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

34-013-21097

Well Details

Well ID: 34-013-21097
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 B
License Status: Producing
License Date: 2016-09-09
Spud Date: 2017-03-23
Spud Drilling Contractor: NOMAC DRILLING CORP
Final Drill Date: 2017-06-07
Well Total Depth: 16900.00 ft
Configuration: Horizontal
Latitude: 39.860000
Longitude: -80.860000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2016-09-09 Proposed Formations:POINT PLEASANT, Issued Date:9/9/2016, Expired Date:9/9/2018 12:00:00 PM, Drilling unit acres:355.447, Proposed Well Type:OG, Proposed Well Class:FWC
Reached Total Depth 2017-06-07
Correction to Well 2017-07-21 UPDATED TARGET.TAKEPOINT PER AS-DRILLED PLAT RCVD 7/10/2017 ALE
Construction Permit Expires 2018-09-09
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 10694 0
2019-04-04 16717 0
10694 0
16717 0
10694 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 09/24/2017 01/31/2018 10060 15,656,900.0 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 Proppants - Manufactured - Preferred Sands
HC-15 C&J Energy Services Bulk Acid Listed Below Listed Below 0 0 0
SI-6 C&J Energy Services Paraffin & Scale Additives Listed Below Listed Below 0 0 0
GA-7F C&J Energy Services Gelling Agents Listed Below Listed Below 0 0 0
CI-3 C&J Energy Services Acid Corrosion Inhibitors Listed Below Listed Below 0 0 0
Water XTO Energy/ExxonMobil Carrier Fluid Water 7732-18-5 100 88.5721 0
Water 7732-18-5 30 0.026241 0
Water 7732-18-5 85 0.868174 0
Water 7732-18-5 96 0.016678 0
Aluminum Oxide 1344-28-1 1.1 0.011873 0
Titanium Oxide 13463-67-7 0.1 0.003963 0
Sodium Acetate Anhydrous 127-09-3 3 0.002624 0
Monoethanolamine hydrochloride 2002-24-6 2 0.000347 0
Sorbitan Monooleate 1338-43-8 2 0.001749 0
Alcohols, C12-15-branched and linear,

ethoxylated propoxylated

120313-48-6 2 0.001749 0
*Quartz (SiO2) 14808-60-7 99 1.68984 0
2-Propenamide as residual 79-06-1 0.1 0.00008700 0
Aluminum Oxide 1344-28-1 1.1 0.03845 0
Crystalline Silica, quartz 14808-60-7 99.9 3.95942 0
Dimethylformamide 68-12-2 20 0.00038 0
Ethoxylated Alcohols 68002-97-1 100 0.00217 0
Distillates (Petroleum), Hydrotreated Light 64742-47-8 35 0.030615 0
Crystalline Silica, quartz 14808-60-7 99.9 3.49193 0
Iron Oxide 1309-37-1 0.1 0.001079 0
Polyethylene glycol 25322-68-3 50 0.005398 0
Titanium Oxide 13463-67-7 0.1 0.001079 0
Phosphonic Acid Salt Proprietary 6 0.001042 0
Polyurethane Resin (Nuisance Dust) 57029-46-6 2 0.034138 0
Proprietary Proprietary 100 0.00000400 0
Poly(oxy-1,2-ethanediyl),alpha-(4-nonylphenyl)-omega

