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| Well ID: 37-081-21484 | Loading map...
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| Country: United States | |
| State: Pennsylvania | |
| County: Lycoming | |
| Municipality: McNett Township | |
| Operator Name: CHIEF OIL & GAS LLC | |
| Well Pad ID: 151059 | |
| Farm/Lease Name: BAUMUNK SOUTH A UNIT 4H | |
| License Status: | |
| Spud Date: | |
| Permit Date: 2014-07-18 | |
| Well Type: GAS | |
| Unconventional Well: Y | |
| Configuration: Horizontal Well | |
| Conservation: No | |
| Latitude: 41.554442 | |
| Longitude: -76.808381 |
| Date | Event |
|---|---|
| 2014-07-18 | New Permit Application |
| 2014-08-02 | Performed Spud Operation |
| 2014-12-09 | Drilling Completion |
| 2015-02-05 | Perforation |
| 2015-05-13 | 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 | 2015-02-06 | 2015-02-06 | 8,607 | 891,900 | |
| 2 | 2016-12-21 | 2016-12-27 | 8,607 | 7,413,710 | 0 |
| Job Number | Trade Name | Supplier | Purpose | Ingredient Name | CAS Number | Additive Percentage by Mass | Job Percentage by Mass | Mass Used (lb) |
|---|---|---|---|---|---|---|---|---|
| 1 | Unislik ST 50 | Universal | Friction Reducer | Petroleum distillates, hydrotreated light | 64742-47-8 | 30 | 0.03 | 0 |
| Hydrochloric Acid | Universal | Acid | Hydrochloric Acid | 7647-01-0 | 37 | 0.07 | 0 | |
| Bactron K-139 | Champion Technologies | Biocide | Glutaraldehyde | 111-30-8 | 5 | 0.002 | 0 | |
| Quaternary ammonium compounds, benzyl-C-12-16 alkyldimethyl, chlorides |
68424-85-1 | 10 | 0.004 | 0 | ||||
| Ethanol | 64-17-5 | 5 | 0.002 | 0 | ||||
| Gyptron T-390 | Champion Technologies | Scale Inhibitor | Methanol | 67-56-1 | 10 | 0.0003 | 0 | |
| Water | Provided by Customer | Base Fluid | Fresh Water | 0000-00-0 | 100 | 99.8952 | 0 | |
| 2 | Bactron K-139 | Nalco Champion | Biocide | Listed Below | ||||
| KAI-13 | Keane | Acid Inhibitor | Listed Below | |||||
| Water | Chief Oil & Gas | Carrier/Base Fluid | Listed Below | |||||
| Hydrochloric Acid (15%) | Keane | Acidizing | Listed Below | |||||
| KFR-20 | Keane | Friction Reducer | Listed Below | |||||
| Formic acid | 64-18-6 | 10 | 0.00004000 | 25 | ||||
| Ethylene glycol | 107-21-1 | 30 | 0.00148 | 1058 | ||||
| Tar bases, quinoline derivs, benzyl chloride-quaternized | 72480-70-7 | 10 | 0.00004000 | 25 | ||||
| 2- Propanol | 67-63-0 | 5 | 0.00002000 | 13 | ||||
| (Mineral oil) Light hydrotreated petroleum distillate | 64742-47-8 | 20 | 0.01221 | 8697 | ||||
| Water | 7732-18-5 | 40 | 0.00868 | 6184 | ||||
| Quaternary ammonium compound | 68424-85-1 | 10 | 0.00217 | 1546 | ||||
| Water | 7732-18-5 | 40 | 0.00198 | 1410 | ||||
| Hydrochloric acid | 7647-01-0 | 15 | 0.0208 | 14821 | ||||
| Glutaraldehyde | 111-30-8 | 5 | 0.00108 | 773 | ||||
| Water | 7732-18-5 | 100 | 86.8271 | 618,674,000.0 | ||||
| Crystallilne silica | 14808-60-7 | 100 | 12.9462 | 9,224,660.0 | ||||
| Alcohols, C12-16, ethoxylated | 68551-12-2 | 2 | 0.00122 | 870 | ||||
| Methanol | 67-56-1 | 45 | 0.00976 | 6958 | ||||
| Cinnamaldehyde | 104-55-2 | 10 | 0.00004000 | 25 | ||||
| Alcohols, C12-15 linear, ethoxylated | 68131-39-5 | 10 | 0.00004000 | 25 | ||||
| N,N-Diethanololeamide | 93-83-4 | 2 | 0.00122 | 870 | ||||
| 1,2- Ethanediol | 107-21-1 | 40 | 0.00014 | 102 | ||||
| Ethanol, 2,2',2"-nitrilotris-, tris(dihydrogen phosphate) (ester), sodium salt |
68171-29-9 | 30 | 0.00148 | 1058 | ||||
| Ethanaminium, N,N,N-trimethyl-2-((1-oxo-2-propenyl)oxy)-, chloride, polymer with 2-propenamide |
69418-26-4 | 30 | 0.01831 | 13045 | ||||
| Water | 7732-18-5 | 85 | 0.11787 | 83985 | ||||
