X

Track changes made to this page

If you find this page useful and would like to be notified of changes made to this page, start by inputting your email below.



Privacy policy
Close this window

powered by ChangeDetection

34-013-21096

Well Details

Well ID: 34-013-21096
Loading map...
Country: United States
State: Ohio
County: Belmont
Municipality: York Township
Operator Name: XTO ENERGY INC.
Well Pad ID: US-OH-000910
Farm/Lease Name: SCHNEGG UNIT C
License Status: Producing
License Date: 2016-09-07
Spud Date: 2017-03-20
Spud Drilling Contractor: NOMAC DRILLING CORP
Final Drill Date: 2017-06-01
Well Total Depth: 18556.00 ft
Configuration: Horizontal
Latitude: 39.860000
Longitude: -80.860000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2016-09-07 Proposed Formations:POINT PLEASANT, Issued Date:9/7/2016, Expired Date:9/7/2018 12:00:00 PM, Drilling unit acres:426.533, Proposed Well Type:OG, Proposed Well Class:FWC
Reached Total Depth 2017-06-01
Correction to Well 2017-07-21 UPDATE TARGET/TAKE PER AS-DRILLED PLAT RCVD 07/06/2017 ALE
Construction Permit Expires 2018-09-07
Completion Report Received 2019-04-03
Record Last Modified 2019-04-05

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2019-04-04 16717 0
2019-04-04 18414 0
16717 0
18414 0
16717 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 09/28/2017 10/25/2017 9964 20,269,100.0 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 C&J Energy Services Sand - Bulk - Pennsylvania Listed Below Listed Below 0 0 0
GA-7F C&J Energy Services Gelling Agents Listed Below Listed Below 0 0 0
FR-16 C&J Energy Services Friction Reducer Listed Below Listed Below 0 0 0
Sand C&J Energy Services Proppants - Manufactured - Preferred Sands Listed Below Listed Below 0 0 0
SI-6 C&J Energy Services Paraffin & Scale Additives Listed Below Listed Below 0 0 0
CI-3 C&J Energy Services Acid Corrosion Inhibitors Listed Below Listed Below 0 0 0
HC-15 C&J Energy Services Bulk Acid Listed Below Listed Below 0 0 0
Water XTO Energy/ExxonMobil Carrier Fluid Water 7732-18-5 100 88.4739 0
BIO-CLEAR 2000 C&J Energy Services Biocides Listed Below Listed Below 0 0 0
BR-11 C&J Energy Services Gel Breakers Listed Below Listed Below 0 0 0
Methanol 67-56-1 1 0.000171 0
2-Butoxyethanol 111-76-2 15 0.000318 0
Titanium Oxide 13463-67-7 0.1 0.003139 0
2,2-Dibromo-3-nitrilo-propionamide (DBNPA) 10222-01-2 30 0.003209 0
Crystalline Silica, quartz 14808-60-7 99.9 4.482 0
Titanium Oxide 13463-67-7 0.1 0.004486 0
Proprietary Proprietary 1 0.00000300 0
Proprietary Proprietary 100 0.00000400 0
Alcohols, C12-15-branched and linear,

ethoxylated propoxylated

120313-48-6 2 0.001809 0
Poly(oxy-1,2-ethandiyl), alpha-isodecyl-omega-hydroxy-phosphat

