4 th Wellbore Integrity Network Meeting Monitoring i of Wellbore Performance at Penn West CO 2 -EOR Rick Chalaturnyk Geological Storage Research Group Department of Civil and Environmental Engineering University of Alberta 18th 19th March 2008 Hotel Concorde Montparnasse, Paris, France Outline of Presentation Penn West CO2-EOR Monitoring Project Integrated t Instrumentation t ti System in Observation Well Summary 1
Penn West CO2-EOR Monitoring Pilot Project A multi-year, multi-agency project for the monitoring of CO2 used for an enhanced oil recovery ypilot in central Alberta owned and operated by Penn West Energy Trust. The Alberta Energy Research Institute, Alberta Environment, Western Economic Diversification, Environment Canada, Natural Resources Canada and Penn West Energy Trust are partners in this three-year CO2 monitoring pilot project, the first of its kind in Alberta. Five organizations involved in research program Penn West Energy Trust Alberta Research Council Alberta Geological Survey University of Calgary University of Alberta Penn West CO2-EOR Pilot Location Penn West CO2-EOR Pilot P2 I1 100/7-11 well (the OBS Well) P1 102/7-11 well (the newly drilled production well) 2
Penn West CO2-EOR Monitoring Pilot Project The project will further advance the understanding of the fate of CO2 injected into petroleum reservoirs and enhance our understanding of the role that geological CO2 storage can play in responding to the risks of climate change. This project, which is utilizing leading-edge CO2 monitoring tools and applications, will add to the growing body of knowledge that is being developed in Canada on the capture and storage of carbon dioxide and its potential as a greenhouse gas mitigation option. Goals of Research Program Suitability of existing oil and gas pools for CO2-EOR and CO2 storage Cost effective monitoring programs for detecting and quantifying fate of CO2 Informing long-term (post-closure) monitoring programs Acquisition of experience in implementing monitoring technologies to assist in future development of regulatory framework Evaluation of verification and environmental monitoring methods for CO2 storage 3
Elements of the Intregrated Instrumentation System Overview of Instrumentation Well Design Wellbore Completion P/T Data Interpretation Observation Well, 6 Production Wells and 2 CO2 Injection Wells P2 I1 100/7-11 well (the OBS Well) P1 102/7-11 well (the newly drilled production well) 4
Geology and Design Completion 3 pairs of Ground Surface 0 Completion Configuration for Obs Well (100/7-11-48-9W5) 1100 All fluid sampling tubing, pressure/ geophone cables and 1120 gauge cables run to surface. From surface to 2 downhole Ardley Coal 434 1140 1200 md filled with inhibited fluid (water). All Knee Hill Tuff 494 1160 instrumentation strapped temperature to 2 3/8 tubing string. 506 fluid 1180 Formation 8 phone sampling pressure 1200 Cement Top at gauges 1200 md Edmonton 1220 ports Fluid Sampling Port #1 1240 at 1301 md. Port located within Annulus Geophone Sleipner CO pressure 1260 2, HCO 3, CO 2-3- Upper Lea Park zones where 1023 1280 porosity Saline Mayor is ~ 7% ions string 1300 Aquifer SUBSURFACE PRESSURE: Formation pressure Annulus pressure Lea Park Shale 1400 1420 1440 1460 1480 1500 1520 1540 1560 1580 1600 1620 Geochemical Component WATER COMPOSITION: 1320 Groundwater aquifer CO2SP Trace elements Belly River 1340 1360 Salinity pressure 1380 Time-lapse 3D seismic 1291.4 imaging: Cardium Zone Cardium Conglomerate Upper Cardium Sandstone Middle Cardium Sandstone Lower Cardium