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Corrosion of Cr-Alloyed Steels in Supercritical CO2-Saturated Brine Water

Product Number: 51324-20809-SG

Author: Alexander Gross; Haofei Sun; Jing Liu

Publication Date: 2024

$40.00

In the context of urgent efforts to reduce global carbon emissions, carbon capture, utilization, and storage (CCUS) has gained prominence. Tubing and casing steels are vital materials of construction (MOC) in CCUS systems, especially in supercritical CO2 (s-CO2) environments. However, the understanding of the corrosion behavior of these steels under s-CO2 conditions is limited, which presents integrity challenges. Immersion experiments were conducted with steels containing varying chromium (Cr) levels (0.5 wt% to 16.5 wt%), including P110, P91, and SS 316. These steels were exposed to s-CO2-saturated brine water (3.5 wt% NaCl) at 50 °C and 10 MPa for durations of 10 and 100 hours. Corrosion rates were determined via weight loss measurements, and corrosion products were analyzed with SEM and XRD. P110 displayed the highest corrosion rates (15.7 mm/y at 10 hours, 2.9 mm/y at 100 hours) but developed a thick FeCO3 layer after 100 hours. In contrast, P91 and SS 316 exhibited lower corrosion rates after 100 hours (0.04 mm/y and < 0.01 mm/y, respectively). The influence of Cr content and exposure duration on the corrosion behavior of these steels were discussed. All steels exhibited decreasing corrosion rates over time, primarily due to oxide formation, enhancing the understanding of casing and tubing steel corrosion in s-CO2 environments.

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Role Of Acetic Acid On The Kinetics And Mechanism Of Carbon Steel Dissolution Under CO2 Top Of Line Corrosion

Product Number: 51322-17818-SG

Author: Mariana Costa Folena, José Antônio da Cunha Ponciano Gomes, Frederick Pessu, Anne Neville, Richard Barker

Publication Date: 2022

$20.00

Top of line corrosion (TLC) is a specific corrosion mechanism observed in the oil and gas industry. This phenomena occurs under stratified or wet-gas flow regimes when the upper internal pipeline walls are sufficiently cooled (by heat transfer to the surrounding outer environment), promoting local condensation of water vapor. Carbon dioxide (CO₂) and organic acids dissolving into the condensed water generate a change in the solution chemistry, ultimately influencing the corrosion kinetics of the contacting carbon steel.

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04257 Control of Corrosion and Service Life

Product Number: 51300-04257-SG

ISBN: 04257 2004 CP

Author: Vinod S. Agarwala, Naval Air Systems Command

Publication Date: 2004

$20.00

Service life of any weapon system depends upon factors that impart long-term durability and robustness to its structure and subsystems, while sustaining its functional properties. The paper describes basic principles and guidelines on corrosion control and rules that could be easily followed to ascertain some specified service life and reduce total ownership costs.

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51318-11386-Study on the Corrosion Performance of C110 Tubing in Formate Completion Fluid at High Temperature

Product Number: 51318-11386-SG

Author: Dapeng Li / Lei Zhang / Xiuyun Wang / Zhiwen Yang / Xiaoqi Yue / Minxu Lu

Publication Date: 2018

$20.00

In this paper, the corrosion performance of C110 tubing is investigated in high-density formate completion fluid at 180 oC with different combinations of CO2 mixed and mechanical damage.

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Corrosion and Risk Modelling Analytics

Product Number: 51324-20833-SG

Author: B. R. Shivadhanush; N. J. Laycock; M. Geeta; F. Samie; P. Panchami

Publication Date: 2024

$40.00

The CARMA (Corrosion and Risk Modelling Analytics) project aims to provide improved corrosion prediction capability by using Machine Learning techniques. For the selected system, the initial CARMA model is trained by using a combination of online process monitoring data as the input, combined with online corrosion monitoring data as the output. Once trained and validated, the resulting model can then be used to predict corrosion rates in similar systems or in other parts of the same system, without the need to install corrosion monitoring devices or carry out routine physical inspections at the same frequency as in the past. This paper provides an overview of the model development process for one example system, incorporating data from both online monitoring in the plant and from laboratory experiments.

