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37-115-21250

Well Details

Well ID: 37-115-21250
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Country: United States
State: Pennsylvania
County: Susquehanna
Municipality: Forest Lake Township
Operator Name: CABOT OIL & GAS CORP
Well Pad ID: 145128
Farm/Lease Name: GILLINGHAM M 2
License Status:
Spud Date:
Permit Date: 2013-04-25
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: No
Latitude: 41.844556
Longitude: -75.959611

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

Well History

Date Event
2013-04-25 New Permit Application
2013-05-24 Performed Spud Operation
2013-07-05 Drilling Completion
2013-08-10 Perforation
2013-08-27 Performed Stimulation
2014-03-13 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 2013-08-26 2013-09-03 6,235 5,496,620 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 Other Chemicals Sorbitan Monooleate Trade Secret 0 0.0031289 1649.11
Ethoxylated Alcohol Trade Secret 0 0.0012516 659.644
Water 7732-18-5 0 0.0545002 28724.3
Potassium Chloride 7447-40-7 0 0.00000780 4.1325
Hydrochloric Acid 7647-01-0 0 0.00000940 4.93
Polyacrylate Trade Secret 0 0.0031363 1653
Modified Thiorea Polymer 68527-49-1 0 0.00006550 34.51
Poly (acrylamide-co-acrylic acid) Trade Secret 0 0.0187737 9894.66
Salt Trade Secret 0 0.0031289 1649.11
Sodium Chloride 7647-14-5 0 0.00000470 2.4795
Formaldehyde 50-00-0 0 0.00000940 4.93
Alpha 1427 Baker Hughes Biocide Quaternary Ammonium Compound 68424-85-1 5 0.0012236 644.875
Ethanol 64-17-5 5 0.0012236 644.875
Didecyl Dimethyl Ammonium Chloride 7173-51-5 10 0.0024471 1289.75
Glutaraldehyde 111-30-8 30 0.0073413 3869.25
HCl, 10.1 - 15% Baker Hughes Acidizing Water 7732-18-5 85 0.530101 279389
Hydrochloric Acid 7647-01-0 15 0.0935472 49304
Sand, White, 40/70 Baker Hughes Proppant Crystalline Silica (Quartz) 14808-60-7 100 11.6543 6,142,400.0
FRW-18 Baker Hughes Friction Reducer Petroleum Distillates 64742-47-8 30 0.0187737 9894.66
Scaletrol 720 Baker Hughes Scale Inhibitor Calcium Chloride 10043-52-4 5 0.0007841 413.25
Ethylene Glycol 107-21-1 30 0.0047045 2479.5
Water Operator Carrier Water 7732-18-5 100 86.9553 45,829,800.0
Sand, White, 100 mesh Baker Hughes Proppant Crystalline Silica (Quartz) 14808-60-7 100 0.643962 339400
CI-14 Baker Hughes Corrosion Inhibitor Propargyl Alcohol 107-19-7 5 0.00004680 24.65
Fatty Acids Trade Secret 10 0.00009350 49.3
Methanol 67-56-1 100 0.0009354 493
Polyoxyalkylenes Trade Secret 30 0.0002806 147.9
Olefin Trade Secret 5 0.00004680 24.65
Ferrotrol 300L Baker Hughes Iron Control Citric Acid 77-92-9 60 0.0008134 428.695

For data sources see[5]

Stimulation Data

Stimulation Date Phase Number Chemical Agent Volume (gal) Treating Pressure (psi) Breakdown Pressure (psi)
2013-08-27 0 0 0

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
2013 CABOT OIL & GAS CORP 739,038.96 89 0.00 0 0.00 0
2014 CABOT OIL & GAS CORP 1,845,133.19 354 0.00 0 0.00 0
2015 CABOT OIL & GAS CORP 1,108,200.94 365 0.00 0 0.00 0
2016 CABOT OIL & GAS CORP 1,070,268.94 366 0.00 0 0.00 0
2017 CABOT OIL & GAS CORP 761,673.65 352 0.00 0 0.00 0
2018 CABOT OIL & GAS CORP 613,013.00 365 0.00 0 0.00 0
2019 CABOT OIL & GAS CORP 537,999.00 365 0.00 0 0.00 0

For data sources see[7]

