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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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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.
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Abas, Ahmad Zaki, Azmi Mohammed Nor, Muhammad Firdaus Suhor, Ahmad Mustaza Ahmad Rusli, and Mokhtar Che Ismail. "HIC and SSC of Carbon Steel in High Partial Pressure CO2 Environments with Elevated H2S." E3S Web of Conferences 287 (2021): 02001. http://dx.doi.org/10.1051/e3sconf/202128702001.
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The Hydrogen Induced Cracking (HIC) and Sulfide Stress Cracking (SSC) behaviours of sour service and non-sour service carbon steel API 5L X65 were investigated under high pressure carbon dioxide environments, containing elevated amount of hydrogen sulphide (H2S); the test environments simulated offshore pipelines transporting full-well streams in high carbon dioxide (CO2) environments with elevated H2S concentrations. It was systematically studied under standard NACE condition and high pressure carbon dioxide field condition with variation in other key parameters (temperature, pressure and hydrogen sulfide concentration). The HIC and SSC were tested using a High Pressure and High Temperature (HPHT) Autoclave. The surface cracking morphology was analysed using Scanning Electron Microscopy (SEM), Ultrasonic Technique (UT) and Magnetic Particle (MP). The results showed that no cracks were detected in NACE standard and field-condition SSC tests for both sour service and non-sour services carbon steel. In HIC test, crack was detected on non-sour service carbon steel in NACE standard test while no crack was detected on field condition-based tests for both types of carbon steel.
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Kobayashi, Kenji, Tomohiko Omura, and Shinji Fujimoto. "Effects of Environmental Factors on Hydrogen Absorption and Sulfide Stress Cracking Susceptibility of Low Alloy Steel." Corrosion 76, no. 7 (May 3, 2020): 698–706. http://dx.doi.org/10.5006/3414.
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In this study, the sulfide stress cracking (SSC) susceptibility of high-strength low alloy steels was investigated quantitatively. Double cantilever beam tests were used to evaluate the effects of environmental factors, namely pH, H2S partial pressure, and temperature, on the SSC. The corrosion rates and the absorbed diffusible hydrogen concentration were also determined. The critical stress intensity factor (KISSC), which signifies the SSC susceptibility, was mainly affected by the H2S partial pressure and the temperature. Even though the solution pH apparently affected the corrosion rate, the influence of pH on KISSC was small. Considering these results, the environmental contribution in each elementary process of the SSC phenomenon was discussed. The estimated local hydrogen concentration at the crack tip area, which clearly depends on H2S partial pressure and temperature, showed good correlation to the KISSC obtained in various sour conditions.
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Traidia, Abderrazak, Elias Chatzidouros, and Mustapha Jouiad. "Review of hydrogen-assisted cracking models for application to service lifetime prediction and challenges in the oil and gas industry." Corrosion Reviews 36, no. 4 (July 26, 2018): 323–47. http://dx.doi.org/10.1515/corrrev-2017-0079.
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AbstractThe present manuscript reviews state-of-the art models of hydrogen-assisted cracking (HAC) with potential for application to remaining life prediction of oil and gas components susceptible to various forms of hydrogen embrittlement (HE), namely, hydrogen-induced cracking (HIC), sulfide stress cracking (SSC), and HE-controlled stress corrosion cracking (SCC). Existing continuum models are compared in terms of their ability to predict the threshold stress intensity factor and crack growth rate accounting for the complex couplings between hydrogen transport and accumulation at the fracture process zone, local embrittlement, and subsequent fracture. Emerging multiscale approaches are also discussed, and studies relative to HE in metals and especially steels are presented. Finally, the challenges that hinder the application of existing models to component integrity assessment and remaining life prediction are discussed with respect to identification of model parameters and limitations of the fracture similitude, which paves the way to new directions for further research.
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Davydov, Artem, Andrey Zhitenev, Natalya Devyaterikova, and Konstantin Laev. "Influence of Structural Heterogeneity of High-Strength OCTG Tubes on Sulfide Corrosion Cracking Resistance." Materials Proceedings 3, no. 1 (March 8, 2021): 5. http://dx.doi.org/10.3390/iec2m-09386.
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High-strength oil country tubular goods (OCTG) like C110, according to standard API 5CT (yield strength at least 758 MPa), are subject to requirements in terms of mechanical and corrosion properties. In this work, we studied the influence of seamless tubes microstructure with a 177.8 mm diameter and 10.36 mm wall thickness of class С110 high-strength steel to sulfide stress corrosion cracking (SSC) and sulfide stress corrosion cracking with low strain rates (SSRT). Tubes were obtained from continuous billets by screw piercing with preliminary quenching and tempering. It was established that cracking during the tests always begins from the inner surface of the tube. Rough segregation bands were found on the inner tube surface, which occupies about a third of the thickness. It is shown that the SSRT assessment technique allows to estimate the threshold value of the resistance.
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Khudyakov, Artem, and Pavel Danilkin. "Providing resistance to sulfide stress corrosion cracking of pipelines welded joints by selection of welding parameters." E3S Web of Conferences 121 (2019): 04005. http://dx.doi.org/10.1051/e3sconf/201912104005.
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Sulfide stress cracking (SSC) is one of the most dangerous types of pipelines destruction. Thermal impact of the welding process drives to heterogeneity of the microstructure and properties of the metal, which can lead to cracking of pipeline welded joints. Resistance to SSC of welded joints is determined by the thermal cycle of welding and cooling rate in the temperature range of austenite transformation. Due to performed studies based on simulation of welding heating the recommended range of cooling rates of 10–30 ° C/s was established, in which the resistance to SSC of welded joints is ensured. To calculate the cooling rates in coarse grained heat affected zone (CGHAZ) finite-element models of heat distribution were developed for longitudinal multi-electrode submerged arc welding (SAW) and multi-pass girth welding of pipes. Using the developed welding models, it was found that in order to achieve the cooling rate in CGHAZ it is necessary to reduce heat input up to 15-30% during multi-electrode SAW process of longitudinal welds of pipes . For multi-pass girth welding it is necessary to preheat the edges to be welded up to 100-300 °C depending on type of welding (GMAW or SMAW) and pipe wall thickness.
