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34-029-21894

Well Details

Well ID: 34-029-21894
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Country: United States
State: Ohio
County: Columbiana
Municipality: Elkrun Township
Operator Name: HILCORP ENERGY COMPANY
Well Pad ID: US-OH-001472
Farm/Lease Name: ELKRUN-SCHEEL
License Status: Producing
License Date: 2017-06-22
Spud Date: 2017-07-10
Spud Drilling Contractor: H&P DRILLING
Final Drill Date: 2017-09-03
Well Total Depth: 16237.00 ft
Configuration: Horizontal
Latitude: 40.800000
Longitude: -80.700000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2017-06-22 Proposed Formations:UTICA/POINT PLEASANT, Issued Date:6/22/2017, Expired Date:6/22/2019 12:00:00 PM, Drilling unit acres:848.26, Proposed Well Type:OG, Proposed Well Class:POOL
Correction to Well 2017-07-07 CORRECTION TO CASING PROGRAM & GROUND LEVEL ELEVATION
Reached Total Depth 2017-09-03
Completion Report Received 2017-12-12
Correction to Well 2017-12-29 UPDATE TARGET/TAKE PER AS-DRILLED PLAT
Record Last Modified 2019-06-11
Construction Permit Expires 2019-06-22

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2018-02-02 9538 9704 0
2018-02-02 15938 16104 0
15938 16104 0
9538 9704 0
9538 9704 0

For data sources see[3]

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 10/13/2017 10/25/2017 8341 13,111,200.0 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 (100 Mesh Proppant) Taylor Frac Proppant Silica Substrate 14808-60-7 100 2.65095 3,301,480.0
K-BAC 1005 Water Science Technologie, LLC Biocide 2, 2-Dibromo-3-nitrilopropionamide 10222-01-2 5.8 0.000560703 698.297
Polyethylene glycol 25322-68-3 50 0.00486722 6061.61
Water 7732-18-5 44.3 0.000977712 1217.64
SI-20 Moon Chemical Products Scale Inhibitor Water 7732-18-5 56 0.00540897 6736.31
Phosphinocarboxylic Acid 110224-99-2 44 0.00424991 5292.81
Water Hilcorp Energy Carrier/Base Fluid Water 7732-18-5 100 87.8539 109,413,000.0
Sand (40/70 Proppant) Taylor Frac Proppant Silica Substrate 14808-60-7 100 9.03041 11,246,400.0
NEFE-180 Chemplex Corrosion Inhibitor/Iron Control Acetic acid 64-19-7 89 0.00196425 2446.27
Fatty acids, tall oil 61790-12-3 5 0.000110351 137.431
Alcohols, C14-15, ethoxylated 68951-67-7 5 0.000110351 137.431
Methanol 67-56-1 40 0.00088281 1099.45
2-Ethylhexanol 104-76-7 10 0.000220703 274.862
2-Propyn-1-ol 107-19-7 5 0.000482944 601.456
Coconut oil acid diethanolamine 68603-42-9 5 0.000110351 137.431
Hydrochloric Acid (28%) Oxy Acidizing Hydrochloric Acid (Hydrogen Chloride) 7732-18-5 36 0.128402 159911
Water 7732-18-5 64 0.0553329 68911.3
Other Chemical(s) Listed Above See Trade Name(s) List 2-Ethylhexanol 104-76-7 10 0.000220703 274.862
Phosphinocarboxylic Acid 110224-99-2 44 0.00424991 5292.81
Oleic Acid Diethanolamide 93-83-4 1.5 0.00129687 1615.11
Water 7732-18-5 44.3 0.000977712 1217.64
Polyethylene glycol 25322-68-3 50 0.00486722 6061.61
Fatty acids, tall oil 61790-12-3 5 0.000110351 137.431
Coconut oil acid diethanolamine 68603-42-9 5 0.000110351 137.431
Water 7732-18-5 64 0.0553329 68911.3
2-Propyn-1-ol 107-19-7 5 0.000482944 601.456
Water 7732-18-5 75 0.00730083 9092.41
Alcohols, C14-15, ethoxylated 68951-67-7 5 0.000110351 137.431
Methanol 67-56-1 40 0.00088281 1099.45
Alcohols, C14-15, ethoxylated 68551-12-2 1.5 0.00129687 1615.11
Ammonium Chloride ((NH4)Cl) 12125-02-9 2 0.00172915 2153.48
Plexslick 957 Chemplex SOLVAY Friction Reducer Ammonium Chloride ((NH4)Cl) 12125-02-9 2 0.00172915 2153.48
Petroleum Distillate 64742-47-8 20 0.0172915 21534.8
Alcohols, C14-15, ethoxylated 68551-12-2 1.5 0.00129687 1615.11
Oleic Acid Diethanolamide 93-83-4 1.5 0.00129687 1615.11
Water 7732-18-5 75 0.00730083 9092.41

