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37-037-20001

Well Details

Well ID: 37-037-20001
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Country: United States
State: Pennsylvania
County: Columbia
Municipality: Sugarloaf Township
Operator Name: XPR RESOURCES LLC
Well Pad ID: 147019
Farm/Lease Name: M MARTIN 1H
License Status: PLUGGED & ABANDONED
Spud Date:
Permit Date: 2009-07-22
Well Type: GAS
Unconventional Well: Y
Configuration: Horizontal Well
Conservation: Yes
Latitude: 41.236861
Longitude: -76.366367

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

Well History

Date Event
2009-07-22 New Permit Application
2010-07-07 Permit Renewal Application
2010-08-31 Performed Spud Operation
2011-02-04 New Permit Application
2011-04-05 Drilling Completion
2011-06-15 Perforation
2011-09-07 DEVIATED
2015-05-18 Drilling Completion
2015-07-01 FULLY PLUGGED

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 2011-06-16 2011-06-16 6,763 4,070,106

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- Silica Sand Halliburton Energy Services Proppant Quartz 14808-60-7 100.00 13.79
BE-9M Halliburton Energy Services Biocide Methanol 67-56-1 30.00 0.00320000
Tri-n-butyl tetradecyl phosphonium chloride 81741-28-8 10.00 0.00107000
GBW-30 Breaker Halliburton Energy Services Breaker Hemicellulase enzyme 9012-54-8 15.00 0.00005000
Carbohydrates 95.00 0.00033000
Water Carrier/Base Fluid Water 100.00 86.04
Hydrochloric Acid Halliburton Energy Services Acid Hydrochloric acid 7647-01-0 30.00 0.10
Cla-Web Halliburton Energy Services Clay Control
0.02
Proprietary 60.00
SP Breaker Halliburton Energy Services Breaker Sodium persulfate 7775-27-1 100.00 0.00035000
LP-65 Halliburton Energy Services Scale Inhibitor Ammonium chloride 12125-02-9 10.00 0.00407000
FR-66 Friction Reducer Halliburton Energy Services Friction Reducer Distillates, petroleum, hydrotreated light 64742-47-8 30.00 0.01
WG-36 Gelling Agent Halliburton Energy Services Gel Guar gum 9000-30-0 100.00 0.00145000

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 XPR RESOURCES LLC 0.00 0 0.00 0 0.00 0
2011 XPR RESOURCES LLC 0.00 0 0.00 0 0.00 0
2012 XPR RESOURCES LLC 0.00 0 0.00 0 0.00 0
2013 XPR RESOURCES LLC 0.00 0 0.00 0 0.00 0
2014 XPR RESOURCES LLC 0.00 0 0.00 0 0.00 0
2015 XPR RESOURCES LLC 0.00 0 0.00 0 0.00 0

For data sources see[6]

Waste Data

Period Operator Waste Type Quantity Disposal Method Waste Facility ID
2010 XPR RESOURCES LLC Drilling Fluid Waste 12,857.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE PA0008451
2010 XPR RESOURCES LLC Drilling Fluid Waste 143.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE 301353
2011 XPR RESOURCES LLC Drilling Fluid Waste 2,612.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE PA0008451
2011 XPR RESOURCES LLC Fracing Fluid Waste 54,025.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NC006
2011 XPR RESOURCES LLC Drilling Fluid Waste 2,512.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NC006
2012 XPR RESOURCES LLC Fracing Fluid Waste 350.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NC006
2012 XPR RESOURCES LLC Drilling Fluid Waste 70.00 Bbl CENTRALIZED TREATMENT PLANT FOR RECYCLE WMGR123NC006

For data sources see[7]

