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DUG 2010 Technical Workshop Presentation

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How to Make More production with Plunger Lift.

How to Make More production with Plunger Lift.

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DUG 2010 Technical Workshop Presentation Presentation Transcript

  • 1. HOW TO MAKE MORE PRODUCTION WITH PLUNGER LIFT DEVELOPING UNCONVENTIONAL GAS TECHNICAL WORKSHOP MARCH 29, 2010 HFOPTIMISER.COM
  • 2. CONTENTS  PLUNGER LIFT BENEFITS WITH TELEMETRY  HOW TO OPTIMIZE PRODUCTION  TROUBLESHOOT AND IMPROVE HFOPTIMISER.COM
  • 3. PLUNGER LIFT SYSTEM LUBRICATOR MOTOR CONTROLLER Bluetooth on Site SOLAR VALVE Cell Phone Modem FLOW METER PANEL Licensed or SS Radio (EFM or MVT) Satellite PLUNGERS ARRIVAL SENSOR BH SPRING HFOPTIMISER.COM
  • 4. BENEFITS WITH TELEMETRY  Increase Production  Can work on high water producing wells (200 bbls/d)  Lifting cost is significantly less than gas lift  Retards decline curve  Typical payback is 2 weeks to 60 days  Decrease unplanned downtime  Decrease drive time and vehicle costs  Decrease OT and contract labor  Decrease equipment failures HFOPTIMISER.COM
  • 5. BENEFITS WITH TELEMETRY  Decrease lost gas due to venting  Detection of some EFM calibration issues  Environmentally responsible  Improve site safety Ref: American Gas Stars Partner Program (Oct 2003) American Oil and Gas Reporter (Oct 2005) HF Opti-MISER Case Studies (2009-2010) HFOPTIMISER.COM
  • 6. BENEFITS WITH TELEMETRY WELL MCF/D BBLS/D LINE LIFT PRESSURE PRESSURE Well # 1 550 204 135 500 Well # 2 550 94 180 500 Well # 3 300 61 140 720 Well # 4 550 56 60 540 Well # 5 480 54 70 400 Well # 6 600 50 180 500 Well # 7 200 35 320 540 Well # 8 477 30 140 300 Well # 9 460 27 130 300 HFOPTIMISER.COM
  • 7. BENEFITS WITH TELEMETRY Free Flowing Well HF OPTI-MISER installed 1200 250 Line Pressure 1000 200 800 150 600 100 400 PRODUCTION LEVELED 50 200 Production and STABILIZED ! 0 0 16-Nov-09 16-Jun-09 16-Jul-09 16-Jan-09 16-May-09 16-Jan-10 16-Aug-09 16-Mar-09 16-Oct-09 16-Apr-09 16-Feb-09 16-Sep-09 16-Dec-09 HFOPTIMISER.COM
  • 8. BENEFITS WITH TELEMETRY 1800 Free Flowing Well HF OPTI-MISER installed 250 1600 1400 200 1200 PRODUCTION LEVELED 150 1000 Line Pressure and STABILIZED ! 800 100 600 400 50 Production 200 0 0 14-Jun-09 28-Jun-09 1-Nov-09 15-Nov-09 29-Nov-09 9-Aug-09 23-Aug-09 12-Jul-09 26-Jul-09 6-Sep-09 20-Sep-09 19-Apr-09 13-Dec-09 27-Dec-09 3-May-09 17-May-09 31-May-09 4-Oct-09 18-Oct-09 HFOPTIMISER.COM
