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37-015-21344

Well Details

Well ID: 37-015-21344
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Country: United States
State: Pennsylvania
County: Bradford
Municipality: Asylum Township
Operator Name: CHIEF OIL & GAS LLC
Well Pad ID: 149071
Farm/Lease Name: PMG GOD UNIT 1H
License Status:
Spud Date:
Permit Date: 2010-11-22
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: No
Latitude: 41.715303
Longitude: -76.341069

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

Well History

Date Event
2010-11-22 New Permit Application
2010-12-02 Performed Spud Operation
2011-12-27 Perforation
2012-04-19 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 2011-12-27 2011-12-27 6,447 5,001,150
2 2011-03-04 2011-03-04 6,447 90,846

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 (Proppant) Halliburton Energy Services Propping Agent
Quartz 14808-60-7 99.90 20.90
LP-65 Halliburton Energy Services Scale Inhibitor Ammonium chloride 12125-02-9 0.10
HC-2 Halliburton Energy Services Surfactant Inner Salt of Alkylamines 0.29
Sodium chloride 7647-14-5
CS 650 OS Halliburton Energy Services Oxygen Scavenger Ammonium bisulfite 10192-30-0 0.07
Nickel Chelate Catalyst 2.00
Water Halliburton Energy Services Base Fluid
Water 100.00 80.61
Fresh Water 100.00 78.94
Water Superior Well Services Base Fluid
WFR-3B Superior Well Services Friction Reducer Ethoxylated C12-16 alcohols 68551-12-2 4.00
Stoddard solvent 8052-41-3 10.00
Distillates, petroleum, hydrotreated light 64742-47-8 0.10
1,2-Propylene glycol 57-55-6 25.00
Super Scale Control TSC Superior Well Services Scale Inhibitor Anionic Copolymer
1,2,4-Butanetricarboxylic acid, 2-phosphono- 37971-36-1
1,2-Propylene glycol 57-55-6 0.02
Anionic Polymer
Sand (Proppant) Superior Well Services Propping Agent Quartz 14808-60-7 99.90 18.58
KR-153SL Superior Well Services Biocide Polyethylene glycol 25322-68-3 5000.00
Ethylene glycol 107-21-1 100.00
2,2-Dibromo-3-nitrilopropionamide 10222-01-2 20.00 0.02
Diethylene glycol 111-46-6
FRW-66 Halliburton Energy Services Friction Reducer Distillates, petroleum, hydrotreated light 64742-47-8 0.14
BE-9M Halliburton Energy Services Biocide Methanol 67-56-1
Tri-n-butyl tetradecyl phosphonium chloride 81741-28-8 0.16
2 Water Halliburton Energy Services Base Fluid Water 100.00 80.61
CS 650 OS Halliburton Energy Services Oxygen Scavenger
Nickel Chelate Catalyst 2.00
Ammonium bisulfite 10192-30-0 0.07
FRW-66 Halliburton Energy Services Friction Reducer Distillates, petroleum, hydrotreated light 64742-47-8 0.14
LP-65 Halliburton Energy Services Scale Inhibitor Ammonium chloride 12125-02-9 0.10
Sand (Proppant) Halliburton Energy Services Propping Agent
Quartz 14808-60-7 99.90 18.58
HC-2 Halliburton Energy Services Surfactant Sodium chloride 7647-14-5
Inner Salt of Alkylamines 0.29
BE-9M Halliburton Energy Services Biocide
Tri-n-butyl tetradecyl phosphonium chloride 81741-28-8 0.16
Methanol 67-56-1

