scholarly journals Effect of Jet Impingement Velocity and Angle on CO2 Erosion–Corrosion with and without Sand for API 5L-X65 Carbon Steel

Materials ◽  
2020 ◽  
Vol 13 (9) ◽  
pp. 2198
Author(s):  
Ihsan Ulhaq Toor ◽  
Zakariya Alashwan ◽  
Hassan Mohamed Badr ◽  
Rached Ben-Mansour ◽  
Siamack A. Shirazi
Keyword(s):  
Carbon Steel ◽  
Oil And Gas ◽  
Carbonic Acid ◽  
Ph Value ◽  
Jet Impingement ◽  
Gas Production ◽  
Solid Particles ◽  
Co2 Corrosion ◽  
Recirculating Flow ◽  
Erosion Corrosion

Most oil and gas production wells have plenty of corrosive species present along with solid particles. In such production environments, CO2 gas can dissolve in free phase water and form carbonic acid (H2CO3). This carbonic acid, along with fluid flow and with/without solid particles (sand or other entrained particles), can result in unpredictable severe localized CO2 corrosion and/or erosion–corrosion (EC). So, in this work, the CO2 EC performance of API 5L X-65 carbon steel, a commonly used material in many oil and gas piping infrastructure, was investigated. A recirculating flow loop was used to perform these studies at three different CO2 concentrations (pH values of 4.5, 5.0, and 5.5), two impingement velocities (8 and 16 m/s), three impingement angles (15°, 45°, and 90°), and with/without 2000 ppm sand particles for a duration of 3 h in 0.2 M NaCl solution at room temperature. Corrosion products were characterized using FE-SEM, EDS, and XRD. The CO2 EC rates were found to decrease with an increase in the pH value due to the increased availability of H+ ions. The highest CO2 erosion–corrosion rates were observed at a 45° impingement angle in the presence of solid particles under all conditions. It was also observed that a change in pH value influenced the morphology and corrosion resistance of the corrosion scales.

Velocity Guidelines for Avoiding Erosion-Corrosion Damage in Sweet Production With Sand

1998 ◽  
Vol 120 (1) ◽  
pp. 78-83 ◽  
Author(s):  
J. R. Shadley ◽  
E. F. Rybicki ◽  
S. A. Shirazi ◽  
E. Dayalan
Keyword(s):  
Carbon Steel ◽  
Oil And Gas ◽  
Corrosion Damage ◽  
Gas Production ◽  
Metal Loss ◽  
Co2 Corrosion ◽  
Oil And Gas Production ◽  
Erosion Corrosion ◽  
Steel Piping ◽  
Loss Rates

CO2 corrosion in carbon steel piping systems can be severe depending on a number of factors including CO2 content, water chemistry, temperature, and percent water cut. For many oil and gas production conditions, corrosion products can form a protective scale on interior surfaces of the piping. In these situations, metal loss rates can reduce to below design allowances. But, if sand is entrained in the flow, sand particles impinging on pipe surfaces can remove the scale or prevent it from forming at localized areas of particle impingement. This process is referred to as “erosion-corrosion” and can lead to high metal loss rates. In some cases, penetration rates can be extremely high due to pitting. This paper combines laboratory test data on erosion-corrosion with an erosion prediction computational model to compute flow velocity limits (“threshold velocities”) for avoiding erosion-corrosion in carbon steel piping. Also discussed is how threshold velocities can be shifted upward by using a corrosion inhibitor.

scholarly journals The inhibition performance of mono-ethylene glycol on corrosion rate of x-80 grade carbon steel in saturated brine environment.

2020 ◽  
Vol 1 (1) ◽  
Keyword(s):  
Acetic Acid ◽  
Charge Transfer ◽  
Carbon Steel ◽  
Corrosion Rate ◽  
Ethylene Glycol ◽  
Oil And Gas ◽  
Gas Production ◽  
Electrochemical Measurements ◽  
Co2 Corrosion ◽  
Formation Water

