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Reinforced Thermosetting Resin Pipes (RTRP) Failures & Quality Control Measures Adopted During Construction of The Largest LNGI facility in Kuwait

Product Number: 51323-18799-SG

Author: Faisal Al-Refai, Yousef J. Mansour, Fahad Al-Qanaee, Anas Abdelmotelb

Publication Date: 2023

$20.00

This paper, presents the isolated and common cases of failure, recounting the troubleshooting practices followed and the verified remedial actions. Much of these cases, lessons learned, and quality control measures provide valuable tools to users of this type of piping material in the oil & gas industry. This paper also sheds lights on the shortcomings of RTRP, that are usually trumped by operational benefits.

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Reinforced Thermosetting Resin Pipes (RTRP) Failures and Quality Control Measures AdoptedDuring Construction of The Largest LNGI facility in Kuwait

Product Number: MECC23-20057-SG

Author: Faisal Al-Refai; Yousef J. Mansour; Fahad Al-Qanaee

Publication Date: 2023

$20.00

The LNGI facility in Kuwait represents a movement towards sustainable clean energy. The purpose of the facility is to import liquified natural gas to be stored and subsequently vaporized to its gaseous form to be distributed to end users. End users include refineries and electricity power plants.

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Relating Changes in Electrochemical Properties to Barrier Property Changes of an Organic Coating System

Product Number: 51323-19314-SG

Author: Steven A. Policastro, Erick Iezzi, Attilio Arcari, Rachel M. Anderson, Carlos M. Hangarter

Publication Date: 2023

$20.00

Coating systems are used in a wide variety of environments, including seawater immersion and exposure to the atmosphere, as a method for preventing corrosion. A coating system refers to the layers of coatings that are applied over one another to form a structure that performs multiple functions that cannot be provided by a single coating. For example, the initial layer of the system may consist of a surface pretreatment that thickens the oxide film of the aircraft skin material and aids in adhesion of the base coating to the substrate.

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Remaining Life Assessment of 9Cr-1Mo Steel Radiant Heater Tube in Continuous Catalytic Reforming Unit

Product Number: 51324-21147-SG

Author: Sudharsanan Soundararajan

Publication Date: 2024

$40.00

The radiant tubes in fired heaters operating in the creep range are designed as per API 530. The typical creep design life of the heater tubes is 100,000hours. Tube sample from this 1st Inter-heater was removed after 166,500hours of operation with the process gas outlet temperature of 550oC (1022oF). The tube skin temperature was observed in the range of 600-630oC. Scale characterization using SEM/EDS, Hot and ambient tensile testing, Hardness measurement, Accelerated Creep rupture testing and creep testing was carried out as part of the assessment. This paper explains the methodology adopted for remaining life assessment and compares the results from Larson-Miller Parameter method (LMP) & MPC Omega method. The remaining life evaluation was carried out as per API 579-1/ASME FFS-1. The Creep ductility factor ?cdO and Scatter band factor ?srO was adjusted to match the Omega (?) parameter and initial strain rate (eo) derived from the creep test. As part of the metallurgical analysis damage due to carburization and metal dusting was also evaluated.

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Remnant Life Prediction for Glass-Reinforced Plastic Piping

Product Number: 51324-20897-SG

Author: Raunak Bardia; Valeriia Khokhlova; Wouter Hamer; Heather Gower; Nicholas Laycock

Publication Date: 2024

$40.00

Glass Reinforced Plastic (GRP) pipes are widely used as an alternative to metallic piping in challenging environments, such as concentrated acids. However, compatibility with the environment is typically described only in qualitative terms, and non-destructive inspection techniques do not provide data that can be used to accurately quantify in-service degradation. Consequently, remnant life prediction as the basis for maintenance and replacement of non-metallic piping presents a considerable challenge. The ISO-14692 standard provides a methodology for qualification of GRP piping that uses data from tests carried out with potable water, which can be scaled using a factor for other service fluids, although a default value of 1.0 is commonly used. This paper extends that design practice specified in ISO-14692 by incorporating the chemical compatibility factors as described in EN 13121 for design of GRP tanks and vessels. This procedure is used to calculate a chemical de-rating factor for long-term hoop stress, in addition to the standard design lifetime factor defined in ISO-14692. The combined de-rating relationship is repurposed to evaluate the amount of degradation under the actual service conditions experienced by the piping. Examples of this approach are provided for non-metallic piping carrying a range of service fluids in an operating plant.