For data sources see[4]

Stimulations Data

Stimulation Date Chemical Agent Chemical Agent Concentration (%) Fracking Fluid Volume Mass of Proppant Used (lb) Fracking Company Comments
2017-10-25 H2O 7 9497 Bbl 497820 STINGRAY PRESSURE PUMPING LLC STAGE 33 OF 33 SEE IMAGES FOR STAGES 2-32
2017-10-13 H2O 7 8626 Bbl 296680 STINGRAY PRESSURE PUMPING LLC STAGE 1 OF 33

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2017 HILCORP ENERGY COMPANY 192573 0 27
2018 HILCORP ENERGY COMPANY 2053124 0 361
2019 HILCORP ENERGY COMPANY 270665 0 90

For data sources see[6] [7]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2017 HILCORP ENERGY COMPANY Brine 9510 27
2018 HILCORP ENERGY COMPANY Brine 12663 361
2019 HILCORP ENERGY COMPANY Brine 1269 90

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1756806987 2017-10-4 0:00: CT No Violations 2.00
-1952607319 2017-8-16 0:00: DD No Violations 4.80
-353181510 2018-3-22 0:00: PW No Violations 1.00
-678545411 2017-7-13 0:00: DD No Violations 0.40
-788268316 2017-7-13 0:00: DD No Violations 0.50
0343178139 2017-09-27 Production Wells No Violations The purpose of my inspection was to conduct a status check on well #2-1894. The lease road remained in good repair with limited dust. Preliminary restoration work was occurring at the pad. Well production system construction crews were on location. The well cellar was covered with steel grate and plywood. No annular casing gauges were present. I speak with Hilcorp construction manager Ken Shimek to request installation or documentation of surface and intermediate annular pressures prior to commencement of stimulation. No violations were observed during this inspection.
0353181510 2018-03-22 Production Wells No Violations The purpose of my inspection was to document the annular pressure readings on well #2-1894. At the time of my inspection the intermediate and production annular gauges were plumbed aboved grade and identified. The 9.625 annular pressure gauge indicated 40 psi. The 5.5 annular pressure gauge indicated 0 psi. The well was flowing at the time of inspection. The 5.5 production casing indicated 1911 psi. The production tubing gauge indicated 880 psi. No leaks were observed at the time of inspection. No violations were observed during this inspection.
0518533164 2017-09-06 Drill / Deepen / Reopen No Violations The purpose of my inspection was to obtain the 5.5 production casing cement ticket and witness the location during rig down operations. The lease access road and location remained stable. I did not witness any spills off of containment. The well heads were secured and I did not observe any leaks. I will schedule to reinspect the location to witness and record the annular casing pressures for mechanical integrity. No violations were observed during this inspection.
0678545411 2017-07-13 Drill / Deepen / Reopen No Violations The purpose of my inspection was to document the status of well #2-1894. The weather was raining at the time of inspection. Valid drilling permits were posted at the entrance sign. The lease road and pad remained in good repair. Erosion and sedimentation controls remained in place and were functioning. HAD # 618 had completed setting conductor and was off of location. Steel plating was covering the conductor. No violations were observed during this inspection.
0788268316 2017-07-13 Drill / Deepen / Reopen No Violations The purpose of my inspection was to conduct a status check on drilling operations on well #2-1894. The drilling permit remained posted at the entrance sign. Conductor rig HAD #618 had completed setting conductor and had left location. Steel plate was in place over the conductor casing. The cellar had not been installed yet. Conditions at the time of inspection were rainy. E&S controls remained in place and were functioning. No violations were observed during this inspection.