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Prabowo, Harris, Badrul Munir, Yudha Pratesa, and Johny W. Soedarsono. "Comparison of 2507 Duplex and 28 % Cr- Austenitic Stainless Steel Corrosion Behavior for High Pressure and High Temperature (HPHT) in Sour Service Condition with C-ring Experiment." Periodica Polytechnica Mechanical Engineering 65, no. 3 (July 5, 2021): 280–85. http://dx.doi.org/10.3311/ppme.17598.
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The scarcity of oil and gas resources made High Pressure and High Temperature (HPHT) reservoir attractive to be developed. The sour service environment gives an additional factor in material selection for HPHT reservoir. Austenitic 28 Cr and super duplex stainless steel 2507 (SS 2507) are proposed to be a potential materials candidate for such conditions. C-ring tests were performed to investigate their corrosion behavior, specifically sulfide stress cracking (SSC) and sulfide stress cracking susceptibility. The C-ring tests were done under 2.55 % H2S (31.48 psia) and 50 % CO2 (617.25 psia). The testing was done in static environment conditions. Regardless of good SSC resistance for both materials, different pitting resistance is seen in both materials. The pitting resistance did not follow the general Pitting Resistance Equivalent Number (PREN), since SS 2507 super duplex (PREN > 40) has more pitting density than 28 Cr austenitic stainless steel (PREN < 40). SS 2507 super duplex pit shape tends to be larger but shallower than 28 Cr austenitic stainless steel. 28 Cr austenitic stainless steel has a smaller pit density, yet deeper and isolated.
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Han, Yan, Xue Hui Zhao, Juantao Zhang, Rui Cai, and Guan Fa Lin. "Failure Analysis on Fracture of a 3-1/2″ P110SS Tubing." Advanced Materials Research 524-527 (May 2012): 1412–17. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1412.
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The tubing, as a key ingredient in the well development, worked always under very complex stress and corrosion conditions, the failure of the tubing could cause huge losses. In this paper, a fractured 3-1/2″ P110SS tubing was analyzed through physical and chemical properties testing, SEM, EDS, and XRD method. The results showed that the failure of the tubing was belong to hydrogen sulfide stress corrosion cracking. The tubing material could not pass the SSC test, it was inappropriate to use in well contained high hydrogen sulfide.
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Kobayashi, Kenji, Tomohiko Omura, and Hisashi Amaya. "Effect of Buffer System on the Sulfide Stress Cracking Susceptibility of Low-Alloy Steel." Corrosion 74, no. 7 (February 19, 2018): 788–800. http://dx.doi.org/10.5006/2626.
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The effects of a buffer system in test solution and CO2 partial pressure on sulfide stress cracking (SSC) susceptibility of low-alloy steel were investigated under pH 4.0 at 0.03 MPa H2S partial pressure. A double cantilever beam test was used to quantitatively evaluate SSC susceptibility. The corrosion rates and absorbed diffusible hydrogen concentration were also evaluated. Acetic acid/sodium acetate (acetate buffered solution) and carbonic acid/bicarbonate (bicarbonate buffered solution) buffered solutions were used as buffer systems in this study. From the results, in atmospheric pressure tests, KISSC values in bicarbonate buffered solutions were equivalent to or lower than those in acetate buffered solutions. In high CO2 partial pressure conditions, KISSC values in bicarbonate buffered solutions were much higher than those in acetate buffered solutions. At a high CO2 partial pressure and H2S partial pressure (pCO2/pH2S) ratio condition, hydrogen entry is considered to be greatly prevented by corrosion products probably containing amorphous iron carbonate. Presence of the corrosion product with high protectiveness produced in the high pCO2/pH2S ratio condition suggests the possibility that conventional test conditions using acetate buffered solutions are conservative or are equivalent test conditions for actual field conditions.
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Park, Jin Sung, Jin Woo Lee, Joong Ki Hwang, and Sung Jin Kim. "Effects of Alloying Elements (C, Mo) on Hydrogen Assisted Cracking Behaviors of A516-65 Steels in Sour Environments." Materials 13, no. 18 (September 21, 2020): 4188. http://dx.doi.org/10.3390/ma13184188.
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This study examined the effects of alloying elements (C, Mo) on hydrogen-induced cracking (HIC) and sulfide stress cracking (SSC) behaviors of A516-65 grade pressure vessel steel in sour environments. A range of experimental and analytical methods of HIC, SSC, electrochemical permeation, and immersion experiments were used. The steel with a higher C content had a larger fraction of banded pearlite, which acted as a reversible trap for hydrogen, and slower diffusion kinetics of hydrogen was obtained. In addition, a higher hardness in the mid-thickness regions of the steel, due to center segregation, resulted in easier HIC propagation. On the other hand, the steel with a higher Mo content showed more dispersed banded pearlite and a larger amount of irreversibly trapped hydrogen. Nevertheless, the addition of Mo to the steel can deteriorate the surface properties through localized pitting and the local detachment of corrosion products with uneven interfaces, increasing the vulnerability to SSC. The mechanistic reasons for the results are discussed, and a desirable alloy design for ensuring an enhanced resistance to hydrogen assisted cracking (HAC) is proposed.
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Quej-Ake, Luis Manuel, Jesús Noé Rivera-Olvera, Yureel del Rosario Domínguez-Aguilar, Itzel Ariadna Avelino-Jiménez, Vicente Garibay-Febles, and Icoquih Zapata-Peñasco. "Analysis of the Physicochemical, Mechanical, and Electrochemical Parameters and Their Impact on the Internal and External SCC of Carbon Steel Pipelines." Materials 13, no. 24 (December 17, 2020): 5771. http://dx.doi.org/10.3390/ma13245771.