Poly(oxy-1,2-ethandiyl), alpha-isodecyl-omega-hydroxy-phosphate

108818-88-8 2 0.001809 0
Ethylene Glycol 107-21-1 5 0.004523 0
Water 7732-18-5 30 0.02714 0
2-Propenamide as residual 79-06-1 0.1 0.00009000 0
Water 7732-18-5 96 0.016422 0
Phosphonic Acid Salt Proprietary 6 0.001026 0
Bentonite Clay 68953-58-2 5 0.001965 0
Polyethylene glycol 25322-68-3 50 0.005348 0
Aluminum Oxide 1344-28-1 1.1 0.012494 0
Water 7732-18-5 28.5 0.003048 0
Dimethylformamide 68-12-2 20 0.000424 0
Ethoxylated Sorbitan Monooleate 9005-65-6 1 0.000905 0
Titanium Oxide 13463-67-7 0.1 0.001136 0
Silica, Crystalline-Quartz 14808-60-7 1 0.00000300 0
Ammonium Persulfate 7727-54-0 92 0.000306 0
CJENERGY-Hydrocarbon-00013 64742-47-8 60 0.023576 0
Ethylene Glycol 107-21-1 40 0.000848 0
Crystalline Silica, quartz 14808-60-7 99.9 1.13467 0
Triethyl Phosphate 78-40-0 2.5 0.00005300 0
Monoethanolamine hydrochloride 2002-24-6 2 0.000342 0
Distillates (Petroleum), Hydrotreated Light 64742-47-8 35 0.031664 0
Proprietary Proprietary 0.7 0.00000200 0
Hydrochloric Acid 7647-01-0 15 0.169792 0
Isopropanol 67-63-0 2.5 0.00005300 0
Sodium Acetate Anhydrous 127-09-3 3 0.002714 0
Poly(oxy-1,2-ethanediyl),alpha-(4-nonylphenyl)-omega

hydroxy-, branched

127087-87-0 5 0.000106 0
Tar Bases, Quinoline Derivs. 68513-87-1 1 0.00002100 0
Ethoxylated Alcohols 68002-97-1 100 0.001965 0
Sorbitan Monooleate 1338-43-8 2 0.001809 0
Tar bases, quinoline derivs, benzyl chloride-quaternized 72480-70-7 15 0.000318 0
Polyurethane Resin (Nuisance Dust) 57029-46-6 2 0.029454 0
Ammonium Chloride 12125-02-9 2 0.000342 0
Crystalline Silica, quartz 14808-60-7 99.9 3.13595 0
2-Propenoic acid, polymer with 2-propenamide, sodium salt 25987-30-8 30 0.02714 0
*Quartz (SiO2) 14808-60-7 99 1.45799 0
Aluminum Oxide 1344-28-1 1.1 0.03453 0
Water 7732-18-5 30 0.000636 0
Iron Oxide 1309-37-1 0.1 0.003139 0
Water 7732-18-5 85 0.962154 0
1-DECANOL 112-30-1 5 0.000106 0
1-OCTANOL 111-87-5 2.5 0.00005300 0
Cured Resin Proprietary 13 0.00004300 0
Iron Oxide 1309-37-1 0.1 0.004486 0
Guar Gum 9000-30-0 60 0.023576 0
Iron Oxide 1309-37-1 0.1 0.001136 0
Aluminum Oxide 1344-28-1 1.1 0.049351 0
Cinnamaldehyde 104-55-2 15 0.000318 0

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
2017-09-24 H2O 10 12752 Bbl 410140 C&J Energy Services STAGE 1/38

STAGES 2-37 SEE IMAGES

2017-09-28 H2O 15 10968 Bbl 406820 C&J Energy Services STAGE 49/49

STAGES 2-48 SEE IMAGES

For data sources see[5]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2017 XTO ENERGY INC. 0 0 0
2018 XTO ENERGY INC. 663000 0 0
2019 XTO ENERGY INC. 630465 0 49

For data sources see[6] [7]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2017 XTO ENERGY INC. Brine 0 0
2018 XTO ENERGY INC. Brine 0 0
2019 XTO ENERGY INC. Brine 4924 49