hydroxy-, branched

127087-87-0 5 0.00009500 0
Bentonite Clay 68953-58-2 5 0.00217 0
Hydrochloric Acid 7647-01-0 15 0.153207 0
Crystalline Silica, quartz 14808-60-7 99.9 1.07831 0
Methanol 67-56-1 1 0.000174 0
1-DECANOL 112-30-1 5 0.00009500 0
2-Butoxyethanol 111-76-2 15 0.000285 0
Titanium Oxide 13463-67-7 0.1 0.003495 0
Cinnamaldehyde 104-55-2 15 0.000285 0
Water 7732-18-5 28.5 0.003077 0
2,2-Dibromo-3-nitrilo-propionamide (DBNPA) 10222-01-2 30 0.003239 0
Iron Oxide 1309-37-1 0.1 0.003495 0
Tar bases, quinoline derivs, benzyl chloride-quaternized 72480-70-7 15 0.000285 0
Iron Oxide 1309-37-1 0.1 0.003963 0
Triethyl Phosphate 78-40-0 2.5 0.00004800 0
Aluminum Oxide 1344-28-1 1.1 0.043597 0
Ethylene Glycol 107-21-1 40 0.00076 0
Proprietary Proprietary 0.7 0.00000300 0
Water 7732-18-5 30 0.00057 0
2-Propenoic acid, polymer with 2-propenamide, sodium salt 25987-30-8 30 0.026241 0
CJENERGY-Hydrocarbon-00013 64742-47-8 60 0.026044 0
Tar Bases, Quinoline Derivs. 68513-87-1 1 0.00001900 0
Ammonium Persulfate 7727-54-0 92 0.000421 0
Proprietary Proprietary 1 0.00000500 0
Isopropanol 67-63-0 2.5 0.00004800 0
Silica, Crystalline-Quartz 14808-60-7 1 0.00000500 0
Ethylene Glycol 107-21-1 5 0.004374 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 0.001749 0
Cured Resin Proprietary 13 0.00006000 0
Ammonium Chloride 12125-02-9 2 0.000347 0
1-OCTANOL 111-87-5 2.5 0.00004800 0
Guar Gum 9000-30-0 60 0.026044 0
Ethoxylated Sorbitan Monooleate 9005-65-6 1 0.000875 0
BR-11 C&J Energy Services Gel Breakers Listed Below Listed Below 0 0 0
FR-16 C&J Energy Services Friction Reducer Listed Below Listed Below 0 0 0
BIO-CLEAR 2000 C&J Energy Services Biocides Listed Below Listed Below 0 0 0
Sand C&J Energy Services Sand - Bulk - Pennsylvania Listed Below Listed Below 0 0 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
2018-01-31 H2O 15 9580 Bbl 402360 C&J Energy Services STAGE 38/38

STAGES 2-37 SEE IMAGES

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

STAGES 2-37 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. 0 0 0
2019 XTO ENERGY INC. 626532 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 8819 49