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The review presented herein is regarding the stress corrosion cracking (SCC) phenomena of carbon steel pipelines affected by the corrosive electrolytes that comes from external (E) and internal (I) environments, as well as the susceptibility and tensile stress on the SCC. Some useful tools are presented including essential aspects for determining and describing the E-SCC and I-SCC in oil and gas pipelines. Therefore, this study aims to present a comprehensive and critical review of a brief experimental summary, and a comparison of physicochemical, mechanical, and electrochemical data affecting external and internal SCC in carbon steel pipelines exposed to corrosive media have been conducted. The SCC, hydrogen-induced cracking (HIC), hydrogen embrittlement, and sulfide stress cracking (SSC) are attributed to the pH, and to hydrogen becoming more corrosive by combining external and internal sources promoting cracking, such as sulfide compounds, acidic soils, acidic atmospheric compounds, hydrochloric acid, sulfuric acid, sodium hydroxide, organic acids (acetic acid, mainly), bacteria induced corrosion, cathodic polarization, among others. SCC growth is a reaction between the microstructural, chemical, and mechanical effects and it depends on the external and internal environmental sources promoting unpredictable cracks and fractures. In some cases, E-SCC could be initiated by hydrogen that comes from the over-voltage during the cathodic protection processes. I-SCC could be activated by over-operating pressure and temperature at flowing media during the production, gathering, storage and transportation of wet hydrocarbons through pipelines. The mechanical properties related to I-SCC were higher in comparison with those reviewed by E-SCC, suggesting that pipelines suffer more susceptibility to I-SCC. When a pipeline is designed, the internal fluid being transported (changes of environments) and the external environment concerning SCC should be considered. This review offers a good starting point for newcomers into the field, it is written as a tutorial, and covers a large number of basic standards in the area.
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Cho, Dong Min, Jin-seong Park, Jin Woo Lee, and Sung Jin Kim. "Study on Hydrogen Diffusion and Sulfide Stress Cracking Behaviors of Simulated Heat-Affected Zone of A516-65 Grade Pressure Vessel Carbon Steel." Korean Journal of Metals and Materials 58, no. 9 (September 5, 2020): 599–609. http://dx.doi.org/10.3365/kjmm.2020.58.9.599.
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Hydrogen diffusion and sulfide stress cracking of simulated heat-affected zone (HAZ) of A516- 65 grade steel were examined using an electrochemical permeation technique, glycerin volumetric method, and constant loading method. HAZ samples were fabricated using a metal thermal cycle simulator with a welding heat input of 20, 35, and 50 kJ/cm. The fractions of bainite and martensite-austenite (M-A) constituent in coarse-grained HAZ (CGHAZ) and intercritical HAZ (ICHAZ) obtained by a simulated thermal cycle with a low heat input (20 kJ/cm) were higher than those with a higher heat input. These fractions contributed to the increase in the reversible hydrogen trap density (N<sub>[H]rev</sub>) and reversibly trapped hydrogen concentrations (C<sub>rev</sub>). Although CGHAZ had higher N<sub>[H]rev</sub> and C<sub>rev</sub> meaning that it is more likely to be vulnerable to brittle failure by hydrogen, actual fracture by sulfide stress cracking (SSC) occurred in ICHAZ composed of a mixture of soft ferrite/pearlite, and hard bainite and M-A. The hydrogen diffusion/trapping parameters, which were obtained from the electrochemical permeation or glycerin method, cannot be directly indicative of the resistance to SSC of the steel in a H<sub>2</sub>S environment. The susceptibility to SSC was more influenced by the level of M-A-localization and localized corrosion attack, acting as a stress intensifier under a tensile load.
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Luo, Ming, Zhong-Hua Zhang, Yao-Heng Liu, and Mou-Cheng Li. "Effect of Titanium and Boron Microalloying on Sulfide Stress Cracking in C110 Casing Steel." Materials 13, no. 24 (December 15, 2020): 5713. http://dx.doi.org/10.3390/ma13245713.
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The effect of Ti and B microalloying on the hardenability, prior austenite grain size (PAGS), mechanical properties, and sulfide stress cracking (SSC) of C110 grade steel was studied by Jominy testing, static tensile testing, an optical microscope (OM), scanning electron microscopy (SEM) and double cantilever beam (DCB) testing. The results show that the addition of 0.015% Ti and 0.002% B into a medium-carbon Fe-Cr-Mo-Nb-V steel increased the hardenability and refined the PAGS and quenched martensite packets, and the size of carbides was reduced. It is believed that these behaviors are responsible for the improvement in the threshold stress intensity factor KISSC.
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Wang, Yun, Jun Li, and Guang Qiang Cao. "Material Optimization of Injection and Production String in Su4 Underground Gas Storage." Advanced Materials Research 962-965 (June 2014): 448–52. http://dx.doi.org/10.4028/www.scientific.net/amr.962-965.448.
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There was carbon dioxide (CO2), hydrogen sulfide (H2S) and other corrosive media in underground gas storage. As injection-production running, the injection and production string suffered corrosion. The wall of string might be thinner and be perforated. The well safety was influenced, and even the gas storage. How to choose reasonable and efficient anti-corrosion material was an important problem. According to Su 4 underground gas storage actual injection-production condition and the corrosion environment, the software simulation and laboratory experiments have been done. The material of injection-production string optimization was optimized, based on the evaluation of corrosion rate and the two aspects of sulfide stress cracking resistance. The results showed that the imported super 13Cr (S13Cr) could meet demand. It could ensure that the string corrosion rate was smaller than 0.125 mm/a and there was no pitting corrosion. When the tpemerature was at 135℃, only the S13Cr corrosion passivation membrane was not been damaged. And the sulfide stress cracking (SSC) would not occur. The S13Cr is recoomneded Su 4 underground gas storage.
