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37-005-30864

Well Details

Well ID: 37-005-30864
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Country: United States
State: Pennsylvania
County: Armstrong
Municipality: Kittanning Township
Operator Name: EQT PROD CO
Well Pad ID: 149393
Farm/Lease Name: SWANK 590636
License Status:
Spud Date:
Permit Date: 2011-08-24
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: Yes
Latitude: 40.716981
Longitude: -79.475697

For data sources see[1][2][3]

Well History

Date Event
2011-08-24 New Permit Application
2011-11-02 Performed Spud Operation

For data sources see[4]

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 2012-05-29 2012-05-29 6,902 6,209,616

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 HCl Halliburton 15 HCl Acid
GBW-30 Halliburton Enzyme Breaker Hemicellulase Enzyme 9012-54-8 15.0 None
HCl Halliburton Corrosion Inhibitor Propargyl Alcohol 107-19-7 10.0 0.00006000
Hydrochloric Acid 7647-01-0 28.0 0.03466
Methanol 67-56-1 60.0 0.00034
BA-40L Halliburton Buffer Potassium carbonate 584-08-7 60.0 0.00796
SP Breaker Halliburton Oxidizing Breaker Sodium Persulfate 7775-27-1 100.0 0.00105
BE-9 Halliburton Biocide Tributyl tetradecyl phosphonium chloride 81741-28-8 10.0 0.00435
FR-66 Halliburton Friction Reducer Hydrotreated light petroleum distillate 64742-47-8 30.0 0.03051
LP-65 Halliburton Scale Inhibitor Ammonium chloride 12125-02-9 10.0 0.00274
WG-36 Halliburton Gelling Agent Naptha, hydrotreated heavy 64742-48-9 None None
Guar Gum 9000-30-0 100.0 0.04018

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Gas Production Days Oil Quantity (bbl) Oil Production Days Water Quantity (bbl) Water Production Days
2011 EQT PROD CO 0.00 0 0.00 0 0.00 0
2012 EQT PROD CO 253,375.00 115 0.00 0 0.00 0
2013 EQT PROD CO 485,341.00 365 0.00 0 0.00 0
2014 EQT PROD CO 370,725.00 365 0.00 0 0.00 0
2015 EQT PROD CO 361,612.00 363 0.00 0 0.00 0
2016 EQT PROD CO 282,309.00 365 0.00 0 0.00 0
2017 EQT PROD CO 242,946.00 365 0.00 0 0.00 0
2018 EQT PROD CO 211,706.00 360 0.00 0 0.00 0
2019 EQT PROD CO 183,509.00 361 0.00 0 0.00 0

For data sources see[6]