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04264 Cost and Other Benefits of Vapor Corrosion Inhibitors (VCI) Compared to Legacy Packaging Methods That Prevail in Military Applications

Product Number: 51300-04264-SG

ISBN: 04264 2004 CP

Author: James Henderson and Ronnie Singh, Northern Technologies International Corrosion

$20.00

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Initiation Sites of Pitting Corrosion in the Nickel Alloy UNS N07718

Product Number: 51323-18846-SG

Author: Julia Botinha, Bodo Gehrmann, Helena Alves, Michael Rohwerder

Publication Date: 2023

$20.00

Being one of the most applied nickel alloy in the oil and gas industry, the UNS N07718 (Alloy 718) is mainly composed by nickel, chromium, iron, molybdenum, niobium, titanium and aluminum. UNS N07718 is used in the solution annealed and precipitation hardened condition, where a complex microstructure is formed, which is responsible for its very good mechanical properties, as well as its cracking and corrosion resistance.

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Concrete Reinforcing Steel Corrosion Assessment, Re-passivation and Monitoring in an Industrial Environment

Product Number: 41211-594-SG

Author: Bruce A. Collins

Publication Date: 2011

$20.00

Four separate concrete cooling towers at a coal fired electrical generation plant exhibited reinforcing steel corrosion causing concrete deterioration. The presentation will cover investigation of the corrosion sources, determination of the corrosion control solutions, implementation of the repair construction, and review of the corrosion measurements taken to prove effectiveness of the solution.

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Independent Research on the Effectiveness of Polyethylene Encasement as a Corrosion Control Coating for Ductile Iron Water and Wastewater Piping

Product Number: 51324-20943-SG

Author: Michael J. Szeliga

Publication Date: 2024

$40.00

Polyethylene encasement (PE) is a coating method that consists of a loose wrap of thin plastic around ductile iron piping (DIP), that is typically held in place with PVC tape. It has become the primary means of corrosion control on DIP water and wastewater piping even though no large scale independent studies have been performed to document how often the thin plastic is damaged. Damage to the PE exposes the DIP to direct soil contact and corrosion can occur. The frequency of these exposed anodic (corroding) areas on polyethylene encased DIP has also never been compared to the frequency of anodic areas on uncoated DIP. Uncoated DIP is DIP that that has the 2 to 3 mils thick factory applied black asphaltic paint applied to it. The asphaltic paint is water permeable and provides no significant reduction in corrosion activity on DIP. This research project evaluated cell-to-cell potential data on 89,275 feet of uncoated DIP and 51,609 feet of polyethylene encased DIP. Cell-to-cell potential measurements are the only way to accurately detect areas of corrosion on unbonded DIP.

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51318-11170-Unification of monopile corrosion protection - collaboration in partnerships

Product Number: 51318-11170-SG

Author: Trine Nybo Lomholt / Troels Mathiesen / Sune Egelund / Ditte Bilgrav Bangsgaard

Publication Date: 2018

$20.00

The current paper presents examples of ongoing joint industry projects, of which the authors of this paper take part in one way or another.

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51318-11199-The Effect of Impurities and Pressure on Oxidation in CO2 at 700°-800°C

Product Number: 51318-11199-SG

Author: B. A. Pint / R. G. Brese / J. R. Keiser

Publication Date: 2018

$20.00

Effects of H2O and SO2 on oxidation in a CO2 environment. Experiments at 1 and 25 bar at 700° to 800°C in CO2, CO2+10%H2O and CO2+10%H2O+0.1%SO2. Alloys S30409, N07230, N07208 and superalloy N07247 exposed. Reaction products were characterized.

