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10th Annual Sucker Rod Pumping
Workshop Renaissance Hotel
Oklahoma City, Oklahoma
September 16 - 19, 2014
Downhole Counter Balance Effect Tool
Joe Ippolito
LOTRAM LLC
(661) 599-7886
What I Will Show You Today
• Theory Behind the Tool.
• Tool Description.
• Modeling Used To Deploy the Tool.
• Tool Testing.
• Construction and Deployment
Issues.
• Benefits .
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What Does It Do?
• Reduces Rod Loading
• Reduces PU Structural Loading
• Reduces Peak Gear Box Torque
• Reduces Power Consumption
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How Does It Do It?
• The DH-CBE Utilizes the Pressure
Difference Between Inside the Tubing
And Outside the Tubing (Casing
Pressure) to Generate an Upward
Force.
• This Continuous Upward Force Acts as
a Counterbalance Effect.
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2014 Sucker Rod Pumping Workshop 4
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How Does It Do It?
• The DH-CBE Would Typically be Deployed Below 1,200’
(See Fig. 1).
• Tubing Pressure at this Depth Would Be Approximately
500 PSI.
• Casing Pressure at the Same Depth Could Be as Little
as 2 PSI.
• That 498 PSI Difference Is Used to Power the DH-CBE.
DH–CBE Tool Placement
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Figure 1
Description of DH-CBE
Tool Concept Is Illustrated In Fig. 2
• The DH-CBE Has an Internal Sliding Element.
• There are Plungers of Different Diameters at Each End.
• High Pressure Fluid is Internal to This Element.
• Low Pressure Gas is External.
• The Pressure Difference Pushes the Sliding Element
Upward.
• The Rods Are Landed On the Sliding Element.
• The Sliding Element Moves With the Rod String.
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General Description
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Patent Pending 8
Figure 2
Force Calculation
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Figure 3
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Source of Energy For DH-CBE
• Like Any Counterbalancing Method, Work is Added To And Removed From the System.
• On the Up Stroke the Fluid Works On the Plunger.
• On the Down Stroke the Plunger Works On the Fluid.
• Therefore the Energy/Work is Transferred In And Out of the Fluid.
• The Load Is Not Transfer To the Tubing. Tubing Pressure Remains Constant.
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Reduces Rod Stress
• Rod Stress Above the DH-CBE are
Reduced By the Removal of Load.
• Rod Stress Below the DH-CBE Can Also
Be Reduced By Running Larger Diameter
Rods. The DH-CBE Stops That Extra Rod
Weight From Over Stressing the Rods
Above the DH-CBE.
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Gearbox Torque Reductions
• The CBE Of Crank Mounted Counterweights Is
Not Constant Throughout the Entire Pumping
Cycle. The CBE Moves Between 0 % And 100%.
– This Can Be Seen By a Torsion Analysis of Two Dyno
Cards Having the Same PPRL and MPRL. Yet Peak
Torque Values are Different.
• This Can Be Also Be Seen With Reduced Peak
Torques When Using Air Balance Pumping Units.
– The CBE Effect of the Air Cylinder Induces a Relatively
Constant CBE Throughout the Stroke.
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University Of Texas Torque_Factors_Kinematics
5000
10000
15000
20000
25000
0.0 0.2 0.4 0.6 0.8 1.0
Polis
hed R
od L
oad (
lbf)
Dimensionless Polished Rod Position
Polished Rod Dynamometer Card
PR Load
Permissible Load
PU: C320-298-100 Predicted
Base Case This Card Comes
With the U.T.
Spreadsheet
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University Of Texas Torque_Factors_Kinematics
Modified
Base Case
U.T. Card (Same Peak and
Minimum Rod
Loads)
2000
7000
12000
17000
22000
27000
0.0 0.2 0.4 0.6 0.8 1.0
Polis
hed R
od L
oad (
lbf)
Dimensionless Polished Rod Position
Polished Rod Dynamometer Card
PR Load
Permissible Load
PU: C320-298-100
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Torque Predictions Using U.T. Torque_Factors_Kinematics
DH-CBE PPRL MPRL PT *
LBS LBS LBS IN-LBS
Base Case ----------- 19,772 9,155 303,513
Base Case W/ DH-CBE 4,975 14,797 4,180 291,873
Reductions 25% 54% 3.8%
Modified Case ----------- 19,772 9,155 331,066
Modified Case w/ DH-CBE 4,975 14,797 4,180 306,307
Reductions 25% 54% 7.5%
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* Spreadsheets also predict less periods and smaller values of negative torque.
