Analysis of service stress corrosion cracking in a natural gas transmission pipeline, active or dormant?

2004 ◽  
Vol 11 (1) ◽  
pp. 3-18 ◽  
Author(s):  
J Wang ◽  
A Atrens
Keyword(s):  
Natural Gas ◽  
Stress Corrosion ◽  
Stress Corrosion Cracking ◽  
Corrosion Cracking ◽  
Natural Gas Transmission ◽  
Transmission Pipeline

Validation of EMAT ILI for Management of Stress Corrosion Cracking in Natural Gas Pipelines

2014 ◽  
Author(s):  
Toby Fore ◽  
Stefan Klein ◽  
Chris Yoxall ◽  
Stan Cone
Keyword(s):  
High Resolution ◽  
Natural Gas ◽  
Stress Corrosion ◽  
Stress Corrosion Cracking ◽  
Corrosion Cracking ◽  
Probability Of Detection ◽  
Gas Pipelines ◽  
Line Pipe ◽  
Natural Gas Pipelines ◽  
Electro Magnetic

Managing the threat of Stress Corrosion Cracking (SCC) in natural gas pipelines continues to be an area of focus for many operating companies with potentially susceptible pipelines. This paper describes the validation process of the high-resolution Electro-Magnetic Acoustical Transducer (EMAT) In-Line Inspection (ILI) technology for detection of SCC prior to scheduled pressure tests of inspected line pipe valve sections. The validation of the EMAT technology covered the application of high-resolution EMAT ILI and determining the Probability Of Detection (POD) and Identification (POI). The ILI verification process is in accordance to a API 1163 Level 3 validation. It is described in detail for 30″ and 36″ pipeline segments. Both segments are known to have an SCC history. Correlation of EMAT ILI calls to manual non-destructive measurements and destructively tested SCC samples lead to a comprehensive understanding of the capabilities of the EMAT technology and the associated process for managing the SCC threat. Based on the data gathered, the dimensional tool tolerances in terms of length and depth are derived.

Pipeline Failures Resulting From Interacting Integrity Threats

2016 ◽  
Author(s):  
Gregory T. Quickel ◽  
John A. Beavers
Keyword(s):  
Natural Gas ◽  
Hydrogen Embrittlement ◽  
Stress Corrosion ◽  
Corrosion Fatigue ◽  
Stress Corrosion Cracking ◽  
Corrosion Cracking ◽  
Time Dependent ◽  
Internal Corrosion ◽  
Pipeline Failures ◽  
Fatigue Corrosion

All pipelines contain manufacturing and construction anomalies that typically are stable with time and are not generally considered to be integrity threats. These include laminations, seam weld anomalies, girth weld anomalies, and shallow dents. There also are time-dependent integrity threats to buried natural gas and petroleum pipelines. These include external and internal corrosion, fatigue, corrosion fatigue, stress corrosion cracking (SCC), and hydrogen embrittlement. Unexpected failures can occur when the time dependent integrity threats are coupled with these stable anomalies. This paper describes several of these interactions.

scholarly journals Detection and Verification of SCC in a Gas Transmission Pipeline

2000 ◽  
Author(s):  
B. Ashworth ◽  
Neb Uzelac ◽  
H. Willems ◽  
O. A. Barbian
Keyword(s):  
Stress Corrosion ◽  
Wall Thickness ◽  
Stress Corrosion Cracking ◽  
Confidence Level ◽  
Crack Detection ◽  
Corrosion Cracking ◽  
Inspection Method ◽  
Transmission Pipeline ◽  
History Of ◽  
Location Type

Two sections of a 914mm OD (36 in.) TransCanada (TCPL) gas transmission pipeline (predominantly with 9.14 mm wall thickness) were inspected using an ultrasonic liquid coupled crack detection In-Line Inspection (ILI) tool. One of the objectives of the inspection was to establish the condition of the pipeline sections with a known history of stress-corrosion cracking (SCC). Under test was the practicability of inspecting a gas line using a liquid coupled ILI tool, specifically its ability to detect and size defects deeper than 1 mm and distinguish cracks and crack-like defects from other types of anomalies, such as inclusions and laminations. In order to assess the confidence level of the tool, both sections were inspected in two independent runs and the repeatability of inspection was assessed. Cracks and crack-like defects with depths greater than 12.5% of the wall thickness from both runs were compared and correlation was established to assess repeatability. The accuracy of tool predictions was verified in excavations in both sections. 40 reported features, varying in depths up to over 40% were examined with respect to location, type, and size. Examples of defect patterns are shown to demonstrate the accuracy of the inspection method.

