clocks independent of the NDT certificate. Rotation is what breaks both. Floating production and moorings bring classification and API RP 2FSIM, 2MIM and 2I back into the record set.
Source: 30 CFR Part 250 Subpart I §§250.900, 250.919 and 250.920, and Subpart S (SEMS); API RP 2SIM, Structural Integrity Management of Fixed Offshore Structures; API RP 2X, Ultrasonic and Magnetic Examination of Offshore Structural Fabrication and Guidelines for Qualification of Technicians; API RP 2FSIM, API RP 2MIM and API RP 2I; ASNT SNT-TC-1A:2020; ISO 9712:2021; IACS UR W35 Rev.2 and UR Z17 Annex 1 Section 3; CSWIP underwater inspection scheme; NACE MR0175 / ISO 15156.
| Record or document | What the assessor asks for | Governing clause or standard | Common defect |
|---|---|---|---|
| Annual in-service inspection report | Platforms inspected in the preceding twelve months, extent and area of inspection above water and below, type of inspection employed, structural condition with corrosion-protection evaluation, and a summary of repairs needed — submitted by 1 November | 30 CFR 250.919(a) | Contractor reports capture indications and dispositions but never the extent and area covered, so October is spent reconstructing coverage from job cards and dive video |
| Inspection interval basis | The exposure category BSEE has accepted for the structure and the survey level, resolving to the interval in the API RP 2SIM table | 30 CFR 250.919(d) with API RP 2SIM | Intervals set by campaign convenience or by a risk-based scheme the regulation does not require, with no accepted exposure category on file to check against |
| Post-event inspection plan | A list of affected structures, a timetable for conducting the inspections, and a per-structure inspection plan describing the work that will determine its condition | 30 CFR 250.919(b) | No storm-response plan drafted before hurricane season, so the post-event submission is written under time pressure by whoever is available |
| Damage assessment and remediation submission | Description of detected damage affecting structural integrity, assessment of the structure's ability to withstand anticipated environmental conditions, and remediation plans | 30 CFR 250.919(c) and 250.920 | NDT reports state accept or reject against a fabrication criterion, giving the integrity engineer nothing to build a fitness-for-purpose argument on |
| UT technician TKY practical record | A practical on full mock-ups of tubular joints or flat-plate connections simulating typical cross sections — three or four test plates of 18 to 24 inches carrying ten or more defects — including correct completion of the reporting paperwork | API RP 2X | A generic butt-weld plate practical on file; no TKY specimen map, no marked answer sheet, no reporting-paperwork element, no defect key retained |
| NDE personnel certification level | Level II per SNT-TC-1A or an approved equivalent for anyone evaluating examination results | API RP 2X | Level I technicians interpreting and dispositioning indications because the crew is short, with a Level II countersigning afterwards |
| Splash-zone cleaning and coverage record | The cleaning standard applied, how cleaning was verified, the area cleaned against the area the inspection plan called for, and who accepted the coverage | API RP 2SIM inspection planning and the site NDT procedure | A no-indications MT or ACFM result with no cleaning standard cited and no coverage statement, which proves nothing about the member |
| Subsea survey data set | Close visual inspection, UT thickness, flooded member detection, cathodic protection potential readings and ACFM crack detection, each with a stated coverage basis and named acceptance authority | API RP 2SIM | Results filed by technique and date with no member identifier, so the same joint cannot be trended across two campaigns |
| Diver and ROV inspection certification | Current CSWIP underwater scheme certification — 3.1U or 3.2U diver inspector, 3.3U ROV inspector, 3.4U underwater inspection controller — with logged underwater inspection hours | CSWIP underwater inspection scheme (five-year certificate cycle) | Dive medical and HSE competencies current while the inspection certificate expired mid-campaign; controller cover unavailable because 3.4U prerequisites take years to build |
| Rope access ticket | A current SPRAT or IRATA certificate at the correct level on the day of deployment, alongside the NDT method certificate | SPRAT (Gulf of Mexico) / IRATA (North Sea), three-year cycle | The competence matrix tracks one clock: the rope ticket is current and the MT certificate lapsed, or the reverse, and neither is caught before mobilisation |
| Vision currency across rotation | Annual near-vision examination and colour capability appropriate to the method, current on every day worked | ASNT SNT-TC-1A:2020 (minimum Jaeger Number 2 or equivalent at not less than 12 in., annually; colour contrast at initial certification and five-year intervals) or ISO 9712:2021 (Jaeger 1 or Times Roman N4.5 at not less than 30 cm, annually) | Due date falls mid-hitch, the technician works two weeks uncertified, and every report signed in that window is challengeable |
| Sour-service procedure | A procedure naming the service environment, the damage mechanism it is written to detect, and the technique justification against that morphology, with hardness verification records where the materials basis requires them | NACE MR0175 / ISO 15156 materials basis, applied through the site NDT procedure | A general weld-inspection procedure run in sour service, written for fabrication flaws rather than SSC, HIC, stepwise cracking or SOHIC |
