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37-115-21546

Well Details

Well ID: 37-115-21546
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Country: United States
State: Pennsylvania
County: Susquehanna
Municipality: Dimock Township
Operator Name: CABOT OIL & GAS CORP
Well Pad ID: 148684
Farm/Lease Name: KING D 6
License Status: Active
Spud Date: 2015-03-18
Permit Date: 2013-12-03
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: No
Latitude: 41.716564
Longitude: -75.961764

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

Well History

Date Event
2013-12-03 New Permit Application
2014-11-24 Permit Renewal Application
2015-03-18 Performed Spud Operation
2015-05-28 Drilling Completion
2016-05-17 Perforation
2016-06-08 Perforation
2016-06-08 Performed Stage 1 of Stimulation
2016-06-08 Performed Stage 2 of Stimulation
2016-06-09 Perforation
2016-06-11 Performed Stage 3 of Stimulation
2016-06-12 Perforation
2016-06-15 Perforation
2016-06-15 Performed Stage 4 of Stimulation
2016-06-16 Perforation
2016-06-16 Performed Stage 5 of Stimulation
2016-06-17 Perforation
2016-06-17 Performed Stage 6 of Stimulation
2016-06-18 Perforation
2016-06-18 Performed Stage 7 of Stimulation
2016-06-19 Performed Stage 8 of Stimulation
2016-06-20 Perforation
2016-06-21 Perforation
2016-06-21 Performed Stage 9 of Stimulation
2016-06-22 Perforation
2016-06-22 Performed Stage 10 of Stimulation
2016-06-23 Performed Stage 11 of Stimulation
2016-06-24 Perforation
2016-06-25 Perforation
2016-06-25 Performed Stage 12 of Stimulation
2016-06-26 Perforation
2016-06-26 Performed Stage 13 of Stimulation
2016-06-27 Perforation
2016-06-27 Performed Stage 14 of Stimulation
2016-06-28 Performed Stage 15 of Stimulation
2016-06-29 Perforation
2016-06-30 Perforation
2016-06-30 Performed Stage 16 of Stimulation
2016-07-01 Perforation
2016-07-01 Performed Stage 17 of Stimulation
2016-07-03 Perforation
2016-07-03 Performed Stage 18 of Stimulation
2016-07-04 Perforation
2016-07-04 Performed Stage 19 of Stimulation
2016-07-05 Performed Stage 20 of Stimulation
2016-07-06 Perforation
2016-07-06 Performed Stage 21 of Stimulation
2016-07-07 Performed Stage 22 of Stimulation
2016-07-09 Perforation
2016-07-09 Performed Stage 23 of Stimulation
2016-07-10 Perforation
2016-07-13 Perforation
2016-07-13 Performed Stage 24 of Stimulation
2016-07-14 Perforation
2016-07-14 Performed Stage 25 of Stimulation
2016-07-15 Perforation
2016-07-15 Performed Stage 26 of Stimulation
2016-07-16 Performed Stage 27 of Stimulation
2017-01-20 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 2016-06-07 2016-07-15 6,890 10,116,500 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 CI-14 Baker Hughes Corrosion Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0004276 406
GBW-5 Baker Hughes Breaker MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0032584 3094
