DUG 2010 Technical Workshop Presentation

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How to Make More production with Plunger Lift.

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DUG 2010 Technical Workshop Presentation

  1. 1. HFOPTIMISER.COM DEVELOPING UNCONVENTIONAL GAS TECHNICAL WORKSHOP MARCH 29, 2010 HOW TO MAKE MORE PRODUCTION WITH PLUNGER LIFT
  2. 2. HFOPTIMISER.COM  PLUNGER LIFT BENEFITS WITH TELEMETRY  HOW TO OPTIMIZE PRODUCTION  TROUBLESHOOT AND IMPROVE CONTENTS
  3. 3. HFOPTIMISER.COM PLUNGER LIFT SYSTEM PLUNGERS MOTOR VALVE CONTROLLER Bluetooth on Site Cell Phone Modem Licensed or SS Radio Satellite LUBRICATOR FLOW METER (EFM or MVT) ARRIVAL SENSOR BH SPRING SOLAR PANEL
  4. 4. HFOPTIMISER.COM  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 BENEFITS WITH TELEMETRY
  5. 5. HFOPTIMISER.COM  Decrease lost gas due to venting  Detection of some EFM calibration issues  Environmentally responsible  Improve site safety BENEFITS WITH TELEMETRY Ref: American Gas Stars Partner Program (Oct 2003) American Oil and Gas Reporter (Oct 2005) HF Opti-MISER Case Studies (2009-2010)
  6. 6. HFOPTIMISER.COM WELL MCF/D BBLS/D LINE PRESSURE LIFT 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 BENEFITS WITH TELEMETRY
  7. 7. HFOPTIMISER.COM BENEFITS WITH TELEMETRY 0 200 400 600 800 1000 1200 16-Jan-09 16-Feb-09 16-Mar-09 16-Apr-09 16-May-09 16-Jun-09 16-Jul-09 16-Aug-09 16-Sep-09 16-Oct-09 16-Nov-09 16-Dec-09 16-Jan-10 0 50 100 150 200 250 PRODUCTION LEVELED and STABILIZED ! Free Flowing Well Production Line Pressure HF OPTI-MISER installed
  8. 8. HFOPTIMISER.COM BENEFITS WITH TELEMETRY 0 200 400 600 800 1000 1200 1400 1600 1800 19-Apr-09 3-May-09 17-May-09 31-May-09 14-Jun-09 28-Jun-09 12-Jul-09 26-Jul-09 9-Aug-09 23-Aug-09 6-Sep-09 20-Sep-09 4-Oct-09 18-Oct-09 1-Nov-09 15-Nov-09 29-Nov-09 13-Dec-09 27-Dec-09 0 50 100 150 200 250 PRODUCTION LEVELED and STABILIZED ! Free Flowing Well Production Line Pressure HF OPTI-MISER installed
  9. 9. HFOPTIMISER.COM HOW TO OPTIMIZE PRODUCTION TUBING 5000 ft 1. PREVENT or QUICKLY DETECT UNPLANNED DOWNTIME 2. ELIMINATE FLOW RESTRICTIONS 3. USE RELIABLE HARDWARE 4. USE TELEMETRY WITH CRY-OUT 5. OPERATE AT LOWEST POSSIBLE FBHP (Cycle Frequently!) 6. OPTIMIZE PRODUCTION, OBSERVE PLUNGER VELOCITY 1. Fluid in Tubing (CP-TP) 2. Lift Pressure (CP-LP) CAUSE 1. Plunger Velocity 2. Production EFFECT REAL TIME E-MAILALERT Station Name: Well # 42 Alarm Text: Low Sales Press Time Logged: March 19, 2010, 11:19PM Value: 23.0 Set Point: 25.0 CASING
  10. 10. HFOPTIMISER.COM HOW TO OPTIMIZE PRODUCTION Well # 27 Well # 29 Well # 28 Well # 26 Well # 25 Well # 24 Well # 23 Well # 20 Well # 22 Well # 21 Well # 19 Well # 18 Well # 17 Well # 16 Well # 15 Well # 12 Well # 14 Well # 13 Well # 11 Well # 10 Well # 9 Well # 8 Well # 7 Well # 6 Well # 5 Well # 4 Well # 3 Well # 2 Well # 1
  11. 11. HFOPTIMISER.COM HOW TO OPTIMIZE PRODUCTION FOCUS ON PRODUCTION ! LOOK AT TRENDS LINE PRESSURE GAS PRODUCTION ~ E-Mail Alert ~ Low Line Pressure
  12. 12. HFOPTIMISER.COM HOW TO OPTIMIZE PRODUCTION CP TP LP Flow Rate Lift Pressure Liquid Load Well Closes Well Opens Head Gas Produced Plunger Arrives Lateral leg unloading Don’t shut-in too early
  13. 13. HFOPTIMISER.COM 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 HOW TO OPTIMIZE PRODUCTION
  14. 14. HFOPTIMISER.COM HOW TO OPTIMIZE PRODUCTION
  15. 15. HFOPTIMISER.COM TROUBLESHOOT AND IMPROVE 0 200 400 600 800 1000 1200 1-Oct-09 8-Oct-09 15-Oct-09 22-Oct-09 29-Oct-09 5-Nov-09 12-Nov-09 19-Nov-09 26-Nov-09 3-Dec-09 10-Dec-09 17-Dec-09 24-Dec-09 31-Dec-09 7-Jan-10 14-Jan-10 0 50 100 150 200 250 Production Line Pressure HF OPTI-MISER installed 17% AVG 196 Mcf OPEN on PRESSURE OPEN on TIME AVG 167 Mcf
