Relevant bibliographies by topics / High Pressure High Temperature Corrosion

Contents

  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
  6. Reports

Academic literature on the topic 'High Pressure High Temperature Corrosion'

Author: Grafiati
Published: 4 June 2021
Last updated: 1 February 2022

Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles

Select a source type:

Consult the lists of relevant articles, books, theses, conference reports, and other scholarly sources on the topic 'High Pressure High Temperature Corrosion.'

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 "High Pressure High Temperature Corrosion"

1

Lasebikan, B. A., A. R. Akisanya, and W. F. Deans. "Autoclave design for high pressure-high temperature corrosion studies." Journal of Engineering, Design and Technology 13, no. 4 (October 5, 2015): 539–55. http://dx.doi.org/10.1108/jedt-08-2013-0057.

Full text
Abstract:
Purpose – The purpose of this paper is to develop an autoclave that can be used to assess corrosion behaviour of suitable material in high-pressure–high-temperature (HPHT) environments. Many new discoveries of oil and gas field are in HPHT environments. The development of such fields requires appropriate selection of materials that are able to withstand not just the service loads but also corrosive production fluids in the HPHT environment. Design/methodology/approach – The exposure of material samples to elevated pressure and temperature is usually done using an autoclave. The suitability of an existing autoclave for HPHT corrosion studies is provided together with suggestions on necessary design modifications. An alternative design of the autoclave is proposed based on functionality requirements and life cycle cost assessment. Findings – It is concluded that the existing autoclave was unsuitable for HPHT corrosion tests, and modifications were very expensive to implement and/or not foolproof. A new autoclave was designed, manufactured, tested and successfully used to study the effect of aqueous solution on the corrosion of a pipe subject to a combination of axial tension, internal pressure and elevated temperature. Research limitations/implications – The maximum design pressure of 15 MPa is more than sufficient for high-pressure corrosion studies in aqueous solution where partial pressure of the dissolved gas is one of the main controlling parameters. However, the design pressure is only suitable for corrosion studies in a seawater environment of up to 1,500 m water depth. Originality/value – A new design of autoclave together with all the necessary piping, assembly and control system is proposed for HPHT corrosion studies. The autoclave can be used as standalone or integrated with a mechanical testing machine and thus enables corrosion studies under a wide range of loading.
APA, Harvard, Vancouver, ISO, and other styles
2

Kobayashi, Kenji, Tomohiko Omura, Atsushi Souma, Taro Ohe, Hisashi Amaya, and Masakatsu Ueda. "Environmental Cracking Susceptibility of Low-Alloy Steels Under a High H2S Pressure and High-Temperature Sour Environment." Corrosion 74, no. 5 (November 30, 2017): 509–19. http://dx.doi.org/10.5006/2669.

Full text
Abstract:
Environmental cracking (EC) susceptibility of low-alloy steels with a specified minimum yield strength of 655 MPa (95 ksi) and 758 MPa (110 ksi) manufactured by quenching and tempering heat treatments was investigated in high H2S partial pressures (more than 1.0 MPa) using four-point bend tests in autoclaves. The H2S partial pressures and testing temperatures varied from 1.0 MPa to 10 MPa and 24°C to 150°C, respectively. Materials of grades 95 ksi and 110 ksi containing high Cr and Mo showed no macrocracking under all tested conditions. Localized corrosion occurred at several locations after exposure for 1 month under high H2S pressure and high-temperature conditions. It was concluded that the localized corrosion did not form macrocracking even after long-term (3 months) immersion tests. On the other hand, 110 ksi grade material containing low Cr and Mo suffered from sulfide stress cracking at low temperatures (below 66°C) and at an H2S pressure of 1.0 MPa. The material also showed EC at an H2S pressure of 10 MPa and temperature from 107°C to 150°C. The difference of EC susceptibility among the materials is discussed based on corrosion reactions, hydrogen absorption, and morphologies of the corrosion products on the steel surface.
APA, Harvard, Vancouver, ISO, and other styles
3

Liu, Shaohu, Liu Yuanliang, Zhong Hong, Zou Jiayan, and Yang Dong. "Experimental study on corrosion resistance of coiled tubing welds in high temperature and pressure environment." PLOS ONE 16, no. 1 (January 22, 2021): e0244237. http://dx.doi.org/10.1371/journal.pone.0244237.

Full text
Abstract:
Coiled tubing (CT) has been widely used for oil and gas exploitation, however corrosion of CT under high pressure and high temperature (HPHT) environment was often reported, also corrosion induced failures of CT welds were often observed to occur during service. Corrosion related behaviors of CT welds are not clear. Therefore, a study of the corrosion resistance of CT welds under HPHT environment is carried out. In order to efficiently evaluate the corrosion resistance of welds, some test samples were obtained by linear cutting out of a CT110 in service on the site. The water samples from gas field were used as the test reagent to simulate the actual corrosive medium. Based on the results of weight loss test under HPHT corrosive environment and tensile test under room conditions, the corrosion sensitivities of the welding seam and base material under various temperatures and partial pressures of CO2 as well as the mechanical properties of the corroded CT were compared and evaluated quantitatively, the corrosion morphologies and material products of the test samples were analyzed by scanning electron microscope (SEM). The test results showed that the corrosion rates of the welding seam in a HPHT caldron were 1.7, 2.0 and 1.2 times of the base metal’s when the total pressure is 4MPa, and the temperature is 30°C, 60°C and 90°C, respectively. The corrosion rates of the welding seam is 2.0, 2.1 and 2.0 times of the base metal’s when the partial pressure of CO2 is 0.1MPa, 0.2MPa and 0.3MPa, respectively. The yield strength of the weld seam after corrosion test was found to be reduced by 4.8% (the yield strength of the base metal was reduced by 4.0%) and its tensile strength was reduced by 8.2% (the base metal was reduced by 7.1%). This indicates that CT weld seam is more susceptible to corrosion than CT base material under service condition.
APA, Harvard, Vancouver, ISO, and other styles
4

Slemnik, Mojca. "Impact of High Temperature and Pressure to Steel Passivation in CO2 Atmosphere." Acta Chimica Slovenica 68, no. 2 (June 15, 2021): 447–57. http://dx.doi.org/10.17344/acsi.2020.6590.

