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37-115-22006

Well Details

Well ID: 37-115-22006
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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 10
License Status: Active
Spud Date: 2015-07-04
Permit Date: 2015-05-14
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: No
Latitude: 41.769083
Longitude: -75.608203

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

Well History

Date Event
2015-05-14 New Permit Application
2015-07-02 Performed Spud Operation
2015-07-31 Drilling Completion
2016-07-31 Perforation
2016-09-01 Perforation
2016-09-01 Performed Stage 1 of Stimulation
2016-09-03 Perforation
2016-09-03 Performed Stage 2 of Stimulation
2016-09-04 Perforation
2016-09-04 Performed Stage 3 of Stimulation
2016-09-05 Perforation
2016-09-05 Performed Stage 4 of Stimulation
2016-09-06 Perforation
2016-09-06 Performed Stage 5 of Stimulation
2016-09-07 Perforation
2016-09-07 Performed Stage 6 of Stimulation
2016-09-08 Perforation
2016-09-08 Performed Stage 7 of Stimulation
2016-09-09 Perforation
2016-09-09 Performed Stage 8 of Stimulation
2016-09-09 Performed Stage 9 of Stimulation
2016-09-10 Perforation
2016-09-10 Performed Stage 10 of Stimulation
2016-09-11 Perforation
2016-09-11 Performed Stage 11 of Stimulation
2016-09-12 Perforation
2016-09-12 Performed Stage 12 of Stimulation
2016-09-13 Perforation
2016-09-13 Performed Stage 13 of Stimulation
2016-09-14 Perforation
2016-09-14 Performed Stage 14 of Stimulation
2016-09-15 Perforation
2016-09-15 Performed Stage 15 of Stimulation
2016-09-16 Perforation
2016-09-16 Performed Stage 16 of Stimulation
2016-09-17 Performed Stage 17 of Stimulation
2016-09-18 Perforation
2016-09-18 Performed Stage 18 of Stimulation
2016-09-19 Perforation
2016-09-19 Performed Stage 19 of Stimulation
2016-09-20 Perforation
2016-09-20 Performed Stage 20 of Stimulation
2016-09-21 Perforation
2016-09-22 Perforation
2016-09-22 Performed Stage 21 of Stimulation
2016-09-22 Performed Stage 22 of Stimulation
2016-09-23 Perforation
2016-09-23 Performed Stage 23 of Stimulation
2016-09-24 Performed Stage 24 of Stimulation
2016-09-25 Perforation
2016-09-26 Perforation
2016-09-26 Performed Stage 25 of Stimulation
2016-09-27 Perforation
2016-09-27 Performed Stage 26 of Stimulation
2016-09-28 Perforation
2016-09-28 Performed Stage 27 of Stimulation
2016-09-29 Perforation
2016-09-29 Performed Stage 28 of Stimulation
2016-09-30 Perforation
2016-09-30 Performed Stage 29 of Stimulation
2016-10-02 Perforation
2016-10-02 Performed Stage 30 of Stimulation
2016-10-03 Perforation
2016-10-03 Performed Stage 31 of Stimulation
2016-10-05 Perforation
2016-10-05 Performed Stage 32 of Stimulation
2016-10-05 Performed Stage 33 of Stimulation
2016-10-06 Perforation
2016-10-06 Performed Stage 34 of Stimulation
2016-10-07 Perforation
2016-10-07 Performed Stage 35 of Stimulation
2016-10-08 Perforation
2016-10-08 Performed Stage 36 of Stimulation
2016-10-09 Perforation
2016-10-09 Performed Stage 37 of Stimulation
2016-10-09 Performed Stage 38 of Stimulation
2016-10-10 Perforation
2016-10-11 Performed Stage 39 of Stimulation
2017-01-25 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 2016-08-31 2016-10-10 7,102 16,414,100 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 0.512518 803606
Scaletrol 720, 330 gl tote Baker Hughes Scale Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line.
Listed Below 0 0.0115422 18097.7
Other Chemical(s) Baker Hughes See Trade Name(s) List Water 7732-18-5 85 0.255707 401004
Ferrotrol 300L (Totes) Baker Hughes Iron Control MSDS and Non-MSDS Ingredients are
listed below the green line.
Listed Below 0 0.001608 2521.35
Scaletrol 5279 Baker Hughes Scale Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line.
Listed Below 0 0.0039539 6199.57
HCl, 10.1 - 15% Baker Hughes Acidizing MSDS and Non-MSDS Ingredients are
listed below the green line.
Listed Below 0 0.233935 366800
Alpha 1427, 55 gl drum Baker Hughes Biocide MSDS and Non-MSDS Ingredients are
listed below the green line.
Listed Below 0 0.0223276 35008.8
CI-14 Baker Hughes Corrosion Inhibitor MSDS and Non-MSDS Ingredients are
listed below the green line.
Listed Below 0 0.0003699 580
Water Operator Carrier Water 7732-18-5 100 87.2694 136,858,000.0
2-Propenoic, Polymer with Sodium Phosphinate, Sodium Salt 71050-62-9 20 0.0023081 3619.54
Methanol 67-56-1 100 0.0003698 580
Oleamide DEA 93-83-4 2 0.0017592 2758.79
Crystalline Silica (Quartz) 14808-60-7 100 12.3522 19,371,000.0
Hydrotreated Light Distillate 64742-47-8 30 0.0263878 41381.8
Sodium Chloride 7647-14-5 5 0.0045529 7139.94
Propargyl Alcohol 107-19-7 5 0.00001850 29
Calcium Chloride 10043-52-4 5 0.000577 904.885
Poly (acrylamide-co-acrylic acid) partial sodium salt 62649-23-4 30 0.0263878 41381.8
Alcohols, C12-16, ethoxylated 68551-12-2 2 0.0017592 2758.79
Modified carboxylic acid salt Trade Secret 17 0.0006721 1053.93
Ethanol 64-17-5 5 0.0011162 1750.44
Fatty Acids 61790-12-3 10 0.00003700 58
Glutaraldehyde 111-30-8 30 0.0066972 10502.6
Sorbitan Monooleate 1338-43-8 0.5 0.0004398 689.697
Phosphonate Salt Trade Secret 2 0.00007910 123.991
Sodium Bisulfite 7631-90-5 1 0.00003950 61.9957
Olefin 64743-02-8 5 0.00001850 29
Modified Thiourea Polymer 68527-49-1 7 0.00002590 40.6
Polyoxythylene Sorbitan Monooleate 9005-65-6 0.5 0.0004398 689.697
Ethylene Glycol 107-21-1 45 0.0067744 10623.8
Hydrochloric Acid 7647-01-0 15 0.0350881 55025.8
Formaldehyde 50-00-0 1 0.00000370 5.8
Citric Acid 77-92-9 60 0.0009647 1512.81
Ammonium Chloride 12125-02-9 3 0.0026388 4138.18
Potassium Chloride 7447-40-7 1 0.0001154 180.977
Didecyl Dimethyl Ammonium Chloride 7173-51-5 10 0.0022324 3500.88
Quaternary Ammonium Compound 68424-85-1 5 0.0011162 1750.44
Polyoxyalkylenes 68951-67-7 30 0.000111 174
Sand, White, 40/70 Baker Hughes Proppant MSDS and Non-MSDS Ingredients are
listed below the green line.
Listed Below 0 11.8417 18,567,400.0
FRW-18 Baker Hughes Friction Reducer MSDS and Non-MSDS Ingredients are
listed below the green line.
Listed Below 0 0.087973 137939

