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.

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 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.  

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.

Phase Stability and Inhibition of Calcium Sulfate in the System NaCl/Monoethylene Glycol/H2O

SPE Journal ◽  
2011 ◽  
Vol 17 (01) ◽  
pp. 187-197 ◽  
Author(s):  
Haiping Lu ◽  
Kan Amy T ◽  
Ping Zhang ◽  
Jie Yu ◽  
Chunfang Fan ◽  
...  
Keyword(s):  
Phase Transition ◽  
Phase Behavior ◽  
Calcium Sulfate ◽  
Oil And Gas ◽  
Gas Production ◽  
Inhibition Mechanism ◽  
Oil And Gas Production ◽  
Prediction And Prevention ◽  
Monoethylene Glycol ◽  
Kinetics Of

Summary Calcium sulfate is one of the major mineral scales in oil and gas production. Hemihydrate (CaSO4·0.5H2O) and anhydrite (CaSO4) are the predominant sulfate scales formed at high temperature, while gypsum (CaSO4·2H2O) scale may form at low temperatures (<~45°C). However, it has been shown in this study that anhydrite can form at low temperature in the presence of excess amounts of monoethylene glycol (MEG), and this may occur during offshore production with long tie-backs. The prediction and prevention of calcium sulfate scales requires knowledge of the phase behavior of the three major phases of calcium sulfate. The phase behavior of different calcium sulfate phases is related to the supersaturation state, temperature, and fugacity of water. In this study, the effect of a common hydrate inhibitor, MEG, on calcium sulfate solubility and phase behavior was investigated. This study was run with NaCl/CaSO4/MEG/H2O solutions at 0–6 molality (M) NaCl and 0–95 wt% MEG at 4–70°C. Three approaches were taken to determine the kinetics of calcium sulfate phase transition at various temperatures, ionic strengths, and MEG concentrations: (1) dissolution of gypsum, (2) dissolution of anhydrite, and (3) nucleation and precipitation of calcium sulfate by mixing calcium- and sulfate-containing solutions. The effect of scale inhibitors on phase transition was also evaluated. Phase transition of gypsum to anhydrite was observed in the presence of high concentrations of NaCl and MEG, regardless of the experimental approach. The transition boundary of temperature and concentrations of NaCl and MEG can be estimated from solubility of calcium sulfate and the fugacity of water. The inhibition mechanism of hexamethylene diamine tetra (methylene phosphonic acid) (HDTMP), one of the most effective inhibitors for calcium sulfate scale, was also tested by investigating the kinetics of precipitation and inhibition of calcium sulfate.

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