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34-111-24751

Well Details

Well ID: 34-111-24751
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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 210121
License Status: Producing
License Date: 2017-07-11
Spud Date: 2017-08-02
Spud Drilling Contractor: PATTERSON DRILLING
Final Drill Date: 2017-10-15
Well Total Depth: 20657.00 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:509.071, Proposed Well Type:OG, Proposed Well Class:POOL
Reached Total Depth 2017-10-15
Correction to Well 2018-03-28 UPDATE TARGET/TAKE PER AS-DRILLED 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 10505 10649 0
2018-08-02 20431 20533 0
20431 20533 0
10505 10649 0
10505 10649 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 03/05/2018 10134 17,735,300.0 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 Water Gulfport Energy Carrier/Base Fluid Water 7732-18-5 100 90.2701 148,001,000.0
Sand (40/70 Mesh Proppant) Muskie Proppant Silica Substrate 14808-60-7 100 8.03772 13,178,200.0
Other Chemical(s) Listed Above See Trade Name(s) List Water 7732-18-5 72 0.148971 244244
Coconut oil acid diethanolamine 68603-42-9 5 0.00006397 104.88
Ethanol 64-17-5 2 0.000657025 1077.22
Alkyl dimethyl benzyl ammonium chloride 68424-85-1 5.5 0.00180682 2962.35
Water 7732-18-5 60 0.0197107 32316.5
Fatty acids, tall oil 61790-12-3 5 0.00006397 104.88
Oleic Acid Diethanolamide 93-83-4 1.5 0.00129049 2115.82
Didecyldimethylammonium Chloride 7173-51-5 8 0.0026281 4308.87
Water 7732-18-5 55 0.00825805 13539.4
Methanol 67-56-1 35 0.000447786 734.163
Olefin Proprietary 5 0.00006397 104.88
Water 7732-18-5 60 0.0516197 84632.6
Ammonium Chloride 12125-02-9 2 0.00172066 2821.09
2-Ethylhexanol 104-76-7 10 0.000127939 209.761
2-Propyn-1-ol 107-19-7 5 0.00006397 104.88
Alcohols, C12-16, Ethoxylated 68551-12-2 1.5 0.00129049 2115.82
Alcohols, C14-15, ethoxylated 68951-67-7 5 0.00006397 104.88
SI-20W Moon Scale Inhibitor Phosphinocarboxylic Acid 110224-99-2 45 0.00675659 11077.7
Water 7732-18-5 55 0.00825805 13539.4
Sand (100 Mesh Proppant) Muskie Proppant Silica Substrate 14808-60-7 100 1.35012 2,213,580.0
NEFE-180 Chemplex SOLVAY Corrosion Inhibitor/Iron Control Coconut oil acid diethanolamine 68603-42-9 5 0.00006397 104.88
Acetic acid 64-19-7 65 0.000831602 1363.44
2-Propyn-1-ol 107-19-7 5 0.00006397 104.88
2-Ethylhexanol 104-76-7 10 0.000127939 209.761
Methanol 67-56-1 35 0.000447786 734.163
Olefin Proprietary 5 0.00006397 104.88
Alcohols, C14-15, ethoxylated 68951-67-7 5 0.00006397 104.88
Fatty acids, tall oil 61790-12-3 5 0.00006397 104.88
Plexslick 957 Chemplex Friction Reducer Petroleum Distillate 64742-47-8 20 0.0172066 28210.9
Water 7732-18-5 60 0.0516197 84632.6
Alcohols, C12-16, Ethoxylated 68551-12-2 1.5 0.00129049 2115.82
Ammonium Chloride 12125-02-9 2 0.00172066 2821.09
Oleic Acid Diethanolamide 93-83-4 1.5 0.00129049 2115.82
Hydrochloric Acid (28%) Dover Acidizing Hydrochloric Acid (Hydrogen Chloride) 7647-01-0 28 0.0579332 94983.7
Water 7732-18-5 72 0.148971 244244
Bio B2512 Aquaserv Biocide Ethanol 64-17-5 2 0.000657025 1077.22
Glutaraldehyde 111-30-8 27 0.00886983 14542.4
Alkyl dimethyl benzyl ammonium chloride 68424-85-1 5.5 0.00180682 2962.35
Didecyldimethylammonium Chloride 7173-51-5 8 0.0026281 4308.87
Water 7732-18-5 60 0.0197107 32316.5

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
2018-03-05 H2O 10 7130 Bbl 273240 STINGRAY PRESSURE PUMPING LLC STAGE 56 OF 56 SEE IMAGES FOR STAGES 2-55
2018-01-30 H2O 15 7427 Bbl 275560 STINGRAY PRESSURE PUMPING LLC STAGE 1 OF 56

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2018 GULFPORT ENERGY CORPORATION 3101533 0 194
2019 GULFPORT ENERGY CORPORATION 950811 0 90

For data sources see[6] [7]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2018 GULFPORT ENERGY CORPORATION Brine 50234 194
2019 GULFPORT ENERGY CORPORATION Brine 11221 90

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1163924091 2018-2-21 0:00: CT No Violations 0.50
-1219195013 2017-8-3 0:00:0 CS No Violations 5.00
-1616867294 2018-8-6 0:00:0 PW No Violations 0.30
-1880398320 2020-5-18 0:00: PL No Violations 1.00
0363756758 2017-09-25 Drill / Deepen / Reopen No Violations During my inspection Sidewinder Drilling Rig 103 was in the process of skidding to the well to drill the surface borehole. I met with the Gulfport company man on location and exchanged contact information. The company man will be directing spud and cement notifications to me via email or cell phone.
1163924091 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.
1219195013 2017-08-03 Casing String Witnessed No Violations