Full text
Abstract:
The corrosion behaviour of AISI 347 in 0.1 M sulfuric acid at temperatures 50 and 75 °C and pressures up to 300 bar in a CO2 atmosphere was studied by surface analysis and electrochemical methods. Corrosion reactions in which CO2 is present accelerate the formation of a protective FeCO3 layer, but the success of such a passivation depends on the saturation concentration and the corresponding temperature. Significantly better results compared to untreated steels were obtained at lower temperatures by increasing the pressure. To explain the differences in corrosion rates between samples, the activation energy for the layer dissolution was also discussed. It can be assumed that the compressibility of the CO2 at different pressures has an influence on the formation of the protective iron carbonate layer and its properties and thus to on the corrosion behaviour.
APA, Harvard, Vancouver, ISO, and other styles
5

Kritzer, P., N. Boukis, and E. Dinjus. "Corrosion of Alloy 625 in High-Temperature, High-Pressure Sulfate Solutions." CORROSION 54, no. 9 (September 1998): 689–99. http://dx.doi.org/10.5006/1.3284888.

Full text
APA, Harvard, Vancouver, ISO, and other styles
6

Xu, Peng, Zhengwu Tao, and Zhihong Wang. "Corrosion-resistant systems of formate packer fluid for G3/N80/TP110SS pipes at high temperature, high pressure and high H 2 S/CO 2 ratios." Royal Society Open Science 5, no. 7 (July 2018): 180405. http://dx.doi.org/10.1098/rsos.180405.

Full text
Abstract:
A series of corrosion problems caused by high-temperature, high-pressure and high-acid gas environments has been an issue in oil and gas production for a long time. During the development of a high-acid gas field, the petroleum pipe is subjected to many aspects of corrosion, and the corrosion mechanism is complicated by the condition of the coexistence of H 2 S/CO 2 . Based on the study of the corrosion problem associated with the formate packer fluid in Southwest China, three kinds of steels were studied for corrosion prevention in the alloy G3/N80 steel/TP110SS steel. The study shows that the corrosion rate of the formate packer fluid is low, but corrosion is severe in environments characterized by high temperatures, high pressures and high-acid gas contents. Based on the consideration of cost and the difficulty of realization, an anti-corrosion system was constructed based on the existing packer fluid, mainly through the introduction of a variety of anti-corrosion additives. Through the selection of various additives and corrosion experiments, a corrosion protection system of formate packer fluid was developed. Corrosion tests show that the corrosion rate of the system must be less than 0.076 mm yr −1 to achieve the purpose of corrosion protection. The formate packer fluid with corrosion protection can meet the needs of the current application.
APA, Harvard, Vancouver, ISO, and other styles
7

Ijiri, Masataka, Takayuki Ogi, and Toshihiko Yoshimura. "High-temperature corrosion behavior of high-temperature and high-pressure cavitation processed Cr–Mo steel surface." Heliyon 6, no. 8 (August 2020): e04698. http://dx.doi.org/10.1016/j.heliyon.2020.e04698.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Lu, Hao Sheng, and Peng Fei Yan. "Effect of Pressure and Temperature of Solution Treatment on the Microstructure and Corrosion Resistance of AZ91D Alloy." Applied Mechanics and Materials 628 (September 2014): 111–14. http://dx.doi.org/10.4028/www.scientific.net/amm.628.111.

Full text
Abstract:
As-cast AZ91D magnesium alloy was solid dissolved at atmospheric temperature under different pressures (room pressure、2、3、4、5 and 6 Gpa) and under high-pressure (6 Gpa) at different temperatures (atmospheric temperature, 200, 400, 600, 800 and 1000 °C). The microstructures of the products were characterized by optical microscope and their corrosion resistance was investigated. The results show that increasing the solution pressure at atmospheric temperature has no obvious effect on the microstructure of AZ91D, but decreases the corrosion resistance. Increasing the solution temperature under the high-pressure can obviously improve the microstructure of the alloy, and markedly increases the corrosion resistance, especially over 400 °C.
APA, Harvard, Vancouver, ISO, and other styles
9

Wan, Li Ping, Ying Feng Meng, Gao Li, and Hua Zhou. "Corrosion Behavior of Drilling Pipe Steels for High Sour Gas Field." Advanced Materials Research 415-417 (December 2011): 2292–97. http://dx.doi.org/10.4028/www.scientific.net/amr.415-417.2292.

Full text
Abstract:
A polymer drilling fluid containing high content of hydrogen sulfide was used as the corrosive medium to investigate the effects of temperature, flow velocity, pH value and partial pressure ratio of CO2/ H2S on the corrosion behavior of high strength drill pipe steel S135 and G105. The morphology and composition of the corrosion products were analyzed as well. It was found that the average corrosion rate of the two types of steel increased with increasing temperature of the corrosive medium, with the corrosion rate to decrease slightly within 60°C-80°C and keep almost unchanged above 120°C. At the same time, the corrosion rate of the drill pipe steels had little to do with the flow rate but increased with decreasing pH value of the corrosive medium. Moreover, the partial pressure ratio of CO2/ H2S had a slight effect on the corrosion behavior of the drill pipe steel. However, the two types of drill pipe steel showed a larger corrosion rate in gas phase than in liquid phase corrosive medium, which was contrary to what were observed in gas and liquid phases corrosion tests of conventional acidic drilling fluids. In addition, it was confirmed by sulfide stress corrosion test that the drill pipe steel of a higher strength had smaller critical stress, and the resistance of the drill pipe to stress attack was ranked as G105(C)＞G105(D)＞S135(B)＞S135(A). It was anticipated that the present research results could be used to guide the selection of materials for drilling pipe steels used in natural gas field of high acidity.
APA, Harvard, Vancouver, ISO, and other styles
10

Mustafa, Abdel Hafiz, Bamban Ariwahjoedi, and M. C. Ismail. "Corrosion Behavior of X52 Steel in High Pressure CO2 Environment." Advanced Materials Research 686 (April 2013): 234–43. http://dx.doi.org/10.4028/www.scientific.net/amr.686.234.

