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Adaptive Product Technology for Coalbed Natural Gas (CBM)

Adaptive Product Technology for Coalbed Natural Gas (CBM). William A. Grubb, General Manager Weatherford International Ltd. Progressing Cavity Pumping (PCP). Electric Submersible Pumping (ESP). Plunger Lift. Reciprocating Rod Lift. Forms of Lift Used in CBM. De-watering Characteristics.

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Adaptive Product Technology for Coalbed Natural Gas (CBM)

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  1. Adaptive Product Technology for Coalbed Natural Gas (CBM) William A. Grubb, General Manager Weatherford International Ltd.

  2. Progressing Cavity Pumping (PCP) Electric Submersible Pumping (ESP) Plunger Lift Reciprocating Rod Lift Forms of Lift Used in CBM

  3. De-watering Characteristics • Technology to de-water coal changes over life of well or field • Coal deposits are often active aquifers • Initial wells can produce substantial water volumes • Water production declines with time • Development or in-fill wells typically come on at higher gas – water ratios

  4. De-watering/Production Cycle • Two key points to de-watering success: • Maintain low BHP • Do not shut-in the well – water refloods coal

  5. Operator’s Objectives & Decision Drivers • Mean Time to Failure / Run Life • Capital Expense (CAPEX) • Lease Operating Expense (LOE) • Deliverability & Production Rates • Water Disposal

  6. Lift Technologies forCoalbed Natural Gas Applications • Progressing Cavity Pumping • Electric Submersible Pumping • Plunger Lift • Reciprocating Rod Lift • Automation

  7. System ConsiderationsFor Coalbed Natural Gas Progressing Cavity PlungerLift Electric Submersible Reciprocating Rod Lift 10,000’ TVD or less 4,500’ TVD or less 1,000’ TVD or less 8,000’ TVD or less Operating Depth (Typical) Operating Volume (Typical) Operating Temperature Corrosion Handling Gas Handling Solids Handling Coal Dust Handling Servicing Prime MoverOffshore Application Overall System Efficiency 2,200 BPD or less 20,000 BPD or less 30 BPD or less 1,500 BPD or less 400° F or less 120° - 550º F 100° - 350º F 150° F or less Fair Good Excellent Good Excellent Good Good Good* Good Good Excellent Good Good Good Good Good Workover orPulling Rig WellheadCatcher or Wireline Workover orPulling Rig Workover orPulling Rig Gas or Electric Gas or Electric Wells’ Natural Energy ElectricMotor Good Excellent N/A N/A 35% - 60% N/A 40% - 80% 50%-60% * If vented or if natural gas anchor is used.

  8. Progressing CavityPumping Systems

  9. Wellhead Drive Casing Production Tubing Sucker Rod Stator Rotor Tubing Collar Tag Bar Sub PC Pump Advantagesin Coalbed Natural Gas Operations • Able to produce problem wells; excellent solids handling - coal, shale and sand • Gas producing capabilities • High system efficiency • Produce wells with poor cement jobs • Flexibility in production volume with one pump • Remote locations without power and pilot projects

  10. Electric SubmersiblePumping Systems

  11. ESP Advantagesin Coalbed Natural Gas Operations • Low to moderate costs for shallow depth wells • Minimal surface profile • Flexibility in production volumes with VFD • Repairable, which reduces LOE • Good gas handling with gas separator • Good solids handling when built with hardened bearings

  12. Plunger Lift Systems

  13. Solar Panel Lubricator Catcher Controller Dual “T” Pad Plunger Bumper Spring Plunger Lift Advantages in Coalbed Natural Gas Operations • Unload wells that continue to load up with produced wellbore fluids • Installed as a method of dewatering High GLR coalbed natural gas wells • Maintains higher operating pressure on rate sensitive coalbed natural gas wells

  14. Reciprocating Rod Lift Systems

  15. Sucker Rod Tubing Anchor/ Catcher Sucker Rod Pump Assembly Rod Lift Advantagesin Coalbed Natural Gas Operations • Low to moderate costs for shallow depth wells • High system efficiency • Excellent flexibility – can alter stroke speed /length, plunger size, run time to control production • Equipment available with wide range of gear reducers, structural ratings and stroke length combinations • Surface equipment available in low profile design for visually-sensitive areas • Excellent salvage value

  16. Case Histories • Progressing Cavity Pumping • Electric Submersible Pumping • Plunger Lift • Reciprocating Rod Lift

  17. Case History PCP - Coalbed Natural Gas • Initially client had 5 ESP failures within 2 months • Well data for this problem well - 1100’ depth and 7” casing with 2-3/8” tubing • Introduced a 100-2100 Buna PCP with 4.3 L hydraulic drive system - July 2000 • Solution: Increased the net gas rate to 550 mcf

  18. Case History continued Weatherford PCPCommences Operation Gas Production BPD / MCD WaterProduction PCP - Coalbed Natural Gas

  19. PCP – Coalbed Natural Gas Best Practices & Lessons Learned • Necessary to run looser fitting pumps • Lower RPM extends run life • Reduced tubing wear with full rod on top of rotor • Two snap-on rod guides per rod

  20. Case History ESP - Coalbed Natural Gas Client initially ran conventional water well submersible equipment Average run times were < 4 weeks – equipment sent to junk pile after failure Well Data: • Depth - 600’-1,200’ • Casing - 5 ½” and 7” • Tubing – 2 3/8” and 2 7/8” • Installed specialized CBM-ESP™ with enhanced gas and abrasion handling capabilities • Used repairable CBM equipment • CBM-ESP substantially increased run times

  21. Case History continued ESP - Coalbed Natural Gas Installed CBM-ESP

  22. ESP – Coalbed Natural Gas Best Practices & Lessons Learned • Essential to gather correct application data for sizing • When possible, pre-assemble pump, motor and screens • Use proper field techniques when handling • ESP should be manufactured with compression stages and hardened bearings • When applicable, install ESP with inverted shroud intake

  23. Case History Plunger Lift Coalbed Natural Gas • Client initially ran rod lift pumps • Gas locking problems occurred as reservoir was de-watered and GLR increased • Well Data: • Perf. Depth: 1100 ft. • Casing - 5 1/2” 17 ppf • Tubing – 2 3/8” 4.7 ppf, J-55

  24. Plunger Lift Coalbed Natural Gas Rod Pump  Plunger Lift Plunger Lift Installed

  25. Plunger Lift - Coalbed Natural Gas Best Practices & Lessons Learned • Evaluate production for required GLR to drive system • Examine PPM dissolved solids and coal fines for possible screen application • Shut well for pressure build up • Evaluate shut in pressure vs. GLR

  26. Case History Rod Lift - Coalbed Natural Gas • 45 rod pumping wells, with oldest installed in 1993 • PCPs were unsuccessful • Well Data: • Perf. Depth: 2,000 ft. • Casing - 5 1/2” and 7” • Tubing - 2 3/8”, 2 7/8” and 3 1/2”

  27. Case History continued Rod Lift – Coalbed Natural Gas Installed Rod Pump

  28. Rod Lift – Coalbed Natural Gas Best Practices & Lessons Learned • Tried grooved plungers; determined traditional chrome barrel pumps worked best • Wipers added to top and bottom of plunger increased pump life by keeping coal fines and solids from entering pump • Developed regular pump replacement schedule every 6 months, even though company was experiencing pump runs of up to 18 months, to minimize downtime, keep pump efficiencies high and maximize fluid production ( gas production)

  29. Q&A

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