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| Well ID: 37-115-20212 | Loading map...
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| Country: United States | |
| State: Pennsylvania | |
| County: Susquehanna | |
| Municipality: Lathrop Township | |
| Operator Name: CHIEF OIL & GAS LLC | |
| Well Pad ID: 148675 | |
| Farm/Lease Name: KERR UNIT 1H | |
| License Status: | |
| Spud Date: | |
| Permit Date: 2009-09-02 | |
| Well Type: GAS | |
| Unconventional Well: Y | |
| Configuration: Horizontal Well | |
| Conservation: No | |
| Latitude: 41.697739 | |
| Longitude: -75.840136 |
| Date | Event |
|---|---|
| 2009-09-02 | New Permit Application |
| 2010-07-17 | Performed Spud Operation |
| 2010-08-15 | Drilling Completion |
| 2011-08-11 | Perforation |
| 2011-09-06 | Performed Stimulation |
| 2012-02-06 | DEVIATED |
For data sources see[4]
| Job Number | Job Start Date | Job End Date | True Vertical Depth (ft) | Total Water Volume (gal) | Total Non-Water Volume (gal) |
|---|---|---|---|---|---|
| 1 | 2011-10-04 | 2011-10-04 | 7,505 | 3,390,576 |
| Job Number | Trade Name | Supplier | Purpose | Ingredient Name | CAS Number | Additive Percentage by Mass | Job Percentage by Mass | Mass Used (lb) |
|---|---|---|---|---|---|---|---|---|
| 1 | LP-65 | Halliburton Energy Services | Scale Inhibitor | |||||
| Ammonium Chloride 12125-02-9 5.0 - 10.0 |
0.04 | |||||||
| CS 650 OS | Halliburton Energy Services | Oxygen Scavenger | ||||||
| Ammonium bisulfite | 10192-30-0 | 0.01 | ||||||
| Nickel Chelate Catalyst n/a |
2.00 | |||||||
| Sand (Proppant) | Halliburton Energy Services | Propping Agent | Quartz | 14808-60-7 | 99.90 | 14.46 | ||
| Water | Base Fluid | Fresh Water | 100.00 | 85.35 | ||||
| FRW-66 | Halliburton Energy Services | Friction Reducer | ||||||
| Hydrotreated Light Distillate 64742-47-8 10.0 - 30.0 |
0.11 | |||||||
| BE-9M | Halliburton Energy Services | Biocide | Tributyl tetradecyl phophonium chloride 81741-28-8 5.0 - 10.0 Methanol 67-56-1 10.0 - 30.0 |
0.02 | ||||
| Tributyl tetradecyl phophonium chloride 81741-28-8 5.0 - 10.0 Methanol 67-56-1 10.0 - 30.0 |
||||||||
For data sources see[5]
| Stimulation Date | Phase Number | Chemical Agent | Volume (gal) | Treating Pressure (psi) | Breakdown Pressure (psi) |
|---|---|---|---|---|---|
| 2011-09-06 | 0 | 0 | 0 |
For data sources see[6]
| Period | Operator Name | Gas Quantity (mcf) | Gas Production Days | Oil Quantity (bbl) | Oil Production Days | Water Quantity (bbl) | Water Production Days |
|---|---|---|---|---|---|---|---|
| 2009 | CHIEF OIL & GAS LLC | 0.00 | 0 | 0.00 | 0 | 0.00 | 0 |
| 2010 | CHIEF OIL & GAS LLC | 0.00 | 0 | 0.00 | 0 | 0.00 | 0 |
| 2011 | CHIEF OIL & GAS LLC | 139,500.00 | 34 | 0.00 | 0 | 0.00 | 0 |
| 2012 | CHIEF OIL & GAS LLC | 2,237,272.77 | 364 | 0.00 | 0 | 0.00 | 0 |
| 2013 | CHIEF OIL & GAS LLC | 1,342,545.00 | 361 | 0.00 | 0 | 0.00 | 0 |
| 2014 | CHIEF OIL & GAS LLC | 708,214.00 | 365 | 0.00 | 0 | 0.00 | 0 |
| 2015 | CHIEF OIL & GAS LLC | 430,941.82 | 357 | 0.00 | 0 | 0.00 | 0 |
| 2016 | CHIEF OIL & GAS LLC | 220,496.68 | 254 | 0.00 | 0 | 0.00 | 0 |
| 2017 | CHIEF OIL & GAS LLC | 377,225.36 | 288 | 0.00 | 0 | 0.00 | 0 |
| 2018 | CHIEF OIL & GAS LLC | 256,159.89 | 310 | 0.00 | 0 | 0.00 | 0 |
| 2019 | CHIEF OIL & GAS LLC | 619,650.25 | 363 | 0.00 | 0 | 0.00 | 0 |
For data sources see[7]
| Period | Operator | Waste Type | Quantity | Disposal Method | Waste Facility ID |
|---|---|---|---|---|---|
| 2010 | CHIEF OIL & GAS LLC | Drilling Fluid Waste | 8,767.00 Bbl | CENTRALIZED TREATMENT PLANT FOR RECYCLE | WMGR119 |
| 2010 | CHIEF OIL & GAS LLC | Fracing Fluid Waste | 50.50 Bbl | CENTRALIZED TREATMENT PLANT FOR RECYCLE | PA0027057 |
