37-113-20284

Well Details

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Country: United States
State: Pennsylvania
County: Sullivan
Municipality: Cherry Township
Operator Name: CHIEF OIL & GAS LLC
Well Pad ID: 148383
Farm/Lease Name: G & S BIG RIGGER UNIT 5H
License Status: Active
Spud Date: 2014-07-27
Permit Date: 2014-05-19
Unconventional Well: Y
Configuration: Horizontal Well
Latitude: 41.531208
Longitude: -76.462894

For data sources see

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	2016-08-08	2016-08-17	7900	5,632,270.0	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	Sargent/Unimin	Proppant		Listed Below
	Water	Chief Oil & Gas	Base Fluid		Listed Below
	EC6486A	Nalco Champion	Scale Inhibitor		Listed Below
	Unihib G	GeoSafe	Acid Inhibitor		Listed Below
	Hydrochloric Acid (15%)	PVS	Acidizing		Listed Below
				Ethanol, 2,2',2-nitrilotris-, 1,1',1-tris(dihydrogen phosphate), sodium salt	68171-29-9	30	0.00163	894
				Distillate, petroleum, hydrotreated, light	64742-47-8	30	0.01993	10962
				Crystallilne silica	14808-60-7	100	14.3128	7,873,900.0
				Acetophenone	98-86-2	1	0.00000100	1
				Ethoxylated (C10-16) alcohols	68002-97-1	35	0.00005000	25
				Glutaraldehyde	111-30-8	5	0.00128	702
				Water	7732-18-5	100	85.4367	47,001,300.0
				Quaternary ammonium compound	68424-85-1	10	0.00255	1404
				Ethylene glycol	107-21-1	30	0.00163	894
				Ammonium acetate	631-61-8	13	0.00863	4750
				Formaldehyde	50-00-0	1	0.00000100	1
				Diethylene glycol mono-n-butyl ether	112-34-5	60	0.00008000	43
				Thiourea	62-56-6	1	0.00000100	1
				Alcohols, (C10-16), ethoxylated	68002-97-1	5	0.00332	1827
				Alcohols, C12-14, ethoxylated	68439-50-9	5	0.00332	1827
				Alcohols, C12-16, ethoxylated	68551-12-2	5	0.00332	1827
				Methanol	67-56-1	5	0.00001000	4
				Ethanol	64-17-5	5	0.00128	702
				Hydrochloric acid	7647-01-0	15	0.02296	12629
	Bactron K-139	Nalco Champion	Biocide		Listed Below
	Unislick ST-50	CESI Chemical	Friction Reducer		Listed Below

For data sources see

Production Data

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	604,628.76	113	0.00	0	0.00	0
2017	CHIEF OIL & GAS LLC	870,465.74	352	0.00	0	0.00	0
2018	CHIEF OIL & GAS LLC	439,577.13	363	0.00	0	0.00	0
2019	CHIEF OIL & GAS LLC	85,605.24	90	0.00	0	0.00	0

