Small Scale Field Test--Quarterly Reports

24th Quarter

Oct. 31, 2017

Q24_2017.pdf, Oct. 31, 2017 (Adobe Acrobat PDF file, 124 kB)

  1. Wellington project UIC Class VI permit was put on hold and the well is classified as temporary abandoned UIC Class II well.
  2. Three shallow water monitoring wells located in section 28 and perforated at 100 ft, 200 ft, and 50 ft depth were properly plugged and abandoned
  3. Well site locations were restored
    1. KGS 1-32, 2-32, and 1-28 sites to be restored, but wells to be left open for future work and reentry. Berexco will not do anything with the wells for at least a year.
    2. Berexco assumed responsibility to plug/recomplete all 3 wells.
    3. Removed shallow and deep monitoring gauges and other equipment.
    4. Returned all leased equipment.
  4. Seismometer network left in the field as-is with permission from operator and land owner.
  5. Wellington seismometer array is on loan by IRIS-PASSCAL until September 30, 2018 with the possibility of extension per Pnina Miller.

23rd Quarter

Aug. 1, 2017

Q23_2017.pdf, Aug. 1, 2017 (Adobe Acrobat PDF file, 886 kB)

  1. Wellington project team continues earthquake activity with 15 seismometer stations on loan from IRIS, 3 KGS seismometers and regional USGS stations: over 2,100 earthquakes have been documented (magnitude 0.4-2.5) since April 2015, northward progression from Oklahoma is recorded, 2.1 TB of Wellington earthquake data provided to DOE NETL in July 2017, several publications are in preparations or have been accepted.
  2. Since mid-April 2016, continuous (1-sec) baseline pressure measurements have been acquired in the perforated lower Arbuckle zone in the shut-in Class VI injector. Because of this monitoring, the well has not been retrofitted for installation of MVA tools (BP2 Milestone).
  3. Berexco's financial and insurance teams are researching viable approaches for providing insurance or alternative methods to satisfy financial responsibility requirements for UIC Class VI permit.

22nd Quarter

April 28, 2017

Q22_2017.pdf, April 28, 2017 (Adobe Acrobat PDF file, 1.2 MB)

  1. Day-to-day field operations similar to that reported in previous two quarters (Q20 and Q21) and are a continuation of Tasks 12-15
  2. Continued monitoring of CO2 plume movement
    1. Recorded volumes of CO2 produced, oil, and brine recovered
    2. Only seven wells are being monitored based on past geochemical analyses that indicate the CO2 plume has largely stabilized. Wells are currently being sampled for on-site (performed by KGS) and lab-based geochemical analyses (performed by Baker Chemicals). CO2 gas quality measurements are being performed by Berexco staff.
  3. The primary CO2 plume has been managed by pressure maintenance including use of two nearby injection wells and targeted fluid withdrawal in eight surrounding wells. The CO2 injection conforms largely to the stratigraphic architecture recorded in the geocellular model. Key work for the remainder of the CO2-EOR phase is to continue measuring all inputs and outputs to obtain accurate measurement of CO2 sequestered in the reservoir and the incremental oil produced from a single injection cycle.
  4. On March 31, 2017 the daily CO2 amount recorded was 1-8 MCFD. As of March 31, 2017, the cumulative produced CO2 accounts for 18% of the injected volume (no change from December, 2016).
  5. The re-processed 3D seismic was analyzed using AVAZ (Amplitude Variation with AZimuth) pre-stack methods which allowed mapping of fracture density and orientation in the Mississippian reservoir and the Arbuckle saline acquirer.
  6. CO2 fluid substitution seismic modeling in the Mississippian was completed.
  7. Data collected for the project is constantly being updated and pre-processed for uploading into web-based interactive database catalogue.