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Performing Coating And Corrosion Assessments To Maintain Military Fuel Piping

Product Number: 51322-18027-SG

Author: Adam Beers

Publication Date: 2022

$20.00

In any military base, there are numerous assets that need to be maintained. These assets can easily be traced from the fuel offload all the way through to the fuel dispenser. In between, this fuel travels through pipelines, into storage tanks, into pump stations, through filter separators, into fuel dispensers, and finally into either a track or non-track vehicle including jets. Therefore, it is extremely important to develop a system to inventory all assets and perform condition assessments on each to prevent degradation, corrosion, possible section loss of the metallic substrate, and loss of the liquid fuel. This paper will highlight some of the assets related to the fuels pipeline and related assets.

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04758 Evaluation of an On-Line Biofilm Detector and Bio-Traps to Monitor MIC in Produced Oilfield Brine

Product Number: 51300-04758-SG

ISBN: 04758 2004 CP

Author: Gary E. Jenneman, Robert Webb, and Erin Holle, ConocoPhillips; Kerry Sublette and C. Mehta, Universi

Publication Date: 2004

$20.00

A laboratory flow loop is used to evaluate the ability of an on-line, electrochemical, biofilm-activity probe to monitor biofilm activity in synthetic oilfield brine and correlate its activity to localized pitting corrosion. In addition, bio-traps containing porous polymer beads for trapping biomass are evaluated as a rapid means to evaluate biofilm community structure.

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51318-11094-Mild steel corrosion behavior in a CO2-H2O-CHOOH environment

Product Number: 51318-11094-SG

Author: Molatelo Thebe / Werner Ernst / Deon Slabbert / Roelf Sandenbergh

Publication Date: 2018

$20.00

The corrosion behavior of mild steel in a gas reforming CO2-H2O-CHOOH environment at high temperature and pressure (210°C; 3500KPa) was studied using polarization and mass loss tests as well as online corrosion monitoring techniques

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Phosphate Esters Inhibitors in Naphthenic Acid Corrosion – An Experimental Evaluation

Product Number: 51319-13491-SG

Author: Gheorghe Bota

Publication Date: 2019

$20.00

Crude oils with a total acid number (TAN) higher than 0.5 are highly corrosive at temperatures between 400 and 700°F typical to atmospheric and vacuum distillations of oil refineries. This destructive effect of naphthenic acids (NAP) is enhanced by the presence of hydrogen sulfide generated in thermal decomposition of sulfur compounds also contained in crude oils. The efforts of mitigating the acidic crudes corrosive effects include blending such oils with crudes of lower acids content neutralization or removal of naphthenic acids from oils and the use of corrosion inhibitors. Most commonly used inhibitors for mitigating the NAP corrosion are based on organic polysulfides or on phosphate esters. Two phosphate esters corrosion inhibitors were evaluated in laboratory experiments using a specific testing procedure – “pretreatment - challenge”. This experimental method evaluates the naphthenic corrosive effects at high temperature on scales formed from crude factions on metal surfaces. Adding the inhibitors to the crude fractions improved the protective properties of scales formed under such conditions. The corrosive effect of naphthenic acid was evaluated by sample weight loss. The scales formed on these samples were investigated using scanning electron microscopy (SEM) and transmission electron microscopy (TEM) coupled with energy dispersive spectroscopy (EDS).Keywords: phosphate esters corrosion inhibitors naphthenic acids high temperature

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Utilizing Temperature and Humidity Sensors in Developing Corrosion Prevention Strategies

Product Number: 51319-13120-SG

Author: Eric Uutala

Publication Date: 2019

$20.00

Understanding environmental conditions experienced during shipping (both domestic and export) and/or storage is critical when determining the most effective corrosion control system for metal components. Temperature and humidity sensors were used to help understand the conditions within industrial packaging applications during different overseas shipping routes and during warehouse storage. The effect of secondary packaging (i.e. polyethylene film) on temperature and humidity within a package was also evaluated. The scope of this paper is to compile and analyze the data and utilizing it to help develop the best corrosion prevention strategies.Key words: Sensor corrosion control packaging overseas shipping

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51318-10801-Corrosion Management and Asset Tracking through Improved Airframe Contaminant Monitoring

Product Number: 51318-10801-SG

Author: Jeff Demo / Mark Kim

Publication Date: 2018

$20.00

A contaminant detection system has been developed to identify and track the species and concentration of corrosive airframe contaminants.