| Contractor qualification verification | The NDT contractor's written practice and personnel records, held by the operator as evidence it verified contractor competence | 30 CFR Part 250 Subpart S (SEMS) | The contractor supplies a certificate list; the written practice, examination papers and OJT logs are never produced or requested |
| Mooring and floating asset inspection history | Inspection history by component identity from anchor to the connection at the unit, including turret bearings, fairleads, chain stoppers, anchors and suction piles | API RP 2I, API RP 2MIM, API RP 2FSIM | Records filed by campaign rather than component, so the history of an individual chain segment cannot be reconstructed when it matters |
| Classed-unit NDT approval | For MODUs and floating units under class: the NDT supplier verification for new construction and the separate in-water survey approval | IACS UR W35 §1.1 and UR Z17 Annex 1 Section 3 | An offshore contractor working a classed floating unit on OCS documentation alone, holding no class-side verification for the work scope |
The report BSEE reads is built from your field records
30 CFR 250.919(a) requires a comprehensive in-service inspection report submitted annually by 1 November to the Regional Supervisor. Its content list is specific: the fixed and floating platforms inspected in the preceding twelve months; the extent and area of inspection for both above-water and underwater portions of the platform, and for floating platforms the pertinent components of the mooring system; the type of inspection employed, with visual, magnetic particle and ultrasonic testing named; the overall structural condition of each platform including a corrosion-protection evaluation; and a summary of results indicating what repairs were needed.
Read that against a real contractor NDT report. Most record indications, dimensions and dispositions well. Few record the extent and area actually covered, and fewer separate above-water from underwater coverage per structure. The operator then spends October reconstructing coverage from job cards, dive video logs and technician recollection. We restructure the report template and the data fields so the November filing becomes a query against the year's records rather than an archaeology project — and so the coverage claim is defensible if BSEE asks how it was derived.
Intervals come from API RP 2SIM, not from your campaign plan
30 CFR 250.919(d) requires inspections at the intervals specified in the API RP 2SIM interval table, driven by the exposure category BSEE has accepted for the platform and the survey level, and states that the risk-based inspection intervals option in RP 2SIM is not required. That has commercial consequences. A contractor proposing a risk-based interval is proposing something the regulation does not ask for, and an operator accepting it still owes the RP 2SIM interval underneath. Two documents have to agree before a campaign is scoped: the accepted exposure category on file, and the survey level the interval calls for.
API RP 2SIM carries the guidance for evaluating structural damage, above-water and below-water structural inspection, fitness-for-purpose assessment, risk reduction, mitigation planning and decommissioning, incorporating and expanding what API RP 2A-WSD Section 17 previously held. 30 CFR 250.920 keeps the assessment categories, the analysis-check triggers for added personnel, added topside facilities, increased loading or significant damage, and the platform list obligation on a five-year cycle. Where category and level disagree, the campaign scope is wrong before a technician mobilises.
API RP 2X is why a generic UT Level II is not enough offshore
API RP 2X, Ultrasonic and Magnetic Examination of Offshore Structural Fabrication and Guidelines for Qualification of Technicians, expects NDE personnel evaluating examination results to be certified Level II in accordance with ASNT SNT-TC-1A or an approved equivalent in the techniques used. It then makes the practical decisive, treating the candidate's demonstrated ability to detect and evaluate the weld discontinuities of interest as of greater significance than all other requirements. That inverts the usual file: hours and training records matter less than the specimen record.
The specimen requirement is where files fail. RP 2X points at full mock-ups of tubular joints or flat-plate connections simulating typical cross sections, and describes three or four test plates of 18 to 24 inches carrying ten or more defects as an adequate test of ability. It also tests the candidate's ability to correctly complete the reporting paperwork associated with NDE reporting procedures. A Level II certificate earned on a butt-weld plate evidences none of that for a T, K or Y joint. We author and grade the TKY practical and retain the specimen maps, defect keys, marked answer sheets and grading records.
Splash zone work is won or lost on coverage, not technique
The splash zone concentrates corrosion and fatigue damage, and it is where an auditor challenges coverage rather than method selection. Magnetic particle and alternating current field measurement both depend on surface condition, so the procedure has to state the cleaning standard applied, how cleaning is verified, and who accepts that the cleaned area matches the area the inspection plan called for. Without those three statements, a report showing no indications proves nothing about the member — it proves something about whatever surface happened to be exposed.