  • 9. HOW TO OPTIMIZE PRODUCTION CASING 1. PREVENT or QUICKLY DETECT TUBING UNPLANNED DOWNTIME REAL TIME E-MAIL ALERT 2. ELIMINATE FLOW RESTRICTIONS Station Name: Well # 42 3. USE RELIABLE HARDWARE Alarm Text: Low Sales Press 4. USE TELEMETRY WITH CRY-OUT Time Logged: March 19, 2010, 11:19PM 5. OPERATE AT LOWEST POSSIBLE Value: 23.0 FBHP (Cycle Frequently!) Set Point: 25.0 6. OPTIMIZE PRODUCTION, OBSERVE PLUNGER VELOCITY CAUSE 1. Fluid in Tubing (CP-TP) 2. Lift Pressure (CP-LP) EFFECT 1. Plunger Velocity 2. Production 5000 ft HFOPTIMISER.COM
  • 10. HOW TO OPTIMIZE PRODUCTION Well # 1 Well # 2 Well # 3 Well # 4 Well # 5 Well # 6 Well # 7 Well # 8 Well # 9 Well # 10 Well # 11 Well # 12 Well # 13 Well # 14 Well # 15 Well # 16 Well # 17 Well # 18 Well # 19 Well # 20 Well # 21 Well # 22 Well # 23 Well # 24 Well # 25 Well # 26 Well # 27 Well # 28 Well # 29 HFOPTIMISER.COM
  • 11. HOW TO OPTIMIZE PRODUCTION LINE PRESSURE GAS PRODUCTION FOCUS ON PRODUCTION ! ~ E-Mail Alert ~ LOOK AT TRENDS Low Line Pressure HFOPTIMISER.COM
  • 12. HOW TO OPTIMIZE PRODUCTION Well Opens Head Gas Produced Liquid Load TP Plunger Arrives CP Lateral leg unloading Lift Pressure Well Don’t shut-in too early Flow Rate Closes LP HFOPTIMISER.COM
  • 13. HOW TO OPTIMIZE PRODUCTION 1. Open on Lift Pressure 2. Be at Open Lift Pressure when plunger hits bottom 3. Use a rapid fall plunger if pressure builds fast 4. Allow only small amount of liquid to enter the tubing so that # 2 can be achieved 5. Flow long enough to unload lateral line 6. Adjust settings, review production 7. Implement preventative maintenance program  Plunger velocities of 200 – 300 fpm are not uncommon  If needed, use a standing valve HFOPTIMISER.COM
  • 14. HOW TO OPTIMIZE PRODUCTION HFOPTIMISER.COM
  • 15. TROUBLESHOOT AND IMPROVE OPEN on TIME 1200 HF OPTI-MISER installed 250 AVG 167 Mcf AVG 196 Mcf OPEN on 1000 PRESSURE 200 17% 800 150 600 Line Pressure 100 400 Production 50 200 0 0 5-Nov-09 12-Nov-09 19-Nov-09 26-Nov-09 7-Jan-10 14-Jan-10 1-Oct-09 8-Oct-09 15-Oct-09 22-Oct-09 29-Oct-09 3-Dec-09 10-Dec-09 17-Dec-09 24-Dec-09 31-Dec-09 HFOPTIMISER.COM
  • 16. TROUBLESHOOT AND IMPROVE OPEN on Line Pressure PRESSURE OPEN on TIME Production AVG 133 Mcf AVG 172 Mcf 29% HFOPTIMISER.COM
  • 17. TROUBLESHOOT AND IMPROVE Line Pressure Production By Pass Plunger replaced Dual Row Pad. Cycles more frequently. 39% HFOPTIMISER.COM
  • 18. TROUBLESHOOT AND IMPROVE Motor Valve Leaks or EFM calibration issue. Flow when well is closed. Motor Valve Leaks. TP declines when well is closed HFOPTIMISER.COM
  • 19. TROUBLESHOOT AND IMPROVE TP is pushing fluid out. Possible candidate for a standing valve. HFOPTIMISER.COM
  • 20. TROUBLESHOOT AND IMPROVE Well is closing when flow rate is increasing. Flow longer. HFOPTIMISER.COM
  • 21. TROUBLESHOOT AND IMPROVE LP declines when well is closed. Unplanned venting to tank. HFOPTIMISER.COM