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Remote Monitoring Survey

Product Number: 51323-19260-SG

Author: Andreas Junker Olesen, Lars Vendelbo Nielsen

Publication Date: 2023

$20.00

Remote monitoring is becoming an increasingly more accepted way of gathering data from test stations. Not only because the value of having continuous data often exceeds that of performing spot-wise measurements in time, but also because the cost of collecting data manually is getting higher. Still, regulations require annual surveys to document the safe operation of pipeline CP systems.

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Research On Cluster Well Group Casing Cathodic Protection For Field Test And Optimization Of Anode Bed

Product Number: 51322-17724-SG

Author: Dawei Zhuang, Qian Zhao, Yanxia Du, Xiaoyong Wang, Qiongwei Li

Publication Date: 2022

$20.00

Deep well casing is an important part of oilfield production. In the long service life of well casing, corrosion can result in wall thinning and even perforation of the casing due to contacting with soil, water and other naturally occurring substances within the formation. The most economic and effective method to decrease corrosion of well casing is cathodic protection (CP). However, the vertical depth of casing is several kilometers, and CP current requirements of casing in different layers are quite different. At the same time, the conductivity of different formations will affect the distribution of CP current.

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Research Progress of Fouling Scale Control Technology in Low Permeability Oilfields

Product Number: 51324-21027-SG

Author: Chenglong Li; Qiongwei Li; Ning Liu; Min Yang; Peng Xu

Publication Date: 2024

$40.00

In recent years, Changqing Oilfield has continuously enlarged the scale of exploration and development, and its oil and gas equivalent output has exceeded 6,500 × 104t/a. However, the oilfield has been developed by multiple reservoir system stacking, and it has gradually entered the stage of medium-high water cut, and scaling has become more and more prominent impact of production system. In accordance with compose the prevention and control strategy, chemical and physical scaling technology research and on-site tests have been combined to extend the scaling cycle and slow down the scaling rate, and achieve good results.

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Residual Analysis Assay For Thiol-Based VCI Quantification In Top-Of-Line Corrosion Environments

Product Number: 51322-17918-SG

Author: Mariana Costa Folena, José Antônio da Cunha Ponciano Gomes, Hanan Alshareef Farhat, Iain Manfield, Joshua Owen, Anne Neville, Richard Barker

Publication Date: 2022

$20.00

Top of line corrosion (TLC) is a degradation mechanism predominantly encountered in the oil and gas industry. Initiation of TLC requires a stratified flow regime with wet gas transportation and the existence of a significant temperature gradient between the hot fluid inside the pipeline and the colder external environment.1,2,3 This temperature difference results in the condensation of water vapor, present in the gas phase, onto the cooler, upper internal section of the pipeline. The condensed water can be particularly aggressive as it lacks dissolved salts (e.g. bicarbonates), some of which are able to buffer the bulk electrolyte, increasing the pH and suppressing corrosivity.4,5,6 The absence of such salts typically results in a very low pH condensate (<pH 4), often containing dissolved acidic gases, such as carbon dioxide (CO2) and hydrogen sulfide (H2S), and also acetic acid (HAc), which can cause severe degradation, particularly in the form of localized corrosion.5

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Resistance of U-bend and Integral Finned Duplex Stainless Steel UNS-S32205 and UNS-S32750 to Sulfide Stress Corrosion Cracking

