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Well ID: 34-013-21257 | Loading map...
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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 210486 | |
License Status: Producing | |
License Date: 2017-10-24 | |
Spud Date: 2017-09-14 | |
Spud Drilling Contractor: PATTERSON DRILLING | |
Final Drill Date: 2017-12-02 | |
Well Total Depth: 23836.00 ft | |
Configuration: Horizontal | |
Latitude: 39.930000 | |
Longitude: -80.770000 |
For data sources see[1]
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 | 2017-10-24 | Proposed Formations:UTICA/POINT PLEASANT, Issued Date:10/24/2017, Expired Date:10/24/2019 12:00:00 PM, Drilling unit acres:625.06, Proposed Well Type:OG, Proposed Well Class:EOUT |
Reached Total Depth | 2017-12-02 | |
Correction to Well | 2018-08-24 | UPDATE TARGET TAKE ACREAGE AS-DRILLED PLAT |
Completion Report Received | 2019-01-09 | |
Record Last Modified | 2019-01-15 | |
Construction Permit Expires | 2019-10-24 |
For data sources see[2]
Perforation Date | Interval Top (ft) | Interval Base (ft) | Number of Shots |
---|---|---|---|
2019-01-14 | 10896 | 11065 | 0 |
2019-01-14 | 23557 | 23659 | 0 |
23557 | 23659 | 0 | |
10896 | 11065 | 0 | |
10896 | 11065 | 0 |
For data sources see[3]
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 | 07/27/2018 | 10552 | 18,880,600.0 | 0 |
Job Number | Trade Name | Supplier | Purpose | Ingredient Name | CAS Number | Additive Percentage by Mass | Job Percentage by Mass | Mass Used (lb) |
---|---|---|---|---|---|---|---|---|
1 | Hydrochloric Acid (28%) | Oxy | Acidizing | Hydrochloric Acid (Hydrogen Chloride) | 7647-01-0 | 28 | 0.0833313 | 144259 |
Plexslick 957 | Chemplex | Friction Reducer | Alcohols, C12-16, Ethoxylated | 68551-12-2 | 2 | 0.00194921 | 3374.37 | |
Petroleum Distillate | 64742-47-8 | 20 | 0.0194921 | 33743.7 | ||||
Water | 7732-18-5 | 60 | 0.0584764 | 101231 | ||||
Oleic Acid Diethanolamide | 93-83-4 | 2 | 0.00194921 | 3374.37 | ||||
Ammonium Chloride | 12125-02-9 | 2 | 0.00194921 | 3374.37 | ||||
Water | Gulfport Energy | Carrier/Base Fluid | Water | 7732-18-5 | 100 | 91.014 | 157,559,000.0 | |
Biotreat 15588 | X-Chem | Biocide | Glutaraldehyde | 111-30-8 | 20 | 0.00587946 | 10178.2 | |
Didecyl dimethyl Ammonium Chloride | 7173-51-5 | 3 | 0.000881918 | 1526.73 | ||||
Quaternary Ammonium chloride | 68424-85-1 | 3 | 0.000881918 | 1526.73 | ||||
Water | 7732-18-5 | 74 | 0.021754 | 37659.3 | ||||
SC-30 | X-Chem | Scale inhibitor | sodium hydroxide | 1310-73-2 | 1.5 | 0.000204564 | 354.13 | |
Water | 7732-18-5 | 98.5 | 0.013433 | 23254.5 | ||||
Sand (Silca) | Muskie | Proppant | Silica Substrate | 14808-60-7 | 100 | 8.54608 | 14,794,500.0 | |
NEFE-180 | Chemplex | Corrosion Inhibitor/Iron Control | Alcohols, C14-15, ethoxylated | 68951-67-7 | 5 | 0.00008891 | 153.913 | |
Methanol | 67-56-1 | 35 | 0.000622356 | 1077.39 | ||||
Coconut oil acid diethanolamine | 68603-42-9 | 5 | 0.00008891 | 153.913 | ||||
Fatty acids, tall oil | 61790-12-3 | 5 | 0.00008891 | 153.913 | ||||
2-Ethylhexanol | 104-76-7 | 10 | 0.000177816 | 307.825 | ||||
2-Propyn-1-ol | 107-19-7 | 5 | 0.00008891 | 153.913 | ||||
Acetic acid | 64-19-7 | 65 | 0.0011558 | 2000.87 | ||||
Olefin | Proprietary | 5 | 0.00008891 | 153.913 | ||||
Other Chemical(s) | Listed Above | See Trade Name(s) List | 2-Ethylhexanol | 104-76-7 | 10 | 0.000177816 | 307.825 | |
Oleic Acid Diethanolamide | 93-83-4 | 2 | 0.00194921 | 3374.37 | ||||