Inspection Data

Inspections Performed

Inspection ID Inspection Category Inspection Date Inspection Type Inspection Result Inspection Comments
1842705 Primary Facility 2009-11-06 Routine/Complete Inspection No Violations Noted
1850555 Primary Facility 2009-12-16 Compliance Evaluation No Violations Noted
1851078 Primary Facility 2009-12-03 Routine/Complete Inspection No Violations Noted
1919154 Primary Facility 2010-10-04 Drilling/Alteration No Violations Noted 37 ft 20" conductor-- ran 440 ft 13 3/8 casing 20 bbl cement return to surface-- ran 1525 ft 9 5/8 casing 10 bbl cement return to surface
1920110 Primary Facility 2010-09-13 Drilling/Alteration No Violations Noted rig @ 3411 ft deep. set 37 ft 20" conductor cemented with 21 yards concrete. ran 440 ft 13 3/8 casing cemented to surface with 20 bbl cement return to surface. ran 1525 ft 9 5/8 casing cemented to surface with 10 bbl cement returned to surface.
1947219 Primary Facility 2011-02-03 Drilling/Alteration No Violations Noted
1956771 Primary Facility 2011-03-10 Drilling/Alteration No Violations Noted
1958074 Primary Facility 2011-03-17 Drilling/Alteration No Violations Noted
1964248 Primary Facility 2011-04-06 Routine/Partial Inspection Violation(s) Noted
1966839 Primary Facility 2011-04-19 Routine/Complete Inspection No Violations Noted
1981581 Primary Facility 2011-06-16 Follow-up Inspection No Violations Noted
2003899 Primary Facility 2011-09-20 Routine/Complete Inspection Outstanding Violations - No Viols Req'd
2012677 Primary Facility 2011-10-19 Drilling/Alteration Outstanding Violations - No Viols Req'd
2021307 Primary Facility 2011-11-22 Routine/Complete Inspection Outstanding Violations - No Viols Req'd
2072440 Primary Facility 2012-05-30 Routine/Complete Inspection No Violations Noted
2089838 Primary Facility 2012-08-08 Routine/Complete Inspection Outstanding Violations - No Viols Req'd
2154684 Primary Facility 2013-04-08 Routine/Complete Inspection Outstanding Violations - No Viols Req'd
2303236 Primary Facility 2014-08-26 Routine/Complete Inspection No Violations Noted
2347788 Primary Facility 2015-02-18 Plugging(Includes Plugged/Mined Through) No Violations Noted This inspection occurred prior to the mobilization of plugging equipment. Arrived @16:40 on 2/18/15. Containment has been laid down on the pad and there are two Baker tanks on site. Tubing pressure was ~ 1550 psi as measured by a 10,000 psi water-filled gauge. The cellar was frozen, ice and snow were directly adjacent to the well. There were no other annular vents visible at the time of my inspection. Left location @ 17:00.
2347797 Primary Facility 2015-02-24 Plugging(Includes Plugged/Mined Through) No Violations Noted : This inspection took place during plug and abandon operations. Arrived on site @12:30. On location were WPX petroleum engineer Kent Knapschaefer and landman Jeff Volinas, Jason Nicholas with Nick’s Well Plugging. The service rig was up when I arrived. When I arrived the well head was frozen. Once thawed out, the well blew down quickly. Fresh water was pumped down the tubing and annulus to kill the well. 90 bbl were pumped with 10 bbl circulated out to the flowback tank. Left location @17:00.
2347805 Primary Facility 2015-02-25 Plugging(Includes Plugged/Mined Through) No Violations Noted Plugging operations continue. Arrived @ 12:30, sunny, warmer than previous frigid temps. Onsite were: WPX pet. engineer Kent Knapschaefer, Jason Nicholas and crew with Nick’s Well Plugging, Team Services rig crew, and Baker Hughes wireline services led by Cliff Smarr. BOPs were installed and 2-3/8” tubing was pulled before I arrived. Wireline services were preparing to gauge the 5-1/2” production casing when I arrived. Cast Iron Bridge Plug (CIBP) set at 5809’ in the 5-1/2” casing, as per the plugging procedure. Left location at 16:00
2347858 Primary Facility 2015-02-26 Plugging(Includes Plugged/Mined Through) No Violations Noted Plugging operations continued. Arrived @11:30 cloudy, warmer. Operations were delayed due to difficulties freeing the production casing from the slips. Casing jacks were brought onsite and needed 310,000 lbf to free the casing. At the time the Baker Hughes crew noted that there was very little casing stretch visible at the surface. The plan was then to run a free point tool to find the casing free point (anticipated to be below 4000’ based on a previous CBL). The free point tool was checked at numerous depths but the casing free point was not observed. A radial cement bond log on the 5-1/2” casing was run. I left the location at 16:00. Results of the CBL available later indicated a cement top at 3490’ with some cement at 1760’ to 1810’. Even this log was not consistent with the failure to obtain tension on the pipe. It was decided that we would monitor for methane the next day and modify the plugging procedure accordingly.
