Academic literature on the topic 'SSC (Sulfide Stress Cracking)'
Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles
Consult the lists of relevant articles, books, theses, conference reports, and other scholarly sources on the topic 'SSC (Sulfide Stress Cracking).'
Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.
You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.
Journal articles on the topic "SSC (Sulfide Stress Cracking)"
1
Huang, Weishan, Jing-Li Luo, Hani Henein, and Josiah Jordan. "Sulfide stress cracking assessment of low-alloy L80 casing steel in H2S environment." Anti-Corrosion Methods and Materials 66, no. 4 (July 1, 2019): 379–87. http://dx.doi.org/10.1108/acmm-08-2018-1984.
Full textAbstract:
Purpose This paper aims to evaluate the sulfide stress cracking (SSC) resistance of L80 casing steels with different alloying chemistries (e.g. Ti-B and Mn-Cr-Mo) by correlating the reduction in area ratio with the mechanical property, inclusion and carbide. Design/methodology/approach SSC tests were conducted in 5.0 Wt.% sodium chloride and 0.5 Wt.% acetic acid solution saturated with H2S using constant load tensile method. The microstructure and fracture morphology of the steel were observed using scanning electron microscope. The inclusion and carbide were identified by energy dispersive spectroscopy and auger electron microscope. Findings Among all the testing steels, electric resistance welding (ERW) L80-0.5Mo steel demonstrates the highest SSC resistance because of its appropriate mechanical properties, uniform microstructure and low inclusion content. The SSC resistance of L80 steels generally decreases with the rising yield strength. The fracture mode of steel with low SSC resistance is jointly dominated by transgranular and intergranular cracking, whereas that with high SSC resistance is mainly transgranular cracking. SSC is more sensitive to inclusions than carbides because the cracks are easier to be initiated from the elongated inclusions and oversized oxide inclusions, especially the inclusion clusters. Unlike the elongated carbide, globular carbide in the steel can reduce the negative effect on the SSC resistance. Especially, a uniform microstructure with fine globular carbides favors a significant improvement in SSC resistance through precluding the cracking propagation. Originality/value The paper provides the new insights into the improvement in SSC resistance of L80 casing steel for its application in H2S environment through optimizing its alloying compositions and microstructure.
2
Kappes, Mariano, Mariano Iannuzzi, Raúl B. Rebak, and Ricardo M. Carranza. "Sulfide stress cracking of nickel-containing low-alloy steels." Corrosion Reviews 32, no. 3-4 (October 1, 2014): 101–28. http://dx.doi.org/10.1515/corrrev-2014-0027.
Full textAbstract:
AbstractLow-alloy steels (LAS) are extensively used in oil and gas (O&G) production due to their good mechanical properties and low cost. Even though nickel improves mechanical properties and hardenability with low penalty on weldability, which is critical for large subsea components, nickel content cannot exceed 1-wt% when used in sour service applications. The ISO 15156-2 standard limits the nickel content in LAS on the assumption that nickel concentrations above 1-wt% negatively impact sulfide stress cracking (SSC) resistance. This restriction excludes a significant number of high-strength and high-toughness alloys, such as Ni-Cr-Mo (e.g., UNS G43200 and G43400), Ni-Mo (e.g., UNS G46200), and Ni-Cr-Mo-V grades, from sour service applications and can be used only if successfully qualified. However, the standard is based on controversial research conducted more than 40 years ago. Since then, researchers have suggested that it is the microstructure that determines SSC resistance, regardless of Ni content. This review summarizes the advantages and disadvantages of nickel-containing LAS in terms of strength, weldability, hardenability, potential weight savings, and cost reduction. Likewise, the state of knowledge on the effect of nickel on hydrogen absorption as well as SSC initiation and propagation kinetics is critically reviewed.
3
Mendibide, Christophe, and Claude Duret-Thual. "Formation of Microgrooving on C110 Casing Steel After Sulfide Stress Cracking Test." Corrosion 77, no. 4 (January 25, 2021): 433–44. http://dx.doi.org/10.5006/3714.
Full textAbstract:
NACE TM0177 is a commonly used materials qualification standard specifying how sulfide stress cracking (SSC) tests must be conducted and interpreted to verify the suitability of material application in sour service. This standard specifies through the so-called method A test (a tensile uniaxial environmental cracking test) that a material could be considered acceptable for sour service as long as no failure is evidenced after 720 h of exposure, and no initiation of environmental cracking is observed on the reduced length of the specimen after macrographic observations. After cross-sectional observations, so-called “microgrooves” can sometimes be evidenced on the surfaces of nonfailed specimens. Such features can hardly be interpreted as SSC crack initiation sites considering their shape and depth. Experience, however, shows that the formation of these microgrooves appears to be dependent on test conditions and type of load. This paper presents the results of investigations on the parameters influencing the microgroove formation on C110 steel after the method A uniaxial tensile SSC test. Test parameters influencing the groove formation are studied, and the results suggest that grooving is not SSC initiation for the testing conditions used in this work.
4
Li, Fa Gen, Quan Feng, An Qing Fu, and Rui Cai. "Failure Analysis for Girth Weld of Gathering Pipelines." Materials Science Forum 1035 (June 22, 2021): 480–85. http://dx.doi.org/10.4028/www.scientific.net/msf.1035.480.
Full textAbstract:
Through failure generalization, fracture feature analysis and material performance test, a comprehensively analysis was made on the fracture failure analysis for girth weld of gathering pipelines containing H2S gas. The results showed that the fracture failure might be mainly due to sulfide stress cracking in the girth weld. The crack originated from the fusion line on the inner surface of girth weld and extended along the girth weld to outside closed to bends. The sulfide stress cracking of the girth weld was caused by the intersection of multiple factors. The service condition was located in SSC 3 zone and the SSC risk of girth weld was high. The girth weld itself was not been stress-relieved, and its ability to resist SSC was poor. Due to low wall thickness, welding defects, welding stress and additional load, the actual stress of weld was higher.
5
Tale, Sagar, Ramadan Ahmed, Rida Elgaddafi, and Catalin Teodoriu. "Sulfide Stress Cracking of C-110 Steel in a Sour Environment." Corrosion and Materials Degradation 2, no. 3 (July 5, 2021): 376–96. http://dx.doi.org/10.3390/cmd2030020.
Full textAbstract:
The scope of this study includes modeling and experimental investigation of sulfide stress cracking (SSC) of high-strength carbon steel. A model has been developed to predict hydrogen permeation in steel for a given pressure and temperature condition. The model is validated with existing and new laboratory measurements. The experiments were performed using C-110 grade steel specimens. The specimens were aged in 2% (wt.) brine saturated with mixed gas containing CH4, CO2, and H2S. The concentration H2S was maintained constant (280 ppm) while varying the partial pressure ratio of CO2 (i.e., the ratio of partial pressure of CO2 to the total pressure) from 0 to 15%. The changes occurring in the mechanical properties of the specimens were evaluated after exposure to assess material embrittlement and SSC corrosion. Besides this, the cracks developed on the surface of the specimens were examined using an optical microscope. Results show that the hydrogen permeation, and subsequently SSC resistance, of C-110 grade steel were strongly influenced by the Partial Pressure Ratio (PPR) of CO2 when the PPR was between 0 and 5%. The PPR of CO2 had a limited impact on the SSC process when it was between 10 and 15 percent.