Study of the Susceptibility of API 5L X80 Girth Welds to Sulfide Stress Corrosion Cracking and Hydrogen Embrittlement

2010 ◽  
Author(s):  
Adriana Forero Ballesteros ◽  
Jose´ A. da Cunha Ponciano ◽  
Ivani de S. Bott
Keyword(s):  
Hydrogen Embrittlement ◽  
Stress Corrosion ◽  
Stress Corrosion Cracking ◽  
Oil And Gas ◽  
Hydrogen Permeation ◽  
Sodium Thiosulfate ◽  
Corrosion Cracking ◽  
Transmission Pipeline ◽  
Girth Welds ◽  
Almost All

The growing demand for natural gas and oil, as energy sources, has driven industry’s need for ever-increasing strength levels in oil and gas transmission pipeline materials in order to achieve safe and economic transportation. The current world trend points to the use of pipes with larger diameters and thinner wall thicknesses, operating under high pressure. In addition, pipeline steels for sour service must exhibit good Hydrogen Induced Cracking (HIC) and Sulphide Stress Corrosion Cracking (SSCC) resistance. This study evaluates the susceptibility of API 5L-X80 girth welds to SSCC and Hydrogen Embrittlement (HE). Slow strain rate tensile (SSRT) tests and Hydrogen Permeation tests were performed at room temperature, in different acidic environment containing sodium thiosulfate solutions. Most of the SSRT tests undertaken in solution, showed a loss of ductility and a decrease in the reduction of area, as compared with tests conducted in air. The susceptibility to HE and potentially SSCC was evidenced by a reduction in ductility in the SSRT tests and an increase in the hydrogen permeation current values, for almost all welded joints. This was observed with greater intensity for the more acidic test solutions (pH = 3.4), while for the less acidic test solutions (pH = 4.4) little loss of ductility was observed and the hydrogen permeation current remained at values close to zero, indicating little or no permeation of hydrogen through the metal for the testing times applied. The behaviour exhibited by the samples tested in the more acidic solutions was attributed to the dissolution of material from the sample together with hydrogen embrittlement. These results confirmed that the use of sodium thiosulfate solutions to generate H2S, permits the study of phenomena related to SCC in environments containing sulphides.

Stress Corrosion Cracking “Like-in-Kind” Reliability Approach for Pipelines Without Crack Tool In-Line Inspection

2020 ◽  
Author(s):  
Amal Elsisi ◽  
Winston Y. W. Lee ◽  
Pushpendra Tomar ◽  
Dan Williams
Keyword(s):  
Stress Corrosion ◽  
Stress Corrosion Cracking ◽  
Direct Limit ◽  
Limit State ◽  
Corrosion Cracking ◽  
Pipeline System ◽  
Acoustic Transducer ◽  
Threat Level ◽  
Transmission Pipeline ◽  
Electro Magnetic

Abstract Gas transmission pipeline operators increasingly rely on Electro-Magnetic Acoustic Transducer (EMAT) technology to reliably detect, identify and size stress corrosion cracking (SCC) anomalies in their pipeline system. However, scheduling EMAT in-line inspection (ILI) on every pipeline in the system is not always practicable or achievable in an expeditious manner. A means of conducting a preliminary assessment of the SCC threat on pipelines without EMAT ILI data in an objective and quantifiable manner is useful for understanding the threat level and for prioritizing or deciding on outstanding EMAT inspections. A wealth of system-specific SCC field data from historical integrity excavations across the pipeline system typically exists in a pipeline operator’s dataset and can be readily leveraged for quantitatively estimating the SCC threat reliability in other, similar (“like-in-kind”) parts of the pipeline system. This system-specific data, based on actual SCC findings from integrity excavations, is an improved and more granular alternative to applying industry-wide SCC statistics to estimates of SCC reliability levels on pipelines without EMAT ILI data. This paper presents a robust and direct limit state approach for estimating the SCC reliability level in pipelines that have not yet had an EMAT ILI completed by leveraging system-wide SCC field findings from historical integrity excavations.

Self Excited Eddy Currents for the Detection of SCC

2008 ◽  
Author(s):  
Grant A. Coleman
Keyword(s):  
Natural Gas ◽  
Stress Corrosion ◽  
Stress Corrosion Cracking ◽  
Eddy Currents ◽  
Basic Design ◽  
Proof Of Concept ◽  
Pipe Axis ◽  
Natural Gas Transmission ◽  
Novel Method ◽  
As Stress

Self Excited Eddy Currents (SEEC) present a unique and novel method for internal inspection of natural gas transmission pipelines for the presence of features aligned with the main pipe axis such as Stress Corrosion Cracking (SCC). This paper outlines the theory, methodology and basic design principles of building a SEEC based tool. Results from initial proof of concept testing are presented.

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