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1037825163 2018-10-23 0:00 CT No Violations 0.70
-1217189567 2018-4-12 0:00: CT No Violations 0.50
-1254087702 2019-3-7 0:00:0 PW No Violations 0.30
-1859240421 2018-3-28 0:00: CT No Violations 0.50
-1946292528 2020-10-23 0:00 PW No Violations 0.30
-2004951406 2020-5-11 0:00: PL No Violations 0.40
-2045137953 2018-5-7 0:00:0 CT No Violations 0.60
-2126201860 2018-4-5 0:00:0 CT No Violations
-486564147 2018-3-28 0:00: CS No Violations 0.50
-803457293 2017-3-22 0:00: CS No Violations 5.00
-816283123 2019-1-29 0:00: CT No Violations 0.50
-853053426 2018-4-26 0:00: CT No Violations 0.90
0187638341 2018-09-25 Completion Testing No Violations On site inspection accompanied by ODNR Engineer Mark Atkinson along with Ohio EPA representatives Sean Stephenson and John Rochott, also present representing XTO Energy was Gary Beal. It was observed on this day that there is 4 wells present on the well pad also identified as the Schnegg Well Pad owned by XTO Energy ODNR owner identification number 8063. The pad surface was observed to be free from standing water and does have a stone surface in good repair. The company has erected a earthen berm around the well pad surface and is recovering any surface water created on the well pad from the recent rain events. A large oval shaped metal construction polymer lined open top fresh water container has been erected on the South East side of the well pad. The well head is equipped with a lower A and upper B section with 2 diameter riser pipes attached to both well head sections. The A section riser pipe that is monitoring and controlling the pressure between the 13.375 and 9.625 diameter well head sections does have a valve present that is in the open position however no transducer is present. The B section riser pipe that monitors and controls the pressure between the 5.5 and 9.625 diameter casing strings does also have a valve present that is in the closed position with no electronic transducer present. Both riser pipes are ties into a steel line that runs into the production tank facility. The production tank facility consists of (6) tanks of steel construction that are situated inside a polymer lined steel containment dike area. The well head is equipped with (2) 7.0625 diameter primary master valves that are in the closed position with no sales line attached to the casing well head section.
0365211378 2019-01-08 Completion Testing No Violations On site inspection to witness the pressure testing of the well bore annular areas between the 5.5 & 9.625 casing strings along with the annular space of the 9.625 and 13.375 casing strings. The company had 2 completion engineers on site along with C&J Cement Service providing the pressure pumping and charting. The test were administered off a 10% loss over a 30 minute time frame. All annular well bore sections on each of the 4 wells on the pad were monitored for communication during the tests. I was on site between the hours of 10:00 am and 6:00 pm.
0486564147 2018-03-28 Casing String Witnessed No Violations On site follow up inspection accompanied by ODNR Inspector Andrew Corder. Upon inspection it was observed that the lower well head A and B sections well heads outlet ports war open with flow lines hooked up to the production facility tank battery. Atop the (B) section well head was a 7.0625 master valve followed by a flow cross and second master valve. Crews from Cactus well head were on site pressure testing the master valves and flow cross completion well head assembly.
0688201528 2018-10-09 Completion Testing No Violations Status check inspection found the well equipped with a lower A and upper B section with a production tree installed on the well head B section. There is annular pressure monitoring in place on both the A & B section well head section with 2 riser pipes installed on the outlet valves. The riser pipes are plumed into a main sales line that is connected to the production tank facility. The 9.625 well head (B) section valve that monitors the pressure between the 5.5 diameter production casing and the 9.625 intermediate casing string is in the open position. The 13.375 well head (A) section valve that monitors the pressure between the outside of 9.625 intermediate diameter casing string and the inside of the 13.375 diameter casing string is in the open position. No gauges are present on the well head annular ports, only electronic transducers.
0777442184 2018-05-16 Completion Testing No Violations Status check inspection found the well shut in and not in production due to a well control incident that occurred on 02/15/2018 involving the said well. The said well does have annular pressure monitoring in place and is being monitored by the companys SCADA electronic monitoring and recording system. The Divisions management is working with the company regarding the material modifications made to the well pad during the repair of the #7 well and along with the review of the well construction and presence of annular well bore pressure. The well will need to have a clean out run done with coil tubing prior to being placed back into production.
