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34-031-24744

Well Details

Well ID: 34-031-24744
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Country: United States
State: Ohio
County: Coshocton
Municipality: Clark Township
Operator Name: BAKERWELL INC
Well Pad ID:
Farm/Lease Name: SAMPLES LOUISE
License Status: Final Restoration
License Date: 2018-07-20
Spud Date: 1982-02-14
Spud Drilling Contractor:
Final Drill Date: 1982-02-19
Well Total Depth: 3525.00 ft
Configuration: Vertical
Latitude: 40.430000
Longitude: -81.980000

For data sources see[1]

Well History

Well Status Well Status Date Comment
CO 1981-12-31 432 BAKERWELL INC GeoDate 12/31/81
Original Spud 1982-02-14 PD.NAT. & WTR. FDT=2ND GMM UPDATED PLUG SATUS PER PLUG REPORT UPDATE LOCATION PER DOGRM SURVEYOR 1/9/19 ALE.
Completed 1982-02-19 PD.NAT. & WTR. FDT=2ND GMM UPDATED PLUG SATUS PER PLUG REPORT UPDATE LOCATION PER DOGRM SURVEYOR 1/9/19 ALE.
Reached Total Depth 1982-02-19 PD.NAT. & WTR. FDT=2ND GMM UPDATED PLUG SATUS PER PLUG REPORT UPDATE LOCATION PER DOGRM SURVEYOR 1/9/19 ALE.
APP 2016-06-28 Proposed Formations:CLINTON SANDSTONE, Issued Date:6/28/2016, Expired Date:6/28/2018 12:00:00 PM, Drilling unit acres:20, Proposed Well Type:OG, Proposed Well Class:
APP 2018-07-20 Proposed Formations:CLINTON SANDSTONE, Issued Date:7/20/2018, Expired Date:7/19/2020 12:00:00 PM, Drilling unit acres:20, Proposed Well Type:OG, Proposed Well Class:
Plugged/Abandoned 2018-08-17 PD.NAT. & WTR. FDT=2ND GMM UPDATED PLUG SATUS PER PLUG REPORT UPDATE LOCATION PER DOGRM SURVEYOR 1/9/19 ALE.
Record Last Modified 2019-01-09 PD.NAT. & WTR. FDT=2ND GMM UPDATED PLUG SATUS PER PLUG REPORT UPDATE LOCATION PER DOGRM SURVEYOR 1/9/19 ALE.
Construction Permit Expires 2020-07-19 PD.NAT. & WTR. FDT=2ND GMM UPDATED PLUG SATUS PER PLUG REPORT UPDATE LOCATION PER DOGRM SURVEYOR 1/9/19 ALE.

For data sources see[2]

Stimulations Data

Stimulation Date Chemical Agent Chemical Agent Concentration (%) Fracking Fluid Volume Mass of Proppant Used (lb) Fracking Company Comments
H2O 0 1800 Bbl 60000

For data sources see[3]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
1984 BAKERWELL INC 0.00 1440.00 365
1985 BAKERWELL INC 0.00 1298.00 365
1986 BAKERWELL INC 0.00 884.00 320
1987 BAKERWELL INC 723.00 38.00 365
1988 BAKERWELL INC 0.00 421.00 365
1990 BAKERWELL INC 0.00 598.00 365
1992 BAKERWELL INC 0.00 513.00 365
1993 BAKERWELL INC 0.00 452.00 365
1994 BAKERWELL INC 0.00 436.00 365
1995 BAKERWELL INC 0.00 369.00 365
1996 BAKERWELL INC 0.00 442.00 365
1997 BAKERWELL INC 0.00 513.00 365
1998 BAKERWELL INC 0.00 372.00 365
1999 BAKERWELL INC 0.00 470.00 365
2000 BAKERWELL INC 0.00 373.00 0
2001 BAKERWELL INC 0.00 372.00 365
2002 BAKERWELL INC 0.00 359.00 365
2003 BAKERWELL INC 0.00 216.00 365
2004 BAKERWELL INC 0.00 0.00 365
2005 BAKERWELL INC 0.00 65.00 365
2006 BAKERWELL INC 0.00 213.00 365
2007 BAKERWELL INC 0.00 214.00 365
2008 BAKERWELL INC 0.00 200.00 365
2009 BAKERWELL INC 0.00 141.00 365
2010 BAKERWELL INC 0.00 143.00 365
2011 BAKERWELL INC 0.00 158.00 365
2012 BAKERWELL INC 0.00 75.00 366
2013 BAKERWELL INC 0.00 214.00 365
2014 BAKERWELL INC 0.00 71.00 365
2015 BAKERWELL INC 0.00 108.00 365
2016 BAKERWELL INC 0.00 0.00 365
2017 BAKERWELL INC 0.00 0.00 365
2018 BAKERWELL INC 0.00 0.00 365