6
Koh, S. U., J. S. Kim, B. Y. Yang, and K. Y. Kim. "Effect of Line Pipe Steel Microstructure on Susceptibility to Sulfide Stress Cracking." Corrosion 60, no. 3 (March 1, 2004): 244–53. http://dx.doi.org/10.5006/1.3287728.
Full textAbstract:
Abstract The purpose of this experiment was to evaluate the effect of microstructure on sulfide stress cracking (SSC) properties of line pipe steel. Different kinds of microstructures, with chemical compositions identical to one steel heat, were produced by various thermomechanically controlled processes (TMCP). Coarse ferrite-pearlite, fine ferrite-pearlite, ferrite-acicular ferrite, and ferrite-bainite microstructures were investigated with respect to corrosion properties, hydrogen diffusion, and SSC behavior. SSC was evaluated using a constant elongation rate test (CERT) in a NACE TM0177 solution (5% sodium chloride [NaCl] + 0.5% acetic acid [CH3COOH], saturated with hydrogen sulfide [H2S]). The corrosion properties of steels were evaluated by potentiodynamic and linear polarization methods. Hydrogen diffusion through steel matrix was measured by an electrochemical method using a Devanathan-Stachurski cell. The effect of microstructure on cracking behavior also was investigated with respect to crack nucleation and propagation processes. Test results showed that ferrite-acicular ferrite microstructure had the highest resistance to SSC, whereas ferrite-bainitic and coarse ferritie-pearlitic microstructures had the lowest resistance. The high susceptibility to SSC inferritie-bainitic and coarse ferritic-pearlitic microstructures resulted from crack nucleation on hard phases such as grain boundary cementite in coarse ferritie-pearlitic microstructures and martensite/retained austenite (M/A) island in bainitic phases. Hard phase cementite at grain boundaries or M/A constituent in bainitic phases acted as crack nucleation sites and could be cracked easily under external stress; consequently, the susceptibility of steel to SSC increased. Metallurgical parameters including matrix structure and defects such as grain boundary carbides and inter-lath M/A constituents were more critical parameters for controlling SSC than the hydrogen diffusion rate.
7
Le Hien, Nguyen Thi. "CRACKING CORROSION OF LOW CARBON STEEL IN ENVIRONMENT WITH A HIGH CONCENTRATION OF CO2 AND H2S." Vietnam Journal of Science and Technology 55, no. 5B (March 24, 2018): 210. http://dx.doi.org/10.15625/2525-2518/55/5b/12228.
Full textAbstract:
Cracking corrosion of API 5CT Grade L80 Type 1 low carbon steel has been studied in a in brine solutions with H2S 12.3 psia and CO2 9.4 psia. Testing was performed according to the methodology reference from the NACE TM0177, Bent-beam test method in solution B for stress corrosion cracking and sulfide stress corrosion cracking test and NACE TM0284, immersion test method in solution A for Hydrogen induced cracking test.The obtained results showed pitting and general corrosion at both temperatures of 24 oC and 82 oC. In case of stress corrosion cracking (SCC) testing at 82 °C, microscopy of the samples tested for 30 days developed pitting corrosion in the surface and cracking starting in the surface of the samples. The cracks, mostly found in the middle of the samples where the maximum bending occurred. General corrosion was also observed in the samples, with significant decrease in the dimensions of the samples after testing (due to general corrosion). However, in case of sulfide stress corrosion (SSC) and hydrogen induced cracking (HIC) tests at room temperature (24-25 oC), no cracking was observed on the sample.
8
Zhao, Ming-Chun, and Ke Yang. "Effects of Nano-sized Microalloyed Carbonitrides and High-density Pinned Dislocations on Sulfide Stress Cracking Resistance of Pipeline Steels." Journal of Materials Research 20, no. 9 (September 2005): 2248–51. http://dx.doi.org/10.1557/jmr.2005.0321.
Full textAbstract:
Sulfide stress cracking (SSC) resistance was investigated by comparing acicular ferrite (AF) and ferrite-pearlite (FP) in a microalloyed steel and in a non-microalloyedsteel. In microalloyed steel, AF exhibited better SSC resistance than FP, while in non-microalloyed steel, AF presented far worse SSC resistance than FP. In microalloyed steel, nano-sized carbonitrides and high-density pinned dislocations in AF were analyzed to behave as innocuous hydrogen traps, offering numerous sites for hydrogen redistribution and modifying critical cracking conditions. Dislocations in AF of microalloyed steel in the final analysis are attributed to pinning by the nano-sized carbonitrides.
9
Kobayashi, Kenji, Tomohiko Omura, and Masakatsu Ueda. "Effect of Testing Temperature on Sulfide Stress Cracking of Low Alloy Steel." Corrosion 74, no. 6 (January 9, 2018): 603–12. http://dx.doi.org/10.5006/2605.
Full textAbstract:
In this study, effects of environmental temperature on susceptibility to sulfide stress cracking (SSC)—a type of hydrogen embrittlement (HE) occurring in sour environments—of low alloy steels were investigated from the perspective of hydrogen entry, absorption, and accumulation. SSC susceptibility was evaluated using a double cantilever beam (DCB) test and a four-point bend (4PB) test in sour environments at several testing temperatures. 4PB test specimens included notched and un-notched specimens to investigate influences of stress concentration and local stress. In the case of evaluation methods using specimens with high-stress concentration area, a decrease in testing temperature from room temperature to 4°C significantly increased SSC susceptibility. Hydrogen entry and absorption behaviors were also evaluated at several testing temperatures using a hydrogen permeation test. The hydrogen concentration at the plastic deformed area increased remarkably with decreasing testing temperature. It is considered that the influence of testing temperature is due to hydrogen concentration at the stress concentration area with plastic deformation. In a low temperature condition, the degree of hydrogen accumulation at the crack tip areas of a DCB specimen or crack initiation site of a 4PB specimen could be higher than that in a higher temperature condition. When steels are applied to low temperature conditions with H2S, a prior material evaluation reproducing both environmental temperature and actual stress condition is needed.
10
Shei, S. A., and C. D. Kim. "A Microstructural Study of the Sulfide Stress Cracking Resistance of a Cr-Mo-V-B Steel." Corrosion 41, no. 1 (January 1, 1985): 12–18. http://dx.doi.org/10.5006/1.3581963.
Full textAbstract:
Abstract A study was conducted to determine the effect of microstructure and strength level on the sulfide stress cracking (SSC) performance of a Cr-Mo-V-B steel. The steel was heat treated by quenching and tempering in a temperature range of 1100 to 1325 F (593 to 718 C). Crack initiation and propagation behaviors were examined using three-point bending tests. The experimental results showed that an increase in tempering temperature was associated with an increase in crack initiation time, indicating an increase in SSC resistance. The increased tempering temperature also changed the crack propagation path from a mixture of transgranular and intergranular to primarily transgranular cracking. Crack initiation and propagation were shown to be associated with decohesion and/or microvoid formation at carbide/matrix and inclusion/matrix interfaces. Differences in the SSC resistance were correlated with the morphology of carbide particles.
