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Report 1:

HIC damage in a Recycle Gas Knockout Drum. Special in this case is the fact that the main HIC damage was caused by the liquid entering through the inlet, and not from the sour gas.
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Report 2: HIC damage in a Micro Scrubber of a sour gas plant. The HIC damage was normal. What we want to show is that even when a damaged item is out of service, the groth of the HIC damage can continue.
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Report 3: HIC damage and cracks in a weld of a high pressure H2S Absorber. The HIC damage was mainly just above the liquid level. In the liquid phase itself no damage was present. The cracks in the weld were detected in 1998 and because of a very strong growth in 1992, the absorber was taken out of service.
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Report 4A & 4B:

HIC damage in a Naphta Depentanizer Fash Drum. Most of the damage was in the liquid phase, and only in both shells, not in the caps. It were 2 different charges of steel. What we want to show is that there is always one main direction of the stepwise cracking. Report 4B - HIC damage in an inlet separator of a sour gas plant.
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Report 5A, 5B & 5C: HIC damage in a 6" Sourgas Pipe (the material was not clean). The cuttings of the pipe to make the stepwise cracking visible were made in the wrong direction (see report 6A). Report 5B - HIC damage in a 8" cap of a magnetrol (measuring the liquid level). In the cap were all types of HIC delaminations present, including stepwise cracking from the middle of the plate material. Report 5C - HIC damage in a low pressure H2S absorber. All items do have a wall thickness below 10 mm.
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Report 6A & 6B: Report 6A is an addition to Report 5A. It shows stepwise cracking after cutting the material into the right direction. There is also a report about HIC damage in seamless piping made from clean steel. Report 6B - very strong HIC damage in 2 Reactor Effluent Condensers. The stepwise cracking could not be confirmed with automated testing equipment.
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Report 7A, 7B, 7C & 7D: Report 7A - HIC damage in a  Sour Gas Scrubber. The heavy HIC damage was caused within 3 months. The damaged part was used many years on another plant and was out of service (cleaned and stored) for several years, without any damage. In 1995 we finished our new procedure with help of Shell Research. Report 7B is about the same drum as in report 1. The area with HIC damage was replaced with a new plate. Within 1 year the new plate was filled up with heavy HIC damage. Report 7C - HIC damage in a H2S Absorber. Most of the damage was opposite the inlet. Report 7D - HIC damage in a High Pressure Amine Absorber. The main damage was in an area of the lowest shellpart In the beginning, in 1987, there was strong growth. Since 1992 the groth has stopped.
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Report 8A, 8B & 8C: Report 8A - HIC damage in airfin coolers. Report 8B shows you a part from the condensor in report 6B. We show you that an at the outside goodlooking shellpart is filled up with stepwise cracking, and we show you the minimum sound material wall thickness after removing the HIC damage. Report 8C shows that we are able to find cracks in and below welds. In this report we talk about an H2S Absorber.
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Report 9A & 9B: Report 9A - HIC damage in a DEA Absorber. The main damage was only in the lowest shellpart. In the other 9 shellparts there was no real HIC damage present. The answer to this is the fact that the lowest shellpart was made from steel of a different charge number. Report 9B - Fatigue cracks in Pressure Swing Absorbers. These cracks were caused due to a wrong construction. It was the hardest job to find the start of these cracks. Later on we could prove that such cracks can grow very fast.
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Report 10A, 10B, 10C & 10D: Report 10A shows that free atomar hydrogen coming from the product and which is diffunding through the material, doesn't diffund everywhere in the same intensity. Report 10B - another example that free atomar hydrogen is diffunding in a special way through the material, and some other special findings of HIC damage. Report 10C - HIC damage in a renewed H2S FLARE K.O. Drum, caused within 4 years. Report 10D shows the difference between testing for HIC damage using the ASME-code and the Verkade NDT Services procedure. It is a pity that worldwide ASME is used to detect HIC damage.
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Report 11: HIC damage in a propane accumulator in a lube oil plant. The item wasn't in the program for HIC testing. Still some tests on it were done, and nothing found. 3 years later some square meters of HIC delaminations and blisters were found.
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Report 12: The growth of the HIC damage in the propane accumulator (see report 11). It shows also evidence that the growth of HIC damage can stop, even when the conditions stay the same. It is a fact that HIC damage can grow very fast after a turn around, or when the service conditions have changed (a little bit). There is also some information about the new HIC resistant steel which has been used for the new propane accumulator.
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Report 13A, 13B & 13C: Report 13A is about cracks in the HAZ zone of demister welds, before and after repair. Report 13B informs you about HIC damage in LPG storage tanks (bullets). Report 13C is about HIC damage in a drum, with cracks in the H.A.Z.
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Report 14A & 14B: Report 14A and 14B are about a pressure test of a sour gas scrubber which was rejected due to HIC damage.
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Report 15: About corrosion under pipe supports. We can test pipes with a diameter starting at 1.5 inch up for corrosion at the support.
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  Presentation about HIC damage.
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  Failure analysis of an amine-absorber pressure vessel (HIC).
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  Information about further developments about our method to determine corrosion at the supports of pipes.
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  Information about HTHA damage present in carbon steel.
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  Information about determining SCC in stainless steel by means of manual UTtesting.
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  Corrosion in pipelines underneath supports and pipe clamps.
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Information about pipes with teflon wrap
   
 
Information about dented pipes