0803457293 2017-03-22 Casing String Witnessed No Violations
0816283123 2019-01-29 Completion Testing No Violations On site inspection found crews in the area repairing the production flow lines associated with the #7 & #9 wells on the well pad. The flow lines were severed during the repair of the #7 well after a well control incident on 02/15/2018. The area excavated on this day was observed to be on the West of the well head cellars between the #7 and #9 wells. The earthen material removed from the ditch is being compacted while it is being returned to the disturbed area. The said well is equipped with a lower A and upper B section with 2 diameter riser pipes installed on each section. Each rise pipe consists of 2 diameter flow lines equipped with shut off valves and electronic transducers. The riser pipes are tied into a single flow line that runs to the production tank facility. The A section which is the well head attached to the 13.375 diameter casing string and measures the pressure between the 13.375 and 9.625 casing string has a riser pipe attached to the well head section, the riser pipe valve is open to the production tank facility and the pressure remains at zero pounds. The B section which is the section between the 5.5 and 9.625 diameter casing strings is closed and the pressure reads zero pound pressure as reported by the company men on site. Recently a coil tubing unit was brought in and a clean out run was conducted on the 5.5 production tubing. No production tubing is set in the 5.5 production casing. A production tree has been installed on the well head B section. The well is shut in and has been since the incident on 02/15/2018.
0851671887 2019-01-17 Completion Testing No Violations Status check inspection found a coil tubing work over rig on location and rigged up on the # 9 well on the pad. The work over rig is owned by Key Energy said well has recently had the 5.5 diameter casing prepped for production. The B section well head pressure is 400 psi and the A section is tied into a low pressure recover system that is tied into the production tanks and open to the tanks.
0853053426 2018-04-26 Completion Testing No Violations On site inspection as a follow up to a well control incident that occurred on 02/15/2018 involving the said well. The said well has the production valves closed and is shut in and has not produced commercially. There has been flow lines and valves installed on the 13.375 and 9.625 diameter casing string well head sections and the valves on both sections are open. The company has installed annular pressure monitoring gauges on these sections. The annular pressure is monitored by the means of electronic gauges that send pressure reading back to the SCADA main frame recorder every 4 minutes. A remediation plan has been submitted and approved by the Divisions Hydrologist Jake Glascock. Crews from Parsons excavating is on site cutting the entire well pad surface down 2 to attempt to remove any contaminated material. Photographs taken on this day.
0974731749 2018-03-15 Completion Testing No Violations Follow up inspection to a well control incident that occurred on 02/15/2018 involving the said well. On this day I was accompanied by ODNR South East Region District Supervisor Brent Bear along with ODNR Engineering Supervisor Mark Atkinson and Engineer Tech Anthony Carlson with Jack Glascock from the Divisions Hydrology section also on site. Matters involving the remediation and sampling of areas affected by the well situation were addressed and documented by the ODNR Team members. Addressing the said well - The annular pressure between the 9.625 and 13.375 casing string was zero. The annular space between the 9.625 annular and the 13.375 internal has been compromised and is leaking. The company Supervisors on site Gary Beall and Tracy Vanfleet were on site an monitoring pressure on the other 3 wells on the pad.
1037825163 2018-10-23 Completion Testing No Violations Status check inspection accompanied by ODNR Inspector John Fleming with XTO Representatives Gary Beal and Tracy Vanscoy also present. The purpose of the meeting was to discuss the monitoring and recovery any pressure created from the annular spaces between the 5.5 and 9.625diameter casing strings and between the 9.625 and the 13.375 casing strings. On this day the 13.375 diameter casing well head section the valve was open and the 9.625 diameter casing the valve was open also. The 5.5 casing production casing is isolated with 2 master valves and a flow cross with no production flow lines attached. The 5.5 casing has bridge plugs and kill weight fluid inside of it. The production facility consists of 6 steel tanks each capable of 400 barrels capacity each. Also present is 4 vertical separators and 4 line heaters. The only metering present is the product produced from inside the production casing. No metering of the annular pressure is present. The 9.625 and 13.375 well head section annular pressure is being monitored electronically.
