X

Track changes made to this page

If you find this page useful and would like to be notified of changes made to this page, start by inputting your email below.



Privacy policy
Close this window

powered by ChangeDetection

34-069-20067

Well Details

Well ID: 34-069-20067
Loading map...
Country: United States
State: Ohio
County: Henry
Municipality: Richfield Township
Operator Name: OGE ENERGY LTD
Well Pad ID:
Farm/Lease Name: SONNENBERG
License Status: Producing
License Date: 1999-03-17
Spud Date: 1999-05-10
Spud Drilling Contractor:
Final Drill Date: 1999-05-10
Well Total Depth: 1770.00 ft
Configuration: Vertical
Latitude: 41.330000
Longitude: -83.960000

For data sources see[1]

Well History

Well Status Well Status Date Comment
CO 1976-02-27 772 GRAHAM MICHAELIS CORP GeoDate 2/27/76
Original Spud 1976-05-05 CONVERTED BACK TO PRODUCTION WELL 01/04/2006 (NO PERMIT ISSUED TO DO SO. JG) CONVERT 6-22-2000, RO 3-20-99, DF=683.8
CO 1992-12-17 772 GRAHAM MICHAELIS CORP GeoDate 12/17/92
GAS WELL 1992-12-17 Issued Date 12/17/92 Expired Date 12/17/93 Proposed Purpose OG Was Plug Supervised Y Who Superivsed FAUST, SAMUEL E.Plug and Abandon Date 5/7/93
Plugged/Abandoned 1993-05-07 CONVERTED BACK TO PRODUCTION WELL 01/04/2006 (NO PERMIT ISSUED TO DO SO. JG) CONVERT 6-22-2000, RO 3-20-99, DF=683.8
Change of Owner 1999-03-05 Operator changed from 772, GRAHAM MICHAELIS CORP to 6136, AURORA ENERGY LTD. APPLICATION WAS FOR A REOPEN IN WHICH WE DO NOT NEED A CHANGE OF OWNER FOR.
APP 1999-03-17 Proposed Formations:TRENTON, Issued Date:3/17/99, Expired Date:3/16/00 6:00:00 AM, Drilling unit acres:10, Proposed Well Type:OG, Proposed Well Class:POOL
Completed 1999-05-10 CONVERTED BACK TO PRODUCTION WELL 01/04/2006 (NO PERMIT ISSUED TO DO SO. JG) CONVERT 6-22-2000, RO 3-20-99, DF=683.8
Reached Total Depth 1999-05-10 CONVERTED BACK TO PRODUCTION WELL 01/04/2006 (NO PERMIT ISSUED TO DO SO. JG) CONVERT 6-22-2000, RO 3-20-99, DF=683.8
APP 2000-06-22 Proposed Formations:TRENTON, Issued Date:6/22/00, Expired Date:6/22/01 6:00:00 AM, Drilling unit acres:10, Proposed Well Type:OG, Proposed Well Class:ERP
Last Compliance Report 2006-01-04 CONVERTED BACK TO PRODUCTION WELL 01/04/2006 (NO PERMIT ISSUED TO DO SO. JG) CONVERT 6-22-2000, RO 3-20-99, DF=683.8
Completion Report Received 2006-01-05 CONVERTED BACK TO PRODUCTION WELL 01/04/2006 (NO PERMIT ISSUED TO DO SO. JG) CONVERT 6-22-2000, RO 3-20-99, DF=683.8
APP 2006-02-13 Proposed Formations:TRENTON, Issued Date:2/13/2006, Expired Date:2/13/2007 6:00:00 AM, Drilling unit acres:10, Proposed Well Type:OG, Proposed Well Class:POOL
Change of Owner 2006-10-03 Operator changed from 6136, AURORA ENERGY LTD to 8096, OGE ENERGY LTD
Construction Permit Expires 2007-02-13 CONVERTED BACK TO PRODUCTION WELL 01/04/2006 (NO PERMIT ISSUED TO DO SO. JG) CONVERT 6-22-2000, RO 3-20-99, DF=683.8
Record Last Modified 2017-02-15 CONVERTED BACK TO PRODUCTION WELL 01/04/2006 (NO PERMIT ISSUED TO DO SO. JG) CONVERT 6-22-2000, RO 3-20-99, DF=683.8

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2012-05-18 1663 1688 48
2012-05-18 1512 1608 0
1670 1682 24
1663 1688 48
1512 1608 0
1512 1608 0
2006-09-11 1692 1714 44
2006-09-11 1670 1682 24

For data sources see[3]

Stimulations Data

Stimulation Date Chemical Agent Chemical Agent Concentration (%) Fracking Fluid Volume Mass of Proppant Used (lb) Fracking Company Comments
Not Treated 0 0 0
ACID 28 5000 Gal 0
ACID 28 5000 Gal 0
ACID 0 2000 Gal 0 WELL GAUGED 47MCF
ACID 0 2250 Gal 0 WELL GAUGED 130MCF, ALSO SEE OTHER COMPLETION.

