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34-019-22171

Well Details

Well ID: 34-019-22171
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Country: United States
State: Ohio
County: Carroll
Municipality: Augusta Township
Operator Name: EAP OHIO LLC
Well Pad ID: US-OH-000526
Farm/Lease Name: LOZIER 14-15-5
License Status: Producing
License Date: 2012-06-20
Spud Date: 2012-07-15
Spud Drilling Contractor: PATTERSON DRILLING
Final Drill Date: 2012-08-07
Well Total Depth: 13154.00 ft
Configuration: Horizontal
Latitude: 40.680000
Longitude: -81.000000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2012-06-20 Proposed Formations:POINT PLEASANT, Issued Date:6/20/2012, Expired Date:6/20/2014 12:00:00 PM, Drilling unit acres:154.44, Proposed Well Type:OG, Proposed Well Class:EDPW
Reached Total Depth 2012-08-07
Correction to Well 2012-12-07 CORRECTION TO TARGET INFORMATION: FOOTAGE & X,Y COORDINATES FROM AS DRILLED SURVEY. UNIT SIZE DECREASED TO 134.59 ACRES.
Completion Report Received 2013-02-05
Correction to Well 2014-05-16 UNIT SIZE INCREASED TO 334.65 ACRES.
Construction Permit Expires 2014-06-20
Record Last Modified 2017-02-10

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2013-02-11 9162 9653 40
2013-02-11 9722 10213 40
12522 13013 40
11962 12453 40
11402 11893 40
10842 11333 40
10282 10773 40
9722 10213 40
9162 9653 40
8602 9093 40
8042 8533 40
8042 8533 40
2013-02-11 8042 8533 40
2013-02-11 8602 9093 40
2013-02-11 10282 10773 40
2013-02-11 11962 12453 40
2013-02-11 12522 13013 40
2013-02-11 10842 11333 40
2013-02-11 11402 11893 40

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 10/06/2012 10/06/2012 7631.00 5,187,672.0

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 Additional Ingredients Not Listed on MSDS
ClayCare Baker Hughes Clay Stabilizer Water 7732-18-5 30.00 0.02
Choline chloride 67-48-1 75.00 0.05
Recycled Produced Water Carrier/Base Fluid 19.58
GW-3LDF Baker Hughes Gelling Agent Polysaccharide Blend 60.00 0.11
Petroleum Distillate Blend 60.00 0.11
ENZYME G-NE Baker Hughes Breaker No Hazardous Components 0.00
BF-9L Baker Hughes pH Adjusting Agent Potassium hydroxide 1310-58-3 15.00 0.00247000
XLW-32 Baker Hughes Crosslinker Boric acid 10043-35-3 20.00 0.00214000
Methanol 67-56-1 90.00 0.00965000
GBW-5 Baker Hughes Breaker Peroxydisulfuric acid, diammonium salt 7727-54-0 100.00 0.00066000
Northern White Sand Baker Hughes Proppant - Natural Quartz 14808-60-7 100.00 13.89
CI-14 Baker Hughes Corrosion Inhibitor Methanol 67-56-1 68.00 0.00050000
Propargyl alcohol 107-19-7 5.00 0.00004000
100 Mesh Sand Baker Hughes Proppant - Natural Quartz 14808-60-7 100.00 2.77
BF-9L, CI-14, ENZYME G-NE, FERROTROL

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

Baker Hughes Breaker, Corrosion Inhibitor, Friction Reducer, Gelling Agent, Iron Control Agent, pH Adjusting Agent, Scale Inhibitor Calcium chloride 10043-52-4
Hemicellulase Enzyme Concentrate 9025-56-3
Proprietary Disinfectant
Proprietary Alcohol
Proprietary Copolymer
Water 7732-18-5
Proprietary Weak Acid
Proprietary Biocide
Proprietary Polymer
Proprietary Acid
Proprietary Silica
Proprietary Solvent
Proprietary Surfactant
ALPHA 1427 Baker Hughes Antibacterial Agent Glutaraldehyde 111-30-8 30.00 0.00385000
Ethanol 64-17-5 5.00 0.00064000
Didecyl dimethyl ammonium chloride 7173-51-5 10.00 0.00128000
Water 7732-18-5 60.00 0.00771000
FERROTROL 300L Baker Hughes Iron Control Agent Citric acid 77-92-9 50.00 0.00126000
SCALETROL 720 Baker Hughes Scale Inhibitor Ethylene glycol 107-21-1 35.00 0.00505000
Diethylene glycol 111-46-6 5.00 0.00072000
Fresh Water Carrier/Base Fluid 62.91
Hydrochloric Acid 10.1-15 Baker Hughes Acid Hydrochloric acid 7647-01-0 15.00 0.06
Water 7732-18-5 85.00 0.38
FRW-18 Baker Hughes Friction Reducer Distillates, petroleum, hydrotreated light 64742-47-8 30.00 0.00721000

