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Sensitivity Study Of Typical Pipelines And Station Pipes In Hydrogen Environment

Product Number: 51322-17707-SG

Author: Fei Fan, Zhao Na, Zhou Shun, Feng Min, Shen Ke, Yang Zhiwen, Wang Chong, Chen Yingfeng, Wang Yanjun

Publication Date: 2022

$20.00

With the increasing global energy demand, the transportation volume of natural gas increases rapidly, and pipeline transportation has become the most commonly used transportation mode of natural gas. Hydrogen is produced as a byproduct of ethylene production from ethane. Hydrogen is flammable and explosive. If it is directly discharged into the atmosphere, there are some safety risks. As a kind of efficient and clean secondary energy, hydrogen can not only avoid energy waste, but also increase economic benefit if it is mixed into natural gas pipeline.

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Severe microbiologically influenced corrosion (MIC) of pure zinc and galvanized steel in the presence of Desulfovibrio vulgaris

Product Number: 51320-14537-SG

Author: Di Wang, Tuba Unsal, Tingyue Gu, Sith Kumseranee, Suchada Punpruk

Publication Date: 2020

$20.00

Zinc and its alloys are used as sacrificial anodes because zinc is an active metal. Carbon steel can be coated with zinc to protect against corrosion. These metals are known as galvanized steel. In this work, microbiologically influenced corrosion (MIC) of pure zinc and galvanized steel caused by a sulfate reducing bacterium was investigated. After 7 days of incubation in 125 mL anaerobic vials with 100 mL culture medium and 1 mL inoculum, the sessile cell count on the galvanized steel was slightly higher than that on pure zinc. The abiotic weight loss for pure zinc was 1.4 ± 0.1 mg/cm2 vs. 4.6 ± 0.1 mg/cm2 for galvanized steel after 7 days of anaerobic incubation at 37oC. The weight losses for galvanized steel and pure zinc were 31.5 ± 2.5 mg/cm2 and 35.4 ± 4.5 mg/cm2, respectively, which were 10X larger than the previously reported carbon steel weight loss in the same SRB broth. Electrochemical corrosion tests confirmed the severe corrosion of these two metals. The corrosion current densities of galvanized and pure zinc were 25.5 µA/cm2 and 100 µA/cm2, respect􀀀vely at the end of the 7-day incubation with SRB, confirming that pure zinc was more prone to SRB MIC than galvanized steel. In both cases, the corrosion product was mainly ZnS. Three MIC mechanisms were possible for the severe corrosion. Extracellular electron transfer MIC is thermodynamically favorable for Zn. Furthermore, the detection of H2 evolution in the vials suggest that proton attack and H2S attack occurred against Zn in the SRB broth with neutral pH after passive film damage by the SRB biofilm.

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Severe Pipe Damage In SAGD Steam Distribution Lines

Product Number: 51322-17670-SG

Author: Haixia Guo, Saravanan Meyyappan, Basil Perdicakis, Neil Fricke, Yasin Suzuk, Simon Yuen, Duane Serate

Publication Date: 2022

$20.00

In Oil Sands In-Situ operation bitumen is often extracted from underground oil sands deposits through SAGD (Steam Assisted Gravity Drainage) technology. This method involves forcing steam into sub-surface oil sands deposits, usually those at depth greater than 150m (492 ft), to heat the bitumen locked in the sand, allowing it to flow well enough to be extracted [1]. This process technology makes it possible to access the underground deposits otherwise difficult to access through the open mine method. It is particularly relevant in Canada because it is the most common method of in situ extraction used in the oil sands.

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Shale Gas Production Pipeline Failure - Case Study

Product Number: 51324-20698-SG

Author: Feras El Yaakobi; Sherman Kung; Connor Graham; Jeannine Schmid; Daryl Foley

Publication Date: 2024

$40.00

Shale gas production is unique and presents challenges in terms of corrosion mitigation and pipeline integrity management. Many of these challenges stem from variations in production modes from the early stages and as the system becomes mature, with many variables involved such as frac flowback, H2S, CO2, iron, microbial, velocities, topography, O2, hydrates, and paraffin. When combined with economic challenges the oil and gas industry faces, these factors force producers to strike a balance between technical decisions and operational/cost efficiencies, which adds complexity to an already difficult-to-manage system. This paper will review a pipeline failure case study from a critical sour shale gas gathering system in Canada. The case study will cover the history of the pipeline from commissioning until failure, challenges faced, root-cause analysis, solutions implemented, and results obtained. The case study will help increase awareness about best practices regarding pipeline pigging, corrosion inhibitor batch treatments, and analytical testing used when conducting failure root cause analysis. It also serves as a documentation for a corrosion failure in a pipeline with a staggering corrosion rate of over 2,800 mpy resulting in a pipeline failure in less than five weeks of operations.

