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37-005-30989

Well Details

Well ID: 37-005-30989
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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 590637
License Status: Active
Spud Date: 2012-03-10
Permit Date: 2012-01-23
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: No
Latitude: 40.717064
Longitude: -79.475683

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

Well History

Date Event
2011-06-05 Perforation
2012-01-23 New Permit Application
2012-01-26 Performed Spud Operation
2012-04-03 Drilling Completion
2012-05-29 Perforation
2012-05-29 Performed Stage 1 of Stimulation
2012-05-29 Performed Stage 2 of Stimulation
2012-05-29 Performed Stage 3 of Stimulation
2012-05-30 Perforation
2012-05-30 Performed Stage 4 of Stimulation
2012-05-30 Performed Stage 5 of Stimulation
2012-05-30 Performed Stage 6 of Stimulation
2012-05-31 Perforation
2012-05-31 Performed Stage 7 of Stimulation
2012-05-31 Performed Stage 8 of Stimulation
2012-06-03 Perforation
2012-06-03 Performed Stage 10 of Stimulation
2012-06-03 Performed Stage 11 of Stimulation
2012-06-03 Performed Stage 9 of Stimulation
2012-06-04 Perforation
2012-06-04 Performed Stage 12 of Stimulation
2012-06-05 Perforation
2012-06-05 Performed Stage 13 of Stimulation
2012-06-05 Performed Stage 14 of Stimulation
2012-06-05 Performed Stage 15 of Stimulation
2012-06-05 Performed Stage 16 of Stimulation
2012-06-06 Perforation
2017-03-29 Deviated
2017-06-06 Performed Stage 17 of Stimulation

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 2012-06-06 2012-06-06 6,876 5,515,188

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 SP Breaker Halliburton Energy Services Oxidizing Breaker Sodium persulfate 7775-27-1 100.00 0.00075000
Hydrochloric Acid Halliburton Energy Services Corrosion Inhibitor Propargyl alcohol 107-19-7 10.00 0.00006000
Hydrochloric acid 7647-01-0 28.00 0.03
Methanol 67-56-1 60.00 0.00037000
Hydrochloric Acid Halliburton Energy Services 15 HCl Acid
GBW-30 BREAKER Halliburton Energy Services Enzyme Breaker Hemicellulase enzyme 9012-54-8 15.00 0.00
WG-36 GELLING AGENT Halliburton Energy Services Gelling Agent Naphtha, petroleum, hydrotreated heavy 64742-48-9 0.00 0.00
Guar gum 9000-30-0 100.00 0.01
LP-65 Halliburton Energy Services Scale Inhibitor Ammonium chloride 12125-02-9 10.00 0.00255000
BE-9 Biocide Halliburton Energy Services Biocide Tri-n-butyl tetradecyl phosphonium chloride 81741-28-8 10.00 0.00402000
BA-40L Halliburton Energy Services Buffer Carbonic acid, dipotassium salt 584-08-7 60.00 0.00846000
FR-66 Friction Reducer Halliburton Energy Services Friction Reducer Distillates, petroleum, hydrotreated light 64742-47-8 30.00 0.02

For data sources see[5]

Stimulation Data

Stimulation Date Phase Number Chemical Agent Volume (gal) Treating Pressure (psi) Breakdown Pressure (psi)
2012-05-29 1 SAND 975,311 7,207 0
2012-05-29 2 SAND 975,311 7,151 9,274
2012-05-29 3 SAND 975,311 6,808 9,543
2012-05-30 4 SAND 975,311 6,456 8,913
2012-05-30 5 SAND 975,311 6,372 8,840
2012-05-30 6 SAND 975,311 8,225 6,293
2012-05-31 7 SAND 975,311 7,919 5,975
2012-05-31 8 SAND 975,311 0 7,348
2012-06-03 9 SAND 975,311 7,718 5,890
2012-06-03 10 SAND 975,311 0 0
2012-06-03 11 SAND 975,311 7,956 7,718
2012-06-04 12 SAND 975,311 8,006 8,391
2012-06-05 13 SAND 975,311 7,298 5,668
2012-06-05 14 SAND 975,311 7,719 6,656
2012-06-05 15 SAND 975,311 8,391 6,948
2012-06-05 16 SAND 975,311 5,668 6,506
2017-06-06 17 SAND 975,311 6,305 6,305

For data sources see[6]

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 261,363.00 115 0.00 0 0.00 0
2013 EQT PROD CO 496,868.00 365 0.00 0 0.00 0
2014 EQT PROD CO 541,862.00 365 0.00 0 0.00 0
2015 EQT PROD CO 473,115.00 363 0.00 0 0.00 0
2016 EQT PROD CO 274,530.00 365 0.00 0 0.00 0
2017 EQT PROD CO 235,211.00 365 0.00 0 0.00 0
2018 EQT PROD CO 207,315.00 360 0.00 0 0.00 0
2019 EQT PROD CO 185,418.00 361 0.00 0 0.00 0

For data sources see[7]