For data sources see

Waste Data

Period	Waste Type	Quantity	Disposal Method	Waste Facility ID
2014-S02	Drill Cuttings (in Tons)	119.73 Tons	LANDFILL	100933
2014-S02	Drill Cuttings (in Tons)	331.78 Tons	LANDFILL	301358
2014-S02	Drilling Fluid Waste (in Barrels)	1,236.19 Bbl	RESIDUAL WASTE PROC FAC (GENERAL PERMIT)	WMGR123
2015-S01	Drill Cuttings (in Tons)	113.85 Tons	LANDFILL	100933
2015-S01	Drill Cuttings (in Tons)	167.08 Tons	LANDFILL	301358
2015-S01	Drilling Fluid Waste (in Barrels)	660.00 Bbl	RESIDUAL WASTE PROC FAC (GENERAL PERMIT)	WMGR123
2016-S02	Fracturing Fluid Waste (in Barrels) RWC 805	192.00 Bbl	RESIDUAL WASTE PROC FAC (GENERAL PERMIT)	WMGR123
2016-S02	Fracturing Fluid Waste (in Barrels) RWC 805	8,907.14 Bbl	REUSE OTHER THAN ROAD SPREADING
2016-S02	Produced Fluid (in Barrels) RWC 802	13,346.07 Bbl	REUSE OTHER THAN ROAD SPREADING
2017-M01	Produced Fluid (in Barrels) RWC 802	85.00 Bbl	RESIDUAL WASTE PROCESSING FACILITY	WMGR123
2017-M02	Produced Fluid (in Barrels) RWC 802	249.39 Bbl	REUSE (AT WELL PAD)
2017-M03	Produced Fluid (in Barrels) RWC 802	214.32 Bbl	REUSE (AT WELL PAD)
2017-M04	Produced Fluid (in Barrels) RWC 802	296.85 Bbl	REUSE (AT WELL PAD)
2017-M05	Produced Fluid (in Barrels) RWC 802	154.68 Bbl	REUSE (AT WELL PAD)
2017-M06	Produced Fluid (in Barrels) RWC 802	150.85 Bbl	REUSE (AT WELL PAD)
2017-M07	Produced Fluid (in Barrels) RWC 802	165.06 Bbl	REUSE (AT WELL PAD)
2017-M08	Produced Fluid (in Barrels) RWC 802	435.02 Bbl	REUSE (AT WELL PAD)
2017-M09	Produced Fluid (in Barrels) RWC 802	183.70 Bbl	REUSE (AT WELL PAD)
2017-M10	Produced Fluid (in Barrels) RWC 802	88.80 Bbl	REUSE (AT WELL PAD)
2017-M11	Produced Fluid (in Barrels) RWC 802	161.58 Bbl	REUSE (AT WELL PAD)
2017-M12	Produced Fluid (in Barrels) RWC 802	166.61 Bbl	REUSE (AT WELL PAD)
2018-M01	Produced Fluid (in Barrels) RWC 802	320.65 Bbl	REUSE (AT WELL PAD)
2018-M02	Produced Fluid (in Barrels) RWC 802	273.90 Bbl	REUSE (AT WELL PAD)
2018-M03	Produced Fluid (in Barrels) RWC 802	149.46 Bbl	REUSE (AT WELL PAD)
2018-M04	Produced Fluid (in Barrels) RWC 802	225.47 Bbl	REUSE (AT WELL PAD)
2018-M05	Produced Fluid (in Barrels) RWC 802	231.29 Bbl	REUSE (AT WELL PAD)
2018-M06	Produced Fluid (in Barrels) RWC 802	76.81 Bbl	REUSE (AT WELL PAD)
2018-M07	Produced Fluid (in Barrels) RWC 802	129.43 Bbl	REUSE (AT WELL PAD)
2018-M08	Produced Fluid (in Barrels) RWC 802	126.91 Bbl	REUSE (AT WELL PAD)
2018-M10	Produced Fluid (in Barrels) RWC 802	94.36 Bbl	REUSE (AT WELL PAD)
2018-M11	Produced Fluid (in Barrels) RWC 802	198.73 Bbl	REUSE (AT WELL PAD)
2018-M12	Produced Fluid (in Barrels) RWC 802	190.35 Bbl	REUSE (AT WELL PAD)
2019-M01	Produced Fluid (in Barrels) RWC 802	212.06 Bbl	REUSE (AT WELL PAD)
2019-M02	Produced Fluid (in Barrels) RWC 802	189.53 Bbl	REUSE (AT WELL PAD)
2019-M03	Produced Fluid (in Barrels) RWC 802	190.33 Bbl	REUSE (AT WELL PAD)