The same discipline extends across the subsea scope. Close visual inspection, ultrasonic thickness readings, flooded member detection, cathodic protection potential readings and ACFM crack detection each need a stated coverage basis and a named acceptance authority. Records carrying a technique, a result and a date but no member identifier and no coverage statement are the single most common reason a structural integrity file cannot support a fitness-for-purpose argument two years later, when the damage assessment under 250.919(c) is the thing being written.
Deployment tickets and NDT certificates expire on different clocks
A technician who cannot reach the weld does not inspect it, so offshore personnel carry two certification stacks. Rope access runs SPRAT in the Gulf of Mexico and IRATA in the North Sea, both on a three-year cycle with revalidation required before expiry, or within a short grace window after. Diver-deployed and remote inspection run the CSWIP underwater scheme: 3.1U and 3.2U diver inspector grades, 3.3U for ROV inspectors, and 3.4U for the underwater inspection controller, on a five-year certificate cycle with renewal by examination.
The 3.4U prerequisite shows how long the runway is. Candidates come from a previously approved 3.1U or 3.2U diver inspector who has held that certification for a minimum of three years, with a minimum of 100 logged hours of underwater inspection work. You cannot backfill a controller at short notice, and losing one mid-campaign stops the campaign. Where the unit is classed rather than regulated, IACS UR Z17 Annex 1 §3.5 adds its own thresholds — one year as an assistant diver including at least ten different assignments, one year of ROV inspection work for operators, two years for supervisors.
Rotation is what actually breaks qualification currency
Every recurring obligation in NDT assumes an office calendar. Offshore runs 28 and 28, 21 and 21, or call-out, and each obligation lands somewhere in that cycle. ASNT SNT-TC-1A:2020 sets an annual near-vision examination — a minimum of Jaeger Number 2 or equivalent type and size letter at the distance designated on the chart and not less than 12 inches, in at least one eye, corrected or natural — with colour contrast differentiation at initial certification and five-year intervals thereafter. ISO 9712:2021 sets near vision annually at Jaeger 1 or Times Roman N4.5 at not less than 30 cm, on a five-year certificate.
Miss the annual date by two weeks while the technician is offshore and every report he signs in that window is challengeable. The fix is a currency calendar keyed to crew-change dates rather than anniversaries: vision tests booked into the back-to-back onshore period, recertification examinations scheduled against a rotation with enough margin that a failure gets a second attempt before the certificate lapses, and rope access revalidation slotted so the ticket and the method certificate never expire in the same hitch. We run that calendar as part of the retainer described at /consulting/ndt-consulting-level-iii.
Sour service changes what the procedure has to find
H2S service changes the damage mechanism, and the mechanism decides the technique. Sulfide stress cracking, hydrogen-induced cracking, stepwise cracking and stress-oriented hydrogen-induced cracking present as planar and stepped internal features aligned to the rolling direction of the plate, not as the porosity, lack of fusion and slag a weld-inspection procedure is written to catch. NACE MR0175 / ISO 15156 governs materials selection and qualification for H2S-containing environments in oil and gas production; the NDT obligation follows from that materials basis rather than being stated inside it.
A procedure fit for sour service names the service environment it was written for, names the mechanism it is designed to detect, and justifies the technique against that morphology — scan pattern, beam angles, coverage, and the mapping approach for internal laminar features. It sits alongside hardness verification records where the materials basis requires them. A general weld-inspection procedure run in sour service without that statement is the first thing an operator's integrity engineer flags, and it is a procedure problem rather than a technician problem.
Floating production, moorings and where classification comes back
Fixed platforms on the US Outer Continental Shelf are regulated, not classed. Floating production systems, MODUs and mobile offshore units bring classification back and with it a second document set. API RP 2FSIM covers floating systems integrity management and routes moorings to API RP 2MIM and risers to API RP 2RIM. API RP 2I covers in-service inspection of mooring hardware for MODUs and permanent floating installations, spanning anchor to the connection at the floating unit and including turret bearings, fairleads, chain stoppers, anchors and suction piles.
The failure is filing, not inspection. NDT results filed by campaign cannot reconstruct the history of an individual chain segment or fairlead, which is exactly what a mooring integrity argument needs. We restructure the register so component identity is primary and campaign is secondary. Where the unit is classed, IACS UR W35 also reaches NDT on the new construction of offshore structures subject to classification, and UR Z17 Annex 1 Section 3 governs in-water survey by diver or ROV — both covered at /consulting/maritime-ndt-consulting.