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Zhang, Xianguang, Wen Yang, Haikun Xu, and Lifeng Zhang. "Effect of Cooling Rate on the Formation of Nonmetallic Inclusions in X80 Pipeline Steel." Metals 9, no. 4 (March 29, 2019): 392. http://dx.doi.org/10.3390/met9040392.
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Nonmetallic inclusions have a strong influence on the hydrogen-induced cracking (HIC) and sulfide stress cracking (SSC) in pipeline steels, which should be well controlled to improve the steel resistance to HIC and SSC. The effects of cooling rate on the formation of nonmetallic inclusions have been studied both experimentally and thermodynamically. It was found that the increasing cooling rate increased the number density and decreased the size of the inclusions, while the inverse results were obtained by decreasing the cooling rate. Furthermore, as the cooling rate decreased from 10 to 0.035 K/s, the inclusions were changed from Al2O3-CaO to Al2O3-CaO-MgO-CaS. At a high cooling rate, the reaction time is short and the inclusions cannot be completely transformed which should be mainly formed at high temperatures. While, at low cooling rate, the inclusions can be gradually transformed and tend to follow the equilibrium compositions.
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Pei, Jun Feng, Gui Xin Zhang, Shun Shi Yin, and Xue Feng Deng. "Influencing Factors of 1Cr13 SSCC for Oil & Gas Wellhead." Advanced Materials Research 79-82 (August 2009): 1005–8. http://dx.doi.org/10.4028/www.scientific.net/amr.79-82.1005.
Full textAbstract:
With the exploration of oil-gas field developing, more and more oil-gas well contain H2S, hydrogen sulfide stress corrosion has serious effect on production and restrict oil field development. With the applications of 1Cr13 steel in oil & gas wellhead, it is urgent to research hydrogen sulfide stress corrosion cracking (SSCC) properties in high-strength under the simulation condition of production. The tensile test under constant load and slow strain rate test (SSRT) were adopted to analyze the behaviors of 1Cr13 steel with orthogonal test under saturated H2S solution which included carbon dioxide under a partial pressure and its sample fracture was observed with SEM (Scanning Electron Microscope). Constant load tensile test is one of the first recognized by NACE to assess the performance of metallic materials against SSC approach under tensile stress in the aqueous solution which was in low pH value and H2S was saturated. Through the research above the mechanism of stress corrosion and the environmental factors that influence stress corrosion were investigated. The experimental results shown that the effects of environmental factors on SCC (Stress Corrosion Cracking) sensitivity of materials are in the following order: temperature effect > solution pH effect > chloride ion concentration effect, and 1Cr13 material has a better corrosion resistance for H2S and CO2 conditions under a certain stress so it can be proposed as the material of value for oil & gas wellhead. Through SEM it can be seen that the fracture is belonged to brittle fracture. The lattice bonding force is destroyed by hydrogen into the material that gathered in the certain crystal face and the material transform from plastic to brittleness, the material is failed, and SCC occurred.
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Zhang, Ye Qin, Li Chun Qi, and Yi Sheng Huang. "Anticorrosion Property of TC27 Titanium Alloys and Application Evaluation in Tubing." Materials Science Forum 1035 (June 22, 2021): 615–23. http://dx.doi.org/10.4028/www.scientific.net/msf.1035.615.
Full textAbstract:
In view of the combined effect of the load and the corrosive environment on the downhole tubing and the need for the selection of downhole tubing materials, the study on the pitting corrosion, crevice corrosion, erosion corrosion, high temperature and high pressure simulation of corrosion, galvanic corrosion, resistance to sulfide stress corrosion cracking SSC, resistance to hydrogen induced cracking, stress corrosion cracking test under simulated working conditions for TC27 titanium alloy was carried out. Furthermore, the corrosion performance was evaluated by the test results and evaluation standards such as GB/T 18590-2001, SY/T 7394-2017, GB/T 15748-2013. The results show that TC27 have excellent resistance to pitting corrosion, crevice corrosion and erosion corrosion under the corrosive environment of NaCl and H2S. The alloy also has excellent corrosion resistance and crack resistance under high-intensity environments such as high temperature and high pressure, and has good overall performance, which can effectively meet the needs of anti-corrosion performance of downhole tubing materials in different corrosive environments.
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Zhang, Fang Fang, Chun Feng, Li Juan Zhu, and Wen Wen Song. "Research Progress on Corrosion Resistance of Titanium Alloy Oil Well Tubing." Materials Science Forum 1035 (June 22, 2021): 528–33. http://dx.doi.org/10.4028/www.scientific.net/msf.1035.528.
Full textAbstract:
Compared with aluminum alloy and alloy steel, titanium alloy has higher specific strength, lower modulus of elasticity, and better toughness, fatigue performance and corrosion resistance. In terms of oil well tubing, the development of titanium alloy lags behind that of aluminum alloy and alloy steel. Aluminum alloy tubing is sensitive to pitting, fatigue corrosion and stress corrosion cracking. At the same time, it is not suitable for ultra-deep wells due to temperature limitations. Easily interact with corrosive media to cause corrosion and cracking. Titanium alloy oil well tubing is expected to solve this corrosion problem, but its corrosion resistance research is still incomplete. Therefore, it is necessary to develop titanium alloy oil well tubing with good corrosion resistance to improve corrosion fatigue (CF), fatigue during deep oil well and natural gas drilling operations. Catastrophic brittle fracture caused by hydrogen induced cracking (HIC), pitting corrosion and sulfide stress cracking (SSC). In this paper, by investigating a large number of domestic and foreign documents, the corrosion types of titanium alloy oil well pipes are analyzed, and the research status of corrosion resistance of titanium alloy oil well pipes is reviewed from three aspects: oil pipes, casings and drill pipes.
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Islam, M., W. T. Riad, S. Al-Kharraz, and S. Abo-Namous. "Stress Corrosion Cracking Behavior of 90/10 Cu-Ni Alloy in Sodium Sulfide Solutions." Corrosion 47, no. 4 (April 1, 1991): 260–68. http://dx.doi.org/10.5006/1.3585253.