Dissertations / Theses on the topic "SSC (Sulfide Stress Cracking)"
1
Almansour, Mansour A. "Sulfide stress cracking resistance of API-X100 high strength low alloy steel in H2S environments." Thesis, University of British Columbia, 2007. http://hdl.handle.net/2429/267.
Full textAbstract:
Sulfide Stress Cracking (SSC) resistance of the newly developed API-X100 High Strength Low Alloy (HSLA) steel was investigated in the NACE TM0177 "A" solution. The NACE TM0177 "A" solution is a hydrogen sulfide (H2S) saturated solution containing 5.0 wt.% sodium chloride (NaC1) and 0.5 wt.% acetic acid (CH3COOH). The aim of this thesis was to study the effect of microstructure, non-metallic inclusions and alloying elements of the X100 on H2S corrosion and SSC susceptibility. The study was conducted by means of electrochemical polarization techniques and constant load (proof ring) testing. Microstructural analysis and electrochemical polarization results for X100were compared with those for X80, an older generation HSLA steel. Uniaxial constant load SSC testing was conducted using X100 samples and the results were compared with those reported for older generation HSLA steels.
Addition of H2S to the NACE TM0177 "A" solution increased the corrosion rate of X100from 51.6 to 96.7 mpy. The effect of H2S on the corrosion rate was similar for X80. The corrosion rate for X80 increased from 45.2 to 80.2 mpy when H2S was added to the test solution. Addition of H2S enhanced the anodic kinetics by forming a catalyst (FeHSads) on the metal surface and as a result, shifted the anodic polarization curve to more current densities. Moreover, the cathodic half cell potential increased due to the decrease in pH, from 2.9 to 2.7, which shifted the cathodic polarization curve to more current densities. The increase in both the anodic and cathodic currents, after H2S addition, caused the rise in the corrosion current density.
In H2S saturated NACE TM-0177 "A" solution, the X100 steel corrosion rate was higher than the X80 steel by 20%. Longer phase boundaries and larger nonmetallic inclusions in the X100 microstructure generated more areas with dissimilar corrosion potentials and therefore, a stronger driving force for corrosion. Higher density of second phase regions and larger nonmetallic inclusions acted as an increased cathode area on the X100 surface which increased the cathodic current density and consequently, increased the corrosion current density.
Proof ring tests on the X100 gave a threshold stress value, C5th, of 46% YS, 343.1 MPa(49.7 ksi). The main failure was caused by SSC cracking. SSC nucleated at corrosion pits on the metal surface and microcracks in the metal body and propagated perpendicular to the applied stress. Hydrogen Induced Cracking (HIC) was observed in the X100. HIC cracks nucleated at banded martensite-ferrite interfaces and propagated along the rolling direction parallel to the applied tensile stress through the softer ferrite phase.
When compared to older HSLA grades, the X100 tested in this study had a high SSC susceptibility and therefore, is not be recommended for H2S service applications. The high X100 SSC susceptibility was caused by the material high corrosion rates in H2Smedia which formed corrosion pits that acted as crack initiation sites on the metal surface and provided more hydrogen that migrated into the steel. In addition, the X100
inhomogeneous microstructure provided a high density of hydrogen traps in front of the main crack tip which promoted SSC microcrack formation inside the metal. Microcracks in the metal body connected with the main crack tip that originated from corrosion pits which assisted SSC propagation.
2
Rytirova, Lenka. "Etude de la dégradation par l'hydrogène des aciers micromaillés et duplex : influence de la microstructure." Châtenay-Malabry, Ecole centrale de Paris, 2006. http://www.theses.fr/2006ECAP1028.
Full textAbstract:
Les installations pétrolières ou de gaz naturel peuvent être contaminées par H2S humide. Cet environnement est très agressif pour les aciers utilisés pour le transport ou les procédés liés à ces produits, car il peut provoquer l'absorption d'hydrogène par l'acier. En l'absence de contrainte, cet hydrogène peut causer une fissuration (Hydrogen Induced Cracking, HIC). En présence de contrainte appliquée ou résiduelle, une rupture peut se produire par un mécanisme dit de fissuration sous contrainte en présence d’hydrogène sulfuré (Sulphide Stress Cracking, SSC) ou de fissuration orientée induite par l'hydrogène (Stress Oriented Hydrogen Induced Cracking, SOHIC). La résistance des aciers est étroitement reliée aux caractéristiques microstructurales : inclusions non métalliques, constituants de phase dure, structure en bandes, etc. Cette thèse présente les résultats de tests de résistance à HIC et SCC d'aciers pour pipelines : deux aciers au carbone peu alliés (X52 et X 60) et un acier inoxydable 22-05 de type duplex (microstructure mixte d'austénite et ferrite). Ces matériaux ont été testés conformément aux normes NACE TM 0284 (HIC) et TM 0177, méthode A (SSC). Des essais de perméation électrochimique ont été réalisés pour compléter notre connaissance du comportement de ces matériaux en présence d'hydrogène (diffusivité, piégeage), et quelques essais de perméation ont été suivis de dosage de l'hydrogène piégé par dégazage sous vide à 600 °C. Les essais ont été réalisés en prenant en compte l'orientation des échantillons par rapport au sens de laminage, ainsi que l'état structural : état brut de réception (AR) et état après traitement thermique (HT)Petroleum and natural gas systems can be contaminated with aqueous H2S. This environment is very aggressive to the steels used for the transport and processing of these products. Hydrogen absorption into steel may result, and provokes hydrogen induced cracking(HIC) in the absence of applied stress. In the presence of applied or residual stress, the failure process can occur by sulphide stress cracking (SSC) or stress oriented hydrogen induced cracking (SOHIC). The resistance of steels is closely related to the microstructure features: non-metallic inclusions, hard phase constituents, banded structures etc. This thesis summarizes results of HIC and SSC resistance of pipelines steels: two carbon micro alloyed steels (X52 and X60 according to API 5L Specification) and one 225 duplex stainless steel (austenite – ferrite microstructure). Materials have been tested according to NACE TM 0284 (HIC) and TM 0177 - Method A (SSC). To obtain detailed information about material behaviour in the presence of hydrogen, electrochemical permeation tests were performed as well. This method lets know the hydrogen diffusivity in these materialsand the hydrogen trapping. Some permeation tests were followed by vacuum outgasing at 600°C, to obtain information about irreversible trapping. The different tests have been achieved in as-received state (AR, after rolling) and after a laboratory heat treatment (HT, quenching and tempering). Influence of samples taking orientation has been also examined. Microstructure and fracture surfaces of broken SSC specimens analysis was performed by means of optical metallography and scanning electron microscopy
3
Malheiros, Livia Cupertino. "Study of Structure, Hydrogen Diffusion and Trapping, Plasticity and Fracture towards the Comprehension of Hydrogen-Assisted Cracking of High-Strength Low-Alloy Martensitic Steels." Thesis, La Rochelle, 2020. http://www.theses.fr/2020LAROS022.