-

1516126445 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.
1522687219 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.
1525892754 2018-05-09 Completion Testing No Violations On this day I received notification at 1:28 am of a release on the well pad site from a Gulfport HSE representative identified as Brad Burwell. The initial report indicated that the company was in the initial flow back operation stage of operation when the choke manifold integrity was compromised and the well did disperse at an uncontrolled rate for 1 hour and 2 minutes. Upon arrival at 8:00 am it was observed that the choke manifold was sand washed out from the inside due to the high pressure volume flowing through the choke manifold system. The choke manifold used was a #8 choke of 8/64ths size with a 3/4 diameter stem. Pro Flow was the flow back contractor. My initial investigation found product from the well bore had been dispersed both onto and off of the well pad location however no sign of impact outside the original limits of disturbance was discovered. The company estimated a off pad impact of 1/3rd acre. I also measured the pad dimensions which were 355 x 418 and found impact on a total area on the South West side of the pad to be 218 x 235. This area was titrate tested for chlorides in a total of (6) locations in which all indicated chloride levels on the well pad surface above 6,208 parts per million chlorides on high range chloride sampling strips. I was assisted on site by ODNR Engineer Technician Andy Thomas and ODNR Emergency Response member Jason Blocker. Together we titrate tested the location for chlorides and worked with the company in identifying any possible affected areas from the release. Also on location during the afternoon hours was a company identified as Shale Testing Solutions who took surface samples from ground level at 10 different locations across the well pad, the samples were taken back to their lab for analytical testing of Radium 226& 228. Throughout the day 3rd party contractors were on site breaking down the flow back equipment and pressure testing it on site with the cleaned equipment being removed from site. The company ha
1525985940 2018-05-10 Completion Testing No Violations Status check follow up to a well control incident that occurred on 05/09/2018 during the initial flow back production stage. On this day I met on site with ODNR Engineers Andy Thomas and Mark Atkinson along with ODNR Hydrologists Jake Glascock. Also on site were multiple representatives from Gulfport Energys production and HSE team. Discussions took place involving the remediation of the affected areas on the well pad from the product dispersed from the well during the incident. The company was advised that their plan to flush the well pad with water was not approved and the affected area was to be identified and remediated. Blake Arthur with Gulfport indicated they had contracted Hull and Associates to conduct testing of the well pad surface. It was also indicated that once the testing was complete another contractor would mobilize and remove material from the well pad surface.
1526490759 2018-05-16 Completion Testing No Violations Follow up inspection to a well control incident that occurred on 05/09.2018 involving the said well. The initial incident and release occurred during the initial stages of the well production when a choke manifold failed. The well initially released product uncontrolled for 1 hour and 20 minutes. On this day it was observed that Cactus well head company was on site attempting to switch the production tree stack assembly with a 3rd party contractor identified as Full Circle on site to pressure test the new well head upper assembly (production tree). The well head annular pressure was checked on the 13.375 and 9.625 well pad sections and no annular pressure was present. Also on site were excavation crews removing the affected area of the pad surface, the material removed from the affected area is being stockpiled and hauled off location. To date a total of 30 dump truck loads and 15 roll off containers have been loaded with material affected from the release and hauled off site. I also tested the standing fluid on the pad site at 4 different locations in the area where the pad surface has been removed and found no chloride levels over 500 parts per million. However a defined ditch line directly off the East side pad corner was tested and chloride levels were found as high as 4,389 parts per million. The company man on site was advised to address the issue through the Divisions Hydrologist.
1526919758 2018-05-21 Completion Testing No Violations Follow up inspection to a well control incident that occurred on 05/09/2018 involving the said well. The initial incident and release occurred during the initial stages of the well production when a choke manifold failed. The well initially released product uncontrolled for 1 hour and 20 minutes. On this day I met on site with ODNR Division Hydrologist Jake Glascock and we reviewed the action that has been take to address the well pad remediation and identified any potential points of interest that may still contain high chloride levels. Mr. Glascock is working on site with a 3rd party contractor identified as Hull and Associates to conduct surface testing for chlorides on the well pad. Hull and Associates will also prepare documents for the Division in regards to gridding and sampling and present those documents over to Mr. Glascock for review. The company (Gulfport) has 3rd party contractors on site recovering any surface fluid created from the recent rain events. The said well along with 2 additional wells on the pad are currently shut in and not producing however they are all complete and capable of production.
1529003007 2018-06-14 Completion Testing No Violations Follow up inspection to a well control incident that occurred on 05/09.2018 involving the said well accompanied this day by ODNR North Region Emergency Response Coordinator Andrew Adgate. The initial incident and release occurred during the initial stages of the well production when a choke manifold failed. The well initially released product uncontrolled for 1 hour and 20 minutes. The affected area from the release has been remediated by the means of removing the surface level of stone with additional testing being completed to confirm that no radiological material or chlorides present. All testing documentation has been submitted to Division staff hydrologists Jake Glascock. Chloride levels were tested both on or off the well pad and no chlorides were found over 96 parts per million on the well pad and chloride levels of 328 parts per million found off the well pad in a defined ditch line. 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 with no annular pressure found on either annulis of the said well. 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.
1616867294 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 zero psi. The 5.5 diameter production casing internal working pressure is 5,800 psi. The production flowline pressure is 2,000 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.
1791310705 2018-05-09 Production Wells No Violations On this day, I accompanied ODNR Inspector William Stolarik. Please reference his comments for a detailed report.
363756758 2017-9-25 0:00: DD No Violations 3.00

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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