scholarly journals Corrosion-resistant systems of formate packer fluid for G3/N80/TP110SS pipes at high temperature, high pressure and high H 2 S/CO 2 ratios

2018 ◽  
Vol 5 (7) ◽  
pp. 180405 ◽  
Author(s):  
Peng Xu ◽  
Zhengwu Tao ◽  
Zhihong Wang
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Corrosion Rate ◽  
Corrosion Protection ◽  
High Pressures ◽  
Gas Production ◽  
Corrosion Mechanism ◽  
Acid Gas ◽  
High Acid ◽  
High Temperature High Pressure

A series of corrosion problems caused by high-temperature, high-pressure and high-acid gas environments has been an issue in oil and gas production for a long time. During the development of a high-acid gas field, the petroleum pipe is subjected to many aspects of corrosion, and the corrosion mechanism is complicated by the condition of the coexistence of H 2 S/CO 2 . Based on the study of the corrosion problem associated with the formate packer fluid in Southwest China, three kinds of steels were studied for corrosion prevention in the alloy G3/N80 steel/TP110SS steel. The study shows that the corrosion rate of the formate packer fluid is low, but corrosion is severe in environments characterized by high temperatures, high pressures and high-acid gas contents. Based on the consideration of cost and the difficulty of realization, an anti-corrosion system was constructed based on the existing packer fluid, mainly through the introduction of a variety of anti-corrosion additives. Through the selection of various additives and corrosion experiments, a corrosion protection system of formate packer fluid was developed. Corrosion tests show that the corrosion rate of the system must be less than 0.076 mm yr −1 to achieve the purpose of corrosion protection. The formate packer fluid with corrosion protection can meet the needs of the current application.

Analysis on Casing Size and Steel Grade and Application in High-Temperature High-Pressure Gas Wells

2013 ◽  
Vol 703 ◽  
pp. 143-146
Author(s):  
Ling Feng Li
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Natural Gas ◽  
Gas Production ◽  
Steel Grade ◽  
Production Engineering ◽  
Gas Wells ◽  
Gas Well ◽  
Size Series ◽  
High Temperature High Pressure

Analysis on casing size and steel grade and application in high-temperature high-pressure gas wells are important in natural gas production engineering. This paper presents the standard casing size series, casing steel grade standard and code, types of casing steel grade, main problems in high-temperature high-pressure gas wells, using casing material suitable as solving means for high-temperature high-pressure gas well and application. For application, the study above is good and easy for on-the-spot application.

Engineering Corrosion Protection in High Temperature High Pressure Sour Gas Wells

2015 ◽  
Author(s):  
Sunder Ramachandran ◽  
Ghaithan A. Al-Muntasheri ◽  
Hasan Al-Ajwad ◽  
Anuj Gupta ◽  
Jairo Leal ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Corrosion Protection ◽  
Gas Wells ◽  
High Temperature High Pressure ◽  
Sour Gas

Scale Prediction and Inhibition for Oil and Gas Production at High Temperature/High Pressure

SPE Journal ◽  
2012 ◽  
Vol 17 (02) ◽  
pp. 379-392 ◽  
Author(s):  
Chunfang Fan ◽  
Amy T. Kan ◽  
Ping Zhang ◽  
Haiping Lu ◽  
Sarah Work ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
High Temperatures ◽  
Oil And Gas ◽  
Gas Production ◽  
Scale Formation ◽  
Oil And Gas Production ◽  
Scale Inhibition ◽  
Kinetics Of ◽  
High Temperature High Pressure

Summary With the advance of new exploration and production technologies, oil and gas production has gone to deeper and tighter formations than ever before. These developments have also brought challenges in scale prediction and inhibition, such as the prevention of scale formation at high temperatures (150–200°C), pressures (1,000–1,500 bar), and total dissolved solids (TDS) (>300,000 mg/L) commonly experienced at these depths. This paper will discuss (1) the challenges of scale prediction at high temperatures, pressures, and TDS; (2) an efficient method to study the nucleation kinetics of scale formation and inhibition at these conditions; and (3) the kinetics of barite-crystal nucleation and precipitation in the presence of various scale inhibitors and the effectiveness of those inhibitors. In this study, nine scale inhibitors have been evaluated at 70–200°C to determine if they can successfully prevent barite precipitation. The results show that only a few inhibitors can effectively inhibit barite formation at 200°C. Although it is commonly believed that phosphonate scale inhibitors may not work for high-temperature inhibition applications, the results from this study suggest that barite-scale inhibition by phosphonate inhibitors was not impaired at 200°C under strictly anoxic condition in NaCl brine. However, phosphonate inhibitors can precipitate with Ca2+ at high temperatures and, hence, can reduce efficiency. In addition, the relationships of scale inhibition to types of inhibitors and temperature are explored in this study. This paper addresses the limits of the current predition of mineral solubility at high-temperature/high-pressure (HT/HP) conditions and sheds light on inhibitior selection for HT/HP application. The findings from this paper can be used as guidelines for applications in an HT/HP oilfield environment.

Effect of CO2 on Anti-Corrosion Property of a Polyurea Coating Modified with Organosilicone

2014 ◽  
Vol 789 ◽  
pp. 466-470
Author(s):  
Qing Hao Shi ◽  
Bing Ying Wang ◽  
Bin Zhao
Keyword(s):  
High Temperature ◽  
Partial Pressure ◽  
Composite Coating ◽  
Corrosion Test ◽  
Electrochemical Impedance ◽  
Failure Process ◽  
Corrosion Property ◽  
Corrosion Mechanism ◽  
Partial Pressures ◽  
High Temperature High Pressure

The corrosion mechanism of organic silicon modified polyurea composite coating under different CO2 partial pressures was studied using high-temperature autoclave, combined with scanning electron microscopy (SEM), adhesion tests and electrochemical impedance spectroscopy (EIS) technology. The experimental results showed that: there was no corrosion product formed on the surface of coating sample after high-temperature high-pressure corrosion test, and with the increasing of CO2 partial pressure, the coating adhesion and impedance values decline increases. Moreover CO2 partial pressure increases accelerated the failure process of polyurea composite coating system.

Homogeneous carbon doping of magnesium diboride by high-temperature, high-pressure synthesis

2014 ◽  
Vol 104 (16) ◽  
pp. 162603 ◽  
Author(s):  
M. A. Susner ◽  
S. D. Bohnenstiehl ◽  
S. A. Dregia ◽  
M. D. Sumption ◽  
Y. Yang ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Magnesium Diboride ◽  
Carbon Doping ◽  
High Pressure Synthesis ◽  
Pressure Synthesis ◽  
High Temperature High Pressure

High temperature-high pressure synthesis of a new phase of LaCuO3

1989 ◽  
Vol 137 (4-5) ◽  
pp. 205-206 ◽  
Author(s):  
A.W. Webb ◽  
E.F. Skelton ◽  
S.B. Qadri ◽  
E.R. Carpenter ◽  
M.S. Osofsky ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
High Pressure Synthesis ◽  
Pressure Synthesis ◽  
New Phase ◽  
High Temperature High Pressure
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