FRW-18 Baker Hughes Friction Reducer MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0320438 30427.3
Sand, White, 40/70 Baker Hughes Proppant MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 10.1858 9,671,940.0
Tetrasodium EDTA 64-02-8 0.1 0.00005990 56.8637
Petroleum Distillates 64742-47-8 30 0.0179559 17059.1
Poly (acrylamide-co-acrylic acid) partial sodium salt 62649-23-4 30 0.0096081 9128.18
Calcium Chloride 10043-52-4 5 0.0007838 744.645
Glutaraldehyde 111-30-8 30 0.0066782 6344.63
Ethylene Glycol 107-21-1 45 0.0070541 6701.8
Sorbitan monooleate ethoxylate 9005-65-5 5 0.0029927 2843.18
Quaternary Ammonium Compound 68424-85-1 5 0.001113 1057.44
Formaldehyde 50-00-0 1 0.00000430 4.06
Polyoxyalkylenes 68951-67-7 30 0.0001282 121.8
Olefin 64743-02-8 5 0.00002140 20.3
Modified Thiourea Polymer 68527-49-1 7 0.00002990 28.42
Ammonium Persulphate 7727-54-0 100 0.0032567 3094
Sorbitan, mono-(9Z)-9octadecenoate 1338-43-8 5 0.0029927 2843.18
Sorbitan Monooleate 1338-43-8 0.5 0.0001601 152.136
Fatty Acids 61790-12-3 10 0.00004270 40.6
Hydrotreated Light Distillate 64742-47-8 30 0.0096081 9128.18
Hydrochloric Acid 7647-01-0 15 0.0405431 38518.1
Ammonium Chloride 12125-02-9 3 0.0009608 912.818
Acetic Acid 64-19-7 0.1 0.00005990 56.8637
Didecyl Dimethyl Ammonium Chloride 7173-51-5 10 0.0022261 2114.88
2-Propenoic, Polymer with Sodium Phosphinate, Sodium Salt 71050-62-9 20 0.0031352 2978.58
Oxyalkylated alcohol 78330-21-9 5 0.0029927 2843.18
Crystalline Silica (Quartz) 14808-60-7 100 10.7581 10,220,700.0
Polyoxythylene Sorbitan Monooleate 9005-65-6 0.5 0.0001601 152.136
Oleamide DEA 93-83-4 2 0.0006405 608.546
Acrylamide Modified Polymer 38193-60-1 60 0.0359119 34118.2
Alcohols, C12-16, ethoxylated 68551-12-2 2 0.0006405 608.546
Sodium Chloride 7647-14-5 5 0.0047508 4513.48
Methanol 67-56-1 100 0.0004273 406
Ethanol 64-17-5 5 0.001113 1057.44
Acetic Acid, Potassium Salt 127-08-2 1 0.0005985 568.637
Potassium Chloride 7447-40-7 1 0.0001568 148.929
Citric Acid 77-92-9 60 0.0011146 1058.97
Propargyl Alcohol 107-19-7 5 0.00002140 20.3
HCl, 10.1 - 15% Baker Hughes Acidizing MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.270401 256760
Water Operator Carrier Water 7732-18-5 100 88.7834 84,349,000.0
Alpha 1427 Baker Hughes Biocide MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0222723 21148.8
Ferrotrol 300L (Totes) Baker Hughes Iron Control MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0018587 1764.95
MaxPerm 30 Baker Hughes Friction Reducer MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0598848 56863.7
Sand, White, 100 mesh Baker Hughes Proppant MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.577955 548798
Other Chemical(s) Baker Hughes See Trade Name(s) List Water 7732-18-5 85 0.30057 285557
Scaletrol 720, 330 gl tote Baker Hughes Scale Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0156841 14892.9

