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37-005-30863

Well Details

Well ID: 37-005-30863
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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 590635
License Status: Active
Spud Date: 2011-11-28
Permit Date: 2011-08-09
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: Yes
Latitude: 40.717019
Longitude: -79.475689

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

Well History

Date Event
2011-08-09 New Permit Application
2011-11-02 Performed Spud Operation
2012-03-08 Drilling Completion
2012-07-19 Perforation
2012-07-19 Performed Stage 1 of Stimulation
2012-07-19 Performed Stage 2 of Stimulation
2012-07-19 Performed Stage 3 of Stimulation
2012-07-20 Perforation
2012-07-20 Performed Stage 4 of Stimulation
2012-07-20 Performed Stage 5 of Stimulation
2012-07-20 Performed Stage 6 of Stimulation
2012-07-21 Perforation
2012-07-21 Performed Stage 10 of Stimulation
2012-07-21 Performed Stage 11 of Stimulation
2012-07-21 Performed Stage 12 of Stimulation
2012-07-21 Performed Stage 7 of Stimulation
2012-07-21 Performed Stage 8 of Stimulation
2012-07-21 Performed Stage 9 of Stimulation
2012-07-22 Perforation
2012-07-22 Performed Stage 13 of Stimulation
2012-07-22 Performed Stage 14 of Stimulation
2012-07-22 Performed Stage 15 of Stimulation
2012-07-23 Perforation
2012-07-23 Performed Stage 16 of Stimulation
2012-07-23 Performed Stage 17 of Stimulation
2012-07-23 Performed Stage 18 of Stimulation
2012-07-23 Performed Stage 19 of Stimulation
2012-07-23 Performed Stage 20 of Stimulation
2012-07-24 Perforation
2012-07-24 Performed Stage 21 of Stimulation
2012-07-24 Performed Stage 22 of Stimulation
2017-03-28 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 2012-07-24 2012-07-24 6,865 5,206,656

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 60.00 0.01
Hydrochloric Acid Halliburton Energy Services 15 HCl Acid
LP-65 Halliburton Energy Services Scale Inhibitor Ammonium chloride 12125-02-9 10.00 0.00263000
GBW-30 BREAKER Halliburton Energy Services Enzyme Breaker Hemicellulase enzyme 9012-54-8 15.00 0.00
BE-9 Biocide Halliburton Energy Services Biocide Tri-n-butyl tetradecyl phosphonium chloride 81741-28-8 10.00 0.00404000
Hydrochloric Acid Halliburton Energy Services Corrosion Inhibitor Hydrochloric acid 7647-01-0 28.00 0.04
Methanol 67-56-1 60.00 0.00047000
Propargyl alcohol 107-19-7 10.00 0.00008000
FR-66 Friction Reducer Halliburton Energy Services Friction Reducer Distillates, petroleum, hydrotreated light 64742-47-8 30.00 0.03
SP Breaker Halliburton Energy Services Oxidizing Breaker Sodium persulfate 7775-27-1 100.00 0.00038000
LGC-36 Halliburton Energy Services Gelling Agent Guar gum 9000-30-0 30.00 0.00484000
Naphtha, petroleum, hydrotreated heavy 64742-48-9 30.00 0.00484000

For data sources see[5]

Stimulation Data

Stimulation Date Phase Number Chemical Agent Volume (gal) Treating Pressure (psi) Breakdown Pressure (psi)
2012-07-19 1 SAND 3,123,960 7,759 6,011
2012-07-19 2 SAND 3,123,960 8,244 5,677
2012-07-19 3 SAND 3,123,960 8,060 5,257
2012-07-20 4 SAND 3,123,960 8,240 5,799
2012-07-20 5 SAND 3,123,960 8,032 5,654
2012-07-20 6 SAND 3,123,960 8,225 5,461
2012-07-21 7 SAND 3,123,960 8,117 5,828
2012-07-21 8 SAND 3,123,960 8,080 5,538
2012-07-21 9 SAND 3,123,960 8,238 5,852
2012-07-21 10 SAND 3,123,960 7,842 5,969
2012-07-21 11 SAND 3,123,960 7,592 5,283
2012-07-21 12 SAND 3,123,960 7,563 5,455
2012-07-22 13 SAND 3,123,960 7,727 5,308
2012-07-22 14 SAND 3,123,960 7,707 6,294
2012-07-22 15 SAND 3,123,960 8,474 5,751
2012-07-23 16 SAND 3,123,960 8,215 5,966
2012-07-23 17 SAND 3,123,960 7,995 7,100
2012-07-23 18 SAND 3,123,960 7,255 5,693
2012-07-23 19 SAND 3,123,960 7,314 5,749
2012-07-23 20 SAND 3,123,960 7,458 6,838
2012-07-24 21 SAND 3,123,960 7,435 6,710
2012-07-24 22 SAND 3,123,960 7,785 5,361