Methanol | 67-56-1 | 35 | 0.000622356 | 1077.39 | ||||
Didecyl dimethyl Ammonium Chloride | 7173-51-5 | 3 | 0.000881918 | 1526.73 | ||||
Ammonium Chloride | 12125-02-9 | 2 | 0.00194921 | 3374.37 | ||||
Water | 7732-18-5 | 60 | 0.0584764 | 101231 | ||||
2-Propyn-1-ol | 107-19-7 | 5 | 0.00008891 | 153.913 | ||||
Alcohols, C14-15, ethoxylated | 68951-67-7 | 5 | 0.00008891 | 153.913 | ||||
Water | 7732-18-5 | 98.5 | 0.013433 | 23254.5 | ||||
Alcohols, C12-16, Ethoxylated | 68551-12-2 | 2 | 0.00194921 | 3374.37 | ||||
Water | 7732-18-5 | 74 | 0.021754 | 37659.3 | ||||
Olefin | Proprietary | 5 | 0.00008891 | 153.913 | ||||
Fatty acids, tall oil | 61790-12-3 | 5 | 0.00008891 | 153.913 | ||||
Coconut oil acid diethanolamine | 68603-42-9 | 5 | 0.00008891 | 153.913 | ||||
Quaternary Ammonium chloride | 68424-85-1 | 3 | 0.000881918 | 1526.73 |
For data sources see[4]
Stimulation Date | Chemical Agent | Chemical Agent Concentration (%) | Fracking Fluid Volume | Mass of Proppant Used (lb) | Fracking Company | Comments |
---|---|---|---|---|---|---|
2018-07-27 | H2O | 28 | 7358 Bbl | 229580 | STINGRAY PRESSURE PUMPING LLC | STAGE 61 OF 61…SEE IMAGES FOR STAGES 2-60 |
2018-06-09 | H2O | 28 | 7522 Bbl | 169480 | STINGRAY PRESSURE PUMPING LLC | STAGE 1 OF 61 |
For data sources see[5]
Period | Operator Name | Gas Quantity (mcf) | Oil Quantity (bbl) | Production Days |
---|---|---|---|---|
2018 | GULFPORT ENERGY CORPORATION | 357682 | 0 | 20 |
2019 | GULFPORT ENERGY CORPORATION | 1891684 | 0 | 90 |
Period | Operator Name | Waste Type | Quantity (bbl) | Production Days |
---|---|---|---|---|
2018 | GULFPORT ENERGY CORPORATION | Brine | 5149 | 20 |
2019 | GULFPORT ENERGY CORPORATION | Brine | 18046 | 90 |
Inspection ID | Inspection Date | Inspection Type | Inspection Result | Inspection Comments |
---|---|---|---|---|
-1066608933 | 2018-1-22 0:00: | CT | No Violations | 1.00 |
-1107789453 | 2018-8-20 0:00: | DD | No Violations | 0.50 |
-1819674620 | 2018-9-17 0:00: | CT | No Violations | 0.20 |
-34592128 | 2020-5-21 0:00: | PL | No Violations | 0.30 |
-686319644 | 2019-3-7 0:00:0 | PW | No Violations | 0.40 |
-753467083 | 2018-11-14 0:00 | PL | No Violations | 0.50 |
0686319644 | 2019-03-07 | Production Wells | No Violations | Status check inspection found (4) wells present on the pad. The said well is equipped with (2) primary master valves along with a production tree that is tied into a main sales line. The lower well head assembly consists of a lower A and upper B section with 2 diameter riser pipes attached to both well head section service ports for the purpose of annular pressure monitoring. The 2 diameter riser pipes are equipped with valves and gauges with the A section gauge reads 200 pounds pressure and the B section gauge reads 300 pounds pressure, the 5.5 casing pressure is 4,800 pounds and the production flow line pressure downstream of the well head choke is 2,200 pounds. The company does have flow back iron and a choke manifold tied into the B section well head, the company field production supervisor Justin Hogue reported they have been bleeding the annular pressure down two times a week and not letting it build up over 1,200 pounds pressure. They B section is being blead down into a gas buster open top 500 barrel tank. 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. |