Full textAbstract:
Le défi que représente le développement d'aciers pour oil country tubular goods (OCTG) avec une résistance mécanique de plus en plus élevée tout en maintenant une résistance suffisante au sulfide stress cracking (SSC) motive cette recherche vers une meilleure compréhension de la fragilisation par l'hydrogène des aciers martensitiques revenus faiblement alliés. La caractérisation structurale est réalisée par de multiples techniques,notamment le MEB-EBSD, le MET, la DSC, la DRX synchrotron et conventionnelle. Les résultats sont liés aux paramètres de diffusion et de piégeage provenant de la perméation électrochimique (EP) et de la spectroscopie de désorption thermique (TDS). Ils sont principalement examinés en termes de densité de dislocation, de concentration de lacune, de limite d'élasticité, de composition et de température de revenu pour dix aciers martensitiques. Des essais de traction, de charge-décharge et de relaxation des contraintes sont réalisés sans hydrogène, après pré-chargement et désorption de l'hydrogène, et sous flux d'hydrogène pour évaluer l'impact du piégeage et de la mobilité de l'hydrogène dans les interactions hydrogène-plasticité. Pour l'essai sous flux d'hydrogène, une cellule de perméation électrochimique est construite sur une machine de traction, ce qui permet de surveiller en continu le flux global d'hydrogène et la charge mécanique pendant l'essai de traction des éprouvettes entaillées et non entaillées. En faisant varier les géométries des entailles et les densités de courant de polarisation cathodique, nous avons testé la susceptibilité des aciers à la fissuration assistée par l'hydrogène sous différentes intensités de flux et de concentration d'hydrogène pour plusieurs états mécaniques. Les essais sur des échantillons pré-chargés ont révélé que l'hydrogène profondément piégé a un impact mineur sur le comportement mécanique et la rupture, tandis que l'hydrogène mobile entraîne une rupture fragile par quasi clivage aux surfaces d'entrée de l'hydrogène. Les résultats de l'essai de perméation sous charge de traction sont intégrés dans la modélisation par éléments finis (FEM). Les conditions macroscopiques et locales (issues de la FEM) pour le développement de la rupture par quasi-clivage assistée par l'hydrogène sont évaluées, ainsi que la sensibilité de ces conditions de seuil (contrainte, déformation plastique, flux et concentration d'hydrogène) à l’intensité de la polarisation cathodique appliquéeThe challenge of developing steels for sour service oil country tubular goods (OCTG) with mechanical strengthhigher and higher maintaining a sufficient resistance to sulfide stress cracking (SSC) motivates this researchtowards a better understanding of the hydrogen embrittlement of low-alloy tempered martensitic steels. Structuralcharacterization is performed by multiple techniques including SEM-EBSD, TEM, DSC, synchrotron andconventional XRD. The results are related to diffusion and trapping parameters from electrochemical permeation(EP) and thermal desorption spectroscopy (TDS), being mostly discussed in terms of dislocation density, vacancyconcentration, yield strength, composition and tempering temperature for ten martensitic steels. Tensile, loadingunloadingand stress-relaxation tests are completed without hydrogen, after hydrogen pre-charging and desorption,and under hydrogen flux to evaluate the impact of hydrogen trapping and mobility on the hydrogen-plasticityinteractions. For the test under hydrogen flux, an electrochemical permeation cell is built on a mechanical testingmachine, which allows continuous monitoring of the global hydrogen flux and mechanical loading during thetensile test of notched and unnotched specimens. By varying the notch geometries and the cathodic polarizationcurrent densities, we tested the susceptibility of the steels to hydrogen-assisted cracking under various intensitiesof hydrogen flux and concentration for several mechanical states. Tests on pre-charged specimens revealed thatdeeply trapped hydrogen has a minor impact on the mechanical behavior and fracture, whereas mobile hydrogenleads to brittle quasi-cleavage fracture at the hydrogen entry surfaces. The permeation test under tensile loadingresults are incorporated into finite elements modelling (FEM). Macroscopic and local (from FEM) conditions forthe development of hydrogen-assisted quasi-cleavage fracture are evaluated, as well as the sensitivity of thesethreshold conditions (stress, plastic strain, hydrogen flux and concentration) to the severity of the applied cathodicpolarization
4
Guedes, Sales Daniella. "Etude des mécanismes d'endommagement d'aciers martensitiques associés au SSC (Sulphide Stress Cracking)." Thesis, La Rochelle, 2015. http://www.theses.fr/2015LAROS041.
Full textAbstract:
Dans le cadre de ces travaux, il a clairement été établi que l’hydrogène piégé ou diffusible pouvait avoir une forte influence sur les propriétés mécaniques des matériaux. Cependant, cet effet varie de façon importante en fonction de leur microstructure, leur composition chimique et leur traitement thermique. En effet, les aciers martensitiques trempés/revenus dédiés à des tubes pour des milieux sous-service présentent, de par leur structure, différents types de pièges tels que les dislocations, les joints de grains, les précipités, les inclusions, les lacunes et d’autres interfaces qui jouent un rôle important dans les mécanismes endommageants. Ces aciers de haute résistance mécanique, lorsqu’ils sont soumis à des contraintes mécaniques et à un environnement agressif (qui dépend de la pression en H2S et du pH de la solution) peuvent rompre à cause du phénomène de Sulphide Stress Cracking (SSC). Ce dernier est une forme de fragilisation par l’hydrogène (FPH) qui inclut un amorçage de fissure suivi d’une étape de propagation conduisant à la rupture, dont la contribution de l’hydrogène reste encore mal comprise. En parallèle de l’impact de la microstructure de l’acier, les champs de contrainte et déformation subis par le matériau modifient les effets induits par l’hydrogène. C’est pourquoi un montage de perméation sous contrainte a été utilisé afin de pouvoir réaliser des essais mécaniques jusqu’à rupture sous flux d’hydrogène et les comparer au comportement du matériau lorsque celui-ci est sollicité à l’air ou dans un environnement H2S. Ainsi, l’impact sur le comportement mécanique du flux d’hydrogène mais également de son piégeage peut être étudié. Dans ce cadre, des éprouvettes plates et axisymétriques, lisses et entaillées ont été employées. Les informations expérimentales obtenues dans ce travail ont servi à alimenter un modèle numérique qui a permis de caractériser localement l’état mécanique et les concentrations d’hydrogène piégé et diffusible dans le matériau. Ceci a rendu possible la définition d’un critère local de ruptureThe findings of this work established that the diffusible and trapped hydrogen could have a strong influence on the mechanical properties of materials. However, this effect varies significantly with the materials’ microstructure, chemical composition, and heat treatment. Due to their structure, quenched and tempered martensitic steels (developed for tubes suitable for sour service environments) have different types of traps such as dislocations, grain boundaries, precipitates, inclusions, vacancies and other interfaces that play an important role in the damage mechanisms. These high strength steels may break due to Sulphide Stress Cracking (SSC) if subjected to mechanical stress and an aggressive environment (which depends on the H2S partial pressure and pH solution). This phenomenon is a form of hydrogen embrittlement (HE) that includes a crack initiation followed by a propagation step leading to failure. However the hydrogen contribution is still insufficiently understood. In addition to the impact of the microstructure on the steel, the stress and the deformation fields in the material also modify the effects induced by hydrogen. To investigate this event, electrochemical permeation tests under stress were used to perform mechanical tests under hydrogen flux until failure is reached. The results were compared to those mechanically loaded in air or in a H2S environment. This enabled the examination of the impact of the hydrogen flux and trapping on the mechanical behavior of martensitic steel. In this framework, flat and axisymmetric, smooth and notched specimens were employed. Experimental data obtained in this work were used to provide a numerical model that enables the locally characterization of the mechanical condition and the concentrations of trapped and diffusible hydrogen in the material. These outcomes enabled us to determine a local failure criterion
5
Della, Roverys Coseglio Mario Sergio. "Susceptibility of low-temperature plasma nitrided 17-4 PH (H1150D) to sulphide stress cracking (SSC) in typical oilfield environment." Thesis, University of Birmingham, 2018. http://etheses.bham.ac.uk//id/eprint/8488/.
