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34-029-21719

Well Details

Well ID: 34-029-21719
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Country: United States
State: Ohio
County: Columbiana
Municipality: Hanover Township
Operator Name: CHESAPEAKE EXPLORATION LLC
Well Pad ID: US-OH-000934
Farm/Lease Name: TREBILCOCK 25-15-4
License Status: Plugged Back
License Date: 2012-03-05
Spud Date: 2012-04-07
Spud Drilling Contractor: NOMAC DRILLING CORP
Final Drill Date: 2012-04-22
Well Total Depth: 8155.00 ft
Configuration: Vertical
Latitude: 40.750000
Longitude: -80.860000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2012-03-05 Proposed Formations:TRENTON-BLACK RIVER, Issued Date:3/5/2012, Expired Date:3/5/2014 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:ST, Proposed Well Class:STRT
Reached Total Depth 2012-04-22
Completion Report Received 2012-07-03
Construction Permit Expires 2014-03-05
Record Last Modified 2015-09-24

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2014-06-04 8151 14035 352
8151 14035 352
8151 14035 352

For data sources see[3]

Fracking Activities

Fracking Jobs

Job Number Job Start Date Job End Date True Vertical Depth (ft) Total Water Volume (gal) Total Non-Water Volume (gal)
1 06/18/2012 06/18/2012 8095.00 3,637,326.0

Fluid Composition Data

Job Number Trade Name Supplier Purpose Ingredient Name CAS Number Additive Percentage by Mass Job Percentage by Mass Mass Used (lb)
1 FERROTROL 300L Baker Hughes Iron Control Agent Citric acid 77-92-9 50.00 0.00224000
Additional Ingredients Not Listed on MSDS
SCALETROL 720 Baker Hughes Scale Inhibitor Ethylene glycol 107-21-1 35.00 0.00480000
Diethylene glycol 111-46-6 5.00 0.00069000
BF-9L Baker Hughes pH Adjusting Agent Potassium hydroxide 1310-58-3 15.00 0.00216000
Ottawa Sand Proppant Quartz 14808-60-7 100.00 13.96
ALPHA 1427 Baker Hughes Antibacterial Agent Water 7732-18-5 60.00 0.00772000
Ethanol 64-17-5 5.00 0.00064000
Quaternary ammonium compounds,

benzyl-C12-16-alkyldimethyl, chlorides

68424-85-1 7.00 0.00090000
Glutaraldehyde 111-30-8 30.00 0.00386000
Didecyl dimethyl ammonium chloride 7173-51-5 10.00 0.00129000
ENZYME G-NE Baker Hughes Breaker No Hazardous Components 0.00
100 Mesh Sand Proppant Quartz 14808-60-7 100.00 2.03
Recycled Produced Water Carrier/Base Fluid 4.24
ClayCare Baker Hughes Clay Stabilizer Water 7732-18-5 30.00 0.02
Choline chloride 67-48-1 75.00 0.05
GBW-15L Baker Hughes Breaker Sodium chloride 7647-14-5 100.00 0.00988000
Hydrochloric Acid 10.1-15 Baker Hughes Acid Hydrochloric acid 7647-01-0 15.00 0.12
Water 7732-18-5 85.00 0.68
Fresh Water Carrier/Base Fluid 78.58
GW-3LDF Baker Hughes Gelling Agent Petroleum Distillate Blend 60.00 0.08
Polysaccharide Blend 60.00 0.08
BF-9L, CI-14, ENZYME G-NE, FERROTROL

300L, FRW-18, GBW-15L, GW-3LDF, SCALETROL 720

Baker Hughes Breaker, Corrosion Inhibitor, Friction Reducer, Gelling Agent, Iron Control Agent, pH Adjusting Agent, Scale Inhibitor Proprietary Acid
Proprietary Silica
Proprietary Weak Acid
Proprietary Enzyme
Proprietary Disinfectant
Water 7732-18-5
Proprietary Alcohol
Calcium chloride 10043-52-4
Proprietary Copolymer
Proprietary Solvent
Hemicellulase Enzyme Concentrate 9025-56-3
Proprietary Biocide
Proprietary Surfactant
Proprietary Polymer
XLW-32 Baker Hughes Crosslinker Methanol 67-56-1 90.00 0.00864000
Boric acid 10043-35-3 20.00 0.00192000
CI-14 Baker Hughes Corrosion Inhibitor Propargyl alcohol 107-19-7 5.00 0.00007000
Methanol 67-56-1 68.00 0.00089000
FRW-18 Baker Hughes Friction Reducer Distillates, petroleum, hydrotreated light 64742-47-8 30.00 0.01