0753467083 | 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 rig moved off the said well (#1) after drilling out the completion plugs and setting the 2.875 production tubing at a set depth of 10,757. The said well identified as the # 2-A has been stimulated and has (2) primary master valves installed and is awaiting the completion drill out process. No production tubing is slated to be set in the well. No production tank battery has been set on location as of this day. |
0880422419 | 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 400 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. |
1066608933 | 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. |
1107789453 | 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 6800 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 400 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. |
1110439756 | 2017-10-18 | Casing String Witnessed | No Violations | Patterson Rig 583 had reach total depth in the 24-inch diameter open hole section of the well bore. The 18.625-inch diameter casing string was ran to a depth of 571 feet. Stingray Cementing Services was on site to perform a cement job on the casing. Stingray ran 950 sacks of Class A cement with cement returns to surface successful. Inspector Bill Stolarik was also on site to witness the casing installation. Please see his report for further details. |
1505398286 | 2017-09-14 | Casing String Witnessed | No Violations | On site inspection to witness the conductor casing cement job with Butchs Rat Hole rig on the well along with Stingray Cement Service. The rig has drilled a 36 diameter well bore to a measured depth of 110 from ground level elevation. The rig then proceeded to run 110 of 26 diameter .375 wall casing. Stingray Cement Service cemented the casing using a 92 barrel cement mix consisting of 430 sacks of class A cement. The cement was displaced with 59 barrels of fresh water with cement returns witnessed to surface inside the tin horn cellar. |
1508333009 | 2017-10-18 | Casing String Witnessed | No Violations | On site inspection to witness the surface casing cement job with Patterson Drilling rig 583-Wyoming Casing Service and Stingray Cement Service. The rig has drilled a 24 diameter surface borehole to a measured depth of 571 off of a 26 drilling rig Kelly bushing heigth. The target coal seam came in at 525 to 534. Upon reaching total depth the rig loaded the borehole with fresh water before pulling the drill string with circulation established to surface at this point. The drill string was then pulled out of the hole and the 18.625 casing inserted to a depth of 571 with a float collar and casing shoe ran along with 5 centralizers and a cement basket. Stingray Cement Service cemented the casing by first pumping 25 barrels of 6% gel spacer followed by a 200 barrel absolute volume cement mix consisting of 950 sacks of class A cement with .3% calcium and .25 pound per sack loss circulation material and 5.26 gallons of water per sack, the cement yield was 1.18 and weight per gallon was 15.6 with the weight verified by weight of scale. Cement returns were witnessed to surface at 85 barrels into displacement with a total of 163 barrels of fresh water displacement. The final displacement pressure was 300 psi and the casing was pressure tested to 924 psi upon the landing of the cement plug. The casing floats held and the company will run a borehole deviation survey before proceeding. |
1819674620 | 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. |
880422419 | 2018-9-17 0:00: | CT | No Violations | 1.00 |
For data sources see[10]