New metal complexes with inhibiting and biocide properties

2020 ◽  
pp. 46-52
Author(s):  
F.F. Veliyev ◽  
Keyword(s):  
Carbon Dioxide ◽  
Carbon Steel ◽  
Hydrogen Sulphide ◽  
Copper Complex ◽  
Produced Water ◽  
Methanol Solutions ◽  
Production Wells ◽  
Carbon Dioxide Co2 ◽  
Water Saturated ◽  
Reducing Bacteria

Methanol solutions of various concentrations have been developed based on synthesized N, Nʹ- (pirazin-2-il) pyridine - 2,6-diamine ligand (N5-2pz), its linear pentanuclear of nickel string (II) [Ni5(μ5-dpzpda)4Cl2] (Ni5-N5-2pz) and tetracyclic copper complex (II) [Cu4(Hdpzpda)2(CH3COO)6] (Cu4-N5-2pz). Anticorrosion impact of these solutions on carbon steel Сt20 was studied on the model of produced water saturated with carbon dioxide (CO2) in the medium of hydrogen sulphide with different concentrations (H2S). Biocide properties of developed solutions against corrosion bacteria (sulphate-reducing bacteria, Tionand hydrocarbon oxidizing bacteria) have been studied on the samples of produced water taken from flooded production wells of “Bibiheybat” OGPD as well and good results obtained.

Carbon Dioxide Induced Corrosion of Carbon Steel X65 Exposed to Nitrite Aqueous Solutions

SPE Journal ◽  
2018 ◽  
Vol 24 (05) ◽  
pp. 2279-2291
Author(s):  
Silvia M. Vargas ◽  
Richard Woollam ◽  
William Durnie ◽  
Michael Hodges
Keyword(s):  
Carbon Dioxide ◽  
Carbon Steel ◽  
Corrosion Inhibitors ◽  
Produced Water ◽  
Ph Value ◽  
Oil Fields ◽  
Acid Solutions ◽  
Test Results ◽  
Ph Level ◽  
Carbon Dioxide Co2

Summary Nitrate used to control reservoir souring in oil fields contains nitrite impurities. Nitrite is a strong oxidizer, and when used in souring–treatment fluids, the flow path often includes carbon–steel piping. Vanadium, also an oxidizer, is at times found in oilfield–production streams that commingle with souring–treatment fluids. The interactions between nitrite and vanadium and their effects on carbon steel X65 corrosion were investigated. The effect of nitrite on corrosion was investigated using synthetic brine to simulate produced water [rich in carbon dioxide (CO2), pH value of approximately 5] and seawater (negligible CO2, pH value of approximately 7). Tests were conducted with carbon steel X65 exposed to synthetic brine at 25, 60, and 80°C using a rotating cylinder electrode (RCE). The test results demonstrate the following: The corrosivity of nitrite strongly depends on the pH level. Nitrite increases corrosion at pH of approximately 5 and is relatively benign at pH of approximately 7. Nitrite reduces to ammonium (thermodynamically stable in acid solutions), whereas vanadium(III) delays the formation of ammonium. Inhibited corrosion tests indicate that nitrite reduces the performance of the studied commercial corrosion inhibitors (CIs).

Vapour–liquid equilibrium data for the hydrogen sulphide (H2S)+carbon dioxide (CO2) system at temperatures from 258 to 313K

2013 ◽  
Vol 356 ◽  
pp. 223-228 ◽  
Author(s):  
Antonin Chapoy ◽  
Christophe Coquelet ◽  
Haifan Liu ◽  
Alain Valtz ◽  
Bahman Tohidi
Keyword(s):  
Carbon Dioxide ◽  
Hydrogen Sulphide ◽  
Liquid Equilibrium ◽  
Equilibrium Data ◽  
Carbon Dioxide Co2

Vapour-Liquid Equilibrium Study for the Carbon Dioxide and Hydrogen Sulphide in Deionized Water and NaCl Aqueous Solution at Temperature from 373.15 to 423.15 K

2021 ◽  
Author(s):  
Mohd Fakrumie Zaidin ◽  
Alain Valtz ◽  
Christophe Coquelet ◽  
Antonin Chapoy
Keyword(s):  
Carbon Dioxide ◽  
Aqueous Solution ◽  
Hydrogen Sulphide ◽  
Deionized Water ◽  
Phase Behaviour ◽  
Liquid Equilibrium ◽  
Average Deviation ◽  
Equilibrium Study ◽  
Vle Data ◽  
Carbon Dioxide Co2

Abstract New vapour liquid equilibrium (VLE) data for carbon dioxide (CO2) and hydrogen sulphide (H2S) mixture in deionized water and NaCl aqueous solution are generated at temperature range from 373.15 to 423.15 K and pressure up to 25.0 MPa. A static-analytic type method, taking advantage of two magnetic capillary samplers for phase sampling is used for this VLE measurements. The VLE data generated in this work are compared against literature data, Duan model and the simplified cubic plus association (CPA-SRK72) Equation of State (EoS) model predictions. From the results, it is demonstrated that the CPA-SRK72 EoS model is able to predict the phase behaviour of CO2 and H2S in water and NaCl aqueous solutions with low absolute average deviation (AAD) against the measured experimental data.