2347883 Primary Facility 2015-02-27 Plugging(Includes Plugged/Mined Through) No Violations Noted Plugging operations continued. Arrived @08:00 with DEP OGI Bruce Jankura, sunny, very cold. Onsite were WPX’s Kent, Team Services’s Stacy, Baker Hughes’ Cliff, and Nick’s Well Plugging’s Jason with their attendant crews. Using the Altair 5, we monitored for gas in the surface to intermediate casing annulus and the production casing. Since there was no gas detected we agreed to the following: set a 200’ cement plug (5800’ to 5600’) using 15.6 ppg, Class A cement, 1.18 ft3/sk. Pump a gel spacer from 5600’ – 1800’ (~84 bbls). Pump a cement plug from ~ 1800’ to surface. The plan was to do this in three stages: 1800’ to 800’, 800’ to 200’ and 200’ to surface. Discussed requirements monument requirements with Kent. Left location at ~11:00.
2351873 Primary Facility 2015-03-10 Plugging(Includes Plugged/Mined Through) No Violations Noted Time 1600. weather: rain, cloudy, and warm. On- site to verify report of bubbling at the recently plugged gas well. Bubbles (diameter ~ 1”) were emerging intermittently from near the center of the water-filled depression around the well. There appeared to be ~6 bubbles in close succession and then a gap. I confined some of the gas and used the MSA 60 meter to verify that this was combustible gas. I used the Altair 5 and found no methane, carbon monoxide, or hydrogen sulfide at the vent. Informed WPX Petroleum Engineer Kent Knapschaefer of these findings and requested updates on WPX’s plans. I aslso requested a local contact. There are no violations at this time.
2352825 Primary Facility 2015-03-18 Plugging(Includes Plugged/Mined Through) No Violations Noted Time 11:50, windy with sun. Met with Williams’ staff Bob Goodwin and Kent Knapscheafer to investigate source of bubbling at the recently plugged well. The water had been removed from the cellar which was approximately 4’ deep with a muddy floor. The conductor was exposed and there was solid cement emerging from the conductor. The cement obscured the casing tops. The steel plate centered about the center of the well also obscured the top of the well. It was not possible to ID the bubble source.Williams plans to have the steel plate removed and then try the soap solution again, or perhaps enough water to just cover the cement. Once the source has been identified the short-term plan is to leave water in the cellar so that the situation can be monitored pending further investigation and a long-term plan. Left at 12:30. There are no violations at this time.
2361125 Primary Facility 2015-04-07 Plugging(Includes Plugged/Mined Through) No Violations Noted Arrived at 11:40, cloudy, warm, intermittent rain. At the time of my inspection subcontractors from ROC and United Rentals had already excavated around the cellar. Ground water was infiltrating the excavation. A pump arrived shortly after I did. Subcontractors pumped out the water, made a cut down the length of the cellar, scrapped away the lip of cement at the cellar’s base, and peeled the cellar off with a track hoe. When I left the location at 14:20, contractors were waiting on a jack hammer attachment to remove the cement and cut the cement and annuli. The next day, 4/8/15, I received a report containing photos and video from Kent Knapschaefer (WPX petroleum engineer) showing bubbling on the 9-5/8” x 5-1/2” annulus. The contractors installed a new cap and vent. WPX installed a pressure gauge and shut the vent in to build pressure and obtain a sample for stable isotopic analysis.
2367506 Primary Facility 2015-04-29 Plugging(Includes Plugged/Mined Through) No Violations Noted Arrived at 13:00. Met company man Matt Wilson. Drilling rig was onsite, Wilson was making preparations for staring on 4/30/15. Operations near the well head made precluded a measurement of combustible gas at the 9-5/8” x 5-1/2”. But Wilson had observed 45 psi on the gauge following shut in. This pressure blew down in seconds, he said. Discussed the replug prog. The plan, to the first decision point, was to weld casing head onto the 9-5/8” casing, spear the 5-1/2” bring it up and in slips, install BOPs and start to drill out the cement plug down to ~ 1750’, then try to cut and pull casing. Wilson said it was unwise to estimate how long it would take to drill out the plug. Left at 14:00
2368548 Primary Facility 2015-05-11 Plugging(Includes Plugged/Mined Through) No Violations Noted Stopped at location to discuss plugging activity. Site quiet. Also investigated complaint related to equipment on containment. Containment was in place at the time of my inspection and equipment was on containment. Conducted a thorough inspection of the site. Did not observe any discoloration or other indications of leaks or spills. The location was appropriately protected at the time of my inspection.
2370915 Primary Facility 2015-05-18 Plugging(Includes Plugged/Mined Through) No Violations Noted Arrived @7:30. Company man Jon Short has replaced Matt Wilson on site. Rig on location, quiet at the time of my inspection, following success in cutting window and placing rock-to-rock plug as per the 5/13/15 revised prog:
2454749 Primary Facility 2016-02-22 Routine/Complete Inspection No Violations Noted
2619611 Primary Facility 2017-07-07 Site Restoration No Violations Noted On July 7, 2017, the Department conducted a site restoration inspection at the WPX Energy Appalachia, LLC (WPX) Martin 1V Well Pad in Sugarloaf Township, Columbia County. Andrew Hobbins, Water Quality Specialist represented the Department. Nobody was present for WPX. The Department received a Notice of Termination (NOT) from WPX on June 27, 2017.