Full text
Abstract:
Research in high pressure CO2 environment is important in oil and gas industry due to potential development of high pressure CO2 gas fields. Current understanding limits the use of carbon steel pipeline material in this high pressure CO2 environment due to excessive corrosion rates predicted by corrosion prediction software. The aim of this work is to elucidate the corrosion behavior of X52 steel in high pressure CO2 environment. Electrochemical methods of linear polarization resistance (LPR), electrochemical impedance spectroscopy (EIS) and potentiodynamic polarization techniques were employed to study the CO2 corrosion mechanism at high pressures of 10-60 bar at ambient temperature. Surface morphology and chemical composition of corrosion film was studied by using scanning electron microscopy (SEM) and X-ray diffraction (XRD). The results obtained showed that the corrosion rates at high pressures were significantly influenced by CO2 pressure. However FeCO3 and F3C were the main component of the corrosion product film.
APA, Harvard, Vancouver, ISO, and other styles
More sources

Dissertations / Theses on the topic "High Pressure High Temperature Corrosion"

1

Liu, Jing. "High temperature and high pressure corrosion of titanium in hydrometallurgical applications." Thesis, University of British Columbia, 2015. http://hdl.handle.net/2429/52353.

Full text
Abstract:
The corrosion characteristics of titanium (ASTM Grade 2) in copper pressure leaching environments are determined from room temperature and pressure up to high temperatures and pressures (230 °C, 430 psi). Anodic oxidation and controlled chemical oxidation methods are used to improve the corrosion resistance of Ti. Electrochemical and mass loss measurements are performed to evaluate the corrosion resistance of pre-oxidized titanium, compared to that of titanium with no prior oxidation, to generate a best practices guide for the hydrometallurgical industry. The results at low temperature showed that H₂SO₄ solution is very corrosive for Ti with a freshly polished surface. The corrosion rates (CRs) of Ti are obtained using mass loss and electrochemical measurements in H₂SO₄ with Cl-, Cu²⁺ and Fe³⁺ additions up to 175 °C. It is found that the CRs of Ti are unaffected by the presence of Cl− ions in H₂SO₄ solutions. CRs obtained from mass loss and electrochemical measurements confirm that Cu²⁺ and Fe³⁺ ions are good corrosion inhibitors for Ti. Iso-corrosion diagrams, with 0.1, 0.5 and 1 mm yr−1 lines for Ti in 3-50 wt.% H₂SO₄ solutions with Cu²⁺ and Fe³⁺ additions from room temperature to 175 °C are constructed from immersion test data. The effects of temperature (100-230 °C) and SO₄²− concentration (0-0.5 mol L−¹) on the pitting corrosion of Ti are studied in neutral Cl− containing solutions using cyclic potentiodynamic polarization and linear-sweep thermammetry measurements. A metastable pitting temperature threshold (MPTT) is defined for Ti as a function of sulfate to chloride mole ratio using linear-sweep thermammetry measurements. iii Anodic oxide films (AOFs) are potentiostatically formed on Ti in 0.5 M H₂SO₄ solutions at various anodizing voltages (up to 80 V) at 25 °C. A new method is developed to fabricate chemically oxidized films (COFs) with high corrosion resistance by controlled chemical oxidation with H₂O₂ solutions at 90 °C. The corrosion behavior of the as grown AOFs and COFs is investigated in copper sulfide leaching solutions. It is confirmed that chemical oxidation with 2 M H₂O₂/0.1 M HCl solution leads to the best improvement of the corrosion resistance of Ti.
Applied Science, Faculty of
Materials Engineering, Department of
Graduate
APA, Harvard, Vancouver, ISO, and other styles
2

Leonard, Fabien. "Study of stress corrosion cracking of alloy 600 in high temperature high pressure water." Thesis, University of Manchester, 2010. https://www.research.manchester.ac.uk/portal/en/theses/study-of-stress-corrosion-cracking-of-alloy-600-in-high-temperature-high-pressure-water(73edf35d-2bf4-42be-9816-b0746620dcf5).html.

Full text
Abstract:
Stress corrosion cracking (SCC) of alloy 600 is regarded as one of the most important challenges to nuclear power plant operation worldwide. This study investigates two heats of alloy 600 (forged control rod drive mechanismnozzle and rolled divider plate) in order to obtain a better understanding of the effects of the material parameter on the SCC phenomenon. The experimental approach was designed to determine the effect of the manufacturing process (forged vs. rolled), the cold-work (as-received vs. cold-worked) and the strain path (monotonic vs. complex) on SCC of alloy 600. Specimens with different strain paths have been produced from two materials representative of plant components and tested in high temperature (360°C) high pressure primary water environment. The manufacturing process has been proven to have a great effect on the stress corrosion cracking behaviour of alloy 600. Indeed, the SCC susceptibility assessment has demonstrated that the rolled materialis resistant to SCC even after cold work, whereas the forged material is susceptible in the as-received state. Microstructural characterisations have been undertaken to explain these differences in SCC behaviour. The carbide distribution is the main microstructural parameter influencing SCC but the misorientation, in synergy with the carbide distribution, has been proven to give a better representation of the materials SCC susceptibilities.
APA, Harvard, Vancouver, ISO, and other styles
3

Ubah, Chinedu Gideon. "Design of high temperature and pressure electrochemical cell and corrosion chemistry of alloy 625 in high temperature and high pressure aqueous media using a two-electrode electrochemical method." Thesis, University of British Columbia, 2010. http://hdl.handle.net/2429/28201.

