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37-005-30719

Well Details

Well ID: 37-005-30719
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Country: United States
State: Pennsylvania
County: Armstrong
Municipality: Kittanning Township
Operator Name: EQT PROD CO
Well Pad ID: 149601
Farm/Lease Name: WRIGHT 590662
License Status:
Spud Date:
Permit Date: 2010-10-13
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: No
Latitude: 40.722889
Longitude: -79.421056

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

Well History

Date Event
2010-10-13 New Permit Application
2011-08-18 Performed Spud Operation
2011-12-26 Drilling Completion
2012-02-04 Perforation
2013-06-13 DEVIATED

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 2012-03-03 2012-03-03 7,051 4,717,356

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 BA-40L Halliburton Energy Services Buffer Carbonic acid, dipotassium salt 584-08-7 0.00
BE-9 Biocide Halliburton Energy Services Biocide Tri-n-butyl tetradecyl phosphonium chloride 81741-28-8 0.00420000
SP Breaker Halliburton Energy Services Oxidizing Breaker Sodium persulfate 7775-27-1 0.00040000
FR-66 Friction Reducer Halliburton Energy Services Friction Reducer Distillates, petroleum, hydrotreated light 64742-47-8 0.03
Hydrochloric Acid Halliburton Energy Services Corrosion Inhibitor Methanol 67-56-1 0.00060000
Hydrochloric acid 7647-01-0 0.06
Propargyl alcohol 107-19-7 0.00010000
GBW-30 BREAKER Halliburton Energy Services Enzyme Breaker Hemicellulase enzyme 9012-54-8 0.00
WG-36 GELLING AGENT Halliburton Energy Services Gelling Agent Naphtha, petroleum, hydrotreated heavy 64742-48-9 0.00
Guar gum 9000-30-0 0.01
LP-65 Halliburton Energy Services Scale Inhibitor Ammonium chloride 12125-02-9 0.00260000
Hydrochloric Acid Halliburton Energy Services 15 HCl Acid

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
2010 EQT PROD CO 0.00 0 0.00 0 0.00 0
2011 EQT PROD CO 0.00 0 0.00 0 0.00 0
2012 EQT PROD CO 460,416.00 241 0.00 0 0.00 0
2013 EQT PROD CO 314,374.00 365 0.00 0 0.00 0
2014 EQT PROD CO 210,811.00 365 0.00 0 0.00 0
2015 EQT PROD CO 293,190.00 365 0.00 0 0.00 0
2016 EQT PROD CO 213,592.00 366 0.00 0 0.00 0
2017 EQT PROD CO 173,321.00 363 0.00 0 0.00 0
2018 EQT PROD CO 155,119.00 365 0.00 0 0.00 0
2019 EQT PROD CO 134,500.00 362 0.00 0 0.00 0

For data sources see[6]

