AMPP Store - Products tagged with 'brine'

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03140 Fluid Compatibility of Elastomers in Oilfield

Product Number: 51300-03140-SG

ISBN: 03140 2003 CP

Author: J. Buc Slay, Thomas W. Ray

Publication Date: 2003

$20.00

The process of determining the fluid compatibility (FC) of elastomers and how compatibility affects material selection for downhole applications. Effects of completion fluids (Bromides and Formates) on elastomers. Elastomer samples were conditioned at temperatures from 175°F (80°C) to 380°F (193°C) for up to 3 weeks.

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08271 Effects of Oxygen, Temperature and Salinity on Carbon Steel Corrosion in Aqueous Solutions; Model Predictions versus Laboratory Results

Product Number: 51300-08271-SG

ISBN: 08271 2008 CP

Author: Steven Grise and Brian Saldanha

Publication Date: 2008

$20.00

Corrosion of carbon steel materials in brine solutions. Model results will be compared with literature data and lab experiments. Conditions will be limited to near neutral pH (5-9), temperature from 22oC to 55oC, and O2 atmospheres up to 101.325 kPa.

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51318-10516-Properties of Brines formed by Deliquescence of Sea-Salt Aerosols

Product Number: 51318-10516-SG

Author: C. R. Bryan / E.J. Schindelholz

Publication Date: 2018

$20.00

We have used thermodynamic modeling to predict the chemical composition of the brines that form by deliquescence of sea-salt aerosols, and to estimate brine volumes and salt/brine volume ratios as a function of temperature and atmospheric relative humidity.

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Corrosion Of Wrought And Cast Ni-Fe-Cr-Mo Alloys In High-Temperature Brines And CO2-Rich Supercritical Phases With Oxygen And Hydrogen Sulfide

Product Number: 51322-17882-SG

Author: Manuel Marya

Publication Date: 2022

$20.00

Carbon dioxide capture, utilization, and storage (CCUS) is part of decarbonization solutions to reduce green-house gas emissions, as exemplified by the growing number of capital expenditure projects worldwide.^1-2 In CCUS, the carbon dioxide (CO₂) is consecutively (1) captured at origin, such as power plants and natural gas production sites, (2) separated from other gases and impurities, (3) compressed, (4) transported through pipelines, and finally (5) injected into a storage site such as deleted hydrocarbon wells, saline aquafers, coal beds, underground caverns, or seawater.^1,3 Since the 1970s, specifically the first commercial carbon dioxide flooding in the United States (known as SACROC), carbon dioxide sequestration has been largely discussed in the context of enhanced oil recovery (EOR), not in the newer context of Sustainability. Nonetheless, substantial experience has been drawn from EOR, including for the selection of the right and economical materials.⁴ As reflected by the literature, past materials test programs have rarely given any attention to downhole jewelry alloys compared to tubulars or surface-infrastructure alloys, and consequently the track records for such bar-stock alloys are either inexistent or not readily available. ^5-7 This lack of apparent return-on-experience represents a knowledge gap against the prospect of a safe greenhouse gas control method; needless to say, it also justifies the requirements for reliable well integrity monitoring solutions in carbon dioxide sequestration wells.^8-9

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Investigating the Interaction of Brine Solutions and Diluted Inhibited HCl Acid on Coiled Tubing Steel Corrosion

Product Number: 51320-14596-SG

Author: N. Chkolny, J. Burns, D. Maley, C. Wiggins

Publication Date: 2020

$20.00

Coiled tubing is defined as a continuous tubular product that is used for oil and gas well interventions. Its popularity continues to grow due to its versatility and speed of operation. Though superior grades of metal alloys exist in terms of corrosion resistance, coiled tubing operations primarily employ high-strength low-alloy steels because of their availability, lower cost and weldability. The low-alloy steel can also be thermo-mechanically controlled to elicit specific material properties, such as yield strength and ductility. These coiled tubing steels are often introduced into potentially corrosive downhole conditions, therefore proper testing must be completed to ensure adequate corrosion protection prior to job execution. Downhole corrosive conditions often encountered include; oxygen saturated fluids, elevated temperatures, exposure to oxidizing agents, hydrochloric acid and highly concentrated brines. Often these fluids will be recirculated in a closed loop system, consistently re-exposing equipment to potentially damaging conditions. Frequently, these challenging conditions faced are tested individually with pressurized mass loss coupon testing at bottom hole conditions. However, due to a recent coiled tubing incident in which the coiled tubing pipe had completely parted downhole, the post-job incident investigation involving SEM and metallographic analysis revealed pitting corrosion throughout the tubing, despite the pre-job testing performed indicating adequate acid corrosion protection for the entirety of the job. A literature review indicated very little research was available involving the possible interaction of brine solutions and diluted acid on coiled tubing carbon steels. This paper aims to investigate the possible corrosive interactions between salt brines and inhibited acid blends at elevated temperatures on high grade coiled tubing coupon samples through metallographic examinations and mass loss tests in pressurized heated cells. Coiled tubing coupons will be exposed to a variety of acid blends diluted with a 10% brine (8% wt NaCl and 2% wt CaCl2) or fresh water to investigate the possibility of corrosion enhancement between saline fluids in a diluted acid system.

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On-Line Real-Time Corrosion Monitoring Techniques Under Co2 - Brine Environment – Comparative Study

Product Number: 51317--9040-SG

ISBN: 9040 2017 CP

Author: Hui Li

Publication Date: 2017

$20.00

Injection water/brine handling systems are important elements of the oil & gas field operations. This comparative study offers insights relevant to accuracy, sensitivity and responsiveness of different corrosion monitoring techniques in brine environment.

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Stress Corrosion Cracking And Hydrogen Embrittlement of High-Strength Non-Magnetic Alloys In Hot Concentrated Brines

Product Number: 86162-SG

Author: J. G. Erlings, H.W. de Groot, J.F.M. van Roy

Publication Date: 1986

$20.00

Unexpected brittle failures of UNS NO5500 drill string parts and non-magnetic drill collars have recently been observed in cases where the UNS NO5500 components were galvanically coupled to carbon steel in concentrated salt solutions at temperatures between ambient and higher than 373 K. Cracking occured preferable at locations with a tri-axial stress condition (roots of threads) and has been ascribed to hydrogen embrittlement.

Products tagged with 'brine'

03140 Fluid Compatibility of Elastomers in Oilfield

08271 Effects of Oxygen, Temperature and Salinity on Carbon Steel Corrosion in Aqueous Solutions; Model Predictions versus Laboratory Results

51318-10516-Properties of Brines formed by Deliquescence of Sea-Salt Aerosols

Corrosion Of Wrought And Cast Ni-Fe-Cr-Mo Alloys In High-Temperature Brines And CO2-Rich Supercritical Phases With Oxygen And Hydrogen Sulfide

Investigating the Interaction of Brine Solutions and Diluted Inhibited HCl Acid on Coiled Tubing Steel Corrosion

On-Line Real-Time Corrosion Monitoring Techniques Under Co2 - Brine Environment – Comparative Study

Stress Corrosion Cracking And Hydrogen Embrittlement of High-Strength Non-Magnetic Alloys In Hot Concentrated Brines

Association for Materials Protection and Performance