For data sources see[4]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
1991 GRAHAM MICHAELIS CORP 0.00 0.00 365
1999 AURORA ENERGY LTD 77.00 0.00 14
2000 AURORA ENERGY LTD 0.00 0.00 0
2005 AURORA ENERGY LTD 21.00 0.00 57
2006 OGE ENERGY LTD 37.00 0.00 0

For data sources see[5] [6]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
1991 GRAHAM MICHAELIS CORP Brine 0 365
1999 AURORA ENERGY LTD Brine 0 14
2000 AURORA ENERGY LTD Brine 0 0
2005 AURORA ENERGY LTD Brine 1225 57
2006 AURORA ENERGY LTD Brine 9 106

For data sources see[7] [8]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1296123606 2012-1-4 0:00:0 PW No Violations
-1393011145 2009-10-15 0:00 AM No Violations
-1616746435 2005-11-8 0:00: ER No Violations
-1869841307 2003-7-2 0:00:0 ER No Violations
-2024735190 2011-8-8 0:00:0 PW No Violations
0000013385 Final Restoration No Violations PASSED Y WITNESSED 8/4/94 INSPECTOR FAUST, SAMUEL E. DATE 08/0419/94 DATA FROM OLD VAX INFO
0000013386 Final Restoration No Violations PASSED Y WITNESSED 5/18/93 INSPECTOR DATE 05/1819/93 DATA FROM OLD VAX INFO
0006973513 2001-08-23 Salt Water Injection Well No Violations Small injection pump running at this time. Could not chk annulus pressure, no 1/4 inch tap for my gauge.
0034073717 2002-08-21 Preliminary Restoration No Violations Preliminary restoration done.
0353113520 2013-01-31 Production Wells No Violations At the time of the inspection the well was shut. There was 0 psi on the annulus gauge and no gauges on the production lines. There were no signs of any leaks. The corrective action from the Compliance Notice issued in 2011 has not been completed. The inspection was done at the request of Eric Vendel from The Ohio Division of Oil and Gas.
0583332638 2015-02-11 Production Wells Violations Noted At the time of the inspection the well was still shut in and has not produced since the previous inspection on 1-31-2013. The well is capable of production but no Production Records have been filed since 2006. No Hydrogen Sulfide was detected but this is a known Hydrogen Sulfide area so precaution should be taken during any service or plugging work. There has been no response from OGE Energy to previous Compliance Notice #2024735190 issued on 9-8-2011. This well is hereby ordered to be plugged and the land restored by 9-11-2015.
1046727616 2003-03-03 Enhanced Recovery Project Violations Noted Main valve from the flow line shut in. No ID at well head.
1047484310 2003-03-03 Enhanced Recovery Project Violations Noted Checked tank battery site and injection well with Jeff Fry. Checked pressure at well. Pressure at injection side was 140 lbs and annulus pressure was 80 lbs. Request operator to install 1/4 inch needle valve at 2 inch baylon valve. This would be safer when checking pressure and would release less annulus pressure. There was no well identification at the injection well site. A sign must be posted which includes company name, phone number, permit number, lease name, township and county. The sign should be posted by 3/25/03.
1051101872 2003-04-23 Salt Water Injection Well Violations Noted Sign posted at wellhead. Chiefs Order for failure to post sign will be terminated. Valves to check annulus and injection pressure are 1/2 inch fittings. Gauge to check pressures require 1/4 inch fittings. The valves and fittings to check annulus and injection pressure must be in good working order. This is important so chance for damage to wellhead is minimized during inspection. Install 1/4 inch valve at annulus and injection monitoring locations. Could not check pressure at well. No gauges attached to wellhead. Noted gauge with 2 inch fitting next to wellhead.
1052162025 2003-04-23 Enhanced Recovery Project Violations Noted Sign posted at wellhead. Notice of Violation for failure to post sign will be terminated. Valves and fittings to check annulus and injection pressure are 1/2 inch fittings. Gauge to check pressure requires 1/4 inch fittings. The valves and fittings to check annulus and injection pressure must be in good working order. This is important so chance for damage to wellhead is mininmized during inspection. Install 1/4 inch valve at annulus and injection monitoring locations. Could not check pressure at well. No gauges attached to wellhead. Noted gauge with 2 inch fitting at wellhead.
1054755355 2003-06-04 Enhanced Recovery Project No Violations Company has installed 1/4 inch valves as requested per NOV.

