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37-115-22042

Well Details

Well ID: 37-115-22042
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Country: United States
State: Pennsylvania
County: Susquehanna
Municipality: Gibson Township
Operator Name: CABOT OIL & GAS CORP
Well Pad ID: 152558
Farm/Lease Name: BOLCATO G 2
License Status: Active
Spud Date: 2015-08-31
Permit Date: 2015-07-15
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: No
Latitude: 41.769078
Longitude: -75.608367

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

Well History

Date Event
2015-07-15 New Permit Application
2015-08-31 Performed Spud Operation
2015-10-19 Drilling Completion
2016-01-11 Perforation
2016-08-01 Perforation
2016-09-25 Perforation
2016-09-25 Performed Stage 1 of Stimulation
2016-09-26 Perforation
2016-09-26 Performed Stage 2 of Stimulation
2016-09-27 Performed Stage 3 of Stimulation
2016-09-28 Perforation
2016-09-29 Perforation
2016-09-29 Performed Stage 4 of Stimulation
2016-09-30 Perforation
2016-09-30 Performed Stage 5 of Stimulation
2016-10-01 Perforation
2016-10-01 Performed Stage 6 of Stimulation
2016-10-02 Performed Stage 7 of Stimulation
2016-10-03 Perforation
2016-10-04 Perforation
2016-10-04 Performed Stage 8 of Stimulation
2016-10-05 Perforation
2016-10-05 Performed Stage 9 of Stimulation
2016-10-06 Perforation
2016-10-06 Performed Stage 10 of Stimulation
2016-10-07 Perforation
2016-10-07 Performed Stage 11 of Stimulation
2016-10-07 Performed Stage 12 of Stimulation
2016-10-08 Perforation
2016-10-08 Performed Stage 13 of Stimulation
2016-10-09 Perforation
2016-10-09 Performed Stage 14 of Stimulation
2016-10-10 Perforation
2016-10-10 Performed Stage 15 of Stimulation
2016-10-11 Perforation
2016-10-11 Performed Stage 16 of Stimulation
2016-10-11 Performed Stage 17 of Stimulation
2016-10-12 Perforation
2016-10-12 Performed Stage 18 of Stimulation
2016-10-13 Perforation
2016-10-13 Performed Stage 19 of Stimulation
2016-10-13 Performed Stage 20 of Stimulation
2016-10-13 Performed Stage 21 of Stimulation
2016-10-14 Perforation
2016-10-14 Performed Stage 22 of Stimulation
2016-10-14 Performed Stage 23 of Stimulation
2016-10-14 Performed Stage 24 of Stimulation
2016-10-15 Perforation
2016-10-15 Performed Stage 25 of Stimulation
2016-10-15 Performed Stage 26 of Stimulation
2016-10-15 Performed Stage 27 of Stimulation
2017-01-24 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 2016-09-24 2016-10-14 7,117 9,831,360 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 Sand, White, 100 mesh Baker Hughes Proppant MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.674758 630497
Water Operator Carrier Water 7732-18-5 100 87.7117 81,971,900.0
FRW-18 Baker Hughes Friction Reducer MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.092146 86101.6
Alpha 1427 Baker Hughes Biocide MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0256393 23957.5
Scaletrol 720, 330 gl tote Baker Hughes Scale Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.005288 4941.15
Sand, White, 40/70 Baker Hughes Proppant MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 11.1864 10,452,700.0
HCl, 10.1 - 15% Baker Hughes Acidizing MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.275766 257677
Scaletrol 5279 Baker Hughes Scale Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0112346 10497.7
CI-14 Baker Hughes Corrosion Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0004345 406
Ferrotrol 300L (Totes) Baker Hughes Iron Control MSDS and Non-MSDS Ingredients are
listed below the green line. 		Listed Below 0 0.0018888 1764.95
Other Chemical(s) Baker Hughes See Trade Name(s) List Water 7732-18-5 85 0.29513 275817
Polyoxythylene Sorbitan Monooleate 9005-65-6 0.5 0.0004607 430.508
Ethanol 64-17-5 5 0.0012818 1197.88
Quaternary Ammonium Compound 68424-85-1 5 0.0012818 1197.88
Ammonium Chloride 12125-02-9 3 0.0027639 2583.05
Fatty Acids 61790-12-3 10 0.00004340 40.6
Poly (acrylamide-co-acrylic acid) partial sodium salt 62649-23-4 30 0.0276392 25830.5
Potassium Chloride 7447-40-7 1 0.00005290 49.4115
Polyoxyalkylenes 68951-67-7 30 0.0001303 121.8
Sorbitan Monooleate 1338-43-8 0.5 0.0004607 430.508
Hydrochloric Acid 7647-01-0 15 0.0413623 38655.6
Phosphonate Salt Trade Secret 2 0.0002247 209.954
Modified Thiourea Polymer 68527-49-1 7 0.00003040 28.42
Hydrotreated Light Distillate 64742-47-8 30 0.0276392 25830.5
Propargyl Alcohol 107-19-7 5 0.00002170 20.3
Crystalline Silica (Quartz) 14808-60-7 100 11.8592 11,083,200.0
Calcium Chloride 10043-52-4 5 0.0002644 247.057
Ethylene Glycol 107-21-1 45 0.0068723 6422.59
Citric Acid 77-92-9 60 0.0011331 1058.97
Sodium Chloride 7647-14-5 5 0.0047717 4459.47
Didecyl Dimethyl Ammonium Chloride 7173-51-5 10 0.0025635 2395.75
Olefin 64743-02-8 5 0.00002170 20.3
Modified carboxylic acid salt Trade Secret 17 0.0019096 1784.61
Methanol 67-56-1 100 0.0004344 406
Sodium Bisulfite 7631-90-5 1 0.0001123 104.977
Glutaraldehyde 111-30-8 30 0.0076905 7187.25
Oleamide DEA 93-83-4 2 0.0018426 1722.03
2-Propenoic, Polymer with Sodium Phosphinate, Sodium Salt 71050-62-9 20 0.0010574 988.229
Alcohols, C12-16, ethoxylated 68551-12-2 2 0.0018426 1722.03
Formaldehyde 50-00-0 1 0.00000430 4.06