Available for download

Mitigation Of Carbon Steel MIC Using THPS Enhanced By A Biofilm Dispersing Peptide In A Flow Loop With An Oilfield Biofilm Consortium

Product Number: 51322-17560-SG

Author: Di Wang, Tuba Unsal,Mazen A. Saleh, Mohammed D. Alotaibi, Magdy E. Mohamed, Sith Kumseranee, Suchada Punpruk, Tingyue Gu

Publication Date: 2022

$20.00

MIC is a major threat to oil pipelines because it reduces the service life of pipelines and can potentially leads to catatrophes. Microbial communities commonly associated with pipeline corrosion include sulfate reducing bacteria (SRB), acid producing bacteria (APB), acetogenic bacteria and methanogens. In a field environment, SRB, APB and other microbes often live in a synergistic biofilm consortium. Sessile SRB are often the main culprit of MIC. They can utilize sulfate as the terminal electron acceptor and various carbon sources and elemental iron as electron donors. Corrosive APB biofilms are also a contributing factor in an acidic environment because they release H+ which is an oxidant.

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Clarifying Material Selection: Understanding the Corrosion Mechanisms for Wastewater Clarifier Mechanisms

Product Number: 51217-060-SG

Author: D. A. Sherman, R. A. Nixon

Publication Date: 2017

$20.00

Wastewater treatment plant clarifier environments present challenges for selecting materials of construction. Coated carbon steel, hot-dip galvanized steel, and stainless steel are most commonly specified for new or refurbished clarifier mechanisms, and all have their advantages and disadvantages with regard to achieving the intended design life.

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51318-11529-Evaluation of macrofouling crevice characteristics in MIC of steel

Product Number: 51318-11529-SG

Author: Samanbar Permeh / Bin Li / Mayren Echeverria Boan / Berrin Tansel / Kingsley Lau / Matthew Duncan

Publication Date: 2018

$20.00

Tests were conducted in simulated water environments with nutrient-rich environments with sulfate reducing bacteria (SRB). Effects of crevice environments, caused by macrofoulers on corrosion and in comparison with biotic condition, were studied.

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Corrosion Propagation of Carbon Steel Rebar Embedded in Concrete

Product Number: 51319-13564-SG

Author: Francisco Presuel-Moreno

Publication Date: 2019

$20.00

Binary and ternary concrete mixtures were prepared. Two type of specimens were prepared: single (1 cm cover) and three (1.25 cm cover) rebar specimens. Electromigration was used to accelerate chloride transport this lasted anywhere between a week to a few months. The effect of concrete cover length of the rebar under the reservoir and concrete composition was investigated. This paper present the monitoring via linear polarization resistance and galvanostatic pulse to determine the corrosion current. The solution resistance and rebar potential was monitored for over 600 days. Corrosion in some cases initiated several weeks after removing the electromigration

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51318-11628-Electrochemical sensor for monitoring microbiologically influenced corrosion

Product Number: 51318-11628-SG

Author: Xin Pang

Publication Date: 2018

$20.00

An amperometric electrochemical biosensor based on a conducting polymer and carbon nanotubes was developed for detection and monitoring of hydrogen sulfide generated by sulfate reducing bacteria, the main culprits of MIC.

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51318-10636-Oil and Gas Field Corrosion Inhibitor Performance Validation Implementation of EIS

Product Number: 51318-10636-SG

Author: J. Sonke / W.M. Bos

Publication Date: 2018

$20.00

Results, interpretation, benefits and limits of using electrochemical impedance spectroscopy (EIS). Results reveal CI protection/failure mechanisms under specific test conditions.