  • 22. TROUBLESHOOT AND IMPROVE Added Standing Valve. Shorter Fall Time. Increased afterflow. 103% HFOPTIMISER.COM
  • 23. TROUBLESHOOT AND IMPROVE Added Standing Valve 20% HFOPTIMISER.COM
  • 24. HF OPTI-MISER WELL CONTROL SYSTEM A SYSTEM THAT ALLOWS OPERATORS TO INCREASE PROFITS HARBISON-FSCHER LAST FLOW RATE (mcfd) PRESSURES VALVE STATUS POLLED Prior % of COLEMAN (psi) ALARM A B C Group Well # Date Time AOF 24 hr AOF mcf % of Act CSG TBG SALES STATUS Prod Tank Chem A Billy Bob # 2 14-May-06 10:32 AM 100 65 65% 75 115% 250 230 45 OPEN CLOSE CLOSE A Billy Bob # 3 14-May-06 11:15 AM 59 47 80% 65 138% 125 110 35 OPEN CLOSE CLOSE A Sally Sue # 1 14-May-06 2:00 PM 45 32 71% 28 88% 175 185 40 CLOSE CLOSE CLOSE A Hank's Praire # 5 1-Apr-06 8:00 AM 15 12 80% 8 67% 225 205 45 CLOSE CLOSE CLOSE A Treasure Trove # 1 14-May-06 9:35 PM 53 47 89% 30 64% 90 ACTIONABLE 95 110 OPEN CLOSE CLOSE A B B DATA Bluebonnet 5 Exxon 88-Z3456 Macky's 2E4 14-May-06 14-May-06 14-May-06 12:52 AM 10:32 AM 11:15 AM 75 100 59 32 65 47 43% 65% 80% 25 75 65 78% 115% 138% 193 250 125 187 230 110 25 45 INFORMATION 35 OPEN OPEN OPEN CLOSE CLOSE CLOSE CLOSE CLOSE CLOSE B Smith BR549 14-May-06 2:00 PM 45 32 71% 28 88% 175 185 95 CLOSE CLOSE CLOSE B Henry's Gander 1-Apr-06 8:00 AM 15 12 80% 8 67% 225 205 45 CLOSE CLOSE CLOSE B Rainbow 6 14-May-06 9:35 PM 53 47 89% 30 64% 90 95 35 OPEN CLOSE CLOSE B Willow Root 4 14-May-06 12:52 AM 75 32 43% 25 78% 193 187 25 OPEN CLOSE CLOSE C GPS 40:56:75 14-May-06 10:32 AM 100 65 65% 75 115% 250 230 45 OPEN CLOSE CLOSE C Conoco 87-692 14-May-06 11:15 AM 59 47 80% 65 138% 125 110 35 OPEN CLOSE CLOSE C Conoco 87-719 14-May-06 2:00 PM 45 32 71% 28 88% 175 185 40 CLOSE CLOSE CLOSE C Charlie's Back 40 1-Apr-06 8:00 AM 15 12 80% 8 67% 225 205 45 CLOSE CLOSE CLOSE C Treasure Trove # 1 14-May-06 9:35 PM 53 47 89% 30 64% 90 95 110 OPEN CLOSE CLOSE C D Phone Bluebonnet 5 Sedona 1 14-May-06 14-May-06 12:52 AM 10:32 AM 75 100 32 65 43% 65% 25 75 78% 115% 193 250 187 230 25 Available 45 OPEN OPEN CLOSE CLOSE CLOSE CLOSE D D D Book Casper 06-1492 Michigan by 4 Full House, Ace's Hi 14-May-06 14-May-06 1-Apr-06 11:15 AM 2:00 PM 8:00 AM 59 45 15 47 32 12 80% 71% 80% 65 28 8 138% 88% 67% 125 175 225 110 185 205 35 Tee Times 40 45 OPEN CLOSE CLOSE CLOSE CLOSE CLOSE CLOSE CLOSE CLOSE D BP 05-B1476 14-May-06 9:35 PM 53 47 89% 30 64% 90 95 110 OPEN CLOSE CLOSE D BP 06-A1348 14-May-06 12:52 AM 75 32 43% 25 78% 193 187 25 OPEN CLOSE CLOSE NOTES: 1) AOF = Absolute Open flow HFOPTIMISER.COM 2) Group's could be Engineer's Name or Other Designation. 3) Allow sorting by any column 4) Provide a variety of column headings from which customer can choose to show, and choose the order.
