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37-113-20165

Well Details

Well ID: 37-113-20165
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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
License Status: Active
Spud Date: 2012-08-25
Permit Date: 2012-08-16
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: No
Latitude: 41.531322
Longitude: -76.463003

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

Well History

Date Event
2012-08-16 New Permit Application
2012-08-23 Performed Spud Operation
2012-09-21 Drilling Completion
2013-02-04 Perforation
2013-02-26 Perforation
2013-02-26 Performed Stage 1 of Stimulation
2013-02-26 Performed Stage 2 of Stimulation
2013-02-27 Perforation
2013-02-27 Performed Stage 3 of Stimulation
2013-02-27 Performed Stage 4 of Stimulation
2013-02-27 Performed Stage 5 of Stimulation
2013-02-28 Perforation
2013-02-28 Performed Stage 6 of Stimulation
2013-02-28 Performed Stage 7 of Stimulation
2013-02-28 Performed Stage 8 of Stimulation
2013-03-01 Perforation
2013-03-01 Performed Stage 10 of Stimulation
2013-03-01 Performed Stage 11 of Stimulation
2013-03-01 Performed Stage 9 of Stimulation
2013-03-02 Perforation
2013-03-02 Performed Stage 12 of Stimulation
2013-03-02 Performed Stage 13 of Stimulation
2013-03-02 Performed Stage 14 of Stimulation
2013-03-03 Perforation
2013-03-04 Perforation
2013-03-04 Performed Stage 15 of Stimulation
2013-03-04 Performed Stage 16 of Stimulation
2013-04-23 Perforation
2013-04-23 Performed Stage 17 of Stimulation
2013-04-23 Performed Stage 18 of Stimulation
2013-04-24 Performed Stage 19 of Stimulation
2019-08-01 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 2013-04-24 2013-04-24 7,930 5,346,516

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 BA-40L Halliburton Buffering Agent Potassium carbonate 584-08-7 60.0 0.006
Water 7732-18-5 85.0 None
Alkyl (C12-16) dimethylbenzlammonium chloride 68424-85-1 1.0 None
Quaternary ammonium compounds,
benzyl-C-12-16 alkyldimethyl, chlorides 		68424-85-1 10.0 None
Ethanol 64-17-5 5.0 None
Bactron K-139 Champion Technologies Biocide Glutaraldehyde 111-30-8 5.0 0.06
MCS-2510T Multi-Chem Scale Inhibitor Ethylene Glycol 107-21-1 30.0 0.01
(FRW-66) Halliburton Friction Reducer Hydrotreated Light Distillate 64742-47-8 30.0 0.09
Hydrochloric Acid 28 Halliburton Acid Hydrogen Chloride 7647-01-0 30.0 0.53
MCB-8614 Multi-Chem Biocide Glutaraldehyde 111-30-8 10.0 0.05
Gyptron T-390 Champion Technologies Scale Inhibitor Methanol 67-56-1 10.0 0.01
Sand (Proppant) Halliburton Propping Agent Crystalline Silica 14808-60-7 99.9 34.0
Water Provided By Customer Base Fluid Fresh Water 100.0 65.24

For data sources see[5]

Stimulation Data

Stimulation Date Phase Number Chemical Agent Volume (gal) Treating Pressure (psi) Breakdown Pressure (psi)
2013-02-26 1 Sand 5,048,568 8,313 8,600
2013-02-26 2 Sand 5,048,568 8,209 8,476
2013-02-27 3 Sand 5,048,568 7,840 8,496
2013-02-27 4 Sand 5,048,568 7,812 8,313
2013-02-27 5 Sand 5,048,568 7,809 8,565
2013-02-28 6 Sand 5,048,568 7,812 8,459
2013-02-28 7 Sand 5,048,568 8,249 8,447
2013-02-28 8 Sand 5,048,568 7,838 8,578
2013-03-01 9 Sand 5,048,568 7,787 8,681
2013-03-01 10 Sand 5,048,568 7,496 8,483
2013-03-01 11 Sand 5,048,568 7,471 8,293
2013-03-02 12 Sand 5,048,568 7,445 8,384
2013-03-02 13 Sand 5,048,568 7,379 8,354
2013-03-02 14 Sand 5,048,568 7,678 8,276
2013-03-04 15 Sand 5,048,568 8,123 8,512
2013-03-04 16 Sand 5,048,568 8,122 8,555
2013-04-23 17 Sand 5,048,568 6,759 8,359
2013-04-23 18 Sand 5,048,568 7,074 8,414
2013-04-24 19 Sand 5,048,568 7,138 8,291