Full textAbstract:
To attend the growing global demand for energy, oil production—expected to grow in the foreseeable future-relies on the extraction from unconventional resources, such as deep deposits off the coast and ultra-deep water. These environments are contaminated with significant amounts of hydrogen sulphide, a by–product that promotes hydrogen absorp- tion and subsequent failure by sulphide stress cracking (SSC). The 17-4 PH—a stainless steel widely used for oilfield components—is susceptible to SSC, in spite of its favourable combination of properties. In this study, plasma–based treatments, often used to improve wear resistance, were identified as potential methods to increase the resistance to SSC. To evaluate it, the 17-4 PH was surface–modified by conventional and low–temperature plasma nitriding (LTPN) and submitted to standard SSC experiments. LTPN resulted in superior resistance to SSC compared to both unmodified and HTPN conditions, at- tributed to the formation of a nitrogen–rich layer comprising mixed iron nitrides (ε–Fe2-3N and γ’–Fe4N) and expanded martensite without precipitation of chromium nitrides. The protection provided by this structure was mainly due to the compressive residual stress induced by nitriding, combined with the superior resistance to localise corrosion and the reduced hydrogen uptake by the substrate.
6
Chasse, Kevin Robert. "A study on the mechanism of stress corrosion cracking of duplex stainless steel in hot alkaline-sulfide solution." Diss., Georgia Institute of Technology, 2012. http://hdl.handle.net/1853/42793.
Full textAbstract:
Corrosion and stress corrosion cracking of structural components cost an estimated $300 billion annually in the United States alone and are a safety concern for a number of industries using hot alkaline environments. These process environments may contain different amounts of sulfide and chloride; however, the combined role of these ions on the stress corrosion cracking of duplex stainless steels, which are widely used because of their generally reliable performance, had never been studied. This study shows that chlorides in sulfide-containing caustic environments actually have a significant influence on the performance of these alloys. A mechanism for stress corrosion cracking of duplex stainless steels in hot alkaline environments in the presence of sulfide and/or chloride was proposed. Microstructural and environmental aspects were studied using mechanical, electrochemical, and film characterization techniques. The results showed that selective corrosion of the austenite phase depended on percent sulfidity, alkalinity, and chloride content. Chlorides enhanced crack initiation and coalescence along the austenite/ferrite phase boundaries. Unstable passivity of duplex stainless steels in hot alkaline-sulfide environments was due to anion adsorption on the surface leading to defective film formation. Chlorides and sulfide available at the electrolyte/film surface reduced the charge transfer resistance and shifted the response of the films to lower frequencies indicating the films became more defective. The surface films consisted of an outer, discontinuous layer, and an inner, barrier layer. Fe, Mo, and Mn were selectively dissolved in alkaline and alkaline-sulfide environments. The onset of stress corrosion cracking was related to the extent of selective dissolution and was consistent with a film breakdown and repair mechanism similar to slip-step dissolution. Recommendations for reducing the susceptibility of duplex stainless steels to stress corrosion cracking in sulfide-containing caustic environments include reducing the chloride to hydroxide ratio and alloying with less Mo and Mn. The results will impact the petrochemical, pulp and paper, and other process industries as new duplex grades can be developed with optimal compositions and environments can be controlled to extend equipment life.
7
Hazlewood, Patrick Evan. "Factors Affecting the Corrosivity of Pulping Liquors." Diss., Georgia Institute of Technology, 2006. http://hdl.handle.net/1853/10531.
Full textAbstract:
Increased equipment failures and the resultant increase in unplanned downtime as the result of process optimization programs continue to plague pulp mills. The failures are a result of a lack of understanding of corrosion in the different pulping liquors, specifically the parameters responsible for its adjustment such as the role and identification of inorganic and organic species. The current work investigates the role of inorganic species, namely sodium hydroxide and sodium sulfide, on liquor corrosivity at a range of process conditions beyond those currently experienced in literature. The role of sulfur species, in the activation of corrosion and the ability of hydroxide to passivate carbon steel A516-Gr70, is evaluated with gravimetric and electrochemical methods. The impact of wood chip weathering on process corrosion was also evaluated. Results were used to identify black liquor components, depending on the wood species, which play a significant role in the activation and inhibition of corrosion for carbon steel A516-Gr70 process equipment. Further, the effect of black liquor oxidation on liquor corrosivity was evaluated. Corrosion and stress corrosion cracking performance of selected materials provided information on classes of materials that may be reliably used in aggressive pulping environments.
8
Dai, Tao Dai. "Effect of Postweld Heat Treatment on the Properties of Steel Clad with Alloy 625 for Petrochemical Applications." The Ohio State University, 2018. http://rave.ohiolink.edu/etdc/view?acc_num=osu1523572474171801.
Full text
9
Ruel, Fiona. "Contribution électrochimique à l’étude de la corrosion sous contrainte des aciers inoxydables lean duplex en milieu purement chloruré et sous présence de sulfure d’hydrogène." Thesis, Saint-Etienne, EMSE, 2014. http://www.theses.fr/2014EMSE0743/document.