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 299,984.00 119 0.00 0 0.00 0
2013 EQT PROD CO 458,982.00 365 0.00 0 0.00 0
2014 EQT PROD CO 310,594.00 365 0.00 0 0.00 0
2015 EQT PROD CO 342,868.00 363 0.00 0 0.00 0
2016 EQT PROD CO 222,983.00 365 0.00 0 0.00 0
2017 EQT PROD CO 188,047.00 365 0.00 0 0.00 0
2018 EQT PROD CO 134,883.00 351 0.00 0 0.00 0
2019 EQT PROD CO 156,583.00 362 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 1,151.00 Bbl INJECTION DISPOSAL WELL 34-155-21447
2012 EQT PROD CO Produced Fluid 1,164.00 Bbl INJECTION DISPOSAL WELL 34-083-24137
2012 EQT PROD CO Produced Fluid 8,348.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Drilling Fluid Waste 12,740.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Fracing Fluid Waste 71,880.00 Bbl REUSE OTHER THAN ROAD SPREADING
2012 EQT PROD CO Produced Fluid 203.00 Bbl INJECTION DISPOSAL WELL 34-151-21179
2012 EQT PROD CO Produced Fluid 197.00 Bbl INJECTION DISPOSAL WELL 34-155-23795
2012 EQT PROD CO Produced Fluid 932.00 Bbl INJECTION DISPOSAL WELL 34-155-21438
2012 EQT PROD CO Produced Fluid 271.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE 525-1
2012 EQT PROD CO Produced Fluid 95.00 Bbl INJECTION DISPOSAL WELL 34-007-24355
2013 EQT PROD CO Produced Fluid 9,260.00 Bbl REUSE OTHER THAN ROAD SPREADING
2013 EQT PROD CO Produced Fluid 51.00 Bbl INJECTION DISPOSAL WELL 34-007-24355
2013 EQT PROD CO Produced Fluid 903.00 Bbl INJECTION DISPOSAL WELL 34-155-21438
2013 EQT PROD CO Produced Fluid 94.00 Bbl INJECTION DISPOSAL WELL 34-099-20974
2014 EQT PROD CO Produced Fluid 33.00 Bbl INJECTION DISPOSAL WELL 34-155-21438
2014 EQT PROD CO Produced Fluid 100.00 Bbl INJECTION DISPOSAL WELL 34-007-21847
2014 EQT PROD CO Produced Fluid 3,288.00 Bbl REUSE OTHER THAN ROAD SPREADING
2015 EQT PROD CO Produced Fluid 13.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NW011
2015 EQT PROD CO Produced Fluid 212.00 Bbl INJECTION DISPOSAL WELL 34-007-23262
2015 EQT PROD CO Produced Fluid 2,793.00 Bbl REUSE OTHER THAN ROAD SPREADING
2016 EQT PROD CO Produced Fluid 445.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW005
2016 EQT PROD CO Produced Fluid 412.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NW011
2016 EQT PROD CO Produced Fluid 844.00 Bbl REUSE OTHER THAN ROAD SPREADING
2017 EQT PROD CO Other Oil & Gas Wastes 17.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO Produced Fluid 110.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2017 EQT PROD CO 110.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2017 EQT PROD CO Produced Fluid 296.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO Other Oil & Gas Wastes 110.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2017 EQT PROD CO 203.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2017 EQT PROD CO Produced Fluid 800.00 Bbl REUSE (AT WELL PAD)
2017 EQT PROD CO 470.00 Bbl REUSE (AT WELL PAD)
2018 EQT PROD CO Produced Fluid 296.33 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW011
2018 EQT PROD CO Produced Fluid 441.00 Bbl REUSE (AT WELL PAD)
2018 EQT PROD CO Produced Fluid 109.66 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NW005
2018 EQT PROD CO Produced Fluid 271.36 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123SW005
2018 EQT PROD CO Produced Fluid 62.77 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 867.37 Bbl REUSE (AT WELL PAD)
2019 EQT PROD CO Produced Fluid 19.67 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
2013639 Primary Facility 2011-10-25 Drilling/Alteration No Violations Noted @ 40'
2013658 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.
2022326 Primary Facility 2011-11-22 Drilling/Alteration No Violations Noted @ 40'
2023965 Primary Facility 2011-12-02 Drilling/Alteration No Violations Noted Installing Intermediate casing
2036184 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.
2049200 Primary Facility 2012-02-16 Routine/Complete Inspection No Violations Noted waiting for lateral to be drilled
2049219 Primary Facility 2012-02-29 Drilling/Alteration No Violations Noted @6800' turn & build
2070685 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.
2086469 Primary Facility 2012-07-19 Routine/Complete Inspection No Violations Noted Stimulating well
2093402 Primary Facility 2012-08-17 Complaint Inspection No Violations Noted Drilling complete on 4 wells. Production equipment being installed.
2098454 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.
2114017 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.
2122667 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.
2164287 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.
2208888 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.
2243530 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.
2413135 Primary Facility 2015-10-06 Routine/Complete Inspection No Violations Noted 4 wells on pad. Tag and e&s ok.
2441169 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.
2559093 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.
2617222 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.
2673151 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.
2841419 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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