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34-013-21259

Well Details

Well ID: 34-013-21259
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Country: United States
State: Ohio
County: Belmont
Municipality: Mead Township
Operator Name: GULFPORT APPALACHIA LLC
Well Pad ID: US-OH-001508
Farm/Lease Name: DILLES BOTTOM 210007
License Status: Producing
License Date: 2017-09-28
Spud Date: 2017-09-11
Spud Drilling Contractor: PATTERSON DRILLING
Final Drill Date: 2017-12-31
Well Total Depth: 19139.00 ft
Configuration: Horizontal
Latitude: 39.930000
Longitude: -80.770000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2017-05-26 Proposed Formations:TRENTON, Issued Date:5/26/2017, Expired Date:5/26/2019 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:ST, Proposed Well Class:STRT
APP 2017-09-28 Proposed Formations:UTICA/POINT PLEASANT, Issued Date:9/28/2017, Expired Date:9/28/2019 12:00:00 PM, Drilling unit acres:562.592, Proposed Well Type:OG, Proposed Well Class:EOUT
Reached Total Depth 2017-12-31
Correction to Well 2018-08-24 TARGET TAKE AS-DRILLED
Completion Report Received 2019-01-09
Record Last Modified 2019-01-15
Construction Permit Expires 2019-09-28

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2019-01-14 10991 11162 0
2019-01-14 18861 18966 0
18861 18966 0
10991 11162 0
10991 11162 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 06/09/2018 07/14/2018 10743 17,512,300.0 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 88.2058 146,140,000.0
Sand (Silca) Muskie Proppant Silica Substrate 14808-60-7 100 11.4565 18,981,200.0
Biotreat 15588 X-Chem Biocide Water 7732-18-5 74 0.0223423 37016.9
Quaternary Ammonium chloride 68424-85-1 3 0.000905768 1500.69
Glutaraldehyde 111-30-8 20 0.00603845 10004.6
Didecyl dimethyl Ammonium Chloride 7173-51-5 3 0.000905768 1500.69
Hydrochloric Acid (28%) Oxy Acidizing Hydrochloric Acid (Hydrogen Chloride) 7647-01-0 28 0.0548511 90877.8
SC-30 X-Chem Scale inhibitor Water 7732-18-5 98.5 0.0136111 22550.9
sodium hydroxide 1310-73-2 1.5 0.000207275 343.415
NEFE-180 Chemplex Corrosion Inhibitor/Iron Control Fatty acids, tall oil 61790-12-3 5 0.00005852 96.949
2-Ethylhexanol 104-76-7 10 0.000117031 193.899
Methanol 67-56-1 35 0.00040961 678.645
Acetic acid 64-19-7 65 0.000760703 1260.34
Olefin Proprietary 5 0.00005852 96.949
Alcohols, C14-15, ethoxylated 68951-67-7 5 0.00005852 96.949
2-Propyn-1-ol 107-19-7 5 0.00005852 96.949
Coconut oil acid diethanolamine 68603-42-9 5 0.00005852 96.949
Plexslick 957 Chemplex Friction Reducer Petroleum Distillate 64742-47-8 20 0.0193225 32013.8
Water 7732-18-5 60 0.0579676 96041.3
Ammonium Chloride 12125-02-9 2 0.00193225 3201.38
Oleic Acid Diethanolamide 93-83-4 1.5 0.00144919 2401.03
Alcohols, C12-16, Ethoxylated 68551-12-2 1.5 0.00144919 2401.03
Other Chemical(s) Listed Above See Trade Name(s) List 2-Propyn-1-ol 107-19-7 5 0.00005852 96.949
2-Ethylhexanol 104-76-7 10 0.000117031 193.899
Alcohols, C14-15, ethoxylated 68951-67-7 5 0.00005852 96.949
Alcohols, C12-16, Ethoxylated 68551-12-2 1.5 0.00144919 2401.03
Fatty acids, tall oil 61790-12-3 5 0.00005852 96.949
Water 7732-18-5 74 0.0223423 37016.9
Ammonium Chloride 12125-02-9 2 0.00193225 3201.38
Olefin Proprietary 5 0.00005852 96.949
Quaternary Ammonium chloride 68424-85-1 3 0.000905768 1500.69
Methanol 67-56-1 35 0.00040961 678.645
Oleic Acid Diethanolamide 93-83-4 1.5 0.00144919 2401.03
Coconut oil acid diethanolamine 68603-42-9 5 0.00005852 96.949
Water 7732-18-5 60 0.0579676 96041.3
Didecyl dimethyl Ammonium Chloride 7173-51-5 3 0.000905768 1500.69
Water 7732-18-5 98.5 0.0136111 22550.9