Full text
Abstract:
As aqueous processing moves to higher temperatures and pressures to take advantage of increased kinetics, there is a need to develop and test appropriate reactor materials to ensure that corrosion is minimized. Corrosion testing often requires an electrochemical approach for a comprehensive understanding of the range of behaviors exhibited from a corroding metal or alloy in different environments. Prior art of designs for electrodes, associated pressure vessels and sealing technology is presented. The development of an apparatus and methods for high temperature and high pressure electrochemical corrosion testing are discussed. The final flow-through electrochemical cell design, the Flow-Through External Pressure-Balanced Reference Electrode (FTEPBRE) design, working/counter electrode and other components, which were developed for temperatures and pressures in excess of 500ºC and 5000 PSI is presented. A two-electrode electrochemical testing method is presented, using Stainless Steel (SS 316) as both Quasi Reference Electrode (QRE) and Counter Electrode (CE), and Alloy 625 (Ni-062.8%, Cr-21.8%, Mo-7.35, Fe-3.97%, Nb-2.7%) as the Working Electrode (WE). The effects of pressure, and its combination with temperature on OCP and corrosion rate of alloy 625 (WE) in both naturally aerated and de-oxygenated environments in 0.1 M sodium sulphate (Na₂SO₄) solution with a flow rate of 7 mL/min were investigated and discussed. The effect of pressure represented as a change in activation volume and reaction volume for the homogenous and heterogeneous phases is also presented. The corrosion rate was observed to increase with both temperature and pressure: higher for naturally aerated conditions than the corresponding de-aerated ones. Results also show that the instability of the QRE affected the result and direction of the OCP tests. A reduction in the corrosion current was observed above 207 bar (3000 PSI) in the polarization tests and was attributed to the increasing stability of the passive film formed on the surface of the alloys.
APA, Harvard, Vancouver, ISO, and other styles
4

Asselin, Edouart. "High temperature and high pressure corrosion of Ni-based alloys and stainless steels in ammoniacal sulphate solution." Thesis, University of British Columbia, 2007. http://hdl.handle.net/2429/30709.

Full text
Abstract:
The corrosion characteristics of Alloy 625 (UNS 00625, Ni - 22 Cr - 10 Mo) in oxygenated ammoniacal sulphate environments are determined at room temperature and pressure and up to high temperatures and pressures (673 K, 250 bar) commensurate with the process of supercritical water oxidation (SCWO). Electrochemical methods such as linear polarization, potentiodynamic polarization and impedance spectroscopy are used. It is found that the electrochemical and morphological response is dictated by the alloying element Cr and the formation of a Cr(III) oxide. Mo and, to a lesser extent Ni, are found to dissolve readily. Thermodynamic analysis of the Ni-NH₃-H₂O system, including new Pourbaix diagrams at temperatures as high as 653 K , has shown that Ni - ammine formation is possible at moderate temperatures but that the stability of these complexes decreases substantially with temperature. According to one of the models investigated, which is based on the only available high temperature equilibrium constant data, Ni-ammines become unstable above approximately 473 K . Impedance spectroscopy has shown that transpassive dissolution of the alloy's ptype, cation conducting, Cr(III) oxide occurs at temperatures as low as 373 K and total pressure (oxygen saturated) as low as 40 bar. As temperature and pressure are increased the corrosion process is increasingly diffusion controlled. Transpassive dissolution results in the thinning and eventual total removal of the alloy's protective semiconductor barrier layer. Cation ejection from the barrier layer into the solution and porous outer layer phase results in precipitation of a Cr(III) scale (oxide or hydroxyl-oxide) at the alloy surface which acts as a diffusion barrier. It is hypothesized that the outer layer is either physically removed at supercritical conditions due to rapid dissolution and grain boundary attack of the alloy or chemically removed by solution acidification due to the formation of sulphuric acid at high density supercritical conditions. Alloys 625, 316 L, Ni - 20 Cr and pure Nb are tested at SCWO conditions and it is found that the corrosion resistance increases with Cr content and Nb is found to perform well in sulphate containing SCWO solutions at oxygen concentrations up to 4 m. It is also confirmed in this work that maximum material loss occurs in the high-density supercritical region of the reactor. New Pourbaix diagrams for Nb at elevated temperatures (348 and 368 K) are calculated and compared to electrochemical and weight loss measurements performed in concentrated acids. Through electrochemical experiments in concentrated sulphuric and hydrochloric acids, Nb is found to be an ideal candidate for the high-density supercritical sections of SCWO reactors.
Applied Science, Faculty of
Materials Engineering, Department of
Graduate
APA, Harvard, Vancouver, ISO, and other styles
5

Jones, Franziska Anna. "The Effect of a High-Temperature High-Pressure Nitrogen Environment with Carbonaceous Impurities on the Performance of Three Austenitic Alloys." Thesis, University of Canterbury. Mechanical Engineering, 2007. http://hdl.handle.net/10092/3268.

Full text
Abstract:
WhisperGenTM heater head components are currently machined from the austenitic stainless steel Sandvik 253MA. The inner surface of the heater heads is subjected to the working gas of the engine, which is a high-pressure, high-temperature nitrogen-based environment with carbonaceous impurities. As a result of this exposure, a scale forms during operation and eventually spalls. This spalled scale causes abrasive damage to piston seals and guides, which leads to pressure loss and eventual failure of the engine. The aim of the present work was to compare the performance of the austenitic alloy 253MA with two alternative alloys, Incoloy 800H and AISI 310, thereby enabling a material recommendation. A literature review provided information about many general aspects of high temperature corrosion in similar alloys. However, little was found about the application of these alloys in environments similar to those experienced by a WhisperGenTM heater head. Therefore, laboratory experiments were conducted to indicate the relative performance characteristics of the three potential alloys (253MA, Incoloy 800H and AISI 310). To overcome the difficulties with testing at high temperatures and pressures, Thermo-Calc™ was used to calculate gas mixtures at 1 bar that approximated the chemical potentials of carbon and nitrogen in the working gas at 24 bar. Comparisons of the different materials were made via weight loss/gain measurements and metallographic analysis, which included optical microscopy, scanning electron microscopy, X-ray mapping and electron back scatter diffraction (EBSD). The laboratory test sample results were also compared with results from heater heads of the same materials that were run in an actual WhisperGenTM engine. The experimental results taken in total indicate that 253MA is the least suitable alloy for the heater head application because it exhibited poor spalling performance, internal oxidation and formation of a large amount of Cr23C6. AISI 310 was shown in all cases to develop the detrimental sigma phase, although this alloy was the least susceptible to internal oxidation. Incoloy 800H was the most resistant alloy to all forms of degradation and is thus recommended for the heater head application.
APA, Harvard, Vancouver, ISO, and other styles
6

Lasebikan, B. A. "Mechanical behaviour and stress corrosion cracking of super duplex stainless steel pipes in high pressure and high temperature environment." Thesis, University of Aberdeen, 2011. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.540314.

