Passivation Services in Texas

Yes, statewide, on new fabrication and installed systems, covering Greater Houston and the Gulf Coast corridor, Dallas-Fort Worth, Austin and San Antonio. We passivate to ASTM A967 with cleaning per ASTM A380 and record the chemistry, measured concentration, temperature, dwell time, rinse endpoint and verification result, because a certificate without those figures demonstrates intent rather than outcome.

Because marine atmosphere carries chloride, and chloride breaks down the passive chromium oxide layer that makes stainless corrosion-resistant. The attack is not uniform thinning; it is pitting, concentrated wherever salt can deposit and moisture persists. That makes it hard to anticipate from general condition and easy to miss, because a surface can look acceptable while localized pitting is well advanced.

Under insulation, beneath pipe supports and shoes, on horizontal ledges and flat tops where salt accumulates, and at crevices around fasteners and unsealed joints. What those share is a place where chloride can concentrate and moisture cannot dry. Corrosion under insulation is the most consequential because it is invisible until cladding is removed, which is usually during a shutdown when there is no time to react.

No, and conflating the two is the specific error this page exists to correct. Internal passivation treats the wetted product-contact surface and controls rouging. External coastal corrosion is a separate problem governed by material grade, installation detailing and whether water can sit against the metal. A complete internal passivation record tells you nothing about the condition of the outside of the same run of pipe.

316 for anything outdoors or in coastal atmosphere. The molybdenum content gives materially better resistance to chloride pitting, and the price difference is small against the cost of replacing corroded pipework in locations that are difficult to access. Specifying 304 externally to save money on a coastal site is the decision most often regretted, usually within a few years rather than a decade.

ASTM A967 covers both and either will form a passive layer. On Texas sites the handling question tends to settle it: nitric is more aggressive to work with, and crews doing this in Gulf Coast summer heat inside plant areas are safer with citric, which also produces a less troublesome waste stream. Nitric still has legitimate applications. What matters more than the choice is that the surface was properly cleaned first under ASTM A380, and that chloride-bearing residues in particular were removed, because passivating over salt deposits on a coastal site locks the contaminant against the steel.

By removing insulation at sample points rather than assuming. It is hidden by definition, which is why it is so often found during a shutdown rather than before one. On critical coastal runs, installing inspection ports in the cladding allows condition checks without stripping the whole line, and that decision is far cheaper at installation than as a retrofit.

Yes, by circulating cleaning and then passivating solution at controlled concentration and temperature and rinsing to a measured endpoint. On the Gulf Coast the essential caveat is the one this page keeps returning to: circulating a loop treats the inside of the pipe and nothing else. A line can come out of an in-place passivation with a verified internal surface while the outside of the same run is pitting under its insulation. If coastal exposure is part of your problem, the in-place scope has to be paired with an external condition survey, because the two are separate programs with separate budgets.

It depends on temperature, surface finish, water chemistry and how well the system was passivated initially, so there is no universal interval. What is predictable is that a hot Water for Injection loop will rouge eventually, because heat drives it. Treating derouging as a planned maintenance item to be scheduled into an outage is considerably cheaper than reacting when water quality results start drifting.

Use the form on this page or call 201-450-8280. Useful inputs are whether the system is new or in service, materials and approximate surface area or footage, your access window, and whether the equipment is indoors or in coastal atmosphere. If you are seeing external corrosion, photographs of where it appears are genuinely useful, because location usually identifies whether the cause is deposits, a support detail or water trapped under insulation.

They can be cleaned and passivated, and on new work exterior treatment of exposed stainless in coastal service is worth specifying. It does not make the material immune, and it removes free iron and restores a uniform film, which materially delays the onset of pitting. Maintenance washdown then extends that benefit.

Significantly, because it removes deposited chloride before it can concentrate, and it is the cheapest available control. A scheduled freshwater washdown of exposed stainless in coastal plants is a corrosion maintenance activity rather than housekeeping, and its absence is visible within a few years on any coastal installation.

It is where chlorides, tensile stress and elevated temperature coincide, which describes an insulated hot line in a coastal plant precisely. Austenitic stainless is susceptible, the cracking produces little metal loss so it gives no thinning warning, and residual welding stress is often sufficient. It is a design consideration rather than an inspection finding.

The jacket and the vapour barrier, sealed at ends, penetrations and supports, because insulation that admits moisture holds chloride-bearing water against warm stainless and creates the ideal condition for both pitting and cracking. In a coastal climate the cladding detail is the corrosion control, not the insulation thickness.

They do, because the humid salt-laden environment provides a ready electrolyte. Stainless supported on carbon steel, galvanised fixings against stainless and mixed materials at brackets all corrode faster here than inland. Isolating the contact is inexpensive at installation and awkward to retrofit once corrosion has started.

By deliberate close inspection of the surfaces most at risk rather than by waiting for a leak, because pitting perforates locally while the surrounding surface looks sound. Visual inspection with magnification at supports and under insulation, on a defined schedule with photographs, is what catches it while remediation is still possible.

Less than for general corrosion, because pitting and cracking are localised and a thickness reading a few centimetres away will be unremarkable. Thickness monitoring suits general wall loss; for chloride attack the useful programme is targeted visual and surface inspection at the high-risk locations.

The rouging mechanism is temperature driven and is essentially the same everywhere, so the interval is set by the plant’s operating temperature and usage rather than by the outside air. What the climate adds is an external corrosion problem running in parallel, which means coastal plants carry two surface programmes rather than one.

Circulation passivation of an installed loop is normal practice and often the only practical option. What must be verified is that the chemistry reached every branch at the intended concentration and temperature for the intended time, which means confirming flow through the low-flow branches rather than assuming the pump delivered it.

Photographs from fixed positions of exterior surfaces, supports and insulation condition at handover, along with the passivation records and material grades installed. Coastal degradation is progressive, and without a baseline every future observation becomes an argument about whether it is new rather than a measure of the rate.

Address the cause before the symptom: fix breached insulation and cladding, establish washdown, isolate dissimilar metal contacts, then remediate and passivate the affected surfaces. Plants that remediate surfaces repeatedly while the insulation keeps admitting salt water spend continuously and never resolve the problem.

Corrosion under insulation on a hot line, discovered when cladding is removed for an unrelated reason, after years of a breached vapour barrier holding chloride-bearing moisture against warm stainless. It is invisible from outside, it is predictable, and it is almost entirely preventable through cladding detail and inspection.

Materially. Chloride deposition falls sharply with distance inland, so a plant in Houston’s ship channel area and one in Dallas face genuinely different external corrosion environments. Specifying the coastal regime state-wide wastes money inland; specifying the inland regime on the coast produces the failures described above.

Generally not, because a coating on stainless conceals the surface and traps moisture at holidays and damage, which can accelerate localised attack rather than prevent it. The better approach is correct grade selection, exterior passivation, sound insulation detailing and a washdown regime that removes deposited chloride.

It becomes the classic corrosion-under-insulation case: the vapour barrier degrades, moisture enters, chloride concentrates against warm stainless, and pitting or cracking progresses invisibly for years. The first symptom is frequently a leak, and by then the affected length usually needs replacing rather than repairing.

On a defined annual cycle for exterior surfaces and insulation condition, with fixed-position photographs, and more frequently where damage has been found. The inspection is cheap, the failures it prevents are not, and the trend it builds is what turns replacement planning into a scheduled decision.