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34-111-21955

Well Details

Well ID: 34-111-21955
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Country: United States
State: Ohio
County: Monroe
Municipality: Summit Township
Operator Name: C G O INC
Well Pad ID:
Farm/Lease Name: BETA RAY
License Status: Final Restoration
License Date: 2018-03-30
Spud Date: 1980-05-20
Spud Drilling Contractor:
Final Drill Date: 1980-06-11
Well Total Depth: 2503.00 ft
Configuration: Vertical
Latitude: 39.800000
Longitude: -81.250000

For data sources see[1]

Well History

Well Status Well Status Date Comment
CO 1979-12-26 1 HOPEWELL OIL & GAS DEV CO GeoDate 12/26/79
Original Spud 1980-05-20 UPDATE WELL LOCATION PER DOGRM SURVEY 5/21/18 ALE.
Completed 1980-06-11 UPDATE WELL LOCATION PER DOGRM SURVEY 5/21/18 ALE.
Reached Total Depth 1980-06-11 UPDATE WELL LOCATION PER DOGRM SURVEY 5/21/18 ALE.
Change of Owner 1999-04-24 Operator changed from 1, HOPEWELL OIL & GAS to 2849, C G O INC
APP 2018-03-30 Proposed Formations:GORDON SAND, Issued Date:3/30/2018, Expired Date:3/29/2020 12:00:00 PM, Drilling unit acres:20, Proposed Well Type:OG, Proposed Well Class:
Plugged/Abandoned 2018-07-02 UPDATE WELL LOCATION PER DOGRM SURVEY 5/21/18 ALE.
Record Last Modified 2019-05-10 UPDATE WELL LOCATION PER DOGRM SURVEY 5/21/18 ALE.
Construction Permit Expires 2020-03-29 UPDATE WELL LOCATION PER DOGRM SURVEY 5/21/18 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 0 25000

For data sources see[3]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
1984 HOPEWELL OIL & GAS DEVELOPMENT 956.00 68.00 365
1985 HOPEWELL OIL & GAS DEVELOPMENT 1249.00 0.00 0
1986 HOPEWELL OIL & GAS DEVELOPMENT 1081.00 34.00 365
1987 HOPEWELL OIL & GAS DEVELOPMENT 3295.00 70.00 365
1988 HOPEWELL OIL & GAS DEVELOPMENT 2456.00 0.00 365
1989 HOPEWELL OIL & GAS DEVELOPMENT 2629.00 78.00 365
1990 HOPEWELL OIL & GAS DEVELOPMENT 2343.00 38.00 365
1991 HOPEWELL OIL & GAS DEVELOPMENT 2109.00 37.00 365
1992 HOPEWELL OIL & GAS DEVELOPMENT 1810.00 0.00 365
1993 HOPEWELL OIL & GAS DEVELOPMENT 1496.00 0.00 365
1994 HOPEWELL OIL & GAS DEVELOPMENT 1221.00 0.00 365
1995 HOPEWELL OIL & GAS DEVELOPMENT 1035.00 66.00 365
1997 HOPEWELL OIL & GAS DEVELOPMENT 696.00 0.00 365
1998 HOPEWELL OIL & GAS DEVELOPMENT 790.00 0.00 365
1999 HOPEWELL OIL & GAS DEVELOPMENT 304.00 0.00 60
2000 C G O INC 436.00 0.00 365
2001 C G O INC 352.00 0.00 365
2002 C G O INC 321.00 0.00 365
2003 C G O INC 263.00 0.00 365
2004 C G O INC 206.00 0.00 365
2005 C G O INC 169.00 0.00 365
2006 C G O INC 193.00 0.00 365
2007 C G O INC 320.00 0.00 365
2008 C G O INC 262.00 0.00 365
2009 C G O INC 103.00 0.00 365
2010 C G O INC 163.00 0.00 365
2011 C G O INC 171.00 0.00 365
2012 C G O INC 361.00 0.00 300
2013 C G O INC 294.00 0.00 300
2014 C G O INC 381.00 0.00 300
2015 C G O INC 183.00 0.00 360
2016 C G O INC 111.00 0.00 90
2017 C G O INC 0.00 0.00 0

