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34-029-21706

Well Details

Well ID: 34-029-21706
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Country: United States
State: Ohio
County: Columbiana
Municipality: Washington Township
Operator Name: CHESAPEAKE EXPLORATION LLC
Well Pad ID: US-OH-000465
Farm/Lease Name: JANIE TRUST 5-12-3
License Status: Plugged Back
License Date: 2012-01-25
Spud Date: 2012-03-11
Spud Drilling Contractor: PATTERSON DRILLING
Final Drill Date: 2012-03-30
Well Total Depth: 8577.00 ft
Configuration: Vertical
Latitude: 40.610000
Longitude: -80.760000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2012-01-25 Proposed Formations:TRENTON-BLACK RIVER, Issued Date:1/25/2012, Expired Date:1/24/2014 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:ST, Proposed Well Class:STRT
Reached Total Depth 2012-03-30
Completion Report Received 2012-05-09
Construction Permit Expires 2014-01-24
Record Last Modified 2015-07-01

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2014-06-30 9269 13510 275
9269 13510 275
9269 13510 275

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 05/29/2012 05/29/2012 8480.00 2,492,070.0

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 Ottawa Sand Proppant Quartz 14808-60-7 100.00 11.28
Potassium Carbonate
Ammonium Persulfate
B10 (HIGH PH BUFFER)
APB01 (AMMONIUM PERSUFATE BREAKER),

B10 (HIGH PH BUFFER), BXL02 Borate XL, CI-150, FE 200, FRW-200, LTB-01

FTS International Breaker, Corrosion Inhibitor, Cross Linker, Friction Reducer, Iron Control Agent, pH Adjusting Agent Proprietary Corrosion Inhibitor Additive (CI-150)
Proprietary Friction Reducer Additive

(FRW-200 and FRW-200W)

Proprietary Breaker Additive (LTB-1)
Water 7732-18-5
Proprietary Breaker (APB01) Additive
Proprietary Iron Control Additive (FE-200L)
0.08009
20.00
pH Adjusting Agent Friction Reducer Cross Linker
EC6629A
0.02388
Anti-Bacterial Agent
007727-54-0
LT Encapsulated AP Breaker (LTB01) FTS International Breaker Quartz 14808-60-7 25.00 0.02
Peroxydisulfuric acid, diammonium salt 7727-54-0 100.00 0.09
BULK)
0.00955
0.07281
Surfactant
26.00
EC6110A
CI-150 (Corrosion Inhibitor) FTS International Corrosion Inhibitor Proprietary Aromatic Aldehyde 10.00 0.00015000
Isopropanol 67-63-0 60.00 0.00088000
N,N-Dimethylformamide 68-12-2 10.00 0.00015000
Proprietary Quaternary Ammonium Compound 10.00 0.00015000
Proprietary Organic Amine Resin Salt 30.00 0.00044000
55.00
FRW-200
0.00215
FTS INTERNATIONAL
000584-08-7
60.00
0.01290
50.00
Additional Ingredients Not Listed on MSDS
10.1 - 15 HCL FTS International Acid Hydrochloric acid 7647-01-0 15.00 0.12
Water 7732-18-5 85.00 0.70
Crystalline Silica (Quartz)
001310-58-3
0.00291
No Hazardous Components
Fresh Water Carrier/Base Fluid 69.95
0.01605
0.00108
FE 200 FTS International Iron Control Agent Sodium hydroxide 1310-73-2 1.90 0.00010000
Ethylenediaminetetraacetic acid tetrasodium salt hydrate 64-02-8 41.00 0.00207000
Glycine, N,N-bis(carboxymethyl)-, trisodium salt 5064-31-3 2.00 0.00010000
HVG-01
0.02293
INTERNATI ONAL
010555-76-7
2.00
10.00
100.00
EC6110A, EC6629A Nalco Anti-Bacterial Agent, Scale Inhibitor Proprietary Acrylate Polymer
Methanol 67-56-1
Water 7732-18-5
Proprietary Quaternary Ammonium Salt
0.00386
Boric Acid
Proprietary Cured Acrylic Resin

Petroleum Distillate Hydrotreated Light Guar Gum

Glutaraldehyde
010043-35-3
Potassium Hydroxide
Recycled Produced Water Carrier/Base Fluid 15.10
100 Mesh Sand Proppant Quartz 14808-60-7 100.00 2.40
APB-01 Ammonium Persulfate Breaker
064742-47-8
Borate XL Instant XL (BXL02)
15.00
Distillates, petroleum, hydrotreated light
Ethanol
TURQUOISE-1
0.00000
Breaker
000064-17-5
Gelling Agent
Scale Inhibitor
TRADE SECRET
12.00
Dioxide)
25.00
014808-60-7
Quaternary Ammonium Compounds
NALCO
N/A
0.00309
009000-30-0
FTS
48.00
068439-51-0
Sodium Metaborate Tetrahydrate
0.00644
000111-30-8
NONE
5.00
0.00226