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Abstract The stress corrosion cracking (SCC) of 90/10 Cu-Ni alloy in sulfide solutions is not reported in the literature. The SCC behavior of the alloy was studied in dilute and concentrated Na2S solutions at room temperature. The alloy was found to be susceptible to SCC under slow strain rate conditions in the concentrated (0.1 to 1 M) sulfide solutions, but not in the dilute (0.002 to 0.03 M) solutions. On the basis of electrochemical data and EPMA analysis of the metal/film interface of the cracked samples, the mechanism of cracking can possibly be attributed to a dealloying (selective dissolution) phenomenon where the copper matrix but not the solute Ni is selectively removed.
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Matrosov, Yury, Ivan Shabalov, Alexey Kholodnyi, and Valery Velikodnev. "Steel for gas and oil pipelines resistant to destruction in hydrogen sulphide-containing media." E3S Web of Conferences 121 (2019): 04008. http://dx.doi.org/10.1051/e3sconf/201912104008.
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About a third reserves of the natural gas and oil contain H2S impurities, which, in the presence of moisture, form an acidic medium and can lead to pipeline destruction by the mechanisms of hydrogen-induced cracking (HIC) and sulfide stress cracking (SSC). With the growing number of hydrocarbon fields being developed with a high content of H2S, the demand for gas and oil large diameter pipes grade from ВМS to Х70MS with high resistance to HIC and SSC increases. Comprehensive studies have been carried out in laboratory and industrial conditions to determine the effect of the chemical composition and thermomechanical processing on the microstructure, mechanical properties and resistance to HIC of rolled plates from low-alloy pipe steels. Optimal concentration of segregating elements (С ≤ 0.06%, Mn ≤ 1.00%), and schedules of accelerated cooling after controlled rolling (Тsc ≥ Ar3; Тfc = 520±30°C; Vc ≥ 20°C/с) provide the high resistance to destruction in H2S-containing media due the formation of a homogeneous microstructure without developed central segregation heterogeneity was determined. According to the research results, the technology for manufacturing of plates for large-diameter pipes grade X52MS, X56MS, X60MS, and X65MS ordered for sour service was developed.
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Li, Wen Fei, and Xuan Ye Li. "The Experiment Research of Corrosion Behavior about Tubing Steel in Environment with High H2S and CO2 Content." Applied Mechanics and Materials 318 (May 2013): 284–92. http://dx.doi.org/10.4028/www.scientific.net/amm.318.284.
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The corrosion behavior of C100 steel in simulated environments with high H2S and CO2 content was studied through high-temperature and high-pressure autoclave, and the H2S stress corrosion cracking (SSC) resistance of C100 steel was evaluated by SSC tests. Scanning electron microscopy (SEM), transmission electron microscope (TEM) and X-ray diffraction (XRD) technique were employed to characterize the corrosion products and the metal matrix. The results indicate that all of the corrosion products in this investigation are mainly composed of different types of iron sulfide such as Fe0.95S, FeS0.9, Fe0.985S, Fe7S8 and FeS, and the absence of iron carbonate in the corrosion scales suggests that the corrosion process is governed by H2S corrosion. The corrosion rate decreases in the initial stage and then increases with the enhance of the temperature. There exists a minimum corrosion rate at about 110°C. Under the partial pressure of H2S lower than 9MPa, the corrosion rate decreases with the increase of P . While over 9MPa, a higher P will result in a faster corrosion process. When the applied stress is 72 %, 80 % and 85 % of actual yield strength (AYS), all tested specimens show no crack, which reveals a superior SSC resistance. The precipitation of the second phase particles at the grain boundary or in crystal grain, the dislocation tangle and the dislocation pinning of the dispersion carbonide hinder the SSC cracks to propagate.
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Song, Guang San, Ke Tong, and Xiao Dong He. "Mechanical Property, HIC and SSCC Test Analysis of L245NS Anti-Sulfur Bending Pipe." Applied Mechanics and Materials 319 (May 2013): 456–61. http://dx.doi.org/10.4028/www.scientific.net/amm.319.456.
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Rational utilization of the anti-sulfur tubes is considerable significance to the reliability and service life of oil-gas pipeline system. Unfortunately, there have been no such researches in the field of anti-sulfur bending pipe. In this paper, the mechanical property test, hydrogen induced cracking(HIC) test and sulfide stress-corrosion cracking(SSC) test were conducted to investigate the Φ406.4×10.31mm L245NS anti-sulfur bending pipe with the technique of induction heating bending. And the test result was analyzed combining with microstructure of pipe. The results show that mechanical properties and HIC behavior of L245NS bending pipe reach the standard with the 890~930°C induction quenching and 580-630°C temper process. The strength and Charpy toughness of inner arc and outer arc are higher than base metal. Most HIC crack initiated at the bainite structure and banded structure. The L245NS anti-sulfur bending pipe exhibits good resistance to SSCC under the NACE TM0177-2005 experiment environment.
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Della Roverys Coseglio, Mario Sergio, Xiaoying Li, Hanshan Dong, Brian J. Connolly, Phil Dent, and Chris Fowler. "Corrosion Behavior of Active-Screen Plasma Nitrided 17-4 PH (H1150D) Steel in H2S/CO2-Containing Environments." CORROSION 75, no. 10 (August 5, 2019): 1237–45. http://dx.doi.org/10.5006/3273.
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The presence of hydrogen sulfide (H2S) in typical oilfield environments promotes hydrogen absorption and subsequent failure of high-strength steels by sulfide stress cracking (SSC). Plasma nitriding is as a potential method to increase the resistance of the 17-4 PH to SSC, although further investigation is required to evaluate the corrosion resistance of the modified layer when it is exposed to H2S-containing environments. The aim of this study was therefore to evaluate the corrosion resistance of the 17-4 PH in typical oilfield environment. Samples were plasma nitrided at low (420°C) and high (500°C) temperatures and immersed in produced water with mixed H2S and CO2. The electrochemical data and scanning electron microscopy (SEM) micrographs showed that there were no detrimental effects on the corrosion resistance when plasma nitriding was performed at low temperature (420°C), whereas the integrity of the modified layer was compromised when an elevated temperature (500°C) was applied. The enhanced resistance to localized corrosion of the nitride case obtained after the low-temperature surface modification was attributed to the formation of a compound layer of mixed M4N/M2-3N, the inner section being more corrosion resistant than the outer part, as revealed by SEM micrographs.
