AMPP Store - Products tagged with 'fracture toughness'

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51316-7183-Sour Service Fatigue and Fracture Behavior of High Strength Steels

Product Number: 51316-7183-SG

ISBN: 7183 2016 CP

Author: Thodla Ramgopal

Publication Date: 2016

$20.00

Fatigue Crack Growth Rate (FCGR) and fracture toughness behavior of high strength steels used in drilling riser applications was investigated in sour environments. Frequency scan tests were performed were performed on X80 C110 and S135 in moderate to mildly sour environments.

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51318-10921-Titanium Alloy Stress Corrosion Resistance to Methanol Vapor in Hydrocarbon Gas Export Systems

Product Number: 51318-10921-SG

Author: Ronald W. Schutz / Birendra Jena / Ramgopal Thodla / Heath W. Walker

Publication Date: 2018

$20.00

Susceptibility of Grades 23 and 29 titanium Tapered Stress Joint (TSJ) forgings to gas phase methanolic Stress Corrosion Cracking (SCC) was measured in deaerated, dry 0-0.5 wt.% and saturated methanol-containing methane gas environments at 25C in a two phase laboratory program.

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51318-11439-Evaluation of resistance to cracking for HIPed and rolled duplex stainless steel microstructures

Product Number: 51318-11439-SG

Author: Lisa Blanchard / Hongbiao Dong / Kasra Sotoudeh

Publication Date: 2018

$20.00

This work aims to evaluate and compare the resistance to HISC for two types of DSS products with different microstructures: rolled and hot isostatically-pressed (HIPed), using the conventional fracture toughness test methods.

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Charpy Impact Requirements for Carbon Capture and Storage (CCS) Wells Using CRA Alloys

Product Number: 51324-20629-SG

Author: Bostjan Bezensek; Willem Maarten van Haaften; Brian Chambers; Hisashi Amaya; Yuji Arai

Publication Date: 2024

$40.00

This paper presents the second part of the collaborative study on the qualification of carbon steel and CRA material grades for CCS wells injection service following AMPP2023 publication C2023-18760 for CO2 injection casing. In this paper the focus is on the CRA alloy tubing for CO2 injection. The Charpy impact testing and fracture mechanics CTOD testing was performed on representative high strength 25Cr CRA alloys of 80 ksi and 125 ksi grades to provide data for validation of the BS 7910 Annex J Master curve procedure for converting Charpy impact values to fracture toughness. The study showed that BS 7910 Annex J Master curve model can be applied to high strength OCTG 25Cr CRA grades. An example case study is presented for an injection tubing showing that the API 5CRA requirements for Group 2 materials appear to be sufficient for the accidental load scenarios considered in CO2 injection well design.

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Comparison of Two ASTM E1820 Standard Fracture Toughness Test Methods for LAS Material in Deaerated Saltwater under Cathodic Protection

Product Number: 51324-21094-SG

Author: Arshad B Gavanluei; Joseph Wilhelmi; Paul Bunch; Matt Vaclavik; Fokion Oikonomidis

Publication Date: 2024

$40.00

Low alloy steels (LAS), frequently used for pressure-containing equipment in subsea applications, are susceptible to hydrogen embrittlement when exposed to seawater environments under cathodic protection (CP), which can result in a reduction of toughness and ductility. Fracture toughness, which is an indication of a material’s resistance to crack propagation and unstable crack growth, is often determined from laboratory tests for design verification analysis or fitness-for-service applications. In hydrogen charging environments such as deaerated saltwater under CP, the fracture toughness is typically measured using either an unloading compliance (UC) or a rising displacement DCPD test method, both of which are described for air testing in the current ASTM E1820 standard. In this study, slow load rate fracture toughness tests on compact tension C(T) specimens using both test methods on the same heat of material are performed and compared. The tests are performed in a deaerated saltwater under CP environment using the same targeted K-rate of 0.005N/mm3/2/s. The UC test method is performed with a clip gauge for load-line displacement (LLD) and in-situ crack depth measurement, and the rising displacement DCPD test method infers LLD indirectly and uses DCPD for crack depth prediction. A comparison of the test results indicated a 35-65% increase in the calculated ???????? fracture toughness of the material when using the rising displacement DCPD test method.

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Effects of NaCl on Corrosion and Cracking Susceptibility of OCTG C110 Steel in Sour Environments

Product Number: 51323-19010-SG

Author: Lianlian Liu, Raymundo Case

Publication Date: 2023

$20.00

The catastrophic failure of high-strength low-alloy (HSLA) carbon steel C110 pipelines can cause huge economic loss and environmental pollution. Most studies reported that sulfide stress cracking (SSC) is the principal failure type of C110 pipelines in sour environments. The mechanism of SSC can be described as follows: The adsorbed H2S on the steel surface can accelerate the hydrogen uptake by accelerating the hydrogen reduction reaction and catalyzing the hydrogen absorption process. The absorbed hydrogen atoms accumulate in the stress-concentrated region.

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Environmentally Assisted Cracking Of Nickel Based Alloy 955 In Saltwater With Cathodic Protection For HPHT Application

Product Number: 51322-17768-SG

Author: Arshad B Gavanluei, Vipul Shinde, Manuel Marya, Ramgopal Thodla, Alexis Simon, Stanley Gregory

Publication Date: 2022

$20.00

Precipitation hardened (PH) Ni-based alloys have been utilized in oil and gas industry for decades. Among them, UNS1 N07718 because of its performance in sour wellbore fluids and in hydrogen charging environments has received the most attention for multiple upstream applications such as tubing hangers, production stab, multi-phase flow meter bodies, valve stems, etc. It has been reported that the alloy performance is generally acceptable for many applications up to 175 °C (350 °F) – 204 °C (400 °F) in the exposed wellbore environments such as sour production fluid, completion brine, and depending on metallurgical processing and microstructure externally exposed to SWCP at the seabed temperature.

