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Well ID: 34-059-24320 | Loading map...
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Country: United States | |
State: Ohio | |
County: Noble | |
Municipality: Wayne Township | |
Operator Name: ASCENT RESOURCES UTICA LLC | |
Well Pad ID: US-OH-000835 | |
Farm/Lease Name: MOHOROVICH W RCH GR | |
License Status: Producing | |
License Date: 2018-05-04 | |
Spud Date: 2014-09-03 | |
Spud Drilling Contractor: PATTERSON DRILLING | |
Final Drill Date: 2018-06-28 | |
Well Total Depth: 19436.00 ft | |
Configuration: Horizontal | |
Latitude: 39.950000 | |
Longitude: -81.370000 |
For data sources see[1]
Well Status | Well Status Date | Comment |
---|---|---|
APP | 2013-09-27 | Proposed Formations:POINT PLEASANT, Issued Date:9/27/2013, Expired Date:9/27/2015 12:00:00 PM, Drilling unit acres:203.32, Proposed Well Type:ST, Proposed Well Class: |
APP | 2013-10-02 | Proposed Formations:POINT PLEASANT, Issued Date:10/2/2013, Expired Date:10/2/2015 12:00:00 PM, Drilling unit acres:, Proposed Well Type:ST, Proposed Well Class:STRT |
APP | 2014-08-25 | Proposed Formations:POINT PLEASANT, Issued Date:8/25/2014, Expired Date:8/24/2016 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:ST, Proposed Well Class:STRT |
Correction to Well | 2014-08-29 | CORRECTION TO LEASE NAME. |
APP | 2016-10-03 | Proposed Formations:POINT PLEASANT, Issued Date:10/3/2016, Expired Date:10/3/2018 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:ST, Proposed Well Class:TI |
Change of Owner | 2017-12-14 | Operator changed from 8928, CARRIZO (UTICA) LLC to 9520, ASCENT RESOURCES UTICA LLC |
APP | 2018-05-04 | Proposed Formations:UTICA THROUGH POINT PLEASANT, Issued Date:5/4/2018, Expired Date:5/3/2020 12:00:00 PM, Drilling unit acres:671.065, Proposed Well Type:OG, Proposed Well Class:POOL |
Reached Total Depth | 2018-06-28 | |
Correction to Well | 2018-12-21 | UDATE TARGET/TAKE PER AS-DRILLED PLAT |
Completion Report Received | 2019-06-03 | |
Record Last Modified | 2019-06-11 | |
Construction Permit Expires | 2020-05-03 |
For data sources see[2]
Job Number | Job Start Date | Job End Date | True Vertical Depth (ft) | Total Water Volume (gal) | Total Non-Water Volume (gal) |
---|---|---|---|---|---|
1 | 08/14/2018 | 09/17/2018 | 7662 | 16,746,200.0 | 260533 |
Job Number | Trade Name | Supplier | Purpose | Ingredient Name | CAS Number | Additive Percentage by Mass | Job Percentage by Mass | Mass Used (lb) |
---|---|---|---|---|---|---|---|---|
1 | APB-1 | FTSI | Gel breaker | Listed Below Green Line | Listed Below | 0 | 0 | 0 |
Water | Supplied by Operator | Base Fluid | Water | 7732-18-5 | 100 | 87.3568 | 139,663,000.0 | |
HVG-1 4.0 | FTSI | Water gelling agent | Listed Below Green Line | Listed Below | 0 | 0 | 0 | |
0.1%-7.5% HCL | FTSI | Acid | Listed Below Green Line | Listed Below | 0 | 0 | 0 | |
10.1%-15.0% HCL | FTSI | Acid | Listed Below Green Line | Listed Below | 0 | 0 | 0 | |
CS-1000 SI | FTSI | Scale Inhibitor | Listed Below Green Line | Listed Below | 0 | 0 | 0 | |
Other Chemical(s) | Listed Above | See Trade Name(s) List | Water | 7732-18-5 | 92.5 | 1.07303 | 0 | |
Water | 7732-18-5 | 85 | 0.128476 | 0 | ||||
Water | 7732-18-5 | 50 | 0.0306974 | 0 | ||||
Water | 7732-18-5 | 100 | 0.021161 | 0 | ||||
Water | 7732-18-5 | 45 | 0.00368095 | 0 | ||||
Water | 7732-18-5 | 55 | 0.0130268 | 0 | ||||
