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37-115-21545

Well Details

Well ID: 37-115-21545
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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 4
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: 41.716606
Longitude: -75.961772

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

Well History

Date Event
2013-12-03 New Permit Application
2014-11-21 Permit Renewal Application
2015-03-18 Performed Spud Operation
2015-05-04 New Permit Application
2015-06-05 Drilling Completion
2016-05-18 Perforation
2016-06-07 Performed Stage 1 of Stimulation
2016-06-10 Perforation
2016-06-11 Perforation
2016-06-11 Performed Stage 2 of Stimulation
2016-06-12 Perforation
2016-06-12 Performed Stage 3 of Stimulation
2016-06-13 Perforation
2016-06-13 Performed Stage 4 of Stimulation
2016-06-13 Performed Stage 5 of Stimulation
2016-06-14 Perforation
2016-06-15 Perforation
2016-06-15 Performed Stage 6 of Stimulation
2016-06-16 Performed Stage 7 of Stimulation
2016-06-17 Perforation
2016-06-18 Perforation
2016-06-18 Performed Stage 8 of Stimulation
2016-06-19 Perforation
2016-06-19 Performed Stage 9 of Stimulation
2016-06-20 Perforation
2016-06-20 Performed Stage 10 of Stimulation
2016-06-22 Perforation
2016-06-22 Performed Stage 11 of Stimulation
2016-06-23 Perforation
2016-06-23 Performed Stage 12 of Stimulation
2016-06-24 Perforation
2016-06-24 Performed Stage 13 of Stimulation
2016-06-25 Performed Stage 14 of Stimulation
2016-06-26 Perforation
2016-06-26 Performed Stage 15 of Stimulation
2016-06-27 Perforation
2016-06-28 Perforation
2016-06-28 Performed Stage 16 of Stimulation
2016-06-29 Performed Stage 17 of Stimulation
2016-06-30 Perforation
2016-06-30 Performed Stage 18 of Stimulation
2016-07-01 Perforation
2016-07-02 Perforation
2016-07-02 Performed Stage 19 of Stimulation
2016-07-03 Performed Stage 20 of Stimulation
2016-07-04 Perforation
2016-07-04 Performed Stage 21 of Stimulation
2016-07-05 Perforation
2016-07-06 Perforation
2016-07-06 Performed Stage 22 of Stimulation
2016-07-07 Perforation
2016-07-07 Performed Stage 23 of Stimulation
2016-07-09 Perforation
2016-07-09 Performed Stage 24 of Stimulation
2016-07-10 Performed Stage 25 of Stimulation
2016-07-11 Perforation
2016-07-11 Performed Stage 26 of Stimulation
2016-07-12 Perforation
2016-07-13 Performed Stage 27 of Stimulation
2016-07-14 Perforation
2016-07-14 Performed Stage 28 of Stimulation
2016-07-15 Perforation
2016-07-15 Performed Stage 29 of Stimulation
2016-07-16 Perforation
2016-07-16 Performed Stage 30 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 2016-06-06 2016-07-15 6,801 11,448,900 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 Alpha 1427 Baker Hughes Biocide MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0219949 23581.3
FRW-18 Baker Hughes Friction Reducer MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0418451 44863
Water Operator Carrier Water 7732-18-5 100 88.9952 95,458,300.0
Other Chemical(s) Baker Hughes See Trade Name(s) List Water 7732-18-5 85 0.298018 319661
Scaletrol 720, 330 gl tote Baker Hughes Scale Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0154088 16520.1
Sand, White, 100 mesh Baker Hughes Proppant MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.566661 607529
MaxPerm 30 Baker Hughes Friction Reducer MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0497424 53329.8
CI-14 Baker Hughes Corrosion Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.000426 456.75
GBW-5 Baker Hughes Breaker MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0029362 3148
Sand, White, 40/70 Baker Hughes Proppant MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 9.9918 10,712,500.0
Ferrotrol 300L (Totes) Baker Hughes Iron Control MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0018618 1996.07
Acetic Acid, Potassium Salt 127-08-2 1 0.0004972 533.298
Fatty Acids 61790-12-3 10 0.00004260 45.675
Ethanol 64-17-5 5 0.0010992 1179.06
Crystalline Silica (Quartz) 14808-60-7 100 10.5536 11,320,000.0
Sorbitan monooleate ethoxylate 9005-65-5 5 0.002486 2666.49
Poly (acrylamide-co-acrylic acid) partial sodium salt 62649-23-4 30 0.0125477 13458.9
Petroleum Distillates 64742-47-8 30 0.0149157 15999
Citric Acid 77-92-9 60 0.0011166 1197.64
Tetrasodium EDTA 64-02-8 0.1 0.00004970 53.3298
Sodium Chloride 7647-14-5 5 0.0047312 5074.84
Ammonium Persulphate 7727-54-0 100 0.0029349 3148
Methanol 67-56-1 100 0.0004258 456.75
Oleamide DEA 93-83-4 2 0.0008365 897.26
Modified Thiourea Polymer 68527-49-1 7 0.00002980 31.9725
Oxyalkylated alcohol 78330-21-9 5 0.002486 2666.49
Propargyl Alcohol 107-19-7 5 0.00002130 22.8375
Ammonium Chloride 12125-02-9 3 0.0012548 1345.89
Didecyl Dimethyl Ammonium Chloride 7173-51-5 10 0.0021985 2358.13
Calcium Chloride 10043-52-4 5 0.0007701 826.005
Hydrotreated Light Distillate 64742-47-8 30 0.0125477 13458.9
Alcohols, C12-16, ethoxylated 68551-12-2 2 0.0008365 897.26
Ethylene Glycol 107-21-1 45 0.0069307 7434.04
Glutaraldehyde 111-30-8 30 0.0065954 7074.38
Sorbitan, mono-(9Z)-9octadecenoate 1338-43-8 5 0.002486 2666.49
Sorbitan Monooleate 1338-43-8 0.5 0.0002091 224.315
Acetic Acid 64-19-7 0.1 0.00004970 53.3298
Polyoxyalkylenes 68951-67-7 30 0.0001277 137.025
Olefin 64743-02-8 5 0.00002130 22.8375
Quaternary Ammonium Compound 68424-85-1 5 0.0010992 1179.06
Polyoxythylene Sorbitan Monooleate 9005-65-6 0.5 0.0002091 224.315
Acrylamide Modified Polymer 38193-60-1 60 0.0298315 31997.9
2-Propenoic, Polymer with Sodium Phosphinate, Sodium Salt 71050-62-9 20 0.0030803 3304.02
Potassium Chloride 7447-40-7 1 0.000154 165.201
Hydrochloric Acid 7647-01-0 15 0.0405272 43470.4
Formaldehyde 50-00-0 1 0.00000430 4.5675
HCl, 10.1 - 15% Baker Hughes Acidizing MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.270279 289772

