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34-067-21232

Well Details

Well ID: 34-067-21232
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Country: United States
State: Ohio
County: Harrison
Municipality: Archer Township
Operator Name: EAP OHIO LLC
Well Pad ID: US-OH-001016
Farm/Lease Name: KLODT 29-11-5
License Status: Producing
License Date: 2014-12-18
Spud Date: 2014-12-20
Spud Drilling Contractor: NOMAC DRILLING CORP
Final Drill Date: 2015-04-22
Well Total Depth: 16034.00 ft
Configuration: Horizontal
Latitude: 40.360000
Longitude: -81.070000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2013-08-23 Proposed Formations:TRENTON /BLACK RIVER, Issued Date:8/23/2013, Expired Date:8/23/2015 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:ST, Proposed Well Class:STRT
APP 2014-12-18 Proposed Formations:POINT PLEASANT, Issued Date:12/18/2014, Expired Date:12/17/2016 12:00:00 PM, Drilling unit acres:1245.1, Proposed Well Type:OG, Proposed Well Class:POOL
Reached Total Depth 2015-04-22
Correction to Well 2015-09-04 CHANGE IN TARGET AND TAKE-POINT INFORMATION (FOOTAGES AND COORDINATES) FROM AS DRILLED SURVEY PLAT.
Completion Report Received 2016-02-17
Construction Permit Expires 2016-12-17
Record Last Modified 2017-10-23

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2016-02-17 8405 15897 825
8405 15897 825
8405 15897 825

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 06/11/2015 06/16/2015 8176 6,330,450.0 580643

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 Fresh Water CHESAPEAKE ENERGY Carrier/Base Fluid Water 007732-18-5 100 81.9514 0
TS-15 X CHEM Scale Inhibitor Proprietary Sodium Polycarboxylate TRADE SECRET 100 0.01647 0
Water 007732-18-5 0 0 0
Chlorine Dioxide TERRA SERVICES Anti-Bacterial Agent Chlorine Dioxide 010049-04-4 100 0.00967 0
A264, J218, J475, J580, J609, J610,

L058, Acid, Hydrochloric 15pct, Acid, Hydrochloric 7.5pct, Northern White Sand, 100 Mesh Sand

SCHLUMBERGER Breaker, Corrosion Inhibitor, Cross Linker, Friction Reducer, Gelling Agent, Iron Control Agent, Acid, Proppant - Natural Ammonium Sulfate 007783-20-2 30 0.00823 0
Crystalline Silica (Quartz Sand, Silicon Dioxide) 014808-60-7 100 16.3447 0
Crystalline Silica (Quartz Sand, Silicon Dioxide) 014808-60-7 100 0.52559 0
Sodium Erythorbate 006381-77-7 100 0.00022 0
Water 007732-18-5 85 0.13667 0
Aliphatic alcohols, ethoxylated # 1 NA 30 0.00028 0
Carbohydrate polymer NA 100 0.0899 0
Water 007732-18-5 93 0.75967 0
Potassium Hydroxide 001310-58-3 15 0.00727 0
Aliphatic amine polymer NA 30 0.00823 0
Hydrogen Chloride 007647-01-0 15 0.02412 0
Ammonium Persulfate 007727-54-0 100 0.00067 0
Methanol (Methyl Alcohol) 000067-56-1 40 0.00038 0
Aliphatic polyol NA 30 0.01454 0
Ammonium Persulfate 007727-54-0 100 0.00257 0
Aliphatic acid NA 30 0.00028 0
Hydrochloric Acid 007647-01-0 8 0.0616 0
Propargyl Alcohol (2-Propynol) 000107-19-7 10 0.00009000 0

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
2015-06-11 H2O 0 735 Bbl 0 Schlumberger STAGES 1/33

25 SHOTS STAGES 2-32 SEE IMAGES

2015-06-16 H2O 0 4682 Bbl 343680 Schlumberger STAGE 33/33

25 SHOTS

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2015 CHESAPEAKE EXPLORATION LLC 253425 16935 78
2016 CHESAPEAKE EXPLORATION LLC 863926 29665 365
2017 CHESAPEAKE EXPLORATION LLC 466749 8388 365
2018 CHESAPEAKE EXPLORATION LLC 337594 4558 365
2019 CHESAPEAKE EXPLORATION LLC 71152 822 90

For data sources see[6] [7]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2015 CHESAPEAKE EXPLORATION LLC Brine 6139 78
2016 CHESAPEAKE EXPLORATION LLC Brine 12047 365
2017 CHESAPEAKE EXPLORATION LLC Brine 1771 365
2018 CHESAPEAKE EXPLORATION LLC Brine 889 365
2019 CHESAPEAKE EXPLORATION LLC Brine 1110 90