FRW-1450 | FTSI | Friction Reducer | Listed Below Green Line | Listed Below | 0 | 0 | 0 | |
CI-150 | FTSI | Acid Corrosion Inhibitor | Listed Below Green Line | Listed Below | 0 | 0 | 0 | |
Hydrochloric acid | 7647-01-0 | 0.005 | 0.00000118 | 0 | ||||
Glutaraldehyde | 111-30-8 | 5 | 0.00105805 | 0 | ||||
Guar gum | 9000-30-0 | 55 | 0.00005375 | 0 | ||||
Petroleum Distillate | 64742-47-8 | 55 | 0.00005375 | 0 | ||||
Phosphorous Acid | 10294-56-1 | 2 | 0.000473702 | 0 | ||||
Silica, Quartz | 14808-60-7 | 100 | 9.43956 | 0 | ||||
N-olefins | Proprietary | 3 | 0.00003899 | 0 | ||||
Raffinates, Sorption Process | 64741-85-1 | 55 | 0.00005375 | 0 | ||||
Acetic acid | 64-19-7 | 40 | 0.00327196 | 0 | ||||
Orthophosphoric acid | 7664-38-2 | 0.75 | 0.000177638 | 0 | ||||
Cationic Polyacrylamide | 9003-05-8 | 30 | 0.0184184 | 0 | ||||
Thiourea-formaldehyde Copolymer | 68527-49-1 | 10 | 0.000129956 | 0 | ||||
Ammonium Persulfate | 7727-54-0 | 100 | 0.00001171 | 0 | ||||
Hydrogen Chloride | 7647-01-0 | 15 | 0.0226721 | 0 | ||||
Propargyl Alcohol | 107-19-7 | 5 | 0.00006498 | 0 | ||||
Distillates (petroleum), hydrotreated light | 64742-47-8 | 30 | 0.0184184 | 0 | ||||
Quaternary ammonium compound | 68424-85-1 | 10 | 0.0021161 | 0 | ||||
Fatty Acids, Tall Oil | 61790-12-3 | 10 | 0.000129956 | 0 | ||||
Isotridecanol, ethoxylated | 9043-30-5 | 2 | 0.00000195 | 0 | ||||
Phosphonic Acid, {Nitrilotris (methylene)} Tris | 6419-19-8 | 35 | 0.00828979 | 0 | ||||
Alcohols, C11-14-iso-, C13-rich, ethoxylated | 78330-21-9 | 5 | 0.00306974 | 0 | ||||
Phosphonic Acid, {(Dimethylamino) Methylene} Bis - | 29712-30-9 | 5 | 0.00118426 | 0 | ||||
Hydrogen Chloride | 7647-01-0 | 7.5 | 0.0870026 | 0 | ||||
Ethanol | 64-17-5 | 5 | 0.00105805 | 0 | ||||
Suspending Agent | 1302-78-9 | 5 | 0.00000489 | 0 | ||||
Quartz | 14808-60-7 | 4 | 0.00000391 | 0 | ||||
Alcohol Ethoxylate Surfactants | Proprietary | 10 | 0.000129956 | 0 | ||||
Citric Acid | 77-92-9 | 30 | 0.00245397 | 0 | ||||
Methanol | 67-56-1 | 90 | 0.00116961 | 0 | ||||
Silica, Quartz | 14808-60-7 | 100 | 1.7766 | 0 | ||||
Bactron K-139 | FTSI | Biocide | Listed Below Green Line | Listed Below | 0 | 0 | 0 | |
FE-200A | FTSI | Iron Control | Listed Below Green Line | Listed Below | 0 | 0 | 0 | |
40/70 White | FTSI | Proppant | Listed Below Green Line | Listed Below | 0 | 0 | 0 | |
100 Mesh Sand | FTSI | Proppant | Listed Below Green Line | Listed Below | 0 | 0 | 0 |
For data sources see[3]
Stimulation Date | Chemical Agent | Chemical Agent Concentration (%) | Fracking Fluid Volume | Mass of Proppant Used (lb) | Fracking Company | Comments |
---|---|---|---|---|---|---|
0 | 0 | 0 |
For data sources see[4]
Period | Operator Name | Gas Quantity (mcf) | Oil Quantity (bbl) | Production Days |
---|---|---|---|---|
2018 | ASCENT RESOURCES UTICA LLC | 19552 | 5849 | 8 |
2019 | ASCENT RESOURCES UTICA LLC | 246768 | 68581 | 90 |
Period | Operator Name | Waste Type | Quantity (bbl) | Production Days |
---|---|---|---|---|
2018 | ASCENT RESOURCES UTICA LLC | Brine | 2118 | 8 |
2019 | ASCENT RESOURCES UTICA LLC | Brine | 18497 | 90 |
Inspection ID | Inspection Date | Inspection Type | Inspection Result | Inspection Comments |
---|---|---|---|---|
-1424584765 | 2017-8-7 0:00:0 | DD | No Violations | 0.50 |
-1488793638 | 2019-4-30 0:00: | PW | No Violations | 0.20 |
-1592288869 | 2014-9-3 0:00:0 | CS | No Violations | 2.00 |
-2009558215 | 2019-12-13 0:00 | PW | No Violations | 0.10 |