For data sources see[5]

Stimulation Data

Stimulation Date Phase Number Chemical Agent Volume (gal) Treating Pressure (psi) Breakdown Pressure (psi)
2016-09-25 1 SAND, WHITE 1,262 7,340 5,525
2016-09-26 2 SAND, WHITE 1,262 7,019 6,276
2016-09-27 3 SAND, WHITE 1,262 6,993 6,580
2016-09-29 4 SAND, WHITE 1,262 6,927 6,290
2016-09-30 5 SAND, WHITE 1,262 7,064 7,182
2016-10-01 6 SAND, WHITE 1,262 7,300 7,702
2016-10-02 7 SAND, WHITE 1,262 7,295 7,586
2016-10-04 8 SAND, WHITE 1,262 6,962 6,939
2016-10-05 9 SAND, WHITE 1,262 7,179 6,740
2016-10-06 10 SAND, WHITE 1,262 7,945 6,937
2016-10-07 11 SAND, WHITE 1,262 7,049 7,384
2016-10-07 12 SAND, WHITE 1,262 6,974 7,678
2016-10-08 13 SAND, WHITE 1,262 7,230 6,508
2016-10-09 14 SAND, WHITE 1,262 6,846 6,923
2016-10-10 15 SAND, WHITE 1,262 6,908 6,084
2016-10-11 16 SAND, WHITE 1,262 6,880 7,009
2016-10-11 17 SAND, WHITE 1,262 7,089 7,820
2016-10-12 18 SAND, WHITE 1,262 7,515 7,883
2016-10-13 19 SAND, WHITE 1,262 7,163 7,292
2016-10-13 20 SAND, WHITE 1,262 7,114 7,414
2016-10-13 21 SAND, WHITE 1,262 6,911 7,814
2016-10-14 22 SAND, WHITE 1,262 6,795 8,107
2016-10-14 23 SAND, WHITE 1,262 6,796 6,885
2016-10-14 24 SAND, WHITE 1,262 6,394 6,787
2016-10-15 25 SAND, WHITE 1,262 6,473 8,190
2016-10-15 26 SAND, WHITE 1,262 6,153 6,853
2016-10-15 27 SAND, WHITE 1,262 5,830 6,215

