1. Sucker Rod Lift – Troubleshooting & Problem Solving Breakout
Norman W. Hein, Jr.
Senior Exploration & Production Technology Engineer
CONSOL Energy – CNX Gas Company, LLC
Title slide
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2. 2015 SRL for GWD - ©NWHein & BWilliams
Introductions
14:30; Governor's Square 16
15:40
Total Attendance ~30
~20 Producing company
~7 Equipment Manufacturing company
~3 Service/Consulting company
2015 SRL for GWD - ©NWHein & BWilliams
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3. 2015 SRL for GWD - ©NWHein & BWilliams
Topics
Solids problem with pump, pushed around curve and laying in open hole horizontal lateral; what can be done to provide longer run time and keep out of “muck”
Should review pump shop report to determine what are actual pump problems and compare history of reports on same well to compare component run times to determine what changes could be made
Many special pumps are available that were developed to handle solids, so need to find out what type of pump have been used along with what metallurgy of components to see if changes in type of pump and/or metallurgy should be considered
Running back in the well without trying to clean it out may then cause short run times for new pumps. Types of potential methods to clean out the heel of horizontal were discussed.
2015 SRL for GWD - ©NWHein & BWilliams
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4. 2015 SRL for GWD - ©NWHein & BWilliams
Topics (cont)
Pump fillage problem; should they use back pressure control valve on tubing or what else to consider since normally have only 35 to 40% pump fillage; pump set above curve; installed own designed separator
BPCV may be considered but, needs to be properly set so not putting excessive pressure on tubing fluid while trying to keep the gas in the liquid; but, need to look at increased load affects (presentations and papers over the past few years) and this may not be where the problem occurs unless sufficient energy to blow tubing dry
May also be due to type of downhole gas separator and/or design. Papers and presentations over past few years, especially by Echometer along with new simulation model software should be considered. It also may be that the velocity of the system is too high to allow separation to occur (PR velocity is related to plunger velocity and “long and slow” may result in high plunger velocity)
2015 SRL for GWD - ©NWHein & BWilliams
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Topics (cont)
May also need to consider the type of pump. There are a number of special pumps available for handling gas that cannot be separated by downhole separator. The pump shop records along with design specifications (type of pump, fit tolerance, etc.)
However, need to consider, as for the first problem, once solve this one if there also is another problem that is being shadowed. For example, once solve solid problem may then have gas problems; or once solve gas problem may then have solids problem
Biggest problem is there are many special pumps for gas or solids; but very few pumps are available that can handle both
2015 SRL for GWD - ©NWHein & BWilliams
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6. 2015 SRL for GWD - ©NWHein & BWilliams
Topics (cont)
So, is there a max rod velocity to consider?
Publications are available that discuss max velocity, especially related to theoretical fall coupled with type of pumping unit
Number operators have rules of thumb where N * S is considered and should be below some number
1440 is typically used (114” stroke * 10 spm)
1500 or 1600 have been used (306” * 4.5 or 5 spm)
But higher velocities by itself may not be the problem as much as its associated impact effect such as;
wear,
heat generated from contact,
plunger impact incompletely filled pump, etc.
2015 SRL for GWD - ©NWHein & BWilliams
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7. 2015 SRL for GWD - ©NWHein & BWilliams
Topics (cont)
Downhole restriction from tubing anchor catcher (TAC); is it a problem?
A number of presentations over the past few years showed a number of operators had similar downhole restrictions problems
It depends on gas velocity and pressure
It was difficult to troubleshoot; apparently high fluid level but, pump card showing incompletely filled pump
Solutions by some operators pull the TAC
But, there are other options such as new, patented slim-hole TAC as well as hydraulic TAC, or potentially the deviations in the well are inhibiting tubing movement at depths greater than the free point of the tubing string
2015 SRL for GWD - ©NWHein & BWilliams
02/23/2015

8. 2015 SRL for GWD - ©NWHein & BWilliams
Topics (cont)
Do sinker bars require guided, centralizer sub, installed between each bar (been using field installed guide but not having problems)?
While normally recommended, it may not be necessary to install the guided sub as long as associated problems:
Keeping plunger in middle of barrel,
No pull tube/valve rod failures,
No holes in tubing across sinker bar section or in lowest section of rod string
Don’t solve problems not having; but, might want to consider talking to pump manufacturer since some have designed and can install there own centralizer at top of pump that will help solve some of the above pump concerns and should stay where installed
2015 SRL for GWD - ©NWHein & BWilliams
02/23/2015

9. Contact Information
Norman W. Hein, Jr.
Senior EPT Engineer
CONSOL Energy – CNX Gas Company, LLC
1000 CONSOL Energy Drive, Canonsburg, PA
Phone:
Cell:
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11. 2015 SRL for GWD - ©NWHein & BWilliams
Copyright
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Disclaimer
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