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Kong, Fan Yu. "Research on Test about Stress Corrosion Cracking of SPV50Q Spherical Tank." Advanced Materials Research 284-286 (July 2011): 2437–41. http://dx.doi.org/10.4028/www.scientific.net/amr.284-286.2437.
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SPV50Q steel belongs to high-alloyed steel that is widely used to fabricate storage tank for liquefied petroleum gas. However, it has a great tendency to the problem of environmental cracking under the service condition of LPG containing wet sulfide hydrogen surpassing the lowest allowance for steels. In order to quantitatively evaluate the cracking susceptibility on this steel in the wet H2S environment, the pre-fatigue crack M-WOL specimen stress corrosion cracking tests in three H2S concentrations were performed under the different welding conditions, and in safety performance analysis of equipment, and preventing countermeasure had been proposed. The method could be extended forecasting accident in LPG SCC.
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Kurahashi, H., T. Kurisu, Y. Sone, K. Wada, and Y. Nakai. "Stress Corrosion Cracking of 13Cr Steels in CO2-H2S-Cl− Environments." Corrosion 41, no. 4 (April 1, 1985): 211–19. http://dx.doi.org/10.5006/1.3581993.
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Abstract Stress corrosion cracking (SCC) behavior of two 13Cr steels was investigated in aqueous CO2-H2S environments. U-bend tests, constant load tensile tests, and corrosion tests were performed in CO2 environments containing different amounts of H2S. In addition, the slow strain rate tensile (SSRT) tests and hydrogen absorption measurements were done under cathodic hydrogen charging conditions to determine why 13Cr steels are more susceptible to SCC in H2S environments than low alloy steels are. The 13Cr steels were less resistant to SCC in the CO2-H2S environments than low alloy steels were, but some 13Cr steels were not subject to SCC even at a hydrogen sulfide partial pressure of 0.3 atm. Furthermore, it was found that SCC in a CO2-H2S environment was caused by hydrogen embrittlement and that the SCC susceptibility of 13Cr steels was affected by their intergranular cracking behavior. Thus, their microstructures and carbide dispersions are important factors in defining SCC susceptibility of 13Cr steels.
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Pei, Jun Feng, Jun Ning Liu, and Wei Ying He. "Effect of Laser Shock Processing on Sulfide Stress Corrosion Cracking of X70 Pipeline Steel Welded Joint." Applied Mechanics and Materials 44-47 (December 2010): 451–55. http://dx.doi.org/10.4028/www.scientific.net/amm.44-47.451.
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Laser shock processing (LSP) is a new technique for metal surface strengthening by which residual compressive stress in the superficial layer can be induced to greatly improve the stress corrosion resistance property. The effect of LSP on sulfide stress corrosion cracking (SSCC) of X70 pipeline steel welded joint has been studied in this paper. A convergent lens is used to deliver 20 J, 20 ns laser pulses by a Q switch Nd:YAG laser, operating at 10 Hz. The pulses are focused to a diameter of 3 mm onto samples. The power density of laser at the surface of the sample was about 5 GW/cm2. The surface residual stress level after LSP is much higher than before. SSCC behavior of X70 pipeline steel welded joint was investigated using slow strain rate testing (SSRT) in H2S solution. Morphology of X70 pipeline steel fracture surface was observed by scanning electron microscope (SEM). It has been demonstrated that LSP is an effective surface treatment technique to improve the stress corrosion cracking (SCC) resistance properties of X70 pipeline steel welded joints.
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Tromans, D., S. Ramakrishna, and E. B. Hawbolt. "Stress Corrosion Cracking of ASTM A516 Steel in Hot Caustic Sulfide Solutions—Potential and Weld Effects." Corrosion 42, no. 2 (February 1, 1986): 63–70. http://dx.doi.org/10.5006/1.3584887.
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Abstract A combination of slow strain rate (tensile) testing (SSRT) and double cantilever beam (DCB) fracture mechanics testing techniques have been used to study the stress corrosion cracking (SCC) behavior of welded and unwelded pressure vessel quality steel plate (ASTM A516 Grade 70) in hot (92 C) caustic sulfide solutions (3.35 m NaOH + 0.42 m Na2S) of general relevance to the pulp and paper industry. Tests were conducted over a range of potentials (E) and stress intensities (KI). The most susceptible SCC situation occurred at potentials near the activepassive transition, where crack propagation rates were slightly lower in the fusion zone (FZ) of the weld than in the base material (BM). However, crack initiation on smooth specimens was far more frequent in the FZ. More noble potentials did not prevent SCC, but decreased the crack propagation rate and decreased crack initiation (i.e., crack density), particularly in the FZ. A fracture mechanics analysis of partial surface cracks and through thickness cracks was used to assess the cracking of kraft digesters in light of the results. It was concluded that anodic protection could play a beneficial role by decreasing the probability of crack coalescence and the resulting formation of a long critical (catastrophic) crack in the weld region. Instead, only small isolated cracks should form, which penetrate the vessel wall more slowly and lead to leakage before catastrophic failure.
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Li, Bo, Ming Luo, Zhanbing Yang, Feifei Yang, Huasong Liu, Haiyan Tang, Zhonghua Zhang, and Jiaquan Zhang. "Microstructure Evolution of the Semi-Macro Segregation Induced Banded Structure in High Strength Oil Tubes During Quenching and Tempering Treatments." Materials 12, no. 20 (October 11, 2019): 3310. http://dx.doi.org/10.3390/ma12203310.