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 686,047.75 57 0.00 0 0.00 0
2017 CABOT OIL & GAS CORP 3,027,617.51 365 0.00 0 0.00 0
2018 CABOT OIL & GAS CORP 1,669,563.00 365 0.00 0 0.00 0
2019 CABOT OIL & GAS CORP 1,124,081.00 364 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 22.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR119
2015 CABOT OIL & GAS CORP Drill Cuttings 1,435.37 Tons LANDFILL 101247
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 9,487.40 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Produced Fluid 1,863.46 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NE004
2016 CABOT OIL & GAS CORP Other Oil & Gas Wastes 59.80 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Soil Contaminated by Oil 15.17 Tons LANDFILL THR029
2016 CABOT OIL & GAS CORP Synthetic Liner Materials 17.08 Tons LANDFILL 101247
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 18.91 Bbl REUSE OTHER THAN ROAD SPREADING
2016 CABOT OIL & GAS CORP Other Oil & Gas Wastes 408.80 Bbl REUSE OTHER THAN ROAD SPREADING
2016 CABOT OIL & GAS CORP Soil Contaminated by Oil & Gas Related Spills 15.17 Tons LANDFILL THR029
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 11,324.07 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NE004
2016 CABOT OIL & GAS CORP Produced Fluid 2,126.22 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Other Oil & Gas Wastes 0.10 Tons RESIDUAL WASTE PROCESSING FACILITY 301333
2017 CABOT OIL & GAS CORP Produced Fluid 1,524.03 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2017 CABOT OIL & GAS CORP Other Oil & Gas Wastes 41.00 Bbl REUSE (AT WELL PAD)
2017 CABOT OIL & GAS CORP Produced Fluid 8,416.05 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE004
2017 CABOT OIL & GAS CORP Soil Contaminated by Oil 0.04 Tons RESIDUAL WASTE PROCESSING FACILITY 301333
2017 CABOT OIL & GAS CORP Soil Contaminated by Oil & Gas Related Spills 0.04 Tons RESIDUAL WASTE PROCESSING FACILITY 301333
2017 CABOT OIL & GAS CORP Synthetic Liner Materials 2.46 Tons LANDFILL 101247
2017 CABOT OIL & GAS CORP Waste Water Treatment Sludge 1.77 Tons REUSE (AT WELL PAD)
2017 CABOT OIL & GAS CORP Other Oil & Gas Wastes 2.40 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE004
2017 CABOT OIL & GAS CORP Produced Fluid 3,056.65 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2017 CABOT OIL & GAS CORP Waste Water Treatment Sludge 33.43 Tons LANDFILL THR029
2017 CABOT OIL & GAS CORP Waste Water Treatment Sludge 24.29 Tons LANDFILL 100933
2018 CABOT OIL & GAS CORP Produced Fluid 3,722.89 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2018 CABOT OIL & GAS CORP Produced Fluid 552.93 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE004
2018 CABOT OIL & GAS CORP Produced Fluid 1,417.95 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2019 CABOT OIL & GAS CORP Produced Fluid 461.80 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2019 CABOT OIL & GAS CORP Produced Fluid 3,449.56 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
2403164 Primary Facility 2015-08-31 Drilling/Alteration No Violations Noted
2404905 Primary Facility 2015-09-04 Routine/Complete Inspection No Violations Noted
2415518 Primary Facility 2015-10-14 Drilling/Alteration No Violations Noted
2480574 Primary Facility 2016-05-03 Routine/Complete Inspection No Violations Noted
2518326 Primary Facility 2016-09-12 Routine/Complete Inspection No Violations Noted At time of inspection, arrived on site at 13:15p.m., Baker Hughes was the frack company on site to frack the wells. I met with company man Mike Vollmer. They just completed stage 13 and were running the plug and perforations on the 10H. I took a walk around the location and everything looked OK.

They have completed 0 out of 27 stages on the 2H, 13 out of 38 stages on the 5H, 13 out of 46 stages on the 6H, 12 out of 43 stages on the 8H, and 13 out of 39 stages on the 10H. All the water was being hauled in and pumped into tanks near the site entrance and then pumped through a poly line to a larger set of tanks on the other side of the site. All the tanks were on containment and the containment was in good condition. I left the site at 14:10p.m.