For data sources see[5]

Stimulation Data

Stimulation Date Phase Number Chemical Agent Volume (gal) Treating Pressure (psi) Breakdown Pressure (psi)
2016-06-08 1 SAND, WHITE 831 7,856 7,256
2016-06-08 2 SAND, WHITE 831 7,751 6,824
2016-06-11 3 SAND, WHITE 831 7,149 7,059
2016-06-15 4 SAND, WHITE 831 8,235 7,067
2016-06-16 5 SAND, WHITE 831 8,159 6,945
2016-06-17 6 SAND, WHITE 831 8,264 7,964
2016-06-18 7 SAND, WHITE 831 7,676 6,431
2016-06-19 8 SAND, WHITE 831 8,064 6,190
2016-06-21 9 SAND, WHITE 831 8,125 6,338
2016-06-22 10 SAND, WHITE 831 7,790 5,889
2016-06-23 11 SAND, WHITE 831 8,430 6,718
2016-06-25 12 SAND, WHITE 831 8,149 6,537
2016-06-26 13 SAND, WHITE 831 8,191 6,915
2016-06-27 14 SAND, WHITE 831 8,176 6,725
2016-06-28 15 SAND, WHITE 831 8,282 7,195
2016-06-30 16 SAND, WHITE 831 7,976 7,505
2016-07-01 17 SAND, WHITE 831 7,691 5,823
2016-07-03 18 SAND, WHITE 831 7,873 6,395
2016-07-04 19 SAND, WHITE 831 7,984 6,924
2016-07-05 20 SAND, WHITE 831 7,832 6,598
2016-07-06 21 SAND, WHITE 831 7,678 7,827
2016-07-07 22 SAND, WHITE 831 6,676 5,242
2016-07-09 23 SAND, WHITE 831 7,113 5,806
2016-07-13 24 SAND, WHITE 831 6,844 6,112
2016-07-14 25 SAND, WHITE 831 7,107 6,683
2016-07-15 26 SAND, WHITE 831 7,052 7,542
2016-07-16 27 SAND, WHITE 831 6,569 5,631

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
2015 CABOT OIL & GAS CORP 0.00 0 0.00 0 0.00 0
2016 CABOT OIL & GAS CORP 3,442,440.25 138 0.00 0 0.00 0
2017 CABOT OIL & GAS CORP 4,806,531.52 364 0.00 0 0.00 0
2018 CABOT OIL & GAS CORP 2,229,151.00 365 0.00 0 0.00 0
2019 CABOT OIL & GAS CORP 1,437,724.00 362 0.00 0 0.00 0

For data sources see[7]

Waste Data

Period Operator Waste Type Quantity Disposal Method Waste Facility ID
2015 CABOT OIL & GAS CORP Drilling Fluid Waste 116.67 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NC018
2015 CABOT OIL & GAS CORP Drilling Fluid Waste 20.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR119
2015 CABOT OIL & GAS CORP Drill Cuttings 1,395.29 Tons LANDFILL 101247
2016 CABOT OIL & GAS CORP Synthetic Liner Materials 19.60 Tons LANDFILL 101247
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 9,561.50 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Produced Fluid 5,426.12 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 1,296.95 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2016 CABOT OIL & GAS CORP Produced Fluid 29.45 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2016 CABOT OIL & GAS CORP Waste Water Treatment Sludge 64.13 Tons LANDFILL 100933
2016 CABOT OIL & GAS CORP Other Oil & Gas Wastes 0.07 Tons RESIDUAL WASTE PROCESSING FACILITY 301333
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 196.84 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE002
2017 CABOT OIL & GAS CORP Produced Fluid 465.70 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2017 CABOT OIL & GAS CORP Produced Fluid 1,100.62 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2018 CABOT OIL & GAS CORP Produced Fluid 467.75 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2018 CABOT OIL & GAS CORP Produced Fluid 267.49 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2019 CABOT OIL & GAS CORP Produced Fluid 382.34 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002

For data sources see[8]

