1. Seating Nipple By-Pass System
Daryl Mazzanti – President
GARP Services LLC

2. Typical Rod Pump Design Pump-in Options & Limitations
Outline
Typical Rod Pump Design
Pump-in Options & Limitations
The Seating Nipple By-Pass Solution
Enables pumping down the production tubing
For improved paraffin treating
For improved chemical placement
For the ability to remove solids without a WO rig

4. Pump-in Options / Limitations of Conventional PU Design
Since pumping down the production tubing is not possible….
Back-side treating (batch or continuous) with hot liquids and/or chemicals is the only method of pumping liquids into the wellbore
No method exists to circulate the well to remove solids (even with a workover rig if the reservoir has low pressure)

5. Limitations of Backside Paraffin removal
Hot liquid & chemical treatments are very inefficient
A great deal of heat transfers to the earth
Much larger liquid volumes are necessary to ensure a sufficient amount of paraffin is removed
The load fluid may enter the reservoir and reduce permeability to hydrocarbons
Chemical placement is difficult
-long pathway
-achieving optimum chemical concentration is
difficult (trial and error)

6. Limitations of Backside continuous chemical Treatments
Annular gas production may prevent chemicals from reaching bottom
As with batch treatments, if too much load is pumped, the liquids may enter the reservoir and reduce permeability to hydrocarbons

7. SOLUTION: Seating Nipple By-Pass System

10. Summary of By-Pass System
Costs of mandrel-valves are comparable to conventional gas lift valves
Two valves included (one as a back up) to lessen pulling risk in case one valve fails open
Small ID cap string tail pipe prevents washing out valve seats, i.e., the pressure drop is taken over the length of the string.. Not the valve seats
Future on-site system possible designed for automated treating of paraffin, scale, and corrosion (with additional surface tank, heat exchanger, transfer pump, treating pump and VSD). Promises to be more effective/less costly than batch or continuous paraffin-chemical treating
Solids may be circulated out of the well using viscosified fluids at 1-3 BPM– pumping down the production tubing and taking returns up the production annulus. Screens and solids traps may now be used without fear of plugging since the solids may periodically be removed
~2/3 less volume of hot water/oil necessary than previously
Less chance of dirty or incompatible water being used in the well – can use the well’s own filtered salt water

11. On-Site automated treating system

12. Daryl Mazzanti – President
Contact Information
Daryl Mazzanti – President
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Website :