1217189567 2018-04-12 Completion Testing No Violations On site inspection to a well control incident that occurred on 02/15/2018 involving the Schnegg # 7 well. Upon inspection it was observed that there is a total of 4 wells on the pad. The said well is equipped with a 13.375 (A) well head section and a 9.625 (B) well head section. The annular sections are open to the atmosphere.
1254087702 2019-03-07 Production Wells No Violations On site inspection found the well is now in production and producing through a primary master valve and production tree that feeds into a sand trap and choke manifold system, the sand trap is being evacuated when needed into a 500 barrel horizontal tank that is set for temporary use inside a polymer lined containment area. The well head A&B sections have 2 diameter riser pipes attached to the service outlet ports, the riser pipes are equipped with both shut off and check valves along with electronic transducers. The purpose of the riser pipes is for annular pressure control and monitoring, the riser pipes are tied into a low pressure recover system. The production facility houses the equipment related to all (4) wells on the pad and consists of fluid separators and line heaters along with gas measurement devices, also present is a total of (6) steel tanks capable of holding 400 fluid barrels volume each. The above ground storage tank used for fresh water storage has been removed from the pad since my last inspection. The well pad surface and lease road are stone construction and in good repair, the areas disturbed during the past well control incident have been restored. Proper well identification is posted.
1313332013 2018-06-20 Completion Testing No Violations Status check inspection to document the status of the well and well pad reconstruction after a well control incident on 02/15/2018 involving the said well. The company has worked with the Divisions Hydrology and Engineering section to remediate the well pad and recover any affected material created during the incident. The well has been repaired at surface and the company has met with the Divisions management regarding moving foreword with the well completion process. The company is monitoring and control any annular pressures on the 4 existing wells on the pad.
1518741337 2018-02-15 Work Over Reconditioning No Violations On scene response to a report of a well control situation during the well completion drill out process. I received notification of the event at 10:07 am on this day from ODNR Inspector Andrew Corder who reported the company had notified Him of the loss of surface control of a well on the Schnegg Unit in York Township of Belmont County. I responded and arrived on scene at 10:40 am. Upon arrival at the end of Ohio State Route 148 and Belmont County Road 56 I stopped and made contact with the Belmont County EMA Director as well as Deputies with the Belmont County Sheriff and Troopers with the Ohio State Highway Patrol with multiple crews from area Fire Agencies also present. Information was gathered regarding the situation from crews working at the well site during the time of the incident. All personnel on site at the time of the incident was accounted for. I assisted in providing information to the area response emergency personnel and confirmed the well owner was contacted and was enroot and relayed information back to ODNR staff. I was also notified that the well owner XTO Energy did have well control specialist identified as Cudd Energy enroot from Texas. Addressing the well status. While enroot to location I was notified that the discharging fluid from the well had caught fire and was burning. During the course of the day I made 2 trips to the well pad to evaluate the situation from a safe standpoint. Both trips were made accompanied by ODNR Inspector Andrew Corder with the fist trip with a representative from XTO Energy and the second trip was to escort Cudd Well Control Specialist to the scene to evaluate the situation. The initial fire burnt from approximately 10:30 am until 11:56 am, the discharging gases continued to ignite throughout the day. Also as the day progressed multiple ODNR representatives arrive on scene including Chief Rick Simmers- Regional Supervisor Mike Moreland- Emergency Response personnel Scott King and Trish Cartmell. Incident Command wa