For data sources see[4]

Stimulations Data

Stimulation Date Chemical Agent Chemical Agent Concentration (%) Fracking Fluid Volume Mass of Proppant Used (lb) Fracking Company Comments
2012-10-10 H2O 15 10282 Bbl 918592 BAKER-HUGHES STAGE 5
2012-10-11 H2O 15 9781 Bbl 997936 BAKER-HUGHES STAGE 6
2012-10-07 H2O 15 87040 Bbl 1006816 BAKER-HUGHES STAGE 2
2012-10-14 H2O 15 12640 Bbl 1005196 BAKER-HUGHES STAGE 7
2012-10-09 H2O 15 89050 Bbl 1006010 BAKER-HUGHES STAGE 4
2012-10-06 H2O 15 10687 Bbl 1005314 BAKER-HUGHES STAGE 1
2012-10-08 H2O 15 9624 Bbl 1006677 BAKER-HUGHES STAGE 3
2012-10-15 H2O 15 12249 Bbl 985398 BAKER-HUGHES STAGE 9
2012-10-14 H2O 15 12791 Bbl 1008311 BAKER-HUGHES STAGE 8

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2012 CHESAPEAKE EXPLORATION LLC 535.00 19.00 3
2013 CHESAPEAKE EXPLORATION LLC 394493 15063 353
2014 CHESAPEAKE EXPLORATION LLC 18246 430 33
2015 CHESAPEAKE EXPLORATION LLC 194288 3954 330
2016 CHESAPEAKE EXPLORATION LLC 189852 4621 366
2017 CHESAPEAKE EXPLORATION LLC 174852 3843 365
2018 CHESAPEAKE EXPLORATION LLC 159353 2876 365
2019 CHESAPEAKE EXPLORATION LLC 36317 678 90

For data sources see[6] [7]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2012 CHESAPEAKE EXPLORATION LLC Brine 2142 3
2013 CHESAPEAKE EXPLORATION LLC Brine 8655 353
2014 CHESAPEAKE EXPLORATION LLC Brine 81 33
2015 CHESAPEAKE EXPLORATION LLC Brine 23858 330
2016 CHESAPEAKE EXPLORATION LLC Brine 1603 366
2017 CHESAPEAKE EXPLORATION LLC Brine 809 365
2018 CHESAPEAKE EXPLORATION LLC Brine 1039 365
2019 CHESAPEAKE EXPLORATION LLC Brine 186 90

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1229240462 2015-12-4 0:00: PL No Violations
-820127839 2017-8-30 0:00: PW No Violations 0.70
0820127839 2017-08-30 Production Wells No Violations

I conducted a status check of this well. Identification signs were posted at the access road entrance, the well, and the storage tanks. The #8H well is in production and is equipped with a plunger-lift assembly. The production tanks are surrounded by a steel dike. The equipment on the pad consists of the following: 6 producing wells