Waste Data

Period Operator Waste Type Quantity Disposal Method Waste Facility ID
2013 CABOT OIL & GAS CORP Drilling Fluid Waste 235.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE002
2013 CABOT OIL & GAS CORP Drill Cuttings 875.26 Tons LANDFILL 101247
2013 CABOT OIL & GAS CORP Drilling Fluid Waste 35.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE001
2013 CABOT OIL & GAS CORP Fracing Fluid Waste 879.67 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE001
2013 CABOT OIL & GAS CORP Produced Fluid 12,970.96 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE002
2013 CABOT OIL & GAS CORP Drilling Fluid Waste 330.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NE002
2013 CABOT OIL & GAS CORP Drill Cuttings 473.39 Tons LANDFILL THR029
2013 CABOT OIL & GAS CORP Produced Fluid 1,908.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE001
2013 CABOT OIL & GAS CORP Fracing Fluid Waste 2,978.75 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE002
2014 CABOT OIL & GAS CORP Produced Fluid 4,035.78 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE002
2014 CABOT OIL & GAS CORP Produced Fluid 19.75 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE001
2015 CABOT OIL & GAS CORP Produced Fluid 775.65 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE002
2016 CABOT OIL & GAS CORP Produced Fluid 213.64 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2016 CABOT OIL & GAS CORP Produced Fluid 518.03 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE002
2016 CABOT OIL & GAS CORP Produced Fluid 135.44 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2017 CABOT OIL & GAS CORP Produced Fluid 53.21 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2017 CABOT OIL & GAS CORP Synthetic Liner Materials 1.05 Tons LANDFILL 101247
2017 CABOT OIL & GAS CORP Produced Fluid 433.94 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2017 CABOT OIL & GAS CORP Produced Fluid 14.02 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123
2018 CABOT OIL & GAS CORP Produced Fluid 13.87 Bbl REUSE (AT WELL PAD)
2018 CABOT OIL & GAS CORP Produced Fluid 274.17 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2018 CABOT OIL & GAS CORP Produced Fluid 172.00 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2019 CABOT OIL & GAS CORP Produced Fluid 383.47 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2019 CABOT OIL & GAS CORP Produced Fluid 12.77 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE004

For data sources see[8]

Inspection Data

Inspections Performed

Inspection ID Inspection Category Inspection Date Inspection Type Inspection Result Inspection Comments
2173924 Primary Facility 2013-05-29 Drilling/Alteration No Violations Noted Conductor set
2184758 Primary Facility 2013-05-17 Routine/Partial Inspection No Violations Noted pre-operations
2219047 Primary Facility 2013-07-09 Drilling/Alteration No Violations Noted Patterson 253 - currently at 1846'
2351212 Primary Facility 2015-03-04 Routine/Complete Inspection No Violations Noted The Department was on site to conduct a routine complete inspection of the Gillingham well pad.
2408440 Primary Facility 2015-09-21 Routine/Complete Inspection No Violations Noted
2505621 Primary Facility 2016-07-27 Routine/Complete Inspection No Violations Noted At time of inspection, arrived on site at 9:30a.m., the cellar was full of water with no bubbling noticed, the (13x9) vent pipe was open and venting into a tank, the (9x5) vent pipe was open and venting into a tank, there was 565psi on the production casing, I took a walk around the location and everything looked OK.

I left the site at 10:05a.m.

2544773 Primary Facility 2016-11-30 Routine/Complete Inspection No Violations Noted The Department was on site to conduct a routine complete inspection of the Gillingham well pad (ESX11-115-0200).

Well permits associated with this site are as follows: 115-20849 115-20850 115-20851 115-20852 115-21249 115-21250 115-21251 115-21252

The site was stable, with excellent growth throughout. There were still tiered filter sock BMPs still in place, starting to deteriorate. Due to the abundance of good perennial vegetation, it can be suggested to repair or remove the filter sock, at the Operator's discretion. There is a local quarry off the South side of the pad. Was raining very hard at time of inspection, however there appeared to be no runoff from the site affecting anything off the LOD.


There were no violations.

2604208 Primary Facility 2017-06-13 Routine/Complete Inspection No Violations Noted At time of inspection, arrived on site at 13:55p.m.

The cellar had water at the bottom with no bubbling noticed. The (13x9) annulus vent pipe was open and venting into a small plastic tank, the (9x5) annulus vent pipe was open and venting into a small plastic tank. There was 607psi on the production casing. I took a walk around the location and there were no obvious concerns noticed. I left the site at 14:30p.m.

2709583 Primary Facility 2018-03-20 Routine/Complete Inspection No Violations Noted At time of inspection.

The well was in production. There was ice 4' below grade in the cellar and was unable to check for gas. The (13x9) and (9x5) annuli vent pipes were connected together and going to the same tank. I took a walk around the location and there were no obvious concerns noticed. There were no violations noted.

2809468 Primary Facility 2018-12-03 Routine/Complete Inspection No Violations Noted At time of inspection.

The well was in production. The cellar was full of water and over flowing onto the well site and there was no bubbling noticed. There was no sheen noticed on the water and would suggest the cellar be emptied. The (13x9) and (9x5) annuli vent pipes were connected together and going to the same poly vent tank. There was gas detected at the poly vent tank with a MSA Altair 5X multi gas detector that was calibrated on 12/3/18. I took a walk around the location and there were no obvious concerns noticed. There were no violations noted.

2821375 Primary Facility 2019-01-02 Routine/Complete Inspection No Violations Noted I performed a RTNC inspection of the Gillingham Well Site and Tank Farm. The weather at the time of inspection was partly sunny and slightly above freezing.
    Due to ongoing wet conditions, the pad surface was wet, but not unstable.  The well pad access road was a bit muddy but was not to the point of allowing mud to leave the site.  
   The cut slope was very rocky but stable.  There was not an abundance of vegetation on the cut slope due to the extremely rocky conditions.  The fill slope had a heavy crop of vegetation occupying it.  The slope was stable and solid.  
    The tank pad was solid and stable as well, with cut and fill slopes having no erosional issues at the time of inspection.
    The well site signage was clearly visible and the E&S log was up to date, having been updated today.
    The wells on site were clearly labeled.
    The tank pad surface was stable and overgrown with encroaching vegetation.  The fill slope of the tank pad was well vegetated and stable.  There were no erosion

For data sources see[9]

References