The formation/deposition of hydrate and scale in gas production and transportation pipeline has continue to be a major challenge in the oil and gas industry. Pipeline transport is one of the most efficient, reliable and safer means of transporting petroleum products from the well sites to either the refineries or to the final destinations. Acetic acid (HAc), is formed in the formation water which also present in oil and gas production and transportation processes. Acetic acid aids corrosion in pipelines and in turn aids the formation and deposition of scales which may eventually choke off flow. Most times, Monethylene Glycol (MEG) is added into the pipeline as an antifreeze and anticorrosion agent. Some laboratory experiments have shown that the MEG needs to be separated from unwanted substance such as HAc that are present in the formation water to avoid critical conditions in the pipeline. Internal pipeline corrosion slows and decreases the production of oil and gas when associated with free water and reacts with CO2 and organic acid by lowering the integrity of the pipe. In this study, the effect of Mono-Ethylene Glycol (MEG) and Acetic acid (HAc) on the corrosion rate of X-80 grade carbon steel in CO2 saturated brine were evaluated at 25oC and 80oC using 3.5% NaCl solution in a semi-circulation flow loop set up. Weight loss and electrochemical measurements using the linear polarization resistance (LPR) and electrochemical impedance spectroscope (EIS) were used in measuring the corrosion rate as a function of HAc and MEG concentrations. The results obtained so far shows an average corrosion rate increases from 0.5 to 1.8 mm/yr at 25oC, and from 1.2 to 3.5 mm/yr at 80oC in the presence of HAc. However, there are decrease in corrosion rate from 1.8 to 0.95 mm/yr and from 3.5 to 1.6mm/yr respectively at 25oC and 80oC on addition of 20% and 80% MEG concentrations to the solution. It is also noted that the charge transfer with the electrochemical measurements (EIS) results is the main corrosion controlling mechanism under the test conditions. The higher temperature led to faster film dissolution and higher corrosion rate in the presence of HAc. The EIS results also indicate that the charge transfer controlled behaviour was as a result of iron carbonate layer accelerated by the addition of different concentrations of MEG to the system. Key words: CO2 corrosion, Carbon steel, MEG, HAc, Inhibition, Environment.

scholarly journals Corrosion Investigation of Commercially Available Linepipe Steel in CO2 Environment

2018 ◽  
Vol 7 (3.32) ◽  
pp. 15
Author(s):  
Muhammad Haris ◽  
Saeid Kakooei ◽  
Mokhtar Che Ismail
Keyword(s):  
Carbon Steel ◽  
Corrosion Rate ◽  
Oil And Gas ◽  
Corrosion Behaviour ◽  
Complex Problem ◽  
Gas Production ◽  
Co2 Corrosion ◽  
Oil And Gas Production ◽  
The Difference ◽  
Co2 Environment

CO2 corrosion has been the most prevalent form of corrosion and is considered as a complex problem in oil and gas production industries. The CO2 in presence of water causes sweet corrosion that is responsible for failure of pipeline during transportation of Oil and Gas. This work studies the corrosion behaviour of carbon steel specimens in CO2 environment at different temperatures but at constant pressure. The effect of CO2 on Carbon Steel specimens (X65, A106) were studied in simulated solution of 3 wt.% NaCl. The specimens were immersed into the CO2 containing solution for 48 hours and corrosion behaviour was investigated by using electrochemical test like Linear Polarization Resistance and Tafel plot. The results indicate that the temperature has an important effect of corrosion rate of carbon Steel in CO2 environment. Corrosion rate of 1.5-2 mm/yr was reported for both steels at lower temperature while at higher temperature the difference can be observed due to difference in protective nature of steels. Similar Corrosion rate around 1.5 -2 mm/yr was observed at 25°C for both A106 and X65 while at 50°C and 75°C the corrosion rate varies significantly 1.5-3 mm/yr and 3.5-6 mm/yr.  

Erosion-Corrosion of a Carbon Steel Elbow in a Natural Gas Gathering Pipeline

2018 ◽  
Author(s):  
Wei Wu ◽  
Qiao Qiao ◽  
Guangxu Cheng ◽  
Tinggang Pei ◽  
Yun Li ◽  
...  
Keyword(s):  
Carbon Steel ◽  
Natural Gas ◽  
Solid Particles ◽  
Co2 Corrosion ◽  
Composition Analysis ◽  
Internal Diameter ◽  
General Corrosion ◽  
Metallographic Examination ◽  
Corrosion Failure ◽  
Erosion Corrosion

A failed carbon steel elbow from a natural gas gathering pipeline in a gas field in Northeast China was investigated by macroscopic and microscopic examinations, chemical composition analysis, metallographic examination, and numerical simulation methods. The investigation results show that the intrados of the elbow was subject to slight general corrosion, while the extrados suffered from severe localized corrosion. The damage of the elbow resulted from an erosion-corrosion in the natural gas containing a few amount of corrosive impurities, liquid water, and solid particles. The impurities in the natural gas, specifically CO2 and chlorides, would be dissolved into water droplets in the natural gas. These corrosive droplets reacted with the pipe metal, resulting in typical CO2 corrosion of carbon steel pipe. Furthermore, the droplets and solid particles in the gas would destroy the protectiveness of the corrosion product film on the intrados by mechanical erosion, finally leading to the deterioration of the local environment and then the acceleration of corrosion failure. For controlling corrosion, some measures should be given. However, considering the difficulty of the increase in the curvature radius or the internal diameter of the pipeline, increasing wall thickness of the elbow pipe was a relatively feasible measure to mitigate the erosion-corrosion of the pipe.