Full text
Abstract:
The oil and gas industry is constantly looking at ways to keep costs down in high temperature and high pressure (HPHT) well completions. The use of duplex or super duplex stainless steel (DSS or SDSS) for production tubing rather than high alloy (austenitics or nickel based) steels is one way to achieve this. An effective use of DSS or SDSS requires an understanding of the effects of environmental and metallurgical variables on the general and localised corrosion behaviour and resistance to environment assisted cracking (EAC) in HPHT well conditions. This research investigates the behaviour of small scale SDSS pipes subject to combined loads in a chloride and sulphide environment which are commonly found in the non-production annulus of oil and gas well completions. The effects of H2S (which can sometimes leak from the production fluid) on the chloride-based fluid and ammonium bisulphite in the non-production environment is examined. This is used to provide a realistic assessment of the type of fluid that SDSS production tubing may be exposed to in service. Experimental results are presented for the failure envelope under combined internal pressure and axial tension, and mechanical properties of SDSS pipe over a range of temperatures. A standalone autoclave was designed and commissioned to study the initiation of EAC in SDSS pipes in several aqueous solutions under a range of loading conditions: internal pressure, axial load, and a combination of internal pressure and axial load. The work presented in this thesis shows that corrosion tests can be carried out using small scale pipes for better understanding of the effects of stress state on corrosion behaviour. In particular, the safe working envelope of SDSS in terms of load combination, chloride-sulphide environment and temperature is determined in this thesis. This would help the end user understand and gain better in-service performance of SDSS in oil and gas HPHT environment.
APA, Harvard, Vancouver, ISO, and other styles
7

Krishnamoorthy, Vijay. "Effect of gas density on corrosion in horizontal multiphase slug flow at high temperatures and pressures." Ohio : Ohio University, 1997. http://www.ohiolink.edu/etd/view.cgi?ohiou1177096097.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Parakala, Shilpha R. "EIS Investigation of Carbon Dioxide and Hydrogen Sulfide Corrosion Under Film Forming Conditions." Ohio University / OhioLINK, 2005. http://rave.ohiolink.edu/etdc/view?acc_num=ohiou1125871582.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

SALA, BEATRICE. "Contribution a l'etude de la corrosion du titane, de ses alliages et de certains aciers inoxydables en milieu aqueux, a haute temperature et sous pression." Orléans, 1987. http://www.theses.fr/1987ORLE2048.

Full text
Abstract:
Application de l'electrochimie a haute temperature et sous pression illustree par trois cas de corrosion: 1) corrosion du titane et de ses alliages en milieu sulfurique 2) corrosion d'un acier a 13% de chrome en milieu carbonique; 3) corrosion d'aciers austeno-ferritique en milikeu carbonique contenant de l'hydrogene sulfure. Identification de differents facteurs permettant l'amelioration de la resistance a la corrosion de ces differents materiaux
APA, Harvard, Vancouver, ISO, and other styles
10

Plennevaux, Cécile. "Etude des risques de corrosion et de rupture différée des aciers en présence d'H2S dans les conditions d'exploration de pétrole et de gaz à haute pression et haute température." Thesis, Lyon, INSA, 2012. http://www.theses.fr/2012ISAL0101.

Full text
Abstract:
L'exploitation des champs de pétrole et de gaz sous haute pression (HP) et haute température (HT) a augmenté ces dernières années, nécessitant de réévaluer les risques de corrosion dans ces milieux de plus en plus sévères. Afin de contribuer à une meilleure évaluation des risques de rupture différée des aciers en présence d'H2S (SSC, Sulfide Stress Cracking) dans ces conditions, trois axes de recherche ont été suivis. Nous avons d'abord identifié un besoin d'amélioration de prédiction des conditions corrosives sous haute pression et haute température, et en particulier pour le calcul du pH in situ. Un modèle a été développé ; il prend en compte le comportement non-idéal des phases en équilibre, et permet un calcul plus précis du pH et de la fugacité des gaz acides à haute pression et haute température. Dans un deuxième temps, nous avons étudié l'effet de la pression partielle de CO2 (PCO2) sur les réactions de surface et sur les risques de SSC. Cette étude, réalisée à l'aide de mesures électrochimiques en l’absence d’un film de sulfure de fer, a permis de montrer que la présence de CO2 augmente sensiblement les cinétiques des réactions cathodiques à la surface de l'acier ainsi que le chargement en hydrogène, en particulier lorsque la pression partielle en H2S (PH2S) est faible. Enfin, des essais SSC ont été mis en œuvre dans des conditions fixes de pH et de PH2S, en faisant varier PCO2 entre zéro et 100 bar. L'objectif était de vérifier que la présence de CO2 sous forte pression augmentait bien les risques de fissuration, comme prévu par les résultats des essais électrochimiques. Les difficultés liées à la mise en œuvre d'essais en autoclave sous pression n'ont pas permis d'apporter une conclusion définitive. Néanmoins, ces travaux montrent qu'il peut exister un risque de sous-estimation de la sévérité des milieux dans les pratiques conventionnelles, lorsque PCO2 est significativement plus élevée que PH2S. Dans ces conditions spécifiques, les résultats de ce travail peuvent servir à améliorer les critères de choix de matériaux pour les milieux HP/HT
The production of high pressure (HP) and high temperature (HT) wells has considerably increased in the last decade. It is therefore needed to reassess the risks of corrosion in always more severe environments. This work was three fold to better assess the risk of Sulfide Stress Cracking (SSC) in these environments. Firstly, there was a need to improve prediction methods for the evaluation of HP/HT environments severity, especially the in situ pH calculation. A model was which taking into account the non-ideal behaviour of gas and liquid phases in equilibrium. The determination of the in situ pH and the acid gas fugacity at high pressure and high temperature is more accurate. In a second part of the work, the impact of CO2 partial pressure (PCO2) on surface reactions and hence on the risk of SSC was examined. Electrochemical and hydrogen permeation measurements in the absence of an iron sulphide film showed that CO2 induces an increase of both cathodic reactions kinetics and hydrogen charging in the steel, especially at low H2S partial pressure (PH2S). In the last part of this work, SSC tests were performed at constant pH and constant PH2S, with various PCO2 from 0 to 100 bar. The objective was to experimentally confirm that increasing PCO2 increases the SSC risk, as inferred from the electrochemical study. Unfortunately, experimental artefacts linked with autoclave test conditions did not lead to clear conclusions on this point. However, this work shows that conventional tools might lead to underestimate SSC risks at high PCO2 and low PH2S. In these specific conditions, the new results presented in this report may contribute to improve materials selection criteria for high pressure and high temperature conditions
APA, Harvard, Vancouver, ISO, and other styles
More sources

