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34-067-21115

Well Details

Well ID: 34-067-21115
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Country: United States
State: Ohio
County: Harrison
Municipality: Moorefield Township
Operator Name: GULFPORT APPALACHIA LLC
Well Pad ID: US-OH-000513
Farm/Lease Name: RYSER
License Status: Producing
License Date: 2012-10-25
Spud Date: 2013-01-03
Spud Drilling Contractor: PATTERSON DRILLING
Final Drill Date: 2013-06-19
Well Total Depth: 14500.00 ft
Configuration: Horizontal
Latitude: 40.210000
Longitude: -81.200000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2012-10-25 Proposed Formations:POINT PLEASANT, Issued Date:10/25/2012, Expired Date:10/25/2014 12:00:00 PM, Drilling unit acres:166.763, Proposed Well Type:OG, Proposed Well Class:EDPW
Correction to Well 2013-01-18 CORRECTION TO TARGET INFORMATION: FOOTAGE & X,Y COORDINATES. CHANGE IN UNIT SIZE TO 511.058 ACRES.
Reached Total Depth 2013-06-19
Completion Report Received 2014-02-06
Correction to Well 2014-03-27 CHANGE IN TARGET AND TAKE-POINT INFORMATION (FOOTAGES & COORDINATES) FROM AS DRILLED SURVEY PLAT. CHANGE IN TARGET ELEVATION AND UNIT SIZE INCREASED TO 1107.017 ACRES.
Construction Permit Expires 2014-10-25
Record Last Modified 2017-10-24

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2014-02-10 8321 14373 0
8321 14373 0
8321 14373 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 09/06/2013 09/12/2013 7932 8,783,490.0 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 ScaleClear 112 Weatherford Scale Inhibitor Polymer Based NA 100 0.00118 0
FR-403 Weatherford Friction Reducer Water 7732-18-5 60 0.05473 0
Distillates, Petroleum, Hydrotreated Light 64742-47-8 20 0.01824 0
Sodium Chloride 7647-14-5 20 0.01824 0
30/50 White Minerva/Cadiz Proppant Sand 14808-60-7 100 0 0
Fresh water Stingray Carrier Water 7732-18-5 100 83.1257 0
40/70 White Minerva/Cadiz Proppant Sand 14808-60-7 100 15.4269 0
OB-2 Stingray Encapsulated Breaker Ammonium Persulfate 7727-54-0 75 0.00299 0
Silica, Crystalline-Quartz 14808-60-7 10 0.0004 0
Cured acrylic resin NA 16 0.00064 0
FRS 51 Weatherford Non-Emulsifier Alcohols, C6-C12, ethoxylated 68439-45-2 15 0.00577 0
Methyl Alcohol 67-56-1 40 0.01538 0
N-dodecyl-2-pyrrolid one 2687-96-9 2.5 0.00096 0
Water 7732-18-5 42.5 0.01634 0
Clean Gel Stingray Guar Gel heavy aliphatic NA 35 0.01154 0
Solvent naphtha, (petroleum) 64742-96-7 65 0.02144 0
Hydrochloric Acid 10 -15% Stingray Acid Water 7732-18-5 85 0.278445 0
Hydrochloric Acid NA 15 0.04914 0
100 mesh Minerva/Cadiz Proppant Sand 14808-60-7 100 0.92301 0
Acid Inhibitor Stingray Corossion Inhibitor Water 7732-18-5 40 0.00037 0
Proprietary polycarboxylic acid mixture NA 60 0.00055 0
BioClear 5000 Weatherford Biocide Water 7732-18-5 95 0.02289 0
2,2-dibromo-3-nitril oprop ionam ide 10222-01-2 5 0.0012 0
Per Break Stingray Persulfate Breaker Ammonium Persulfate 7727-54-0 99 0.00396 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
2013-09-11 H2O 15 486482 Gal 1007497 STINGRAY PRESSURE PUMPING LLC STAGE 15