1 Low pressure vertical separator 1 heat treater 6 sand separators 6 gas processing units 1 combustor unit


1216021990 2012-07-23 Drill / Deepen / Reopen No Violations I arrived on site at approximately 11:05am to witness the cementing of the 9 5/8 intermediate casing. My inspection revealed that Patterson Rig # 261 had approximately 15 joints of casing left to run into the wellbore. While running the remainder of the casing, the crew cross threaded a couple of joints of casing and had to lay those joints down. Patterson Rig # 261 and Wyoming Casing ran 2033 of 9 5/8 casing with 19 centralizers (on joints 1,2,3,5,7,9,12,15,18,21,23,25,27,30,33,36,39,42,45).
1229240462 2015-12-04 Preliminary Restoration No Violations I was on location to conduct a preliminary restoration inspection. The well is equipped with a plunger lift unit. Jersey barriers were installed around the wellhead. The well is properly identified with a clear, legibly-marked well identification sign. The tank battery consisted of eight, 400 BBL production tanks and was diked. The tanks are located within a spray-lined and sealed secondary containment. There are e-stops outside the barriers, and the tanks are grounded, and have static dissipators. There is a truck grounding area for trucks collecting condensate and/or produced water. Lightning protection and a windsock are installed on top of the production tanks. Other production equipment on the well pad consisted of:



Jersey barriers are installed around the production equipment. The entire well pad is enclosed with a six-foot high, chain link fence with three-strand barbed wire and the man doors were locked. Along the interior of the chain link fence there is an earthen berm and it was stable. 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. The pad has a crushed limestone surface, and is in good repair. The lease road is stable and drivable. Preliminary restoration passed.

1342705949 2012-07-19 Drill / Deepen / Reopen No Violations I was on site to witness the cementing of the 13 3/8 surface casing. I received a phone call from Patterson Rig # 261 at 12:51am and they advised that they would be ready to cement the 13 3/8 surface casing in 5 to 6 hours from the time of this phone call. I arrived on location at approximately 7:45am and found that they were still running the 13 3/8 casing. I spoke with Dean Cooke (Rig Consultant) and he advised that they had approximately half the casing ran into the wellbore. Patterson Rig # 261 has drilled a 17 1/2 hole to a depth of 753 and Wyoming Casings crew ran the 13 3/8 surface casing to a depth of 753. A float shoe, float collar, and 9 centralizers (on joints 1,2,3,5,7,9,11,13,15) were ran with the casing. O-TEX cemented the 13 3/8 casing with 690 sacks of Class H cement (additives 2% CaCl , .27% Cello Flake, and .4% C-41P defoamer). The wellbore had good circulation throughout the job and there was approximately 23 barrels of cement circulated to surface . O-TEX landed the plug with a displacement of 109 barrels. I departed the well site at approximately 2:30pm.
1343311795 2012-07-26 Plug / Plug Back No Violations David Newman (Chesapeake Drilling Superintendent) called me last night at 11:30pm and advised me that they had lost part of the hammer bit down the hole and they were not going to attempt fish it out of the hole. They decided to pump a 500 cement plug on top of the lost tools and sidetrack around them. I was on site to witness the plugging back of the wellbore. Dean Cook (Rig Consultant) advised me that they were drilling at 5184 when they lost the part of the bit down the hole. O-TEX pumped a 250 sack ClassH (.4% C-35 salt tolerant dispersant and .4% C-41P defoamer) cement plug with a weight of 17.5 pounds per gallon and a yield of .94 cubic feet per sack through the drill pipe. Dean Cook advised me that they are going to trip all the drill string out of the hole and wait a minimum of 8 hours before going back into the hole to verify the top of the cement plug. Once they verify the top of the cement plug, they will start drilling the plug and try to kick-off the top of the plug. If they are successful in kicking off the plug, then they will sidetrack around the lost tools. I departed the site at approximately 12:22pm to check on other drilling rigs in Carroll County.
1343663414 2012-07-30 Drill / Deepen / Reopen No Violations I was on site to check the status of Patterson Drilling Rig # 261. My inspection revealed that the rig is drilling at 6865 and will be shutting down at 6900 to run a survey. Dean Cook (rig consultant) advised me that they were going to switch to synthetic oil base mud at 6900 so they will be on synthetic oil base mud when they drill the curve. He also advised me that the rig should be moving to the Edie site in Carroll County after they finish this well.

For data sources see[10]

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 - tblStimulation Table". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  6. ↑ "Risk Based Data Management System - Production Table - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  7. ↑ "Combined Production - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  8. ↑ "Risk Based Data Management System - Production Table - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  9. ↑ "Combined Production - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  10. ↑ "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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