21st Quarter

April 20, 2017

Q21_2017.pdf, April 20, 2017 (Adobe Acrobat PDF file, 700 kB)

  1. Day-to-day field operations similar to that reported in previous two quarters (Q19 and Q20) and are a continuation of Tasks 12-15
  2. Continued monitoring of CO2 plume movement
    1. Recorded volumes of CO2 produced, oil, and brine recovered
    2. Only seven wells are being monitored based on past geochemical analyses that indicate the CO2 plume has largely stabilized. Wells are currently being sampled for on-site (performed by KGS) and lab-based geochemical analyses (performed by Baker Chemicals). CO2 gas quality measurements are being performed by Berexco staff.
  3. The primary CO2 plume has been managed by pressure maintenance including use of two nearby injection wells and targeted fluid withdrawal in eight surrounding wells. The CO2 injection conforms largely to the stratigraphic architecture recorded in the geocellular model. Key work for the remainder of the CO2-EOR phase is to continue measuring all inputs and outputs to obtain accurate measurement of CO2 sequestered in the reservoir and the incremental oil produced from a single injection cycle.
  4. On December 31, 2016 the daily CO2 amount recorded was 1-8 MCFD down from 190 MCFD on September 30th. As of December 31, 2016, the cumulative produced CO2 accounts for 18% of the injected volume (up from 16% in September).
  5. Preliminary decline curve analysis has been performed that predicts incremental oil production for the field for next 4-5 years
  6. The existing 3D seismic survey was re-processed and delivered. Currently, geophysical team is working on resolving seismic anisotropy to image fracture patterns and orientations in Mississippian reservoir.

20th Quarter

Nov. 29, 2016

Q20_2016.pdf, Nov. 29, 2016 (Adobe Acrobat PDF file, 8 MB)

  1. Day-to-day field operations similar to that reported last quarter (Q19) and are a continuation of Tasks 12-15
  2. Continued monitoring of CO2 injection
    1. Recorded volumes of CO2 produced, oil, and brine recovered
    2. Reduced well-based monitoring to seven wells after CO2 ended and continuous water injection began. Past geochemical analyses indicate the plume has largely stabilized. As such, only the seven innermost wells are currently being sample for on-site (performed by KGS) and lab-based geochemical analyses (performed by Baker Chemicals). CO2 gas quality measurements are being performed by Berexco staff.
  3. Since mid-April 2016, continuous (1-sec) baseline pressure measurements have been acquired in the perforated lower Arbuckle zone in the shut-in Class VI injector (See Appendix 1). Because of this monitoring, the well has not been retrofitted for installation of MVA tools (BP2 Milestone).
  4. The primary CO2 plume has been managed by pressure maintenance including use of two nearby injection wells and targeted fluid withdrawal in eight surrounding wells. The CO2 injection conforms largely to the stratigraphic architecture recorded in the geocellular model. Key work for the remainder of the CO2-EOR phase is to continue measuring all inputs and outputs to obtain accurate measurement of CO2 sequestered in the reservoir and the incremental oil produced from a single injection cycle.
  5. 5. On September 30, 2016 the daily CO2 amount recorded was 190 MCFD down from 450 MCFD on July 25th. As of September 30, 2016, the cumulative produced CO2 accounts for 16% of the injected volume (up from 11% in July).
  6. The new 2D seismic survey was acquired, processed, and delivered. For consistency, all 2-D seismic lines were processed or reprocessed using the most-recent technologies offered by Fairfield-Nodal (see Appendix 2).

19th Quarter

Aug. 11, 2016

Q19_2016.pdf, Aug. 11, 2016 (Adobe Acrobat PDF file, 7 MB)