For data sources see[5]

Stimulation Data

Stimulation Date Phase Number Chemical Agent Volume (gal) Treating Pressure (psi) Breakdown Pressure (psi)
2016-06-07 1 SAND, WHITE 3,023,463 8,092 6,580
2016-06-11 2 SAND, WHITE 3,023,463 7,864 9,785
2016-06-12 3 SAND, WHITE 3,023,463 8,401 6,682
2016-06-13 4 SAND, WHITE 3,023,463 8,453 7,930
2016-06-13 5 SAND, WHITE 3,023,463 8,004 7,792
2016-06-15 6 SAND, WHITE 3,023,463 8,307 8,116
2016-06-16 7 SAND, WHITE 3,023,463 8,148 8,425
2016-06-18 8 SAND, WHITE 3,023,463 8,476 8,676
2016-06-19 9 SAND, WHITE 3,023,463 8,261 7,890
2016-06-20 10 SAND, WHITE 3,023,463 8,316 8,267
2016-06-22 11 SAND, WHITE 3,023,463 8,249 6,957
2016-06-23 12 SAND, WHITE 3,023,463 8,287 7,312
2016-06-24 13 SAND, WHITE 3,023,463 8,114 7,746
2016-06-25 14 SAND, WHITE 3,023,463 8,263 7,459
2016-06-26 15 SAND, WHITE 3,023,463 8,276 7,457
2016-06-28 16 SAND, WHITE 3,023,463 8,001 6,503
2016-06-29 17 SAND, WHITE 3,023,463 7,960 6,692
2016-06-30 18 SAND, WHITE 3,023,463 7,409 6,812
2016-07-02 19 SAND, WHITE 3,023,463 7,151 5,129
2016-07-03 20 SAND, WHITE 3,023,463 7,078 6,252
2016-07-04 21 SAND, WHITE 3,023,463 6,754 5,913
2016-07-06 22 SAND, WHITE 3,023,463 7,128 5,549
2016-07-07 23 SAND, WHITE 3,023,463 6,934 5,867
2016-07-09 24 SAND, WHITE 3,023,463 7,008 5,930
2016-07-10 25 SAND, WHITE 3,023,463 7,169 6,886
2016-07-11 26 SAND, WHITE 3,023,463 7,206 6,377
2016-07-13 27 SAND, WHITE 3,023,463 6,794 7,327
2016-07-14 28 SAND, WHITE 3,023,463 7,071 7,848
2016-07-15 29 SAND, WHITE 3,023,463 6,795 7,568
2016-07-16 30 SAND, WHITE 3,023,463 7,139 8,063

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 3,717,999.86 138 0.00 0 0.00 0
2017 CABOT OIL & GAS CORP 5,218,506.63 364 0.00 0 0.00 0
2018 CABOT OIL & GAS CORP 2,713,227.00 365 0.00 0 0.00 0
2019 CABOT OIL & GAS CORP 1,804,336.00 362 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 1,774.84 Tons LANDFILL 101247
2016 CABOT OIL & GAS CORP Synthetic Liner Materials 19.60 Tons LANDFILL 101247
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 7,064.58 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Produced Fluid 3,567.75 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 958.26 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2016 CABOT OIL & GAS CORP Produced Fluid 19.36 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2016 CABOT OIL & GAS CORP Waste Water Treatment Sludge 47.38 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 193.91 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE002
2017 CABOT OIL & GAS CORP Produced Fluid 532.24 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2017 CABOT OIL & GAS CORP Produced Fluid 1,131.12 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2018 CABOT OIL & GAS CORP Produced Fluid 633.36 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2018 CABOT OIL & GAS CORP Produced Fluid 357.40 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2019 CABOT OIL & GAS CORP Produced Fluid 328.22 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
2353959 Primary Facility 2015-03-23 Routine/Complete Inspection No Violations Noted
2356518 Primary Facility 2015-03-31 Drilling/Alteration No Violations Noted
2358885 Primary Facility 2015-04-07 Drilling/Alteration No Violations Noted
2364610 Primary Facility 2015-03-11 Routine/Partial Inspection No Violations Noted
2364764 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.
2374773 Primary Facility 2015-06-01 Drilling/Alteration No Violations Noted
2481750 Primary Facility 2016-04-28 Routine/Complete Inspection No Violations Noted
2483981 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.

2485207 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.

2492476 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.

2533438 Primary Facility 2016-10-24 Routine/Complete Inspection No Violations Noted
2828093 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.

2842409 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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