After a named storm, 250.919(b) starts the clock
Where structures have been exposed to a natural occurrence such as a hurricane, earthquake or tropical storm, the Regional Supervisor may require an initial report of all structural damage followed by updates that include a list of affected structures, a timetable for conducting the inspections, and an inspection plan for each structure describing the work that will determine its condition. 250.919(c) then allows the Regional Supervisor to require the inspection results, a description of any detected damage that may adversely affect structural integrity, an assessment of the structure's ability to withstand anticipated environmental conditions, and remediation plans.
None of that drafts well under time pressure. The Gulf season is on a known calendar, so the plan template, technique selection, personnel matrix and contractor call-off belong on the shelf before June. We write the storm-response inspection plan set against your platform list and accepted exposure categories, so the post-event submission is a fill-in rather than a rebuild, and so the technicians called out already hold current API RP 2X TKY practicals, current vision records and current deployment tickets on the day the helicopter leaves.
What an outsourced Level III owns offshore, and what stays with you
The scope is procedures, qualification and defensibility. We author method procedures and technique sheets, map acceptance criteria to the governing document for each scope rather than to a shop default, author and grade the API RP 2X TKY practical, write the personnel written practice, and keep examination masters, marked papers and grading records retained instead of discarded after the result is issued. We build the currency calendar around rotations and maintain the audit-response file an operator's contractor review will ask for.
Execution and daily verification stay with you. Contractor selection and performance is an element of SEMS under 30 CFR Part 250 Subpart S, which is why an operator asks for your written practice and personnel records rather than a certificate list — and why an inspection contractor that can produce them wins on the audit rather than on the bid. The authority boundary between qualifying personnel and certifying them is set out at /consulting/outside-ndt-level-3-can-and-cannot-do, and examination authorship and retention at /consulting/ndt-level-3-exam-oversight.
What does BSEE require in the annual in-service inspection report?
Under 30 CFR 250.919(a) an operator submits a comprehensive report by 1 November covering: the fixed and floating platforms inspected in the preceding twelve months; the extent and area of inspection for both above-water and underwater portions, plus the pertinent mooring system components for floating platforms; the type of inspection employed, with visual, magnetic particle and ultrasonic testing named in the rule; overall structural condition including a corrosion-protection evaluation; and a summary indicating what repairs were needed.
Does an SNT-TC-1A UT Level II certificate qualify a technician for offshore tubular joints?
Not on its own. API RP 2X expects NDE personnel evaluating results to hold Level II per SNT-TC-1A or an approved equivalent, then treats demonstrated ability to detect and evaluate the weld discontinuities of interest as more significant than every other requirement. It points at full mock-ups of tubular joints or flat-plate connections simulating typical cross sections — three or four test plates of 18 to 24 inches with ten or more defects — and tests the candidate on completing the reporting paperwork.
Who sets the inspection interval for a fixed platform in the Gulf of Mexico?
The regulation does. 30 CFR 250.919(d) requires inspections at the intervals specified in the API RP 2SIM table, driven by the exposure category BSEE has accepted for the platform and the survey level, and does not require RP 2SIM's risk-based inspection interval option. A contractor proposing a risk-based interval is proposing something the rule does not ask for, and the operator still owes the RP 2SIM interval underneath it.
How do rope access and NDT certifications interact for offshore technicians?
They are independent stacks on independent clocks. Rope access runs SPRAT in the Gulf of Mexico and IRATA in the North Sea, both on a three-year cycle with revalidation required before expiry. The NDT method certificate runs on its own annual vision and five-year recertification cycle. A technician needs both current on the day of deployment; a matrix tracking one produces people on a helicopter who cannot sign the report they were sent to produce.
What happens to qualification currency on a 28-and-28 rotation?
Every recurring obligation lands somewhere in the cycle and half of them land offshore. The SNT-TC-1A annual near-vision examination, the ISO 9712 annual vision confirmation and five-year certificate expiry, the CSWIP five-year underwater renewal and the three-year rope access revalidation all fall due against calendar anniversaries, not crew changes. Missing a vision date by two weeks makes every report signed in that window challengeable. The calendar has to be keyed to back-to-back onshore periods instead.
What changes in an NDT procedure written for sour service?
The mechanism, and therefore the technique. H2S service produces sulfide stress cracking, hydrogen-induced cracking, stepwise cracking and stress-oriented hydrogen-induced cracking — planar and stepped internal features aligned to the rolling direction, not the fabrication flaws a weld procedure catches. NACE MR0175 / ISO 15156 governs materials selection for H2S environments; the NDT obligation follows from it. The procedure must name the environment, name the mechanism, and justify coverage and scan approach against that morphology.