Checked annulus and injection pressure at well. Annulus and injection pressure were both 130 lbs. This may indicate an integrity problem with the well. Request operator contact inspector at 937-599-1445 for field test of pressure on the well.

1055772995 2003-06-04 Enhanced Recovery Project No Violations Checked injection well with Jeff Fry. New valves were installed with 1/4 inch fittings on annulus and injection pipes. NOV will be terminated. Pressure check on annulus and injection show pressure at equalibrium. Inspection on 3/3/03 showed injection pressure 140 and annulus pressure 80. A problem may have developed with the well since pressures are now equal. Spoke to Tony Krieder by phone. He indicated that the well was not cuurently being used for injection. Requested that Tony contact the inspector for on site inspection to check well together. If a problem has developed with the well, it will need to be repaired or plugged.
1065615502 2003-10-08 Enhanced Recovery Project No Violations Checked pressure at well. Injection pressurewas 150 psi and annulus pressure was 85 psi. No problems noted.
1071581320 2003-12-16 Enhanced Recovery Project No Violations Checked pressure at well site. Injection side 140 psi. Annulus side 80 psi. ID sign posted at well. No problems noted.
1077729186 2004-02-25 Enhanced Recovery Project No Violations Sign posted. Annulus pressure 100 psi and injection pressure 125 psi.
1084470177 2004-05-12 Enhanced Recovery Project No Violations Well surrounded by crops. Injection pressure 130 psi, annulus pressure 100 psi. No problems noted.
1089911202 2004-07-15 Enhanced Recovery Project No Violations Sign posted. Injection pressure 130 psi, annulus pressure 150 psi.
1095965504 2004-09-23 Enhanced Recovery Project No Violations Sign posted. Injection pressure 125 psi. Annulus pressure 220 psi.
1096379791 2004-09-28 Enhanced Recovery Project No Violations Met with consultants Dean Franks and John Dooley in preparation of resuming well production and brine injection. Operation has been inactive for over 2 years. The tank battery located at the scrubber plant is not properly diked. There are two 400 barrel brine tanks and one 300 barrel oil tank. There is a plastic liner (approximately 200 mils) under the tanks. A dike with an impermeable liner, which is capable of containing the contents of the combined tank capacity, must be constructed around the tank battery before production resumes. Request inspector be notified when dike construction completed.
1100618458 2004-11-16 Enhanced Recovery Project No Violations Reviewed construction of dike and liner for brine tanks for injection well. Dike appears to be constructed to design submitted. Liner overlaps dike and is being cover with dirt and stone to keep liner in place. No pressure readings taken at wellhead this day. Spoke to Tony Krieder by phone (419-748-8226). He anticipated that operations may resume in the next month.
1104942525 2005-01-05 Enhanced Recovery Project No Violations Spoke to operator Tony and Aurora employee Mark at gas plant before inspection. Production has not yet resumed. Drilling for new injection well will probably be started in a few weeks. Checked pressure on existing injection well.
1112194794 2005-03-30 Enhanced Recovery Project No Violations Checked pressure on injection well. Injection pressure was 110 psi and annulus pressure was 575 psi. Permit allows for maximum injection pressure of 500 psi, however the annulus pressure is not resticted to this maximum psi.
1118945984 2005-06-16 Enhanced Recovery Project No Violations Checked pressure on well. Annulus side showed 650psi and injection side 180 psi. ID sign posted.
1126558954 2005-09-12 Enhanced Recovery Project No Violations Checked well for pressure. Annulus side shows 660 psi while injection side was 330 psi. Spoke to operator about well use since new injection well is now in service. Operator will decide if to change to production well or plug.
1135879940 2005-12-27 Production Wells No Violations This well now appears to be a production well as noted by the pumpjack operating on the well. Phone conversation with John Hunter on 11/8/05 requested that a well completion form be submitted to the Columbus office indicating a change in the status of the well from injection to production. No correspondence has been received from the operator regarding this change and should be submitted ASAP. If you have any questions, please contact inspector at 419-599-0058.
1191531076 2007-10-04 Salt Water Injection Well No Violations Sign posted at well is for previous company. New ID sign needs to be posted. No injection pressure but annulus pressure at 480 psi. New gauges on well.
1283006418 2020-3-4 0:00:0 PW No Violations
1296123606 2012-01-04 Production Wells No Violations No change from last inspection. NOVs from last inspection on 8/5/2011 still need resolved.
1302622957 2011-04-12 Production Wells No Violations Check on status of NOV that I received after Ken retired. It is not clear that the NOV is still valid, it may have been resolved previously by inspector Pispanin. The well has been converted back to a production well. The well does not appear to have been produced for some time, due to the conditions at the well site. Overgrown with weeds and no lease road. The gas plant and injection facilities have been shut down. An attempt to contact the company was unsuccessful. The phone numbers given in RBDMS are no longer valid.
13385 FR No Violations
13386 FR No Violations
1393011145 2009-10-15 Administrative Inspection No Violations Inspection report to terminate NOV.
1616746435 2005-11-08 Enhanced Recovery Project No Violations Spoke to operator Tony on site. The well is being converted back to a production well. A temporary bridge plug has been placed in the well. Spoke to John Hunter by phone. A well completion form must be submitted to indicate the changes made to the well. The form should also indicate that the well is no longer being used as an injection well.
1869841307 2003-07-02 Enhanced Recovery Project No Violations Met on site with Tony Krieder to check pressure on the well since previous inspection showed injection and annulus pressure at equilibrium. Pressure was checked before any changes were made to well. Pessure on injection side showed 135 psi on both inspector and operator gauge. Pressure on annulus side showed 125 psi on both inspector and operator gauge. Tony indicated that injection pressure fluctuates and annulus pressure drops about 5 psi when gauges are attached/removed. This would account for equal pressures noted at previous inspection. Annulus pressure was dropped to 75 psi to avoid confusion in the future. Thank you for your cooperation in this matter.
2024735190 2011-08-08 Production Wells Violations Noted Well located in corn field. No lane to well. No production records since 2000. 8 withcasing head, 4.5 with casing head, tubing, and rods. No pumpjack on well. No I.D. on well.
34073717 2002-8-21 0:00: PL No Violations
353113520 2013-1-31 0:00: PW No Violations
583332638 2015-2-11 0:00: PW No Violations
6973513 2001-8-23 0:00: SW No Violations