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C110 oil well casing tubes should have high strength and corrosion resistance which is commonly used for deep wells operation containing corrosive media. In this paper, the microstructure evolution of a kind of semi-macro segregation originated banded structure in casing tubes is studied under different heat treatments. It is shown that the characteristics of the banded structure will change significantly in subsequent hot working and heat treatment processes. For the hot-rolled ones, the banded structure is composed of pearlite plus bainite. After quenching, it evolves into martensite band with high concentration solute elements. Finally, the banded structure will change into a carbide banding under the following tempering process. The temperature and cooling rate of the tempering practice show an obvious effect on the final band structure. To improve anti-SSC (sulfide stress corrosion cracking) performance, the favorable QT (quenching and tempering) practice for C110 steel should be a higher tempering temperature and a quicker cooling rate, from which the banded structure defects can be decreased together with an obvious improvement of the tube wall hardness uniformity.
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Cao, Huai Xiang, Chun Mao Wang, and Xing Qi Qiu. "Analysis on Backside Cracks in 316LMod Inner Linings of Urea Reactors." Applied Mechanics and Materials 184-185 (June 2012): 858–63. http://dx.doi.org/10.4028/www.scientific.net/amm.184-185.858.
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Backside cracks were found universally in the ultra-low carbon austenitic stainless steel (316LMod) inner linings of urea reactors in recent years, and led to urea reactors leakage. Analyses on the sample revealed that, the backside cracks were caused by the interaction of wet hydrogen sulfide (H2S) and chloride ions (Cl-) stress corrosion cracking (SCC), and H2S played a dominant role. The source of H2S and chloride ions was the leak detection steam. Furthermore, measures to avoid backside cracks in 316LMod inner linings of urea reactors were put forward and verified.
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Gabetta, G., S. Correra, S. Sgorlon, and M. Bestetti. "Test Conditions for Pipeline Materials Selection with High Pressure Sour Gas." International Journal of Corrosion 2018 (May 29, 2018): 1–9. http://dx.doi.org/10.1155/2018/3402692.
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Acid gases, such as CO2, H2S, and/or sulfur in oil industry’s production fluids, can be responsible for both general and localized corrosion, acting with different mechanisms, which depend on chemical and physical properties of the produced fluids. Materials selection for handling such fluids is performed by combining experience with suggestions from standards and regulations. A good deal of knowledge is available to predict corrosion rates for CO2-containing hydrocarbons, but the effect of high H2S pressure is less understood, mainly due to the difficulty of performing laboratory tests in such challenging conditions. For instance, the so-called NACE solution to assess SSC (Sulfide Stress Cracking) susceptibility of steels is a water-based solution simulating production fluids in equilibrium with one bar bubbling H2S gas. This solution does not represent environments where high gas pressure is present. Moreover, it does not take into account the corrosive properties of sulfur and its compounds that may deposit in such conditions. Besides, properties of high pressure gases are intermediate between those of a gas and those of a liquid: high pressure gases have superior wetting properties and better penetration in small pores, with respect to liquids. These features could enhance and accelerate damage, and nowadays such conditions are likely to be present in many production fields. This paper is aimed to point out a few challenges in dealing with high pressure gases and to suggest that, for materials selection in sour service, a better correspondence of test conditions with the actual field conditions shall be pursued.
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Lee, Eun Hee, Kyung Mo Kim, and Uh Chul Kim. "Stress Corrosion Cracking of Alloy 600 in a High-Temperature Water Containing Sulfate and Thiosulfate." Key Engineering Materials 277-279 (January 2005): 644–48. http://dx.doi.org/10.4028/www.scientific.net/kem.277-279.644.
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The stress corrosion cracking (SCC) susceptibility of Alloy 600 MA has been studied in deaerated 0.01 M sodium sulfate (Na2SO4) and sodium thiosulfate (Na2S2O3) solutions at 340°C. Pre-strained reverse U-bend (RUB) specimens are tested using a static-autoclave system. The specimens show an intergranular SCC and a higher resistance to SCC in a Na2S2O3 solution than in a Na2SO4 solution. The results of the deposits and surface analyses by using XRD and SEM/EDS confirm the existence of the sulfides. The SCC of Alloy 600 MA is associated with the reduced sulfur species and protective oxide film properties formed on the alloy surface in the Na2SO4 and Na2S2O3 solutions.
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Craig, B. D., J. K. Brownlee, and T. V. Bruno. "Sulfide Stress Cracking of Nickel Steels." CORROSION 48, no. 2 (February 1992): 90–97. http://dx.doi.org/10.5006/1.3299824.
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Qiu, Zhi Chao, Na Zhang, and Xiang Liu. "Slow Strain Rate Tension Stress Corrosion Cracking Test for L80 and C90 Steel." Advanced Materials Research 763 (September 2013): 165–69. http://dx.doi.org/10.4028/www.scientific.net/amr.763.165.
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Slow strain rate tension stress corrosion cracking test was applied to test the SSC-resistant ability of L80 and C90 steel. The experimental result showed that: L80 steel occurred plastic fracture and had good resistance to SSC; C90 steel occurred plastic-brittle fracture and the ability of SSC-resistance was worse than that of L80.
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Maiya, P. S., and B. K. Pai. "Modeling of Notch Effects on Stress Corrosion Cracking." Journal of Pressure Vessel Technology 114, no. 2 (May 1, 1992): 171–77. http://dx.doi.org/10.1115/1.2929025.