-209675240 | 2018-9-10 0:00: | CT | No Violations | 0.20 |
-567851711 | 2018-11-9 0:00: | CT | No Violations | |
0209675240 | 2018-09-10 | Completion Testing | No Violations | The purpose of my inspection was a status check on hydraulic stimulation operations. During my inspection Frac Tech Services and Nine Energy Wireline was on location. 59 stages of 76 have been completed. |
0295451316 | 2014-12-08 | Drill / Deepen / Reopen | No Violations | On the day of my inspection I witnessed that Patterson UTI Drilling Rig #334 had ran and set their 2nd Intermediate casing at 6660 feet and were beginning to skid to the Mohorovich 2H 34059244210000 with plans to re-enter wellbore late tonight. |
0567851711 | 2018-11-09 | Completion Testing | No Violations | Status check inspection found the well drilling and completion process is now complete. The well was stimulated in 76 stages of 151 total stage length average. The 5.5 diameter casing has a bottom toe sleeve that was set at 19,257. There is a 7.0625 primary master valve on the well. A service rig is on location and rigged up on the # 14 well drilling out the completion plugs and running the production tubing. Crews are on site installing the production equipment, 2 tank batteries are being constructed on site. Annular pressure monitoring is in place. |
1202413297 | 2020-9-11 0:00: | PW | No Violations | 1.00 |
1412347681 | 2015-04-29 | Preliminary Restoration | No Violations | On the day of my inspection accompanied by Southeast Regional Supervisor Brent Bear, the site passed preliminary restoration according to ORC 1509.072A. |
1416882533 | 2016-09-19 | Drill / Deepen / Reopen | No Violations | |
1424584765 | 2017-08-07 | Drill / Deepen / Reopen | No Violations | On the day of my inspection I witnessed there was no change in the status of the well since the last inspection on September 19, 2016 with the 9.625 inch diameter intermediate secured with a bolted night cap. There is no production equipment, flowline or salesline in place and the location is shared with the Mohorovich 2S, 3S, 4S, 8H and Rector 14H. |
1488793638 | 2019-04-30 | Production Wells | No Violations | The purpose of my inspection was a status check. During my inspection the well was equipped with a production tree style wellhead. Production tubing valves were in the open position. Pressure monitoring was present the 13.375-inch diameter intermediate casing had 17 pounds per square inch, 9.625-inch diameter intermediate had 1050 pounds per square inch, 5.5-inch diameter production casing had 1900 pounds per square inch, and the production tubing had 1500 pounds per square inch. The production equipment consisted of ten 400-barrel tanks, two vapor recovery towers, six sand traps, six gas production units, three horizontal heater treaters, one compressor, and one combustor. The identification was posted at the well, tank battery, and entry. Laminated copies of the Drilling permits were posted at entry. |
1530040800 | 2018-06-26 | Drill / Deepen / Reopen | No Violations | |