Books on the topic "High Pressure High Temperature Corrosion"

1

Khanna, Anand S. High temperature corrosion. New Jersey: World Scientific, 2016.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
2

High temperature corrosion. London: Elsevier Applied Science, 1988.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
3

Sequeira, César A. C. High Temperature Corrosion. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2019. http://dx.doi.org/10.1002/9781119474371.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Li, Zhengwei. High temperature corrosion of intermetallics. Hauppauge, N.Y: Nova Science Publishers, 2008.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
5

Blachere, J. R. High temperature corrosion of ceramics. Park Ridge, N.J., U.S.A: Noyes Data Corp., 1989.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
6

North Atlantic Treaty Organization. Advisory Group for Aerospace Research and Development. High temperature surface interactions. Neuilly sur Seine, France: AGARD, 1989.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
7

Lai, G. Y. High-temperature corrosion of engineering alloys. Materials Park, OH: ASM International, 1990.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
8

Eisenforschung, Max-Planck-Institut für, and Materials Technology Institute of the Chemical Process Industries (U.S.), eds. Carburization: A high temperature corrosion phenomenon. St. Louis, MO: Material Technology Institute of the Chemical Process Industries, 1998.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
9

High temperature oxidation and corrosion of metals. Amsterdam: Elsevier, 2008.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
10

Symposium, on High Temperature Corrosion and Materials Chemistry (5th 2004 Honolulu Hawaii). High temperature corrosion and materials chemistry V. Pennington, NJ: Electrochemical Society, 2005.

Find full text
APA, Harvard, Vancouver, ISO, and other styles
More sources

Book chapters on the topic "High Pressure High Temperature Corrosion"

1

Kassim, Khairan Syuhada. "Corrosion Resistant Alloy Pipeline Installation for High Pressure High Temperature Requirement." In Lecture Notes in Civil Engineering, 302–9. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-33-6311-3_35.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

Zhang, Jingfu, Shuai Shao, Shuting Wang, Wenhui Xiao, and Ziyang Lin. "Carbon Dioxide Corrosion on Casing Under High-Temperature and High-Pressure Conditions in Deep Wells." In Proceedings of the International Field Exploration and Development Conference 2018, 247–60. Singapore: Springer Singapore, 2019. http://dx.doi.org/10.1007/978-981-13-7127-1_24.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Li, W., O. T. Woo, D. Guzonas, J. Li, X. Huang, R. Sanchez, and C. D. Bibby. "Effect of Pressure on the Corrosion of Materials in High Temperature Water." In Characterization of Minerals, Metals, and Materials 2015, 99–106. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2015. http://dx.doi.org/10.1002/9781119093404.ch12.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Li, W., O. T. Woo, D. Guzonas, J. Li, X. Huang, R. Sanchez, and C. D. Bibby. "Effect of Pressure on the Corrosion of Materials in High Temperature Water." In Characterization of Minerals, Metals, and Materials 2015, 99–106. Cham: Springer International Publishing, 2015. http://dx.doi.org/10.1007/978-3-319-48191-3_12.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

Zhao, Lei, and Zhiyue Xu. "Carbon Nanocomposite for Reliable Seal Applications in High-Temperature, High-Pressure, Corrosive Environments." In TMS 2018 147th Annual Meeting & Exhibition Supplemental Proceedings, 777–85. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-72526-0_73.

Full text
APA, Harvard, Vancouver, ISO, and other styles
6

Kimura, S., Y. Ishikura, T. Kataoka, M. Soeda, T. Masuda, Y. Yoshikawa, and M. Nagata. "Stable and Corrosion-Resistant Sapphire Capacitive Pressure Sensor for High Temperature and Harsh Environments." In Transducers ’01 Eurosensors XV, 518–21. Berlin, Heidelberg: Springer Berlin Heidelberg, 2001. http://dx.doi.org/10.1007/978-3-642-59497-7_123.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Zhou, Qi, Qin Ma, Yu Qiang Yi, Jian Jun Liu, and Hong Lin Xu. "H2S/CO2 Corrosion Behavior of Tubular Goods under High Temperature and High Pressure." In Materials Science Forum, 370–73. Stafa: Trans Tech Publications Ltd., 2006. http://dx.doi.org/10.4028/0-87849-995-4.370.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Kim, Weon Ju, Seok Min Kang, and Ji Yeon Park. "Corrosion Behavior of Si3N4 Ceramics under High-Temperature and High-Pressure Water Condition." In Advanced Materials Research, 259–62. Stafa: Trans Tech Publications Ltd., 2007. http://dx.doi.org/10.4028/0-87849-463-4.259.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

Nordin, H. M., A. J. Elliot, and S. G. Bergin. "High Temperature Aqueous Corrosion and Deuterium Uptake of Coupons Prepared from the Front and Back Ends of Zr-2.5Nb Pressure Tubes." In Zirconium in the Nuclear Industry: 16th International Symposium, 373–400. 100 Barr Harbor Drive, PO Box C700, West Conshohocken, PA 19428-2959: ASTM International, 2010. http://dx.doi.org/10.1520/stp49268t.

Full text
APA, Harvard, Vancouver, ISO, and other styles
10

Nordin, H. M., A. J. Elliot, and S. G. Bergin. "High Temperature Aqueous Corrosion and Deuterium Uptake of Coupons Prepared from the Front and Back Ends of Zr-2.5Nb Pressure Tubes." In Zirconium in the Nuclear Industry: 16th International Symposium, 373–400. 100 Barr Harbor Drive, PO Box C700, West Conshohocken, PA 19428-2959: ASTM International, 2010. http://dx.doi.org/10.1520/stp49366s.