PU: C320-298-100
Comparison of Unit Types With Dynamometer Cards
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5000
10000
15000
20000
25000
0.0 0.5 1.0
Polis
hed R
od L
oad (
lbf)
Dimensionless Polished Rod Position
Polished Rod Dynamometer Card
PR Load
Permissible Load
Conventional PU:C320-298-100 Air Balance PU:C320-305-100
5000
10000
15000
20000
25000
0.000 0.500 1.000
Po
lish
ed
Ro
d L
oad
(lb
f)
Dimensionless Polished Rod Position
Polished Rod Dynamometer Card
PR Load
PermissibleLoad
Peak Torque 303,513 IN-LB Peak Torque 205,378 IN-LB
PERFORMANCE MODELING
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Performance Objectives
• Place the Tool Deep Enough to Generate
The Needed Forces. Deeper (Higher
Pressure) Produces Greater Forces.
• Placing the Tool Too Deep May Induce
Buckling Above the Tool. The Rods
Below the DH-CBE Need to Pull the Tool
Down.
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2014 Sucker Rod Pumping Workshop 18
Performance Modeling
• Model the Rod String Suspended Below the DH-CBE
to Determine Rod Loading at That Point.
– Adjust Flowline Pressure to Match Tool Depth.
– To Prohibit Buckling We Try to Induce a MPRL Greater Than
DH-CBE Upward Force. Much Like Prohibiting Rod Floating
at Surface.
– Some Applications May Tolerate Light Compression, Much
Like We See Above Some Pumps.
• 1” Rods in 2 7/8” Tubing Would Be More Tolerant of
Compression.
• Can Also Use Centralizers .
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Performance Modeling
• Model the Entire Rod String Without the DH-CBE
to Determine:
– Displacement, It Will Be Understated Because of
Reduced Rod Stretch.
– Model Top Rod Stress Than Reduce it By Applying the
DH-CBE Load Reduction.
– Intending to Develop a Wave Equation Model That Can
Include DH-CBE Forces.
• Take Prior Dynamometer and Adjust for DH-CBE
Load Reductions and Added Rod Weight.
– Conduct Torsion Analysis on Modified Card.
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Proof of Concept - Testing Results
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Field Testing
• Installed On April 22, 2013 In the Bellevue Field,
Bakersfield, Ca.
• C320-213-75 PU, 6.6 SPM, 2.75” Pump, 87 Rod String
• A Highly Deviated Well With 7” Casing, Tool O.D. was
5.25”.
• Top Perforation is at 7,096 Feet, Pump Depth was at
4,680 Feet.
• High Water Cut 98.5%.
• High GOR, Observed But Not Measured.
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Testing History
• Dynamometer Analysis Was Performed
Before and After Engaging the Tool.
• These Comparisons Were Made While Using
the Same New Rod Pump.
• DH-CBE Sized For 5,000 LBS.
• Well Went Down In Dec 2013 With a Hole In
the Tubing.
• DH-CBE Removed in June 2014, Found 3
Failed Joints.
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Testing History
• We Did Not Return the Well to Production
With the DH-CBE.
• Test Well Was Not Overloaded.
• Tested at the Same Displacement.
• The Operator Did Not Want to Increase
Displacement at That Time. They Have
Limited Waste Water Injection Capacity.
• Did Not Need The DH-CBE Without a
Production Increase.
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Before & After Dynamometers
Polished-Rod Stroke (Inches) 0 76.2
Polis
hed-R
od L
oad (
Pounds) 20,545
15,952
6,545
1,597
20,000
15,000
10,000
5,000
0
Before
After
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BEFORE AFTER Diff.
Polished-Rod PPRL 20,545 15,952 -4,593 LBS
MPRL 6,545 1,597 -4,948 LBS
Diff 14,000 14,355 355 LBS
Mod Goodman
Diagram (.8) D Rods 97 84 -13 %
Rod Stress Max 26,158 20,310 -5,848 PSI
Min 8,333 2,033 -6,300 PSI
Rod Stretch 21.90 20.10 -1.80 IN
Plngr Stk 61.80 64.50 2.70 IN
Ovr-Trvl 7.50 8.30 0.80 IN
Valve Ck Load TV 17,716 12,363 -5,353 LBS
SV 9,401 4,753 -4,648 LBS
Diff 8,315 7,610 -705 LBS
Dynamometer Test Analysis
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Reductions
PU Structural Loading 22%
Stress - Upper Rods 13%
Gearbox Peak Torque 9%
Results Summary
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Reductions will increase with deeper wells.
