Reservoir Performance Analysis and Optimization: A Comprehensive OFM Approach

A: The hard boundary here is that ESD and HIPPS act on surface pressure and fire/gas signals, not on reverse flow paths at low differential pressure. A stuck-open gas lift check valve allows produced liquids to migrate into the lift gas system during a compressor trip, and neither ESD nor HIPPS reacts to that condition. Tubing overpressure is covered by PSHH logic, and platform-wide escalation is explicitly mitigated by ESD actions. Zonal crossflow is possible, but it depends on completion architecture rather than surface safeguards.

A: The breakpoint is the relative permeability crossover, not the surface liquid rate. As water cut rises, oil relative permeability drops, reducing effective oil drawdown at the same total rate. A modest lift increase can re-balance phase mobilities and stabilize oil without forcing more water. Choking back often worsens oil loss, and a full shut-in assumes pressure depletion without evidence.

A: The 5,000 psi range is typical for tubing, but the tie-in location governs what’s measured. If annulus pressure is being logged as tubing pressure, OFM-derived drawdown and skin are biased low, and that error persists quietly. Range issues or SAT assumptions don’t fix a mis-tapped impulse line captured in as-built steel.

A: The limiting factor is sparse, inconsistent pressure data under changing operating conditions. Rate-transient methods tolerate variable drawdown by normalizing rates with flowing pressure, something OFM can supply continuously. Decline curves ignore physics under interference, and material balance collapses without reliable average pressure.