1518852055 2018-02-16 Work Over Reconditioning No Violations On this day I arrived on scene at 6:45 am and took part in a 7:00 am briefing and 10:00 am operations briefing with updates of the operations to be conducted at the well site on this day. The main objective of the day was to gain aerial footage of the site. During the late morning hours ODNR Supervisors Mike Moreland and Brent Bear also arrived on scene a the Incident Command center. Shorty after 12:00 pm I traveled to the Southern side of the well site and accessed the current condition of the well and location from a safe vantage point while monitoring air quality conditions. It was observed that the well head of the said well appeared to be leaking from the completion flow cross outlet valve above the well head master valve which is bolted to the B section of the permanent well head assembly. There was a coil tubing unit owned by Cudd Well Service sitting backed up to the well head and it has been reported that the 2.375 coil tubing was in the well bore at an approximate measured depth of approximately 4,500 a the time of the incident. However the lubricator stack for the coil tubing unit could be standing open and it appears that the coil tubing has been evacuated from the well bore and the coil tubing is scattered randomly over the site and the well is discharging from the lubricator stack also. No fires were visible on site. Several water truck were visible on site and reportedly owned by Stallion water service and could be seen still idling. Access to the site is still limited due to the heavy volume of fluid being discharged. It was also observed that the well pad had no perimeter earthen berm isolating the site from the adjoining water way. Photographs were taken on this day.
1520539369 2018-03-08 Completion Testing No Violations
1520623087 2018-03-09 Completion Testing No Violations Supervisor Brent Bear and myself visited the well pad this morning and Cudd well control is breaking down the pressure relief system used to flair the well. There was tractor trailers on site hauling off the pressure control system. The additional master control valve and flow cross will remain on the well head and shut in. The Company has indicate they will submitting a proposed plan for well repair process and the demobilization will reportedly continue through the weekend
1520886743 2018-03-12 Completion Testing No Violations On site follow up inspection to a recent well control incident that occurred on the morning of 02/15/2017. On this day I was accompanied on site by ODNR Deputies Dave Claus and Bob Worstall along with Terry Whitehair and John Fleming. XTO HSE representative on site was Chance Decker, also on site was 2 Gentlemen from the Service Company identified as Great White who indicated they were conducting a feasibility study in regards to the well repair. I provided the men from Great White with my outside diameter calipers and they gauged the casing string present below the well head and determined the 13.3735 diameter casing was not present directly below the well head and the 9.625diameter casing was present. The annulis between the 5.5 diameter casing and 9.625 diameter casing remained open and static. The well was observed to be migrating pressure from between the 9.625 annular and the inside of the 13.375 internal. All of Cudd Well control Equipment is off location. The remainder of the 300 barrel fluid volume tanks used in the well completion process is being moved off location.
1520967497 2018-03-13 Completion Testing No Violations
1521061399 2018-03-14 Completion Testing No Violations
1521158692 2018-03-15 Completion Testing No Violations I accompanied the following Division personnel on todays inspection: Inspector, Bill Stolarik, Engineering Technician, Anthony Carson, Engineering Supervisor, Mark Atkinson, and Hydrologist, Jake Glascock. During the inspection, Leidos Consulting was obtaining preliminary soil samples for XTO. A review of the proposed soil sampling map that had been received from XTO revealed two additional locations would need to be included. The first location was the burn pit that was used during the well control incident. The second location contained sand on the ground surface situated on the side of the well pad that did not contain a berm. The on site XTO HSE Representative and Brian Teller, XTO Operations Manager agreed to sample both locations, incorporate the sampling analysis for radium-226 and radium-228 and follow the recommendation to wait for the sample results prior to excavation and removal of soils to a landfill. Please refer to Bill Stolariks report for further details.
