34-155-24080

Well Details

Well ID: 34-155-24080	Loading map... {"type":"SATELLITE","minzoom":false,"maxzoom":false,"types":["ROADMAP","SATELLITE","HYBRID","TERRAIN"],"mappingservice":"googlemaps3","width":"100%","height":"350px","centre":false,"title":"","label":"","icon":"","visitedicon":"","lines":[],"polygons":[],"circles":[],"rectangles":[],"wmsoverlay":false,"copycoords":false,"static":false,"zoom":14,"layers":[],"controls":["pan","zoom","type","scale","streetview","rotate"],"zoomstyle":"DEFAULT","typestyle":"DEFAULT","autoinfowindows":false,"resizable":false,"kmlrezoom":false,"poi":true,"markercluster":false,"clustergridsize":60,"clustermaxzoom":20,"clusterzoomonclick":true,"clusteraveragecenter":true,"clusterminsize":2,"imageoverlays":[],"kml":[],"gkml":[],"searchmarkers":"","enablefullscreen":false,"scrollwheelzoom":false,"locations":[{"text":"","title":"","link":"","lat":41.17,"lon":-80.81,"icon":""}]}
Country: United States
State: Ohio
County: Trumbull
Municipality: Weathersfield Township
Operator Name: PIN OAK ENERGY PARTNERS LLC
Well Pad ID: US-OH-000575
Farm/Lease Name: KIBLER
License Status: Producing
License Date: 2013-09-24
Spud Date: 2013-09-25
Spud Drilling Contractor: PATTERSON DRILLING
Final Drill Date: 2013-11-21
Well Total Depth: 14384.00 ft
Configuration: Horizontal
Latitude: 41.170000
Longitude: -80.810000

For data sources see^[1]

Well History

Well Status	Well Status Date	Comment
APP	2013-09-24	Proposed Formations:POINT PLEASANT, Issued Date:9/24/2013, Expired Date:9/24/2015 12:00:00 PM, Drilling unit acres:551.1, Proposed Well Type:OG, Proposed Well Class:EDPW
Reached Total Depth	2013-11-21
Correction to Well	2014-02-14	CHANGE IN SURFACE, TARGET AND TAKE-POINT INFORMATION (FOOTAGE AND COORDINATES) FROM AS DRILLED SURVEY PLAT. UNIT SIZE CHANGED TO 546.67 ACRES.
Completion Report Received	2014-08-04
Construction Permit Expires	2014-09-24
Change of Owner	2017-09-12	Operator changed from 8966, HALCON OPERATING COMPANY INC to 9722, PIN OAK ENERGY PARTNERS LLC
Record Last Modified	2017-09-12

For data sources see^[2]

Perforation Treatments

Perforation Date	Interval Top (ft)	Interval Base (ft)	Number of Shots
2014-02-04	6819	14208	888
	6819	14208	888
	6819	14208	888

