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34-129-20254

Well Details

Well ID: 34-129-20254
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Country: United States
State: Ohio
County: Pickaway
Municipality: Wayne Township
Operator Name: CHUCK HENRY ENERGY LLC
Well Pad ID:
Farm/Lease Name: SUTTON (ERP #2)
License Status: Active Injection
License Date: 2018-07-20
Spud Date: 2015-01-27
Spud Drilling Contractor: KILBARGER DRLG
Final Drill Date: 2015-02-04
Well Total Depth: 2540.00 ft
Configuration: Vertical
Latitude: 39.590000
Longitude: -83.020000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2014-12-31 Proposed Formations:TRENTON, BLACK RIVER, TREMPEALEAU, Issued Date:12/31/2014, Expired Date:12/30/2016 12:00:00 PM, Drilling unit acres:205.406, Proposed Well Type:OG, Proposed Well Class:EOUT
APP 2015-01-15 Proposed Formations:TRENTON, BLACK RIVER, TREMPEALEAU, Issued Date:1/15/2015, Expired Date:1/14/2017 12:00:00 PM, Drilling unit acres:214.048, Proposed Well Type:OG, Proposed Well Class:EOUT
Reached Total Depth 2015-02-04
APP 2016-12-07 Proposed Formations:KNOX, Issued Date:12/7/2016, Expired Date:12/7/2018 12:00:00 PM, Drilling unit acres:214.048, Proposed Well Type:EOR, Proposed Well Class:ERP
First Injection 2017-03-16
Change of Owner 2017-06-28 Operator changed from 5755, HOCKING HILLS ENERGY WELL SERV to 9919, CHUCK HENRY ENERGY LLC
APP 2018-07-20 Proposed Formations:TREMPEALEAU, Issued Date:7/20/2018, Expired Date:7/19/2020 12:00:00 PM, Drilling unit acres:214.048, Proposed Well Type:IER, Proposed Well Class:ERP
Record Last Modified 2018-07-27
Construction Permit Expires 2020-07-19