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97398 PERFORMANCE OF STABILIZED HALOGEN BIOCIDES IN COOLING WATER

Product Number: 51300-97398-SG

ISBN: 97398 1997 CP

Author: Anthony W. Dallmier, J. D. Martens, Wllhrn F. McCoy

$20.00

Available for download

Environmentally-Assisted Cracking (SSC And SCC) Of Martensitic Stainless Steel OCTG Material In Sour Environment In 5%Nacl And 20%Nacl Solution

Product Number: 51322-17563-SG

Author: Yuichi Kamo, Yusuke Mizuno, Yasuhide Ishiguro

Publication Date: 2022

$20.00

Martensitic stainless steels for OCTG materials are widely used in sweet and mild sour conditions. Environmentally-assisted cracking (EAC) is a major corrosion-related issue when using stainless steels as OCTG materials. The EAC in specific oil/gas well conditions with sour environments is defined as sulfide stress cracking (SSC) and stress corrosion cracking (SCC). The SSC is a type of cracking caused by hydrogen embrittlement, which is attributed to a cathodic reaction under acidic conditions, while SCC is associated with an anodic reaction. SSC testing for martensitic stainless steels for OCTG material is often carried out at or near ambient temperature under conditions simulating condensed water, and SCC tests are conducted at higher temperatures under conditions simulating formation water and/or the brine availability test.

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NACE Publication 1F 192-2013-SG, "Use of Corrosion-Resistant Alloys in Oilfield Environments"

Product Number: 24010-SG

Publication Date: 2013

$109.00

Corrosion Resistant Alloys (CRAs) and issues of welding, fabrication, and assessment in oil and gas production. Environmentally assisted cracking. Technology gaps impacting the industry.

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08280 Systemic Integration of Advanced NDE and Corrosion Monitoring for Improved Refining Reliability

Product Number: 51300-08280-SG

ISBN: 08280 2008 CP

Author: Edwin Niccolls, Axel Gallon, and Koji Yamamoto

Publication Date: 2008

$20.00

Available for download

51318-10850-Case Study: Corrosion Susceptibility of Pipelines in Trenchless Installations

Product Number: 51318-10850-SG

Author: Michael Snow / Amanda Harmon / Len Krissa / Karen Crippen

Publication Date: 2018

$20.00

Two drilling mud samples, taken at different HDD operations. Results demonstrated the presence of microorganism populations associated with microbiologically influenced corrosion (MIC) at one of the two test locations.

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Metallic Film-Coated Optical Fiber Sensor For Corrosion Monitoring At High Pressures

Product Number: 51322-17804-SG

Author: Ruishu F. Wright, Paul R. Ohodnicki, Jr, Nathan Diemler, Margaret Ziomek-Moroz, John Baltrus, Michael Buric

Publication Date: 2022

$20.00

Corrosion is a common and critical issue in the oil and natural gas industry and it adversely affects the component functionality and structural integrity of infrastructure for exploration, production, transportation, processing, and CO2 sequestration. The natural gas delivery system includes 528,000 km (328,000 miles) of transmission and gathering pipelines in U.S. According to the Pipeline and Hazardous Materials Safety Administration (PHMSA) database, corrosion has caused ~25% of the natural gas transmission and gathering pipeline incidents over the last 30 years in the U.S., and 61% out of corrosion-caused incidents were due to internal corrosion.

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Understanding the Discrepancies in Wet Bottom and Dry Bottom MASTMAASIS Testing Results of AA2060

Product Number: 51317--9171-SG

ISBN: 9171 2017 CP

Author: Mary Parker

Publication Date: 2017

$20.00

In the current study, in-situ measurements were used to deconstruct the testing environment of dry-bottom (DB) ASTM G85-A2 to provide an understanding of what makes this test successful when others are not.

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51317--9649-Corrosion Management Planning Lessons for Seawater Conveyance in Mining

Product Number: 51317--9649-SG

ISBN: 9649 2017 CP

Author: Zoe Coull

Publication Date: 2017

$20.00

This paper will present a case study, which will outline the challenges and lessons learned with corrosion in a Mine project in Chile where the internal corrosion of the seawater conveyance line caused a number of technical, project schedule and budget impacts during the commissioning stage of the project.

