Problems - Investigation ofInvestigation of Sucker Rod ... Annual Sucker Rod Pumping Workshop ......

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Transcript of Problems - Investigation ofInvestigation of Sucker Rod ... Annual Sucker Rod Pumping Workshop ......

  • 5th Annual Sucker Rod Pumping WorkshopWorkshop

    Wyndham Hotel, Dallas, TexasSeptember 15 18 2009September 15 18, 2009

    Problems - Investigation ofProblems Investigation of Sucker Rod Lift ProblemsJohn SparksEd Delgado

    Lynn Rowlan

  • Introduction

    1.1. Investigate Operational ProblemsInvestigate Operational Problems22 In Different WellsIn Different Wells2.2. In Different Wells In Different Wells Using: Using: gg

    Dynamometer InstrumentDynamometer Instrument Fluid Level InstrumentFluid Level Instrument

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 2

  • Investigation of Well Problemsg1.1. Drop in ProductionDrop in Production2.2. Pump Is StarvingPump Is Starving3 Well is Pounding Fluid and Tagging Hard3. Well is Pounding Fluid and Tagging Hard4. Pump Displacement & in-Tank Not Close5. 83% of Surface Stroke lost to Rod Stretch6 Hole in Tubing6. Hole in Tubing7. Sticking Downhole on Upstroke

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 38. Damaged Pumping Unit

  • Investigation of Well Problem:Drop in productionDrop in productionp pp pUpon Arrival Well had High tag somewhat like a Fluid Pound Shot Fluid Level ~ Fluid Above Pump Intakep Dynamometer Indicated Well was Pumping Off,

    but another Fluid Level Showed Fluid Abovebut another Fluid Level Showed Fluid Above Pump

    Shut Well down for 3 hoursShut Well down for 3 hours Higher Fluid Level

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 4

    Pump still pounding fluid

  • This Fluid Level Was Acquired After Leaving The Unit Down 2 Hours And 45 Minutes. Shot Fluid Level Just Before Turning The Well Back OnLevel Just Before Turning The Well Back On....

    2078 Ft Fluid Above Pump

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 5

  • Load Data Shows:NO PUMP FILLAGE 02.5

    5.0

    7.5

    10.0

    Fo Max Fo From Fluid Level

    NO PUMP FILLAGE0 118.4-7.5

    -5.0

    -2.5

    0

    #8

    2078 Ft Fluid Above Pump

    DownDown

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 6

  • NO Flow Into Pump, Conclusion:Pump Is Starving; Mud Anchor Probably Fullp g; y

    Pump IsPump Is 13.5% full, most of Liquid fillage from tubing fluid slippage pp gbetween Plunger and BarrelBarrel

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 7

    3000 Lbs Tag

  • Investigation of Well Problem:Well is Pounding Fluid and Tagging Hardg gg g

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 8

  • Tagging Hard for longer than 1 second

    Still Tagging Tag Starts

    9

  • Well is Pounding Fluid and Tagging Hard

    70% Pump Fillage

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 10

    1000 Lbs Tag

  • Well is Pounding Fluid and Tagging Hard12.50 May want to change the sampling May want to change the sampling

    speed from the default 30 samples speed from the default 30 samples 10.00

    Wrf + Fo Max

    per second to 240 samples per sec per second to 240 samples per sec

    @ Default 30 samples per second @ Default 30 samples per second

    5 00

    7.50

    Wrf

    sampling speed the tag is sampling speed the tag is smoothed out ~ smoothed out ~ --2000 lbs 2000 lbs

    2.50

    5.00

    Fo Max Fo From Fluid LevelNotice that this tag occurs 6.0 Notice that this tag occurs 6.0 inches from the bottom of the inches from the bottom of the strokestroke

    0

    50

    96.4

    70% Pump Fillage

    stroke. stroke.

    Well should be reWell should be re--spaced andspaced and

    0 102.0-2.50 112000 Lbs Tag

    6 in. off Bottom Well should be reWell should be re spaced and spaced and 10.47 SPM reduced!10.47 SPM reduced!

  • Severe Tag w\ Vibrations (Rod Part 06/23/2008)15.00 06/02/08

    10.00

    12.50 Wrf + Fo Max

    5.00

    7.50 Wrf

    2.50

    Fo Max Fo From Fluid Level

    0 102.0-2.50

    0 92.4

    12

    Found Well Running And With A Severe Fluid Pound, Producing Severe Vibration In The Rod String.

