TY - JOUR A1 - Ruhl, Aki Sebastian A1 - Kranzmann, Axel T1 - Corrosion in supercritical CO2 by diffusion of flue gas acids and water N2 - Carbon capture and storage (CCS) includes processing of supercritical carbon dioxide (scCO2). The carbon dioxide (CO2) stemming from flue gases contains acid forming impurities, especially in the case of coal fired power plants. In the present work, the mobility and reactivity of acids in supercritical scCO2 was investigated. The corrosive attack of low alloyed carbon steel (material 1.0484) by water (H2O) alone in scCO2 was negligible. Nitric acid (HNO3) was very mobile and corrosive towards the carbon steel while sulfuric acid did not migrate through the scCO2 to react with the steel surface. Hydrochloric acid in scCO2 was very mobile and reactive towards both carbon steel and high alloyed test equipment. Gravimetric analyses revealed a severe material loss after corrosion in the presence of HNO3. Thickness measurements showed localized material losses. KW - Supercritical CO2 KW - Corrosion KW - Carbon steel KW - Carbon capture and storage KW - CCS KW - Flue gas acids PY - 2012 U6 - https://doi.org/10.1016/j.supflu.2012.04.015 SN - 0896-8446 VL - 68 SP - 81 EP - 86 PB - Elsevier CY - New York, NY [u.a.] AN - OPUS4-28054 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER - TY - JOUR A1 - Ruhl, Aki Sebastian A1 - Göbel, Artur A1 - Kranzmann, Axel T1 - Corrosion behavior of various steels for compression, transport and injection for carbon capture and storage N2 - Steels used within the process chain of carbon capture and storage (CCS) are exposed to conditions that are currently not fully tested. In the present work a number of steels were selected as possible construction materials: Alloyed steels for application in the compression and injection sections and low alloyed carbon steels for use as pipelines. Exposure tests were conducted over 600 hours at ambient pressure in a continuous flow of a simulated gas stream consisting of carbon dioxide with low contents of the relevant flue gas components nitrogen dioxide, sulfur dioxide, carbon monoxide, oxygen and water. Temperatures were adjusted to 5, 60 and 170 centigrade. KW - CCS KW - Material selection KW - Gas corrosion KW - Dew point corrosion KW - Compression KW - Pipeline KW - Injection PY - 2012 U6 - https://doi.org/10.1016/j.egypro.2012.06.074 SN - 1876-6102 VL - 23 SP - 216 EP - 225 PB - Elsevier CY - Amsterdam AN - OPUS4-27913 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER - TY - CONF A1 - Pfennig, Anja A1 - Schulz, S. A1 - Werlitz, T. A1 - Bülow, E. A1 - Wetzlich, S. A1 - Tietböhl, J. A1 - Frieslich, C. A1 - Kranzmann, Axel T1 - Influence of heat treatment on the corrosion of steels in CCS environment T2 - TMS 2012 - 141st Annual Meeting & Exhibition CY - Orlando, FL, USA DA - 2012-03-11 KW - CCS KW - Carbon capture and storage KW - Corrosion KW - Steel KW - Pipeline KW - Carbon KW - Heat treatment KW - CO2-storage PY - 2012 SN - 978-1-11829-607-3 VL - 1 IS - Supplemental Proceedings SP - 103 EP - 110 PB - John Wiley & Sons CY - Hoboken, NJ, USA AN - OPUS4-28007 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER - TY - CONF A1 - Pfennig, Anja A1 - Linke, B. A1 - Schulze, S. A1 - Kranzmann, Axel T1 - Corrosion in pipe steels exposed to supercritical CO2 during carbon capture and storage CCS N2 - The CCS technique involves the compression of emission gasses in deep geological layers. To guarantee the safety of the site, CO2-corrosion of the injection pipe steels has to be given special attention when engineering CCS-sites. To get to know the corrosion behaviour samples of the heat treated steel 1.72252CrMo4, used for casing, and the stainless injection-pipe steel 1.4034 X46Cr13 were kept at T=60 °C and ambient pressure as well as p=100 bar for 700 h - 8000 h in a CC 2-saturated synthetic aquifer environment similar to possible geological on-shore CCS-sites in the northern German Basin. The isothermal corrosion behaviour obtained by mass gain of the steels in the gas phase, the liquid phase and the intermediate phase gives surface corrosion rates around 0.1 to 0.8 mm/year at ambient pressure and much lower about 0.02 to 0.2 mm/year at 100 bar where the CO 2 is in its supercritical state. Severe pit corrosion with pit heights around 4.5 mm are only located on the 42CrMo4 steel. Main phase of the continuous complicated multi-layered carbonate/oxide structure is siderite FeCO 3 in both types of steel. T2 - EUROCORR 2011 - Developing solutions for the global challenge CY - Stockholm, Sweden DA - 04.09.2011 KW - Steel KW - Pipeline KW - Corrosion KW - Carbonate layer KW - CCS