Gas Well Deliquification Workshop Sheraton Hotel, February 23-26, 2009 Pressure Activated Chamber Technology (PACT) A new artificial lift system for CBM wells Leslie Lam, Black Hills Exploration Ryan Davis, Merrion Oil & Gas Mark Turland, ProActive Pumping Solutions Jim Wetzel, Nojak Pumping Solutions
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INTRODUCTION PACT technology applied to CBM and other wells in San Juan Basin PACT is being used to replace conventional rod pumping systems and plunger lift systems PACT system has no moving parts at surface and a very small footprint PACT uses very little energy and discharges no emissions 3
CONVENTIONAL ARTIFICIAL LIFT SYSTEMS (ALS) Critical issues to be considered in selecting an artificial lift system Geographic location Well bore design Depth MD & TVD Production requirements Operating pressures Properties of produced fluids Availability of electricity Companies operating philosophy 4
ALS FOR CBM WELLS Artificial lift systems currently in use in CBM wells in San Juan Basin Sucker Rod Pumping System (SRPS) Plunger Lift System (PLS) Electric Submersible Pump (ESP) Progressive Cavity Pump (PCP) Well Head Compression 5
SUCKER ROD PUMPING SYSTEM (SRPS) Well conditions and operating practices that reduce system efficiency No electricity Low produced fluid volume Fluid pound Gas engines limiting pump off controllers Tagging the pump Water lubrication Stuffing box leakage Safety 6
PLUNGER LIFT SYSTEMS (PLS) Factors affecting effectiveness of plunger lift systems Low producing bottom hole pressure Sticking plungers Compressor issues High sales line pressure Harmful emissions Reservoir problems 7
PRESSURE ACTIVATED CHAMBER TECHNOLOGY (PACT) System Overview Uses compressed gas from compressor to lift fluids Uses chambers connected by polytubing and supported by wireline, spaced 250 apart inside casing Compressed gas forces fluid to be lifted in timed cycles from one chamber to the next Optimized by adjusting cycle times 8
PRESSURE ACTIVATED CHAMBER TECHNOLOGY (PACT) 160 SYSTEM PUM PING CAPACITY 140 Pump Capacity (bbls/day) 120 100 80 60 Model 3000 3/8in gas lines 10ft chambers Model 3005 1/2in gas lines 10ft chambers Model 3020 1/2in gas lines 20ft chambers 40 20 0 0 500 1000 1500 2000 2500 3000 Pump Depth (ft) 9
CASE HISTORIES 3 wells are in operation using the PACT system Merrion Oil & Gas Panther #1 Merrion Oil & Gas Vine Com #1 Black Hills Exploration Jicarilla 29-03-13 #2 10
PANTHER #1 Operating parameters (SRPS) Pump depth 1750 Fluid production 22 bbls/day Gas production 185 mcf/day Location has electricity SRPS had well pumped off and pounding fluid SRPS has electric prime mover controlled by % timer Stuffing box leaks are an ongoing issue 11
PANTHER #1 12
PANTHER #1 Pumping System Configuration Merrion Oil & Gas Corporation Pump Depth 1756 Casing 4 ½ Installation 11/4/2008 13
PANTHER #1 PACT system results Water production 18 bbls/day Gas production 165 mcf/day Fluid level at 1630 ffs Based on compressed gas usage the energy cost is expected to be 14% of the compressor power consumption* * Compressor oversized for well conditions and goes into recirculation mode several times a day. 14
PANTHER #1 15
PANTHER #1 16
PANTHER #1 Factors affecting PACT performance System capacity miscalculated System freezing Compressor downtime Operator training Lack of excess capacity 17
VINE COM #1 Operating parameters (SRPS) Pump depth 1250 Water production 18 bbls/day Gas production 220 mcf/day Location has electricity SRPS had well pumped off and pounding fluid SRPS has electric prime mover controlled by % timer Stuffing box leaks are an ongoing issue 18
VINE COM #1 19
VINE COM #1 Pumping System configuration Merrion Oil & Gas Corporation Pump Depth 1248 Casing 4 ½ Installation 11/6/2008 20
VINE COM #1 PACT system results Water production dropped to 6 bbls/day Gas production increased to 225 mcf/day Fluid level shots verified that the system was pumped off Based on compressed gas usage the energy cost is expected to be 5% of the compressor power consumption 21
VINE COM #1 22
VINE COM #1 23
VINE COM #1 Factors affecting PACT performance System freezing Compressor downtime Operator training Lack of excess capacity 24
JICARILLA 29-03-13 #2 Operating parameters Perforations at 1300 Low pressure flowing gas well Initial production Oct 2001 176 mcf/day 4 bbls/day 2008 production 30 mcf/day 0 fluid Well head compression unsuccessful Swab tested Sep 2008 160 mcf/day 60 bbls/day 25
JICARILLA 29-03-13 #2 Production History 6000 Black Hill Gas Resources Jicarilla 29-03-13 #2 5500 5000 4500 4000 3500 3000 2500 2000 1500 1000 500 0 Mcf/Mo BW/Mo 26 10/2001 1/2002 4/2002 7/2002 10/2002 1/2003 4/2003 7/2003 10/2003 1/2004 4/2004 7/2004 10/2004 1/2005 4/2005 7/2005 10/2005 1/2006 4/2006 7/2006 10/2006 1/2007 4/2007 7/2007 1/2008 10/2007 4/2008 7/2008 10/2008
JICARILLA 29-03-13 #2 PACT system results First artificial lift installed on well Water level pulled below perforations after 3 weeks, production stable Fluid production 15 bbls/day Gas production 110 mcf/day Based on compressed gas usage the energy cost is expected to be 12% of the compressor power consumption 27
JICARILLA 29-03-13 #2 Installation concerns A frame not tall enough for installation over BOP Poly tubing and support cable controlled separately while de-spooling in well Small pieces used in installation could fall in well Unable to land assembly with BOP installed Difficulty installing BOP 28
JICARILLA 29-03-13 #2 29
JICARILLA 29-03-13 #2 30
CONCLUSIONS Installation requires provision to eliminate system freezing Pumping capacity must allow for expected compressor down time Improved operator training for system optimization is required Efficient and effective deliquification method Very environmentally friendly and safe 31
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