  • Investigation of Well Problem:Pump Displacement not close to BBLS in Tankp p

    40 BPD in Tank?

    88% Pump Fillage

    129 BPD

  • Pump Displacement 129.3 BPD not close to 40 BBLS measured in Tank

    Too Low TV Leakage Rate 17 5 BPDToo Low, TV Leakage Rate 17.5 BPD

  • More Research Needed in Pump Slippage Calculationsp pp g

    Traveling Valve Test Leakage:Leakage Rate 17 5 BPDLeakage Rate 17.5 BPD

    Patterson HF Calculates:Slippage Rate 15 2 BPDSlippage Rate 15.2 BPD

    Pump Displacement Production in Tank:Production in Tank:129.3 40 = 89.3 BPDSlippage Rate 89.3 BPD

  • Investigation of Well Problem:83% of Surface Stroke lost to Rod Stretch

    17.9 In

  • After Hot Water Treatment +100 BPD

  • Investigation of Well Problem: Hole in Tubing & Sticking During Upstroke g g g p

    L d t Lift Fl id t S f ?L d t Lift Fl id t S f ?Load to Lift Fluid to Surface?Load to Lift Fluid to Surface?

    Load Spike as Plunger StopsLoad Spike as Plunger Stops

  • Shot Fluid Level Down Tubing Hole in the Tubing Below Liquid Level g q

    Shot #2 Tubing Pump On 09/18/08 16:19:46Shot #2 Tubing Pump On 09/18/08 16:19:461)1) Shot well 3 Shot well 3

    times 1 downtimes 1 downShot #2, Tubing, Pump On 09/18/08 16:19:46Shot #2, Tubing, Pump On 09/18/08 16:19:46 times, 1 down times, 1 down casing, 2 casing, 2 down tubingdown tubing

    2)2) All three shots All three shots ))same depth same depth with in 150 with in 150 feetfeet

    Shot #3, Tubing, Pump OnShot #3, Tubing, Pump On 09/18/08 17:03:0409/18/08 17:03:04

    3)3) Pump running Pump running entire 44 min. entire 44 min. while shot while shot d t bid t biShot #3, Tubing, Pump OnShot #3, Tubing, Pump On 09/18/08 17:03:0409/18/08 17:03:04 down tubingdown tubing

    4)4) Tubing and Tubing and Casing Psi Casing Psi equal andequal andequal and equal and liquid level liquid level equal equal

  • Sticking DownholeSticking Downhole or Damage Pumping Unit

    MoveMove

    Plunger Stops Plunger Stops for 1 Second for 1 Second while Polishedwhile PolishedMove Move

    Up Up 17.15 17.15

    while Polished while Polished Rod moves up Rod moves up 17.15 inches. 17.15 inches. Applying aApplying a

    1 Sec.1 Sec.

    Applying a Applying a 2315 Lb Force, 2315 Lb Force, before plunger before plunger starts to move.starts to move.Plunger Position MUST become Plunger Position MUST become gg

    Flat OR Pump not Sticking!Flat OR Pump not Sticking!

  • Investigation of Well Problem: Sticking Downhole or Damage Pumping Unit g g p g

    Load Spikes Due toLoad Spikes Due toLoad Spikes Due to Load Spikes Due to Damaged Pumping Damaged Pumping UnitUnit

  • Sticking Downhole or Damage Pumping Unit

    Instantaneous SPM Spikes match Polished Rod Load Instantaneous SPM Spikes match Polished Rod Load Spikes, IF changing speeds are due to Surface ProblemSpikes, IF changing speeds are due to Surface Problem

  • Conclusions1.1. Dynamometer and Fluid Level Analysis Dynamometer and Fluid Level Analysis

    Used to Identify Many ProblemsUsed to Identify Many ProblemsUsed to Identify Many ProblemsUsed to Identify Many Problems2.2. Identifying the Cause and Solution to the Identifying the Cause and Solution to the

    Problem can be Difficult to DetermineProblem can be Difficult to Determine3 Experience Helps Trouble Shoot the Well3. Experience Helps Trouble Shoot the Well4. Must Spend Time to Get Representative

    D t (Offi d Fi ld)Data (Office and Field)5. Effective Communication with Operator

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 23

    pis Critical in Correcting Problem

  • Copyrightpy g

    Rights to this presentation are owned by the company(ies) and/or author(s) listed on the title page By submitting this presentation toauthor(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.Pl it CD f di t ib ti d/ l di t d b th W k h 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/orwritten 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.

    Sept. 15 - 18, 2009 2009 Sucker Rod Pumping Workshop 24

  • DisclaimerThe 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.gThe 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 g g ywarranty 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