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	12/16/2013	12/19/2013	6450	9,987,940.0	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	Hydrochloric Acid (HCl)	FTSI	Acid	Water	7732-18-5	63	0.00965781	0
	Hydrochloric Acid (HCl)	FTSI	Acid	Hydrogen Chloride	7647-01-0	37	0	1,465,220.0
	FE-100L	FTSI	Iron control	Water	7732-18-5	60	0.00001942	0
	FE-100L	FTSI	Iron control	Citric acid	77-92-9	55	0.00001780	3093
	Water	Operator	Carrier	Water	7732-18-5	100	0.871521	83,299,500.0
	100 Mesh Sand	FTSI	proppant	Silica, Quartz	14808-60-7	100	0.00141791	135523
	NE-450	FTSI	Non-emulsifier	Proprietary non-hazardous materials	Proprietary	100	0	0
				Proprietary	Proprietary	0	0	0
				Oxyalkylated alcohol	Proprietary	5	0	61753
	CS-750 SI	FTSI	Scale Inhibitor	Water	7732-18-5	60	0.000162939	0
				Glycerin	56-81-5	20	0.00005431	25956
				Proprietary	Proprietary	25	0.00006789	0
	CI-150	FTSI	Acid Corrosion Inhibitor	Alkylene Oxide Block Polymer	Proprietary	10	0	0
				Water	7732-18-5	5	0	0
				Ethylene Glycol	107-21-1	30	0.00001220	0
				Dimethylformamide	68-12-2	10	0	0
				Fatty Acid Salt	Proprietary	0.1	0	0
				Organic amine resin salt	Proprietary	30	0.00001220	0
				Isopropanol	67-63-0	30	0.00001220	3887
				Aliphatic alcohol	Proprietary	0.1	0	0
				Aromatic aldehyde	Proprietary	10	0	0
				Diethylene glycol	111-46-6	1	0	0
				Quaternary ammonium compound	Proprietary	10	0	0
				Fatty Acid	Proprietary	0.1	0	0
	FRW-200	FTSI	Friction reducer	Alcohols (C12-C16), ethoxylated	68551-12-2	4	0.00001354	0
				Acrylamide	79-06-1	0.1	0	0
				Alcohols (C12-C14), ethoxylated	68439-50-9	4	0.00001354	0
				Polyethylene glycol monooleate	9004-96-0	3	0.00001015	0
				Alcohols (C10-C16), ethoxylated	68002-97-1	4	0.00001354	0
				Sorbitol Tetraoleate	61723-83-9	2	0	0
				Dewaxed heavy paraffinic	64742-65-0	1.5	0	0
				Ammonium Acrylate	10604-69-0	0.5	0.00000169	0
				Alkyloxypolyethyleneoxyethanol	84133-50-6	1	0	0
				Acrylamide P/W acrylic acid, ammonium salt	26100-47-0	25	0.00008460	0
				Petroleum distillate hydrotreated light	64742-47-8	26	0	32344
				Ammonium Chloride	12125-02-9	12	0.00004061	0
				Hydrotreated heavy paraffinic	64742-54-7	5	0.00001692	0
				Water	7732-18-5	48	0.000162431	0
				Copolymer of acrylamide and sodium acrylate	25987-30-8	33	0.000111671	0
				Isopropanol	67-63-0	0.3	0.00000102	0
				Sorbitan Monooleate	1338-43-8	3	0.00001015	0
				Surfactant	Proprietary	7	0.00002369	0
	ICI-3240	FTSI	Biocide	Water	7732-18-5	55	0	0
				Dazomet (Tetrahydro-3, 5-dimethyl-2H-1, 3, 5-thiadiazine-2-thione.	533-74-4	24	0.000111312	44330
				Sodium Hydroxide	1310-73-2	23	0.000106674	0
	SHALE SURF 1000	FTSI	Surfactant	Water	7732-18-5	85	0	0
				Ethoxylated alcohol	Proprietary	20	0.00016069	76793
				Methanol	67-56-1	10	0	0
				2-Butoxyethanol	111-76-2	10	0	0
				Cyclohexene	5989-27-5	10	0	0
				Poly-(oxy-1,2-ethanediyl)-alpha-undecyl-omega	34398-01-1	11	0	0
				2-Propanol	67-63-0	10	0	0
	30/50 White	FTSI	proppant	Silica, Quartz	14808-60-7	100	0.109135	10,431,000.0

For data sources see^[4]

