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

Evaluation of TG202 inhibitor for tubing steels in 15% hydrochloric acid by electrochemical noise technology

2021 ◽  
Author(s):  
Mi-feng Zhao ◽  
Juantao Zhang ◽  
Fangting Hu ◽  
Anqing Fu ◽  
Kelin Wang ◽  
...  
Keyword(s):  
Hydrochloric Acid ◽  
Corrosion Rate ◽  
Oil And Gas ◽  
Electrochemical Noise ◽  
Gas Production ◽  
Inhibition Mechanism ◽  
Oil And Gas Production ◽  
Effective Technology ◽  
Steel Tubing ◽  
Inhibition Performance

Abstract Acid fracturing is an effective technology for increasing oil and gas production. However, acid will cause serious corrosion to the tubing. In this paper, the inhibition performance of TG202 inhibitor for acidizing of high temperature and high pressure gas wells on N80 carbon steel and 13Cr martensitic stainless steel tubing in 15% hydrochloric acid was studied by electrochemical noise technology. The results showed that with the increase of TG202 inhibitor content, the noise resistance increased and the corrosion rate of tubing steel decreased. Under the same condition, the order of corrosion rate of tubing steels: 13Cr > HP-13Cr > N80 > P110. The pitting corrosion of HP-13Cr and 13Cr is significant. The research showed that TG202 inhibitor had a protective effect on tubing during acidizing. The inhibition mechanism of TG202 inhibitor was discussed.

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.

Synergistic Properties of Phosphonate and Polymeric Scale Inhibitor Blends for Barium Sulphate Scale Inhibition

2014 ◽  
Author(s):  
S.S.. S. Shaw ◽  
K.S.. S. Sorbie
Keyword(s):  
Oil And Gas ◽  
Production Systems ◽  
Barium Sulphate ◽  
Gas Production ◽  
Test Results ◽  
Oil And Gas Production ◽  
Scale Inhibition ◽  
Inhibition Performance ◽  
The Individual ◽  
Better Than

Abstract Barium sulphate is one of the most difficult types of scale to inhibit in oil and gas production systems, due to its physical hardness and its chemical and thermal stability. Barium sulphate is most commonly inhibited using either phosphonate or polymeric scale inhibitors (SIs) deployed at sub-stoichiometric concentrations. What is less well known in the oil industry is the effect of using combinations of two (or more) SIs synergistically for enhanced scale inhibition performance. A positive “synergistic” effect would be where, for example, 5ppm of A + 5ppm of B performed better than 10ppm of either A or B. In this paper, a series of static barium sulphate inhibition efficiency (IE) test results are presented, in which a series of pairs of SIs have been tested to determine their synergistic properties at pH 5.5 and 95°C. Polymers can be blended with phosphonates, or alternatively pairs of phosphonates or polymers may be applied. In all cases, the synergistic IE is compared with the IE of each SI tested independently at the mass dosage (i.e. the same concentration in mg/L or ppm). Each separate single SI used in the work has been tested previously for barium sulphate IE at pH 5.5, 95°C in order to determine the minimum inhibitor concentration (MIC) for each species (Shaw et al, 2012a, 2012b). Previously, 9 phosphonate and 9 polymeric SIs have been tested individually and, in this work, 34 SI combinations have been tested to examine their synergistic properties. The MICs of the synergistic blends are compared with the normal MICs of the individual SIs. Surprisingly, in most cases, the IE of the blends is usually higher over the range of SI concentrations tested (i.e. the MIC of the blend is lower), compared to that of each SI tested separately. Certain “pairs” of SIs used together yield a significantly beneficial effect, e.g. DETPMP and HMTPMP. Some mechanistic reasons why these synergistic pairs work particularly well are suggested.

scholarly journals Influence of O2 on the Erosion-Corrosion Performance of 3Cr Steels in CO2 Containing Environment

Materials ◽  
2020 ◽  
Vol 13 (3) ◽  
pp. 791 ◽  
Author(s):  
Lei Xia ◽  
Yan Li ◽  
Leilei Ma ◽  
Hongmei Zhang ◽  
Na Li ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Digital Camera ◽  
Gas Production ◽  
Corrosion Products ◽  
X Ray Diffraction ◽  
Oil And Gas Production ◽  
Corrosion Scale ◽  
Erosion Corrosion ◽  
Corrosion Scales ◽  
Energy Spectrometer

With the introduction of O2 during oil and gas production, the erosion-corrosion rate of tubing steels increases; the objective of this report is to explore the reason for this. Erosion–corrosion experiments were performed in environments of CO2 and CO2–O2, respectively. Macrographs, microstructures, and the compositions of erosion-corrosion scales were investigated using a digital camera, scanning electron microscope (SEM), Kevex-SuperDry energy spectrometer (EDS) and X-ray diffraction (XRD). The results show that the erosion-corrosion products are composed of large FeCO3 particles and some amorphous product in the CO2 environment, while they are made up of FeCO3, Fe2O3, Fe3O4, and bits of amorphous product in the CO2–O2 environment. The interface between erosion-corrosion scales and the substrate of 3Cr steel is smooth, and Cr enrichment obviously exists in the erosion-corrosion products in the CO2 condition. However, the erosion-corrosion scale is loose and porous with little Cr enrichment in the CO2–O2 environment, which makes the protectiveness of the erosion–corrosion scale weak, and pitting corrosion occurs. The addition of O2 may destroy the protective FeCO3 scale and Cr enrichment in the erosion-corrosion scale, which may be the main reason for the decline in the level of protectiveness of the erosion-corrosion scale, making it weak in terms of preventing the corrosive medium from diffusing to the substrate.

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