For data sources see

Inspection Data

Inspections Performed

Inspection ID	Inspection Category	Inspection Date	Inspection Type	Inspection Result	Inspection Comments
2291997	Primary Facility	2014-07-31	Routine/Complete Inspection	No Violations Noted
2293702	Primary Facility	2014-08-06	Drilling/Alteration	No Violations Noted
2300875	Primary Facility	2014-09-03	Routine/Complete Inspection	No Violations Noted
2330188	Primary Facility	2014-12-05	Routine/Complete Inspection	No Violations Noted
2330338	Primary Facility	2014-12-08	Routine/Complete Inspection	No Violations Noted
2353823	Primary Facility	2015-03-19	Routine/Complete Inspection	No Violations Noted	Arrived on 3/19/15 @ 9:30, cold, windy, sunny. With me were OGIs Ken Kennedy, Joe Gaboff, and David Schoonover. There are 6 wells on the pad. The 1H was previously drilled and had been in production for some time. The 2H-6H were drilled to TD during 12/14. 2H, 9-5/8” x 5-1/2” - 35% methane, measureable flow, 6H: 9-5/8” x 5-1/2” - 21% methane, cement tops are down. Other annuli: 0 at the time of this inspeciton. The liner was still in place on the messy location.
2363817	Primary Facility	2015-04-01	Follow-up Inspection	No Violations Noted	115-hr shut-in pressure test.
2378135	Primary Facility	2015-06-09	Follow-up Inspection	No Violations Noted	Arrived @ 11:00. Weather: thunder storms last night and today. Met with Chief’s Jon Hafer to begin 72-hour pressure build-up test. Heavy rain made setting up a challenge. Continuous pressure loggers were installed on the 13-3/8” x 9-5/8” and 9-5/8” x 5-1/2” annular vents for the 2H, 3H, 4H, 5H, and 6H wells. The loggers were set to begin taking readings at 13:00. To ensure that pressures did not exceed regulatory limits, Hafer planned to visit the location each day. The 1H, drilled previously was in production.
2379024	Primary Facility	2015-06-09	Follow-up Inspection	No Violations Noted	Arrived @ 11:00. Weather: thunder storms last night and today. Met Jon Hafer to begin 72-hour pressure build-up test for the G&S Big Rigger 2H, 3H, 4H, 5H, and 6H wells. Annuli were open with vents plumbed to polytanks prior to the start of the test. Gas was detected at the polytank for the 2H and 4 H wells, and the tank for the 6H (4% methane). Gas was not detected at the tank for the 3H and 5H at the time of my inspection. On the 6H, the annular vent pipe configuration required some modification prior to shut-in. Hafer plans to check daily to ensure pressure on the 6H 13-3/8” x 9-5/8” does not exceed regulatory limits. The 1H, in production, appeared to be discharging more fluid and gas than seen on previous inspections from its annular vents to its polytank (5% methane detected at polytank). There were not enough pressure loggers to include the 1H in this pressure build up test.
2379220	Primary Facility	2015-05-29	Follow-up Inspection	No Violations Noted	Arrived @ 10:00. Weather: sunny, hot and breezy. Already onsite was DEP OGI Ken Kennedy, Team rig crew and Baker Hughes crew. Met with company man Floyd Roberts. Freepoint on 6H determined to be 1550’, approximately 40’ below the intermediate casing shoe. Discussed pros and cons of conducting planned remediation at this depth. At approximately 15:00, Chief decided to cancel proposed remediation. Staff begain preparations to rig down and travel to Woodlands Unit A location to drill out plugs. Left location at approximately 15:30.
2379251	Primary Facility	2015-06-10	Follow-up Inspection	No Violations Noted	: Arrived @ 15:00. Weather hot and humid. Annuli on G&S Big Rigger 2H, 3H, 4H, 5H, 6H shut-in for pressure build-up test. Purpose of inspection to check pressure build up on 6H annuli. After 26 hours 9-5/8” x 5-1/2” annulus at 132.85 psig. 13-3/8” x 9-5/8”, slight pressure build. Left @15:45.
2379335	Primary Facility	2015-06-15	Follow-up Inspection	No Violations Noted	Arrived @ 10:45. Cloudy, hot, humid, sticky with occasional cloud bursts. Met with Jon Hafer and DEP Mineral Resource Program Specialist Rick Swank to try to conduct annular flow measurements. 9-5/8” x 5-1/2” annulus on 6H measured 0.09 inches of water using the 1/8” orifice plate. This measurement was consistent on both Hafer’s and Swank’s digital meters. The DEP analogue meter which measures 0-10 inches of water was not sufficiently sensitive to measure this flow. At the conclusion of the pressure build up test for the 6H, leaks in some of the well head seals were discovered. As a result Chief intends to do another pressure build up test for the 6H. Left location at 12:46.