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The intergranular stress corrosion cracking (IGSCC) of sensitized Type 304 stainless steel (SS) has been investigated by slow strain rate tests (SSRTs) in 289°C water containing sulfate impurity. Both smooth and circumferentially notched specimens were used to assess the effects of strain concentrations on stress corrosion cracking (SCC). Experiments were conducted over a range of nominal strain rates of 10−5 to 10−7 s−1. A comparison of the results observed for the smooth and notched specimens suggests that the estimated growth rates of small cracks in SSRT specimen geometry is influenced by the presence of strain concentrations. In particular, the average crack growth rates estimated from tests performed at the same nominal strain rate are observed to increase with the notch depth, and power-law relationships exist between strain rate and SCC parameters such as failure time and crack growth rate. The strain concentration factors at the notch roots of Type 304 specimens subjected to axial load have been estimated by finite-element elastic-plastic stress analyses, as well as by Neuber’s rule. The nominal and crack-tip strain rate effects on SCC in both smooth and notched specimens are interpreted in terms of a model based on elastic-plastic fracture mechanics and film-rupture mechanisms that invoke diffusion-controlled SCC growth kinetics.
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Kimura, M., N. Totsuka, T. Kurisu, K. Amano, J. Matsuyama, and Y. Nakai. "Sulfide Stress Corrosion Cracking of Line Pipe." CORROSION 45, no. 4 (April 1989): 340–46. http://dx.doi.org/10.5006/1.3577866.
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Zhang, Peng, Li Qiong Chen, and Yang Biao. "Experiment Study on Safety Evaluation of L245A-Pipe Steel in Wet H2S Environment." Advanced Materials Research 156-157 (October 2010): 1603–8. http://dx.doi.org/10.4028/www.scientific.net/amr.156-157.1603.
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As Pipeline in Wet H2S environment must consider its anti-hydrogen-induced cracking (HIC) and sulfide stress corrosion cracking (SSCC) performance, in this paper, to ensure L245A-pipe mechanical properties qualified under the premise, according to NACE TM 0284-2003 and NACE TM 0177-2005 standard conducted a test evaluation in Wet H2S in the context of anti-hydrogen-induced cracking performance (HIC) and sulfide stress corrosion cracking resistance (SSCC) and came L245A-pipe in standard Wet H2S environment didn’t produce hydrogen-induced cracking, occurred sulfide stress corrosion cracking, the design conditions and working conditions are no stress corrosion cracking conclusions. And make recommendations on the safe operation in Wet H2S.
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Abdulle, Amaal, Harry van Goor, and Douwe Mulder. "Hydrogen Sulfide: A Therapeutic Option in Systemic Sclerosis." International Journal of Molecular Sciences 19, no. 12 (December 19, 2018): 4121. http://dx.doi.org/10.3390/ijms19124121.
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Systemic sclerosis (SSc) is a lethal disease that is characterized by auto-immunity, vascular injury, and progressive fibrosis of multiple organ systems. Despite the fact that the exact etiology of SSc remains unknown, oxidative stress has been associated with a large range of SSc-related complications. In addition to the well-known detrimental properties of reactive oxygen species (ROS), gasotransmitters (e.g., nitric oxide (NO), carbon monoxide (CO), and hydrogen sulfide (H2S)) are also thought to play an important role in SSc. Accordingly, the diverse physiologic actions of NO and CO and their role in SSc have been previously studied. Recently, multiple studies have also shown the importance of the third gasotransmitter H2S in both vascular physiology and pathophysiology. Interestingly, homocysteine (which is converted into H2S through the transsulfuration pathway) is often found to be elevated in SSc patients; suggesting defects in the transsulfuration pathway. Hydrogen sulfide, which is known to have several effects, including a strong antioxidant and vasodilator effect, could potentially play a prominent role in the initiation and progression of vasculopathy. A better understanding of the actions of gasotransmitters, like H2S, in the development of SSc-related vasculopathy, could help to create early interventions to attenuate the disease course. This paper will review the role of H2S in vascular (patho-)physiology and potential disturbances in SSc. Moreover, current data from experimental animal studies will be reviewed. Lastly, we will evaluate potential interventional strategies.
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Payer, J. H., S. P. Pednekar, and W. K. Boyd. "Sulfide stress cracking susceptibility of nickel containing steels." Metallurgical Transactions A 17, no. 9 (September 1986): 1601–10. http://dx.doi.org/10.1007/bf02650097.
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Scenini, F., and A. Sherry. "Stress Corrosion Cracking of Sensitized Type 304 Stainless Steel in High-Temperature Water with Anionic Impurities Contamination." Corrosion 68, no. 12 (July 11, 2012): 1094–107. http://dx.doi.org/10.5006/0690.
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This paper describes some results selected from a larger program that was aimed at understanding the stress corrosion cracking (SCC) initiation of Type 304 stainless steel (UNS S30400) in high-temperature deaerated water. Out of a large number of statically loaded samples, only a small minority of the tested samples underwent SCC. The occurrence of SCC indicates a synergism between sensitization, ionic impurities (mainly chloride and sulfate), and/or superficial defects and cold work. In fact, none of the nonsensitized materials initiated cracking (within the time scale of the tests), while only three sensitized samples underwent extensive SCC. The crack morphology of the fractured sample was predominantly inter-granular with some transgranular regions. Transmission electron microscopic samples containing crack tips were, in most respect, in line with the literature: a magnetite/spinel duplex layer on the crack surfaces, a Cr-rich oxide at the crack tip, and Ni enrichment at the metal/oxide interface and oxidized deformation bands intercepting the crack flanks. Also, finger-like features protruding several hundreds of nanometers along the slip planes intersecting the intergranular crack were found on grain boundaries with a high degree of localized deformation. These results support the theory that cracking initiation and propagation might be associated with the formation of oxide on crystallographic planes inside the material.
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Chavane, A., M. Habashi, G. M. Pressouyre, and J. Galland. "High-Strength Steels with Improved Sulfide Stress Cracking Resistance." CORROSION 42, no. 1 (January 1986): 54–61. http://dx.doi.org/10.5006/1.3584880.
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Yoshino, Y., and Y. Minozaki. "Sulfide Stress Cracking Resistance of Low-Alloy Nickel Steels." CORROSION 42, no. 4 (April 1986): 222–33. http://dx.doi.org/10.5006/1.3586000.
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