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
2012 CHIEF OIL & GAS LLC 0.00 0 0.00 0 0.00 0
2013 CHIEF OIL & GAS LLC 784,938.00 65 0.00 0 0.00 0
2014 CHIEF OIL & GAS LLC 2,254,196.00 360 0.00 0 0.00 0
2015 CHIEF OIL & GAS LLC 1,363,864.25 356 0.00 0 0.00 0
2016 CHIEF OIL & GAS LLC 942,907.61 286 0.00 0 0.00 0
2017 CHIEF OIL & GAS LLC 1,086,931.14 365 0.00 0 0.00 0
2018 CHIEF OIL & GAS LLC 739,106.48 363 0.00 0 0.00 0
2019 CHIEF OIL & GAS LLC 565,487.13 365 0.00 0 0.00 0

For data sources see[7]

Waste Data

Period Operator Waste Type Quantity Disposal Method Waste Facility ID
2012 CHIEF OIL & GAS LLC Drill Cuttings 1.75 Tons LANDFILL 301358
2012 CHIEF OIL & GAS LLC Drill Cuttings 1,543.80 Tons LANDFILL 100933
2013 CHIEF OIL & GAS LLC Fracing Fluid Waste 2,442.00 Bbl REUSE OTHER THAN ROAD SPREADING
2013 CHIEF OIL & GAS LLC Fracing Fluid Waste 205.38 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NC006
2013 CHIEF OIL & GAS LLC Produced Fluid 1,433.00 Bbl REUSE OTHER THAN ROAD SPREADING
2014 CHIEF OIL & GAS LLC Produced Fluid 2,874.68 Bbl REUSE OTHER THAN ROAD SPREADING
2014 CHIEF OIL & GAS LLC Produced Fluid 110.00 Bbl RESIDUAL WASTE PROC FAC (GENERAL PERMIT) WMGR123NC018
2015 CHIEF OIL & GAS LLC Produced Fluid 49.06 Bbl REUSE OTHER THAN ROAD SPREADING
2016 CHIEF OIL & GAS LLC Produced Fluid 8.92 Bbl REUSE OTHER THAN ROAD SPREADING
2018 CHIEF OIL & GAS LLC Produced Fluid 15.90 Bbl REUSE (AT WELL PAD)
2019 CHIEF OIL & GAS LLC Produced Fluid 79.33 Bbl REUSE (AT WELL PAD)

For data sources see[8]