2405586	Primary Facility	2015-09-02	Drilling/Alteration	No Violations Noted	replacing well head on 6H
2405946	Primary Facility	2015-09-09	Routine/Complete Inspection	No Violations Noted	5H well shut in drilled to TD. 13x9, and 9x5 annuli venting to polytank, 0% methane.
2406722	Primary Facility	2015-09-11	Routine/Complete Inspection	No Violations Noted	13x9 0% LEL, 9x5: 5% LEL, no samples.
2427990	Primary Facility	2015-11-24	Routine/Complete Inspection	No Violations Noted	Arrived 11:30, cloudy and cold. There are 6 wells on the location. The G&S Big Rigger 1H is in production. The other wells have been TD’ed but not hydraulically stimulated. There is liner on the pad location.
2480042	Primary Facility	2016-04-27	Drilling/Alteration	No Violations Noted	Arrived @ 9:45. Weather sunny. Met with Jon Hafer (Chief). The purpose of this inspection was to observe the shut-in flow rate testing being conducted on the 6 G&S Big Rigger wells. At the time of my inspection the shut-in test on the G&S Big Rigger 3H was being concluded. The shut-in well was fitted with continuous pressure loggers and remote read transducers. At the conclusion of the test, these devices were transferred to the G&S Big Rigger 1H. The annular vents were shut but the well remained in production. G&S Big Rigger 5H: During the shut-in pressure build-up test for the G&S Big Rigger 3H, the flow rates at 13-3/8” x 9-5/8” and 9-5/8” x 5-1/2” annular vents were less than 5.28 scf/day. Left location @ 12:40.
2493868	Primary Facility	2016-06-06	Routine/Complete Inspection	No Violations Noted
2499395	Primary Facility	2016-06-30	Routine/Complete Inspection	No Violations Noted	Arrived @ 13:30. Weather: sunny, low humidity, warm. Met with Jon Hafer and Floyd Roberts (Chief). The purpose of this inspection was to check on progress with frac monitoring and long-term annular pressure monitoring. The G&S Big Rigger 2H-6H wells were being prepared for toe prep. At the time of my inspection staffers were waiting for a replacement seal assembly for the 6H because one of the seals was split. The seal was examined because pressure on the 6H’s 5-1/2” casing was encountered when the blind flange was removed. B-sections on several well heads had also been replaced due to seat ring pitting which was observed after the blind flanges were removed. These activities compromised the conclusion of the long-term annular pressure monitoring project. The inspection result is OUTNO because the presence of methane at the 13-3/8” x 9-5/8” annulus of the G&S Big Rigger 1H was noted in a 9/11/15 inspection report (IR# 2406714) . No new violations were noted at the time of this inspection. Left location
2499459	Primary Facility	2016-07-01	Routine/Complete Inspection	No Violations Noted
2503161	Primary Facility	2016-07-12	Drilling/Alteration	Outstanding Violations - No Viols Req'd	Arrived @ 08:40. Weather: sunny and hot. Met with Jon Hafer and company man Floyd Roberts (Chief) who were making preparations to begin temperature and acoustic logging on the G&S Big Rigger 6H. Also onsite were Renagade (slickline) and EXPRO (logging). EXPRO was using a high-precision temperature and spectral noise logger (HPT-SNL) made by TGT. The tool was described as capturing 100-60,000 Hz noise with a hydrophone that detects signal at a radius of 15’.
2503259	Primary Facility	2016-07-13	Drilling/Alteration	Outstanding Violations - No Viols Req'd
2503282	Primary Facility	2016-07-15	Drilling/Alteration	Outstanding Violations - No Viols Req'd
2508095	Primary Facility	2016-08-05	Routine/Complete Inspection	No Violations Noted	Routine inspection to assess overall site conditions relating to erosion and sediment control and frack set-up. Vegetative cover on site is greater than 70% perennial vegetation; all temporary E&S control BMPs have been removed. no evidence of accelerated erosion or sedimentation was observed. Set up for upcoming well completions appears to be largely complete. All containments on site were checked and appeared to be in good repair and installed properly. The brine tanks and chemicals on site are in secondary containment in addition to the primary pad liner that has been installed for the well completions. A large temporary impoundment for freshwater has been installed on site. No violations were cited during this inspection.
