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34-111-24752

Well Details

Well ID: 34-111-24752
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Country: United States
State: Ohio
County: Monroe
Municipality: Switzerland Township
Operator Name: GULFPORT APPALACHIA LLC
Well Pad ID: US-OH-001484
Farm/Lease Name: FOLLOWAY 211257
License Status: Producing
License Date: 2017-07-11
Spud Date: 2017-09-15
Spud Drilling Contractor: SIDEWINDER DRILLING INC
Final Drill Date: 2017-10-24
Well Total Depth: 20689.00 ft
Configuration: Horizontal
Latitude: 39.820000
Longitude: -80.960000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2017-06-13 Proposed Formations:TRENTON, Issued Date:6/13/2017, Expired Date:6/13/2019 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:ST, Proposed Well Class:STRT
APP 2017-07-11 Proposed Formations:UTICA/POINT PLEASANT, Issued Date:7/11/2017, Expired Date:7/11/2019 12:00:00 PM, Drilling unit acres:490.512, Proposed Well Type:OG, Proposed Well Class:POOL
Reached Total Depth 2017-10-24
Correction to Well 2018-03-30 UPDATE TAKE/TARGET PER AS-DRLLED PLAT
Completion Report Received 2018-07-13
Record Last Modified 2018-08-03
Construction Permit Expires 2019-07-11

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2018-08-02 10319 10463 0
2018-08-02 20416 20521 0
20416 20521 0
10319 10463 0
10319 10463 0

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 01/31/2018 03/04/2018 10159 18,115,900.0 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 Other Chemical(s) Listed Above See Trade Name(s) List Water 7732-18-5 55 0.00828625 13871.2
Fatty acids, tall oil 61790-12-3 5 0.00006433 107.689
Didecyldimethylammonium Chloride 7173-51-5 8 0.00260536 4361.38
Ethanol 64-17-5 2 0.000651341 1090.35
Alkyl dimethyl benzyl ammonium chloride 68424-85-1 5.5 0.00179119 2998.45
2-Ethylhexanol 104-76-7 10 0.000128661 215.379
Oleic Acid Diethanolamide 93-83-4 1.5 0.00129951 2175.38
Alcohols, C14-15, ethoxylated 68951-67-7 5 0.00006433 107.689
Water 7732-18-5 60 0.0195402 32710.4
Water 7732-18-5 72 0.149534 250321
Ammonium Chloride 12125-02-9 2 0.00173268 2900.51
Methanol 67-56-1 35 0.000450313 753.825
Alcohols, C12-16, Ethoxylated 68551-12-2 1.5 0.00129951 2175.38
2-Propyn-1-ol 107-19-7 5 0.00006433 107.689
Olefin Proprietary 5 0.00006433 107.689
Coconut oil acid diethanolamine 68603-42-9 5 0.00006433 107.689
Water 7732-18-5 60 0.0519804 87015.2
Plexslick 957 Chemplex Friction Reducer Ammonium Chloride 12125-02-9 2 0.00173268 2900.51
Alcohols, C12-16, Ethoxylated 68551-12-2 1.5 0.00129951 2175.38
Water 7732-18-5 60 0.0519804 87015.2
Petroleum Distillate 64742-47-8 20 0.0173268 29005.1
Oleic Acid Diethanolamide 93-83-4 1.5 0.00129951 2175.38
Hydrochloric Acid (28%) Dover Acidizing Water 7732-18-5 72 0.149534 250321
Hydrochloric Acid (Hydrogen Chloride) 7647-01-0 28 0.0581522 97346.9
Sand (100 Mesh Proppant) Muskie Proppant Silica Substrate 14808-60-7 100 1.31591 2,202,840.0
NEFE-180 Chemplex SOLVAY Corrosion Inhibitor/Iron Control 2-Propyn-1-ol 107-19-7 5 0.00006433 107.689
Olefin Proprietary 5 0.00006433 107.689
2-Ethylhexanol 104-76-7 10 0.000128661 215.379
Alcohols, C14-15, ethoxylated 68951-67-7 5 0.00006433 107.689
Methanol 67-56-1 35 0.000450313 753.825
Acetic acid 64-19-7 65 0.000836296 1399.96
Coconut oil acid diethanolamine 68603-42-9 5 0.00006433 107.689
Fatty acids, tall oil 61790-12-3 5 0.00006433 107.689
Sand (40/70 Mesh Proppant) Muskie Proppant Silica Substrate 14808-60-7 100 8.03177 13,445,200.0
Bio B2512 Aquaserv Biocide Glutaraldehyde 111-30-8 27 0.0087931 14719.7
Didecyldimethylammonium Chloride 7173-51-5 8 0.00260536 4361.38
Ethanol 64-17-5 2 0.000651341 1090.35
Water 7732-18-5 60 0.0195402 32710.4
Alkyl dimethyl benzyl ammonium chloride 68424-85-1 5.5 0.00179119 2998.45
Water Gulfport Energy Carrier/Base Fluid Water 7732-18-5 100 90.3091 151,178,000.0
SI-20W Moon Scale Inhibitor Phosphinocarboxylic Acid 110224-99-2 45 0.00677966 11349.2
Water 7732-18-5 55 0.00828625 13871.2