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Gas Production Days Oil Quantity (bbl) Oil Production Days Water Quantity (bbl) Water Production Days
2010 CHIEF OIL & GAS LLC 0.00 0 0.00 0 0.00 0
2011 CHIEF OIL & GAS LLC 0.00 0 0.00 0 0.00 0
2012 CHIEF OIL & GAS LLC 1,441,811.74 304 0.00 0 0.00 0
2013 CHIEF OIL & GAS LLC 1,089,026.00 361 0.00 0 0.00 0
2014 CHIEF OIL & GAS LLC 639,076.00 294 0.00 0 0.00 0
2015 CHIEF OIL & GAS LLC 736,266.41 315 0.00 0 0.00 0
2016 CHIEF OIL & GAS LLC 793,884.09 353 0.00 0 0.00 0
2017 CHIEF OIL & GAS LLC 675,147.96 365 0.00 0 0.00 0
2018 CHIEF OIL & GAS LLC 602,016.11 361 0.00 0 0.00 0
2019 CHIEF OIL & GAS LLC 700,696.95 365 0.00 0 0.00 0

For data sources see[6]

Waste Data

Period Operator Waste Type Quantity Disposal Method Waste Facility ID
2010 CHIEF OIL & GAS LLC Drilling Fluid Waste 130.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR119
2010 CHIEF OIL & GAS LLC Drilling Fluid Waste 714.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE PA0008451
2011 CHIEF OIL & GAS LLC Drill Cuttings 70.71 Tons LANDFILL NY31346244
2011 CHIEF OIL & GAS LLC Drilling Fluid Waste 130.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR119
2011 CHIEF OIL & GAS LLC Fracing Fluid Waste 974.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE PA0008451
2011 CHIEF OIL & GAS LLC Drill Cuttings 127.13 Tons LANDFILL 100955
2011 CHIEF OIL & GAS LLC Drill Cuttings 766.43 Tons LANDFILL 301626
2012 CHIEF OIL & GAS LLC Produced Fluid 2,269.20 Bbl REUSE OTHER THAN ROAD SPREADING
2012 CHIEF OIL & GAS LLC Fracing Fluid Waste 9,934.00 Bbl REUSE OTHER THAN ROAD SPREADING
2013 CHIEF OIL & GAS LLC Produced Fluid 97.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123SW018
2013 CHIEF OIL & GAS LLC Produced Fluid 1,569.00 Bbl REUSE OTHER THAN ROAD SPREADING
2014 CHIEF OIL & GAS LLC Produced Fluid 686.80 Bbl REUSE OTHER THAN ROAD SPREADING
2015 CHIEF OIL & GAS LLC Produced Fluid 2,163.99 Bbl REUSE OTHER THAN ROAD SPREADING
2016 CHIEF OIL & GAS LLC Fracturing Fluid Waste 80.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123
2016 CHIEF OIL & GAS LLC Produced Fluid 1,797.13 Bbl REUSE OTHER THAN ROAD SPREADING
2017 CHIEF OIL & GAS LLC Produced Fluid 105.05 Bbl REUSE OTHER THAN ROAD SPREADING
2017 CHIEF OIL & GAS LLC Produced Fluid 561.12 Bbl REUSE (AT WELL PAD)
2018 CHIEF OIL & GAS LLC Produced Fluid 53.21 Bbl REUSE (AT WELL PAD)
2019 CHIEF OIL & GAS LLC Produced Fluid 180.28 Bbl REUSE (AT WELL PAD)

For data sources see[7]