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
2018-06-09 H2O 28 11994 Bbl 496080 STINGRAY PRESSURE PUMPING LLC STAGE 1 OF 38
2018-07-14 H2O 28 9799 Bbl 502020 STINGRAY PRESSURE PUMPING LLC STAGE 38 OF 38…SEE IMAGES FOR STAGES 2-37

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2018 GULFPORT ENERGY CORPORATION 366491 0 20
2019 GULFPORT ENERGY CORPORATION 1938922 0 90

For data sources see[6] [7]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2018 GULFPORT ENERGY CORPORATION Brine 2718 20
2019 GULFPORT ENERGY CORPORATION Brine 7886 90

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-120137084 2018-11-14 0:00 PL No Violations 0.50
-1296248753 2019-3-7 0:00:0 PW No Violations 0.40
-1836641106 2020-5-21 0:00: PL No Violations 0.30
-2040954892 2017-9-22 0:00: CS No Violations 9.00
-823415175 2018-9-17 0:00: CT No Violations 1.00
0039008280 2017-10-03 Drill / Deepen / Reopen No Violations Following a down hole motor failure from the previous day, Patterson rig 583 had reached total depth in the 12.25-inch diameter open hole section of the well bore. They are currently moving the drilling string from the well bore. Once the drill string is out of the well bore they will begin running the 9.625-inch diameter casing string. They will then cement that casing string in place.
0120137084 2018-11-14 Preliminary Restoration No Violations Preliminary Restoration status check inspection found the area affected by the well pad construction meets ORC 1509.072 with vegetation established and erosion control in place. The lease road and well pad surface is stone construction and in good repair. There is a 3rd party mid stream contractor installing a mid stream facility on the North slope of the well pad. All outward slopes are stable with good vegetation established. The restoration is sufficient with no violations noted but will need followed up on when the mid stream facility is complete and the remainder of the production equipment is installed on the well pad. The current operations on the pad finds a derrick style service rig owned by Hybrid Drilling is on location and rigging up on the # 3 well and preparing to drill out the completion plugs. The 2.875 production tubing was at a set depth of 10,757 on the said well (#4-C). A completion tree has been installed.
0823415175 2018-09-17 Completion Testing No Violations On the day of my inspection accompanied by ODNR inspector Bill Stolarik I witnessed the well was currently shut in and was not producing. There was a 5800 pound per square inch manual frack valve installed on the well head and annular pressure monitoring was in place for the 13.375-inch diameter casing, gauge reading was 100 pounds per square inch, and the 9.625-inch diameter deep intermediate casing, gauge reading was 0 pounds per square inch. There were six 500-barrel portable fluid storage tanks that were not hooked to any of the wells on the pad at the time of my inspection. There were currently crews installing gravel on the well pad in preparation for the workover rig to move in. Well heads were identified, and no production was reported for this well at the time of my inspection.
0926181593 2018-08-20 Drill / Deepen / Reopen No Violations On the day of my inspection I witnessed the well was currently shut in and was not producing. There was a 5800 pound per square inch manual master valve installed on the well head and annular pressure monitoring was in place for the 13.375-inch diameter casing, gauge reading was 100 pounds per square inch, and the 9.625-inch diameter deep intermediate casing, gauge reading was 0 pounds per square inch. Also, on location was six 500-barrel portable fluid storage tanks that were not hooked to any of the wells on the pad at the time of my inspection. Well heads were identified, and no production was reported for this well at the time of my inspection.
1068545509 2017-09-25 Drill / Deepen / Reopen No Violations The company attempted to run the 13.375-inch diameter casing string and was unable to successful accomplish running the casing to total depth. The casing string would not progress past the 814 foot mark in the well bore. Most of the red rock came in at a depth of 790 feet to 810 feet. There was an influx of water that came in at 1480 foot in the well bore. The Berea was called at a depth of 2240 feet within the well bore. The company is currently reaming the hole to enable them to run and cement their 13.375-inch diameter casing string.
1217342930 2018-09-17 Completion Testing No Violations Status check inspection accompanied by ODNR Inspector Ryan Armstrong found 4 wells present on the well pad. All 4 wells have had the drilling and completion process complete and are awaiting a service rig to make the clean out The wells are equipped with 2 manually operated primary master valves. Attached to the well head A&B section outlet valves are gate valves with 2 riser pipes connected, attached to the riser pipes are valves and gauges. No production equipment has been set. The lease road and well pad are stone surface construction and in good repair.
