The ultra-deep Shunbei Oil and Gas Field in Tarim Basin in China is characterized by ultra-high temperature, ultra-high pressure, high H2S content, and moderate CO2 content. The formation depth reaches 8000 m, mainly consisting of oil reservoirs, volatile oil reservoirs, and gas reservoirs. Gas lift and flooding are major measures deployed for enhancing oil recovery in Shunbei Field, during which the tubing corrosion emerges as a challenge, reducing the development efficiency. Therefore, an experimental evaluation of the tubing corrosion has been conducted in response to the corrosion conditions in strip regions #1, #4, and #5 in Shunbei Field. Experimental results show that the tubing in the nitrogen gas lift conditions all exhibit slight corrosion, but this can still meet the service requirements of the tubing. Under the nitrogen gas huff and puff conditions, the corrosion rate of the steel gradually increases with the rising temperature. Under the condition of water alternating gas injection, the steel corrosion rate is around 0.8 mm/a, which cannot meet the long-term service requirements. Through grey relational analysis of the factors affecting corrosion, the influence order of each factor derived is: temperature > oxygen content > pressure. Therefore, special attention and regular corrosion inspections should be carried out for the pump hanging section at high temperatures in the wells. This study provides important guidance for the corrosion control for nitrogen gas injection operations in Shunbei Oil and Gas Field.