For data sources see[5]

Stimulation Data

Stimulation Date Phase Number Chemical Agent Volume (gal) Treating Pressure (psi) Breakdown Pressure (psi)
2016-09-01 1 SAND, WHITE 2,107 7,796 6,512
2016-09-03 2 SAND, WHITE 2,107 8,071 7,240
2016-09-04 3 SAND, WHITE 2,107 7,917 7,541
2016-09-05 4 SAND, WHITE 2,107 7,656 8,167
2016-09-06 5 SAND, WHITE 2,107 7,967 7,465
2016-09-07 6 SAND, WHITE 2,107 7,876 6,942
2016-09-08 7 SAND, WHITE 2,107 7,570 6,295
2016-09-09 8 SAND, WHITE 2,107 7,759 6,444
2016-09-09 9 SAND, WHITE 2,107 7,564 5,935
2016-09-10 10 SAND, WHITE 2,107 7,554 6,099
2016-09-11 11 SAND, WHITE 2,107 7,907 6,444
2016-09-12 12 SAND, WHITE 2,107 7,992 8,185
2016-09-13 13 SAND, WHITE 2,107 8,028 7,878
2016-09-14 14 SAND, WHITE 2,107 8,220 9,167
2016-09-15 15 SAND, WHITE 2,107 7,605 6,446
2016-09-16 16 SAND, WHITE 2,107 7,444 6,620
2016-09-17 17 SAND, WHITE 2,107 7,566 5,683
2016-09-18 18 SAND, WHITE 2,107 7,274 5,441
2016-09-19 19 SAND, WHITE 2,107 7,781 7,100
2016-09-20 20 SAND, WHITE 2,107 7,405 6,121
2016-09-22 21 SAND, WHITE 2,107 7,341 6,094
2016-09-22 22 SAND, WHITE 2,107 7,542 6,585
2016-09-23 23 SAND, WHITE 2,107 7,820 6,665
2016-09-24 24 SAND, WHITE 2,107 7,456 6,392
2016-09-26 25 SAND, WHITE 2,107 7,549 6,602
2016-09-27 26 SAND, WHITE 2,107 7,311 6,922
2016-09-28 27 SAND, WHITE 2,107 7,332 6,546
2016-09-29 28 SAND, WHITE 2,107 7,062 5,549
2016-09-30 29 SAND, WHITE 2,107 7,376 7,200
2016-10-02 30 SAND, WHITE 2,107 7,466 6,621
2016-10-03 31 SAND, WHITE 2,107 7,560 5,343
2016-10-05 32 SAND, WHITE 2,107 7,187 6,437
2016-10-05 33 SAND, WHITE 2,107 7,222 7,293
2016-10-06 34 SAND, WHITE 2,107 7,073 7,924
2016-10-07 35 SAND, WHITE 2,107 7,302 6,386
2016-10-08 36 SAND, WHITE 2,107 7,773 7,319
2016-10-09 37 SAND, WHITE 2,107 7,674 7,989
2016-10-09 38 SAND, WHITE 2,107 7,066 6,040
2016-10-11 39 SAND, WHITE 2,107 4,986 4,078