Inspection Data

Inspections Performed

Inspection ID Inspection Category Inspection Date Inspection Type Inspection Result Inspection Comments
1952202 Primary Facility 2011-02-03 Routine/Complete Inspection No Violations Noted Mouse hold not covered. Wellhead - no guages that I could see, however cellars filled with ice/snow.
1961053 Primary Facility 2011-03-29 Routine/Complete Inspection No Violations Noted 0 psi on annulus
1990551 Primary Facility 2011-07-25 Routine/Complete Inspection Pending Cellar filled in with gravel. 200# on either 9 5/8 or 13 3/8 -can't determine as cellar is filled to top with gravel. Need to remove gravel from cellar to determine which annulus has pressure and to ensure no visible bubbling is taking place. Well vented to tank.
2298707 Primary Facility 2014-08-11 Routine/Complete Inspection No Violations Noted
2306432 Primary Facility 2014-09-19 Routine/Complete Inspection No Violations Noted While in the process of surveying the site, I observed an area of standing water on the pad surface behind the reuse water tank battery. There was also an area of standing water inside the tank battery. The water inside the tank battery appeared to be sediment laden. It had a rust like appearance to it; orange and brown in color. Based on visual observance of the discolored water in containment and water on the pad surface which appeared to be emanating from under the containment system, I used an Extech, ExStik (2) pH, Conductivity, Salinty and TDS meter to field screen the water for conductivity. Conductivity readings were in the range of (6-8) milliSiemens/cm in containment. I recorded over the limit conductivity readings on the pad surface just outside containment and in standing water pooled in rocks in the site perimeter ditch. The highest possible recorded reading on this meter is (19.99) milliSiemens/cm.
2308775 Primary Facility 2014-09-26 Follow-up Inspection No Violations Noted . I met with (2) employees of Mr. Dirt, the company Chief Oil and Gas has subcontracted to remediate an area of staining and potential contamination of the NW corner of the pad surface. Thus far Mr. Dirt has filled (7) steel containers of excavated material in the general area where I recorded elevated conductivity readings in surface water next to the reuse water and gas buster tank battery. Please see the 9/19/14 inspection report, which describes the details of the conditions observed at the site and the conductivity readings recorded on my meter. The remediation of the pad surface was temporarily halted as Mr. Dirt was waiting for another container as they have planned to continue to excavate the impacted area. The 8th container as part of the remediation process is expected to be the final container as part of the process, according to Mr. Dirt. Mr. Dirt stated that around (250) cubic yards of the pad surface has been excavated and filled into containers up to this point.
2440935 Primary Facility 2016-01-14 Routine/Complete Inspection No Violations Noted
2508229 Primary Facility 2016-08-04 Routine/Complete Inspection No Violations Noted
2518840 Primary Facility 2016-09-13 Site Restoration No Violations Noted
2642785 Primary Facility 2017-10-02 Routine/Complete Inspection No Violations Noted Four wells staged for production. Site has interim restoration. Four separators within containment. One production tank severely corroded. The operator will empty the 1H tank by the afternoon of 10/2/2017. No violations noted at this time.
2652459 Primary Facility 2017-10-26 Routine/Complete Inspection No Violations Noted Four well staged for production. One production tank was noted to have severe corrosion during a 10/2/2017 inspection. The noted tank has since been removed. Two addition tanks were also removed and now only one production tank is plumbed into the dump line.
2802772 Primary Facility 2018-11-13 Routine/Complete Inspection No Violations Noted This site was restored and the NOT was acknowledged 8/8/16.

Four wells are staged for production. Four GPUs are present within secondary containment. This containment was in good condition overall. One steel produced water tank is present and in good condition. The secondary containment around the produced water tank is steel with plastic lining and is in good condition.

A labeled methanol container is present near the well heads. This container sits on top of a black plastic tank. The department recommends more substantial secondary containment for this container. An unlabeled green container is also present near the well heads. The department recommends labeling this container.

Several portions of the pad which had been restored and vegetated have been disturbed by truck traffic. In these areas, the soil has been compacted, some vegetated has died, and water is ponding. The department recommends restabilizing these areas as needed in the spring.

Post Construction Stormwater Management (PCSM) is handle

For data sources see[8]

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. ↑ "Oil and Gas Production Reports". Pennsylvania Department of Environmental Protection. 2019-03-31. Retrieved 2019-05-21. 
  7. ↑ "Oil and Gas Waste Reports". Pennsylvania Department of Environmental Protection. 2019-03-31. Retrieved 2019-05-21. 
  8. ↑ "Oil and Gas Compliance Report". Pennsylvania Department of Environmental Protection. 2019-05-20. Retrieved 2019-05-21. 
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