2509305	Primary Facility	2016-08-09	Routine/Complete Inspection	No Violations Noted	Routine inspection to assess hydraulic fracturing operations. Jon Hafer of Chief was present during the inspection. All equiment and amterials on site were within containment. No evidence of spills was observed during the inspection. Three barrels marked "waste fuel" and several other containers were observed within a small secondary containment not appropriately sized to contain the volume of the barrels and containers. Though the barrels were empty at the time, it was advised that they should be placed in containment that would adequately hold the volume of fluid that could potentially be placed in the barrells. During the inspection a seal on piping connecting to one of the wells failed. At the time, the well was not pressurized and only a minimal amount of fluid was released to the containment surrounding the well head. No fluid left containment. Repairs on the seal commmenced immediately. No violations were cited during this inspection.
2514679	Primary Facility	2016-08-16	Drilling/Alteration	No Violations Noted	: Arrived @ 10:55. Weather: hot, humid, with rain and threat of rain. Hydraulic fracturing operations were ongoing at the time of my inspection. Universal was handling the frac with Cased Hole Solutions handling the wire line. The purpose of my inspection was to check on the frac and document arrangements for monitoring annular pressures on wells that were not being pumped. I met with company man Brett Fowler (Chief). He reported that the zipper frac involving the three wells with northwest trending laterals: G&S Big Rigger 4H, 5H, and 6H, was at approximately stage 20-21 out of 27 stages on each of the wells and was scheduled to be finished tomorrow. The 2 wells with southeast-trending laterals: G&S Big Rigger 2H, and 3H, would be fracced next. During these operations the G&S Big Rigger 1H, a producing well, was shut-in.
2514680	Primary Facility	2016-08-16	Drilling/Alteration	Outstanding Violations - No Viols Req'd	Arrived @ 10:55. Weather: hot, humid, with rain and threat of rain. Hydraulic fracturing operations were ongoing at the time of my inspection. Universal was handling the frac with Cased Hole Solutions handling the wire line. The purpose of my inspection was to check on the frac and document arrangements for monitoring annular pressures on wells that were not being pumped. I met with company man Brett Fowler (Chief). He reported that the zipper frac involving the three wells with northwest trending laterals: G&S Big Rigger 4H, 5H, and 6H, was at approximately stage 20-21 out of 27 stages on each of the wells and was scheduled to be finished tomorrow. The 2 wells with southeast-trending laterals: G&S Big Rigger 2H, and 3H, would be fracced next. During these operations the G&S Big Rigger 1H, a producing well, was shut-in.
2514894	Primary Facility	2016-08-24	Drilling/Alteration	No Violations Noted	Arrived @ 13:54. Weather: hot. Hydraulic fracturing operations were ongoing at the time of my inspection. Universal was handling the frac with Cased Hole Solutions handling the wire line. The purpose of my inspection was to check on the frac and follow-up on Chief’s 08/23/16 report of a possible communication between the frac on the G&S Big Rigger 3H and Chief’s Dacheux 3H, a producing well whose lateral was located approximately 9,300’ away from the G&S Big Rigger 3H lateral. I met with company man Brett Fowler (Chief), who said he knew nothing about the possible communication and wanted me to talk to his boss, Ted Balch (Chief Completions Superintendent). Following the phone calls I asked Mr. Fowler about the on-going operations. He told me that, at the time of my inspection they were approximately 1 hour into fraccing stage 21 stage of the G&S Big Rigger 3H, and finishing the stage would require approximately another hour. There would be a total of 29 stages. Afterward they would frac stage 21 of the G&S
2517126	Primary Facility	2016-09-07	Routine/Complete Inspection	No Violations Noted