| 2010 | CHIEF OIL & GAS LLC | Drilling Fluid Waste | 1,517.00 Bbl | CENTRALIZED TREATMENT PLANT FOR RECYCLE | PA0008451 |
| 2012 | CHIEF OIL & GAS LLC | Produced Fluid | 1,041.10 Bbl | REUSE OTHER THAN ROAD SPREADING | |
| 2013 | CHIEF OIL & GAS LLC | Produced Fluid | 257.60 Bbl | REUSE OTHER THAN ROAD SPREADING | |
| 2014 | CHIEF OIL & GAS LLC | Produced Fluid | 184.23 Bbl | REUSE OTHER THAN ROAD SPREADING | |
| 2015 | CHIEF OIL & GAS LLC | Produced Fluid | 84.11 Bbl | REUSE OTHER THAN ROAD SPREADING | |
| 2016 | CHIEF OIL & GAS LLC | Produced Fluid | 138.81 Bbl | REUSE OTHER THAN ROAD SPREADING | |
| 2017 | CHIEF OIL & GAS LLC | Produced Fluid | 0.19 Bbl | STORAGE PENDING DISPOSAL OR REUSE | |
| 2017 | CHIEF OIL & GAS LLC | Produced Fluid | 435.53 Bbl | REUSE (AT WELL PAD) | |
| 2018 | CHIEF OIL & GAS LLC | Produced Fluid | 192.00 Bbl | RESIDUAL WASTE PROCESSING FACILITY | WMGR123 |
| 2018 | CHIEF OIL & GAS LLC | Produced Fluid | 57.66 Bbl | REUSE (AT WELL PAD) | |
| 2019 | CHIEF OIL & GAS LLC | Produced Fluid | 233.26 Bbl | REUSE (AT WELL PAD) |
For data sources see[8]
| Inspection ID | Inspection Category | Inspection Date | Inspection Type | Inspection Result | Inspection Comments |
|---|---|---|---|---|---|
| 1897668 | Primary Facility | 2010-07-09 | Complaint Inspection | No Violations Noted | |
| 1919700 | Primary Facility | 2010-10-12 | Routine/Complete Inspection | Violation(s) Noted | Inspected well head. Cellar has 1' water in bottom. Observed gas coming to surface on outside of 13 3/8" casing. Well is shut in and has not been fracced yet. Operator was notified of condition on 10/8/10 after DEP inspector McShea visited the site. |
| 1938962 | Primary Facility | 2010-12-21 | Follow-up Inspection | No Violations Noted | Met John Hafer of Cummings Riter on site. PErforming 24 hr pressure test on 9 5/8" and 13 3/8" annulus's. Shut in started at 11:00. |
| 2009105 | Primary Facility | 2011-09-12 | Routine/Complete Inspection | No Violations Noted | |
| 2327702 | Primary Facility | 2014-11-25 | Routine/Partial Inspection | No Violations Noted | release occurred at 2:58 AM on 11/25/14. Originally staff estimated that 20 bbl. were lost but after they calculated loss it was 8.6 bbl. so they re-estimated 8-10bbl of synthetic oil based drill mud (Invert). The Patterson 254 rig was on site drilling the Kerr Unit 3H well when the release occurred. It was reported that the hose ruptured releasing the product onto the cage and barrier on the well site. Originally, an estimated 2 bbl. were released to the well site and the remainder was to containment. When the Department made the site visit, Mr. Vales explained that the thinks it was less than a gallon that reached the well site. The impacted area was reported as being a 1’X3’X1” section of pad. Chief explained that they immediately shut down the rig and began to contain the material. Southland was hired to pressure wash the area and Patrik’s Vacuum and Wash Services LTD. Was hired to vacuum the site. |
| 2443003 | Primary Facility | 2016-01-20 | Incident- Response to Accident or Event | No Violations Noted | Arrived at site at 12:00 in response to an estimated (8-10) barrel spill to secondary containment of a combination of freshwater and re-use water. Universal Well Services is the subcontractor for Chief performing hydraulic fracturing operations. According to Chief Personnel on-site, Universal is on the 18th stage of frac operations on the 3H well and frac operations should be completed for the well tomorrow, 1/21/16. The Kerr 1H, 2H and 3V wells were in production, but are currently shut in. The spill occurred during the 17th stage of the frac. The result of the spill was sand washing out an elbow/90 degree joint of the iron flow line while under pressure. Fluid was released out of the flow pipe onto containment as the sand wore away the pipe. The reuse water is production fluid from other Chief Well Sites transported to the site via trucks. There was no evidence the fluid spilled escaped containment and impacted the ground surface of the well pad. |