Product Number: 51322-18038-SG

Author: Karen Picker, Luiza Esteves, Yong-Joo Kim

Publication Date: 2022

$20.00

The use of Duplex Stainless Steels (DSS) in refinery sour environments is governed by ANSI/NACE MR0103/ISO 17945NACE “Metallic materials resistant to sulfide stress cracking in corrosive petroleum refining environments” which limits DSS base materials to be used in Hydrogen Sulfide (H2S) services to a maximum hardness of 28 HRC for materials with a PREN ≤ 40 and to a maximum hardness of 32 HRC for those materials with PREN > 40.¹ These hardness values are in line with the hardness requirements of solution annealed as produced straight tubes, but when the heat exchanger design requires the use of integral finning or u-bend tubes, these are subject to significant work hardening that results in as bent and as finned heat exchanger tubes with hardness measurement as high as 418 HV0.5 or 35.6 HRC which clearly exceeds the allowable limits stated above.

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Results and Relation to Deformation Mechanisms for SSRT Testing of Austenitic Stainless in Hydrogen Gas

Product Number: 51324-20659-SG

Author: Ulf H Kivisäkk; Ulrika Borggren; Raveendra Siriki

Publication Date: 2024

$40.00

The use of Hydrogen as a fuel is widely discussed today with stainless steels able to be used for tubing and as fittings in various systems. The application areas vary from tubing and fittings in vehicles, filling stations, production or storages facilities. In all applications resistance against hydrogen embrittlement is a key prerequisite. Earlier the susceptibility to hydrogen embrittlement of three austenitic stainless steels tested by different SSRT methods has been reported: electrochemical charged, thermal pre-charged and in situ testing in 85 to 87.5 MPa hydrogen gas at -40°C. The low nickel versions of UNS S31603 experienced brittle fracture whereas the high nickel version of UNS S31603 as well as UNS S31675 had ductile fractures. The appearance of the fracture surface in SEM indicates that all test methods promote ingress of hydrogen to the center of the specimen. In this work, study of the deformation mechanisms has been performed by EBSD obtained 5 mm from the fracture. The study reveals that the low nickel version of UNS S31603 experiences formation of deformation induced martensite, the high nickel version of UNS S31603 shows no martensite but produces twinning. UNS S31675 which has a small grain size shows no formation of martensite and only small degree of twinning. The deformation structures are discussed with respect to the outcome of the SSRT-testing and austenite stability.

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Retention Improvement Of Sulfonic Acid Based Scale Inhibitor On Sandstone Formations At HTHP Conditions

Product Number: 51322-17875-SG

Author: Yasmin Hayatgheib, Salima Baraka-Lokmane, Thibaut Charpentier, Wassim Taleb, Paul Thornton, John-Richard Ordonez-Varela, Richard Barker, Wassim Taleb, Anne Neville

Publication Date: 2022

$20.00

Oilfield waters have a complex composition depending on reservoir rock at different geographical locations that can be carried into the production water¹. The alteration in environmental conditions such as pressure, temperature, salt content or pH can cause the liquid to oversaturate and the contained ions to form complexes. These will precipitate out of the solution, deposit and grow on contacting surfaces such as reservoirs, upstream production tubing, sub-surface safety valves, water injection lines to top side refining equipment namely heat exchangers and transport lines ^2–4. Scaling can also be induced by incompatible mixing of fluids. For example CaCO₃ and /or BaSO₄ form through typical mixing of SO4 2- containing sea water with the formation water that carries high concentrations of divalent cations such as Ca²⁺and Ba^2+₂. Similarly, sulfide scales form upon mixing with H₂S-containing formation water enriched with Fe, Zn or Pb ions ⁵. ZnS and PbS have been observed to form in presence of only 25 ppm H₂S at gulf of Mexico containing 50 ppm Zn and 5 ppm Pb , due to their low solubility constant K_sp ^6,7.

AMPP Conference Papers

Association for Materials Protection and Performance