Waste Data

Period Operator Waste Type Quantity Disposal Method Waste Facility ID
2011 EQT PROD CO Fracing Fluid Waste 780.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE 34-099-23127
2011 EQT PROD CO Drilling Fluid Waste 295.00 Bbl INJECTION DISPOSAL WELL 34-115-21896
2011 EQT PROD CO Fracing Fluid Waste 130.00 Bbl INJECTION DISPOSAL WELL 34-053-20968
2011 EQT PROD CO Fracing Fluid Waste 110.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR119
2011 EQT PROD CO Produced Fluid 177.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE 34-099-23127
2012 EQT PROD CO Produced Fluid 207.00 Bbl INJECTION DISPOSAL WELL 34-155-21447
2012 EQT PROD CO Produced Fluid 77.00 Bbl INJECTION DISPOSAL WELL 34-167-28462
2012 EQT PROD CO Produced Fluid 521.00 Bbl INJECTION DISPOSAL WELL 34-007-24355
2012 EQT PROD CO Produced Fluid 638.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE EPA ID: 748-163
2012 EQT PROD CO Produced Fluid 197.00 Bbl INJECTION DISPOSAL WELL 34-155-21438
2012 EQT PROD CO Produced Fluid 112.00 Bbl INJECTION DISPOSAL WELL 2D0855151
2012 EQT PROD CO Produced Fluid 464.00 Bbl INJECTION DISPOSAL WELL 34-083-24137
2012 EQT PROD CO Produced Fluid 3,031.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Produced Fluid 230.00 Bbl INJECTION DISPOSAL WELL 34-133-22523
2012 EQT PROD CO Fracing Fluid Waste 670.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Produced Fluid 2,113.00 Bbl INJECTION DISPOSAL WELL 34-167-28466
2012 EQT PROD CO Produced Fluid 159.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE 525-1
2013 EQT PROD CO Produced Fluid 5,703.00 Bbl REUSE OTHER THAN ROAD SPREADING
2013 EQT PROD CO Produced Fluid 90.00 Bbl INJECTION DISPOSAL WELL 34-059-24202
2013 EQT PROD CO Produced Fluid 80.00 Bbl INJECTION DISPOSAL WELL 34-059-24067
2013 EQT PROD CO Produced Fluid 110.00 Bbl INJECTION DISPOSAL WELL 34-119-28780
2014 EQT PROD CO Produced Fluid 79.00 Bbl INJECTION DISPOSAL WELL 34-155-23196
2014 EQT PROD CO Produced Fluid 5,682.00 Bbl REUSE OTHER THAN ROAD SPREADING
2014 EQT PROD CO Produced Fluid 110.00 Bbl INJECTION DISPOSAL WELL 34-155-23223
2014 EQT PROD CO Produced Fluid 519.00 Bbl INJECTION DISPOSAL WELL 34-007-21847
2014 EQT PROD CO Produced Fluid 191.00 Bbl INJECTION DISPOSAL WELL 34-155-21438
2015 EQT PROD CO Produced Fluid 100.00 Bbl INJECTION DISPOSAL WELL 34-155-23795
2015 EQT PROD CO Produced Fluid 101.00 Bbl INJECTION DISPOSAL WELL 34-059-24202
2015 EQT PROD CO Produced Fluid 200.00 Bbl INJECTION DISPOSAL WELL 34-007-24355
2015 EQT PROD CO Produced Fluid 403.00 Bbl INJECTION DISPOSAL WELL 34-007-21847
2015 EQT PROD CO Produced Fluid 188.00 Bbl INJECTION DISPOSAL WELL 34-007-23262
2015 EQT PROD CO Fracing Fluid Waste 115.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NW009
2015 EQT PROD CO Produced Fluid 6,439.00 Bbl REUSE OTHER THAN ROAD SPREADING
2016 EQT PROD CO Produced Fluid 2,699.00 Bbl REUSE OTHER THAN ROAD SPREADING
2016 EQT PROD CO Produced Fluid 659.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NW011
2016 EQT PROD CO Produced Fluid 15.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2016 EQT PROD CO Produced Fluid 915.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW005
2017 EQT PROD CO Produced Fluid 1,025.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO Produced Fluid 1,460.00 Bbl REUSE (AT WELL PAD)
2017 EQT PROD CO 1,072.00 Bbl REUSE (AT WELL PAD)
2017 EQT PROD CO 330.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2017 EQT PROD CO 1,025.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO Produced Fluid 330.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2018 EQT PROD CO Produced Fluid 371.46 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2018 EQT PROD CO Produced Fluid 741.10 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2018 EQT PROD CO Produced Fluid 47.52 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW005
2018 EQT PROD CO Produced Fluid 45.67 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW009
2018 EQT PROD CO Produced Fluid 445.01 Bbl REUSE (AT WELL PAD)
2019 EQT PROD CO Produced Fluid 36.83 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2019 EQT PROD CO Other Oil & Gas Wastes 26.00 Bbl REUSE (AT WELL PAD)
2019 EQT PROD CO Produced Fluid 593.38 Bbl REUSE (AT WELL PAD)
2019 EQT PROD CO Produced Fluid 84.31 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW009

For data sources see[7]