Waste Data

Period Operator Waste Type Quantity Disposal Method Waste Facility ID
2012 EQT PROD CO Produced Fluid 431.00 Bbl INJECTION DISPOSAL WELL 34-155-21447
2012 EQT PROD CO Produced Fluid 1,570.00 Bbl INJECTION DISPOSAL WELL 34-083-24137
2012 EQT PROD CO Produced Fluid 6,123.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Produced Fluid 762.00 Bbl INJECTION DISPOSAL WELL 34-121-23995
2012 EQT PROD CO Drilling Fluid Waste 901.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Produced Fluid 93.00 Bbl INJECTION DISPOSAL WELL 34-151-21198
2012 EQT PROD CO Fracing Fluid Waste 5,390.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Produced Fluid 432.00 Bbl INJECTION DISPOSAL WELL 34-155-23795
2012 EQT PROD CO Produced Fluid 1,008.00 Bbl INJECTION DISPOSAL WELL 34-155-21438
2012 EQT PROD CO Produced Fluid 308.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE 525-1
2012 EQT PROD CO Produced Fluid 661.00 Bbl INJECTION DISPOSAL WELL 34-007-24355
2013 EQT PROD CO Produced Fluid 8,093.00 Bbl REUSE OTHER THAN ROAD SPREADING
2013 EQT PROD CO Produced Fluid 31.00 Bbl INJECTION DISPOSAL WELL 34-007-24355
2013 EQT PROD CO Produced Fluid 120.00 Bbl INJECTION DISPOSAL WELL 34-083-24137
2014 EQT PROD CO Produced Fluid 102.00 Bbl INJECTION DISPOSAL WELL 34-155-21438
2014 EQT PROD CO Produced Fluid 501.00 Bbl INJECTION DISPOSAL WELL 34-007-21847
2014 EQT PROD CO Produced Fluid 3,314.00 Bbl REUSE OTHER THAN ROAD SPREADING
2014 EQT PROD CO Produced Fluid 107.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123
2015 EQT PROD CO Produced Fluid 25.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NW011
2015 EQT PROD CO Produced Fluid 316.00 Bbl INJECTION DISPOSAL WELL 34-007-21847
2015 EQT PROD CO Produced Fluid 3,415.00 Bbl REUSE OTHER THAN ROAD SPREADING
2015 EQT PROD CO Produced Fluid 59.00 Bbl INJECTION DISPOSAL WELL 34-059-24202
2016 EQT PROD CO Produced Fluid 847.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW005
2016 EQT PROD CO Produced Fluid 435.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NW011
2016 EQT PROD CO Produced Fluid 130.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2016 EQT PROD CO Produced Fluid 1,301.00 Bbl REUSE OTHER THAN ROAD SPREADING
2017 EQT PROD CO Other Oil & Gas Wastes 23.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO Produced Fluid 210.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2017 EQT PROD CO 110.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2017 EQT PROD CO Produced Fluid 819.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO 819.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO Produced Fluid 880.00 Bbl REUSE (AT WELL PAD)
2017 EQT PROD CO 330.00 Bbl REUSE (AT WELL PAD)
2018 EQT PROD CO Produced Fluid 674.17 Bbl REUSE (AT WELL PAD)
2018 EQT PROD CO Produced Fluid 145.94 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW005
2018 EQT PROD CO Produced Fluid 457.35 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2018 EQT PROD CO Produced Fluid 387.34 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2018 EQT PROD CO Produced Fluid 111.67 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW009
2019 EQT PROD CO Other Oil & Gas Wastes 65.00 Bbl REUSE (AT WELL PAD)
2019 EQT PROD CO Produced Fluid 550.30 Bbl REUSE (AT WELL PAD)
2019 EQT PROD CO Produced Fluid 23.45 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW010

For data sources see[8]

Inspection Data

Inspections Performed

Inspection ID Inspection Category Inspection Date Inspection Type Inspection Result Inspection Comments
2042062 Primary Facility 2012-02-08 Routine/Complete Inspection No Violations Noted not drilled
2049228 Primary Facility 2012-02-16 Routine/Complete Inspection No Violations Noted not drilled
2051619 Primary Facility 2012-03-14 Drilling/Alteration No Violations Noted Near casing point of intermediate casing
2056777 Primary Facility 2012-04-04 Routine/Complete Inspection No Violations Noted TD @ 11,354'
2070694 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.
2086496 Primary Facility 2012-07-19 Routine/Complete Inspection No Violations Noted Fraced
2093406 Primary Facility 2012-08-17 Complaint Inspection No Violations Noted Drilling complete on 4 wells. Production equipment being installed.
2098448 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.
2114009 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.
2122668 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.
2164295 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.
2208895 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.
2243528 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.
2413138 Primary Facility 2015-10-06 Routine/Complete Inspection No Violations Noted 4 wells on pad. Tag and e&s ok.
2441166 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.
2559090 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.
2617228 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.
2673155 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.
2841427 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. Corrosion was getting to be noticeable within the cellar. Flow could be heard. The cellar was not filled in and little water was on bottom. 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.

For data sources see[9]

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. ↑ "Completion Reports - Stimulations". Pennsylvania Department of Conservation and Natural Resources. 2020-03-02. Retrieved 2020-03-02. 
  7. ↑ "Oil and Gas Production Reports". Pennsylvania Department of Environmental Protection. 2019-03-31. Retrieved 2019-05-21. 
  8. ↑ "Oil and Gas Waste Reports". Pennsylvania Department of Environmental Protection. 2019-03-31. Retrieved 2019-05-21. 
  9. ↑ "Oil and Gas Compliance Report". Pennsylvania Department of Environmental Protection. 2019-05-20. Retrieved 2019-05-21. 
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