Inspection Data

Inspections Performed

Inspection ID Inspection Category Inspection Date Inspection Type Inspection Result Inspection Comments
2093580 Primary Facility 2012-08-22 Routine/Partial Inspection No Violations Noted Predrill inspection conducted as site was being completed.
2166619 Primary Facility 2013-04-22 Routine/Complete Inspection No Violations Noted
2166642 Primary Facility 2013-04-09 Routine/Complete Inspection No Violations Noted tear down after fraccing activity. Site messy. High C puddles, stains, sheen on containment. Called Rich who said he would deal with it promptly.
2168290 Primary Facility 2013-05-21 Routine/Complete Inspection No Violations Noted
2171165 Primary Facility 2013-05-31 Routine/Complete Inspection No Violations Noted
2229745 Primary Facility 2013-12-16 Routine/Partial Inspection Viol(s) Noted & Immediately Corrected Completed well was not tagged. Received photo from R. Adams on 12/18/13 showing label now in place.
2258016 Primary Facility 2014-03-28 Routine/Complete Inspection No Violations Noted 9:00, rainy day. Met landowner George Kramer who would like peripheral silt sock removed since vegetative growth >70%. Inspection revealed Mr Kramer is correct confirmed with him and with Chief. Otherwise no issues on the location at this time.
2272283 Primary Facility 2014-05-20 Routine/Complete Inspection No Violations Noted
2291990 Primary Facility 2014-07-31 Routine/Complete Inspection No Violations Noted
2293691 Primary Facility 2014-08-06 Drilling/Alteration No Violations Noted
2300872 Primary Facility 2014-09-03 Routine/Complete Inspection No Violations Noted
2330179 Primary Facility 2014-12-05 Routine/Complete Inspection No Violations Noted
2330331 Primary Facility 2014-12-08 Routine/Complete Inspection No Violations Noted
2353783 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.
2379020 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.
2379214 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.
2379245 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.
2379326 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.
2405592 Primary Facility 2015-09-02 Drilling/Alteration No Violations Noted replacing well head on 6H
2405936 Primary Facility 2015-09-09 Routine/Complete Inspection No Violations Noted 1H well top gauge: 1250 psi. 13x9 annulus shut in, 0% methane. 9x5 annulus shut-in, 100% methane, and pressure.
2406714 Primary Facility 2015-09-11 Routine/Complete Inspection Violation(s) Noted 1H: when shut-in pressure builds on 9x5. Sampled 13x9, 9x5, and production gas. Tubing installed at end of August. Well in production.
2427986 Primary Facility 2015-11-24 Routine/Complete Inspection Outstanding Violations - No Viols Req'd 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.
2479931 Primary Facility 2016-04-27 Routine/Complete Inspection Outstanding Violations - No Viols Req'd 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. The the conclusion of the test, these devices were transferred to the G&S Big Rigger 1H, which remained in production.

G&S Big Rigger 1H: 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.

2493842 Primary Facility 2016-06-06 Routine/Complete Inspection Outstanding Violations - No Viols Req'd Arrived @ 10:30. Weather cloudy with threat of rain. 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 1H (not in production) was being concluded. The 13-3/8” x 9-5/8” and 9-5/8” x 5-1/2” annuli had been shut-in and fitted with continuous pressure loggers and remote read transducers. The 9-5/8” x 5-1/2” annulus took ¿ 17 days and built to a stable pressure plateau of ¿ 145 psi. The 13-3/8” x 9-5/8” annulus was showing a vacuum at the conclusion of the test.

Stabilized flow rates were taken by differential pressure reading across a 1/8” orifice plate restriction. The only annulus showing significant flow was the G&S Big Rigger 6H which measured 211.20 SCF/Day. Throughout the well testing this has been the only annulus to consistently show measureable flow. There has been no significant change in flow rate at the 6H 9-5/8” x 5-1/2” annulu