Inspection Data

Inspections Performed

Inspection ID Inspection Category Inspection Date Inspection Type Inspection Result Inspection Comments
1999117 Primary Facility 2011-08-23 Drilling/Alteration No Violations Noted 40' 26" conductor
2003366 Primary Facility 2011-09-13 Routine/Complete Inspection No Violations Noted Waiting to be drilled
2009626 Primary Facility 2011-04-10 Drilling/Alteration No Violations Noted tripping in w/ 83/4" bit
2009716 Primary Facility 2011-09-28 Drilling/Alteration No Violations Noted drlg 17 1'2" hole @ 480'
2012103 Primary Facility 2011-10-18 Routine/Complete Inspection No Violations Noted @ KOP 5700'
2022376 Primary Facility 2011-11-22 Routine/Complete Inspection No Violations Noted @ 5700'
2024003 Primary Facility 2011-12-02 Routine/Complete Inspection No Violations Noted @ KOP
2026249 Primary Facility 2011-12-08 Routine/Complete Inspection No Violations Noted @ KOP
2029415 Primary Facility 2011-12-21 Drilling/Alteration No Violations Noted Building curve @ 7790'
2032489 Primary Facility 2012-01-05 Routine/Complete Inspection No Violations Noted TD 10640'
2039447 Primary Facility 2012-02-02 Routine/Complete Inspection No Violations Noted Drilling had been completed. Flowback pit and well stimulation impoundment located onsite and both had more than the required two feet of lined freeboard. All erosion controls had been implemented and maintained as outlined in the E&S plan included as part of the ESCGP.
2047084 Primary Facility 2012-03-01 Routine/Complete Inspection No Violations Noted Id sign and e&s plan in place. Trucks hauling water. Haliburton onsite for frac.
2055369 Primary Facility 2012-03-30 Routine/Complete Inspection No Violations Noted Drilling had been completed. Flowback pit and well stimulation impoundment located onsite and both had more than the required two feet of lined freeboard. All erosion controls had been implemented and maintained as outlined in the E&S plan included as part of the ESCGP.
2069622 Primary Facility 2012-05-18 Routine/Complete Inspection No Violations Noted Drilling appeared to have been completed well was not fully equipped for production. Frac flowback and reshwater impoundments located onsite. Both impoundments liners appeared to be in sound condition and there was more than the required two feet of lined freeboard. Site and access road erosion controls had been properly maintained and there was no observed accelerated erosion or sedimenation in relation to the site or access road.
2098460 Primary Facility 2012-09-07 Routine/Complete Inspection No Violations Noted Drilling had been completed, wells appeared to be equipped for production. Brine tanks located onsite. Brine tanks within containment and appeared to be in sound condition. Frac flowback impoundment had been removed and was awaiting final grading work. Fresh water impoundment was being emptied to be prepped for liner removal and regrading. All site and access road erosion controls were functioning properly and there was no observed evidence of accelerated erosion or sedimentation.
2114038 Primary Facility 2012-10-25 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. Site was in the process of beginning final site restoration. There were approximately 40 roll-offs boxes sitting on the well pad. 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.
2164327 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.
2208899 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. Site had been regraded and the vegetation had begun to take hold. Once the vegetation has achieved 70% uniform coverage the sediment trap will be removed and those areas regraded as well.
2301634 Primary Facility 2014-09-02 Routine/Complete Inspection No Violations Noted
2307242 Primary Facility 2014-09-26 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. There was no observed accelerated erosion or sedimentation observed in relation to the site or access road. All cut and fill slopes had been stabilized with vegetation as had the area which had been utilized for below grade impoundment.
2348586 Primary Facility 2015-03-03 Routine/Complete Inspection 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.
2436585 Primary Facility 2015-12-29 Routine/Complete Inspection No Violations Noted Well is tagged-in production. Well casing-equipment-tank battery-dike-production units all OK.
2452050 Primary Facility 2016-02-23 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 vegetation had attained 70% uniform vegetative cover in the areas that had nopt been returned to agricultural use.
2560245 Primary Facility 2017-02-09 Routine/Complete Inspection No Violations Noted Well tagged-in production. Well head casing-production set equipment-tank battery-dike containment looked ok.
2615309 Primary Facility 2017-07-14 Routine/Complete Inspection No Violations Noted Well appeared to be equipped for production. Brine tank located onsite and it appeared to be in sound condition. There was no observed accelerated erosion or sedimentation in relation to the site or access road.
2658920 Primary Facility 2017-11-09 Routine/Complete Inspection No Violations Noted Multi-well pad. At time of inspection, well drilled and appears equipped for production.
2709193 Primary Facility 2018-03-23 Routine/Complete Inspection No Violations Noted This well is tagged and in production. The well head casing, piping, production set equipment, tank battery and containment dike look ok.
2820931 Primary Facility 2019-01-02 Routine/Complete Inspection No Violations Noted This well is tagged and in production with the annulus open. The well head casing, piping, production set equipment, containment dike and tank battery look ok.

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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