The well pad has not been completely restored, but has been reduced in size. PCSM has not been addressed at the site. The restored area has been returned to approximate original contours. Vegetation was observed to be greater than 70%. The well that was on site was plugged in 2015. Section 3216(d) of the Oil and Gas Act states "Within nine months after plugging a well, the owner or operator shall remove all production or storage facilities, supplies and equipment and restore the well site." The Department recommends restoring the remain pad surface to approximate original contours. Chapter 78a.65(3) also states "Within 60 days after the restoration of t

2620345 Primary Facility 2017-07-07 Site Restoration No Violations Noted On July 7, 2017, the Department conducted a site restoration inspection at the WPX Energy Appalachia, LLC (WPX) Martin 1V Well Pad in Sugarloaf Township, Columbia County. Andrew Hobbins, Water Quality Specialist represented the Department. Nobody was present for WPX. The Department received a Notice of Termination (NOT) from WPX on June 27, 2017.

The well pad has not been completely restored, but has been reduced in size. PCSM has not been addressed at the site. The restored area has been returned to approximate original contours. Vegetation was observed to be greater than 70%. The well that was on site was plugged in 2015. Section 3216(d) of the Oil and Gas Act states "Within nine months after plugging a well, the owner or operator shall remove all production or storage facilities, supplies and equipment and restore the well site." The Department recommends restoring the remain pad surface to approximate original contours. Chapter 78a.65(3) also states "Within 60 days after the restoration of t

Violations Commited

Inspection ID Violation ID Violation Date Date Resolved Violation Code Violation Type Violation Comments
1964248 608356 04/06/2011 2011-04-06 201G - Failure to post permit number, operator name, address, telephone number in a conspicuous manner at the site during drilling Administrative

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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