Full text
APA, Harvard, Vancouver, ISO, and other styles

Conference papers on the topic "High Pressure High Temperature Corrosion"

1

Papavinasam, S., and R. W. Revie. "High-Temperature, High-Pressure Rotating Electrode System." In 1998 2nd International Pipeline Conference. American Society of Mechanical Engineers, 1998. http://dx.doi.org/10.1115/ipc1998-2041.

Full text
Abstract:
Corrosion in high pressure vessels, such as pipelines, furnaces, and steam generators, is influenced by composition (material and atmosphere), pressure, temperature and flow. To simulate the corrosion conditions in high pressure vessels, a simple system is necessary to control the parameters and measure instantaneous corrosion rates. This paper describes a simple, compact, and relatively inexpensive high-temperature, high-pressure rotating electrode (HTHPRE) system that can be used to control simultaneously pressure, temperature, and flow, and to measure instantaneous corrosion rates using electrochemical techniques. It can be used with corrosive gases, such as H2S and CO2.
APA, Harvard, Vancouver, ISO, and other styles
2

Kimura, M., T. Tamari, Y. Yamazaki, K. Sakata, R. Mochizuki, and H. Sato. "Development of New 15Cr Stainless Steel OCTG With Superior Corrosion Resistance." In SPE High Pressure/High Temperature Sour Well Design Applied Technology Workshop. Society of Petroleum Engineers, 2005. http://dx.doi.org/10.2118/98074-ms.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Piccolo, Eugenio Lo, Lucrezia Scoppio, Perry Ian Nice, and Stale Nodland. "Corrosion and Environmental Cracking Evaluation of High Density Brines for Use in HPHT Fields." In SPE High Pressure/High Temperature Sour Well Design Applied Technology Workshop. Society of Petroleum Engineers, 2005. http://dx.doi.org/10.2118/97593-ms.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Saleem, M. A., A. A. Hulaibi, and R. J. Carswell. "New Corrosion Mapping Technology at High Temperature Application." In ASME 2007 Pressure Vessels and Piping Conference. ASMEDC, 2007. http://dx.doi.org/10.1115/pvp2007-26177.

Full text
Abstract:
Process industries such as oil, gas and petrochemical plants have critical process equipment operating at high temperatures. These equipment require periodic comprehensive integrity assessments for safe and reliable operation. Conventional NDE techniques such as manual ultrasonic are not only slow and subjective, but also often unsuccessful beyond 300°F (150°C). There have been tremendous efforts in the industry to invent suitable new technologies for high temperature application. Hence, comprehensive monitoring of large size equipment operating at higher temperatures remained as a challenging task for decades. In line with this requirement, and in an ongoing effort to deploy new technologies, Uthmaniyah Gas Plant (UGP) in Saudi Aramco, one of the largest gas processing plants in the world, partnered with the Inspection Department in a pilot test program to validate a new corrosion mapping technology at high temperature application up to 500°F. Implementation of this breakthrough technology for the first time in Saudi Aramco at UGP has been successful. This technology also has the capability to scan the process equipment at an operating temperature beyond 725°F (385°C). This paper provides an overview of the importance of a comprehensive assessment to critical process equipment operating at high temperature, ongoing developments to enrich the assessment capabilities and how this technology added value in enhancing the safety and reliability of the operating facility.
APA, Harvard, Vancouver, ISO, and other styles
5

Jiang, Ke, Xuedong Chen, Tiecheng Yang, and Zongchuan Qin. "Experiment Study of High-Temperature and High-Flow Rate Naphthenic Acid Corrosion." In ASME 2011 Pressure Vessels and Piping Conference. ASMEDC, 2011. http://dx.doi.org/10.1115/pvp2011-57640.

Full text
Abstract:
The corrosion behaviors of 321 and 316L austenitic stainless steel in high-temperature and high-flow rate naphthenic acid medium were investigated by pipe-flow and jet-impingement method. The influence of temperature and erosion angle on naphthenic acid corrosion resistance for stainless steel was analyzed. The results indicate that the naphthenic acid corrosion rate increased with increasing temperature and velocity. At the same temperature, the corrosion rate at 90° erosion angle is greater than that at 0°. The present experimental results are very close to those in API 581. Simulation results indicate that, where the mutation of flow direction occurs around the specimen, the near-wall turbulence intensities are very large by both experimental methods. Moreover, by comparing both the simulation and experimental results, it can be found that the naphthenic acid corrosion is very severe in areas of high turbulence.
APA, Harvard, Vancouver, ISO, and other styles
6

Kassim, Khairan Syuhada. "Corrosion Resistant Alloy Pipeline Installation for High Pressure High Temperature Requirement." In Abu Dhabi International Petroleum Exhibition & Conference. Society of Petroleum Engineers, 2019. http://dx.doi.org/10.2118/197246-ms.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Ramachandran, Sunder, Ghaithan A. Al-Muntasheri, Hasan Al-Ajwad, Anuj Gupta, Jairo Leal, and Vladimir Jovancicevic. "Engineering Corrosion Protection in High Temperature High Pressure Sour Gas Wells." In Abu Dhabi International Petroleum Exhibition and Conference. Society of Petroleum Engineers, 2015. http://dx.doi.org/10.2118/177882-ms.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Ye, Yufeng, and Li Xia. "Experimental Research on High-Temperature Pipe Corrosion On-Line Monitoring." In ASME 2012 Pressure Vessels and Piping Conference. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/pvp2012-78325.

Full text
Abstract:
Nowadays, Ultrasound guided wave has adapted to the monitoring corrosion of pipeline at room temperature, but not worked well at high temperature. This paper introduced the basic theory of guided wave on high temperature on-line monitoring; based on some research on the test pipeline, we researched the technology of high temperature on-line monitoring, and made use of the technology on 7 high temperature pipes in Catalytic Cracking Unit to obtain the monitoring the corrosion of high temperature pipeline based on the magnetostrictive effect of guided wave technology by taking one of them as an example to monitor its corrosion and analysis the data.
APA, Harvard, Vancouver, ISO, and other styles
9

Barua, B., M. C. Messner, R. I. Jetter, and T. L. Sham. "Development of Design Method for High Temperature Nuclear Reactor Cladded Components." In ASME 2020 Pressure Vessels & Piping Conference. American Society of Mechanical Engineers, 2020. http://dx.doi.org/10.1115/pvp2020-21469.