Full textAbstract:
Les aciers inoxydables lean duplex, à faible teneur en nickel et sans molybdène, représentent une alternative économique pour les usines de dessalement et l’industrie pétrolière. Celles-ci ont la particularité d’être exposées à des milieux très agressifs dont la présence de chlorure, de sulfure d’hydrogène, de hautes températures ou encore d’acides peut provoquer des phénomènes de fissuration sous contrainte.Cette étude est divisée en deux parties, la première se consacre aux milieux purement chlorurés et la seconde aux milieux contenant du sulfure d’hydrogène. Dans les deux parties, la compréhension des phénomènes liés à la fissuration sous contrainte des lean duplex est effectuée sur la nuance S32304, puis est comparée aux comportements des nuances S32202 et S32101. L’influence des milieux bouillants sur la résistance à la fissuration des aciers inoxydables, les mécanismes de dépassivation et de dissolution sélective des lean duplex, les différents modes de fissuration en présence de sulfure d’hydrogène ou encore l’amorçage de la corrosion sous contrainte assistée par le sulfure d’hydrogène sont abordés dans ce rapportLean duplex stainless steels, with low content of nickel and without molybdenum, represent an economic alternative for desalting plants and petroleum industry. For these uses, steel have the particularity to be exposed to very aggressive environments inducing phenomenon of Stress Corrosion Cracking as chlorides, hydrogen sulphur, high temperatures or acids.This study is divided in two parts dedicated to two different environments. The first part is devoted to chloride middles and the second to hydrogen sulphur middles. In both parts, the understanding of phenomenon linked to the stress corrosion cracking of lean duplex is studied on the grade steel S32304, then is compared to the behaviour of grade steels S32202 and S32101. The topics treated in this report are notably the influence of boiling environments on the cracking resistance of stainless steels, the mechanism of unpassivation and selective dissolution of lean duplex, the different modes of cracking in presence of hydrogen sulphur, and the initiation of stress corrosion cracking assisted by hydrogen sulphur
10
蔡松雨. "On the stress corrosion cracking of alloy steels in sulfide containing chloride environments." Thesis, 1997. http://ndltd.ncl.edu.tw/handle/32633536776986814002.
Full textBooks on the topic "SSC (Sulfide Stress Cracking)"
1
Engineers, National Association of Corrosion. Sulfide stress cracking resistant metallic materials for oilfield equipment. Houston: NACE, 2001.
Find full text
2
National Association of Corrosion Engineers. Sulfide stress cracking resistant metallic materials for oilfield equipment. Houston: NACE, 1999.
Find full text
3
National Association of Corrosion Engineers. Sulfide stress cracking resistant metallic materials for oilfield equipment. Houston: NACE, 1997.
Find full text
4
National Association of Corrosion Engineers. Sulfide stress cracking resistant metallic materials for oilfield equipment. Houston: NACE, 1995.
Find full text
5
Engineers, National Association of Corrosion. Laboratory testing of metals for resistance to sulfide stress cracking in H2S environments. Houston: NACE, 1990.
Find full text
6
National Association of Corrosion Engineers. Technical Practices Committee. Test method: Testing of metals for resistance to sulfide stress cracking at ambient temperatures. Houston: NACE, 1986.
Find full text
7
Sriskandarajah, T. Sulphide stress corrosion cracking of oil and gas well equipment: Report. London: H.M.S.O., 1987.
Find full text
8
National Association of Corrosion Engineers., ed. Metals for sulfide stress cracking and stress corrosion cracking resistance in sour oilfield environments. Houston: NACE, 2003.
Find full text
9
National Association of Corrosion Engineers., ed. Materials resistant to sulfide stress cracking in corosive petroleum refining environments. Houston: NACE, 2003.
Find full text
10
National Association of Corrosion Engineers., ed. Standard recommended practice: Sulfide stress cracking resistant metallic materials for oilfield equipment. Houston: NACE, 2000.
Find full textBook chapters on the topic "SSC (Sulfide Stress Cracking)"
1
Kane, Russell D. "Sulfide Stress Cracking." In Oil and Gas Pipelines, 343–52. Hoboken, New Jersey: John Wiley & Sons, Inc., 2015. http://dx.doi.org/10.1002/9781119019213.ch24.
Full text
2
Elboujdaini, M. "Hydrogen-Induced Cracking and Sulfide Stress Cracking." In Uhlig's Corrosion Handbook, 183–94. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2011. http://dx.doi.org/10.1002/9780470872864.ch15.
Full text
3
King, Roger A. "Sulfide stress cracking." In Trends in Oil and Gas Corrosion Research and Technologies, 271–94. Elsevier, 2017. http://dx.doi.org/10.1016/b978-0-08-101105-8.00011-5.
Full text
4
"Failure Analysis: Sulfide Stress Corrosion Cracking and Hydrogen-Induced Cracking of A216-WCC Wellhead Flow Control Valve Body." In Handbook of Case Histories in Failure Analysis, 475–82. ASM International, 2019. http://dx.doi.org/10.31399/asm.fach.v03.c9001820.
Full text
5
"Corrosion of Martensitic Stainless Steel Weldments." In Corrosion of Weldments, 115–24. ASM International, 2006. http://dx.doi.org/10.31399/asm.tb.cw.t51820115.
Full textAbstract:
Abstract Martensitic stainless steels are essentially iron-chromium-carbon alloys that possess a body-centered tetragonal crystal structure (martensitic) in the hardened condition. Martensitic stainless steels are similar to plain carbon or low-alloy steels that are austenitized, hardened by quenching, and then tempered for increased ductility and toughness. This chapter provides a basic understanding of grade designations, properties, corrosion resistance, and general welding considerations of martensitic stainless steels. It also discusses the causes for hydrogen-induced cracking in martensitic stainless steels and describes sulfide stress corrosion resistance of type 410 weldments.
Conference papers on the topic "SSC (Sulfide Stress Cracking)"
1
Thodla, Ramgopal, Robin Gordon, and Feng Gui. "Effect of Reeling on Sulfide Stress Corrosion Cracking of Welded API5LX65 Line Pipe." In ASME 2015 34th International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2015. http://dx.doi.org/10.1115/omae2015-42414.
Full textAbstract:
The effect of reeling on sulfide stress cracking (SSC) resistance of welded line pipe was investigated in two different environments, a modified NACE B environment and a fitness for service environment (pH = 5/pH2S = 0.46psia). Micro hardness maps were performed to characterize the welds both in the as fabricated condition as well as in the strained and aged condition. The hardness values in all of the conditions, was less than 250VHN (in compliance with NACE requirements). Triplicate specimens were tested in the as fabricated, strained and aged intrados and extrados in both the environments. SSC resistance in a severely sour environment (pH = 3.5/1psia H2S) was affected by reeling with cracking observed in both the intrados and extrados samples. No cracking was observed in the as-fabricated welds. However, in a moderately sour environment (pH = 5/0.46psia H2S) reeling did not have a detrimental effect on the SSC performance. No evidence of cracking on the as-fabricated, intrados, and extrados welds. In moderate sour service reeling doesn’t appear to have a detrimental effect on the SSC behavior.
2
Kisaka, Yuji, and Adrian P. Gerlich. "Review and Critical Assessment of Hardness Criterion to Avoid Sulfide Stress Cracking in Pipeline Welds." In ASME 2016 Pressure Vessels and Piping Conference. American Society of Mechanical Engineers, 2016. http://dx.doi.org/10.1115/pvp2016-63198.
