Gas Well Deliquification Workshop Sheraton Hotel, February 23 25, 2015 Hygr Fluid System Gas Well Deliquification R.F. (Dick) McNichol: President, Hydro Pacific Pumps Daniel Booy: C-FER Technologies Jeremy Dobra: Trident Resources Clint Mason: Definitive Optimization
Contents Principle of Operation Field Installations Testing in Dewatering Consortium System Improvements Conclusions 2
Principle of Operation (1) Power Cycle Hydraulic fluid applies pressure to the transfer piston, forcing the piston upwards and pushing product fluid out the pump discharge The inlet check valve opens and allows more product fluid to enter the pump 3
Principle of Operation (2) Reload Cycle Hydraulic drive stops the over pressure to the piston Inlet check valve closes and the transfer piston check valve opens as gravity and pressure from accumulator returns the piston back to its original position Transfer piston is now ready for the next Power Cycle 4
Principle of Operation (3) Since power fluid is in one tubing string and produced fluid is in the other, only two tubing strings (jointed or coiled) are required Lowers initial capital cost Simplicity and ease of use allows system to be operated with little to no supervision Lowers operational cost Due to low power consumption, smaller units can be powered using solar collectors Increases environmental friendliness No moving parts on surface Safer Operation 5
Hygr Capabilities Present 35 B, C and D models built and tested up 30 BFD max depth 4000 ft. 45, 55 and 65 models initial design done 4G system proven in lab - patents pending Systems to 10,000 ft. being reviewed Engineering done for deeper sets and larger flow rates with alternative drive and reset options. 6
Hydro Pacific Pumps Patents 7
Field Installations: Devon Deployment: System: Status: Crestomere, Alberta (May 2011) Gas Dewatering New 3.5 Hygr Deployed successfully - <3 month payback 8
Field Installations: Apache Deployment: System: Status: Alix, Alberta (May 2011) Gas Dewatering 3.5 Hygrwith EDI wellhead gas driver & PLC controller Deployed running Apache designed field tests 9
Field Installations: Trident (1) Deployment: History: System: Status: Trochu, Alberta (July 2012) CBM Dewatering Low declining production and pressure, clear signs of liquid loading, required frequent swabbing (limited access during much of year) 35D Hygr, Gen 2 EDI gas driver & PLC controller Production 10X and increasing, pressure increasing, Client happy, reviewing other well candidates 10
Field Installations: Trident (2) 11
Field Installation: Trident (3) Saved on OPEX due to the elimination of swabbing Maintained constant production on-time Well went from a shut-in candidate to economic producer Very minimal water now left to pump off Pump being on a set timer is very practical for our operations team 12
Dewatering Consortium Testing A Gas Well Dewatering Pump Project began in 2011 to test a variety of artificial lift systems for gas well dewatering: Project Participants: Cenovus Energy, EnCana Corporation, Enerplus Corporation and Petroleum Technology Alliance Canada (PTAC) Portion of funding received from various government agencies, including Western Economic Diversification C-FER Technologies contracted as the technology service provider Hydro Pacific submitted application to have the Hygr pump tested in the consortium 13
Dewatering Consortium Testing Lab (1) Pumping system initially tested in C-FER laboratory, using custom built Deliquification Flow Loop Loop designed to target wells with low fluid inflow (<10 bpd) Controlled variables included pump discharge, casing and power fluid pressures Measured variables included production flow rate and electrical energy consumption 14
Dewatering Consortium Testing Lab (2) Hygr 35D pump tested. Results were as expected: Positive displacement (PD) pump: pumping rate independent of back pressure Could pump with very little pressure at the intake Able to pump in a pumped-off state Able to pump continuously with solids, ranging from 1% to 10% concentration (by volume) Able to clear 5 of solids from above the pump discharge pump after 18 hours of solids settling Surface back pressure valve eroded during continuous sand production 15
Dewatering Consortium Testing - Field Hygr pump was also selected for further testing in a controlled test well Would it function differently in the field due to realistic depth? Same pump and drive unit used in lab installed in the test well Pump hung using two ¾ coiled tubing strings Same tests performed as were done during lab testing (except for continuous solids testing) 16
Dewatering Consortium Testing Field (2) Results were different than lab testing: - Maximum achievable production was lower than in the lab as stroke timing was not changed to account for depth of set: - Piston was sometimes unable to return to the original position before next power cycle started due to this timing - Issue with pressure drop in the power fluid coiled tubing string (high viscosity oil): use of larger power fluid tubing in future sets will rectify the issue - Produced solids that came to surface after the 20 ft. solids settling test caused the surface BPCV to become sticky - Harder to keep surface back pressure at the expected level - Different valve construction in future to rectify issue (solids separation may be required in extreme cases) 17
Conclusions (1) Dramatically smaller footprint at each well site. More aesthetically appealing, smaller in physical presence. Dramatically fewer moving parts in total and only three moving parts downhole. Suitable for installation in horizontal wells. Easy to change and program strokes per minute and duration of on / off times to meet specific well conditions. 18
Conclusions (2) Can require less horsepower to operate and can be powered by solar energy for very low volume intermittent requirements. No sucker rod or tubing wear due to hydraulic impulse for power with no moving parts in the tubing. Engineering done for deeper sets and larger flow rates with alternative drive and reset options. Safer operation - no moving parts on surface 19
Hygr 4 G System the Next Step, 20
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