Inspection Data

Inspections Performed

Inspection ID Inspection Category Inspection Date Inspection Type Inspection Result Inspection Comments
2353935 Primary Facility 2015-03-23 Routine/Complete Inspection No Violations Noted
2356516 Primary Facility 2015-03-31 Drilling/Alteration No Violations Noted
2358898 Primary Facility 2015-04-07 Drilling/Alteration No Violations Noted
2364612 Primary Facility 2015-03-11 Routine/Partial Inspection No Violations Noted
2364765 Primary Facility 2015-03-11 Preoperation Inspection No Violations Noted The Department was on site at the King, D Pad1 to conduct a Preoperational Inspection. Scott Kuchta (DEP-Water Quality Specialist) and I met with Marc Talarico and Shane Christian. The E&S Inspection Log indicated that Paul Koval conducted a weekly inspection on 3/4/15. During the inspection, the site was covered in snow. The Department walked the perimeter of the well site. At the time of the inspection, there were no obvious E&S issues. It appeared as though the perimeter BMP’s (although snow covered) have been installed per the E&S Plan.
2370565 Primary Facility 2015-05-18 Drilling/Alteration No Violations Noted
2481751 Primary Facility 2016-04-28 Routine/Complete Inspection No Violations Noted
2483984 Primary Facility 2016-05-12 Follow-up Inspection No Violations Noted At time of inspection, arrived on site at 11:50 a.m. to conduct a follow-up inspection for an inspection conducted by Ken Kennedy on 4/28/16 pertaining to gas detected at the vent tanks on the side of the pad. The wells are not producing, the 2H & 3H are shut in and the 4H, 6H, 8H, 9H, & 10H are drilled to TD but haven’t been stimulated yet. I met with Dan Smales (Production Forman) and Bob Birtch (Lead Operator) for Cabot Oil & Gas. Dan unlocked the valves and open and closed the valves so each annulus could be checked separately for gas with an Altair 5X gas detector. There was no gas detected at the vent tanks on the 4H, 6H, & 8H. Gas was detected at the vent tanks for the 2H, 3H, 9H, & 10H.

I left the site at 13:10 p.m. Results of gas shows are on page two.

2485208 Primary Facility 2016-05-17 Drilling/Alteration No Violations Noted At time of inspection, arrived on site at 11:45 a.m., Kudd Energy Services was on site to pressure test the production casing, drill out the toe and run the first perforation. I met with company man John Crawford, they were pulling the coiled tubing out of the 4H. The 9H and 10H were tested at 500psi low and 12500psi high, the 4H, 6H, and 8H were tested at 500psi low and 9500psi high. I took a walk around the location and spotted a small stain off the containment. I showed John where it was and he said he would get someone to clean it up.

I left the site at 12:25 p.m.

2492474 Primary Facility 2016-06-13 Follow-up Inspection No Violations Noted At time of inspection, arrived on site at 9:45 a.m., met with company man Larry Fulmer, the Department was contacted about the activity at the King D pad and the tank pad below the well pad. The wells 4H, 6H, 8H, 9H, and 10H were being stimulated, the water was being hauled to tanks on the lower pad and was being pumped threw a 12" plastic line that was bored under the road. The tanks were on containment and the containment appeared to be in good condition. Stages completed, (4H-5 out of 30), (6H-3 out of 27), (8H-4 out of 25), (9H-6 out of 34), (10H-5 out of 26). I took a walk around the location and everything looked OK.

I left the site at 10:50 a.m.

2533439 Primary Facility 2016-10-24 Routine/Complete Inspection No Violations Noted
2828095 Primary Facility 2019-01-10 Routine/Complete Inspection No Violations Noted I performed a RTNC inspection of the King Pad. The pad was snow covered and the weather was about 27 degrees.

The access road was short and solid. The pad surface was partially vegetated and was stone in others. The pad surface was all solid and stable during the inspection.

The cut and fill slopes were stable and solid appearing, and some vegetation was visible through the snow.

There were no erosional issues apparent on site at the time of the inspection.

The wells were properly labeled.

There were no violations noted.

2842414 Primary Facility 2019-02-01 Routine/Complete Inspection No Violations Noted I arrived onsite at 1440 to conduct a site restoration inspection. The weather was sunny and frigid at approximately 12 degrees F with relatively calm winds and clear skies.

The short access road and pad surface was plowed and covered in a packed layer of snow. The pad contains seven (7) producing wells, seven corresponding GPUs, and one produced water tank.

Unfortunately, site stabilization was unable to be assessed due to snow cover. An additional inspection will need to be performed to ascertain whether the site meets restoration requirements.

No violations were noted. Please feel free to contact me with any questions.

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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