For data sources see[2]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1154530381 2015-1-29 0:00: DD No Violations 3.00
-121273507 2017-1-4 0:00:0 AM No Violations
-1316258789 2017-1-26 0:00: PW No Violations 2.00
-1322901197 2016-11-15 0:00 PW No Violations 4.00
-1406407794 2017-3-21 0:00: ER No Violations 8.00
-1556882878 2016-10-11 0:00 SC No Violations 2.50
-1687939500 2016-11-22 0:00 PW No Violations 2.50
-1743689092 2017-1-6 0:00:0 PW No Violations 9.50
-1816453171 2017-1-9 0:00:0 PW No Violations 8.50
-184703654 2017-1-5 0:00:0 ER No Violations
-2040742664 2016-12-28 0:00 ER No Violations 8.50
-2043283828 2016-5-9 0:00:0 PL No Violations 1.00
-2097201411 2017-3-27 0:00: ER No Violations 4.50
-927546102 2017-1-10 0:00: PW No Violations 4.00
0121273507 2017-01-04 Administrative Inspection No Violations I received a call from well owner Doug Kitchen who stated Knox Energys service rig would be on site to drill out the cement that was left in the 4.5 inch diameter casing after the cement squeeze job. Knox Energy ran tubing down to 2180 feet and bolted on their blow out preventer. The cement will be drilled out on 1-5-17.
0184703654 2017-01-05 Enhanced Recovery Project No Violations Knox Energy on site at 0836 hours. The cement plug that was drilled out was tagged at 2066 feet. Knox Energy began drilling the cement plug out at 1214 hours and finished drilling the cement at 1345 hours. The bottom of the cement was found to be at 2137 feet. The hole was circulated with fresh water to remove the cement cuttings. The shoe was tagged at 2410 feet. The MIT test and bond log will be performed on 1-6-17 and witnessed by inspector John Scott.
0213166491 2016-10-13 Surface Facility Construction No Violations Completed the construction of the containment dike walls and installed a one piece plastic liner.
0577468905 2018-10-17 Salt Water Injection Well No Violations My inspection revealed the well had 0 psi on the annulus and 0 psi on the tubing. The containment facility has been removed. All that remains is the electrical service and the injection line leading to the well. I have in my possesion a plugging permit for this well. I spoke with Chuck Henry Energy today and they confirmed the well would be plugged when the crop has been harvested.
0827934389 2018-05-30 Enhanced Recovery Project No Violations Inspected the containment dike, tanks, injection line, injection pressure and annulus pressure. The injection line is not connected to the injection pump. The tanks are not connected. A pile of fittings and equipment is inside the containment dike. The containment dike is free of fluids. Identification is posted at the facility and the well. I talked to Peter Hatgelakas and he informed me that they are dismantling the facility and plan to plug the well. I reminded Peter that they will need a plug permit.
0927546102 2017-01-10 Production Wells No Violations Permit to Convert to Enhanced Recovery Injection well Issued 12-7-2016. Tubing and packer were ran into the 4.5 casing to test above the squeeze perforations and below the perforations. Perforated interval 2130 feet to 2133 feet (4 shots). 4.5 casing held a 600 psi test above the perforations. The tubing and packer were lowered below the perforations and the annulus was tested. The test lost more than 5% in 15 minutes. Company is going to submit a plan to the UIC section.
1154530381 2015-01-29 Drill / Deepen / Reopen No Violations Kilbarger rig number 1 has reached 339 by 1320 hours. 7 intermediate sting will be set on 1/30/2015. No violations noted.
1279427449 2017-02-24 Surface Facility Construction No Violations Permit to convert to ERP injection well. A Pressure cut off switch has been installed on the injection line. The electric lines have been installed to all equipment. The flow meter has been installed on the injection line (it records in gallons). There are no continuous monitoring devices installed on the injection tubing or the annulus. Identification for the ERP well is posted at the well and containment dike. This containment dike does not have an identification posted for the production well.
1293114987 2018-08-20 Salt Water Injection Well No Violations The purpose of my inspection today was to inspect the well prior to Chuck Henry Enegy plugging the well. The prefabracated containment dike has been removed along with the 210 barrel tanks. The well is located in a agriculatual field and will be plugged once the crops have been harvested.
1316258789 2017-01-26 Production Wells No Violations Permit to convert to ERP injection well. Injection line test from the facility to the well. Line was tested at 565 psi, at 5 minutes 565 psi, at 15 minutes 560 psi.
1322901197 2016-11-15 Production Wells No Violations Hocking Hills Energy installed 928 feet of 4 inch DR-11 in a 28 inch deep ditch, from the tank battery to the well. A tracer line was installed in the ditch. The ditch was backfilled then a 2.375 inch Poly injection line (750 max psi) was inserted through the 4 inch line from the tank battery to the well. The 2.375 inch line was not tested.
1392695686 2018-08-29 Enhanced Recovery Project No Violations The surface facility has been removed. All tanks, injection pump, containment dike liner and dike walls have been removed from location. Electric service lines remain in conduit. The injection line is in place and connected to the injection tubing. The injection tubing master valve is closed. Company has stated that they plan to plug the well after the field has been harvested.
1406407794 2017-03-21 Enhanced Recovery Project No Violations Initial injection operations. The pressure cut off switch is set at 300 psi. The injection pump has a pressure relief valve with max pressure of 550 psi. The containment dike is free of fluids. The injection tubing is not equipped with a 1/4 inch valve for the state pressure gauge.. The injection tubing and annulus are connected to a two pin recorder with a chart. A 2 inch union and 2 inch nipple at the well are leaking brine. The operation was stopped to repair the leaks. After the repairs, the injection line was tested and it failed due to leaks at the facility and the well. A line test is scheduled for 3-22-17. The injection operations are shut in until a successful line test can be demonstrated, and a 1/4 inch valve is installed on the injection tubing.
1422450516 2015-01-28 Drill / Deepen / Reopen No Violations - Received phone call from operator on 1/26/2015 that Kilbarger rig 1 was moving on location, the operator failed to notify when drilling was started on 1/27/2015.

- Permit is not posted in the dog house (rig office). - At time of inspection depth of hole is 214 feet. - New 9 ? casing on site, average length 42 feet. -

1422494045 2015-01-28 Casing String Witnessed No Violations - on site for surface casing cementing, 9.625 casing, set to a depth of 304 feet, hole depth 327 feet.

- New casing 26 Lbs., 12.25 inch hole drilled - Formation Cementing doing cementing Good circulation while pumping, cement circulated to surface. 80% excess cement no drop at surface.

1422966116 2015-02-03 Drill / Deepen / Reopen No Violations - On site for drilling update, current depth 1,912 feet drilling on air.

- Operator had set 7 inch casing on 1/31/2015 was not witness.

1424265199 2015-02-18 Drill / Deepen / Reopen No Violations - Drill equipment on site, rig moved off well.