Stimulations Data

Stimulation Date	Chemical Agent	Fracking Fluid Volume	Mass of Proppant Used (lb)	Fracking Company	Comments
2013-12-26	H2O	10013 Bbl	378837	Frac Tech Services	STAGE 20 30 SHOTS
2013-12-24	H2O	9603 Bbl	299040	Frac Tech Services	STAGE 14 30 SHOTS
2013-12-23	H2O	6845 Bbl	375100	Frac Tech Services	STAGE 12 30 SHOTS
2013-12-28	H2O	11556 Bbl	386795	Frac Tech Services	STAGE 27 30 SHOTS
2013-12-26	H2O	8936 Bbl	501938	Frac Tech Services	STAGE 19 30 SHOTS
2013-02-17	H2O	8215 Bbl	377557	Frac Tech Services	STAGE 3 30 SHOTS
2013-12-28	H2O	7458 Bbl	381800	Frac Tech Services	STAGE 26 30 SHOTS
2013-12-28	H2O	7354 Bbl	378064	Frac Tech Services	STAGE 25 30 SHOTS
2013-12-28	H2O	6977 Bbl	385500	Frac Tech Services	STAGE 28 30 SHOTS
2013-12-23	H2O	7036 Bbl	373569	Frac Tech Services	STAGE 11 30 SHOTS
2013-02-17	H2O	6859 Bbl	303075	Frac Tech Services	STAGE 2 24 SHOTS
2013-12-17	H2O	7433 Bbl	367500	Frac Tech Services	STAGE 4 30 SHOTS
2013-12-26	H2O	10626 Bbl	378074	Frac Tech Services	STAGE 21 30 SHOTS
2013-12-27	H2O	8765 Bbl	69185	Frac Tech Services	STAGE 22 30 SHOTS
2013-12-29	H2O	6713 Bbl	378200	Frac Tech Services	STAGE 29 30 SHOTS
2013-12-25	H2O	7313 Bbl	371784	Frac Tech Services	STAGE 16 30 SHOTS
2013-12-29	H2O	6905 Bbl	408427	Frac Tech Services	STAGE 30 30 SHOTS
2013-12-18	H2O	7141 Bbl	378900	Frac Tech Services	STAGE 7 30 SHOTS
2013-12-25	H2O	6895 Bbl	2447	Frac Tech Services	STAGE 18 30 SHOTS
2013-12-24	H2O	12151 Bbl	370556	Frac Tech Services	STAGE 15 30 SHOTS
2013-12-18	H2O	8041 Bbl	379901	Frac Tech Services	STAGE 5 30 SHOTS
2013-12-27	H2O	7758 Bbl	379047	Frac Tech Services	STAGE 23 30 SHOTS
2013-12-22	H2O	9770 Bbl	376898	Frac Tech Services	STAGE 8 30 SHOTS
	H2O	0 Bbl	0	Frac Tech Services	STAGE 9 30 SHOTS
2013-12-24	H2O	7961 Bbl	369432	Frac Tech Services	STAGE 13 30 SHOTS
2013-12-27	H2O	9291 Bbl	376089	Frac Tech Services	STAGE 24 30 SHOTS
2013-12-25	H2O	7232 Bbl	385970	Frac Tech Services	STAGE 17 30 SHOTS
2013-12-16	H2O	10897 Bbl	303946	Frac Tech Services	STAGE 1 24 SHOTS
2013-12-23	H2O	6916 Bbl	380460	Frac Tech Services	STAGE 10 30 SHOTS
2013-12-18	H2O	8854 Bbl	378900	Frac Tech Services	STAGE 6 30 SHOTS

For data sources see^[5]

Production Data

Period	Operator Name	Gas Quantity (mcf)	Oil Quantity (bbl)	Production Days
2014	HALCON OPERATING COMPANY INC	325246	18523	320
2015	HALCON OPERATING COMPANY INC	208730	3865	356
2016	HALCON OPERATING COMPANY INC	177806	1904	365
2017	PIN OAK ENERGY PARTNERS LLC	140944	937	331
2018	PIN OAK ENERGY PARTNERS LLC	87753	589	293
2019	PIN OAK ENERGY PARTNERS LLC	23312	111	90

For data sources see^[6] ^[7]

Waste Data

Period	Operator Name	Waste Type	Quantity (bbl)	Production Days
2014	HALCON OPERATING COMPANY INC	Brine	23217	320
2015	HALCON OPERATING COMPANY INC	Brine	2167	356
2016	HALCON OPERATING COMPANY INC	Brine	1421	365
2017	PIN OAK ENERGY PARTNERS LLC	Brine	700	331
2018	PIN OAK ENERGY PARTNERS LLC	Brine	245	293
2019	PIN OAK ENERGY PARTNERS LLC	Brine	76	90

For data sources see^[8] ^[9]