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
2018-01-31 H2O 15 7658 Bbl 274400 STINGRAY PRESSURE PUMPING LLC STAGE 1 OF 57
2018-03-04 H2O 10 6869 Bbl 275280 STINGRAY PRESSURE PUMPING LLC STAGE 57 OF 57 SEE IMAGES FOR STAGES 2-56

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2018 GULFPORT ENERGY CORPORATION 3125216 0 195
2019 GULFPORT ENERGY CORPORATION 937295 0 90

For data sources see[6] [7]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2018 GULFPORT ENERGY CORPORATION Brine 44326 195
2019 GULFPORT ENERGY CORPORATION Brine 10124 90

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-266379939 2018-5-9 0:00:0 CT No Violations 0.50
-32288559 2020-5-18 0:00: PL No Violations 1.00
-349808726 2018-1-16 0:00: CT No Violations 0.50
0020664252 2018-05-16 Completion Testing No Violations Status check inspection found the well drilling and completion process complete. The well is shut in due to an incident that occurred on location involving the # 1 well. The incident occurred on 05/09/2018. Addressing the said well, the well is equipped with a lower A section well head and upper B section along with a production tree upper section consisting of 3 manual master valves and an primary (ESD) Emergency Shut Down valve that can be controlled at the well head or remotely on or off location. The well is currently shut in and awaiting the initial flow back production stages. The company does have annular pressure monitoring in place on both the 13.375 and 9.625 well head sections with pressure gauges and flow lines present. The 9.625 well head section has 2,600 (PSI) pounds per square inch present on the gauge and the 13.375 well head section has zero pressure present on the gauge. The company man on site has been informed to address the annular pressure on the 9.625 section.
0266379939 2018-05-09 Completion Testing No Violations On this day I was on site for 10 hours conducting an initial investigation and monitoring the initial clean up of the well pad from a release that occurred involving the Followay #1A well. The said well # 2A has had the drilling and completion process completed and the well was awaiting the initial flow back operation stage. The well is equipped with annular pressure monitoring and flow back iron is attached to all annulis. The well does have production tubing set in the well bore and a production tree is in place. The initial flow back operations takes place trough the secondary production tree production flowline attachment point through two primary master valves and a emergency shut down valve belonging to Pro Flow back. All flow back equipment belonging to Pro Flow is being demobilized from location. I also discussed annular pressure monitoring with the company men on site.
0349808726 2018-01-16 Completion Testing No Violations Status check inspection found crews on site preparing to install the tubing head section of the well head in anticipation of prepping the well for the stimulation process to begin. The 5.5 diameter production casing will be bond logged and have the 5.5 production casing toe sleeve opened for the 1st stage completion plug and perforation gun. The well drilling process is complete.
0769023557 2018-08-06 Production Wells No Violations Status check inspection found 3 wells producing on the pad. The pad surface is of stone construction with a earthen perimeter berm, the perimeter valves are closed. The well head is equipped with a lower A and upper B section along with a production tree. The well is currently in production with the production valves open. The well head has riser pipes and valves with gauges present to monitor annular pressure on the A & B sections with zero pounds per square inch pressure on the A section which monitors the pressure on the 13.375 diameter casing string (between the 13.375 and 9.625). The pressure on the B section which monitors the pressure on the 9.625 casing string (between the 9.625 and 5.5 diameter casing strings) is 1,200 psi. The 5.5 diameter production casing internal working pressure is 4,800 psi. The production flowline pressure is 1,800 psi. The well head assembly is equipped with 2 manual valves on the vertical section of the production tree followed by a manual then a emergency shut down valve on the horizontal outlet section of the production tree. Also on location is 3 gas processing units along with a production facility tank farm consisting of 4 steel construction 400 barrel capacity tanks situated inside a polymer lined steel containment dike area. Proper well identification is posted at the well heads along with hazard and identification on the tank battery. At a critical hazard and muster points of the pad are fire extinguishers and emergency shut down master well control devices.