KW - CO2-storage PY - 2011 SP - Paper 1044-1 EP - Paper 1044-8 AN - OPUS4-28008 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER - TY - CONF A1 - Pfennig, Anja A1 - Linke, B. A1 - Schulze, S. A1 - Kranzmann, Axel T1 - Static and dynamic long term corrosion experiments in CCS-conditions N2 - Dealing with first corrosion screening experiments to predict the reliability and safety of Germanys first Carbon Capture and Storage site in the northern Bassin of Germany, northwest of the Capital Berlin, laboratory experiments have been established to simulate the particular conditions at T=60 °C, highly saline aquifer water similar to 'Stuttgart Aquifer', but only at ambient pressure. With mounting 2 independent full 2-grade titanium autoclave systems (running up to 250 bar and 300 °C) pressures up to p=100 bar are possible. In 2010 a specific corrosion chamber of 2-grade titanium working up to 100 °C, flowing aqui fer water with different gas mixtures was designed to fit to a high cycle fatigue testing machine. Long term fatigue experiments simulating fatigue crack growth under corrosive environments will soon start. These experiments may not only help engineering a CCS site, but results can be used to improve the maintenance of geothermal energy production sites, especially moved parts such as pumps and shafts. T2 - EUROCORR 2011 - Developing solutions for the global challenge CY - Stockholm, Sweden DA - 04.09.2011 KW - CO2 KW - Static corrosion KW - High cycle fatigue KW - Steel KW - CCS KW - CO2-storage KW - Corrosion PY - 2011 SP - 1 EP - 7 (Paper 1087) AN - OPUS4-28009 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER - TY - CONF A1 - Pfennig, Anja A1 - Schulz, Sabrina A1 - Linke, Barbara A1 - Kranzmann, Axel T1 - Supercritical CO2-corrosion in pipe steels during carbon capture and storage CCS N2 - The CCS technique involves the compression of emission gasses in deep geological layers. To guarantee the safety of the site, C02-corrosion of the injection pipe steels has to be given special attention when engineering CCSsites. To get to know the corrosion behaviour samples of the heat treated Steel 1.72252CrMo4, used for casing, and the stainless injection-pipe Steel 1.4034 X46Cr 13 were kept at T=60 °C and ambient pressure as well as p=100 bar for 700 h - 8000 h in a C02-saturated synthetic aquifer environment similar to possible geological on-shore CCS-sites in the northern German Basin. The isothermal corrosion behaviour obtained by mass gain of the steels in the gas phase, the liquid phase and the intermediate phase gives surface corrosion rates around 0.1 to 0.8 mm/year at ambient pressure and much lower about 0.02 to 0.2 mm/year at 100 bar where the C02 is in its supercritical state. Severe pit corrosion with pit heights around 4.5 mm are only located on the 42CrMo4 Steel. Main phase of the continuous complicated multi-layered carbonate/oxide structure is siderite FeCO} in both types of Steel. T2 - 4th International conference on sustainable energy and environment (SEE 2011) - A paradigm shift to low carbon society CY - Bangkok, Thailand DA - 23.11.2011 KW - Steel KW - Pipeline KW - Corrosion KW - Carbonate layer KW - CCS KW - Supercritical CO2- KW - CO2-storage PY - 2011 SP - 1 EP - 6 AN - OPUS4-25534 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER - TY - CONF A1 - Pfennig, Anja A1 - Linke, Barbara A1 - Schulz, Sabrina A1 - Kranzmann, Axel T1 - Supercritical CO2-corrosion in pipe steels during carbon capture and storage CCS N2 - The CCS technique involves the compression of emission gasses in deep geological layers. To guarantee the safety of the site, CC>2-corrosion of the injection pipe steels has to be given special attention when engineering CCS-sites. To get to know the corrosion behaviour samples of the heat treated Steel 1.72252CrMo4, used for casing, and the stainless injection-pipe Steel 1.4034 X46Crl3 were kept at T=60 °C and ambient pressure as well as p=100 bar for 700 h - 8000 h in a CC>2-saturated synthetic aquifer environment similar to possible geological onshore CCS-sites in the northern German Basin. The isothermal corrosion behaviour obtained by mass gain of the steels in the gas phase, the liquid phase and the intermediate phase gives surface corrosion rates around 0.1 to 0.8 mm/year at ambient pressure and much lower about 0.02 to 0.2 mm/year at 100 bar where the CO2 is in its supercritical state. Severe pit corrosion with pit heights around 4.5 mm are only located on the 42CrMo4 Steel. Main phase of the continuous complicated multi-layered carbonate/oxide structure is siderite FeCCh in both types of Steel. T2 - 3rd International congress