1273661056 2018-01-22 Completion Testing No Violations On the day of my inspection the well was equipped with 5.5-inch diameter casing. The operator was preparing the location for completion operations. They were currently laying down the mats that the equipment will be setting on. Once the mats are installed the company will begin mobilizing completion equipment to the site.
1296248753 2019-03-07 Production Wells No Violations Status check inspection found (4) wells present on the pad. The said well is equipped with a tubing head that is tied into a main sales line. The well head consists of a lower A and upper B section with 2 diameter riser pipes attached to both well head sections for the purpose of annular pressure monitoring. The 2 diameter riser pipes are equipped with valves and gauges with the A section gauge reads 250 pounds pressure and the B section gauge reads 500 pounds pressure, the 5.5 casing pressure is 5,600 pounds and the production flow line pressure downstream of the well head choke is 4,000 pounds. Production equipment on location includes (4) gas processing units and a production fluid storage facility that consists of (6) steel 400 barrel tanks situated inside a polymer lined steel containment dike area. There is a third party mid stream pipeline take point on the North East side of the well pad.
1506058531 2017-09-22 Casing String Witnessed No Violations On site inspection to witness the surface casing installation and cementing with Patterson Drilling rig 583 on location along with Wyoming Casing and Stingray Cement Service. Upon arrival it was observed that Patterson Drilling had drilled a 24 diameter surface borehole to a measured depth of 577 off of a 26 drilling rig Kelly bushing heigth with the # 8 Pittsburgh Coal seam encountered at 528 to 535. Upon reaching total depth the rig circulated the hole clean on air and then switched to fresh water fluid and loaded the hole with circulation established to surface. The rig the pulled the drill string and inserted 577 of 18.625 diameter 87.5 pound per foot J-55 grade buttress thread casing with a guide shoe and float collar casing equipment ran and 3 casing centralizers. A Wetherford swell packer was set in the string at 491 to 462. Inspector Andrew Corder accompanied me on site.
1506412951 2017-09-26 Casing String Witnessed No Violations On site inspection from 2:00 am until 4:00 am to witness the 13.375 casing installation. Patterson Drilling rig 583 is on location and has drilled a 17.5 diameter 1st intermediate well bore to a measured depth of 2,271 off of a 26 drilling rig Kelly bushing heigth. The rig is running 13.375 diameter J-55 Grade buttress thread casing to a measured depth of 2,271 with a casing guide shoe and float collar ran and proper centralizer placement demonstrated. Stingray cement service is on location to cement the casing using a 399 barrel class A cement mix with 25 barrels of 6% gel spacer to be ran ahead.
1506431371 2017-09-26 Casing String Witnessed No Violations On the day of my inspection I witnessed the intermediate casing cement job. Patterson 583 drilled a 17.5 inch diameter open hole to a depth of 2271feet. Previous casing set and cemented was 18.625 inch diameter mine string casing to a depth of 577 feet. Costys ran 2271 feet of 13.325 inch diameter casing, j-55, 54.5 lbs/foot. Casing was centralized with 22 centralizers. Shoe track is 46 feet long. Stringray was onsite with 1893 sacks of class A cement. Additives include 0.3% cacl2 and .25 lb/sack celluseal. Cement weighed with mudscale at 15.6 ppg and yield of 1.18. 50% excess ran in open hole. Cement displaced with barrels of fresh water. 25 barrels of gel pumped ahead of cement. No cement returned to surface just gel. Floats held with 2.5 barrels back. Mix water has pH of 6-7, 53 ppm chlorides and 70 degrees Fahrenheit. Waited three hours and ran 131 feet kb of 1 inch diameter tubing into the hole and tagged cement. Had rig pull all the 1 inch back out and verified that there was cement on the bottom of the tubing. A centralizer was at 122 feet kb so I made sure we were not landing on it. On the way back in the tubing kept getting hung up on cement so they laid 1 joint down (31.34 feet) and pumped from there. Stringray then rigged up and pumped 17 barrels of class a neat cement through the inch in tubing. 5 barrels of cement returned to surface.
2040954892 2017-09-22 Casing String Witnessed No Violations On site to witness the 18.625-inch diameter casing job with Inspector Bill Stolarik. The company ran 577 foot of casing in a 24-inch diameter open hole. Stingray cementing was on site to pump 196 barrels of Class A cement. Bill and I reviewed the cement calculations and casing tally. The open hole was filled with water before the casing was ran which indicated that there was no void or loss zone encountered while drilling this section of the well bore.
39008280 2017-10-3 0:00: DD No Violations 2.00
926181593 2018-8-20 0:00: DD No Violations 0.50

For data sources see[10]

References