0836525432 2018-03-26 Production Wells No Violations The purpose of my inspection was to document the annular cement integrity test on well #2-1894. Hilcorp Energy lease operator Jerry Myers was on location to conduct the test. Mr. Myers reported that he found the 5.5 annular pressure gauge had failed and was incorrectly indicating 0 psi at the time of my previous inspection. Mr. Myers replaced the gauge with a working unit. At the time of my inspection the 5.5 annular pressure gauge was indicating 490 psi. The 9.625 annular pressure gauge indicated 25 psi. Prior to the test, Mr. Myers had .375 stainless tubing plumbed to the annular gauges and routed to the open top box on location utilized for the well head sand knock out units. Mr. Myers opened the valve and I witnessed the pressure release until the gauge indicated 0 psi. Mr. Myers then shut the valve and I monitored the gauge for the next hour. I did not witness any pressure recovery while on location. I will continue to make periodic follow-up inspections to document the status of the annular pressures on well #2-1894.
1295858327 2020-1-15 0:00: PL No Violations 1.00
1351105417 2017-07-10 Drill / Deepen / Reopen No Violations The purpose of my inspection was to witness the setting of conduction casing on well #2-1894. HAD #618 was setting 20 diameter casing by the concentric method. At the time of inspection the depth of conductor was 60 feet. Drilling returns were captured in an open top container box. I did not observe any evidence of spills. No violations were observed during this inspection.
1503415739 2017-08-15 Drill / Deepen / Reopen No Violations I was on location to witness the running and cementing of the 13-3/8 surface casing H-P 225 drilled a 17.5 hole to a depth of 657 and Power Torque Services ran 647 of 13-3/8 surface casing. O-Tex Cementing were the cementing contractor on location. The well bore was conditioned. Circulation was established 25 barrels of gel was pumped ahead and followed by 10 barrels fresh water followed by 103.3 barrels of 15.6 class A cement and displaced with 93.7 barrels of water based mud. 4 barrels were returned to surface.
1513107649 2017-12-06 Completion Testing No Violations The purpose for my inspection was to document the status of well completion testing on well #2-1894. The access road remained in good repair. Erosion and sedimentation controls remained in place and were functioning. At the time of my inspection Greenes Completion Testing was on location monitoring flow back. Flow back fluid was being sent to four (4) 500 bbl frac tanks located on containment. I did not observe any evidence of spills or leaks on or off of containment. Production gas was being routed through dedicated production equipment located on the pad. While on location I met with consultant Virgil Gilea. Mr. Gilea reported that fluid recovery was approximately 40-50 barrels per hour. No violations were observed during this inspection.
1516935136 2017-09-01 Drill / Deepen / Reopen No Violations The purpose of my inspection was to witness the production casing cement job. H&P #225 drilled to a total measured depth of 16,237 ft.. A total of 16,231 ft. of 5.5 production casing was ran in the well-bore and centralized with 178 solid steel centralizers. O-Tex Pumping was the cement contractor. After pressure testing their lines to 5,000 psi, I witnessed O-Tex pump a 70 bbl sweep of 13.0 pound per gallon barite, followed by 162.7 bbls of 13.0 pound per gallon scavenger cement. I witnessed cement supervisor Grant Hughes scale the barite and scavenger cement with a pressurized cement scale. Both samples scaled at 13.0 ppg. O-Tex also collected dry samples. After pumping the scavenger cement, O-Tex reported pumping 146 bbls of 13.5 pound per gallon lead cement followed by 408.2 bbls of 14.5 pound per gallon tail cement. While on location I did not observe any evidence of spills or leaks. No violations were observed during this inspection,