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1479188831 2019-8-16 0:00: PW No Violations 0.50
-492814045 2015-4-23 0:00: CS No Violations
-880210670 2016-2-18 0:00: PL No Violations 0.50
-928330518 2015-4-14 0:00: CS No Violations
0492814045 2015-04-23 Casing String Witnessed No Violations I was on the Klodt # 10 - H location to witness the cementing of the 5.5 production string. Nomac Drilling Rig # 73 drilled a 8.5 borehole from 7,399 KB to 16,034 KB. Wyoming Casing Service ran 367 joints of 5.5, 20 lb/ft, P - 110, CDC - HTQ casing, 169 solid body spiral centralizers, float shoe, float collar, landing collar, 93 - Tartan Completion Frac Sleeves ( 2.41 X 5.5 ) and two (2) Tartan BurstPoint Initiation Subs ( 1.12 X 5.5). Total tally was 16,029 set at 16,034 KB. Baker Hughes conditioned the borehole with two spacers consisting of 30 barrels of Ultrabond 10 ( 11.5 ppg ) and 90 barrels of Multibond ( 12 ppg ) prior to cementing. Baker Hughes mixed and pumped a lead cement slurry comprised of 1,078 sacks ( 182 barrels ) of 50/50 Class H blended with 0.05% SF, 0.15% R-3, 0.6% MPA 250 and 5% MP. The lead cement slurry was followed by a tail cement slurry consisting of 1,930 sacks ( 238 barrels ) of Class H blended with 0.05% SF, 0.2% R-3 and 0.3% MPA. Both cement slurries were displaced with a top plug and five (5) barrels of sugar water and 354 barrels of inhibited water. Mix water temperature was 51 F and slurry temperature was 61 F. Mix water pH was 6. The plug was landed at 3267 psi and bled down to 2457 psi while flowing four (4) barrels of fluid. Baker Hughes pumped back the four (4) barrels and shut in. The floats continued to fail to hold after multiple attempts. Chesapeake personnel decided to pressure up the casing ( to minimize any microannulus ) and shut in until the tail cement reached 500 psi compressive strength. The casing was shut in from 2130 hrs. to 0600 hrs. after which the casing was opened and three barrels flowed back and stopped. The floats held and the well was static. Ten ( 10 ) barrels of cement slurry was returned to the cellar. No violations were identified during this inspection.
0880210670 2016-02-18 Preliminary Restoration No Violations I arrived on location accompanied by inspector Mark Moreland, were I witnessed the lease road gate was locked and the lease road in adequate condition. The pad is fenced and all man doors were locked. The permitted wells are producing off of natural reservoir pressure. RBDMS production records indicate that the wells are in producing order. 
The production equipment on the pad consists of the following:

12 400 bbl. Production tanks 8 Producing wells 8 Sand separators

2 Horizontal heater-treaters 1 combustor 1 Low pressure separator tower/Vapor recovery system unit. 5 compressors 

There was approximately 2 to 3 inches of snow on location at the time of my inspection. The site passed preliminary restoration in accordance with ORC 1509.072 A.
0928330518 2015-04-14 Casing String Witnessed No Violations I was on the Klodt # 10H location to witness the placement and cementing of the 13.375 surface casing. Nomac Drilling Rig # 73 drilled a 17.5 diameter borehole to 552 on misted air. Wyoming Casing Service ran 13.375 casing to 502. Baker Hughes connected to the casing and conditioned the borehole with 10 barrels of water, 20 barrels of gelled water ( 8.7 ppg ) then 10 barrels of water. After the spacer Baker Hughes circulated a cement slurry ( 15.6 ppg ) and displaced it with a top plug. Displacement was 79 barrels. Mix water temperature was 55 F and pH was 8. Baker Hughes circulated approximately 25 barrels of cement slurry ( 15.7 ppg ) back to the cellar. Slurry weights were verified by scale. The plug landed at 230 psi and increased to 753 psi. The green cement test was failed due to not holding pressure for the required time period. The casing flowed back .5 barrel and stopped. All floats held. In lieu of the green cement test the well was shut in for eight hours with the cement head on. This allowed for the minimum drill out compressive strength of the cement system to be obtained. The pressure test would be performed in conjunction with the BOP test with a minimum pressure of 300 psi and 30 minute duration. The supporting test data was forward to me for review and upon review I approved the drilling ahead. No violations identified during this inspection.
1091202958 2016-01-11 Preliminary Restoration No Violations On the day of my inspection, I witnessed the well was equipped with a production tree. Production equipment for the well included a sand trap, a gas production unit and a line heater. Production equipment that was shared with permitted wells 34067212280000, 34067212290000, 34067212300000, 34067212310000, 34067212330000, 34067214310000, and 34067214320000 included a vapor recovery system, 5 gas compressors, a gas combustor and 12-400 bbl. tanks that where placed inside proper containment. The site passed preliminary restoration in accordance with ORC 1509.072 A.
1419349206 2014-12-23 Casing String Witnessed No Violations I am on site today to witness the running and the cementing of the 20 inch diameter casing string. Express Drilling Rig # 2 drilled a 26 inch diameter hole to 120 ft. and set 120 ft. of 94 lb. casing. Express Cementing Service cemented with 230 sacks of class A cement at 15.6 lb. and a yield of 1.18

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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