  16. 16. HFOPTIMISER.COM TROUBLESHOOT AND IMPROVE Production Line Pressure 29% AVG 172 Mcf OPEN on PRESSURE OPEN on TIME AVG 133 Mcf
  17. 17. HFOPTIMISER.COM TROUBLESHOOT AND IMPROVE Production Line Pressure 39% By Pass Plunger replaced Dual Row Pad. Cycles more frequently.
  18. 18. HFOPTIMISER.COM TROUBLESHOOT AND IMPROVE Motor Valve Leaks. TP declines when well is closed Motor Valve Leaks or EFM calibration issue. Flow when well is closed.
  19. 19. HFOPTIMISER.COM TROUBLESHOOT AND IMPROVE TP is pushing fluid out. Possible candidate for a standing valve.
  20. 20. HFOPTIMISER.COM TROUBLESHOOT AND IMPROVE Well is closing when flow rate is increasing. Flow longer.
  21. 21. HFOPTIMISER.COM TROUBLESHOOT AND IMPROVE LP declines when well is closed. Unplanned venting to tank.
  22. 22. HFOPTIMISER.COM TROUBLESHOOT AND IMPROVE Added Standing Valve. Shorter Fall Time. Increased afterflow. 103%
  23. 23. HFOPTIMISER.COM TROUBLESHOOT AND IMPROVE Added Standing Valve 20%
  24. 24. HFOPTIMISER.COM A SYSTEM THAT ALLOWS OPERATORS TO INCREASE PROFITS HF OPTI-MISER WELL CONTROL SYSTEM HARBISON-FSCHER Prior % of 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 95 110 OPEN CLOSE CLOSE A Bluebonnet 5 14-May-06 12:52 AM 75 32 43% 25 78% 193 187 25 OPEN CLOSE CLOSE B Exxon 88-Z3456 14-May-06 10:32 AM 100 65 65% 75 115% 250 230 45 OPEN CLOSE CLOSE B Macky's 2E4 14-May-06 11:15 AM 59 47 80% 65 138% 125 110 35 OPEN 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 Bluebonnet 5 14-May-06 12:52 AM 75 32 43% 25 78% 193 187 25 OPEN CLOSE CLOSE D Sedona 1 14-May-06 10:32 AM 100 65 65% 75 115% 250 230 45 OPEN CLOSE CLOSE D Casper 06-1492 14-May-06 11:15 AM 59 47 80% 65 138% 125 110 35 OPEN CLOSE CLOSE D Michigan by 4 14-May-06 2:00 PM 45 32 71% 28 88% 175 185 40 CLOSE CLOSE CLOSE D Full House, Ace's Hi 1-Apr-06 8:00 AM 15 12 80% 8 67% 225 205 45 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 1) AOF = Absolute Open flow 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. NOTES: POLLED PRESSURES COLEMAN LAST VALVE STATUS (psi) FLOW RATE (mcfd) DATA ACTIONABLE INFORMATION Phone Book Available Tee Times
  25. 25. HFOPTIMISER.COM W E L L R E Q U I R E M E N T S F O R P L U N G E R L I F T F L U I D V O L U M E V S F L U I D H E I G H T I N T U B I N G F L U I D V O L U M E V S T U B I N G D I AM E T E R C AS I N G P R E S S U R E R E Q U I R E D ( F O S S AN D G AU L ) ADENDUM
  26. 26. HFOPTIMISER.COM WELL REQUIREMENTS FOR PLUNGER LIFT IS FLUID IN THE TUBING? (Over 90% of US Gas Wells) FLUID SLUGS ON GAS CHARTS DECLINE CURVE ANALYSIS CRITICAL FLOW RATE IS GAS VOLUME SUFFICIENT ? YES IS GAS PRESSURE SUFFICIENT ? YES 300 SCF / BBL / 1,000 FT OF LIFT LIFT PRESSURE at Least DOUBLE FLUID LOAD LIFT PRESSURE = (CP- LP) FLUID LOAD = (CP – TP) (Shortly after Shut-In) LOAD FACTOR PACKER
  27. 27. HFOPTIMISER.COM  Fluid Volume in Tubing (Barrels)  FV = 0.002242 X (CP-TP) X (ID 2 )/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 FLUID VOLUME VS FLUID HEIGHT
  28. 28. HFOPTIMISER.COM FLUID VOLUME VS TUBING SIZE 1.90”, 3.73 lb/ft Tubing (1.500” ID) FV = 0.002242 X (CP-TP) X (ID2 )/SG FV = 0.002242 X (216.5 psi) X 1.502 FV = 1.09 Bbls 2 3/8”, 4.70 lb/ft Tubing (1.995” ID) FV = 0.002242 X (CP-TP) X (ID 2 )/SG FV = 0.002242 X (216.5 psi) X 1.9952 FV = 1.93 Bbls 2 7/8”, 6.50 lb/ft Tubing (2.441” ID) FV = 0.002242 X (CP-TP) X (ID 2 )/SG FV = 0.002242 X (216.5 psi) X 2.4412 FV = 2.89 Bbls BACKPRESSURE FH = (CP-TP) / (0.433 PSI/FT X SG) 500 FEET = (CP-TP) / (0.433 PSI/FT) (CP-TP)= 216.5 PSI FLUID VOLUME vs TUBING SIZE 500 feet Casing Tubing
  29. 29. HFOPTIMISER.COM 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 • D = Depth of the Plunger K Pc 33,500 165 45,000 102 57,600 673 2 7/8 2 3/8 Tubing

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