1521464320 2018-03-19 Completion Testing No Violations On site inspection to witness the well head removal and replacement. I arrived on site at 7:00 am to find crews from Cactus Well Head Company on site and preparing to remove the upper well head control stack master valves and flow cross section above the main well head A & B sections. Contact was made with XTO Company Representative on site Richard Lightner and Gary Clark. Also arriving on site at 7:30 am was a flow back crew with Express Energy to begin testing flow back operations on the 3 additional wells on the pad identified as the Schnegg Unit # 3-# 5 & # 9. The well head assembly internal seals were pressure tested by GE Well Head Company beginning at 10:00 am, this work was done prior to disassembling the well head from its original assembly state. Proceeding the well head pressure test the manual and hydraulic well control stack was removed and a night cap installed on the well head B section. Proceeding the well head break down excavation took place around the well head and wooden cribbing sills installed around the well head so a set of casing jacks may be installed to allow the well head to be removed.
1521548746 2018-03-20 Completion Testing No Violations On site follow up inspection to a well control incident that occurred on 02/155/2018 arriving on location at 6:30 am for the morning safety meeting. On this day crews were mobilized on the well pad preparing to break down the existing well head lower sections to repair any damaged casing strings. Crews with a company identified as GE Well Head was preparing to remover the upper B section when their hydraulic wrench broke that would allow the well head bolts to be removed. During the course of the work heavy rain fall began and for safety reasons the work was shut down for the day. ODNR South East Region District Supervisor Brent Bear was also on location and we accessed the well head and reviewed the well head repair plan submitted by the Company XTO. Work to remove the well head and repair any damaged casing is progressing as depicted on the proposed plan. A well pad perimeter ditch line has been excavated to isolate the well pad from the nearby Cats Creek. Any surface water created on the well pad is now channeled through the ditch line to a previously constructed impoundment area to the East of the well pad. The polymer lined steel containment dike around the well pad production facility has been repaired from where it was disassembled during the well control incident.
1521635021 2018-03-23 Completion Testing No Violations I accompanied Inspector, Bill Stolarik, during todays inspection to witness the installation and testing of the new wellhead. Please refer to Bills inspection report for further details.
1521637565 2018-03-21 Completion Testing No Violations On site inspection follow up to a well control incident that occurred involving the said well on 02/15/2018. Upon my arrival at 8:37 am it was observed that contractors from a well head company identified ad GE Well Head had removed the tree cap and B section of the original well head assembly to expose the 5.5 diameter 23 pound per foot casing string originally set in the well bore. Immediately proceeding gaining access to the 5.5 casing string a slip on casing collar was installed and welded onto the 5.5 diameter casing string. Then the casing jacks were set up over the well and the 5.5 diameter production casing was lifted up out of the well head slips with it taking 160,000 pounds of upward lifting force to move the casing. Because the lower well head was not sitting straight the crews had trouble getting the casing slips out of the bowl. Once the 5.5 slips were removed then the wooden sills were removed from the area around the well head and the casing strings were cut off to allow the lower well head sections to be removed by 18:00 hours on this day. Before leaving the site the 5.5 diameter casing string was secured with a valve.
1521730303 2018-03-22 Completion Testing No Violations On site follow up inspection to a well control incident that occurred on 02/15/2018 involving the said well. I arrived at 8:00 AM to find 2 contract welders on site with a welding company identified as Whites Welding. The welders were repairing the casing strings that had to be cut off below original heigth to allow for the removal of the damaged 13.375 casing string and well head assembly. Initially the 9.625 diameter casing string was brought back up and in preparation to install the 13.375 short pup joint it was discovered that the section of 13.375 was swelled out to 14.250 causing the 13.375 along with the 18.625 and 30 diameter string to have to be cut off again, this will delay the work for 3 to 4 hours total. The men counted to work through the afternoon making the needed repairs to the casing with anticipation of starting to reconstruct the well head tomorrow morning 03/23/2018.