Violations Commited

Inspection ID Violation ID Violation Date Violation Code Violation Comments
0583332638 US-OH-126549 2015-05-19 Well shall be plugged
1046727616 US-OH-100738 2003-03-03 Insufficient/No identification
1047484310 US-OH-100760 2003-03-12 Insufficient/No identification
1051101872 US-OH-100850 2003-05-05 Violation of injection tubing/fitting requirements
1052162025 US-OH-100879 2003-06-16 Violation of injection tubing/fitting requirements
2024735190 US-OH-120583 2011-08-15 Failure to legibly identify well
2024735190 US-OH-120584 2011-08-15 Nonproduction; well shall be plugged or placed in temporary inactive status
2024735190 US-OH-120585 2011-08-15 Failure to register/obtain or maintain bond/insurance
2024735190 US-OH-120586 2011-08-15 Statement of annual production not filed

For data sources see[9]

References

  1. ↑ "Risk Based Data Management System - Well, tblLocational, tblPlugWell, tblInspection, tblCivilTownships and tblPad Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  2. ↑ "Risk Based Data Management System - Well and WellHistry Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  3. ↑ "Risk Based Data Management System - Perfs Table". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  4. ↑ "Risk Based Data Management System - tblStimulation Table". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  5. ↑ "Risk Based Data Management System - Production Table - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  6. ↑ "Combined Production - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  7. ↑ "Risk Based Data Management System - Production Table - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  8. ↑ "Combined Production - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  9. ↑ "Risk Based Data Management System - tblInspection, tblInspFail and tblinspFlDesc Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
Retrieved from "https://wellwiki-prod.cloud.arc.gwu.edu/index.php?title=34-069-20067&oldid=14149328"