scholarly journals EFFECT OF İNORGANİC COMPLEXES OF İMİDAZOLİNE BASED ON SYNTHETİC PETROLEUM ACİDS AND TRİETHYLENTETRAMİN AGAİNST CARBON DIOXIDE CORROSİON

2017 ◽  
Vol 15 (4) ◽  
pp. 364-369
Author(s):  
V.M. Abbasov ◽  
◽  
E.H. Mamadbayli ◽  
D.B. Agamaliyeva ◽  
L.A. Mahmudova ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Carbon Dioxide Corrosion ◽  
Inorganic Complexes

Hazard Assessment of the Internal Carbon Dioxide Corrosion of the Field Pipelines at the Gas and Gas Condensate Fields

2021 ◽  
pp. 56-62
Author(s):  
R.R. Kantyukov ◽  
◽  
D.N. Zapevalov ◽  
R.K. Vagapov ◽  
◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Gas Condensate ◽  
Design Stage ◽  
Carbon Dioxide Corrosion ◽  
Safe Operation ◽  
Internal Corrosion ◽  
Operating Environments ◽  
Facilities Design ◽  
Equipment And Pipelines ◽  
Intensive Development

At many gas and gas condensate fields in operation, carbon dioxide (СО2) is present in the scope of the produced products, which, in combination with the natural and technological factors, stimulates intensive development of the internal corrosion processes in the pipelines and equipment. The relevance of the development of native regulatory documentation aimed at the assessment of the corrosion effects and development of the practical recommendations for protection against carbon dioxide corrosion in the last decade is due to the development of new gas fields in Russia with a high CO2 content (including on the Russian offshore), where there is a risk of local corrosion development with a high flow rate. The presence of CO2 in the produced gas in combination with the moisture and other factors stimulates the intensive development of corrosion processes and requires careful attention to the assessment of the corrosion aggressiveness of operating environments for selecting an efficient anti-corrosion protection. This is required to ensure reliable and safe operation of the equipment and pipelines made of carbon steel. Pipe low-alloy steel of 09G2S (09Mn2Si) grade, which is the most widely used at the domestic gas facilities, is not resistant to carbon dioxide corrosion. The experience of operating foreign deposits under conditions of carbon dioxide corrosion confirms the need and efficiency of considering this corrosion aspect at the facilities design stage. Incorrect assessment and underestimation of CO2 hazard in the produced hydrocarbons in relation to steel equipment and pipelines can lead to unaccounted corrosion risks (up to the facility shutdown), significant costs for the elimination of corrosion consequences (repairs, etc.), and the need to select and justify urgent corrective measures. Accounting the Russian and international experience allows to make a reasonable choice of rational technical solutions for efficient and safe operation of the deposits in conditions of carbon dioxide corrosion.

scholarly journals Effect of shear stress on the wall of technological pipelines at a gas condensate field on the intensity of carbon dioxide corrosion

2020 ◽  
Vol 244 ◽  
pp. 439-447
Author(s):  
Aleksandr Ponomarev ◽  
Aleksandr Yusupov
Keyword(s):  
Carbon Dioxide ◽  
Shear Stress ◽  
Flow Velocity ◽  
Three Dimensional ◽  
Gas Condensate ◽  
Carbon Dioxide Corrosion ◽  
Area Of Interest ◽  
Corrosion Intensity ◽  
Rational Operation ◽  
The Impact

The object of the study is a section of the gas and gas condensate collection system, consisting of an angle throttle installed on a xmas tree and a well piping located after the angle throttle. The aim of the study is to assess the impact of the flow velocity and wall shear stress (WSS) on the carbon dioxide corrosion rate in the area of interest and to come up with substantiated recommendations for the rational operation of the angle throttle in order to reduce the corrosion intensity. In the course of solving this problem, a technique was developed and subsequently applied to assess the influence of various factors on the rate of carbon dioxide corrosion. The technique is based on a sequence of different modeling methods: modeling the phase states of the extracted product, three-dimensional (solid) modeling of the investigated section, hydrodynamic flow modeling of the extracted product using the finite volume method, etc. The developed technique has broad possibilities for visualization of the obtained results, which allow identifying the sections most susceptible to the effects of carbon dioxide corrosion. The article shows that the average flow velocity and its local values are not the factors by which it is possible to predict the occurrence of carbon dioxide corrosion in the pipeline section after the angle throttle. The paper proves that WSS has prevailing effect on the corrosion intensity in the section after the angle choke. The zones of corrosion localization predicted according to the technique are compared with the real picture of corrosion propagation on the inner surface of the pipe, as a result of which recommendations for the rational operation of the angle throttle are formed.