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51318-11195-Criteria for Protective Film Growth on Carbon Steel Rebar in a Carbonation Process

Product Number: 51318-11195-SG

Author: Yoon-Seok Choi / K. Channa R. De Silva / Xiang Yong / David Young / Srdjan Nesic

Publication Date: 2018

$20.00

This research was to determine if an iron carbonate (FeCO3) layer can be effective for prevention of CO2 corrosion of steel rebars, associated with production and use of carbonated calcium silicate cement-based concrete.

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Acceleration Of 316L Stainless Steel Corrosion By Proton-Irradiation-Induced Displacement Damage In Hydrogenated Steam

Product Number: ED22-17134-SG

Author: Rigel D. Hanbury, Jonas K. Heuer, Gary S. Was

Publication Date: 2022

$20.00

From stress corrosion cracking of baffle-former bolts to radiological hazards from Co-60, corrosion of structural materials is the root of many operational issues that occur in light water nuclear reactors. Corrosion must be controlled to mitigate the risks of larger problems that reduce the operational time and lifespan of a reactor. One fundamental feature of nuclear reactors is the radiation field which is known to impact corrosion behavior. However, there is a severe lack of understanding the underlying mechanisms of radiation effects on corrosion, especially for stainless steels. Ion irradiation experiments allow for the controlled study of radiation effects on corrosion and to compensate for the lack of reactor data on structural materials.

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02193 Corrosion Performance of AI 2519 in Marine Environments

Product Number: 51300-02193-SG

ISBN: 02193 2002 CP

Author: Richard A. Hays, Edward B. Bieberich, and Andrew D. Sheetz

Publication Date: 2002

$20.00

Structural, ballistic, and mobility requirements have led to the selection of aluminum alloy 2519 as the primary structural material for the Advanced Amphibious Assault Vehicle (AAAV). Two-year seawater alternate immersion exposures of welded AI 2519 panels with and without protective coatings were conducted to simulate the expected AAAV service environment.

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Data-Driven Machine Learning Techniques Case Study for Corrosion Depth Prediction in Facilities Station Piping

Product Number: 51323-18927-SG

Author: Kane Kaiqi Cheng, Michael Snow

Publication Date: 2023

$20.00

The pipeline industry has widely used integrity principles to manage time-dependent and time-independent threats. The detection of time-dependent threats such as corrosion has been accomplished by using inline inspection tool technologies such as ultrasonic and magnetic flux leak inspection tools. However, most facility piping assets can not easily be inspected using in-line inspection methods and must instead be assessed using data collected from operations, such as flow frequency, product type, Cathodic protection record, or Direct Assessment Methods using Non Destructive Testing such as ultrasonic measurements or monitoring of corrosion coupons.

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TM-02-74-HD1974-SG, Dynamic Corrosion Testing of Metals in High Temperature Water-HD1974

Product Number: TM-02-74-HD1974

Author: NACE International

Publication Date: 1974

$179.00

A pilot plant method for determining the extent and rate of uniform corrosion of metals in circulating water or aqueous solutions at temperatures greater than 100 C° (212° F) but less than approximately 360° C (680° F). Historical Document 1974

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On the Pitting Corrosion Resistance of Metallic Materials Used in Drilling and Reservoir Characterization Applications

