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Breakout Session Low Rate Wells, Gas Wells, Unloading after Stimulation

Shell Exploration & Production. Breakout Session Low Rate Wells, Gas Wells, Unloading after Stimulation. Post-Stimulation Unloading and Operation. Hydraulic Fracturing Acid treatment Coiled Tubing / Bullhead Concern about unloading due to unaerated liquids

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Breakout Session Low Rate Wells, Gas Wells, Unloading after Stimulation

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  1. Shell Exploration & Production Breakout SessionLow Rate Wells, Gas Wells, Unloading after Stimulation

  2. Post-Stimulation Unloading and Operation • Hydraulic Fracturing • Acid treatment • Coiled Tubing / Bullhead • Concern about unloading due to unaerated liquids • Cannot do slickline work if acid in tubing • Nitrogen / Fluid • Commonly no problems unloading because of nitrogen assisting the flowback production

  3. Acid – Bullhead treatment method • Common procedure • Set Plug, test tubing • If tubing test is good, pump acid job • If tubing test is bad, replace GLVs, pump acid job • If acid job does not complete, switch to flush fluid and frac way acid.

  4. Acid – Bullhead treatment method • Alternative procedure • Install new valves (AFLAS packing) in all mandrels, designed to unload acid / flush fluids • No need to frac fluids if job fails • Unload / kickoff well • Run Flowing Gradient Survey • Re-design / replace valves for new conditions

  5. Hydraulic Facture Treatment • Produce liquids a high rate to clear proppant from wellbore before installation of rod pump equipment • Use multi-rate design for shallow lift at high rate, but ability to lift deeper if rate is lower than desired

  6. Gas Wells • Wellhead Backpressure Reduction • Wellsite compression • Chemical treatment • Foam / surfactant • Gas Lift • increase mixture vertical velocity with gas • Reduce hydraulic flow area • Velocity string, Siphon string, Diptube, Tubing extension • Can lift / produce from below perfs if desired

  7. Low Liquid rate gas lift • Conventional and retrievable equipment used • May have conventional above, retrievable on bottom • Pulling units in high demand, so more retrievable equipment is being used. • Like to have lift pressure of 100 psi per 1000 ft. of lift depth • Common pressures are 750 to 850 or 1000 psi

  8. Low Liquid rate gas lift • Economic issue, not a mechanical / physical limitation. How much gas are you willing to expend for the liquids produced. • Consider $60/bbl oil and $15/mcf gas • Compression costs • Wellhead compression is relatively inexpensive • $1300/month for 15 mcfd additional production • Higher compression ratio costs ~ $0.20/mcf • $2700/month for 600 mcfd @ 1100 psi

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