1605509346 2017-10-03 Production Wells No Violations The purpose of my inspection was to document the status of stimulation activities on well #2-1894. The lease road remained in good repair with little to no dust. Production system crews were on location constructing production equipment. Four (4) 500 bbl frac tanks were on location and spotted on containment. I met with Hilcorp Energy consultant Virgil Gilet on location. Mr. Gilet communicated that the coil tubing unit was delayed due to road permits which would delay pressure testing the production casing. I did not observe any spills or leaks from any activities on location. Erosion and sedimentation controls remained in place and functioning. I will schedule to be on location to witness the casing test.
1756806987 2017-10-04 Completion Testing No Violations The purpose of my inspection was to witness the production casing pressure test on well #2-1894 prior to stimulation. Consultant Jeremy Ross was on location to direct testing. Wise Intervention Systems (WIS) was the testing company. Prior to the test WIS performed a clean out run with the coil tubing unit. After rigging up the well head and pressure testing the iron, WIS staged the pressure test by pressuring to 5,000 psi and holding for 5 minutes, then pressuring to 7500 psi and holding for 5 minutes and finally pressuring to 9500 psi and holding for 5 minutes. No declines in pressure were measured during the test. The 5.5 annulus was open during the testing. I did not witness any fluid or pressure from the valve. The equipment was all staged on containment. I did not observe any leaks or spills. No violations were observed during this inspection.
1952607319 2017-08-16 Drill / Deepen / Reopen No Violations The purpose of my inspection was to witness the cementing of the 13.375 surface casing. Mahoning County Inspector John Fleming was present during the inspection. H&P #225 drilled a 17.5 hole to 657 RKB. Power Torque Services ran new 13.375 54.5 lb./ft. J-55 casing to 647. O-Tex cemented the casing with 480 sks of 1.21 yield Class H cement 3% CaCl. I observed cement return to surface. I witnessed O-tex weigh the cement at 15.6 ppg. Four (4) bbls were estimated return. The plug landed at 16:15 and was bumped. Floats were checked and held. No violations were observed during this inspection.
1975544247 2017-08-18 Drill / Deepen / Reopen No Violations The purpose of my inspection was to witness the cementing of the 9.625 intermediate casing. H&P #225 drilled a 12.25 hole to 1655 RKB. Power Torque Services ran new 9.625 36 lb./ft. J-55 casing to 1645. O-Tex cemented the casing with 480 sks of 1.21 yield Class H cement 3% CaCl. I observed cement returns to surface. I witnessed O-tex weigh the cement at 15.6 ppg. Four (4) bbls were estimated return. The plug landed at 16:15 and was bumped. Floats were checked and held. No violations were observed during this inspection.
343178139 2017-9-27 0:00: PW No Violations 0.40
518533164 2017-9-6 0:00:0 DD No Violations 0.50
836525432 2018-3-26 0:00: PW No Violations 1.50

For data sources see[10]

References

  1. ↑ "Risk Based Data Management System - Well, tblLocational, tblPlugWell, tblInspection, tblCivilTownships and tblPad Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  2. ↑ "Risk Based Data Management System - Well and WellHistry Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  3. ↑ "Risk Based Data Management System - Perfs Table". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  4. ↑ "FracFocus Fracking Chemicals Database". 2019-04-02. Retrieved 2019-06-19. 
  5. ↑ "Risk Based Data Management System - tblStimulation Table". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  6. ↑ "Risk Based Data Management System - Production Table - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  7. ↑ "Combined Production - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  8. ↑ "Risk Based Data Management System - Production Table - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  9. ↑ "Combined Production - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  10. ↑ "Risk Based Data Management System - tblInspection, tblInspFail and tblinspFlDesc Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
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