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34-029-21735

Well Details

Well ID: 34-029-21735
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Country: United States
State: Ohio
County: Columbiana
Municipality: Center Township
Operator Name: EAP OHIO LLC
Well Pad ID: US-OH-000407
Farm/Lease Name: CROSSER 20-14-3
License Status: Producing
License Date: 2012-05-24
Spud Date: 2012-07-31
Spud Drilling Contractor: NOMAC DRILLING CORP
Final Drill Date: 2012-08-14
Well Total Depth: 12845.00 ft
Configuration: Horizontal
Latitude: 40.760000
Longitude: -80.830000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2012-05-24 Proposed Formations:POINT PLEASANT, Issued Date:5/24/2012, Expired Date:5/24/2014 12:00:00 PM, Drilling unit acres:126, Proposed Well Type:OG, Proposed Well Class:EDPW
Reached Total Depth 2012-08-14 WCR IN PRELIM FILE
Correction to Well 2012-08-17 CORRECTION TO TARGET FOOTAGE.
Correction to Well 2012-11-09 CORRECTION TO TARGET INFORMATION: FOOTAGE & X,Y COORDINATES (FROM AS DRILLED SURVEY PLAT).
Correction to Well 2013-04-19 UNIT SIZE DECREASED TO 113.94 ACRES.
Completion Report Received 2014-04-16 WCR IN PRELIM FILE
Construction Permit Expires 2014-05-24 WCR IN PRELIM FILE
Record Last Modified 2017-10-24 WCR IN PRELIM FILE

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2014-04-21 8647 12720 360
8647 12720 360
8647 12720 360

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 03/18/2013 03/20/2013 7963 3,433,880.0 267055

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 PTLCA102 PERFORMANCE TECHNOLOGIES Cross Linker Proprietary Inorganic Salt TRADE SECRET 30 0.008 0
Proprietary Alkyl Alcohol TRADE SECRET 60 0.016 0
Sodium Hydroxide 001310-73-2 60 0.016 0
PTLGL140 PERFORMANCE TECHNOLOGIES Gelling Agent No Hazardous Components NONE 0 0 0
PTLSI372 PERFORMANCE TECHNOLOGIES Scale Inhibitor No Hazardous Components NONE 0 0 0
100 Mesh Sand PERFORMANCE TECHNOLOGIES Proppant - Natural Crystalline Silica (Quartz Sand, Silicon Dioxide) 014808-60-7 100 1.02959 0
PTLAI171 PERFORMANCE TECHNOLOGIES Corrosion Inhibitor Isopropanol (Isopropyl Alcohol, Propan-2-ol) 000067-63-0 60 0.00092 0
Proprietary Quaternary Ammonium Compound TRADE SECRET 10 0.00015 0
Ethylene Glycol 000107-21-1 30 0.00046 0
Dimethyl Formamide 000068-12-2 10 0.00015 0
Proprietary Aromatic Aldehyde TRADE SECRET 10 0.00015 0
Proprietary Organic Amine Resin Salt TRADE SECRET 30 0.00046 0
Northern White Sand PERFORMANCE TECHNOLOGIES Proppant - Natural Crystalline Silica (Quartz Sand, Silicon Dioxide) 014808-60-7 100 13.6001 0
PTLAI171, PTLBW112, PTLFR200, PTLGL140, PTLSI372 PERFORMANCE TECHNOLOGIES Breaker, Corrosion Inhibitor, Friction Reducer, Gelling Agent, Scale Inhibitor Proprietary Surfactant TRADE SECRET 0 0.11323 0
Tetrasodium Ethylenediaminetetraacetate 000064-02-8 0 0.04963 0
Proprietary Vinyl Copolymer TRADE SECRET 0 0.05166 0
Proprietary Substituted Fatty Acid Ester TRADE SECRET 0 0.04963 0
Proprietary Methanol TRADE SECRET 0 0.00063 0
Proprietary Oxyalkylated Fatty Acid Derivative TRADE SECRET 0 0.04963 0
Sodium Chloride 007647-14-5 0 0.04963 0
Proprietary Aliphatic Alcohol TRADE SECRET 0 0.04963 0
Proprietary Alkylene Oxide Block Polymer TRADE SECRET 0 0.00063 0
2-Ethylhexanol 000104-76-7 0 0.00063 0
Proprietary Clay TRADE SECRET 0 0.11323 0
Guar Gum 009000-30-0 0 0.11323 0
Copper Sulfate 007758-98-7 0 0.00056 0
Proprietary Polycarboxylic Acid Polymer TRADE SECRET 0 0.01827 0
Diethylene Glycol 000111-46-6 0 0.00063 0
Water 007732-18-5 0 0.06853 0
Petroleum Distillate Hydrotreated Light 064742-47-8 0 0.11323 0
PTLFR200 PERFORMANCE TECHNOLOGIES Friction Reducer Proprietary Aliphatic Hydrocarbon TRADE SECRET 30 0.01428 0
Proprietary Oxyalkylated Alcohol TRADE SECRET 5 0.00238 0
EC6111A NALCO Anti-Bacterial Agent Glutaraldehyde (Pentanediol) 000111-30-8 30 0.00754 0
Water 007732-18-5 0 0.02648 0
PTLIS352 PERFORMANCE TECHNOLOGIES Iron Control Agent Citric Acid 000077-92-9 100 0.00047 0
Recycled Produced Water CHESAPEAKE ENERGY Carrier/Base Fluid Water 007732-18-5 100 7.77114 0
PTLBW112 PERFORMANCE TECHNOLOGIES Breaker Ammonium Persulfate 007727-54-0 100 0.00434 0
PTLMP136 PERFORMANCE TECHNOLOGIES Acid Water 007732-18-5 85 0.78085 0
Hydrochloric Acid 007647-01-0 15 0.1378 0
Fresh Water CHESAPEAKE ENERGY Carrier/Base Fluid Water 007732-18-5 100 76.4617 0
PTLBW102 PERFORMANCE TECHNOLOGIES Breaker Ammonium Persulfate 007727-54-0 100 0.00076 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
2013-03-19 H2O 15 8120 Bbl 500260 Performance Technologies STAGE 6