Inspection Data

Inspections Performed

Inspection ID	Inspection Date	Inspection Type	Inspection Result	Inspection Comments
-2096624372	2013-11-12 0:00	DD	No Violations	0.50
-25124419	2013-11-4 0:00:	DD	No Violations	1.00
-513919017	2017-6-19 0:00:	UP	No Violations	0.30
-538789172	2014-1-31 0:00:	PW	No Violations	1.00
-787041058	2013-9-28 0:00:	DD	No Violations
-799819180	2013-9-30 0:00:	DD	No Violations	1.50
0025124419	2013-11-04	Drill / Deepen / Reopen	No Violations	My inspection found the Patterson Rig 256 making repairs to the top drive on the rig. There are no violations at this time.
0029807560	2017-10-06	UrbanProduction Wells	No Violations	I found that Pin Oak Energy has taken ownership from Halcon on 9/12/2017. There is an identification sign posted at the well pad entrance. The well pad is secure with a locked gate. The well is in production. The flare is in operation.
0177240998	2014-05-06	UrbanPreliminary Restoration	No Violations	I was on location to perform a urban preliminary restoration inspection. I found during my inspection the well was in production. The tank battery consisted of eight, 400 barrel production tanks, a compressor, and separators. The production equipment was shared with permit number 2-4064. A steel and lined dike surrounded the tanks. A flare was burning off flash gas from the production tanks. An identification sign was posted at the entrance to the lease road. Warning and safety signs were properly posted. Safety equipment was installed on the tanks. The lease road was in good repair and shared with two NCL wells. There was a locked gate at the entrance to the well pad. All drainage and erosion controls were in place. The well and production equipment were surrounded by a wooden post and wire fence. The entire area around the well pad was being used for agricultural purposes by the landowner.
0348300800	2016-08-11	Production Wells	No Violations -4064. The equipment on the pad consists of the following: 8 Storage tanks 1 Flare 2 Gas processing units (GPU) 2 Oil stabilization units 1 Dehydrator 1 Thermal electric generator (TEG) 1 Production well on the pad 1 Sand separator Site fenced and man doors locked
0513919017	2017-06-19	UrbanProduction Wells	No Violations	I found the well not in production due to Halcon performing maintenance on the compressor on the day of my inspection. I found Neil Callahan, well tender for Halcon, working was on location. The well is equipped with a plunger lift assembly. Identification signs are posted at the access road entrance, on the well, and next to the tank battery. All of the man doors surrounding the pad are secure with chains and bolts and nuts. The access road is in good repair. The well pad is shared with permit number 2-4064. The equipment on the pad consists of the following: 8 Storage tanks 1 Flare 2 Gas processing units (GPU) 2 Oil stabilization units 1 Dehydrator 1 Thermal electric generator (TEG) 1 Production well on the pad 1 Sand separator Site fenced and man doors locked
0529009559	2013-10-04	Drill / Deepen / Reopen	No Violations	My inspection found Halcon removing panels from the far north end of the sound barrier and relocating the panel to the southern end. The sound barrier will extend approximately another 100 further south along the tree line.
0538789172	2014-01-31	Production Wells	No Violations	Northeast Region Supervisor Tom Hill and myself performed a status check on the above location. We walked the location and observed some of there production equipment operations . ID signs were posted. No noted violations were noted at this time.
0741014162	2013-10-23	Drill / Deepen / Reopen	No Violations	My inspection found Halcon rigging up the Patterson Rig 256. Halcon expects to start drilling Hole #2 today (10/23/2013).
0787041058	2013-09-28	Drill / Deepen / Reopen	No Violations	I was notified by Jim Howell from Halcon that they tagged the cement at approximately 6 ft from the surface. On Monday they will be cementing the remaining 6 ft. They will notify Inspector Skidmore before they perform the cement job.
0799819180	2013-09-30	Drill / Deepen / Reopen	No Violations	I witnessed Halcon grout the backside of the conductor casing. Halcon used 5 yards of grout from City Concrete LLC. The grout was dumped into the annulus until completely full, then the remaining grout was placed throughout the bottom of the cellar.
0810574517	2014-02-13	Completion Testing	No Violations	My inspection found the flare lit. I was notified at 10:45 am by the Halcon field supervisor, Clint. I noticed no noise coming from the flare. The Tetra operator stated the flare was burring off approximately 500,000 MCFs. Photos of the flare were taken.