60 SHOTS

2013-09-12 H2O 15 400260 Gal 669471 STINGRAY PRESSURE PUMPING LLC STAGE 19

60 SHOTS

2013-09-08 H2O 15 340960 Gal 468700 STINGRAY PRESSURE PUMPING LLC STAGE 7

60 SHOTS

2013-09-09 H2O 15 545328 Gal 873500 STINGRAY PRESSURE PUMPING LLC STAGE 11

60 SHOTS

2013-09-09 H2O 15 473306 Gal 852033 STINGRAY PRESSURE PUMPING LLC STAGE 10

60 SHOTS

2013-09-12 H2O 15 8655 Bbl 795000 STINGRAY PRESSURE PUMPING LLC STAGE 20

60 SHOTS

2013-09-08 H2O 15 381856 Gal 584000 STINGRAY PRESSURE PUMPING LLC STAGE 8

60 SHOTS

2013-09-09 H2O 15 461177 Gal 805000 STINGRAY PRESSURE PUMPING LLC STAGE 9

60 SHOTS

2013-09-10 H2O 15 438190 Gal 563500 STINGRAY PRESSURE PUMPING LLC STAGE 12

60 SHOTS

2013-09-10 H2O 15 581112 Gal 804410 STINGRAY PRESSURE PUMPING LLC STAGE 13

60 SHOTS

2013-09-07 H2O 15 472290 Gal 635460 STINGRAY PRESSURE PUMPING LLC STAGE 1

60 SHOTS

2013-09-08 H2O 15 327482 Gal 487809 STINGRAY PRESSURE PUMPING LLC STAGE 5

60 SHOTS

2013-09-11 H2O 15 417535 Gal 716500 STINGRAY PRESSURE PUMPING LLC STAGE 17

60 SHOTS

2013-09-07 H2O 15 384825 Gal 654000 STINGRAY PRESSURE PUMPING LLC STAGE 4

60 SHOTS

2013-09-10 H2O 15 449807 Gal 734000 STINGRAY PRESSURE PUMPING LLC STAGE 14

60 SHOTS

2013-09-12 H2O 15 398294 Gal 808000 STINGRAY PRESSURE PUMPING LLC STAGE 18

60 SHOTS

2013-09-07 H2O 15 402104 Gal 744046 STINGRAY PRESSURE PUMPING LLC STAGE 2

60 SHOTS

2013-09-08 H2O 15 502610 Gal 896278 STINGRAY PRESSURE PUMPING LLC STAGE 6

60 SHOTS

2013-09-11 H2O 15 511098 Gal 1033630 STINGRAY PRESSURE PUMPING LLC STAGE 16

60 SHOTS

2013-09-07 H2O 15 243600 Gal 286460 STINGRAY PRESSURE PUMPING LLC STAGE 3

60 SHOTS

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2013 GULFPORT ENERGY CORPORATION 99965 18240 52
2014 GULFPORT ENERGY CORPORATION 343054 35277 350
2015 GULFPORT ENERGY CORPORATION 152830 17866 352
2016 GULFPORT ENERGY CORPORATION 103177 8928 364
2017 GULFPORT ENERGY CORPORATION 91453 5842 356
2018 GULFPORT ENERGY CORPORATION 71872 4904 358
2019 GULFPORT ENERGY CORPORATION 16510 1016 90

For data sources see[6] [7]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2013 GULFPORT ENERGY CORPORATION Brine 16568 52
2014 GULFPORT ENERGY CORPORATION Brine 15407 350
2015 GULFPORT ENERGY CORPORATION Brine 4447 352
2016 GULFPORT ENERGY CORPORATION Brine 2554 364
2017 GULFPORT ENERGY CORPORATION Brine 1979 356
2018 GULFPORT ENERGY CORPORATION Brine 1689 358
2019 GULFPORT ENERGY CORPORATION Brine 377 90