Waste Data

Period Operator Waste Type Quantity Disposal Method Waste Facility ID
2012 EQT PROD CO Produced Fluid 160.00 Bbl INJECTION DISPOSAL WELL 34-155-21447
2012 EQT PROD CO Drilling Fluid Waste 769.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR119
2012 EQT PROD CO Produced Fluid 745.00 Bbl INJECTION DISPOSAL WELL 34-083-24137
2012 EQT PROD CO Produced Fluid 8,794.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Produced Fluid 301.00 Bbl INJECTION DISPOSAL WELL 34-121-23995
2012 EQT PROD CO Drilling Fluid Waste 1,138.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Fracing Fluid Waste 10,039.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Produced Fluid 683.00 Bbl INJECTION DISPOSAL WELL 34-155-21438
2012 EQT PROD CO Produced Fluid 100.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE 525-1
2012 EQT PROD CO Produced Fluid 26.00 Bbl INJECTION DISPOSAL WELL 34-007-24355
2013 EQT PROD CO Produced Fluid 8,340.00 Bbl REUSE OTHER THAN ROAD SPREADING
2013 EQT PROD CO Produced Fluid 80.00 Bbl INJECTION DISPOSAL WELL 34-013-20609
2013 EQT PROD CO Produced Fluid 405.00 Bbl INJECTION DISPOSAL WELL 34-155-21438
2013 EQT PROD CO Produced Fluid 95.00 Bbl INJECTION DISPOSAL WELL 34-059-24202
2013 EQT PROD CO Produced Fluid 109.00 Bbl INJECTION DISPOSAL WELL 34-119-28780
2014 EQT PROD CO Produced Fluid 717.00 Bbl INJECTION DISPOSAL WELL 34-007-21847
2014 EQT PROD CO Produced Fluid 4,891.00 Bbl REUSE OTHER THAN ROAD SPREADING
2014 EQT PROD CO Produced Fluid 108.00 Bbl INJECTION DISPOSAL WELL 34-155-23223
2015 EQT PROD CO Produced Fluid 75.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NW011
2015 EQT PROD CO Produced Fluid 113.00 Bbl INJECTION DISPOSAL WELL 34-157-25511
2015 EQT PROD CO Produced Fluid 179.00 Bbl INJECTION DISPOSAL WELL 34-007-21847
2015 EQT PROD CO Produced Fluid 100.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123SW001
2015 EQT PROD CO Produced Fluid 213.00 Bbl INJECTION DISPOSAL WELL 34-007-24355
2015 EQT PROD CO Produced Fluid 127.00 Bbl INJECTION DISPOSAL WELL 34-007-2-3097
2015 EQT PROD CO Produced Fluid 41.00 Bbl INJECTION DISPOSAL WELL 34-059-24202
2015 EQT PROD CO Produced Fluid 5,462.00 Bbl REUSE OTHER THAN ROAD SPREADING
2016 EQT PROD CO Produced Fluid 859.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NW011
2016 EQT PROD CO Other Oil & Gas Wastes 51.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW005
2016 EQT PROD CO Produced Fluid 1,048.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW005
2016 EQT PROD CO Produced Fluid 1,743.00 Bbl REUSE OTHER THAN ROAD SPREADING
2017 EQT PROD CO Other Oil & Gas Wastes 45.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO Produced Fluid 565.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2017 EQT PROD CO 566.00 Bbl REUSE (AT WELL PAD)
2017 EQT PROD CO Produced Fluid 1,031.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO 691.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO Produced Fluid 1,226.00 Bbl REUSE (AT WELL PAD)
2017 EQT PROD CO 350.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2018 EQT PROD CO Produced Fluid 596.03 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2018 EQT PROD CO Produced Fluid 690.15 Bbl REUSE (AT WELL PAD)
2018 EQT PROD CO Produced Fluid 149.34 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW005
2018 EQT PROD CO Produced Fluid 521.66 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2018 EQT PROD CO Produced Fluid 113.76 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW009
2019 EQT PROD CO Produced Fluid 258.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW019
2019 EQT PROD CO Other Oil & Gas Wastes 65.00 Bbl REUSE (AT WELL PAD)
2019 EQT PROD CO Produced Fluid 849.07 Bbl REUSE (AT WELL PAD)
2019 EQT PROD CO Produced Fluid 22.61 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW010

For data sources see[7]