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Shortcomings regarding the Testing of Oil and Gas Corrosion Inhibitors

Product Number: 51324-20823-SG

Author: Alyn Jenkins; Khoa Ky; David Orta

Publication Date: 2024

$40.00

Laboratory selection of oilfield corrosion inhibitors used to mitigate carbon dioxide (CO2) and hydrogen sulfide (H2S) corrosion is an essential aspect of every asset integrity program implemented in oil and gas fields. However, many factors increase the complexity of designing a corrosion inhibitor laboratory test program that will deliver reliable results. Several of these factors relate to the challenges of accurately replicating field conditions in the laboratory, including using inhibitor-free crude oil, reproducing pipeline flow regimes and wall shear stress, duplicating the specific form of corrosion that occurs in the field, and simulating inhibitor deliverability and transport in multiphase pipelines. Other elements that increase the difficulty relate to requirements for environmentally acceptable chemistries in certain geographies and the variety of corrosion performance tests and methodologies mandated by different oil companies. After the laboratory testing is complete and a corrosion inhibitor has been selected for field application, optimization of the product in the field should be performed but this is frequently overlooked. If corrosion inhibitor treat rate is not optimized in the field, it can result in overdosing (causing stabilization of emulsions and foaming) or underdosing (which can result in high corrosion rates). This paper discusses the challenges and inconsistencies associated with selecting corrosion inhibitors for use in oil and gas fields. Importantly, this paper discusses how these challenges can be resolved to ensure that the selection of oil and gas corrosion inhibitors follows a reliable process.

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Silica Nanocapsules Based On Gemini Surfactant As Environmentally Friendly Nanocontainers For Corrosion Protection In Seawater

Product Number: 51321-16741-SG

Author: O. Kaczerewska; J. Fikgueiredo; S. Loureiro; I. Sousa; R. Martins; J. Tedim

Publication Date: 2021

$20.00

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Silica Solubility in High Enthalpy Water up to 440°C in the Presence of NaCl

Product Number: 51324-21029-SG

Author: Morten Tjelta; Sissel Opsahl Viig

Publication Date: 2024

$40.00

In geothermal energy production, precipitation/scaling and potential plugging of wells is one of the major threats to flow assurance. Mitigation strategies should be considered at the design stage, but to do so knowledge about solubility across a relevant space of temperature, pressure and fluid composition is needed. In hot fluids, silica scaling is often found to be the major concern. Predictive models available in literature give good agreement with experimental values in the region where data are available, but there is limited data available at high temperatures and low pressures, in particular in the presence of salt. This work describes an experimental setup designed to carry out solubility experiments up to 500 °C and 400 bar. A main feature of the setup is the ability to dilute the sample fluid in the hot zone in order to avoid precipitation during sampling. Illustrations are given for how existing phase relations can be used to guide the execution of such high-pressure high-temperature experiments. Results of silica solubility experiments in the presence of NaCl up to 440 °C at 150-350 bar are presented. This work includes data at the steam side pseudocritical line (critical density isochor) where limited data is available in the literature. The experimental concept, with hot zone dilution to avoid precipitation during sampling, can be used to obtain fluid samples as a function of time. Although utilized in the current work for solubility experiments it should be equally applicable to corrosion studies.

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Silicate Resins for Sustainable Heavy Duty Coatings

Product Number: 51324-21213-SG

Author: Kristen Blankenship; James Lawson

Publication Date: 2024

$40.00

Extending service life of an asset brings value to the owner and has the added benefit of reducing environmental impact. Arguably the biggest threat to service- life is degradation. When constructing with steel, corrosion is the threat to mitigate. Zinc dust incorporated into silicate resins have offered corrosion protection for heavy duty coating applications since the latter half of the last century. In recent years silicate finishes formulated without zinc have entered the market to create a two- coat system offering superior corrosion protection in a finish with various color options. The silicate finish or topcoat is low carbon and resilient to UV degradation allowing it to protect the zinc- rich primer from damage. For applications where a lower gloss finish is desired or appropriate, this technology offers decades long durability sustainably. This paper will explain what a two- coat silicate resin- based coating system is, how it works, what it looks like and most importantly how it reduces environmental impact through increasing service life of assets.Protective coatings, Corrosion control, Degradation, Durability, Coating lifecycle

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Simulating Corrosion And Scale Interactions In Autoclave Experiments: A Sensitivity Study

Product Number: 51322-17622-SG

Author: Robert Jacklin, Joshua Owen, Danny Burkle, Anne Neville, Richard C. Woollam, Richard C. Woollam

Publication Date: 2022

$20.00

Carbon dioxide (CO₂) saturated brines containing high levels of calcium are commonly encountered across the energy sector: from hydrocarbon recovery to the harvesting of geothermal energy and re-deposition of CO₂ for permanent storage. These brines originate in deep underground reservoirs at elevated pressures and temperatures. Despite susceptibility to corrosive attack under these conditions, carbon steels are the preferred choice of pipeline materials for such processes, attributable to their low cost, availability and ease of manufacture.

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Simulation Of The Damage Tolerance Of Thermal Spray Aluminium Sacrificial Coating In Artificial Seawater

Product Number: 51322-17641-SG

Author: Adriana Castro Vargas, Shiladitya Paul

Publication Date: 2022

$20.00

TSA is mainly used to protect offshore steel structures, including atmospheric, splash and immersed zones. During installation or in service, the coating is likely to be damaged due to erosion, wear, scratch etc. TSA coatings protect by acting as a barrier and offering cathodic protection even if the substrate is exposed to seawater.

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Slurry Abrasion Failure Of A Carbon Steel Pipe Carrying Bitumen Froth In Oil Sands

Product Number: 51321-16941-SG

Author: Reinaldo J Chung; Naveen Prathap; Shawn Chen; Jiaren (Jimmy) Jiang; Darren Ting; Marilin Garcia

Publication Date: 2021

$20.00

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Solids Formation In MEA Triazine Contact Towers, Prevention And Advice

Product Number: 51322-17483-SG

Author: Willem-Louis Marais Schlumberger

Publication Date: 2022

$20.00

In this paper focus will be placed on the non-oxidative and non-regenerative H2S scavenger MEA Triazine and its application in contact tower systems, specifically looking at solids (polymeric dithiazine) formation.

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