Fluid Leakage Through Tool
• Looked For a Reduction in Well Tests.
– Rate Variations With Changes in SPM Made It Difficult
To Compare Before and After Well Tests. The Well Has
a Natural Gas Engine.
– Monthly Production Rates Appear Unaffected, See the
Following Plot.
• Looked at Tubing Pressure Tests
– There Was A Very Slow or No Drop In Tubing Pressure
During Pressure Test.
– However Tubing Contained Relatively High Gas
Volumes.
• Fluid Leakage Did Not Appear To Be a Problem.
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Test Well Production
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0
50
100
150
200
250
BFPD
BFPD
Replaced Pump
Removed DH-CBE
Found Holes in Tubing
Installed DH-CBE Did not replace pump. Before & After Dyno
Construction & Installation Issues
• The DH-CBE is Constructed with Sucker
Rod Pump Plungers and Barrels.
– Largest O.D. 5.25”.
• Larger Than the Pump But Smaller than
Tubing Anchor
• Is Hung Shallow.
• The DH-CBE is Full I.D. Therefore it Does
Not Interfere with Running Any Downhole
Equipment.
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Construction & Installation Issues
• We Recommend Using the Same Methods for
Solids and Corrosion Control as the Downhole
Pump. The DH-CBE Operates at Much Lower
Pressures and Therefore Should Last Longer
and Have Less Slip.
• A Landing Tool, Installed In the Rod String
Engages the DH-CBE. It Need Not Latch, the
Generated Forces Keep the DH-CBE Engaged.
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Running Procedure
1. Run the downhole pump assembly.
2. Run sufficient tubing to meet spacing requirement
between DH-CBE and pump.
3. Run DH-CBE
4. Run sufficient tubing to place pump at depth.
5. Run pump and rods matching spacing in step 2 above.
6. Run landing tool.
7. Run rods and space pump.
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DH-CBE Landing Tool
The landing tool
naturally seats in the
DH-CBE and pulls free.
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DH-CBE Landing Tool
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The Landing Tool
Naturally Seats in the
DH-CBE and Pulls Free.
DH-CBE Benefits
• Pump displacements Can Be Increased.
• Pumps Can be Run Deeper.
• Reduced Rod Parts.
• Reduced Energy Consumption.
– Savings from mechanical inefficiencies and electrical resistance
losses.
– Reduced back generated power .
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Copyright
Rights to this presentation are owned by the company(ies) and/or author(s) listed on the title page. By submitting this presentation to the Sucker Rod Pumping Workshop, they grant to the Workshop, the Artificial Lift Research and Development Council (ALRDC), and the Southwestern Petroleum Short Course (SWPSC), rights to:
– Display the presentation at the Workshop.
– Place it on the www.alrdc.com web site, with access to the site to be as directed by the Workshop Steering Committee.
– Place it on a CD for distribution and/or sale as directed by the Workshop Steering Committee.
Other use of this presentation is prohibited without the expressed written permission of the author(s). The owner company(ies) and/or author(s) may publish this material in other journals or magazines if they refer to the Sucker Rod Pumping Workshop where it was first presented.
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Sept. 16 - 19, 2014 2014 Sucker Rod Pumping Workshop
Disclaimer
The following disclaimer shall be included as the last page of a Technical Presentation or Continuing Education Course. A similar disclaimer is included on the front page of the Sucker Rod Pumping Web Site.
The Artificial Lift Research and Development Council and its officers and trustees, and the Sucker Rod Pumping Workshop Steering Committee members, and their supporting organizations and companies (here-in-after referred to as the Sponsoring Organizations), and the author(s) of this Technical Presentation or Continuing Education Training Course and their company(ies), provide this presentation and/or training material at the Sucker Rod Pumping Workshop "as is" without any warranty of any kind, express or implied, as to the accuracy of the information or the products or services referred to by any presenter (in so far as such warranties may be excluded under any relevant law) and these members and their companies will not be liable for unlawful actions and any losses or damage that may result from use of any presentation as a consequence of any inaccuracies in, or any omission from, the information which therein may be contained.
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