For data sources see[4]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2014 CHESAPEAKE EXPLORATION LLC Brine 8641 298
2015 CHESAPEAKE EXPLORATION LLC Brine 3605 307
2016 CHESAPEAKE EXPLORATION LLC Brine 2877 366
2017 CHESAPEAKE EXPLORATION LLC Brine 1220 365
2018 CHESAPEAKE EXPLORATION LLC Brine 183 365
2019 CHESAPEAKE EXPLORATION LLC Brine 37 90

For data sources see[5] [6]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1105687375 2017-9-20 0:00: PW No Violations 0.70
0110012870 2015-10-08 Preliminary Restoration No Violations

-lined and sealed secondary containment. There are concrete barriers protecting the containment from vehicles. There are e-stops outside the barriers, and the tanks are grounded, and have static dissipaters. There is a truck grounding area for trucks collecting condensate and/or produced water. Along the interior of the chain link fence there is a site drain installed. The soil stockpile is well stabilized with vegetation. Drainage and erosion controls at the pad are in place and functioning. A closed-loop, above-ground drilling pit system was used, so there are no earthen pits requiring closure. Preliminary restoration is complete and approved.

0920249222 2014-10-24 Preliminary Restoration No Violations

-lined and sealed secondary containment. There are concrete barriers protecting the containment from vehicles. There are e-stops outside the barriers, and the tanks are grounded, and have static dissipaters. There is a truck grounding area for trucks collecting condensate and/or produced water. Along the interior of the chain link fence there is a site drain installed. The soil stockpile is well stabilized with vegetation. Drainage and erosion controls at the pad are in place and functioning. A closed-loop, above-ground drilling pit system was used, so there are no earthen pits requiring closure. Preliminary restoration is complete and approved.

110012870 2015-10-8 0:00: PL No Violations
1105687375 2017-09-20 Production Wells No Violations The purpose of my inspection was to conduct a status check on well #2-1719-01. The lease road and well pad remained in good repair. A locked chain link fence was constructed around the facility. No signs of vandalism were present. A stable earthen berm was present outside of the fenced perimeter. Correct identification was present. The well cellar contained fresh water near free board. No leaks were detected. The 9.625 annular pressure gauge indicated 0 psi. The 5.5 annular pressure gauge indicated 0 psi. The well was flowing during the inspection. The 5.5 production casing was equipped with a plunger lift assembly. Production equipment on the pad consisted of (1) sand knockout and GPU specific to well #1719-01. Common equipment shared with well #2-1728 included (1) hydrate inhibitor tank, one (1) meter run, one (1) coalescing tower, three (3) 400 bbl produced water tanks and three (3) condensate tanks inside steel containment and one (1) VRU. The containment was lined with an impervious liner and was holding fresh water. No violations were observed during this inspection.
1917624884 2016-11-28 Production Wells No Violations The purpose of my inspection was to conduct a status check on well # 2--established vegetation. A sign board is posted at the entrance and contains correct owner and well identification and emergency response information. A chain link security fence with barbed wire top is constructed around the well pad. The entrance gate and escape doors are locked to prevent unauthorized entry. An electric shut down button is present outside of the entrance gate. An earthen berm perimeter with well-established vegetation is present around the fence/ well pad. The well pad surface is composed of crushed gravel and remains in good repair. A French drain has been installed with a stand pipe that drains on the North side of the pad. The stand pipe valve was open.

Correct and legible identification is posted at the well head. The well cellar contains freshwater with 48 inches of freeboard. No sheen was identified on the surface. Steel grating is set in place on top of the cellar to prevent falls. The mousehole is cemented. The intermediate annular pressure gauge appeared broken. The production casing annular gauge indicated 120 psi. Neither gauge is identified as to its respective casing string. The well is equipped with a plunger lift assembly. The production casing pressure gauge indicated 132.4 psi. The production tubing pressure gauge indicated 185.2 psi. No audible or visual leaks were detected. The well was flowing during the inspection. Production equipment located on the pad consists of one (1) vertical sand/fluid separator, two (2) gas processing units (GPU), one (1) 350 gallon hydrate inhibitor tank within sealed containment, one (1) vertical separator, six (6) 400 bbl production tanks within containment and one (1) emission combustion tower. Co

920249222 2014-10-24 0:00 PL No Violations

For data sources see[7]

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. ↑ "FracFocus Fracking Chemicals Database". 2019-04-02. Retrieved 2019-06-19. 
  5. ↑ "Risk Based Data Management System - Production Table - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  6. ↑ "Combined Production - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  7. ↑ "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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