For data sources see[4] [5]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
1984 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1985 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 0
1986 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1987 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1988 HOPEWELL OIL & GAS DEVELOPMENT Brine 37 365
1989 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1990 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1991 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1992 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1993 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1994 HOPEWELL OIL & GAS DEVELOPMENT Brine 60 365
1995 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1997 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1998 HOPEWELL OIL & GAS DEVELOPMENT Brine 0 365
1999 HOPEWELL OIL & GAS DEVELOPMENT Brine 60
2000 C G O INC Brine 3 365
2001 C G O INC Brine 0 365
2002 C G O INC Brine 2 365
2003 C G O INC Brine 0 365
2004 C G O INC Brine 1 365
2005 C G O INC Brine 0 365
2006 C G O INC Brine 3 365
2007 C G O INC Brine 2 365
2008 C G O INC Brine 0 365
2009 C G O INC Brine 0 365
2010 C G O INC Brine 0 365
2011 C G O INC Brine 0 365
2012 C G O INC Brine 0 300
2013 C G O INC Brine 0 300
2014 C G O INC Brine 0 300
2015 C G O INC Brine 0 360
2016 C G O INC Brine 0 90
2017 C G O INC Brine 0 0

For data sources see[6] [7]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1219753149 2015-4-9 0:00:0 PW No Violations 3.00
-270519246 2016-2-17 0:00: PW No Violations 1.00
0270519246 2016-02-17 Production Wells No Violations Status check follow up inspection to complaint # 4992 and violation # 1439478319 issued on 08/14/2015. Upon inspection it was observed that the electric service for the said well was disconnected between the well and the electric pole disconnect box, with the electric meter showing no current sales. No current activity was present around the well and the 1.5 tubing and 4.5 production casing valves are in the open position with the domestic supply valve being in the closed position with the landowner reporting He has reverted to propane as a primary fuel supply due to the well being unable to supply any quantity of gas. Also noted was the absence of any type of commercial gas sales sub meter to support any documentation of the output sales of gas being reported, and no communication has been received from the well owner in regards to the violation.
0473204081 2019-02-07 Final Restoration No Violations On this day, I am conducting a final restoration inspection. The site meets ORC 1509.072 (B).
1125853064 2018-06-26 Plug / Plug Back No Violations On this day, I accompanied ODNR Inspector William Stolarik and ODNR Inspector Ryan Armstrong. I am onsite to witness the plugging operation conducted by Harmons Well Services and Formation Cementing. Harmons has a service rig on the hole, (1) water-truck, and a half-round for fluid collection. Formation Cementing has a pump-truck and bulk-truck on location. Additionally, Timco was on location with a wireline truck and ran a Bond/VDL/CCL log, which indicated the top of cement, behind the 4.5 inch diameter casing, to be at a depth 1,830 feet, and a tight spot from 920-930 feet. 1.9 inch diameter tubing is inserted into the hole to a depth of 2,410 feet. Circulation was established and Formation Cementing initially pumped 200 pounds of bentonite gel ahead of cement. Then, they pumped the bottom plug that consisted of 30 sacks of cement with a 1.18 yield (6.3 barrels total volume), and a weight of 15.6 pounds per gallon. All tubing is being removed from the hole.
1219753149 2015-04-09 Production Wells No Violations Status check inspection in response to complaint # 4992. Upon inspection of the wellhead the following was witnessed present 4.5 production casing -1.5 tubing and pumping rods with the 4.5 production casing valve closed and the 1.5 tubing valve closed with the well set up to produce fluid by the means of a mechanical pumping unit. A domestic gas hook up and sales meter is present at the wellhead. The electrical service meter showed no recorded electric sales activity. At the production fluid storage area located near the wellhead a single 100 barrel storage tank was found present inside a established dike area along with a mechanical separator. In conversation with the Contract Pumper Troy Harmon it was indicated that the well was producing gas only with the gas sales meter located North of the residence along Twp Road 63 was commonly shared with multiple wells in the area. The Gatherco gas sales meter was witnessed as present with a current sales chart present. No individual gas sales meter was present at the well site. No violations noted on the day of my inspection.