| Dipropylene glycol monomethyl ether | 34590-94-8 | 20 | 0.00007000 | 51 | ||||
| Sand | Keane | Proppant | Listed Below | |||||
| EC6486A | Nalco Champion | Scale Inhibitor | Listed Below |
For data sources see[5]
| Period | Operator Name | Gas Quantity (mcf) | Gas Production Days | Oil Quantity (bbl) | Oil Production Days | Water Quantity (bbl) | Water Production Days |
|---|---|---|---|---|---|---|---|
| 2014 | CHIEF OIL & GAS LLC | 0.00 | 0 | 0.00 | 0 | 0.00 | 0 |
| 2015 | CHIEF OIL & GAS LLC | 0.00 | 0 | 0.00 | 0 | 0.00 | 0 |
| 2016 | CHIEF OIL & GAS LLC | 71,165.74 | 190 | 0.00 | 0 | 0.00 | 0 |
| 2017 | CHIEF OIL & GAS LLC | 1,491,512.79 | 356 | 0.00 | 0 | 0.00 | 0 |
| 2018 | CHIEF OIL & GAS LLC | 573,672.84 | 364 | 0.00 | 0 | 0.00 | 0 |
| 2019 | CHIEF OIL & GAS LLC | 310,638.41 | 364 | 0.00 | 0 | 0.00 | 0 |
For data sources see[6]
| Period | Operator | Waste Type | Quantity | Disposal Method | Waste Facility ID |
|---|---|---|---|---|---|
| 2014 | CHIEF OIL & GAS LLC | Drilling Fluid Waste | 106.02 Bbl | RESIDUAL WASTE PROC FAC (GENERAL PERMIT) | WMGR123SW018 |
| 2014 | CHIEF OIL & GAS LLC | Drilling Fluid Waste | 1,869.71 Bbl | RESIDUAL WASTE PROC FAC (GENERAL PERMIT) | WMGR123 |
| 2014 | CHIEF OIL & GAS LLC | Drill Cuttings | 1,149.81 Tons | LANDFILL | 301358 |
| 2015 | CHIEF OIL & GAS LLC | Fracing Fluid Waste | 2,102.33 Bbl | REUSE OTHER THAN ROAD SPREADING | |
| 2015 | CHIEF OIL & GAS LLC | Fracing Fluid Waste | 40.00 Bbl | RESIDUAL WASTE PROC FAC (GENERAL PERMIT) | WMGR123 |
| 2016 | CHIEF OIL & GAS LLC | Fracturing Fluid Waste | 280.00 Bbl | RESIDUAL WASTE PROC FAC (GENERAL PERMIT) | WMGR123 |
| 2016 | CHIEF OIL & GAS LLC | Produced Fluid | 4,974.54 Bbl | REUSE OTHER THAN ROAD SPREADING | |
| 2017 | CHIEF OIL & GAS LLC | Produced Fluid | 19,250.29 Bbl | STORAGE PENDING DISPOSAL OR REUSE | |
| 2017 | CHIEF OIL & GAS LLC | Produced Fluid | 6,826.41 Bbl | REUSE (AT WELL PAD) | |
| 2017 | CHIEF OIL & GAS LLC | Produced Fluid | 393.34 Bbl | RESIDUAL WASTE PROCESSING FACILITY | WMGR123 |
| 2018 | CHIEF OIL & GAS LLC | Produced Fluid | 2,608.36 Bbl | REUSE (AT WELL PAD) | |
| 2019 | CHIEF OIL & GAS LLC | Produced Fluid | 3,023.51 Bbl | REUSE (AT WELL PAD) |
For data sources see[7]
| Inspection ID | Inspection Category | Inspection Date | Inspection Type | Inspection Result | Inspection Comments |
|---|---|---|---|---|---|
| 2298083 | Primary Facility | 2014-08-21 | Drilling/Alteration | No Violations Noted | |
| 2306304 | Primary Facility | 2014-09-18 | Routine/Complete Inspection | No Violations Noted | Routine Inspection; 9/18/2014. |
| 2318477 | Primary Facility | 2014-11-04 | Incident- Response to Accident or Event | No Violations Noted | |
| 2343996 | Primary Facility | 2015-02-11 | Incident- Response to Accident or Event | No Violations Noted | 2/6/2015: At 15:20, Chief O&G reported a brine release of 2-3 barrels to containment. The brine was spilled from the blender while toe fracturing the Blanchard Unit 3H (081-21487). Several small holes found in containment were believed to have caused approximately 20-30 gallons of brine to leave containment. 2/11/2015: At 08:30 I met with Kellon Balum (Chief). All equipment from completions was removed from the site except the containment and some frac-tanks in secondary containment. At the southwest corner of the well pad the location of the blender and the release were inspected. Several holes in containment were pointed out by Mr. Balum approximately 10' from the edge of containment. Some visbly impacted snow and ice was observed outside containment. Exact volume is unknown but based on the conditons, the volume estimate appears reasonable. Due to sub-freezing conditions, the release has little chance of migrating further. Violations noted to 081-21487. |