Characterization and Prediction of Chemical Inhibition Performance for Erosion-Corrosion Conditions in Sweet Oil and Gas Production

CORROSION ◽  
10.5006/0546 ◽  
2012 ◽  
Vol 68 (10) ◽  
pp. 885-896 ◽  
Author(s):  
Sh. Hassani ◽  
K.P. Roberts ◽  
S.A. Shirazi ◽  
J.R. Shadley ◽  
E.F. Rybicki ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Erosion Corrosion ◽  
Chemical Inhibition ◽  
Inhibition Performance

scholarly journals An Erosion-Corrosion Investigation of Coated Steel for Applications in the Oil and Gas Field, Based on Bipolar Electrochemistry

Coatings ◽  
2020 ◽  
Vol 10 (2) ◽  
pp. 92
Author(s):  
Claudio Mele ◽  
Francesca Lionetto ◽  
Benedetto Bozzini
Keyword(s):  
Oil And Gas ◽  
Electroless Nickel ◽  
Solid Particles ◽  
Bipolar Electrode ◽  
Experimental Conditions ◽  
Gas Field ◽  
Experimental Apparatus ◽  
Erosion Corrosion ◽  
Oil And Gas Field ◽  
Sprayed Coating

In this research, a simple experimental apparatus based on a bipolar electrode (BPE) configuration was set up, in order to tackle erosion-corrosion problems of materials of interest in the oil and gas field. As a case study, the resistance to erosion and corrosion of carbon steel samples coated by Electroless Nickel Plating and by thermo-sprayed coating with the high velocity oxy fuel (HVOF) process was investigated. The main objective was to demonstrate if this simple, contactless technique could be applied to effectively discriminate the erosion-corrosion behavior of different materials in a vast range of experimental conditions. In fact, by means of polarization curves, visual inspection and morphological analysis by scanning electron microscope (SEM), the effects due to erosion-corrosion by solid particles, by fluid and those due to simple erosion were evaluated.

Ultrasonic Measurement of Multiphase Flow Erosion Patterns in a Standard Elbow

2012 ◽  
Author(s):  
N. R. Kesana ◽  
S. A. Grubb ◽  
B. S. McLaury ◽  
S. A. Shirazi
Keyword(s):  
Multiphase Flow ◽  
Oil And Gas ◽  
Particle Diameter ◽  
Gas Production ◽  
Solid Particles ◽  
Economic Losses ◽  
Metal Loss ◽  
Straight Pipe ◽  
Non Invasive ◽  
Good Agreement

Solid particle erosion is a mechanical process in which material is removed from a surface due to impacts of solid particles transported within a fluid. It is a common problem faced by the petroleum industry, as solid particles are also produced along with oil and gas. The erosion not only causes economic losses resulting from repairs and decreased production but also causes safety and environmental concerns. Therefore, the metal losses occurring in different multiphase flow regimes need to be studied and understood in order to develop protective guidelines for oil and gas production equipment. In the current study, a novel non-invasive ultrasonic (UT) device has been developed and implemented to measure the metal loss at 16 different locations inside an elbow. Initially, experiments were performed with a single-phase carrier fluid (gas-sand) moving in the pipeline, and the erosion magnitudes are compared with Computational Fluid Dynamics (CFD) results and found to be in good agreement. Next, experiments were extended to the multiphase slug flow regime. Influence of particle diameter and liquid viscosity were also studied. Two different particle sizes (150 and 300 micron sand) were used for performing tests. The shapes of the sand are also different with the 300 micron sand being sharper than the 150 micron sand. Three different liquid viscosities were used for the present study (1 cP, 10 cP and 40 cP). Carboxymethyl Cellulose (CMC) was used to increase the viscosity of the liquid without significantly altering the density of the liquid. While performing the UT experiments, simultaneous metal loss measurements were also made using an intrusive Electrical Resistance (ER) probe in a section of straight pipe. The probe in the straight pipe is an angle-head probe which protrudes into the flow with the face placed in the center of the pipe. The UT erosion measurements in a bend are also compared with experimental data obtained placing an intrusive flat head ER probe flush in a bend, and the results were found to be in good agreement. Finally, the non-invasive NanoUT permanent placement temperature compensated ultrasonic wall thickness device developed for this work has the capability of measuring metal loss at many locations and also identifying the maximum erosive location on the pipe bend.

Inspection of Clad and Plain Carbon Steel Girth Welds on Offshore Caisson Risers Using Semi-Mechanised Ultrasonic Testing (SMUT)

2008 ◽  
Author(s):  
Robert J. Conder ◽  
Ryan McPherson ◽  
Ton Kooren ◽  
Allan Parlane
Keyword(s):  
Carbon Steel ◽  
Oil And Gas ◽  
Plain Carbon Steel ◽  
Gas Production ◽  
Carbon Steels ◽  
Inconel 625 ◽  
Inspection System ◽  
Oil And Gas Production ◽  
The North ◽  
Girth Welds

Caisson risers installed through drilling slots are an increasingly common method to add additional riser access to existing oil and gas production platforms. This paper describes the inspection methodology used for two new caisson risers on the Talisman Energy owned Tartan platform in the North Sea. The methodology for qualification of the inspection system for both plain carbon steels and Inconel 625 (UNS N06625) clad carbon steel is described. The offshore performance of the SMUT system is discussed and the time and safety benefits of this system are highlighted.

Sign in / Sign up

Export Citation Format

Share Document