1549297461 | 2019-02-04 | Production Wells | No Violations | The purpose of my inspection was a status check. During my inspection the well was equipped with a production tree style wellhead and a plunger lift system. The plunger lift system was plumbed up, but the wells were flowing without the assistance of the plunger. Production tubing valves were in the open position. The gauges that were present read as follows, 13.375-inch diameter intermediate casing had 24 pounds per square inch, 9.625-inch diameter intermediate had 2300 pounds per square inch, 5.5-inch diameter production casing had 2760 pounds per square inch, and the production tubing had 2550 pounds per square inch. The production equipment consisted of ten 400-barrel tanks, two vapor recovery towers, six sand traps, six gas production units, three horizontal heater treaters, one compressor, and one combustor. The identification was posted at the well, tank battery, and entry. Laminated copies of the Drilling permits were posted at entry. Wise tanker truck, USA Compressions, and Ascent Company well tender were all on location. I called Jarod Cogar with Ascents production to make him aware of the pressures found on the 9.625-inch diameter by 5.5-inch diameter annulus and stated that our records indicate that 18.625-inch diameter surface casing was ran on these wells and there were not any gauges present at surface to monitor pressures. I asked that Ascent look into getting a gauge and pressure relief valve assembled on the 18.625-inch casing. |
1592288869 | 2014-09-03 | Casing String Witnessed | No Violations | On the date of inspection I was informed my the company man on duty that a 30 inch diameter hole was drilled by Lightning Energy Services to a depth of 65 feet. Lightning then set 24 inch casing with a weight of 94.62lbs/ft on bottom. Allied Oil and Gas Services pumped 185sk of Class A cement weighing 15.6ppg, with a yield of 1.18, 2% CaCl, and 0.25lbs/sk of flake. They displaced with 29bbl of fresh water. 10bbl of cement returned to surface. While I was on site the cement sank to approximately 12 inches below the bottom of the cellar and was topped off with cement. Cement stayed at surface while I was on site. |
1607606174 | 2018-10-03 | Completion Testing | No Violations | During my inspection Frac Tech Services was on location and they have completed hydraulic stimulation operations on stage 76 of 76. |
1700444037 | 2014-10-14 | Drill / Deepen / Reopen | No Violations | On the day of my inspection I witnessed that Highlands Drilling Rig #10 drilled a 23 inch diameter hole to the depth of 554 feet and ran 524 feet of 18.625 inch 87.5#/ft. J-55 casing and stabbed the float shoe with 4.5 inch diameter drill pipe. Baker Hughes was on site and broke circulation and pumped 35bbls of gel, 10bbls of fresh water and cemented casing with 480 sacks of Class A lead cement with 0.05% Static Free, 1% CaCl, 0.5% EC-1, 0.125#/sk. Cello Flake, 0.75gals/sk. FP-6L, 0.5% BA-10A. Lead cement was followed 125 sacks of Class A tail cement with 0.05% Static Free, 3% CaCl, 0.5% EC-1, 0.125#/sk. Cello Flake, 0.75gals/sk. FP-6L, and 0.5% BA-10A. Displaced cement with 6.8bbls of fresh water. There were good cement returns of 37bbls to surface. |
1953037813 | 2016-09-07 | Drill / Deepen / Reopen | No Violations | On the day of my inspection I witnessed no current activity and the drilling permit expires on 10/2/16. The last activity was on 12/7/14 with the 9.625 inch intermediate being set at 6620 feet. The cellar has been filled with pea gravel to the surface with a 6 inch polyvinyl chloride snorkel for water extraction. |
295451316 | 2014-12-8 0:00: | DD | No Violations | 1.50 |
579907169 | 2020-6-3 0:00:0 | PW | No Violations | 1.00 |
For data sources see[9]