0892201077	2013-10-23	UrbanProduction Wells	No Violations	I found the weeds in the tank battery cut down for a proper inspection of the dike. I called Jim Adams, the well tender, 330-883-7890. The dike was not capable of meeting containment requirements. I told Jim to build a new dike.
1004563008	2013-12-10	Drill / Deepen / Reopen	No Violations	My inspection found that Patterson 256 Rig had moved from the well location. An above ground impound container was installed and being filled. Halcon was preparing the well and site for fracturing operations.
1044672999	2014-01-29	Production Wells	No Violations	My inspection found Halcon working on placing the well into production. There was a small flare operating while working on the compressors. Halcon had a steel cage surrounding the well.
1070334676	2013-10-29	Drill / Deepen / Reopen	No Violations	My inspection found Halcon currently drilling at a depth of 2,240. All drainage and erosion controls were in place. There are no violations at this time.
1270082892	2013-12-23	Completion Testing	No Violations	My inspection found Halcon beginning well stimulation stage 14 out of stage 30. The company performing the operations was called Frac Tech. Wildcat was working the wire line. Halcon shut-in Kibler 1H until the well stimulation for this well was complete. I noticed no violations at this time.
1380542321	2013-09-27	Drill / Deepen / Reopen	No Violations	I was on location today for the cementing of the conductor casing. Lightning Energy Services was the drilling contractor on location for Halcon. Lightning drilled a 36 hole to 60. I was informed while drilling the hole they had a cave in. The hole was cleaned out and drilling continued to the current depth. The conductor casing was 30 and was set to the 60 depth. Universal Well Services was the cementing contractor on location for the cementing of the conductor pipe. Universal broke circulation and circulated 85 BBLs of water to the surface. Universal then switched over to cement and pumped 67 BBLs. The cement mud scaled at 15.6 ppg. The cement was displaced leaving a 20 ft shoe in the casing. No cement returns were witnessed at the surface. I advised Halcon to let the cement set, tag it, and let me know how deep it is.
1383746875	2013-11-02	Drill / Deepen / Reopen	No Violations	I was on location for the cementing of the Intermediate casing. Halcon has drilled a 17.5 hole to 2775 and set 13.375 casing to 2750. Universal was the cement contractor on location. Universal broke circulation on the well and began pumping 25 BBLs of gel with 100 lbs. of flake, followed by 450 BBLs of cement. The cement was mudscaled at 15.7 ppg. There was 2 BBLs of good cement returns. Fire extinguishers were available around the location. The permit was in the company mans trailer. The pad was in stable condition. No violations found.
1385551535	2013-11-25	Drill / Deepen / Reopen	No Violations	Universal Well Service cemented the production casing for Halcon. Patterson Rig 256 drilled Hole #4 using two different drill bit sizes; 8.75 from 2,750 to 7,532 and 8.5 from 7,532 to 14,384. The 5.5 production casing was set at 14,360 using 236 centralizers. Universal established circulation using 10 bbls of fresh water. The operator pumped 90 bbls of a weighted spacer followed by 10 bbls of water. Next, Universal mixed and pumped 1,140 sacks of Type 1 cement with 4% gel as the lead followed by 1,970 sacks of Type 1 cement with 2% gel as the tail. The cement was displaced to 14,304 using 303 bbls of fresh water. Once the plug landed, the operator pressured up to 500 psi over operating pressure. After 5 minutes, pressure was released and the floats held static. There were 45 bbls of good cement returned to surface.
1392227653	2014-04-11	Completion Testing	No Violations	My inspection found Halcon pressure testing the well. Halcon had flow back tanks and a flare stack on location. I spoke to the field supervisor, Clint. I instructed Clinton contact me immediately when lighting the flare. I noticed a smaller flare that was operational next to the production facility. The flare was burning off vapors from the production tanks for permit number 2-4064.
1392384586	2014-02-14	Completion Testing	No Violations	My inspection found the flame from the flare larger this morning; however, the wind is stronger today. I detected no noise coming from the flare. I sat approximately 100 yards north from the flare and the only noise I heard was the compressor, which was located over a 100 yards west of the flare in the production facility. While sitting on location, a train went past that made more noise than the compressor. The railroad track is 0.25 miles south of the well and flare.
