高产水气井井筒压损大，开发时压力降低会引发井筒中液滴回落聚集形成段塞流，导致井筒压降增大、井底流压升高、生产压差及产气量降低，最终造成水淹停产。泡排、柱塞等常规工艺无法满足高产水气井长期稳定排液需求。为此，研发高产水气井自适应智能排采工艺：以气液两相流型图版为指导，利用井下气液分离器、分配器合理分配地层产出的气液，使井筒气液流速维持在环雾流范围，避免液体回落形成段塞流，实现井筒环雾流稳定排液；配套设计防冻堵系统和气液管理平台保障工艺高效运行；建立智能控制系统，实时监控气井生产状态并动态优化产气产液量配比。选取东胜气田Q1井开展工艺应用评价，结果显示：该工艺实施后，平均日产气6 456 m³，较实施前增产15.9%；日产液2.64 m³，生产时率从95.3%提升至100%，压力监测显示井筒无积液。连续运行6个月，有效替代泡排工艺和气举辅助排液措施。与试验前相比，泡排剂用量和气举次数减少，成本降低了50.72万元。这验证了该技术的有效性和经济性，解决了高含水气井积液周期短、稳产难的问题，对储层产能释放、气井智能化管控及全生命周期长效排水采气具有重要意义。

High-water-production gas wells experience significant wellbore pressure loss. During production, pressure decline can cause the liquid droplets in the wellbore to fall back and accumulate, forming slug flow. This leads to increased wellbore pressure drop, elevated bottomhole flowing pressure, and reduced production differential pressure and gas production, ultimately resulting in water flooding and production stoppage. Conventional processes such as foam drainage and plunger lift fail to meet the long-term stable drainage requirements of high-water-production gas wells. To this end, an adaptive intelligent drainage and production process for high-water-production gas wells was designed and developed. Guided by the gas-liquid two-phase flow pattern diagram, the downhole gas-liquid separator and distributor were used to reasonably distribute the gas and liquid produced in the formation in the wellbore, maintaining the wellbore gas and liquid flow velocity within the range of annular mist flow. This prevented liquid fallback and slug flow formation, thereby ensuring stable annular-mist flow drainage in the wellbore. An anti-freezing and blocking system and a gas-liquid management platform were designed to ensure the efficient operation of the process. Additionally, an intelligent control system was established to monitor the production status of gas wells in real time and dynamically optimize the gas-liquid production ratio. Well Q1 in Dongsheng gasfield was selected as the experimental well for process application evaluation. The results showed that after the implementation of this process, the average daily gas production was 6 456 m³, an increase of 15.9% compared to that before implementation, and the daily liquid production was 2.64 m³. The production uptime rate increased from 95.3% to 100%, and the pressure monitoring indicated no liquid accumulation in the wellbore. After continuous operation for six months, the process effectively replaced the foam drainage process and gas lift auxiliary drainage measures. Compared with the period before the experiment, the amount of foam drainage agent and gas lift frequency were reduced, resulting in a cost saving of 507 200 yuan. These findings demonstrate the effectiveness and economic efficiency of the proposed technology. This study solves the problems of short liquid accumulation cycle and difficulty in maintaining stable production in high-water-production gas wells. It holds significant implications for reservoir production capacity enhancement, intelligent control of gas wells, and long-term efficient drainage and gas production throughout the entire life cycle.