  • 25. ADENDUM WELL REQUIREMENTS FOR PLUNGER LIFT FLUID VOLUME VS FLUID HEIGHT IN TUBING FLUID VOLUME VS TUBING DIAMETER CASING PRESSURE REQUIRED (FOSS AND GAUL) HFOPTIMISER.COM
  • 26. WELL REQUIREMENTS FOR PLUNGER LIFT FLUID SLUGS ON GAS CHARTS IS FLUID IN THE TUBING? DECLINE CURVE ANALYSIS (Over 90% of US Gas Wells) CRITICAL FLOW RATE YES 300 SCF / BBL / 1,000 FT OF LIFT IS GAS VOLUME SUFFICIENT ? PACKER YES LIFT PRESSURE at Least IS GAS PRESSURE DOUBLE FLUID LOAD SUFFICIENT ? LOAD LIFT PRESSURE = (CP- LP) FACTOR FLUID LOAD = (CP – TP) (Shortly after Shut-In) HFOPTIMISER.COM
  • 27. FLUID VOLUME VS FLUID HEIGHT  Fluid Volume in Tubing (Barrels) 2  FV = 0.002242 X (CP-TP) X (ID )/SG  CP=Casing Pressure; TP=Tubing Pressure  ID=Tubing Inner Diameter (inches)  SG = Specific Gravity = 1.0 for Water  Fluid Height in Tubing (Feet)  FH = (CP-TP) / (0.433 psi/ft X SG)  0.433 psi/ft = Pressure gradient of water  SG = Specific Gravity = 1.0 for Water  If 20% of the fluid column is liquid, then divide the above results by 20% to get the actual height of the fluid column HFOPTIMISER.COM
  • 28. FLUID VOLUME VS TUBING SIZE BACKPRESSURE FLUID VOLUME FH = (CP-TP) / (0.433 PSI/FT X SG) vs TUBING SIZE 500 FEET = (CP-TP) / (0.433 PSI/FT) 1.90”, 3.73 lb/ft Tubing (1.500” ID) (CP-TP)= 216.5 PSI FV = 0.002242 X (CP-TP) X (ID2)/SG FV = 0.002242 X (216.5 psi) X 1.502 FV = 1.09 Bbls Casing 2 3/8”, 4.70 lb/ft Tubing (1.995” ID) FV = 0.002242 X (CP-TP) X (ID2)/SG FV = 0.002242 X (216.5 psi) X 1.9952 Tubing 500 feet FV = 1.93 Bbls 2 7/8”, 6.50 lb/ft Tubing (2.441” ID) FV = 0.002242 X (CP-TP) X (ID2)/SG FV = 0.002242 X (216.5 psi) X 2.4412 FV = 2.89 Bbls HFOPTIMISER.COM
  • 29. FLUID VOLUME VS TUBING SIZE • Foss and Gaul (CP Required to Lift Plunger) – CPreq’d = CPmin X {(Aann + Atbg) / Aann} – CPmin = {SLP + Pp + PcFV} X {1 + D/K} • CP = Casing Pressure; SLP = Sales Line Pressure • Aann = Area Annulus; Atbg = Area Tubing • Pp = Pressure required to lift just the plunger • Pc = Pressure Required to lift 1 bbl of fluid and overcome friction • FV = Fluid Volume above the Plunger • K = Constant accounting for gas friction below the plunger Tubing K Pc • D = Depth of the Plunger 2 3/8 33,500 165 2 7/8 45,000 102 3 57,600 67 HFOPTIMISER.COM