Sandstone 1599 1619 1619.5 1622 1630.5 1637.2 Fluid Sampling Port #2 at 1622 md. Port located within Upper/Middle Cardium SST Two (2) pressure/temp. gauges at 1302 md. P P and S wave velocity 8 Geophone String. Bottom phone at 1640 md and phone spacing is 20 m. Reflection horizons Seismic amplitude attenuation Two (2) pressure/temp. gauges at 1621 md. Two (2) pressure/temp. gauges at 1610 md. In the middle of the Cardium Zone. Performance Monitoring of P P Cementing 1303 m 24000 22000 1303 Press2 1610 Press1 1620 Press1 1620 m 1303 Temp2 T 1610 Temp1 T 1620 Temp1 Begin circulating prewash fluid Begin circulating cement Cement circulation finished Started Closing BOP Bags Bags Finished Closing Stopped pumping to maintain pressure Began bleeding off annulus pressure 60 55 Pressure, kpa 20000 18000 50 Temperature, C 45 ReservoirPressure 16000 40 14000 Pumping to pressure up annulus started 2/26/05 10:00:00 2/26/05 12:00:00 2/26/05 14:00:00 2/26/05 16:00:00 2/26/05 18:00:00 Time (m/d/y h:m:s) 35 5
Wellbore Completion Feb 27 to Mar 1 1100 1120 1140 1160 1180 1200 1220 1240 1260 1280 1300 1320 1340 1360 1380 1400 1420 1440 1460 1480 1500 1520 1540 1560 1580 1600 1620 Instrument Cables P T 1611mkb All Gauges Survive Installati on And Working Tbi Tubing punch 2 @ 1302 m 2 @ 1610 m 2 @ 1623 m Stabilization period P T 1302mkb Begin circulati on of brine to kill flow 6
Downhole Monitoring Technology Tubing C L Casing Cement Permanent installation system Formation Perforations Sample port Pressure and Temperature 2005-20062006 7
Pressure and Temperature 2006-2007 Pressures within Well Sheath - 2007 22500 50 22000 48 Pressure (kpa) 21500 21000 20500 P 1302mkb P 1611mkb T 1302mkb T 1611mkb 46 44 42 Temperature ( o C) 20000 40 19500 38 Jan/1 Mar/1 May/1 Jul/1 Sep/1 Nov/1 Jan/1 Mar/1 Month (2007) 8
Obs. Well Pressures P2 I1 100/7-11 well (the OBS Well) Pressure, kpa P1 1100 102/7-11 well (the newly drilled production well) 26000 1120 1140 P-1302mkb 6500 1160 1180 P-1611mkb 1200 24000 Inj10-11 P (kpa) 1220 1240 6000 1260 1280 1300 22000 1320 1340 5500 1360 1380 20000 1400 1420 1440 5000 1460 1480 18000 1500 WH (kpa) 1520 4500 1540 1560 1580 16000 1600 Jan/1 Mar/1 May/1 Jul/1 Sep/1 Nov/1 1620 Date/Time Wellhead (Surface) Press ure, kpa RESERV. http://pennwest.civil.ualberta.ca/index.htm Shallow Sensor May 2005 21000 42 20500 20000 P- 1302 mkb T-1302mkb 41.8 41.6 19500 41.4 19000 41.2 18500 41 18000 40.8 17500 40.6 17000 40.4 Apr/30 May/5 May/10 May/15 May/20 May/25 May/30 Jun/4 Jun/9 Date/Time 9
Deep Sensor May 2005 24000 49.1 P-1611mkb T1611 T-1611mkb 49.05 23500 49 48.95 23000 48.9 48.85 22500 48.8 48.75 22000 48.7 Apr/30 May/5 May/10 May/15 May/20 May/25 May/30 Jun/4 Jun/9 Date/Time Early P/T Reading 1. 2. 3. 4. System Period of on Stability Injection Recovering production P T Injector Inj. test 10MP above Reservoir pressure T dropped due to CO2 front Stopped injection test (3 days) Temperature going back to steady-state condition Pressure Fall off, Open valve Reservoir Pressure 1 2 3 4 10
We re sticking my house down this hole!! 4 th Wellbore Integrity Network Meeting Monitoring i of Wellbore Performance at Penn West CO 2 -EOR Rick Chalaturnyk Geological Storage Research Group Department of Civil and Environmental Engineering University of Alberta 18th 19th March 2008 Hotel Concorde Montparnasse, Paris, France Acknowledgements Alberta Energy Research Institute Alberta Environment Western Economic Diversification Environment Canada Natural Resources Canada Penn West Energy Trust EnergyINet - CO 2 Management Program 11