1561085009	2018-01-04	Production Wells	No Violations	I conducted an inspection of this well site with DOGRM inspector, John Fleming. The well was equipped with a plunger lift assembly and the annulus and flow line valves were open. Production records for this welll were current. The tank battery consisted of eight 400 BBL production tanks and was diked. Other production equipment on site included two mechanical separators, one line heater, and one GPU. The site is shared with well 1H (2-4064). The secondary eathern berm was intact and the pad was stable. The signage was located at the main locked gate. The lease access was stable. No violations observed.
1759306068	2013-11-20	Drill / Deepen / Reopen	No Violations	My inspection found Halcon drilling the horizontal at a current depth of 12,641. I noticed no violations at this time.
177240998	2014-5-6 0:00:0	UL	No Violations	1.00
1869338010	2016-02-24	Production Wells	No Violations	I was on location for a status check. My inspection found the access road is in good repair. Identification signs are posted at the access road entrance. The pad is fenced and all man doors are unlocked. The #2-3H is in production. The well is equipped with a plunger lift assembly. There is a steel dike around the storage tanks. The equipment on the pad consists of the following: 8 Storage tanks 1 Flare 2 Gas processing units (GPU) 2 Oil stabilization units 1 Dehydrator 1 Thermal electric generator (TEG) 1 Production well on the pad 1 Sand separator Site fenced and man doors locked I called and spoke with Zane Oshurac from Halcon. I instructed Mr. Oshurac to secure all man doors with locks and post an identification sign at the well.
1935334178	2014-04-12	Completion Testing	No Violations	I arrived on location at 1045 am. My inspection found the flare not lit. Clint, the field supervisor, stated the well was flowing back water. Also, Clint stated the Lordstown Fire and Police Departments were notified concerning the flare.
1964891522	2013-10-26	Drill / Deepen / Reopen	No Violations	I witnessed Universal Well Service cement the surface casing for Halcon using the stab-in method. Patterson Rig 256 drilled Hole #2 to 486 RKB and set 20 casing at 470 RKB with 5 centralizers. The casing had a rating of J-55. Universal established circulation with 10 bbls of fresh water. The operator pumped 1044 sacks of Type 1 cement. The cement was displaced with 7 bbls of fresh water. I witnessed 10 bbls of good cement returned to surface. Next, Universal temporarily shut down operations and Patterson 256 pulled one strand of drill pipe. The operator used 12 bbls of fresh water flush out the drill pipe.
2096624372	2013-11-12	Drill / Deepen / Reopen	No Violations	My inspection found Halcon currently drilling at a depth of 5,933 and building the curve for the horizontal. I noticed no violations at this time.
2126000644	2014-02-13	Completion Testing	No Violations	My inspection at 8:30 am found no flare at this time. The Tetra operator said the well was still flowing water back.
29807560	2017-10-6 0:00:	UP	No Violations	0.20
348300800	2016-8-11 0:00:	PW	No Violations	0.50
529009559	2013-10-4 0:00:	DD	No Violations	0.50
741014162	2013-10-23 0:00	DD	No Violations	0.50
810574517	2014-2-13 0:00:	CT	No Violations	1.00
892201077	2013-10-23 0:00	UP	No Violations	0.50

For data sources see^[10]

References

↑ "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.
↑ "Risk Based Data Management System - Well and WellHistry Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16.
↑ "Risk Based Data Management System - Perfs Table". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16.
↑ "FracFocus Fracking Chemicals Database". 2019-04-02. Retrieved 2019-06-19.
↑ "Risk Based Data Management System - tblStimulation Table". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16.
↑ "Risk Based Data Management System - Production Table - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16.
↑ "Combined Production - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16.
↑ "Risk Based Data Management System - Production Table - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16.
↑ "Combined Production - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16.
↑ "Risk Based Data Management System - tblInspection, tblInspFail and tblinspFlDesc Tables". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16.

[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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