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 692,008.03 57 0.00 0 0.00 0
2017 CABOT OIL & GAS CORP 2,685,438.41 365 0.00 0 0.00 0
2018 CABOT OIL & GAS CORP 1,663,869.00 364 0.00 0 0.00 0
2019 CABOT OIL & GAS CORP 1,058,956.00 341 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 676.19 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NC018
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 1,730.99 Tons LANDFILL 101247
2016 CABOT OIL & GAS CORP Fracturing Fluid Waste 9,545.33 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2016 CABOT OIL & GAS CORP Produced Fluid 2,126.97 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 19.02 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 11,393.21 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NE004
2016 CABOT OIL & GAS CORP Produced Fluid 2,426.89 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 1,760.19 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2017 CABOT OIL & GAS CORP Other Oil & Gas Wastes 337.20 Bbl REUSE (AT WELL PAD)
2017 CABOT OIL & GAS CORP Produced Fluid 8,793.14 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 2.36 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 2,323.39 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2017 CABOT OIL & GAS CORP Waste Water Treatment Sludge 44.53 Tons LANDFILL THR029
2017 CABOT OIL & GAS CORP Waste Water Treatment Sludge 32.36 Tons LANDFILL 100933
2018 CABOT OIL & GAS CORP Produced Fluid 2,450.66 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2018 CABOT OIL & GAS CORP Produced Fluid 387.66 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE004
2018 CABOT OIL & GAS CORP Produced Fluid 949.82 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NC018
2019 CABOT OIL & GAS CORP Produced Fluid 621.72 Bbl RESIDUAL WASTE PROCESSING FACILITY WMGR123NE002
2019 CABOT OIL & GAS CORP Produced Fluid 3,504.47 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
2389963 Primary Facility 2015-07-01 Preoperation Inspection No Violations Noted On 7/1/15, the Department conducted a Preoperational inspection of the Cabot Bolcato G Pad located in Gibson Township, Susquehanna County. The well pad is approximately 95% complete with all E&S BMP’s installed per plan. No construction has been done on the tank pad. The tank pad is not going to be built. The plan for water delivery to this location is to pipe water from the nearby Aldrich Pad. All filter sock controls have been installed for the tank pad. Crews actively repairing minor damage that recent heavy rains have caused. No violations noted. The well permits that have been issued for the pad are: Bolcato G. 3H(115-22015), 5H(115-22016), 6H(115-22004), 8H(115-22005), and the 10H(115-22006).
2390870 Primary Facility 2015-07-20 Drilling/Alteration No Violations Noted
2403186 Primary Facility 2015-08-31 Routine/Complete Inspection No Violations Noted
2404902 Primary Facility 2015-09-04 Routine/Complete Inspection No Violations Noted
2480577 Primary Facility 2016-05-03 Routine/Complete Inspection No Violations Noted
2518350 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.

2538777 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
2539229 Primary Facility 2016-11-16 Incident- Response to Accident or Event Violation(s) 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

2552317 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 691psi 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.

2639537 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.

2657165 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.
2745600 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.

2844239 Primary Facility 2019-02-25 Routine/Complete Inspection No Violations Noted At time of inspection.

The well was in production. The cellar was full of water and ice and there was no bubbling noticed. 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.

Violations Commited

Inspection ID Violation ID Violation Date Date Resolved Violation Code Violation Type Violation Comments
2539229 772814 2016-11-16 2016-11-16 CSL 402(b) Environmental Health & Safety Potential for pollutional substances to enter the waters of the commonwealth.
2539229 772815 2016-11-16 2016-11-16 78.56(a) Environmental Health & Safety Failure to contain a pollutional substance in a properly lined pit or tank.
2539229 772816 2016-11-16 2016-11-16 SWMA 301 Environmental Health & Safety Failure to properly store, transport, process or dispose of a residual waste.
2539229 772817 2016-11-16 2016-11-16 OGA3218.2(A) Environmental Health & Safety Containment for Unconventional wells.

Penalties Applied

Violation ID Penalty ID Penalty Code Penalty Status Penalty Date Enforcement Date Penalty Amount Amount Collected
772814 348928 NOV - Notice of Violation 2017-04-03
772815 348928 NOV - Notice of Violation 2017-04-03
772816 348928 NOV - Notice of Violation 2017-04-03
772817 348928 NOV - Notice of Violation 2017-04-03

For data sources see[9]

References