2518942	Primary Facility	2016-09-14	Routine/Complete Inspection	No Violations Noted	Routine site inspection to assess overall site conditions post-completion of wells. All equipment and tanks on site were within containment. Fluid in the containment surrounding the brine tanks being used for flowback was screened for electrical conductivity and registered 8.0 mS/cm using a Oakton handheld meter. Several puddles were present along the east edge of the well pad. The electrical conductivity of these puddles was also screened, and yeiled results of 2.4 and 3.4 mS/cm. A sample of the puddle with the 3.4 mS/cm electrical conductivity was collected for laboratory analysis. No obvious staining was observed on the pad surface that could indicate a spill. No stressed or dead vegetation was observed in the areas surrounding the well site. No violations were cited during this inspection.
2535220	Primary Facility	2016-10-27	Follow-up Inspection	No Violations Noted	Follow-up inspection conducted after receiving laboratory analysis of fluid samples collected during last inspection (Inspection ID No. 2518947, September 14, 2016). No Chief representatives were present during the inspection. During the September 14, 2016 inspection, fluid samples were collected from a puddle on the well pad in response to field electrical conductivity readings of 3.4 mS/cm. The puddle was located along the east edge of the well pad. No sheen was present on the puddle, and no staining or odors were observed. Chief was notified of these findings, and had all puddles on the pad vacuumed and removed. The laboratory analysis (SAC 942) indicates elevated levels of chlorides (1,713.1 mg/L), strontium (25,830 ug/L), iron (1,130 mg/L), total dissolved solids (3,050 mg/L), and manganese (22.55 mg/L). Elevated levels of these constituents indicate that a release of produced water or flowback occurred on the well site. Electrical conductivity was screened in the same area where the elevated re
2543630	Primary Facility	2016-12-01	Routine/Complete Inspection	No Violations Noted	Arrived @ 10:00. Weather: cloudy, pad was wet with rain from the previous day. Met briefly with Shannon Burrell (EHS) who was checking PCSW basins. There were parcels of apparently used containment on the northwest corner of the pad. Shannon indicated these would be removed. 1H in production. Top gauge: 1500 psi (0-10,000, analog) 2H in production. Top gauge: 1550 psi (0-5,000, analog) 3H in production. Top gauge: 2000 psi (0-5,000, analog), cellar water has sheen 4H in production. Top gauge: 1200 psi (0-5,000, analog) 5H in production. Top gauge: 1200 psi (0-5,000, analog) 6H in production. Top gauge: 1500 psi (0-5,000, analog), PBT ongoing.
2703133	Primary Facility	2018-03-09	Routine/Complete Inspection	No Violations Noted	Six wells staged for production phase. Six each water separators. Dump lines wrapped in insulating blanket. No leaks detected from production equipment. Methanol tanks located near well heads. No violations noted.
2708122	Primary Facility	2018-03-21	Routine/Complete Inspection	No Violations Noted	Arrived @ 12:00. Weather: cold, windy, overcast. All 6 wells were in production at the time of my inspection. All well cellars were full and iced over. No methane was detected at the polytanks which vent the annuli.
2798238	Primary Facility	2018-11-02	Routine/Complete Inspection	No Violations Noted	Chief Oil & Gas submitted a Notice of Termination (NOT) for the G&S Big Rigger pad covered under ESG29-113-17-0006. The NOT was received by the Department on 10/25/18. Arrived onsite at 12:06, it was ~60°F, overcast, and breezy. The gate was open when I arrived. Due to recent rainfall there was a large number of puddles on the pad surface. Several of the puddles were screened for conductivity. All readings were below 160 µS/cm. There were 6 steel produced water tanks onsite and in secondary containment. The conductivity of water in secondary containment around the tanks was 1,670 µS/cm. There were 6 GPUs onsite and in secondary containment; conductivity of water in secondary containment was 67.7 µS/cm. There were also 6 wells staged for production onsite. All 6 well cellars were filled with water; no bubbling was observed. Two infiltrations basins have been constructed as PCSM. The basins appeared to be constructed according to site plans and function as designed. Both contained water due to recent rainf

For data sources see