1521814806 2018-03-23 Completion Testing No Violations On site inspection follow up to a well control incident that occurred on 02/15/2018 accompanied on this day by ODNR South East Region District Supervisor Brent Bear. Upon arrival at 8;00 am I witnessed contract workers with a company identified as GE Well Head installing the 13.375 lower well head section identified technically as the (A) well head section. Upon completing the setting of the lower section contract welders with Whites Welding welded the 13.375lower well head to the 13.375 diameter casing string that was previously repaired. Upon completion of the well the well was pressure tested between the (A) section lower inner seal and the bottom weld. The weld was tested to 900 (PSI) pounds per square inch with nitrogen gas for 15 minutes, the test was charted. The upper (A) section was then installed and torqued up and pressure tested to 4,700 psi, the section tested was between the top of the 9.625 casing hanger seal and 9.625 casing head seal. Following the (A) section completion the Energy Company casing jacks were installed and the 5.5 diameter casing pulled up to 250,000 pounds hydraulic up force and the 5.5 diameter casing slips were set, proceeding the setting of the slips the casing jack pressure was relaxed and the weight transferred over to the well head slips and the slip seals set by tightening the upper slip seal perimeter bolts. Once the slips were set the (B) Section of the well head was installed on the (A) section with a company owned master valve set on top of the (A) section. The well head replacement was completed on this day.
1522338641 2018-03-29 Completion Testing No Violations On site inspection to witness the well bore casing strings being pressure tested with C&J Energy Service providing the pump truck and Richard Lightner with XTO Energy also on location. The pressure test consisted of testing the 5.5 diameter casing, the 5.5 20 pound per foot production casing was first filled with 29.5 barrels of fresh water and pressure up to 3,398 (PSI) pounds per square inch, the casing was tested for 15 minutes and lost 53 pound with a final test pressure of 3,345 psi. The annulis between the 5.5 outside diameter and the 9.625 casing inside diameter was tested with the void taking a total of 2.5 barrels of fresh water to fill and then tested to 2,336 psi for 15 minutes with a final test pressure of 2,228 psi showing a 108 psi loss in 15 minutes. Also tested was the 13.375 54.5 pound per foot casing internal and 9.625 diameter casing annulis, this test was for 15 minutes also with the test pressure being 373 psi and a 56 psi loss down to 317 psi in 15 minutes. Both of the last 2 test were hydrostatic fluid test to check casing integrity.
1578506124 2020-1-8 0:00:0 PW No Violations 0.30
1859240421 2018-03-28 Completion Testing No Violations On site with Inspector William Stolarik to check on current operations. Cactus well head services was on site to pressure test the new well head that had been installed on this well following the incident in the previous month. We walked the site with XTO representative Rich Lightner and discussed operations. They will perform pressure testing in 15-
187638341 2018-9-25 0:00: CT No Violations 0.60
1882005589 2018-03-09 Completion Testing No Violations I accompanied Inspector, Bill Stolarik during this inspection. Please refer to Bills inspection report for the details from todays inspection.
2028564226 2018-06-04 Completion Testing No Violations Status check inspection as a follow up to a incident that occurred on 02/15/2018 involving a well on the location identified as the #7 well. My inspection found the well is shut in and not producing along with the other 3 wells on the pad. A 3rd party contractor identified as ShalePro is on location and the contractor is digging the flow lines up associated with the #3 and #5 wells on the pad and making changes to the flow line system both at the well head and production area. A underground plastic culvert located between the # 7 and # 9 wells on the pad is slated to be removed tomorrow 06/05/2018.
2045137953 2018-05-07 Completion Testing No Violations Status check follow up inspection to a well control incident that occurred on 02/15/2018 involving the said well. The well has been repaired and the 5.5 diameter production casing well head section is shut in. Both the 5.5 x 9.625 and 9.625 x 13.375 casing well head sections have valves installed and flow lines connected, the valves are in the open position. The Divisions Engineering and Hydrology sections are working with the company to remediate the well pad.
2126201860 2018-04-05 Completion Testing No Violations On site inspection accompanied by Engineer Technician Anthony Carson. On this day I witness XTO Representative Luke Beebe on site releasing annular pressure from the 13.375diameter casing and 9.625 diameter casing well head sections. All wells on the pad are still shut in following a well control incident on 02/15/2018 involving the said well. ODNR Engineer Technician Anthony Carson was working on the well pad remediation process with Randy Cutlip with XTO.
365211378 2019-1-8 0:00:0 CT No Violations 4.00
688201528 2018-10-9 0:00: CT No Violations 0.20
777442184 2018-5-16 0:00: CT No Violations 0.50
851671887 2019-1-17 0:00: CT No Violations 0.50
974731749 2018-3-15 0:00: CT No Violations 2.00

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. 
Retrieved from "https://www.wellwiki.org/index.php?title=34-013-21096&oldid=14271368"