1287768383 2018-02-21 Completion Testing No Violations Status check inspection on the well completion process found Stingray Pressure Pumping service on location completing all 3 wells on the pad simultaneously with the company currently pumping on the # 3 well. Addressing the # 2 well - the well has had 33 stages completed out of a total of 57 proposed with a average treating volume of 7,100 barrels total fluid volume. The average initial shut in pressure is 6,100 (psi) pounds per square inch and the pressure drops back to 5,300 psi by the time they start the next stage. The 5.5 diameter production casing annular pressure is being monitored electronically with 30 psi currently showing. All remaining annular pressures are checked and recorded after each stage. The well head consist is made up of a B section lower well head base followed by a B&B well head completion stack made up of a 3 master valves 1 manual and 2 hydraulic with a flow cross sitting atop the master valves. All stimulation equipment is situated on polymer containment.
1366075576 2018-04-02 Preliminary Restoration No Violations Preliminary restoration status check inspection found the area affected by the well pad construction to have erosion control present and vegetation beginning to be established with 70% vegetation present. Construction work is being done installing the production equipment and midstream transportation lines. The pad surface and access road is of gravel construction and in good repair. The restoration will need followed up on later in the year. Addressing the well head and production equipment. The well drilling stimulation and completion process is finished and the well has production tubing inserted into the well bore. The well is shut in and awaiting the completion of the production equipment installation. The production tanks and gas processing units are set and being hooked up. Annular pressure monitoring is in place on the well A and B sections which is monitoring the 13.375 and 9.625 well head casing pressures with zero pressure on either string at the time of my inspection.
1505650869 2017-09-17 Casing String Witnessed No Violations On site inspection to witness the surface casing cement job with Sidewinder Drilling rig 103 on location along with Halliburton Cement Service. The rig has drilled a 17.5 diameter well bore to a depth of 1,515 measured off a drilling rig Kelly Bushing heigth of 30.5 above ground level elevation. The rig ran a total of 1,515 of 54.5 pound per foot J-55 grade Buttress Thread casing with a casing guide shoe and float collar ran with proper centralizer placement demonstrated. Halliburton Cemented the casing using a 280 barrel Class H cement mix consisting of 1,310 sacks of cement. The cement mix was verified at 15.6 pound per gallon by weight of scale. The cement was displaced to the float collar set at 1,469 with 224 barrels of fresh water. Cement returns were witnessed to surface at 195 barrels into displacement with a final displacement pressure of 690 psi and the casing being pressure tested to 1,385 psi upon the landing of the cement plug. Casing string floats held.
20664252 2018-5-16 0:00: CT No Violations 0.50
2126652884 2018-06-14 Completion Testing No Violations Status check inspection accompanied by ODNR North Region Emergency Response Coordinator Andrew Adgate. 3 wells are present on the well pad with a company identified as J&A Flowback on site rigging up flow back equipment to begin the initial flow back operations. Annular pressure is being monitored on the 13.375 and 9.625 sections of all 3 wells present on the pad. The company has a 3000 psi threshold on the 9.625 and a 600 psi threshold on the 13.375 well head section with no annular pressure being allowed to exceed 50% of the maximum threshold pressure.
769023557 2018-8-6 0:00:0 PW No Violations 0.30

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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