Development History -

FLO-WELL Production Systems Incorporated Gas Lift Pump Technology was initially utilized in the shallow gas "stripper" well applications of South Eastern Alberta. We were presented with the challenge of getting production from these "end of life cycle" wells with low pressure reservoirs and liquid loading issues that choked production. Tubing strings were removed and the positive sealing casing plunger lift system was introduced. The 12.5 to 1 mechanical lift advantage in the 4 1/2" casing provided the solution to unloading these low pressure wells. The early tool was released manually with an operator pull latch and release times were improvised from estimating fluid infiltration rates. The knowledge gained from working in a harsh environment on these often neglected problematic wells with associated debris and corrosion issues still proves valuable today!

In a continuing effort to reduce operating costs, basic timed controller systems and automated release mechanisms were added to the system to reduce on-site man hours required. The tool's immediate success has expanded to similar reservoir applications across Alberta with depths ranging from 200 meters to 3000 meters. With the development and availability of newer sophisticated third party controller systems, with the ability to monitor and deliver data from various sensors to a computer processing unit, the tool's application has again been expanded to include new well installations. Time and experience is beginning to accumulate positive data on the benefits of introducing the Casing Plunger Tool System to new well applications. The early life cycle introduction of the FWPS casing plunger technology can spare the costs associated with the implementation and subsequent removal of tubing strings and related equipment and maintenance. These spared costs can be significant and can make the total casing plunger lift system seem small. Casing plunger technology is proving itself as a cost effective and efficient means of increasing and maintaining optimal gas production throughout a wells' life cycle.

Corporate Benefits - Effects on the Bottom Line

The Benefits to selected candidates wells include;

• A single solution to liquid loading issues in low-pressure gas well
• Lower capital cost outlays over most alternative pumping systems
• Cost effective alternative to tubing string installations with the added bonus of longevity
• Lowest pump operating costs–using “free” available well bore differential pressure as the lifting force
• Regular fluid removal increases reservoir life
• Regular swabbing process reduces paraffin and scale build ups on the well bore casing
• Lower methane emissions - reduced wasteful well bore “blow downs” to atmosphere are environmentally sound
• Regular swabbing action reduces coiled tubing clean-out costs
• Added revenues from optimized, stabilized and/or increased production
• Reduced operational labour costs achieved through use of optional automated controller packages
• Positive Sealing Elastomer Elements ensure lift
• Various tool configurations allows for co-mingled gas production from multiple zones

Declining Production due to liquid loading - SOLVED!

• Regular unloading of fluids helps clean up the formation and stabilizes gas production at optimal levels
  
• Casing plunger lift efficiency – 1Bbl of fluid in 2 3/8 inch tubing creates a fluid column of 258 feet and results in 111 PSI of hydrostatic head pressure Versus only 61.7 feet of column and 28 PSI of head pressure in a 4.5 inch casing!
  
• Each increment of 10 PSI of reservoir pressure below the Casing Pump creates an additional lifting capacity of 125 lbs. in the 4.5" O. D. casing (12.5 to 1 driving force translation ratio)

Wells requiring frequent swabbing - SOLVED!

• On-demand swabbing from 1 to 52 maximum cycles/day
  
• Controlled flow keeps solids suspended for better extraction options
  
• Reduces dependency on costly coiled tubing clean up services

Wells with high operating costs - SOLVED!

• No external power requirements - Casing plunger lift operation harnesses existing natural gas formation pressure
  
• Demonstrated mitigation of waxing, scaling and solids contamination
  
• Field serviceable – replaceable sealing and swabbing elements (average 3 month plus service intervals at 24 cycles/Day on 700m well depth - dependant upon well casing condition)

Operating Cost Benefits

1. Tubing Costs eliminated on new wells
2. Tubing and pump jack salvage and re-deployment value from old wells
3. Lower utility costs with no external power source or fuel requirements
4. Lower maintenance costs
5. Lower completion costs on new drill locations