Full textAbstract:
Although employing high strength steels in pipelines provides many benefits, it is difficult to satisfy all required mechanical properties simultaneously because some are potentially at odds with each other. Additionally, when new natural gas pipelines are constructed for severe sour service, the hardness must be below 248 Vickers to avoid sulfide stress cracking (SSC) regardless of pipe grades, and this has been standardized by NACE and applied for approximately five decades. On the other hand, the relevance of this hardness criterion has been controversial. This paper proposes three possible methods to improve SSC resistance for weld metals; 1) reducing impurities, 2) producing fine and homogeneous microstructure, 3) controlling microstructures that characterize high hydrogen permeability, solubility, and low diffusivity. This paper states that reducing impurities and producing fine and homogeneous microstructure would reduce SSC susceptibility and an acicular ferrite would be the effective microstructure to increase SSC resistance for weld metals.
3
Ramirez, Guillermo, Kollin Kenady, and Joshua E. Jackson. "A Method for Field Evaluation of Heat Treatment to Identify Vessels That Are Susceptible to Sulfide Stress Cracking." In ASME 2017 Pressure Vessels and Piping Conference. American Society of Mechanical Engineers, 2017. http://dx.doi.org/10.1115/pvp2017-65216.
Full textAbstract:
Inadequate heat treatment in the head and head-to-shell weld areas of a low-pressure separator vessel was determined to have led to conditions which allowed for the development of sulfide stress cracks, and ultimately resulted in rupture of the vessel. This determination was made through the use of destructive testing and failure analysis of the ruptured vessel. Generally, verification of vessel heat treatment is done through review of temperature recordings from manufacturing documentation or third party verification at the time of fabrication. Unfortunately, heat treatment records of pressure vessels are often misplaced, lost during acquisitions/mergers, or simply never existed. Under the assumption that these vessels were adequately heat treated, the vessel’s owners do not normally take into consideration the high residual stresses which create favorable conditions for sulfide stress cracking (SSC) and other stress corrosion cracking type damage mechanisms. In this case, cold formation of the head resulted in high residual stresses in the flange and knuckle regions. The welds, which had not been properly post-weld heat treated, similarly had high residual stresses. These high stresses resulted in favorable conditions for the SSC to occur when exposed to a corrosive environment such as oil and gas operations. In an effort to prevent similar events from occurring in the future, it was determined to be necessary to evaluate other vessels for inadequate heat treatment that may result in SSC. A non-destructive approach was investigated to evaluate vessels, especially in the absence of the aforementioned heat treatment records, to determine if the formed heads and heat affected zones after welding had adequate heat treatment. A method was developed to identify vessels without adequate heat treatment utilizing standard non-destructive testing techniques. There is the potential that many other low pressure vessels in lethal service could have received inadequate heat treatment. This methodology can therefore be used to determine the heat treatment state for these pressure vessels without destructive testing.
4
Kobayashi, Kenji, Tomohiko Omura, Masahiko Hamada, Hiroyuki Nagayama, Izuru Minato, and Yuki Nishi. "Full Ring Evaluation of X70 Grade UOE Line Pipes for Sour Service." In 2012 9th International Pipeline Conference. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/ipc2012-90417.
Full textAbstract:
High-strength large-diameter UOE line pipes over X70 grade are difficult to apply to actual fields, including H2S, because of a deterioration of sour resistance and a lack of past performance. However, API X70 grade large-diameter UOE line pipes for sour service have been manufactured stably by optimizing the continuous casting process, controlling the shape of inclusions and decreasing coarse precipitates. A full-ring test can simulate fairly well the actual applied conditions of line pipes and evaluate hydrogen induced cracking (HIC), sulfide stress cracking (SSC) and stress oriented hydrogen induced cracking (SOHIC) of line pipes for sour service simultaneously. It was confirmed that the X70 grade UOE line pipes have a good sour resistance from standard HIC tests, four-point bent beam SSC tests and the full-ring test including a seam weld under severe sour conditions (NACE solution A with 0.1 MPa H2S). In addition, the SSC resistance of a girth welded portion was also investigated by using simulated HAZ.
5
Scheel, Jeremy E., and Douglas J. Hornbach. "The Effect of Surface Enhancement on Improving the Fatigue and Sour Service Performance of Downhole Tubular Components." In ASME 2012 International Mechanical Engineering Congress and Exposition. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/imece2012-87482.
Full textAbstract:
Sulfide stress cracking (SSC) and hydrogen embrittlement (HE) prevent the use of high strength carbon steel alloys in the recovery of fossil fuels in H2S containing ‘sour’ environments commonly experienced in deep well fossil fuel recovery efforts. Couplings are a common weak point in casing strings as high magnitude mean tensile stresses are generated by connection interferences created during power make-up of downhole tubular components. When subject to service loads both mean and alternating stresses are increased further providing the high tensile stresses necessary for SSC initiation. Since high strength carbon steel alloys are not typically suited for sour service environments, the current solution is to use or develop much more expensive alloys with increased corrosion-cracking resistance, or limit their use to significantly weaker sour environments, or higher operating temperatures. Failure due to fatigue is another major problem in downhole tubular components. Likelihood of fatigue failure is further exacerbated in corrosive environments (such as H2S and NaCl), commonly encountered in service. The cost for detecting the impending failure before final separation is dramatic at a factor 10X. A cost effective method of mitigating failure from SSC and corrosion fatigue would greatly reduce operational costs and extend component life. Introduction of stable, high magnitude compressive residual stresses into less expensive carbon steel alloys alleviates the tensile stresses, and mitigates SSC, while also improving fatigue performance. Low plasticity burnishing (LPB) is an advanced surface enhancement process providing a means of introducing compressive residual stresses into metallic components for enhanced fatigue, damage tolerance, and SCC performance. The effects of LPB on high cycle fatigue (HCF) and SSC were evaluated on quench and tempered API P110 grade steel. LPB processed specimens had an increase in fatigue life greater than an order of magnitude over untreated specimens. LPB was successful in completely mitigating SSC in all test specimens at tensile stresses up to 90% specified minimum yield strength (SMYS). The initial results indicate that LPB processing of P110 steel provides an economical means of SSC mitigation and fatigue strength improvement in sour environments.
6
Forero Ballesteros, Adriana, Jose´ A. da Cunha Ponciano, and Ivani de S. Bott. "Study of the Susceptibility of API 5L X80 Girth Welds to Sulfide Stress Corrosion Cracking and Hydrogen Embrittlement." In 2010 8th International Pipeline Conference. ASMEDC, 2010. http://dx.doi.org/10.1115/ipc2010-31243.