For data sources see[8] [9]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-106526134 2019-1-29 0:00: CT No Violations 0.50
-1246794968 2019-1-16 0:00: CT No Violations
-139431286 2018-4-5 0:00:0 CT No Violations 0.50
-1598887102 2018-3-15 0:00: CT No Violations 2.00
-1741249524 2018-3-14 0:00: CT No Violations 0.50
-1979061347 2020-1-8 0:00:0 PW No Violations 0.20
-2047685415 2018-10-9 0:00: CT No Violations 0.20
-529645395 2019-1-7 0:00:0 CT No Violations 4.00
-531712572 2018-10-23 0:00 CT No Violations 0.60
-737094080 2018-4-12 0:00: CT No Violations 0.50
-85777580 2017-5-4 0:00:0 PL No Violations 1.00
0022955388 2018-03-28 Completion Testing No Violations On site inspection follow up to a well control incident that occurred on 02/15/2018 involving the # 7 well on the pad. On this day I was accompanied by Inspector Andrew Corder with Rich Lightner and Todd Snyder with XTO also on location. The said well is currently shut in and all annulis have been plumed into a pressure relief flow back system. The company has electronic monitors on the 13.375 diameter and 9.626 diameter well head annular pressure outlet ports. The electronic transducers are downlinked into the companys SCADA recording system. The pressures on the 13.375 and 9.625 well heads were 163 psi on the 13.375 and 167 psi on the 9.625.
0085777580 2017-05-04 Preliminary Restoration No Violations
0106526134 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 522 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.
0139431286 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. There is still 7 stages of the stimulation to drill out. All wells on the pad are still shut in following a well control incident on 02/15/2018 involving the Schnegg # 7 well. ODNR Engineer Technician Anthony Carson was working on the well pad remediation process with Randy Cutlip with XTO.
0404685602 2018-03-22 Completion Testing No Violations Inspection report to document the well head annular pressures as a follow up to a well control incident that occurred on the well pad on 02/15/2018 involving the Schnegg #7 well. The 9.625 casing head which is the pressure between the 5.5 casing outside diameter and the 9.625 casing inside diameter had a recorded pressure of 1,649 pounds per square inch. The 13.375well head section which is the pressure between the 9.625 casing outside diameter and the 13.375 casing inside diameter had a recorded pressure of 1,205 pounds per square inch. Both records are recorded data from the Companys electronic recording system (SCADA).
0529645395 2019-01-07 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.
0531712572 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 closed. The 5.5 casing production casing is isolated with 2 master valves and a flow cross with no production flow lines attached. The well completion process is incomplete with 7 frack plugs left to drill out. 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.
0552146390 2018-03-13 Production Wells No Violations On site inspection follow up to a recent well control situation that occurred on 02/15/2018 involving the Schnegg Unit 7-H well. The said well is shut in and company has reported there is a total of 7 completion plugs left to drill out in the well. I have requested that annular pressure gauges be installed on the 13.375 and 9.625 well head sections.
0737094080 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. There is annular pressure monitoring in place on both the A & B well head sections. The annular casing well head sections have electrical monitoring data gauges installed that allow pressures to be recorded by the companied SCADA computer system. The production casing is currently shut in and the well is not in operation.
0826560347 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.
0883171700 2018-03-23 Completion Testing No Violations Inspection report to document the well head annular pressures as a follow up to a well control incident that occurred on the well pad on 02/15/2018 involving the Schnegg #7 well. The 9.625 casing head which is the pressure between the 5.5 casing outside diameter and the 9.625 casing inside diameter had a recorded pressure of 1,838 pounds per square inch. The 13.375well head section which is the pressure between the 9.625 casing outside diameter and the 13.375 casing inside diameter had a recorded pressure of 1,218 pounds per square inch. Both records are recorded data from the Companys electronic recording system (SCADA). The company has indicated that there is a total of (7) stages in the toe of the well bore that needs the completion plugs drilled out.
1153715115 2020-5-11 0:00: PW No Violations 0.30
1213400098 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.
1246794968 2019-01-16 Completion Testing No Violations Status check inspection found Key Energys Coil Tubing and Pressure Pumping service on location running in the 5.5 diameter production tubing with a 2.375 coil tubing string. The Key Energy units are circulating the previously set kill weight fluid out of the hole with 11.0 pound per gallon brine. Upon arrival they were at a depth of 9,500 in the well bore and at the time of my report at 13:30 hours they has circulated in to the 5.5 casing to a depth of 11,000. At this point they have stopped to conduct a bottoms up clean up cycle, they are circulating at a rate of 1.5 barrels per minute downhole with a applied pressure of 7,500 psi and a return pressure of 6,200 psi. The company man on site reported 800 pounds per square inch pressure on the well head B section the B section is the 5.5 x 9.625 annular space area.
1490410357 2017-03-24 Casing String Witnessed No Violations On site inspection to witness the conductor casing cement job with Lightening Energy top hole auger rig and C&J Cement Service. Lightening drilled a 36 diameter conductor borehole to 100 and ran 100 of 30 diameter .375 wall 118.65 pound per foot weld connection line pipe casing. C&J Cemented the casing with a 66 barrel class A cement mix consisting of 310 sacks of class A-2% calcium 1/4 pound per sack cement, the cement was displaced to 90 with 74 barrels of fresh water with cement returns witnessed to surface inside the tin horn cellar. The cement mix was verified by weight of scale. Both bedrock and freshwater was hit while drilling the hole at 25.
