From Shut-In to Profit: Smart Lift Strategy Restores 2 MMSCF/D, Eliminates Coiled-Tubing Costs, Protects Reservoir Integrity

Restore stable gas production without killing the well or resorting to frequent coiled-tubing interventions.

Collected and reconciled fluid properties, reservoir parameters, and completion details to construct a fit‑for‑purpose well model.
Performed WellFlo modeling to confirm liquid loading severity and evaluate remediation options under realistic operating constraints.
Built the well model using the Gray and Turner correlation to compute critical gas velocity for liquid unloading. Compared in‑situ gas velocity vs. depth at the operating point to locate sections prone to liquid holdup and to validate unloading feasibility.
Assessed a produced‑water sample to determine the appropriate foamer type and concentration, targeting bubble stability, drainage, and compatibility at high temperature.
Developed a technical program to minimize risk of formation damage.

The previously shut-in well had production restored and stabilized to a production rate of 2 MMSCF/day with 100 LPD of foamer injection.
All operations were performed without killing the well, eliminating the chance of formation damage and avoiding frequent coiled-tubing interventions.

Details

Location

Pakistan

Well Type

Gas

Formation

Lower Goru B sand

Hole Size and Angle

7 in., vertical

Casing Size and Type

9-5/8 in., 46 lb/ft, BGT P-110

Liner Size and Type

7 in., VAM Top

Temperature

336°F (168°C)

Pressure

2,241 psi (15.4 MPa)

Measured Depth

11,482 ft (3,500 m)

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