For data sources see[4]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2018 CHESAPEAKE EXPLORATION LLC Brine 1083 92
2019 CHESAPEAKE EXPLORATION LLC Brine 2170 41

For data sources see[5] [6]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1334833581 2018-8-16 0:00: PW No Violations
-1361003570 2018-12-3 0:00: PW No Violations 0.50
-1966945080 2018-10-1 0:00: PW No Violations 0.30
0027609974 2017-08-29 Production Wells No Violations The purpose of my inspection was to conduct a status check on well #2-1706. The well had a valid temporary inactive status permit. The lease road and pad surface was composed of crushed gravel and remained in good repair. Correct identification was posted at the entrance and well head. A locked chain link fence remained around the pad. The well head was protected by jersey barriers. The cellar contained freshwater with no sheen. Steel grate covered the cellar to prevent falls. The annular gauges were plumbed above grade and identified. The 9.625 and 5.5 annular valves were open. The 9.625 gauge indicated 50psi. The 5.5 annulus gauge identified 840 psi. The 5.5 production casing was equipped with a Christmas tree valve assembly. The production casing gauge indicated 0 psi. Gate valves were chained and locked. No leaks were observed. I will contact Chesapeake Regulatory Affairs Manager Jody Jones concerning the 5.5 annular pressure.
0206330573 2018-08-27 Production Wells No Violations The purpose of my inspection was to conduct a status check on well #2-1706-01. Well identification signage was present at the entrance. The location was enclosed by a locked perimeter fence that remained in good repair. At the time of my inspection the well was still not turned into production. All well head valves remained closed and locked out with tags. Pressure gauges on the intermediate casing annulus indicated 0 psi. The production casing annulus indicated 400 psi. The casing pressure gauge indicated 0 psi. The tubing indicated 700 psi. Equipment on location consisted of two (2) GPU units, one (1) solar powered generator and two (2) 400 bbl production tanks. The sales line was not connected on the pad yet. The production tanks were contained within an impervious lined corrugated steel above ground containment. The electric utility was brought to the pad to power the security camera but was not connected. I will schedule a follow-up inspection once the well is turned over to sales.
0809217405 2016-11-30 Production Wells No Violations The purpose of my inspection was to conduct a status check on well #2-1706-01. The well is currently in temporary inactive status. Correct well identification remains present at the entrance and well head. Lease access and the well pad facilities remain in good repair. No other equipment is on the pad. The Owner raised and identified the 9.625 intermediate annular casing pressure gauge and the 5.5 production annular casing pressure gauge. The intermediate annular casing gauge indicated 0 psi. The production casing annular gauge indicated 825 psi. The 9.625 intermediate casing seat is set at 2615 Maximum allowable annular surface pressure (MAASP) at the surface per ORC 1501:9-1-08 (N) (2) is 792 psi. The production casing pressure gauge indicated 400 psi. I will be contacting Chesapeake Regulatory Affairs Advisor Jody Jones concerning the observed pressure on the production casing annulus in order to facilitate further investigation.
1334833581 2018-08-16 Production Wells No Violations The purpose of my inspection was to conduct a status check on well #2-1706-01. Well identification signage was present at the entrance. The location was enclosed by a locked perimeter fence that remained in good repair. At the time of my inspection the well was not yet turned into production. All well head valves remained closed and locked out with tags. Pressure gauges on the intermediate casing annulus indicated 0 psi. The production casing annulus indicated 380 psi. The casing pressure gauge indicated 0 psi. The tubing indicated 700 psi. Equipment on location consisted of two (2) GPU units, one (1) solar powered generator and two (2) 400 bbl production tanks. The sales line was not connected on the pad yet. The production tanks were contained within an impervious lined corrugated steel above ground containment. No violations were observed during this inspection.
1361003570 2018-12-03 Production Wells No Violations The purpose of my inspection was to conduct a status check on well #1706-01. At the time of my inspection the well had been placed into production. Correct identification was posted at the well head. The cellar was holding freshwater and had a grate in place to prevent falls. The intermediate annular gauge indicated 0 psi. The production casing annular gauge indicated 260 psi. The digital 5.5 production casing gauge indicated 1866 psi. The digital tubing pressure gauge indicated 1115 psi. No leaks were observed. Equipment on location consisted of two (2) GPU with sand knock out, one (1) meter station, one (1) hydrate inhibitor tank, one (1) SCADA station and two (2) 400 bbl production tanks. The hydrate inhibitor tank was on containment. No leaks or evidence of leaks were witnessed with the production or metering equipment. The production tanks were located in an above ground imperviously lined steel containment. The containment contained freshwater. Valves were closed and plugged. No violations were observed during this inspection.
1429879949 2015-03-11 Production Wells No Violations

-established ground cover. The soil stockpile is well stabilized with vegetation. Drainage and erosion controls at the pad are in place and functioning. I emailed Steve Ault of Chesapeake on 4/24/2015 about the identification signs. He replied on 4/27/2015 that they had located the wellhead identification signs and they would be installed within the week. I recommend temporary inactive status be granted.