Mechanistic Modeling of Carbon Steel Corrosion in a Methyldiethanolamine (MDEA)-Based Carbon Dioxide Capture Process

CORROSION ◽  
10.5006/0695 ◽  
2013 ◽  
Vol 69 (6) ◽  
pp. 551-559 ◽  
Author(s):  
Yoon-Seok Choi ◽  
Deli Duan ◽  
Shengli Jiang ◽  
Srdjan Nešić
Keyword(s):  
Carbon Dioxide ◽  
Carbon Steel ◽  
Model Development ◽  
Electrochemical Corrosion ◽  
Steel Corrosion ◽  
Mechanistic Modeling ◽  
Uniform Corrosion ◽  
Capture Process ◽  
Corrosion Model ◽  
Carbon Dioxide Co2

A predictive model was developed for corrosion of carbon steel in carbon dioxide (CO2)-loaded aqueous methyldiethanolamine (MDEA) systems, based on modeling of thermodynamic equilibria and electrochemical reactions. The concentrations of aqueous carbonic and amine species (CO2, bicarbonate [HCO3−], carbonate [CO32−], MDEA, and protonated MDEA [MDEAH+]) as well as pH values in the MDEA solution were calculated. The water chemistry model showed a good agreement with experimental data for pH and CO2 loading, with an improved correlation upon use of activity coefficients. The electrochemical corrosion model was developed by modeling polarization curves based on the given species's concentrations. The required electrochemical parameters (e.g., exchange current densities, Tafel slopes, and reaction orders) for different reactions were determined from experiments conducted in glass cells. Iron oxidative dissolution, HCO3− reduction, and MDEAH+ reduction reactions were implemented to build a comprehensive model for corrosion of carbon steel in an MDEA-CO2-water (H2O) environment. The model is applicable to uniform corrosion when no protective films are present. A solid foundation is provided for corrosion model development for other amine-based CO2 capture processes.

scholarly journals Universalism of inhibitors against hydrogen sulfide and carbon dioxide corrosion of carbon steel

2021 ◽  
Vol 225 ◽  
pp. 05001
Author(s):  
Vladimir Vigdorovich ◽  
Liudmila Tsygankova ◽  
Natalia Shel ◽  
Nedal Alshikha
Keyword(s):  
Carbon Dioxide ◽  
Hydrogen Sulfide ◽  
Carbon Steel ◽  
Hydrogen Diffusion ◽  
Electrochemical Impedance ◽  
Negative Impact ◽  
Sulfate Reducing Bacteria ◽  
Carbon Dioxide Corrosion ◽  
Sulfate Reducing ◽  
Reducing Bacteria

The universality of inhibitors is understood as their ability to inhibit several types of corrosion attack: hydrogen sulfide and carbon dioxide corrosion, hydrogen diffusion into metal, development of sulfate-reducing and other types of bacteria, negative impact on the mechanical properties of metals. Indicators of universalism of new inhibitor have been studied. Producer of the inhibiting compositions is Limited Liability Company «INCORGAZ» (S-Petersburg, Russia). The efficacy of the inhibitor in the concentration of 25 - 200 mg/L has been studied with respect to carbon steel in a highly mineralized chloride medium (pH= 6) and NACE medium (5 g/L NaCl, 0.25 g/L CH3COOH, pH =3.5) containing H2S (50-400 mg/L) and CO2 (1at) separately and together. The bactericidal properties of the inhibitor were studied with respect to sulfate-reducing bacteria in the Postgate medium. The investigations were carried out by the methods of linear polarization resistance, electrochemical impedance spectroscopy, gravimetry, potentiodynamic polarization. The protective effectiveness of the inhibitor reaches 80% in the presence of CO2 and 90% in hydrogen sulphide environments. The inhibitor repeatedly reduces the number of sulfate-reducing bacteria and the production of biogenic hydrogen sulfide and inhibits the diffusion of hydrogen into steel.

scholarly journals HIC and SSC of Carbon Steel in High Partial Pressure CO2 Environments with Elevated H2S

2021 ◽  
Vol 287 ◽  
pp. 02001
Author(s):  
Ahmad Zaki Abas ◽  
Azmi Mohammed Nor ◽  
Muhammad Firdaus Suhor ◽  
Ahmad Mustaza Ahmad Rusli ◽  
Mokhtar Che Ismail
Keyword(s):  
Carbon Dioxide ◽  
High Pressure ◽  
Carbon Steel ◽  
Field Condition ◽  
Standard Test ◽  
Sulfide Concentration ◽  
Surface Cracking ◽  
Sulfide Stress ◽  
Carbon Dioxide Co2 ◽  
Sour Service

