problems - investigation ofinvestigation of sucker rod ... · 3. well is pounding fluid and tagging...

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


• 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


Load Data Shows:NO PUMP FILLAGE 0

2.5

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


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


3000 Lbs Tag

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


Tagging Hard for longer than 1 second

Still Tagging Tag Starts

9

Well is Pounding Fluid and Tagging Hard

70% Pump Fillage


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


pis Critical in Correcting Problem

Copyrightpy g

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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 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.The views, opinions, and conclusions expressed in these presentations and/or training materials are those of the author and not necessarily those of the Sponsoring Organizations. The author is solely responsible for the content of the materials.The Sponsoring Organizations cannot and do not warrant the accuracy of these documents beyond the source documents, although we do make every attempt to work from authoritative sources. g y pThe Sponsoring Organizations provide these presentations and/or training materials as a service. The Sponsoring Organizations make no representations or warranties, express or implied, with respect to the presentations and/or training materials, or any part thereof, including any warrantees of title, non-infringement of copyright or patent rights of others, merchantability, or fitness or suitability for any purpose.


Plunger Velocity Should be used to Calculate Pump Slippagep pp g

CB From B to C?

VelC= 9.14 in/secFrom C to D

VelB = 17.57 in/sec

From C to DPlunger Moved ~ 6”

From A to BPlunger Moved ~ 8”

A D

problems - investigation ofinvestigation of sucker rod ... · 3. well is pounding fluid and tagging...

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