For data sources see[4] [5]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
1984 BAKERWELL INC Brine 0 365
1985 BAKERWELL INC Brine 85 365
1986 BAKERWELL INC Brine 90 320
1987 BAKERWELL INC Brine 0 365
1988 BAKERWELL INC Brine 150 365
1990 BAKERWELL INC Brine 165 365
1992 BAKERWELL INC Brine 180 365
1993 BAKERWELL INC Brine 265 365
1994 BAKERWELL INC Brine 180 365
1995 BAKERWELL INC Brine 285 365
1996 BAKERWELL INC Brine 414 365
1997 BAKERWELL INC Brine 305 365
1998 BAKERWELL INC Brine 292 365
1999 BAKERWELL INC Brine 200 365
2000 BAKERWELL INC Brine 255
2001 BAKERWELL INC Brine 185 365
2002 BAKERWELL INC Brine 290 365
2003 BAKERWELL INC Brine 410 365
2004 BAKERWELL INC Brine 75 365
2005 BAKERWELL INC Brine 625 365
2006 BAKERWELL INC Brine 560 365
2007 BAKERWELL INC Brine 510 365
2008 BAKERWELL INC Brine 550 365
2009 BAKERWELL INC Brine 580 365
2010 BAKERWELL INC Brine 585 365
2011 BAKERWELL INC Brine 390 365
2012 BAKERWELL INC Brine 555 366
2013 BAKERWELL INC Brine 695 365
2014 BAKERWELL INC Brine 665 365
2015 BAKERWELL INC Brine 2110 365
2016 BAKERWELL INC Brine 0 365
2017 BAKERWELL INC Brine 0 365
2018 BAKERWELL INC Brine 216 365

For data sources see[6] [7]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1061860808 2018-8-20 0:00: PB No Violations 0.20
-315054660 2018-8-13 0:00: PB No Violations 1.00
0315054660 2018-08-13 Plug / Plug Back No Violations On the day of my inspection I met Joe Zollars at the well site to discuss the upcoming plug job. Joe said that he would be moving in tomorrow to start prepping the site to plug the well. Joe said that the casing is on a packer, so we will set the bottom plug through tubing, then rip and pull the production string, then go back in with tubing to finish setting the cement plugs.
1061860808 2018-08-20 Plug / Plug Back No Violations On the day of my inspection I found that Bakerwell was rigging down and moving out. The pit was closed, and the well was capped and covered. I spoke with Joe Zollars on the phone and he said that they used 9-1/2 bags of sack cement to top the well off this morning before they cut the casing and put the plate on.
1091008945 2019-10-4 0:00: FR No Violations 0.50
1095094214 2004-09-13 Production Wells No Violations Well in production .
1534340168 2018-08-15 Plug / Plug Back No Violations On the day of my inspection I found that Bakerwell was rigged up on the well and pulling tubing. The 1.5 inch diameter tubing was set on a packer and it was pulling slow. Bakerwell had the wellhead equipped with a rubber line leading to the pit to capture any fluid being swabbed out of the well as they pulled the tubing. The rig operator Joe Zollars said that they had Petroset scheduled to set bottom plug later in the day. When I returned to the site I found that Bakerwell had 3422 feet of the 1.5 inch tubing back in the well. Petroset pumped a bottom plug with 30 sacks of class A cement.
1534430010 2018-08-16 Plug / Plug Back No Violations On the day of my inspection I found that Bakerwell had all of the tubing back out of the well and they were running in with their ripping tools to part the 4.5 inch diameter casing. Joe Zollars found a telegraph at a depth of 2500 feet and he tried to rip the casing there. Joe lost his telegraph and came up one joint. He parted the casing at a depth of 2468 feet. Joe said that he would pull the 4.5 inch casing from the well and run the 1.5 inch tubing back in to be ready for the Big Lime plug tomorrow. There was no information on the formation top in the well records. Bakerwell and I both agreed on an estimated formation top of 2240 feet for the Big Lime, based on offset well records. Joe agreed to run the tubing in to a depth of 2440 feet, or as close as possible.
1534522536 2018-08-17 Plug / Plug Back No Violations On the day of my inspection I found that Bakerwell had 1.5 inch diameter tubing ran to a depth of 2449 feet for the Big Lime plug. Petroset established circulation and circulated all of the oil out of the hole. Then they pumped 200 foot cement plug. Bakerwell pulled the tubing up to 973 feet for the Berea plug. Petroset established circulation and pumped a 180 foot cement plug. Bakerwell pulled the tubing up to 570 feet for the plug at the base of the surface casing. Petroset established circulation and pumped a 200 foot cement plug. Bakerwell pulled the tubing up to 200 feet for the surface plug. Petroset established circulation and pumped until cement was circulated to surface. Bakerwell pulled the remaining tubing and broke the wellhead down. We found that the cement had fallen out of site. Petroset filled the well to surface two more times and the cement stayed within 5 feet of the surface. Joe said that he would keep the well open overnight and top it off with sack cement. All of the plugs set today were set with class A cement with 2% gel. I spot checked the weight of the Berea plug and found it to be at 14.7 pounds per gallon.
1588862199 2020-5-7 0:00:0 FR No Violations 0.80
2145845997 2019-05-06 Final Restoration No Violations On the day of my inspection I found that the access road was still in place. There were some erosion ruts forming at the bottom of the road, but it was mostly in good shape. The well site was still very rough. There has been no grading or seeding done at the site or along the access road. There were still some materials and debris left at the site, and the pumping unit was still sitting at the access road entrance. The production tanks have been removed. I called Rex Baker and left a message to call me concerning the final restoration on this site.

For data sources see[8]

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 - tblStimulation Table". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  4. ↑ "Risk Based Data Management System - Production Table - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  5. ↑ "Combined Production - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  6. ↑ "Risk Based Data Management System - Production Table - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  7. ↑ "Combined Production - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  8. ↑ "Risk Based Data Management System - tblInspection, tblInspFail and tblinspFlDesc Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
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