36 SHOTS

2013-03-18 H2O 15 8111 Bbl 514640 Performance Technologies STAGE 2

36 SHOTS

2013-03-20 H2O 15 7852 Bbl 514680 Performance Technologies STAGE 9

36 SHOTS

2013-03-18 H2O 15 9264 Bbl 499660 Performance Technologies STAGE 1

36 SHOTS

2013-03-19 H2O 15 8018 Bbl 500560 Performance Technologies STAGE 5

36 SHOTS

2013-03-19 H2O 15 11545 Bbl 11892 Performance Technologies STAGE 3

36 SHOTS

2013-03-20 H2O 15 7920 Bbl 503500 Performance Technologies STAGE 7

36 SHOTS

2013-03-20 H2O 15 7537 Bbl 491300 Performance Technologies STAGE 8

36 SHOTS

2013-03-19 H2O 15 7439 Bbl 510500 Performance Technologies STAGE 4

36 SHOTS

2013-03-20 H2O 15 7951 Bbl 481680 Performance Technologies STAGE 10

36 SHOTS

15 0 0

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2014 CHESAPEAKE EXPLORATION LLC 903313 496 303
2015 CHESAPEAKE EXPLORATION LLC 511879 48 308
2016 CHESAPEAKE EXPLORATION LLC 402944 38 366
2017 CHESAPEAKE EXPLORATION LLC 302765 39 365
2018 CHESAPEAKE EXPLORATION LLC 253675 56 363
2019 CHESAPEAKE EXPLORATION LLC 56990 15 90

For data sources see[6] [7]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2014 CHESAPEAKE EXPLORATION LLC Brine 8909 303
2015 CHESAPEAKE EXPLORATION LLC Brine 3760 308
2016 CHESAPEAKE EXPLORATION LLC Brine 2967 366
2017 CHESAPEAKE EXPLORATION LLC Brine 1828 365
2018 CHESAPEAKE EXPLORATION LLC Brine 1440 363
2019 CHESAPEAKE EXPLORATION LLC Brine 581 90

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1158475980 2012-8-1 0:00:0 DD No Violations
-1663385207 2012-7-26 0:00: DD No Violations
-1995621760 2012-8-10 0:00: DD No Violations
-510725791 2019-7-30 0:00: PW No Violations 1.00
-799089957 2012-8-7 0:00:0 DD No Violations
0090334245 2012-08-02 Drill / Deepen / Reopen No Violations

---Tex Pumping LLC was the cementing contractor. There was good fluid circulation throughout the cementing operation. The cement was mudscaled, and O-Tex pumped 141 bbls of cement slurry at 15.6 pounds per gallon (ppg). Cement returns to surface were observed. An estimated 25 bbls of cement returned to surface. The plug was dropped and displaced with 104 bbls of water. The plug bumped the float collar at 11:35am. O-Tex pressured up on the casing to 1,020 psi, and the pressure held. When the pressure was released, approximately 0.5 bbl of water bled back, and the float held.

0434260097 2012-08-20 Drill / Deepen / Reopen No Violations I went to the site to follow up on the disassembly an move-out of the drilling rig. The rig was off location, and crews were removing mat boards and miscellaneous equipment.
0708272783 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.