2499321 Primary Facility 2016-06-30 Routine/Complete Inspection Outstanding Violations - No Viols Req'd 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
2499455 Primary Facility 2016-07-01 Routine/Complete Inspection Outstanding Violations - No Viols Req'd Arrived @ 13:30. Weather: threat of storms, very windy, rain during the inspection. Met with Jon Hafer and company man Floyd Roberts (Chief). Coiled tubing rig was toe prepping the 2H well at the time of my inspection. Prior to my inspection the 6H 5-1/2” casing hanger seals were replaced and pressure tested at low and high pressures. The charted showed that the pressures held. Operations were ongoing when I left the site at 15:00.
2499456 Primary Facility 2016-07-01 Routine/Complete Inspection Outstanding Violations - No Viols Req'd
2502993 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.
2503244 Primary Facility 2016-07-13 Drilling/Alteration Outstanding Violations - No Viols Req'd Arrived @ 14:30. Weather: cloudy, breezy with threat of rain. OGI Ken Kennedy and I met with Jon Hafer and company man Floyd Roberts (Chief). Previously corrosion between the ring gasket and ring groove on the B-section had necessitated replacing the B-sections of the G&S Big Rigger 2H, 3H, 4H, and 5H, and other seals had required replacing on the 6H. As a result Roberts had pressure-tested the B-sections separately and also the entire well heads at low and high pressures. Roberts reviewed the test charts with us. The charts showed that, over each pressure range, pressures held constant. Shortly after we arrived the TGT tool was removed from the G&S Big Rigger 2H. The memory was downloaded and preparations were made to begin logging the 3H. The 3H had 400 psi on the production casing. Prior to blowing down the well, a flow line was rigged to handle fluid that might be released during the blow down. In the meantime, the decision was made to move to the 4H. The 3H blew down in minutes with little production o
2503273 Primary Facility 2016-07-15 Drilling/Alteration Outstanding Violations - No Viols Req'd : Arrived @ 08:54. Weather: hot, humid, threat of rain. Met with Jon Hafer and company man Floyd Roberts (Chief) who reported that logging program was running late. Logging was to have finished on the day of my inspection, but the open annuli passes of the 2H and 6H had not been done. Additionally there was the possibility of third run on the 6H to attempt to resolve the origin of an anomalous noise signature. Left location @ 10:20.
2508091 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.

2509301 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.

2512014 Primary Facility 2016-08-19 Routine/Complete Inspection No Violations Noted Routine inspection to assess hydraulic fracturing operations. Overall site conditions were good, with all fluids and petroleum products being stored within containment. Containment was in place around all equipment including trucks, light plants, and other machinery. A small amount of oil was observed in the containment for a light plain located along the west side of the well pad, south of the access road. I reported this finding to the Chief company man on site, who indicated that it would be addressed immediately. Based on my observations, no oil was discharged outside fot he containment.

No violations were cited during this inspection.

2514650 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.
2514817 Primary Facility 2016-08-24 Drilling/Alteration Outstanding Violations - No Viols Req'd 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
2517123 Primary Facility 2016-09-07 Routine/Complete Inspection No Violations Noted
2518935 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.

2535216 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

2543452 Primary Facility 2016-12-01 Routine/Complete Inspection Outstanding Violations - Viols Req'd 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.

2703122 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.
2708107 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.
2798228 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

Violations Commited

Inspection ID Violation ID Violation Date Date Resolved Violation Code Violation Type Violation Comments
2229745 685288 12/16/2013 2013-12-16 OGA 3211(H) - Failure to install, in a permanent manner, the permit number on a completed well. Administrative One well in production on the pad. There was no labeling on this well at the time of my inspection.
2406714 735719 09/11/2015 2015-09-11 78.86 - CASING AND CEMENTING - DEFECTIVE CASING OR CEMENTING - Operator failed to report defect in a well that has defective, insufficient or improperly cemented casing to the Department within 24 hours of discovery. Operator failed to correct defec Environmental Health & Safety Combustible gas on 13x9 annulus.
2543452 774101 2015-09-11 78.86 Environmental Health & Safety methane gas on 13-3/8" x 9-5/8" annulus

For data sources see[9]

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. ↑ "Completion Reports - Stimulations". Pennsylvania Department of Conservation and Natural Resources. 2020-03-02. Retrieved 2020-03-02. 
  7. ↑ "Oil and Gas Production Reports". Pennsylvania Department of Environmental Protection. 2019-03-31. Retrieved 2019-05-21. 
  8. ↑ "Oil and Gas Waste Reports". Pennsylvania Department of Environmental Protection. 2019-03-31. Retrieved 2019-05-21. 
  9. ↑ "Oil and Gas Compliance Report". Pennsylvania Department of Environmental Protection. 2019-05-20. Retrieved 2019-05-21. 
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