The Hydrogen Induced Cracking (HIC) and Sulfide Stress Cracking (SSC) behaviours of sour service and non-sour service carbon steel API 5L X65 were investigated under high pressure carbon dioxide environments, containing elevated amount of hydrogen sulphide (H2S); the test environments simulated offshore pipelines transporting full-well streams in high carbon dioxide (CO2) environments with elevated H2S concentrations. It was systematically studied under standard NACE condition and high pressure carbon dioxide field condition with variation in other key parameters (temperature, pressure and hydrogen sulfide concentration). The HIC and SSC were tested using a High Pressure and High Temperature (HPHT) Autoclave. The surface cracking morphology was analysed using Scanning Electron Microscopy (SEM), Ultrasonic Technique (UT) and Magnetic Particle (MP). The results showed that no cracks were detected in NACE standard and field-condition SSC tests for both sour service and non-sour services carbon steel. In HIC test, crack was detected on non-sour service carbon steel in NACE standard test while no crack was detected on field condition-based tests for both types of carbon steel.

Nanoparticle-Stabilized Carbon Dioxide Foam Used In Enhanced Oil Recovery: Effect of Different Ions and Temperatures

SPE Journal ◽  
2017 ◽  
Vol 22 (05) ◽  
pp. 1416-1423 ◽  
Author(s):  
Jingshan San ◽  
Sai Wang ◽  
Jianjia Yu ◽  
Ning Liu ◽  
Robert Lee
Keyword(s):  
Carbon Dioxide ◽  
Oil Recovery ◽  
Produced Water ◽  
Foam Stability ◽  
Bivalent Ions ◽  
Foam Generation ◽  
Co2 Foam ◽  
Nacl Concentration ◽  
Different Temperatures ◽  
Carbon Dioxide Co2

Summary This paper reports the study of the effect of different ions (monovalent, bivalent, and multiple ions) on nanosilica-stabilized carbon dioxide (CO2) foam generation. CO2 foam was generated by coinjecting CO2/5,000 ppm nanosilica dispersion (dispersed in different concentrations of brine) into a sandstone core under 1,500 psi and at different temperatures. A sapphire observation cell was used to determine the foam texture and foam stability. Pressure drop across the core was measured to estimate the foam mobility. The results indicated that more CO2 foam was generated as the sodium chloride (NaCl) concentration increased from 1.0 to 10%. In addition, the foam bubble became smaller and foam stability improved with the increase in NaCl concentration. The CO2-foam mobility decreased from 13.1 to 2.6 md/cp when the NaCl concentration increased from 1 to 10%. For the bivalent ions, the generated CO2-foam mobility decreased from 19.7 to 4.8 md/cp when CaCl2 concentration increased from 0.1 to 1.0%. Synthetic produced water with total dissolved solids (TDS) of 18,583 ppm was prepared to investigate the effect of multiple ions on foam generation. The results showed that stable CO2 foam was generated as the synthetic produced water and nanosilica dispersion/CO2 flowed through a porous medium. The lifetime of the foam was observed to be more than 2 days as the foam stood at room temperature. Mobility of the foam was calculated as 5.2 md/cp.

Research on Corrosion of Well-Bore Tube and Anticorrosive Measure of Tazhong-1 Gas Field

2011 ◽  
Vol 108 ◽  
pp. 308-313 ◽  
Author(s):  
Shan Fa Tang ◽  
Xue Yang ◽  
Da Wei Wu
Keyword(s):  
Carbon Dioxide ◽  
Hydrogen Sulfide ◽  
Natural Gas ◽  
Corrosion Inhibitors ◽  
Produced Water ◽  
Formation Water ◽  
Well Bore ◽  
Gas Field ◽  
Production Wells ◽  
Sulfide Corrosion

Natural gas of Tazhong-1 gas field contains 7.7% carbon dioxide and 2.31% hydrogen sulfide, and produced water salinity is up to 140000mg/L,the well-bore tube has seriously potential corrosion destructive with natural gas being exploited. Based on the corrosion type partition of down-hole tube for eighteen production wells of Tazhong-1 gas field, P110,P110S and P110SS corrosion behavior were investigated under the conditions of simulated formation water containing carbon dioxide or hydrogen sulfide/carbon dioxide, and corrosion inhibitors were chosen to meet need of anticorrosion of Tazhong-1 gas field. The results show that fifteen wells in eighteen production wells belong to hydrogen sulfide corrosion of both hydrogen sulfide and carbon dioxide influence. Other wells are singular carbon dioxide corrosion. The most severe corrosion of three types of down-hole tubes all occurs at 90°C in both corrosion media, and their corrosion resistance order is respectively P110>P110S>P110SS and P110S>P110SS>P110 under the conditions of simulated formation water containing carbon dioxide or hydrogen sulfide and carbon dioxide. The selected anti-temperature corrosion inhibitors (YU-1、YU-4) can control the corrosion rate of three types of down-hole tubular goods within 0.076mm/a in simulated formation water media with carbon dioxide (PCO2=0.08～4.64MPa) or hydrogen sulfide and carbon dioxide (PH2S/Pco2=1.3/4.64Mpa) while added amount of the inhibitor is 120～300mg/L or 200mg/L. All of these provide technical support for safe and fast development of Tazhong-1 gas field.

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