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37-115-21549

Well Details

Well ID: 37-115-21549
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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 10
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: 41.716364
Longitude: -75.961717

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
2015-04-11 Drilling Completion
2016-05-17 Perforation
2016-06-09 Perforation
2016-06-10 Performed Stage 2 of Stimulation
2016-06-12 Perforation
2016-06-12 Performed Stage 1 of Stimulation
2016-06-12 Performed Stage 3 of Stimulation
2016-06-14 Perforation
2016-06-14 Performed Stage 4 of Stimulation
2016-06-15 Perforation
2016-06-15 Performed Stage 5 of Stimulation
2016-06-16 Perforation
2016-06-16 Performed Stage 6 of Stimulation
2016-06-17 Performed Stage 7 of Stimulation
2016-06-18 Perforation
2016-06-19 Perforation
2016-06-19 Performed Stage 8 of Stimulation
2016-06-20 Perforation
2016-06-20 Performed Stage 9 of Stimulation
2016-06-21 Performed Stage 10 of Stimulation
2016-06-22 Perforation
2016-06-23 Perforation
2016-06-23 Performed Stage 11 of Stimulation
2016-06-24 Perforation
2016-06-24 Performed Stage 12 of Stimulation
2016-06-25 Perforation
2016-06-25 Performed Stage 13 of Stimulation
2016-06-26 Perforation
2016-06-26 Performed Stage 14 of Stimulation
2016-06-28 Perforation
2016-06-28 Performed Stage 15 of Stimulation
2016-06-29 Perforation
2016-06-29 Performed Stage 16 of Stimulation
2016-06-30 Performed Stage 17 of Stimulation
2016-07-01 Perforation
2016-07-02 Perforation
2016-07-02 Performed Stage 18 of Stimulation
2016-07-03 Performed Stage 19 of Stimulation
2016-07-08 Perforation
2016-07-09 Perforation
2016-07-09 Performed Stage 20 of Stimulation
2016-07-10 Perforation
2016-07-10 Performed Stage 21 of Stimulation
2016-07-11 Performed Stage 22 of Stimulation
2016-07-12 Perforation
2016-07-12 Performed Stage 23 of Stimulation
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 Performed Stage 26 of Stimulation
2016-07-23 Perforation
2019-01-09 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 2016-06-08 2016-07-14 7,025 9,920,230 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 FRW-18 Baker Hughes Friction Reducer MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0375198 34882.6
Sand, White, 100 mesh Baker Hughes Proppant MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.567101 527241
HCl, 10.1 - 15% Baker Hughes Acidizing MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.266308 247590
Alpha 1427 Baker Hughes Biocide MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0225217 20938.8
GBW-5 Baker Hughes Breaker MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0028901 2687
Ferrotrol 300L (Totes) Baker Hughes Iron Control MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0018306 1701.91
CI-14 Baker Hughes Corrosion Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0004211 391.5
Scaletrol 720, 330 gl tote Baker Hughes Scale Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0152717 14198.4
Sand, White, 40/70 Baker Hughes Proppant MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 10.0701 9,362,330.0
MaxPerm-20A, 265 gallon tote Baker Hughes Friction Reducer MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0023244 2161.06
MaxPerm 30 Baker Hughes Friction Reducer MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0475752 44231.3
Ethylene Glycol 107-21-1 45 0.0068691 6389.26
Petroleum Distillates 64742-47-8 30 0.0142659 13269.4
Tetrasodium EDTA 64-02-8 0.1 0.00004760 44.2313
Olefin 64743-02-8 5 0.00002100 19.575
Oxyalkylated alcohol 78330-21-9 5 0.0024938 2319.62
Didecyl Dimethyl Ammonium Chloride 7173-51-5 10 0.0022511 2093.88
Fatty Acids 61790-12-3 10 0.00004210 39.15
Acetic Acid, Potassium Salt 127-08-2 1 0.0004755 442.313
Oleamide DEA 93-83-4 2 0.00075 697.653
Glutaraldehyde 111-30-8 30 0.0067534 6281.63
Sodium Chloride 7647-14-5 5 0.0045216 4205.73
Polyoxythylene Sorbitan Monooleate 9005-65-6 0.5 0.0001875 174.413
Crystalline Silica (Quartz) 14808-60-7 100 10.6323 9,889,570.0
Sorbitan, mono-(9Z)-9-octadecenoate 1338-43-8 5 0.0001162 108.053
Polyoxyethylene sorbitan monooleate 9005-65-6 5 0.0001162 108.053
Alcohols, C12-16, ethoxylated 68551-12-2 2 0.00075 697.653
Ammonium Chloride 12125-02-9 3 0.0011251 1046.48
Calcium Chloride 10043-52-4 5 0.0007632 709.918
Acrylamide Modified Polymer 38193-60-1 60 0.0285319 26538.8
Propargyl Alcohol 107-19-7 5 0.00002100 19.575
Acetic Acid 64-19-7 0.1 0.00004760 44.2313
Hydrotreated Light Distillate 64742-47-8 30 0.0119477 11113.1
Ethanol 64-17-5 5 0.0011256 1046.94
Sorbitan Monooleate 1338-43-8 0.5 0.0001875 174.413
2-Propenoic, Polymer with Sodium Phosphinate, Sodium Salt 71050-62-9 20 0.0030529 2839.67
Methanol 67-56-1 100 0.0004209 391.5
1-Propanesulfonic acid, 2-methyl-2-[(1-oxo-2-propen-1-yl)amino]-,
polymer with 2-propenamide, sodium salt 		83446-68-8 60 0.001394 1296.64
Formaldehyde 50-00-0 1 0.00000420 3.915
Quaternary Ammonium Compound 68424-85-1 5 0.0011256 1046.94
Polyoxyalkylenes 68951-67-7 30 0.0001263 117.45
Ammonium Persulphate 7727-54-0 100 0.0028888 2687
Hydrochloric Acid 7647-01-0 15 0.0399319 37142.4
Sorbitan, mono-(9Z)-9octadecenoate 1338-43-8 5 0.0023777 2211.56
Poly (acrylamide-co-acrylic acid) partial sodium salt 62649-23-4 30 0.0112507 10464.8
Modified Thiourea Polymer 68527-49-1 7 0.00002950 27.405
Sorbitan monooleate ethoxylate 9005-65-5 5 0.0023777 2211.56
Potassium Chloride 7447-40-7 1 0.0001526 141.984
Citric Acid 77-92-9 60 0.0010978 1021.15
Other Chemical(s) Baker Hughes See Trade Name(s) List Water 7732-18-5 85 0.293242 272757
Water Operator Carrier Water 7732-18-5 100 88.9248 82,712,900.0