1491264621 2017-04-03 Casing String Witnessed No Violations On site inspection to witness the surface casing cement job with First Class Energy rig 10 on the hole and C&J Cement Service. The rig has drilled a 24 diameter borehole to a measured depth of 342 and ran 18.625 J-
1520553669 2018-03-08 Completion Testing No Violations Inspection report to document the company recently had a surface control incident on a well located directly besides the said well identified as the Schnegg Unit # 7. As a precautionary measure the well has been killed with heavyweight mud and is static. The company has been directed to install annular monitoring on the 13.375 and 9.625 well heads.
1529515868 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 #7 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.
1547736902 2019-01-17 Completion Testing No Violations Status check inspection found a coil tubing work over unit on location owned by Key Energy, the unit consists of the coil tubing unit a pressure pumping unit along with a Nitrogen Assist unit. The company has recently completed the clean out run and drilling out of the completion plugs inside the 5.5 diameter production casing. The total depth that the coil tubing achieved inside the 5.5 diameter production casing was 16,759. The current annular pressure on the well head B section which is the pressure between the 5.5 and 9.625 casing strings is 1000 pounds pressure. The A section well head is tied into the pressure recovery system and open to the production tanks. The 5.5 diameter casing string pressure is 2,600 psi and the hole is loaded with 11.2 pound per gallon brine. At 10:45 am Key energy is completed pulling out of the hole with their coil tubing workover string and is breaking down off the well head. Workover completions are complete at this point and the well head will be prepped for the installation of production equipment.
1551967789 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.
1598887102 2018-03-15 Completion Testing No Violations Follow up inspection to a well control incident that occurred on 02/15/2018 involving the # 7-H 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 # 3 well status- the well is currently shut in and not producing the annular pressure between the 5.5 diameter production casing and 9.625 intermediate casing was documented by gauge at 1,068 psi (pounds per square inch) the 9.625 well head section was plumed into a choke manifold owned by Stingray Pressure Control and blead down. The pressure was blead down to zero in 15 minutes. The 9.625 x 13.375 annulis had a recorded 769 psi on it and was also blead down to zero. The XTO Company representative on site identified as Gary Beall indicate they would formulate a plan to remove the plug. I also indicated to Mr. Beall that the 13.375 x 18.625 annular needed to be pressure monitored.
1632591593 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 a well on the pad identified as the Schnegg Unit B 7-H. 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. There is a reported 7 completion plugs left to drill out in the well bore.
1680988817 2020-10-23 0:00 PW No Violations 0.30
1741249524 2018-03-14 Completion Testing No Violations
1808121185 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 Schnegg Unit 7-H well. The said well has the production valves closed and is shut in and has not producing commercially to this day. The company reports they have 7 completion plugs to drill out of the 5.5 diameter casing string. There has been flow lines and valves installed on the 13.375 and 9.625 diameter casing string well head sections and 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 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.
1968908052 2018-03-19 Completion Testing No Violations On site inspection and documentation of the said well annular pressures. On this day I witnessed the 13.375 casing well head section had 1,100 psi, this well head section is the area between the 13.375 internal pipe area and the 9.625 diameter casing external pipe area. The 9.625 well head section had 1,083 psi, this is the area between the 9.625 diameter casing internal pipe area and the 5.5 diameter casing external pipe area. Electronic transducers have been installed on both well head sections and are taking reading every 4 minutes.
2047685415 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 closed 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.
2142081076 2018-05-07 Completion Testing No Violations Status check inspection as a follow up to a well control incident that occurred on 02/15/2018 involving a well on the pad indicated as the Schnegg Unit B 7H. Addressing the said well, the well 5.5 diameter casing section is shut in, the company has submitted a proposal to drill out the remainder of the 7 completion plugs left to drill out. There is annular pressure monitoring in place on both the 5.5 x 9.625 casing well head section and the 9.625 x 13.375 casing well head sections. The 13.375 and 9.625 casing well heads have flow lines and valves attached with the 13.375 standing open to the flow line that has been installed that runs to the production facility. There is also vent lines that are attached to steel plates welded between the 13.625 x 18.625 and 18.625 x 30. Both 1 lines are visible above ground level and have valves attached that are in the open position, no pressure relief devices are present.
22955388 2018-3-28 0:00: CT No Violations 0.70
404685602 2018-3-22 0:00: CT No Violations 0.50
552146390 2018-3-13 0:00: PW No Violations
826560347 2018-6-4 0:00:0 CT No Violations 0.50
883171700 2018-3-23 0:00: CT No Violations 0.50

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. 
Retrieved from "https://wellwiki-prod.cloud.arc.gwu.edu/index.php?title=34-013-21097&oldid=14271376"