1. Experimental Technologies/Research
Robert C. Trautz
Sr. Project Manager
Knowledge Sharing in MVA/MMV
Mobile, AL
May 17, 2012

2. Outline
•!Comparison of Groundwater Sampling Methodologies
–!Collaboration with the US Geological Survey
•!Integrated Modular Borehole Monitoring (MBM) System
–!Collaboration between SECARB, CO2 Capture Project
and Berkeley Lab
© 2012 Electric Power Research Institute, Inc. All rights reserved. 2

3. Groundwater Sampling: Context
•!Above zone groundwater USGS photo: Fluid Sampling during Pumping at D9-8#2
monitoring may be used
as a compliance tool to
detect CO2 leakage
•!Samples undergo geo-
chemical transformation
when collected from
deep wells, e.g.,
–!Exsolution of dissolved
gases
–!Changes in dissolved CO2 concentrations that control pH
–!Exposure to atmosphere causes changes in redox
•!Industry needs best available practices for compliance
© 2012 Electric Power Research Institute, Inc. All rights reserved. 3

4. Groundwater Sampling Comparison
•!Purpose:
–!Compare sampling methods to identify significant
differences in groundwater quality results
–!Compare costs/benefits of each method
•!Scope: Collect and analyze groundwater samples using
four artificial lift techniques
1.! N2 gas lift
2.! Pumping
3.! Kuster Sampler (wireline)
4.! U-tube sampler
Photo Courtesy of the USGS photo: Fluid Samples from Gas Lift
© 2012 Electric Power Research Institute, Inc. All rights reserved. 4

5. USGS Field Sampling Campaign at Observation
Well D-9-8#2 (March 2012)
Photo Courtesy of the USGS : Mobile Field Sampling and Analytical Laboratory
© 2012 Electric Power Research Institute, Inc. All rights reserved. 5

6. Wellhead Monitoring Used to Guide Sample
Collection during N2 Gas Lift
Image Provided by the USGS
© 2012 Electric Power Research Institute, Inc. All rights reserved. 6

7. Integrated Modular Borehole Monitoring (MBM)
System (Berkeley Lab)
•! Purpose: Multi-sensor
platform designed for a
single-well deployment
!! Reservoir pressure
and temperature
!! 18-level geophones
for CO2 imaging
!! Distributed Temp.
Sensor (DTS) and
heater for near-well
leak detection
!! Distributed fiber optic
cable for seismic
measurements (Schematic courtesy of Paul Cook, Berkeley Lab)
!! U-tube fluid sampler
© 2012 Electric Power Research Institute, Inc. All rights reserved. 7

8. MBM Deployment
Geophone Clamping Assembly
•!Geophone array
(6,000-6,850 ft): three, xyz-
comp. and 15, z-comp.
phones at 50 ft spacing Flat-pack containing control lines,
u-tube sampler, and fiber optic/
•!Bottom hole assembly heater cable, sensor lines
(9,384 – 9,797 ft)
–!Hydroset II packer
–!U-tube
–!Overshot
–!Slotted tail pipe
(structural support for
DTS and heater)
–!Two quartz P & T gauges Geophone, Mechanical Clamp and Flat Pack
© 2012 Electric Power Research Institute, Inc. All rights reserved. 8

9. Pressure Communication
Observed Across Packer Hydroset II
Packer
•!Packer set at 9,384 ft
•!Kill fluid was unloaded
from the annulus but …
–!Flow continued
–!Annulus pressure
climbed when shut in
•!Pressure response was
observed by both
gauges below the
packer
•!Damaged Packer?
© 2012 Electric Power Research Institute, Inc. All rights reserved. 9

10. Berkeley Lab Well Diagnostics – Temperature
Profiles Using DTS During No Flow Conditions
Ambient Temperature (Blue)
Heated Temperature (Red) Packer
Flat
Pack
Rat Hole
Colder Kill Fluid
Temperature Profile along Entire Cable Temperature Profile Across Bottomhole
(0 – 9,800 ft +/-) Assembly (9,300-9,900 ft)
© 2012 Electric Power Research Institute, Inc. All rights reserved. 10

11. T Profiles During Heating ! Comparison of
No Flow to Flow (8.7 gpm) Conditions
Packer
Heat transfer
uphole Significant difference in T
above and below packer
indicates packer is set
© 2012 Electric Power Research Institute, Inc. All rights reserved. 11

12. Well Diagnostics Con’t – Inflow Above Packer
Inflow above packer
© 2012 Electric Power Research Institute, Inc. All rights reserved. 12

13. Summary
•!DTS and heater were successfully used to pinpoint inflow
above the packer
–!Packer is set in top of perforations
•!Discussed options with State Regulators including removal
–!Well has mechanical (pressure) integrity
–!Cement bond logs show good cement behind casing
–!D-9-8#2 is not permitted for injection
–!Completion similar to a production well or MS injector
–!Removal and re-deployment would be costly
–!Research equipment could be irreparably damaged
•!Successful diagnostics saved project $200,000 - $430,000
© 2012 Electric Power Research Institute, Inc. All rights reserved. 13

14. intelligent Distributed Acoustic Sensor
(iDASTM)
© 2012 Electric Power Research Institute, Inc. All rights reserved. 14

15. intelligent Distributed Seismic - VSP
•! Fiber Optic Cable being the sensor: provides very large receiver array (dense
sampling)
•! complete wellbore coverage for every source firing
•! dynamically change the sensor / antenna length to any value greater than one (1)
•! High fold with walk-away / 3-D VSP
•! Identification of lateral variations in lithology for Well-Placement and Landing ERD wells
•! 3-D Velocity and Anisotropy
© 2012 Electric Power Research Institute, Inc. All rights reserved. 15

16. Citronelle MBM Test
Raw Vibroseis on iDAS: Single Sweep, Uncorrelated
!"#$%&'()&
*&&&&&&&+,*&&&&&&&,**&&&&&&-,*&&&&&.***&&.+,*&&&&.,**&&&.-,*&&&+***&&&++,*&&&&+,**&&&&+-,*&&/***&&&
&
*&
.&
+&
/&
01("&'2)&
3&
,&
4&
-&
© 2012 Electric Power Research Institute, Inc. All rights reserved. 16

17. Together…Shaping the Future of Electricity
© 2012 Electric Power Research Institute, Inc. All rights reserved. 17