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Injection of hydrocarbon gas is a common practice to enhance production rates from multiphase wells in the Oil and Gas industry. The gas used is normally dehydrated by a combination of compression and chemical treatments to reach a given dew point specification. The dry non-corrosive gas is injected to the production annulus and enters the production bore via a gas lift valve (GLV) located on the production tubing above the production packer.
Gas lift, utilizing the injection of high-pressure gas via well production annuli and into the production bore through mandrels or valves, is a common artificial lift method in oil wells. Unexpected corrosion located in the annuli below the gas-lift valve was observed on several well completions and led to an investigation of its causes and deployment of alternative mitigation measures. The aggressiveness of the corrosion seen is not in line with industry experiences and prompted a need to better understand contributory factors. Unlike the often traditionally held belief that corrosion should be limited to the interface of the injected gas and packer fluid column; corrosion was seen to extend far beyond this area deep into the wells.
Investigations consisted of reviewing historical packer fluid treatments and well operating conditions, literature surveys, and metallurgical and scale analysis of the retrieved production tubing. In addition, microbiological analysis was undertaken to establish if a microbial influence was present. To substantiate findings a review of the Company’s gas lifted well stock and reported corrosion cases was undertaken.
This paper will describe that CO2 + H2S corrosion was identified as the main degradation mechanism and that the presence of glycol in the packer fluids exerted a crucial detrimental factor. A microbial influence could not be ruled out.
Chemical treatment test methods developed to establish the longevity of protection to be expected, and initial results from them, are described.
In 1950s, as an important measure to improve the corrosion resistance of base metal, internal coating pipes was first applied to sour crude oil and natural gas pipelines [1]. Among the coating systems, FBE coating has good impact resistance, bending resistance, high bonding strength, good resistance for acid, alkali, salt, oil and water fluid. The coating can reduce the internal surface roughness friction resistance of piping & pipeline to reduce project investment.
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At present, there were ten common crossing modes in long-distance oil and gas pipelines[1,2]. There were six ways of tunneling, such as large excavation, horizontal directional drilling, shield tunnel, drilling and blasting tunnel, ramming pipe and pipe jacking. There were four ways of spanning methods, such as truss crossing, arch bridge crossing, suspension cable crossing and cable-stayed bridge crossing. Crossing by shield tunneling, as a pipeline laying method with high mechanization and automation, extensive applicable strata and high safety, has been widely used in recent years.
Carbon capture, utilization and storage (CCUS) is one of the key technologies to achieve the net-zero emission. One of the CCUS method is CO2 injection to depleted oil and gas wells or aquifers and storage (CCS). The CO2 emitted from fossil fuel-based powers and industrial plants are captured and transported to the injection point by ships or pipe line. Following that, the dense phase or supercritical phase CO2 will be injected to depleted oil and gas wells or aquifers through oil country tubular goods, for examples, seamless pipe.