Inspection Data

Inspections Performed

Inspection ID Inspection Category Inspection Date Inspection Type Inspection Result Inspection Comments
2013643 Primary Facility 2011-10-25 Drilling/Alteration No Violations Noted @ 40'
2013659 Primary Facility 2011-10-26 Routine/Complete Inspection No Violations Noted Site construction is still ongoing and the well had been spudded. Erosion controls had been implemented as outlined in the E&S plan contained within ESX10-005-0006.
2015289 Primary Facility 2011-10-31 Incident- Response to Accident or Event Violation(s) Noted Site construction was still underway on the well pad. Conductor pipe had been set for the wells on the pad. During construction activities, prior to lining the drill pits and impoundment onsite, the construction crews pumped out snow melt and precipitation to the sediment traps located on the western side of the well pad. Contact with EQT representative Brian Welsh and Trumbull representatie onsite found that this water was not tested in accordance with PA Code 25 Chapter 78.60 for pH or TDS. In addition this discharge of water toward the sediment trap entered a field drain and resulted in a direct discharge of this water to an UNT of Horney Camp Run.
2022321 Primary Facility 2011-11-22 Drilling/Alteration No Violations Noted @ 3310' tripping in hole
2023967 Primary Facility 2011-12-02 Routine/Complete Inspection No Violations Noted Plugged back to KOP 6080'
2025309 Primary Facility 2011-11-09 Compliance Evaluation No Violations Noted Site construction is still ongoing at the time of the inspection. Erosion controls had been implemented as outlined in the E&S plan contained within ESX10-005-0006. Drill and frac flowback pits were in the process of being lined. Met onsite with EQT representative Brian Welsh to review the location of a field drain located outside of the LOD for ESX10-005-0006 as a result of the transport of the discharge of precipitation related to the 10/31/11 inspection. Site review found that the field drain appears to be located approximately 50 feet downslope of the two sediment traps to the west side of the well pad. If the site E&S plan is followed properly and the site is temporarily stabilized with seed, mulch and subsequent vegetation and the sediment trap is properly maintained this should result in effectively minimizing accelerated erosion and sedimentation.
2036183 Primary Facility 2012-01-23 Routine/Complete Inspection No Violations Noted Site construction completed. Well had been spudded, drilling was not ongoing at the time of the inspection. Drill pit and well stimulation impoundments located onsite and they had more than the required two feet of lined freeboard.
2042052 Primary Facility 2012-02-08 Drilling/Alteration No Violations Noted @ 6524'
2049238 Primary Facility 2012-02-16 Drilling/Alteration No Violations Noted @ 8802'
2070690 Primary Facility 2012-05-23 Routine/Complete Inspection No Violations Noted Drilling had been completed at the time of the inspection. Site was in the process of being set up for well stimulation. Drill pit, flowback impoundment and freshwater impoundment were located onsite and all had more than the required two feet of lined freeboard. All well stimulation equipment onsite was located on containment. All erosion controls had been properly maintained and there was no evidence of accelerated erosion or sedimentation in relation to the access road or well-site.
2086485 Primary Facility 2012-07-19 Routine/Complete Inspection No Violations Noted Fraced
2093404 Primary Facility 2012-08-17 Complaint Inspection No Violations Noted Drilling complete on 4 wells. Production equipment being installed.
2098450 Primary Facility 2012-09-07 Routine/Complete Inspection No Violations Noted Drilling had been completed at the time of the inspection. Wells were in the process of being equipped for production. Brine tanks were observed onsite within containment. Brine tanks appeared to be in sound condition. Drilling pit located onsite and it contained fluids and drill cuttings. Drill pit had more than the required two feet of lined freeboard. Fresh-water impoundment located onsite and it had more than the required two feet of lined freeboard. Frac-flowback impoundment located onsite and it had been emptied except for a few small puddles of fluid. This impoundment was in the process of being prepped to remove the liner and regrade the impoundment. Twelve Baker tanks were observed onsite and both they and the well head apparatus were located on containment. All erosion controls were continuing to function properly and no evidence was observed of accelerated erosion or sedimentation.
2114015 Primary Facility 2012-10-25 Routine/Complete Inspection No Violations Noted Drill pit and frac flowback impoundment had been regraded and final site grading work was underway. Drill cuttings had been solidified and transported to the Evergreen landfill in Indiana County. Frac flowback sludge and frac flowback impoundment liner was contained in lined roll-off boxes onsite. There were four empty Veolia roll-offs still located onsite and there were approximately eight to ten sealed Waste Management roll-off boxes located onsite. Currently the storage of the roll-off boxes containing sludge from the frac flowback pit and the liner from the frac-flowback pit are not on secondary containment. This does not meet the requirements that all hydraulic fracturing additives and flowback be on containment as outlined in the Oil & Gas Act 3218.2(c). On future well pads all roll-off boxes which contain frac flowback sludge and frac flowback impoundment liner should be stored on containment to minimize the possibility of a discharge of liquids from these tanks onto the ground.
2122672 Primary Facility 2012-12-10 Routine/Complete Inspection No Violations Noted Drilling had been completed at the time of the inspection. Wells were in the process of being equipped for production. Brine tanks were observed onsite within containment. Brine tanks appeared to be in sound condition. Fresh-water impoundment located onsite and it had more than two feet of lined freeboard. All implemented erosion controls had been properly maintained. There was no observed accelerated erosion or sedimentation in relation to the access road or well-site.
2164296 Primary Facility 2013-05-03 Routine/Complete Inspection No Violations Noted Drilling had been completed at the time of the inspection. Wells appeared to be equipped for production. Brine tanks located onsite within containment. Site had been regraded and the vegetation had begun to take hold. Contact with the operator confirmed that once the vegetation has achieved 70% uniform coverage the sediment traps would be removed and those areas regraded as well.
2208893 Primary Facility 2013-10-01 Routine/Complete Inspection No Violations Noted Drilling had been completed at the time of the inspection. Wells appeared to be equipped for production. Brine tanks located onsite within containment. Brine tanks appeared to be in sound condition. Site had been effectively restored, sediment traps removed and the vegetative cover met the 70% uniform coverage criteria.
2211294 Primary Facility 2013-07-03 Administrative/File Review Viol(s) Noted & Immediately Corrected CACP enf ID 303201; there is no paper inspection report.
2243532 Primary Facility 2014-02-07 Routine/Complete Inspection No Violations Noted Well appeared to be equipped for production. Brine tanks located onsite within containment and they appeared to be in sound condition.
2413136 Primary Facility 2015-10-06 Routine/Complete Inspection No Violations Noted 4 wells on pad. Tag and e&s ok.
2441168 Primary Facility 2016-01-14 Site Restoration No Violations Noted Well appeared ot be equipped for production. Brine tank located onsite and it appeared to be in sound condition. There was no observed accelerated erosion or sedimenation in relation to the site or access road. Site had been properly restored and the associated ESCGP had been terminated.
2559096 Primary Facility 2017-02-02 Routine/Complete Inspection No Violations Noted Well tagged-in production. Well head casing-production set equipment-tank battery-dike containment looked ok.
2617224 Primary Facility 2017-07-20 Routine/Complete Inspection No Violations Noted Well appeared to be equipped for production. Brine tank located onsite within containment. Both the tank and containment appeared to be in sound condition. There was no observed accelerated erosion or sedimentation in relation to the site or access road.
2673153 Primary Facility 2017-12-14 Routine/Partial Inspection No Violations Noted At time of inspection, well drilled and appears equipped for production. Remaining three wells on the well pad are also drilled and appear equipped for production.
2841413 Primary Facility 2019-02-15 Routine/Partial Inspection No Violations Noted At the time of inspection, well was producing. The well integrity appeared to be in good condition, with no leaks or spills. Flow could be heard. The cellar was filled with water. No bubbles were observed. The well was properly labeled and the Emergency Response sign was posted at the site entrance. The well was being injected with a corrosion and scale inhibitor. Lift equipment was also installed on the well. There were 4 tanks contained within a lined steel dike. 4 line heaters were also being use. A hydrate inhibitor was being injected here.