1467911876 2016-06-22 Production Wells No Violations My purpose for inspection was to conduct a second year temporary inactive well status inspection.

There are two wells on the pad (1H and 10H). The sign board posted at the lease entrance displayed signs with the well name, address, permit number and emergency contact information. The lease road was graveled and in good repair. Erosion and sedimentation controls were in place and ground cover was well established along the road. I walked the entire location and found the well pad constructed with an earthen berm perimeter in good repair, being stabilized with well-established vegetation. Erosion and sedimentation controls are in place and functioning. The well pad was found to be enclosed by a chain link fence with barbed wire at the top. The primary entrance and escape doors were found locked. The surface of the well pad consists of gravel and is in good repair. A perimeter drain was installed and both stand pipes were found open. Soil stockpile is stabilized with well-established vegetation. The 1H well was constructed with 120 of 20 conductor, 516 of 13 3/8 surface casing, 2615 of 9 5/8 intermediate casing and 13, 640 of 5 1/2 production casing. Drilling was completed 4/5/2012. The well was stimulated 5/29/2012. The well head was constructed with a Christmas tree valve assembly and found to be protected by a perimeter of concrete Jersey barriers. Well identification signage was displayed. A cellar grate was in place to prevent falls. The cellar contained water with approximately 8 feet of freeboard. The production casing gauge indicated 0 psi. The intermediate casing gauge indicated 1700 psi. The surface casing gauge indicated 0 psi. None of the gauges are identified as to which casing string it belongs. Identification determination was based upon position on the wellhead. No sheen or leaking gas was observed on the water in the cellar. The mousehole was cemented. Gate valves are chained and locked. No other production equ

1514557657 2017-12-14 Production Wells No Violations The purpose of my inspection was to conduct a status check on well #2-1706-01. ODNR-DOGRM Northeast District Supervisor Stephen Ochs was present during the inspection. Correct identification was present at the entrance. The security fence was found locked. The security fence remained in good repair with no signs of vandalism. The earthen berm around the pad remained stable. Correct identification was posted at the well head. The 9.625 and 5.5 annular pressure gauges were open. The 9.625 annular gauge indicated 0 psi. The 5.5 annular gauge indicated 820 psi. No leaks were observed. The production tree gate valves remained closed, chained and locked. Well #2-1706-01 currently has a valid temporary inactive status permit. No violations were observed during this inspection.
1611636857 2016-03-31 Production Wells No Violations I was on location for a status check. My inspection found the access road gate locked and the

access road in good repair. The pad is fenced and all man doors were locked. An identification sign is posted at the access road entrance and well. The #1H is not in production. The well is equipped with a christmas tree valve assembly. The equipment on the pad consists of the following:

Site fenced and man doors locked

1906770948 2014-12-11 Preliminary Restoration No Violations

-established ground cover. The soil stockpile is well stabilized with vegetation. Crops, woodlands and/or underbrush are growing normally outside the area of disturbance. Drainage and erosion controls outside 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 has not passed pending installation of production equipment.

1966945080 2018-10-01 Production Wells No Violations The purpose of my inspection was to document the status of well #2-1706-01. At the time of my inspection the owners contractor was still completing the sales line. The production valves remained in the closed position. Gates valves were chained and locked. The intermediate annular gauge indicated 0 psi. The production annular gauge indicated 340 psi. No leaks were observed. I will schedule a follow-up inspection to document the status of the well once the well is placed into production. No violations were observed during this inspection.
206330573 2018-8-27 0:00: PW No Violations
2104293762 2018-07-30 Production Wells No Violations The purpose of my inspection was to document the status of well #2-1706-01. At the time of my inspection the owner was in the process of turning the well over to production. Operators were on location to install and connect gas processing units, telemetry and production tanks. The well remained shut-in. The annular pressure gauge on the 9.625 intermediate casing was closed and indicated 0 psi. The annular pressure gauge on the 5.5 production casing was closed and indicated 400 psi. While on location I met Chesapeake instrument and electrical technician Robby Alexander. Mr. Alexander reported the pad was planned to be in production within 30 days. I will schedule a follow-up inspection to document the location after production is established.
27609974 2017-8-29 0:00: PW No Violations 0.50
809217405 2016-11-30 0:00 PW No Violations 1.00

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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