- Pits are still open, appears fluid has been removed. - Weather condition; overcast snowing, ground snow cover, Temperature 14

1442987852 2018-03-15 Salt Water Injection Well No Violations My inspection revealed the salt water injection well had 0 psi on the tubing and 5 psi on the annulus. The dike was free of fluids. Legible identification was posted.
1449554195 2015-10-29 Production Wells No Violations I spoke with well owner Doug Kitchen. The pumping unit is being delivered 11/3/2015. The well will be in production by 11/15/2015.
1457126391 2017-03-22 Enhanced Recovery Project No Violations Initial Injection Operations. Test the injection line multiple times. Each test failed due to leaks on 2inch pipe and fittings at the surface facility. The 1/4 inch fitting has been installed on the injection tubing. Injection operations are not permitted until a successful injection line test is demonstrated.
1481638636 2016-12-12 Production Wells No Violations Permit to convert to enhanced recovery injection well issued 12-7-2016. Witnessed cement bond log on the 4.5 casing by Appalachian Well Surveys. The cement bond log tool was centralized. The cement bond log shall be submitted to the Division of Oil and Gas UIC Section for review per the permit conditions.
1556882878 2016-10-11 Surface Facility Construction No Violations Containment dike construction. 3 of the 4 sides have been installed along with 4 inches of sand.
1568309093 2019-9-12 0:00: PB No Violations 5.30
1574878480 2019-11-27 0:00 SW No Violations 0.30
1614823562 2018-11-29 Plug / Plug Back No Violations My inspection reveled the crops have not been harvested from this field. The well is surrounded by the agricultural field and the well will be plugged when the crop has been harvested. Chuck Henry Energy has a service rig on site waiting on the crop to be harvested. The tank battery has been removed.
1687939500 2016-11-22 Production Wells No Violations Crimped connections have been made to both ends of the 2 3/8 poly injection line.
1708657649 2017-12-13 Salt Water Injection Well No Violations My inspection revealed the salt water injection well had 6 psi on the annulus and the injection tubing was on vacuum. The containment dike was free of fluids. Legible identification was posted.
172598624 2019-3-13 0:00: ER No Violations
1743689092 2017-01-06 Production Wells No Violations Permit to Convert to Enhanced Recovery Injection well Issued 12-7-2016. Appalachian Wire Line on site to run a bond log on the production casing cement squeeze job. Multiple attempts were made to test the production casing. All tests lost over 5% in 15 minutes. Test is rescheduled for 1-9-17.
1812361389 2017-01-20 Production Wells No Violations Permit to convert to enhanced recovery injection well. Witnessed the installation of a Sealtite tension packer and 2 3/8 lined tubing installed at 2114 feet. Annulus was filled with 22.83 barrels of water and inhibitor. Annulus was tested at 790 psi for 15 minutes with no loss in pressure. Variance was approved on 1-19-17.
1816453171 2017-01-09 Production Wells No Violations Permit to Convert to Enhanced Recovery Injection well Issued 12-7-2016. Multiple attempts to test the 4.5 casing. All attempts lost more than 5% in 15 minutes.
1826509654 2016-04-20 Production Wells No Violations Site evaluation for a ERP permit. The well is located in a flat agricultural field with an unnamed intermittent stream 1989 feet East of the well and Lick Run located 1779 feet West of the well. A pond is located South East of the well at GPS 39.59096/W083.02325. The wellhead has 7 surface casing and 4.5 production casing with a 4.5 by 2 swedge and a 2valve with plug. The well is not connected to production equipment or pipelines. No identification is posted at the well.
2040742664 2016-12-28 Enhanced Recovery Project No Violations Hocking Hills Energy has hired Appalachian Well service to run a bond log to confirm the need for remedial cement. The bond log showed the need for 95 of cement. Formation Cementing on site who after obtaining circulation ran 66 sacks of cement followed by a wiper plug. The wiper plug was followed by a wireline measuring tool. The top of the wiper plug was 2080 This plug will be drilled out at a later date along with the cement that was left in the 4.5 inch diameter casing.
2043283828 2016-05-09 Preliminary Restoration No Violations The purpose of this inspection is a status check on a preliminary restoration. During my inspection I witnessed the well is equipped with 4.5 inch casing, tubing, rods and a pumping unit. The production equipment consists of one 210 bbl. tank. Gravel lease road and the well site is located in a Farmers crop field. Location has met 1509.072 A requirements and preliminary restoration has passed. Restoration has passed but the company will be called to discuss the fact that the 210 bbl. tank is within 5 ft. of the well, no identification, and there is no electric hooked up to the electric motor on the pumping unit.
2097201411 2017-03-27 Enhanced Recovery Project No Violations Initial Injection Operations. Injection line test. Tested the injection line from the surface facility to the injection tubing at 585 psi. At 5 minutes 585 psi, at 15 minutes 578 psi. Test passed. There were no leaks observed at the facility or the wellhead. A brine sample was collected at the surface facility. The sample will be taken to the ODNR Lab. Injection operations are ongoing.
213166491 2016-10-13 0:00 SC No Violations 8.00
577468905 2018-10-17 0:00 SW No Violations 0.40
827934389 2018-5-30 0:00: ER No Violations 1.50

For data sources see[3]

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 - tblInspection, tblInspFail and tblinspFlDesc Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
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