For data sources see[5]

Stimulation Data

Stimulation Date Phase Number Chemical Agent Volume (gal) Treating Pressure (psi) Breakdown Pressure (psi)
2016-06-12 1 Sand, White 793 7,708 7,005
2016-06-10 2 Sand, White 793 8,255 6,706
2016-06-12 3 Sand, White 793 7,996 6,610
2016-06-14 4 Sand, White 793 7,501 6,922
2016-06-15 5 Sand, White 793 7,889 6,116
2016-06-16 6 Sand, White 793 7,872 7,495
2016-06-17 7 Sand, White 793 7,834 7,005
2016-06-19 8 Sand, White 793 8,886 7,860
2016-06-20 9 Sand, White 793 7,944 7,105
2016-06-21 10 Sand, White 793 8,070 7,210
2016-06-23 11 Sand, White 793 7,936 7,687
2016-06-24 12 Sand, White 793 7,863 7,183
2016-06-25 13 Sand, White 793 8,001 6,884
2016-06-26 14 Sand, White 793 7,863 7,027
2016-06-28 15 Sand, White 793 8,265 7,193
2016-06-29 16 Sand, White 793 8,226 6,704
2016-06-30 17 Sand, White 793 8,123 7,755
2016-07-02 18 Sand, White 793 8,416 7,562
2016-07-03 19 Sand, White 793 8,032 7,881
2016-07-09 20 Sand, White 793 8,525 8,127
2016-07-10 21 Sand, White 793 7,963 6,714
2016-07-11 22 Sand, White 793 7,884 7,645
2016-07-12 23 Sand, White 793 7,425 7,248
2016-07-13 24 Sand, White 793 7,358 6,203
2016-07-14 25 Sand, White 793 7,159 8,147
2016-07-15 26 Sand, White 793 6,999 7,123

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 2,808,486.46 138 0.00 0 0.00 0
2017 CABOT OIL & GAS CORP 4,764,470.19 364 0.00 0 0.00 0
2018 CABOT OIL & GAS CORP 2,508,207.00 365 0.00 0 0.00 0
2019 CABOT OIL & GAS CORP 1,642,709.00 362 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 1,857.03 Tons LANDFILL 101247
2016 CABOT OIL & GAS CORP Synthetic Liner Materials 19.60 Tons LANDFILL 101247
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 7,142.38 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Produced Fluid 3,491.23 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 968.81 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2016 CABOT OIL & GAS CORP Produced Fluid 18.95 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2016 CABOT OIL & GAS CORP Waste Water Treatment Sludge 47.90 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 205.68 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NE002
2017 CABOT OIL & GAS CORP Produced Fluid 513.69 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2017 CABOT OIL & GAS CORP Produced Fluid 1,088.05 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2018 CABOT OIL & GAS CORP Produced Fluid 556.84 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2018 CABOT OIL & GAS CORP Produced Fluid 330.25 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2019 CABOT OIL & GAS CORP Produced Fluid 383.09 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
2353963 Primary Facility 2015-03-23 Routine/Complete Inspection No Violations Noted
2356507 Primary Facility 2015-03-31 Drilling/Alteration No Violations Noted
2358904 Primary Facility 2015-04-07 Drilling/Alteration No Violations Noted
2364618 Primary Facility 2015-03-11 Routine/Partial Inspection No Violations Noted
2364773 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.
2481754 Primary Facility 2016-04-28 Routine/Complete Inspection No Violations Noted
2483996 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.

2485215 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.

2492484 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.

2533445 Primary Facility 2016-10-24 Routine/Complete Inspection No Violations Noted
2828088 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.

2842424 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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