Strategic Pressure Management Strategies in Producing Wells to Offset Adverse Production Impact During Pigging Operations

Abstract

Maintenance and inspection pigging are indispensable to sustain flow assurance and integrity in oil and gas gathering systems, but the same operations can introduce substantial transient risks in terms of backpressure in both facilities and wells, adversely affecting overall liquid drawdown. The compaction of distributed liquid holdup into a pig‑generated slug, coupled at times with riser or terrain instabilities, drives short‑duration surges in surface facilities that usually force production throttling and trigger trips of process equipment's. At downhole, the temporary rise in arrival pressure during pig transit reduces drawdown and production rates; in low‑pressure gas or brownfield reservoirs, even modest backpressure changes can materially depress deliverability. Field reports demonstrate that high‑resolution pressure surveillance can be used to detect the distinctive patterns that precede slugging and to optimize pig sequence and timing; in one gas gathering system this approach sustained a 20% production increase on a problematic branch by lowering line‑pack pressure through pigging optimization [1]. Furthermore, bypass‑pigging solutions have been shown to reduce slug volume and backpressure at receiving facilities by allowing a controlled gas flow around the pig and by lowering the pig velocity [2]. For complex reservoir fields, OLGA‑benchmarked transient models have successfully predicted pig velocity, pig arrival time, and have been used to revise operating envelopes that both protect facilities and maximize post‑pig throughput [3], while integrated transient field network models have identified and mitigated surging flow regimes interactions across many wells [4]. Choke management under constraints provides the optimum drawdown, sanding, and velocity into time‑dependent choke schedules, in which operators can stabilize wellbore conditions during pigging disturbances and avoid rate fluctuations due to the backpressure caused from pigging operations [5–7]. This paper synthesizes these learnings into a practical pressure management workflow focusing on preparing, predicting, protecting, and protecting linking well choke policies, bypass‑pig configuration, speed control, topside backpressure strategy, and surveillance driven operations. This paper provides decision rules and a choke‑beaning template mapped to facility limits, summarize literature results in curated tables, and discuss economics, HSE, and implementation details. The strategy enables operators to offset adverse production impact during pigging without compromising cleaning and integrity objectives, and it is applicable to both onshore gathering networks and offshore tiebacks where pigging‑induced slugging and backpressure are recurring threats [1–3,5,8,10–12].