Violations Commited

Inspection ID Violation ID Violation Date Date Resolved Violation Code Violation Type Violation Comments
2015289 623570 10/31/2011 2011-10-31 78.60B - Tophole water discharged improperly Administrative
2211294 679924 07/03/2013 2013-07-03 212CMPLRPT - Failure to submit completion report within 30 days of completion of well Administrative

Penalties Applied

Violation ID Penalty ID Penalty Code Penalty Status Penalty Date Enforcement Date Penalty Amount Amount Collected
623570 276605 NOV - Notice of Violation Comply/Closed 2011-11-09
623570 290131 CACP - Consent Assessment of Civil Penalty Comply/Closed 2012-10-25 2012-10-25 $19,250.00 $19,250.00
679924 303201 CACP - Consent Assessment of Civil Penalty Comply/Closed 2013-09-18 2013-09-18 $7,500.00 $7,500.00

For data sources see[8]

References

  1. ↑ "Permits Issued Detail Report". Pennsylvania Department of Environmental Protection. 2019-05-20. Retrieved 2019-05-21. 
  2. ↑ "Spud Data Report". Pennsylvania Department of Environmental Protection. 2019-04-30. Retrieved 2019-05-16. 
  3. ↑ "Oil and Gas Well Pad Report". Pennsylvania Department of Environmental Protection. 2019-05-20. Retrieved 2019-05-21. 
  4. ↑ "Compiled from multiple data sources - see Pennsylvania Oil and Gas Data Sources". 2020-02-27. Retrieved 2020-02-27. 
  5. ↑ "FracFocus Fracking Chemicals Database". 2019-04-02. Retrieved 2019-06-19. 
  6. ↑ "Oil and Gas Production Reports". Pennsylvania Department of Environmental Protection. 2019-03-31. Retrieved 2019-05-21. 
  7. ↑ "Oil and Gas Waste Reports". Pennsylvania Department of Environmental Protection. 2019-03-31. Retrieved 2019-05-21. 
  8. ↑ "Oil and Gas Compliance Report". Pennsylvania Department of Environmental Protection. 2019-05-20. Retrieved 2019-05-21. 
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