Full textAbstract:
The growing demand for natural gas and oil, as energy sources, has driven industry’s need for ever-increasing strength levels in oil and gas transmission pipeline materials in order to achieve safe and economic transportation. The current world trend points to the use of pipes with larger diameters and thinner wall thicknesses, operating under high pressure. In addition, pipeline steels for sour service must exhibit good Hydrogen Induced Cracking (HIC) and Sulphide Stress Corrosion Cracking (SSCC) resistance. This study evaluates the susceptibility of API 5L-X80 girth welds to SSCC and Hydrogen Embrittlement (HE). Slow strain rate tensile (SSRT) tests and Hydrogen Permeation tests were performed at room temperature, in different acidic environment containing sodium thiosulfate solutions. Most of the SSRT tests undertaken in solution, showed a loss of ductility and a decrease in the reduction of area, as compared with tests conducted in air. The susceptibility to HE and potentially SSCC was evidenced by a reduction in ductility in the SSRT tests and an increase in the hydrogen permeation current values, for almost all welded joints. This was observed with greater intensity for the more acidic test solutions (pH = 3.4), while for the less acidic test solutions (pH = 4.4) little loss of ductility was observed and the hydrogen permeation current remained at values close to zero, indicating little or no permeation of hydrogen through the metal for the testing times applied. The behaviour exhibited by the samples tested in the more acidic solutions was attributed to the dissolution of material from the sample together with hydrogen embrittlement. These results confirmed that the use of sodium thiosulfate solutions to generate H2S, permits the study of phenomena related to SCC in environments containing sulphides.
7
Xu, Shugen, Weiqiang Wang, and Huadong Liu. "The Stress Corrosion Cracking of Austenitic Stainless Steel Heat Exchange Tubes: Three Cases Study." In ASME 2010 Pressure Vessels and Piping Division/K-PVP Conference. ASMEDC, 2010. http://dx.doi.org/10.1115/pvp2010-25217.
Full textAbstract:
In this paper, three leakage failure cases of heat exchange tubes have been introduced. The reasons of the leakage for austenitic stainless steel tubes and overlay welding layer on the tube sheet have been analyzed. Through the investigation of the operation process and histories of the equipment, and after chemical compositions analysis of tube material and corrosion products, metallographic test of specimens with cracks, and fracture surface scan with Scanning Electron Microscope (SEM), the cracking reason and mode are described as the Stress Corrosion Cracking (SCC) of austenitic stainless steel. This kind of cracking in three cases was induced by the micro chloride in the high temperature water (or steam). Moreover, sulfide and dissolved oxygen also reduced the threshold value of chloride concentration and enhanced the corrosion rate for SCC. The cracking mode of Case A and B are transgranular; and Case C is intergranular. It indicates that for this kind of in-service heat exchanger, the operators should not only control the chloride concentration in feed water, but also the sulfide and dissolved oxygen in the future. The austenitic stainless steel tubes (China steel types-1Cr18Ni9Ti and 0Cr18Ni10Ti, equal to Type 304 and Type 321 according to ASME code) used in this cases are not fit to this condition. Thus, for the new heat exchanger design, the tube material should be changed into austenitic-ferritic (duplex phase) steel, such as 2205 Series, which has an excellent performance for SCC resistance in the high temperature water (or steam) with chloride.
8
Vega, Oscar E., Jose´ M. Hallen, Agusti´n Villagomez, and Antonio Contreras. "Microstructure, Mechanical Properties and SSC Susceptibility of Multiple SMAW Repairs in Line Pipe Girth Welds." In 2008 7th International Pipeline Conference. ASMEDC, 2008. http://dx.doi.org/10.1115/ipc2008-64187.
Full textAbstract:
Girth welds of seamless API X52 steel pipe containing multiple shielded metal arc welding (SMAW) repairs and one as-welded condition were studied. Microstructural characterization, mechanical behavior and sulfide stress corrosion cracking (SSC) susceptibility of the welded joints were evaluated by means of optical and scanning electron microscopy, hardness, tension, Charpy-V impact resistance and slow strain rate tests (SSRT). The results of this work indicate that increasing the number of welding repairs promotes grain growth in the heat affected zone (HAZ). The yield strength (YS) and ultimate tensile strength (UTS) for the different welding repairs satisfy the specified minimum values of the material. Significant reduction in Charpy-V impact resistance with the increases of the number of repairs was found in the coarse grained heat affected zone (CGHAZ). A high susceptibility to SSC was exhibited by the welded joints and the intercritical heat affected zone was the most susceptible area to SSC.
9
Ponciano, Marcos, Luis Claudio C. Chad, Marcelo Jose B. Teixeira, Vinicius R. de Abreu Lima, Helder Heleno Ferreira, and Monica C. Riccio Ribeiro. "High Toughness API 5L X70MS Pipe Grade Development for Deep and Ultradeep Water Application." In ASME 2012 31st International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/omae2012-83491.
Full textAbstract:
The offshore deep and ultra deep water explorations summed to the distant points of the Brazilian coast bring to national industry important technological challenges. Considering production and transportation need of large volumes of natural gas and oil in a safe condition from offshore installations, the use of large diameter steel pipes produced by UOE-SAWL process is an important alternative and already applied in some important projects. However, due to the hostile environment in which the new fields are placed, it is necessary to develop new products in order to meet the rigorous mechanical properties and Sulfide Stress Cracking (SSC) and Hydrogen Induced Cracking (HIC) resistance requirements. This work presents the evaluation of mechanical properties and SSC resistance of OD 20 inches, WT 25,4 mm APL 5L X70MS line pipe, for both pipe material and girth weld joints. For this work, plates were produced with very restrict metallurgical control, including chemical control and state of art rolling as Thermo-Mechanical Controlled Process with Accelerated Cooling — TMCP-ACC. Very good CHARPY and CTOD values were achieved at −20°C and −40°C respectively, in both conditions, and the pipes presented good (SSC and HIC) resistance even for the girth weld joint performed with a low and high heat inputs simulating the range of conditions that an operator would find in offshore welding operations.
10
Shitamoto, Hidenori, Masayuki Sagara, Hisashi Amaya, Nobuyuki Hisamune, Daisuke Motoya, and Yuuki Watatani. "Effect of Reeling Simulation on the Mechanical Properties of New Duplex Stainless Steel for Line Pipe." In ASME 2014 33rd International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2014. http://dx.doi.org/10.1115/omae2014-23694.
Full textAbstract:
Corrosion resistant alloys (CRAs) such as martensitic and duplex stainless steels (DSS) are used as a flow line material in corrosive wet gas environments (i.e., carbon dioxide and hydrogen sulfide environments). A new DSS which consists of 25mass%Cr - 5mass%Ni - 1mass%Mo - 2.5mass%Cu has been developed for line pipe usage in slightly sour environments. There are several methods currently being used to install offshore oil and gas pipelines. The reel-lay process is fast and one of the most effective offshore pipeline installation methods for seamless, ERW, and UOE line pipes with outside diameters of 18 inches or less. In the case of the reel-laying method, line pipes are subjected to plastic deformation multiplication during reel-laying. Thus, it is important to understand the change of the mechanical properties of line pipes before and after reel-laying. In this study, full-scale reeling (FSR) simulations and small-scale reeling (SSR) simulations were performed to investigate the effect of cyclic deformation on the mechanical properties of the new DSS for line pipe. Furthermore, investigation of the most susceptible temperature range to cracking and sulfide stress cracking (SSC) tests were performed in slightly sour conditions.