Full text
Abstract:
Abstract High temperature nuclear reactors plan to use highly corrosive coolant such as molten salts, molten lead, and lead-bismuth eutectic mixtures. The existing Class A metallic materials qualified in the ASME Section III, Division 5 rules for high temperature nuclear reactors are not ideal for resisting corrosion when exposed to these coolants. One option to overcome this limitation would be to Code-qualify new corrosion-resistant materials for Class A service, however this process is long and expensive and requires long-term creep test data. A near-term alternative would be to allow designers to clad the existing Class A base materials with non-qualified corrosion-resistant materials. However, there are currently no ASME design rules for cladded components to guard against creepfatigue failure and ratcheting strain accumulation in elevated temperature nuclear service. This work addresses this deficiency by proposing a design strategy for cladded components that does not require long-term testing of clad materials. The proposed approach relies on approximate design analysis methods for two types of clad materials — soft clad that creeps faster than the base material and hard clad that creeps slower and has higher yield stress than the base material. The proposed approach treats a soft clad material as perfectly compliant and a hard clad material as linear elastic. Sample finite element analyses of representative high temperature reactor components are performed to verify the approach. At the end, a complete set of design rules is provided for each of the two types of cladded components.
APA, Harvard, Vancouver, ISO, and other styles
10

Rebak, Raul B. "Resistance of Ferritic Steels to Stress Corrosion Cracking in High Temperature Water." In ASME 2013 Pressure Vessels and Piping Conference. American Society of Mechanical Engineers, 2013. http://dx.doi.org/10.1115/pvp2013-97352.

Full text
Abstract:
Austenitic stainless steels such as type 304 and 316 are susceptible to stress corrosion cracking in high temperature water environments typical of boiling water reactors (BWR) and pressurized water reactors (PWR). The accumulation over time of irradiation dose on the austenitic materials increases further their susceptibility to environmental cracking. Ferritic steels containing chromium are less susceptible to irradiation damage such as void swelling. Ferritic steels also offer desirable higher thermal conductivity and lower thermal expansion coefficient. Little is known however about the stress corrosion cracking behavior of ferritic steels in high temperature water. Crack propagation rate studies were conducted using four types of wrought and welded ferritic steels (5 to 17% Cr) in high purity water at 288°C containing dissolved oxygen or dissolved hydrogen. Results show that the ferritic steels are notably more resistant to environmental assisted cracking than the austenitic materials.
APA, Harvard, Vancouver, ISO, and other styles

Reports on the topic "High Pressure High Temperature Corrosion"

1

Jones, R. H., C. H. Jr Henager, and C. F. Jr Windisch. High temperature corrosion and crack growth of SiC/SiC at variable oxygen partial pressures. Office of Scientific and Technical Information (OSTI), June 1994. http://dx.doi.org/10.2172/10182469.

Full text
APA, Harvard, Vancouver, ISO, and other styles
2

John P. Hurley and John P. Kay. CORROSION OF HIGH-TEMPERATURE ALLOYS. Office of Scientific and Technical Information (OSTI), October 1999. http://dx.doi.org/10.2172/824979.

Full text
APA, Harvard, Vancouver, ISO, and other styles
3

Michael L. Swanson. Advanced High-Temperature, High-Pressure Transport Reactor Gasification. Office of Scientific and Technical Information (OSTI), August 2005. http://dx.doi.org/10.2172/896313.

Full text
APA, Harvard, Vancouver, ISO, and other styles
4

Michael Swanson and Daniel Laudal. Advanced High-Temperature, High-Pressure Transport Reactor Gasification. Office of Scientific and Technical Information (OSTI), March 2008. http://dx.doi.org/10.2172/965112.

Full text
APA, Harvard, Vancouver, ISO, and other styles
5

Calo, J. M., and E. M. Suuberg. High pressure/high temperature thermogravimetric apparatus. Final report. Office of Scientific and Technical Information (OSTI), December 1999. http://dx.doi.org/10.2172/765239.

Full text
APA, Harvard, Vancouver, ISO, and other styles
6

Sienicki, James J., Qiuping Lv, and Anton Moisseytsev. High Efficiency Heat Exchanger for High Temperature and High Pressure Applications. Office of Scientific and Technical Information (OSTI), September 2017. http://dx.doi.org/10.2172/1404925.

Full text
APA, Harvard, Vancouver, ISO, and other styles
7

Zdenek, Jeffrey S., and Ralph A. Anthenien. Ion Based High-Temperature Pressure Sensor. Fort Belvoir, VA: Defense Technical Information Center, January 2004. http://dx.doi.org/10.21236/ada453070.

Full text
APA, Harvard, Vancouver, ISO, and other styles
8

Selman, J. R., B. Aladjov, and B. Chen. Corrosion-resistant coatings for high-temperature high-sulfur- activity applications. Office of Scientific and Technical Information (OSTI), January 1992. http://dx.doi.org/10.2172/7243769.

Full text
APA, Harvard, Vancouver, ISO, and other styles
9

McNallan, M., S. Danyluk, and J. E. Indacochea. High temperature corrosion during use of chlorine. Office of Scientific and Technical Information (OSTI), January 1992. http://dx.doi.org/10.2172/6970166.

Full text
APA, Harvard, Vancouver, ISO, and other styles
10

Timothy F. Price. Development of a High-Pressure/High-Temperature Downhole Turbine Generator. Office of Scientific and Technical Information (OSTI), February 2007. http://dx.doi.org/10.2172/903397.

Full text
APA, Harvard, Vancouver, ISO, and other styles
You might also be interested in the extended bibliographies on the topic 'High Pressure High Temperature Corrosion' for particular source types:
Journal articles Dissertations / Theses Books
We offer discounts on all premium plans for authors whose works are included in thematic literature selections. Contact us to get a unique promo code!

To the bibliography