1439478319 2015-08-13 Production Wells Violations Noted Follow up inspection to a previous complaint noted as complaint # 4992 filed by the landowner Kirk Bruce. On this day an inspection of the well head was conducted with the following noted as present at surface- 4.5 production casing- 1.5 production tubing and pumping rods with a pumping unit present. The production valve for the tubing was in the closed position, the 4.5 casing valve for both the commercial and domestic service was in the open position. (2) Baird 10-1500 psi working pressure range back pressure regulators were present on the commercial production outlets along with(2)Model 62 Stream Flow Brass check valve bodies in place. Present on location was the landowner Kirk Bruce and independent contractor Chuck Dye who on their own accord demonstrated that the house gas service had no (0) zero gas volume or pressure present on the domestic gas supply side by installing the 3000psi working pressure gauge provided by the State to be show as the official gauge of record. The landowner demonstrated the casing valve on the house gas service was functioning and also demonstrated the moisture separator drip tank was free of fluid and had no gas present and was found static upon the removal of the drain plug. A domestic gas meter was present and read 303 (30,300 cubic feet) on the rotary index chart, with the landowner stating the meter had been present and recording for a period of 15 years. Also noted the electric service line to the pumping unit is not connected and the electric meter has no current sales reading. At the production fluid storage area a single 100 barrel production tank is present with a mechanical separator which was also observed to have (0) zero pressure, no sub gas lease meter was observed as present on location or found on the property. Photographs were taken on this day. Instructions are as follows - plug the said well within 180 days. ODNR Monroe County Inspector Bill Stolarik 740-507-6592.
1487687842 2017-02-21 Production Wells No Violations Status check follow up inspection to complaint # 4992 and violation # 1439478319 issued on 08/14/2015. Upon inspection the well was observed to be equipped with 4.5 production casing and 1.5 diameter production tubing with both casing and tubing well heads present and the well set up to be produced by the means of a pumping unit. Flow lines are present and attached to both the casing and tubing well heads with production valves in line and in the closed position. On location near the well head is the production facility consisting of a single 100 barrel production tank along with a mechanical separator. No gas sales meter is present in the area of the well. The producer has not responded to the unresolved violation.
1492160332 2017-04-11 Production Wells No Violations
1530026211 2018-06-26 Plug / Plug Back No Violations On site inspection to witness the well logging and plugging process. Harmons Well Service has pulled the 1.900 production tubing out of the hole along with the production rods. The rods tallied out at 1,410. Timco Wireline ran a Bond log and marked the cement top behind the 4.5 diameter production casing at 1,830 with a possible tight spot between 920 and 930. A CCL log was also ran and no hole was indicated in the 4.5. Proceeding the running of the log the 1.900 tubing was ran back in to 2,410 and a 30 sack bottom plug was set.
1530130318 2018-06-27 Plug / Plug Back No Violations On site to witness tagging of bottom hole plug to confirm depth of previous plug tagged it at 2047 and then proceeded to run cutting tools in well they sat down at 908 which according to E-log indicated that possible collar/casing issue at that depth, decision was made to perforate 4.5 casing at 1300 and 1200 and then run tubing back into well and set a isolation plug.
1530545186 2018-07-02 Plug / Plug Back No Violations On this day, I accompanied ODNR Inspector Dave Ball. I am onsite to witness the plugging operation conducted by Harmons Well Services and Formation Cementing. The top of cement on the bottom plug was tagged at 2,047 feet. Timco was onsite and perforated 4 shots at a depth of 1,350 feet and 4 shots at 1,150 feet. We then circulated the hole and set a plug from 1,350 feet to 1,150 feet, to cover the Keener Formation, consisting of 35 sacks Class A cement with a yield of 1.18 and weight of 15.6 pounds per gallon. Then, Timco separated the 4.5 inch diameter casing at a depth of 924 feet, and all was recovered. The rig ran 1.9 diameter tubing in the hole to 924 feet, and a bottom-of-surface plug was set from a depth of 887 feet to 687 feet, consisting of 62 sacks of Class A cement with a yield of 1.18 and a weight of 15.6 pounds per gallon. A brush and stone plug was set at a depth of 200 feet, and a 200 foot surface plug was cemented back to surface with 54 sacks of Class A cement with a 1.36 yield and a weight of 14.7 pounds per gallon.
1530643892 2018-07-02 Plug / Plug Back No Violations On site to assist with plugging operation along with Tom Thomas, Harmon Well Service on site along with Wire line truck from Timco they perforated casing at 1350 and again at 1150 then plug was set by Formation cementing 35 sacks, and tubing was pulled from well and then Timco ran tools in hole to 924 and parted 4.5 casing and wireline got stuck in hole after several attempts line was pulled apart and 4.5 was pulled from well and then they proceeded to run tubing back into well to set 200 plug at 897-697 62 sacks and then we pulled out of hole and proceeded to build stone&brush plug and they set 200-0 plug 54 sacks cement stayed up good. Hole circulated good prior to setting plugs.
1531137453 2018-07-09 Final Restoration No Violations Status check follow up on a previous violation. The said well has been [plugged and all equipment removed. The roadway has been restored and the affected area seeded and mulched. I will follow up once vegetation has been established. All violations are considered resolved.
473204081 2019-2-7 0:00:0 FR No Violations 0.20

Violations Commited

Inspection ID Violation ID Violation Date Violation Code Violation Comments
1439478319 US-OH-112801 2018-07-13 Well shall be plugged

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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