| 2445590 | Primary Facility | 2016-01-28 | Routine/Complete Inspection | No Violations Noted | On 1/28/2016, the Department conducted an inspection of the Chief Kerr Unit Well Pad in response to a complaint that hydraulic fracturing activities currently occurring on this pad are causing the ground to vibrate off-site and that the noise levels from the pad activity are extremely loud. Upon arrival at the site, I parked at the entrance to the well pad just off the side of the Dimock to Nicholson Road. The well pad is approximately 300’ from the road. During the inspection, the operation was pressured up with an active frac job occurring. The noise levels experienced from my location at the entrance was not unusual for this type of operation and did not reach a level which I felt required hearing protection. No vibrations were felt while standing at the access road entrance. No action is required of Chief for this complaint at this time. |
| 2445689 | Primary Facility | 2016-01-25 | Routine/Complete Inspection | No Violations Noted | Inspection in response to an estimated 25-gallon spill of a combination of freshwater and re-use water. I was accompanied by Jon Sassi, DEP Environmental Protection Specialist. Rich Adams of Chief Oil and Gas contacted the Department approximately 3PM on Friday, January 22, 2016 to report the spill. Mr. Adams reported that an estimated 25 gallons of a combination of fresh and brine water was spilled onto the dirt/gravel of the access road to the Kerr Unit Pad while moving equipment during fracking operations due to a missing or uninstalled cap. I contacted Mr. Adams via telephone for more information upon receiving the notification. Mr. Adams confirmed that a combination of fresh/brine water had spilled from equipment (missile) as it was moved onto the incline of the access road. He further stated that clean-up of the spill was underway; affected dirt and gravel was being removed from the access road and stock piled onto containment. Violations were immediately corrected. Violation were to the 3H well, in |
| 2473892 | Primary Facility | 2016-03-24 | Routine/Complete Inspection | No Violations Noted | Inspection of the Kerr Unit Pad in conjunction with the Notice of Termination inspection for the Kerr B Lateral Pipeline. Crews were removing containment and equipment from the recent fracking of the 3H and 4H wells. There were two spills reported to the Department during these fracking operations. One occurred on the pad itself on January 19, 2016 when an elbow on frack piping ruptured during fracking of the 3H, and the other occurred on January 22, 2016 on the access road of the pad while moving equipment around in preparation of the 4H. The Department responded to both incidents. No staining or other indications of soil impact was noticed during a quick observation of the pad in the area of the spill, but there was still some containment and equipment staged on the pad so the area could not be fully assessed at the time of the inspection. |
| 2502539 | Primary Facility | 2016-07-11 | Routine/Complete Inspection | No Violations Noted | |
| 2544725 | Primary Facility | 2016-11-22 | Routine/Complete Inspection | No Violations Noted | The Department was on site to conduct a routine complete inspection of the Kerr Unit 1H-3H well site (ESX11-115-0031).