Product Number: 51324-20872-SG

Author: Helmuth Sarmiento Klapper; Julia Ditmann; Sebastian Jesse

Publication Date: 2024

$40.00

Because of their versatility CrMn-stainless steels have become the most used structural materials in directional and while-drilling reservoir characterization tools. Nevertheless, pitting and environmentally assisted cracking (EAC) are a major concern when these materials are subjected to high halide-containing water-based drilling fluids at elevated temperatures. Consequently, pitting corrosion resistance becomes a crucial property to guarantee operational reliability and integrity of drilling equipment. Indeed, nickel-stabilized austenitic stainless steels and super austenitic stainless steels with higher contents of chromium and molybdenum have been recently developed as alternatives in drilling operations involving harsh environments. In this study, the pitting and repassivation behavior of several grades used in drilling technology was investigated using electrochemical methods. The tests were conducted in brines with different pH-values at temperatures ranging from ambient temperature to 150 °C. Experimental results are compared to PREN-Mod and CPT-values as well as to results from ASTM G48 Method A. The experimental data provided in this paper demonstrates the lack of correlation between the real pitting resistance of most grades commonly used in drilling equipment in brines at elevated temperatures and the commonly used PREN-Mod values. In addition, the limited applicability of results from standardized test methodologies for predicting pitting susceptibility in service is confirmed. The discussed electrochemical results provide on the other hand a more suitable basis for defining criteria regarding materials selection in drilling technology.

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NACE TR31215-2024, Laboratory Evaluation of Corrosion Inhibitors Used in the Oil and Gas Industry

Product Number: NACE TR31215-2024

Publication Date: 2024

$109.00

This technical report presents basic information on laboratory evaluation of corrosion inhibitors used in the oil and gas industry. It includes 18 inhibitor properties that are evaluated before inhibitors are used in the field and refers to various standards available to evaluate those properties.

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51318-11163-Evaluation of Corrosion of Austenitic Steels and Comparison with Martensitic Stainless Steel 17-4

Product Number: 51318-11163-SG

Author: Tatiana R. Ayers, Manuel P. Marya, Dean Lauppe

Publication Date: 2018

$20.00

A series of NACE TM0177 Tensile Test Method A tests were conducted on various commercially available chromium-manganese austenitic stainless steels as well as 17-4PH in the 110ksi-to-130ksi yield strength range (34 - 35 HRC max).

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51318-10629-The Development of Corrosion Monitoring Techniques for Maintenance Management in Petrochemical Plant

Product Number: 51318-10629-SG

Author: Takao Ohtsu / Masazumi Miyazawa

Publication Date: 2018

$20.00

A developed monitoring approach confirmed that the EN-based electrochemical surveillance can detect changes in a petrochemical plant that otherwise could lead to catastrophic failure.

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01374 CORRELATION OF OXIDATION, CARBURIZATION AND METAL DUSTING; "CONTROLLING CORROSION BY CORROSION"

Product Number: 51300-01374-SG

ISBN: 01374 2001 CP

Author: R. Kirchheiner, J. L. Jimenez Soler

$20.00

Available for download

51313-02442-Evaluation of Corr. Characteristics of Al Alloys in Bioethanol Blended Fuel Using 2-Electrode EIS

Product Number: 51313-02449-SG

ISBN: 02449 2013 CP

Author: In Jun Park

Publication Date: 2013

$20.00

Available for download

51317--9711-Review of Recent Developments in Induced AC Current Corrosion Mitigation Design Materials Installation and Monitoring Technologies

Product Number: 51317--9711-SG

ISBN: 9711 2017 CP

Author: Todd Sirola

Publication Date: 2017

$20.00

The issue of induced AC current corrosion and its mitigation for buried pipelines continues. A review of the design methods and mitigation technologies used in the past, and those recently developed and continue to evolve, to meet the AC mitigation challenges faced by buried pipeline operators.

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SP0187-2017-SG (formerly RP0187), Design for Corrosion Control of Reinforcing Steel in Concrete.

Product Number: 21034-SG

ISBN: 1-57590-012-2

Publication Date: 2017

$109.00

Corrosion control methods for structures made of steel-reinforced portland cement concrete. Causes of corrosion of the reinforcing steel and control methods.