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1121213291 2017-8-22 0:00: PW No Violations 1.00
-1708451617 2020-3-6 0:00:0 PW No Violations 1.00
-2014360000 2019-12-10 0:00 PW No Violations 1.00
-55167913 2016-4-20 0:00: PW No Violations 1.50
-696583937 2013-12-10 0:00 PL No Violations 1.00
0055167913 2016-04-20 Production Wells No Violations On the day of my inspection following up on Compliance No. 1382920089 (issued for well causing pollution and contamination), I witnessed the affected spill areas have been properly accessed. During the conduction of my inspection, I noticed lush vegetation was established around the entire perimeter of the well location. The NOV can now be considered resolved.
0696583937 2013-12-10 Preliminary Restoration No Violations On the day of my inspection the site passed preliminary restoration according to 1509.072A.
1121213291 2017-08-22 Production Wells No Violations On the day of my inspection I found this pad to have four producing wells, twelve 400 barrel steel tanks, four gas production units and four sand seperators. Surface annulas has 150 psi and intermediate annulas has no pressure.
1126844244 2018-12-13 Production Wells No Violations On the day of my inspection I was accompanied by Deputy Chief Bob Worstall and Inspector John Fleming. This pad contains 4 properly labeled producing wellheads. Production equipment includes twelve 400 barrel steel tanks in their own polymer lined steel containment, one 50 barrel steel tank, four GPUs, four sand seperators, and a combustor. Surface annular pressure is 1200 and intermediate annular pressure is 0. Gauge should be checked to verify pressure. Production records are current in RBDMS.
1357317188 2012-01-04 Drill / Deepen / Reopen No Violations I am on site today to witness the running and cementing of the conductor casing. There is 105 ft of 26 inch casing in the well bore and the size of the hole is 32 inch. Petroset Cementing will cement casing with 300 sacks. The cement circulated up the to within 12 to 15 from the bottom of the Tin Horn. After pumping stopped the cement fell and will need to be topped off with 9 sack grout cement to surface.
1361565018 2013-02-22 Drill / Deepen / Reopen No Violations Express Drilling has drilled a 32 inch diameter hole to 120 ft. They are setting 26 inch diameter casing and Stingray Cementing Service is cementing the casing with 280 sks. During the installation of the casing a metal bracket was dropped down the hole and will need to be fished out before it can be cemented. I then traveled to witness another job. 3 hours later I returned to witness the cementing of this casing string. Circulated cement to surface.
1361814135 2013-02-25 Drill / Deepen / Reopen No Violations I arrived today to check on the rig status. I found that the Yost # 3 rig is over the well ready to begin drilling. I collected photos and forward them to Uniontown Office and advised that the protective cage over the Producing well was not in place. Later I received a call from Deputy Chief Claus and he advised me to contact Gulfport and explain the cage requirement. I then contacted Chad Shoffner and he said that the cage would be put up and from this point forward would be in place prior to rig move. While I was on location the cage arrived and is being installed.
1361980264 2013-02-27 Drill / Deepen / Reopen No Violations I am on site tonight to witness the running and the cementing of the 18-5/8inch diameter casing string. Yost Drilling rig # 3 is running 422 ft of casing and Stingray Cementing Service will cement the casing with 690 sks of class A @ 15.6 lb. The well size for this section was a 24 inch diameter hole total depth of 450 ft. During the installation of the casing they hit an obstruction and had to spend 2 to 3 hours to circulate it out. Then they cross threaded the next casing joint and spent 3 hours and also had problems with the collar on next joint of casing 2 more hours and had to remove it. I left at this point. Before I got home they called and said that the casing obstruction had been knocked out and that they would be cementing soon. Returned to witnessed cement circulate to surface. Just after the cement job started they had to shut down and replace the rubber hose from the pump truck to the casing head. Did not have enough steel on location and had to wait for it to arrive. Cement did circulate to surface with 30 bbls of good returns
1362527884 2013-03-05 Drill / Deepen / Reopen No Violations The cement job on the 10 3/4 inch diameter casing set 3/02/2012 had a problem. The well was a 17.5 inch hole to 1750 ft. Yost Drilling ran 1722 ft. of 10 3/4 inch diameter casing. They cemented the casing with 2000 sks of 15.6 cement. When they shut down to release the plug the well pressured up they could not displace the cement. I am on site today to do a remedial cement job. Yost Drilling has installed 1 1/4 inch diameter tubing to 312 ft on the back side to the 10 3/4 casing between the 18 5/8 inch diameter casing. Stingray Cement Service pumped 260 sks of class A cement with no Calcium Chloride added. A cement bond log was run prior to this cement job and it was determined the top of the cement was near the 300 ft range. Had good returns and cement remained at surface when the job was complete.
1382920089 2013-10-25 Production Wells Violations Noted I received a call at 9:15 am from All Associates and was advised that a spill had occurred on the Ryser pad around 3:30 am . Dave said that the 2-7/8 inch diameter tubing had parted while drilling out the plugs. There are 418 joints of tubing left in the well. The well was closed in to contain the flow. It blew out the top of the tubing over top of the 100ft derrick for 10 minutes before the well was closed. The fluid in the well bore was a mix of condensate and brine along with a slight amount of oil. It blew out of the tubing with 1000 PSI in the amount of 40 to 50 barrels. Part of the mixture was on containment and part was on the rock pad. The area off containment was 75 ft wide 150 ft long and 150ft wide at the fence line. It looked like a baseball diamond, narrow at the end near the pad and wide along the fence line. I arrived on site and met with Hal Miller and Brad Burwell. The area was then roped off and peat sorb applied to the contamination on the surface. I collected photos but did not collect fluid samples.
1461257627 2016-04-21 Production Wells No Violations The violation for pollution and contamination has been completed. The area has been restored and the production equipment moved back in place.

Violations Commited

Inspection ID Violation ID Violation Date Violation Code Violation Comments
1382920089 US-OH-111380 2013-11-05 Well operation causing pollution and contamination

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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