1. Adaptive Product Technology for Coalbed Natural Gas (CBM)
William A. Grubb, General Manager
Weatherford International Ltd.
Title slide
Keep the title brief and to one line?
The second line (in smaller type style) is for the date of the presentation – depending on your presentation, you may also need to include Location and/or Presenter’s name/s and Job title if needed – as a such a second line may be used for these purposes.
Do not include unnecessary information in your presentation title – starting off with clear and simple messages will set the style and focus the audience for what is to follow.

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

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 for Coalbed Natural Gas Applications
Progressing Cavity Pumping
Electric Submersible Pumping
Plunger Lift
Reciprocating Rod Lift
Automation

7. System Considerations For Coalbed Natural Gas
Progressing Cavity
Plunger Lift
Electric
Submersible
Reciprocating
Rod Lift
Operating Depth (Typical)
Operating Volume (Typical)
Operating Temperature
Corrosion Handling
Gas Handling
Solids Handling
Coal Dust Handling
Servicing
Prime Mover Offshore Application
Overall System Efficiency
4,500’ TVD or less
10,000’ TVD or less
1,000’ TVD or less
8,000’ TVD
or less
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
Good
Good
Excellent
Good*
Excellent
Good
Good
Good
Good
Good
Good
Good
Workover or Pulling Rig
Workover or Pulling Rig
Wellhead Catcher or Wireline
Workover or Pulling Rig
Gas or Electric
Electric Motor
Wells’ Natural Energy
Gas or Electric
Good
Excellent
N/A
N/A
40% - 80%
35% - 60%
N/A
50%-60%
* If vented or if natural gas anchor is used.

8. Progressing Cavity Pumping Systems

9. PC Pump Advantages in Coalbed Natural Gas Operations
Wellhead
Drive
Casing
Production Tubing
Sucker Rod
Stator
Rotor
Tubing Collar
Tag Bar Sub
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 Submersible Pumping Systems

11. ESP Advantages in 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. Plunger Lift Advantages in Coalbed Natural Gas Operations
Lubricator
Catcher
Solar Panel
Controller
Dual “T” Pad
Plunger
Bumper
Spring
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. Rod Lift Advantages in Coalbed Natural Gas Operations
Sucker Rod
Tubing Anchor/
Catcher
Pump
Assembly
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. PCP - Coalbed Natural Gas
Case History
Initially client had 5 ESP failures within 2 months
Well data for this problem well ’ depth and 7” casing with 2-3/8” tubing
Introduced a Buna PCP with 4.3 L hydraulic drive system - July 2000
Solution: Increased the net gas rate to 550 mcf

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

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. ESP - Coalbed Natural Gas
Case History
Client initially ran conventional water well submersible equipment
Average run times were < 4 weeks – equipment sent to junk pile after failure
Well Data:
Depth ’-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. ESP - Coalbed Natural Gas
Case History continued
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. Plunger Lift Coalbed Natural Gas
Case History
Client initially ran rod lift pumps
Gas locking problems occurred as reservoir was de-watered and GLR increased
Well Data:
Perf. Depth: ft.
Casing /2” 17 ppf
Tubing – 2 3/8” 4.7 ppf, J-55

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

27. Rod Lift – Coalbed Natural Gas
Case History continued
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