The wells associated with this site are as follows: 115-20212 115-20276 115-20377 115-21772 115-21773 The Kerr site is an older site, and was stable and vegetated well. There were no erosional problems with the site at this time and the site appeared to be built to specification. There are no violations. If there are any questions, feel free to contact me at (570)346-5539 |
| 2709066 | Primary Facility | 2018-03-14 | Routine/Complete Inspection | No Violations Noted | Arrived at site at: 09:00. Weather: Light snow, cold, ~25 degs. Onsite in response to application received for Reg. Inactive Status for the 2H well on this pad. A total of (5) wells have been drilled on this pad. The 1H, 3H &4H wells were in production. The 2H and 3V were shut-in at time of inspection. The 3V well was put on Reg. Inactive Status on 9/20/16. All (5) wells had prod. trees "PT" installed atop wellheads. The 1H, 2H, 3H &4H were tied into production units. Prod. tree top press. "PTTP", Prod. casing press. "PCP" and Prod. line press. "PLP", were being monitored by wireless data sending units and/or analog gauges. The 1H, 3H and 4H wells had (2) annular vents present at the (9x5) and (13x9) annuli. These wells (9x5) vents were open and venting to shared poly vent tanks. The 3H and 4H wells had (13x9) vents open and venting to shared poly tanks. The 1H wells (13x9) annulus was shut-in at time of inspection. The 2H well had (1) annular vent present at the (9x5) annulus and was open and venting to sha |
| 2828103 | Primary Facility | 2019-01-14 | Routine/Complete Inspection | No Violations Noted | I performed a RTNC inspection of the Kerr well pad. The weather was sunny, cloudless and cold, at around 17 degrees F.
The entrance was in good shape, as was the access road. They were both in good shape and solid with no rills or erosional problems noted. The cut and fill slopes were well vegetated. The vegetation was healthy and quite thick. There were a few personal items from the landowner staged on the wellpad. There was some activity in the compressor station but there did not appear to any detrimental effects to the pad surface. The erosion and sedimentation log was up so date and there were no erosional issuesnoted there. There were no violations noted. |
| Inspection ID | Violation ID | Violation Date | Date Resolved | Violation Code | Violation Type | Violation Comments |
|---|---|---|---|---|---|---|
| 1919700 | 597191 | 10/12/2010 | 2010-10-12 | 78.86* - Failure to report defective, insufficient, or improperly cemented casing w/in 24 hrs or submit plan to correct w/in 30 days | Administrative | |
| 1919700 | 597192 | 10/12/2010 | 2010-10-12 | 207B - Failure to case and cement to prevent migrations into fresh groundwater | Environmental Health & Safety |
| Violation ID | Penalty ID | Penalty Code | Penalty Status | Penalty Date | Enforcement Date | Penalty Amount | Amount Collected |
|---|---|---|---|---|---|---|---|
| 597191 | 265522 | NOV - Notice of Violation | |||||
| 597192 | 265522 | NOV - Notice of Violation |
For data sources see[9]