on green process engineering (GPE 2011) CY - Kuala-Lumpur, Malaysia DA - 06.12.2011 KW - Steel KW - Pipeline KW - Corrosion KW - Carbonate layer KW - CCS KW - Supercritical CO2- KW - CO2-storage PY - 2011 SP - 1 EP - 6 AN - OPUS4-25535 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER - TY - CONF A1 - Pfennig, Anja A1 - Wojtas, P. A1 - Spengler, I. A1 - Kranzmann, Axel T1 - Effect of heat treatment of injection pipe steels on the formation of local corrosion in CCS-environment N2 - When engineering a Carbon Capture and Storage site (CCS) local corrosion (pitting) of the injection pipe steel may become an issue when emission gasses from oxyfuel power plants are compressed into deep geological layers. This highly corrosive environment arises when the flue gasses, mainly composed of CO2 , are injected into saline aquifer water. Immediately carbonic acid is formed causing corrosive attack of the injection steels. The influence of heat treatment on the local corrosion resistance was demonstrated in laboratory experiments at 60 °C and ambient pressure for three steels X46Cr13 (1.4034), X20Cr13 (1.4021) and X5CrNiCuNb16-4 (1.4543) under a similar liquid corrosive environment as found at a geological onshore CCS-site in the Northern German Bassin. T2 - 2nd Oxyfuel combustion conference CY - Yeppoon, Queensland, Australia DA - 12.09.2011 KW - Steel KW - Pipe KW - Corrosion KW - Heat treatment KW - CO2-injection KW - CO2-storage CCS KW - Carbonate KW - Ambient pressure KW - CCS KW - Steels PY - 2011 SP - 1 EP - 3 AN - OPUS4-25536 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER - TY - JOUR A1 - Yevtushenko, Oleksandra A1 - Bettge, Dirk A1 - Bohraus, Stefan A1 - Bäßler, Ralph A1 - Pfennig, A. A1 - Kranzmann, Axel T1 - Corrosion behavior of steels for CO2 injection N2 - The process chain for Carbon Capture and Sequestration (CCS) includes tubing for injection of CO2 into saline aquifers. The compressed CO2 is likely to contain specific impurities; small concentrations of SO2 and NO2 in combination with oxygen and humidity are most harmful. In addition, CO2 saturated brine is supposed to rise in the well when the injection process is interrupted. The material selection has to ensure that neither CO2 nor brine or a combination of both will leak out of the inner tubing. In this comprehensive paper the investigated materials range from low-alloy steels and 13% Cr steels up to high-alloy materials. Electrochemical tests as well as long term exposure tests were performed in CO2, in brine and combination of both; pressure was up to 100 bar, temperature up to 60 °C. Whereas the CO2 stream itself can be handled using low alloy steels, combinations of CO2 and brine require more resistant materials to control the strong tendency to pitting corrosion. The corrosion behavior of heat-treated steels depends on factors such as microstructure and carbon content. For different sections of the injection tube, appropriate materials should be used to guarantee safety and consider cost effectiveness. KW - CCS KW - Injection tubing KW - Corrosion KW - Safety KW - Carbon steel KW - High alloy steel KW - Saline fluid KW - Supercritical CO2 PY - 2014 U6 - https://doi.org/10.1016/j.psep.2013.07.002 SN - 0957-5820 SN - 1744-3598 VL - 92 IS - 1 SP - 108 EP - 118 PB - Elsevier CY - Amsterdam AN - OPUS4-28966 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER - TY - JOUR A1 - Pfennig, Anja A1 - Wolf, Marcus A1 - Wiegand, Reiner A1 - Kranzmann, Axel A1 - Bork, Claus-Peter T1 - Corrosion fatigue behavior and S-N-curve of X46Cr13 exposed to CCS-environment obtained from laboratory in-situ-experiments N2 - In corrosive environments such as CCS bore holes or geothermal power plants the materials loaded cyclically are also exposed constantly to the highly corrosive hot thermal water. The lifetime reduction of (X46Cr13, AISI 420C) is demonstrated in in-situ-laboratory experiments (T=60 °C, geothermal brine: Stuttgart Aquifer flow rate: 9 Nl/h, CO2). S-N plots, micrographic-, phase-, fractographic- and surface analysis were applied to obtain sustainable information on the corrosion fatigue behavior. Maximum number of cycles (here 12.5 x 106 cycles to failure) is reached at σa =173 MPa. No typical fatigue strength exists and passive corrosion fatigue is most likely failure cause. KW - Steel KW - Supercritical CO2 KW - Pipeline KW - Corrosion KW - CCS KW - CO2-storage PY - 2013 U6 - https://doi.org/10.1016/j.egypro.2013.06.499 SN - 1876-6102 VL - 37 SP - 5764 EP - 5772 PB - Elsevier Ltd. CY - Amsterdam AN - OPUS4-29342 LA - eng AD - Bundesanstalt fuer Materialforschung und -pruefung (BAM), Berlin, Germany ER -