| 2355930 | Primary Facility | 2015-03-27 | Compliance Evaluation | No Violations Noted | On 3/27/2015, I met with Kellon Balum (Chief) and we walked the site. Containment was still covering the area around the wellheads. Field conductivity was approximately 1,000 umhos/cm over the majority of the containment area. The well cellars had hydraulic fluid and friction reducer floating on the surface. Please vacuum the cellars ASAP. |
| 2510123 | Primary Facility | 2016-08-04 | Drilling/Alteration | No Violations Noted | Arrived @ 11:30. Weather: hot and breezy. Coiled tubing rig was onsite, drilling out plugs. Met with Company Man Floyd Roberts. Also onsite was completions supervisor Greg Roher, At the time of my inspection the plugs had been drilled out of the Baumunk South Unit 1H. The rig was running out of the hole, having attempted to tag out at total depth of approximately 14500’. Once work on the Baumunk South Unit 1H was completed, the rig was to drill out plugs in to the other well that had been fracced, the Blanchard Unit 3H. The third well on site, the Baumunk South Unit 4H, had not been fracced. The coiled tubing rig was headed next for the Hemlock Hunk Club. Left location @ 12:08 |
| 2512562 | Primary Facility | 2016-08-17 | Routine/Complete Inspection | No Violations Noted | |
| 2545677 | Primary Facility | 2016-12-15 | Routine/Complete Inspection | No Violations Noted | Routine Complete Inspection; 12/15/2016.
At the time of the inspection the site was covered in snow and temperatures were well below freezing. Personnel onsite were preparing the Baumunk South A Unit 4H (081-21484) to fully complete the well (toe frac previously). The other two wells (081-21487 and 081-21483) onsite were in production. Containment was spread out on the site, frac tanks were placed, and the site was being rigged-up. No Violations Noted. |
| 2566542 | Primary Facility | 2017-02-24 | Routine/Complete Inspection | No Violations Noted | Routine Compete Inspection 2/24/2017.
I entered the site at 13:00. At the time of the inspection, the Blanchard Unit 3H (081-21487), Baumunk South A Unit 4H (081-21484), and Baumunk South B Unit 1H (081-21483) wells were in production. Approximately, 15 empty frac tanks were located on the south (fill) side of the well pad. Field conductivity in puddles on the pad ranged from 536-946 umhos/cm. Field conductivity in the cellars was between 391-445 umhos/cm. PCMS features have been installed and a 2-year extension (delaying restoration) was approved on 2/24/2016. Sediment was being deposited in the infiltration basin from the channel above. I recommend addressing the E&S issues as soon as the weather permits. No Violations Noted. |
| 2676435 | Primary Facility | 2017-12-19 | Routine/Complete Inspection | No Violations Noted | Routine complete inspection.
At the time of the inspection, three wells were in production. Annular vents were plumbed to a poly tank north of the wellheads. Water and biocide were stored on containment south of the wellheads (for injection). Production tanks were in containment and were in good condition. The PSCM features do not appear to be functioning properly (as previously noted) but frozen conditions are not ideal to evaluate infiltration. The 2-year extension on the well site restoration requirement was approved on 2/24/2016 and expires on 2/24/2018; please plan accordingly. No violations noted. |
For data sources see[8]