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A Comparative Study between Corrosion in Sour Environments Generated by Na2S.9H2O Salt and H2S Gas

Product Number: 51324-20762-SG

Author: Hunter Thomson; Scott Fairley; Caroline Simpson; Dario M. Frigo; Gordon Graham

Publication Date: 2024

$40.00

Corrosion tests in laboratories to investigate the corrosion rate and to qualify production chemicals are only valid and applicable if the conditions and chemical environment (pressure, temperature, wall shear, pH, CO2 and H2S partial pressures, electrolyte composition) are representative of the field conditions. Representative sulfide concentrations are sometimes achieved by adding a sulfide salt (e.g., Na2S.9H2O) to minimize health and safety risks associated with the direct use of H2S gas. The current study compares the corrosion of carbon steel in nominally comparable sour conditions generated either using H2S gas or sodium sulfide salt. Tests were performed at 90 °C/101.3 kPa and at 120 °C/20 MPa using H2S partial pressures (pH2S) of 0.1 kPa (0.1 mol% H2S at 1.013 bar), 0.2 kPa (0.2 mol% at 1.013 bar) and 40 kPa (0.2 mol% at 200 bar). The corrosion rate was monitored by linear polarization resistance at ambient pressure and by weight loss measurement at higher pressure. Surface morphology of the coupons was assessed by optical microscopy, scanning electron microscopy (SEM) and energy dispersive X-ray spectroscopy (EDX). Ambient pressure linear polarization resistance (LPR) measurements with low H2S partial pressures showed comparable corrosion rates obtained using either H2S gas or sodium sulfide. In contrast, in the tests at higher pressure, significantly lower corrosion rates were measured when using H2S gas than with sodium sulfide. Moreover, microscopy showed pitting when sulfide was introduced as the salt, but pitting was absent when the sour environment was generated by H2S gas. Supportive work on other systems has shown that small changes in in situ conditions, particularly at elevated pressure (high H2S partial pressure), have a significant impact on the recorded corrosion rates, and therefore the ability to accurately match the environment within the test cell between generating the in situ sulfide via salt addition versus H2S gas is likely to be the root cause. In summary, therefore at high H2S partial pressure, particularly where the corrosion becomes dominated by sour corrosion, such issues related to the test methodology, and the ability to achieve representative in situ conditions, may lead to disqualification of corrosion inhibitor candidates that otherwise could have achieved the pass criteria were testing performed using H2S gas.

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Enabling Carbon Steel With A Special scCO2 Corrosion Inhibitor – A Field Study

Product Number: 51322-18205-SG

Author: Tracey Jackson, Peng Jin, Jamie Wood, Johnathon Brooks

Publication Date: 2022

$20.00

In recent years the oil and gas industry has made significant commitments to carbon reduction.¹ Aligned with the goal of decreasing carbon emissions the authors have developed a corrosion inhibitor (CI-1) that is intended to protect scCO₂ systems that are wet or water contaminated (1000 ppm).² The development and composition of this corrosion inhibitor (CI) for dry scCO₂ is reported elsewhere.^2,3 While chemical companies have been treating high water cut, production enhanced, CO₂ floods (i.e. enhanced oil recovery [EOR]) for several decades there were no inhibitors designed specifically for CO₂ disposal systems or wet scCO₂ systems producing CO2 for sale.⁴

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51318-11059- Review of a UNS N04400 Heat Exchanger Tube Failure in Cooling Water Service

Product Number: 51318-11059-SG

Author: Mel Esmacher / Kumar Kembaiyan / Tony Navarrete / Andrew Rentsch

Publication Date: 2018

$20.00

A polyethylene unit experienced a gas leak within a high pressure tube and shell heat exchanger. Failure analysis revealed that the tube wall loss was beneath residual deposits. Preventative measures and improvements in inspection & cleaning procedures are discussed.

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51318-10487-Evaluation of Coating Systems to Address Pitting Corrosion of 316 Stainless Steel for Offshore

Product Number: 51318-10487-SG

Author: Thu Tran Addis

Publication Date: 2018

$20.00

This study was to 1) develop a protocol to test coating performance on pitted stainless steel 2) compare performance of protective coating systems 3) determine application procedure.

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