  1. Completed injection of 1,101 truckloads, 21,784 US tons, 19,803 metric tons, approximately 374,000 MCF of CO2 on June 21, 2016. Total expenditures for purchasing CO2 were $1,964,000. Our overall price for CO2 was $90.16 per US ton from Linde Group.
  2. Injected completed in 165 days or approximately 5 months with an average of 120 tonnes per day of CO2 injected.
  3. Linde Group was able to provide nearly continuous CO2 supply to the site outside of a five day of interruption in April 2016.
  4. Successful monitoring of CO2 injection, prior to and during injection, and post-injection
    1. a. Recorded volumes of CO2 injected and CO2, oil, and brine recovered,
    2. b. Sampled fluids via on-site and lab-based geochemistry from 17 wells,
    3. c. Reduced well based monitoring to seven wells after CO2 ended and continuous water injection began,
    4. d. Operated Wellington seismometer array installing two accelerometers outside of field to improve location and magnitude of events,
    5. e. Since mid-April 2016 have recorded continuous (1-sec) baseline pressure measurements of the perforated lower Arbuckle zone in shut-in Class VI injection.
    6. f. Confirmed that SAR satellite images obtained to date have useful images for InSAR and moving to new ERS satellite with new radar with improved coherency of response in humid temperate climate. Also, frequency of scenes has been reduced from every 20 days to 8 days.
  5. The primary CO2 plume has been managed by pressure maintenance including use of two nearby injection wells and varying fluid withdrawal in eight surrounding wells. Also, fluid flow barriers and baffles with lower permeability lie south and east and downdip of the injection well, which have apparently limited CO2 migration beyond those areas. The CO2 injection thus far has verified the geomodel based on the well and seismic interpretations.
  6. The simulation used to forecast the design of pressure maintenance and injection of CO2 and to forecast the oil response has demonstrated its usefulness. Simulation forecasts are again being confirmed during the initial stages of waterflooding where oil production has reached a new well, #45, to the north of the injection well and one well location out from the inner ring of producing wells.
  7. The CO2 plume remains within the nearby producing wells that surround the injection well indicating conformance of this flood, demonstrating the matrix controlled permeability vs. fractures.
  8. Since the CO2 injection stopped in June 21st and continuous water injection began and this phase of injection is viewed upon as a success due to
    1. high level of sweep efficiency,
    2. lack of notable CO2 fingering beyond the plume,
    3. evidence for a bank of oil recognized by well production with notable increase incremental oil, but lack of significant CO2 production
  9. Cumulative ratio of produced/purchased CO2 is only 11% (as of July 25). No notable changes occurred until CO2 injection ceased and water injection was increased from 50 to 750 barrels on July 14th when the daily CO2 produced has begun falling from ~450 MCFD to half that rate on July 25th.
  10. A rate of 50 BWDP following CO2 injection was maintained to keep the plume stable until a 2D seismic profile could be acquired passing through the injection well. Producing wells were shut-in during the actual seismic survey.
  11. Acquisition of the 2D seismic was designed to have sufficient offset to allow optimized AVO (Amplitude vs. Offset) to evaluate this approach for detection of the CO2 plume during the Arbuckle injection.
  12. The new 2D seismic survey was acquired and will be processed in the same manner as the original 3D seismic survey. Moreover, 3D survey will be reprocessed to bring it to date with current methods offered by Fairfield-Nodal.

Previous Quarters

Q18_2016.pdf, May 17, 2016 (Adobe Acrobat PDF file, 12 MB)

Q17_2016.pdf, Feb. 9, 2016 (Adobe Acrobat PDF file, 13 MB)

Q16_2015.pdf, Oct. 12, 2015 (Adobe Acrobat PDF file, 13 MB)

Q15_2015.pdf, Aug. 12, 2015 (Adobe Acrobat PDF file, 4 MB)

Q14_2015.pdf, May 15, 2015 (Adobe Acrobat PDF file, 12 MB)

Q13_2015.pdf, Feb. 16, 2015 (Adobe Acrobat PDF file, 3 MB)

Q12_2014.pdf, Nov. 4, 2014 (Adobe Acrobat PDF file, 3 MB)

Q11_2014.pdf, revised Sept. 5, 2014 (Adobe Acrobat PDF file, 4 MB)

Q9_2014r.pdf, March 11, 2014 (Adobe Acrobat PDF file, 3 MB)

Q8_2013.pdf, Nov. 5, 2013 (Adobe Acrobat PDF file, 2 MB)

Q7_2013.pdf, May 6, 2013 (Adobe Acrobat PDF file, 925 kB)

Q6_2013.pdf, May 6, 2013 (Adobe Acrobat PDF file, 485 kB)

Q5_2013.pdf, Jan. 31, 2013 (Adobe Acrobat PDF file, 241 kB)

Q4_2012r2.pdf, Nov. 12, 2012 (Adobe Acrobat PDF file, 3 MB)

Q3_2012r.pdf, Revised Sept. 5, 2012 (Adobe Acrobat PDF file, 3.4 MB)

Q2_2012.pdf, May 2012 (Adobe Acrobat PDF file, 1.4 MB)

Q1_2012rev.pdf, March 2012 (Adobe Acrobat PDF file, 2.7 MB)

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South-central Kansas CO2 Project is a DOE-funded project of the Kansas Geological Survey. More ...

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