0799089957 2012-08-07 Drill / Deepen / Reopen No Violations
1110736823 2017-01-26 Production Wells No Violations The purpose of my inspection was to document the annular casing pressure well # 2-1735. ODNR-DOGRM Northeast Regional Manager Thomas Hill and ODNR-DOGRM Senior Health Physicist Robert Leidy were present during the inspection. At the time of inspection, lease operator Romano Oliver arrived on location. I observed the 5.5 production casing annular pressure gauge indicating 600 psi. Mr. Oliver opened the valve and released the pressure to 0 psi. After closing the valve, the pressure did not immediately begin to increase. I will schedule to revist the location to determine if the annular pressure recovers.
1158475980 2012-08-01 Drill / Deepen / Reopen No Violations

-cone bit, and clean the hole with water-based drilling mud. Once the borehole was cleaned, the rig would install the surface casing.

1303492221 2017-02-28 Production Wells No Violations The purpose of my inspection was to document annular and production pressures on well #2-1735. At the time of my inspection, I observed the 9.625 annular casing pressure to indicate 0 psi, the 5.5 annular production casing pressure indicated 650 psi, the 5.5 production casing pressure indicated 160 psi, and the production tubing indicated 157 psi. I will contact Chesapeake Regulatory Affairs Manager Jody Jones to determine what the scheduled date is for equipping the production casing to mitigate annular pressure.
1320827682 2017-09-20 Production Wells No Violations The purpose of my inspection was to conduct a status check on well #2-1735. The road, pad and security fence remained in good repair. The topsoil stockpile was stable. Jersey barriers to were in place to protect the well head and production equipment. The cellar contained freshwater that prevented sight of the annular gauge valves. The annular gauge valves were identified. The 9.625 gauge identified 0 psi. The 5.5 gauge identified 450 psi. The 5.5 production casing was equipped with a plunger lift assembly and was flowing at the time of inspection. No leaks were identified. Production equipment on location consisted of one (1) sand knock out and GPU, one (1) hydrate inhibitor tank, one (1) meter run and two (2) 400 bbl produced water tanks inside an impervious lined steel containment. The pressure relief valve for the fuel gas reservoir inside the GPU was activated and functioning at 120 psi. I called and spoke with Chesapeake field technician Gus Jerome regarding the issue. Mr. Jerome stated he would contact the field foreman to make necessary repairs. I will follow up to ensure the repair was made.
1663385207 2012-07-26 Drill / Deepen / Reopen No Violations

-

1695254239 2012-07-29 Drill / Deepen / Reopen No Violations I went to the site and had a pre-spud meeting with drilling consultants Terry Getz and Cory Holdge at Nomac 311. They anticipate commencing drilling tomorrow (07/30/2012).
1732527890 2016-12-07 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.

Correct and legible identification is posted at the well head. The cellar contains water with approximately 8 of freeboard. No sheen was observed on the water. Steel grating is placed over the cellar to prevent falls. The mousehole is cemented. Annular pressure gauges on the intermediate and production casing are not identified. Determination was made by position on well head. The intermediate annular pressure gauge indicated 0 psi. The production casing annular pressure gauge indicated 550 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 576 psi. Tubing has been placed inside the 5.5 production casing. The digital production casing pressure gauge indicated 164.8 psi. The digital production tubing pressure gauge indicated 157.2 psi. No audible or visual leaks were detected. Production equipment located on the pad consists of one (1) vertical sand/fluid separator, one (1) gas processing unit (GPU), one (1) 350 gallon hydrate inhibitor tank within sealed containment, one (1) sales meter, two (2) 400 bbl production tanks

1753536642 2012-08-04 Drill / Deepen / Reopen No Violations

-Tex Pumping LLC was the cementing contractor. There as good fluid circulation throughout the cementing operation. The cement was mudscaled at 15.6 pounds per gallon (ppg). O-Tex pumped 150 bbls of cement slurry at 15.6 ppg. Cement returns to the surface were observed. An estimated 20 bbls of cement returned to the surface. The plug was displaced with 138 bbls of water. The plug bumped the float collar at 1:35am on 08/05/2012. Pressure was increased to 1000 psi, and pressure held. The float held when the pressure was released.

1768415398 2012-08-14 Drill / Deepen / Reopen No Violations Drove to location met with Wade the Drilling Foreman for Patterson Rig 310 possible 5.5 production casing and cement job soon he will call.
1995621760 2012-08-10 Drill / Deepen / Reopen No Violations
434260097 2012-8-20 0:00: DD No Violations
708272783 2014-10-24 0:00 PL No Violations
90334245 2012-8-2 0:00:0 DD No Violations

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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