2538764 Primary Facility 2016-10-18 Routine/Complete Inspection No Violations Noted I arrived at the site at 11 AM. I initially met with Paul Hovan, Environmental Consultant of Tioga Environmental Consulting LLC. Williams was in preparation to install natural gas pipeline from this pad to the nearby Gibson pipeline according to Mr. Hovan. After talking to Mr. Hovan, I met with Heath Benton, site company completions consultant of Cabot, Mark Miller, consultant of Cabot and Johnny Crawford, Workover Superintendent of Cabot in the company man trailer. Mr. Denton stated the following. "There are (2) Cudd Energy services coil tubing units in the process of drilling out frac plugs on the 2H and 10H wells. They started last Thursday. The frac job was done on Friday. There will be (26) plugs drilled out on the 2H and (26) on the 10H well. Freshwater, recycled water left over from the frac, gel and friction reducer is used in the wells to drill the plugs out. Fluid flows out of the wells, goes through plug catchers, and then to gas buster tanks and then settles in frac tanks. The frac plugs
2539214 Primary Facility 2016-11-16 Incident- Response to Accident or Event No Violations Noted The Department, Briana Cunningham, DEP O&G WQS and I arrived at the site at 11:30 AM to conduct an investigation of the spill incident.

The Department, Briana Cunningham, DEP O&G WQS and I arrived at the site at 11:30 AM to conduct an investigation of the spill incident. We initially met with Kevin Hagadorn, lead flow hand of Erick Flowback Services Incorporated, the Cabot subcontractor in the process of conducting flowback operations on the Bolcato wells. Mr. Hagadorn stated that flowback of the wells is nearly complete and we are cleaning out sand from the wells. Natural gas is sent directly to sales according to Mr. Hagadorn and there is another crew on-site setting the wells up for production. The Department informed Mr. Hagadorn that they had mobilized to the site in order to investigate the spill incident. Mr. Hagadorn contacted Mr. Watson to inform him that the Department was at the site in preparation to assess the spill incident. Upon completion of our conversation with Mr. Hagadorn, the Depar

2552308 Primary Facility 2017-01-11 Routine/Complete Inspection No Violations Noted At time of inspection, arrived on site at 12:55p.m., the well was recently completed and is in production. The well tag was on the well and correct. The cellar had ice at the bottom, the (20x13) vent pipe was open and venting into a small plastic tank, the (13x9) vent pipe was open and venting into a small plastic tank, the (9x5) vent pipe was open and venting into a small plastic tank. There was 683psi on the production casing. The well was producing through a separator and the production fluid was going into a 500bbl flow back tank that was on containment and the containment appeared to be in good condition. There were three 500bbl tanks at the far corner of the site on containment and the containment appeared to be in good condition. I took a walk around the location and there were no obvious concerns noticed.

I left the site at 13:35p.m.

2639545 Primary Facility 2017-09-25 Routine/Complete Inspection No Violations Noted At time of inspection.

The well was in production. It was producing through a sand separator. All the annulus vent lines 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.

2657173 Primary Facility 2017-11-02 Routine/Complete Inspection No Violations Noted This inspection was conducted as a routine complete inspection. Well site is stable. Any silt sock still present appears as if it could be removed. No violations noted.
2745589 Primary Facility 2018-06-26 Routine/Complete Inspection No Violations Noted At time of inspection.

The well was in production. There was water 7.5' below grade in the cellar with no bubbling noticed and there was no gas detected in the remainder of the cellar. The (20x13), (13x9) and (9x5) annuli vent pipes were connected together and going to the same poly vent tank. There was a crew on the site putting down stone and rolling the pad. There was also remedial work done on the slopes. I took a walk around the location and there were no obvious concerns noticed. There were no violations noted.

2844241 Primary Facility 2019-02-25 Routine/Complete Inspection No Violations Noted At time of inspection.

The well was in production. There was water and ice 6' below grade in the cellar with no bubbling noticed and there was no gas detected in the remainder of the cellar. The (20x13), (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 2/5/19. I took a walk around the location and there were no obvious concerns noticed. There were no violations noted.

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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