Study of the effect of test parameters on the assessment of steel resistance to carbon dioxide corrosion

2021 ◽  
Vol 87 (12) ◽  
pp. 36-41
Author(s):  
A. S. Fedorov ◽  
E. L. Alekseeva ◽  
A. A. Alkhimenko ◽  
N. O. Shaposhnikov ◽  
M. A. Kovalev
Keyword(s):  
Carbon Dioxide ◽  
Laboratory Tests ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Sample Surface ◽  
Test Results ◽  
Carbon Dioxide Corrosion ◽  
Gas Industry ◽  
Test Parameters ◽  
Repeatability And Reproducibility

Carbon dioxide (CO2) corrosion is one of the most dangerous types of destruction of metal products in the oil and gas industry. The field steel pipelines and tubing run the highest risk. Laboratory tests are carried out to assess the resistance of steels to carbon dioxide corrosion. However, unified requirements for certain test parameters are currently absent in the regulatory documentation. We present the results of studying the effect of the parameters of laboratory tests on the assessment of the resistance of steels to CO2 corrosion. It is shown that change in the parameters of CO2 concentration, chemical composition of the water/brine system, the buffer properties and pH, the roughness of the sample surface, etc., even in the framework of the same laboratory technique, can lead in different test results. The main contribution to the repeatability and reproducibility of test results is made by the concentration of CO2, pH of the water/brine system, and surface roughness of the samples. The results obtained can be used in developing recommendations for the choice of test parameters to ensure a satisfactory convergence of the results gained in different laboratories, as well as in elaborating of a unified method for assessing the resistance of steels to carbon dioxide corrosion.

scholarly journals Flow Dependence of Carbon Dioxide Corrosion Using Short Electrodes by Jet Impingement

CORROSION ◽  
2009 ◽  
Vol 65 (12) ◽  
pp. 771-777 ◽  
Author(s):  
D. John ◽  
B. Kinsella ◽  
S. Bailey ◽  
R. De Marco
Keyword(s):  
Carbon Dioxide ◽  
Jet Impingement ◽  
Carbon Dioxide Corrosion ◽  
Flow Dependence

Electrochemical Investigation of the Role of Cl−on Localized Carbon Dioxide Corrosion Behavior of Mild Steel

CORROSION ◽  
10.5006/0620 ◽  
2013 ◽  
Vol 69 (1) ◽  
pp. 15-24 ◽  
Author(s):  
X. Jiang ◽  
S. Nešić ◽  
B. Kinsella ◽  
B. Brown ◽  
D. Young
Keyword(s):  
Carbon Dioxide ◽  
Mild Steel ◽  
Corrosion Behavior ◽  
Carbon Dioxide Corrosion ◽  
Electrochemical Investigation

Evaluation of Carbon Dioxide Corrosion on N80 Steel

2014 ◽  
Vol 490-491 ◽  
pp. 311-314
Author(s):  
Zhen Zhong Fan ◽  
An Qi Tong ◽  
Yan Cui ◽  
Jun Feng Yang
Keyword(s):  
Carbon Dioxide ◽  
Liquid Phase ◽  
Corrosion Rate ◽  
Partial Pressure ◽  
Gas Phase ◽  
Test Temperature ◽  
Microscopic Analysis ◽  
Carbon Dioxide Corrosion ◽  
Large White ◽  
N80 Steel

The carbon dioxide corrosion on N80 steel was evaluated under the gas phase and the liquid phase. With the test temperature improved, the corrosion rate increases. Under the condition of gas phase, the corrosion peak is 0.2942mm/a when the temperature is 110°C and pressure is 24 MPa. Under the condition of liquid phase, the corrosion peak is 26.5325mm/a when the temperature is 50°C and pressure is 24 MPa. With the increase of CO2 partial pressure, the corrosion rate of N80 steel was falling. Microscopic analysis shows that the corrosion products of CO2 on N80 steel have a large white flocculent compounds and the corrosion surface have a lot of cracks and holes.

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