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Environmentally Assisted Cracking Susceptibility Of Nickel Based Alloy 955 In A Sour Wellbore Fluid For HPHT Application

Product Number: 51322-17766-SG

Author: Arshad B. Gavanluei, Ramgopal Thodla, Manuel Marya, Alexis Simon, Vipul Shinde, Stanley Gregory

Publication Date: 2022

$20.00

Precipitation-hardened nickel-based alloys have been used for decades in the oil and gas industry. Among these alloys, UNS1 N07718 has received the most attention for use in upstream applications such as tubing hangers, production stab plate, multiphase flowmeter bodies, and valve stems because of its performance in sour wellbore fluids (SWFs) and hydrogen-charging environments.

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Fracture Toughness of 41XX Cr-Mo Steel, Super Martensitic Stainless Steel and Nickel Alloy in High Pressure Hydrogen Environment

Product Number: 51324-21083-SG

Author: Karthik Krishnan; Shashwat Shukla; Arpana Verma

Publication Date: 2024

$40.00

Hydrogen is considered one of the options to be used as alternate fuel source to reduce carbon emissions. Towards this there is growing interest in using underground storage for hydrogen gas (H2) which can be stored in larger volumes, higher pressure than surface storage options would allow for. While underground well storage of natural gas is widely understood; there is far less experience in storing H2 only or H2 in blend with natural gas. An area of knowledge gap is the compatibility of metallic materials that need to be used for well construction for underground storage as the assessment of risk for Hydrogen Embrittlement (HE) would need to be addressed. In this work, some of the common materials used in well construction for various oil and gas wells, i.e., high strength quenched and tempered 41XX type Cr-Mo steel, Super Martensitic Stainless Steel (Super 13Cr) and Age Hardenable Nickel alloy grade Alloy 925 (UNS N09925) all with similar yield strength levels have been assessed for compatibility with high pressure H2 gas. Evaluation was mainly performed via Fracture Toughness testing in both inert and high pressure H2 gas environment per ASTM E1820.1 Details of this assessment and post testing evaluation of the specimens will be provided in this paper.

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Fracture Toughness Testing Methods in H2S Containing Environment for Metallic Materials

Product Number: 51317--8930-SG

ISBN: 8930 2017 CP

Author: Arshad Bajvani Gavanluei

Publication Date: 2017

$20.00

Available fracture toughness (FT) test methodologies are reviewed in this publication to compare their details.

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Influence of K-Rate and Hydrogen Charging on Fracture Toughness of a Super Duplex Stainless Steel

Product Number: 51318-10891-SG

Author: Carlos Eduardo Fortis Kwietniewski / Tiago Renck / Fabrício Pinheiro dos Santos / Adriano Scheid / Marcelo Sartori / Afonso Reguly

Publication Date: 2018

$20.00

To evaluate through fracture toughness tests the susceptibility of SDSS to HISC and to determine the effect of the cathodic protection potential and the stress intensity factor rate (K-rate).

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Influence of the H2 Impurity on the Fatigue Crack Growth and Fracture in a Dense Phase CO2 Pipeline

Product Number: 51324-20721-SG

Author: B Bezensek; S Hopkin; J Sonke; F Gui; C Taylor

Publication Date: 2024

$40.00

Transport of dense phase CO2 by pipelines needs to account for possible degradation mechanisms arising due to H2 impurity which can be present in (typically) the 0.75 ~ 1 mol% range depending on the specification used. H2 gas can affect fatigue and fracture properties even at low partial pressures and hence the integrity. In this study a complementary experimental and computational modeling program was undertaken. API 5L X65 grade material samples were used for comparable testing in pure H2 gas at low partial pressure H2 and in dense phase CO2 at 100 barg with H2 impurity added in a 2 mol% and 4 mol% increments (i.e. partial pressures of 2 barg and 4 barg). The test results show effect of the H2 impurity in the dense phase CO2 accelerated fatigue crack growth and reduced fracture toughness. These findings are supported by computational simulation using density functional theory and molecular dynamics. A scoping integrity assessment for a dense phase CO2 pipeline with H2 impurity at 2 mol% shows the measured accelerated fatigue crack growth only affects large pressure cycles (pressure range in excess of 70 bar for OD/WT pipelines of ~30). The fatigue life is significantly shortened compared to the pure CO2 pipeline and this is mainly driven by the reduced fracture toughness at low partial pressure H2. The fatigue damage is proportional to the maximum operating pressure (as it increases the pressure range). For a postulated 50-year design life a safe pipeline design window considering a range of conservative inputs (material properties, integrity operating window, geometry, postulated defect size etc.) a safe operating pressure of 2900 psig (200barg) was found for a new build pipeline using modern materials. For a repurposed vintage material pipeline the safe operating pressure was set at 2200 psig (150 barg). An ECA incorporating the deleterious effect of H2 should be conducted to confirm the above postulate unless the project falls within the limits of the conservative inputs (material properties, integrity operating window, geometry, postulated defect size etc.), from a fracture mechanics perspective, of the four case studies that form the basis of this overall study. Other impurities if exceeded their safe threshold may create water drop out and acid formation. It is imperative that the project specifications err on the side of caution and restrict the impurities to safe limits until further understanding of the complex interaction mechanisms is developed.

Products tagged with 'fracture toughness'

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