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Well ID: 34-029-21716 | Loading map...
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Country: United States | |
State: Ohio | |
County: Columbiana | |
Municipality: Washington Township | |
Operator Name: EAP OHIO LLC | |
Well Pad ID: US-OH-000465 | |
Farm/Lease Name: JANIE TRUST 5-12-3 | |
License Status: Producing | |
License Date: 2017-05-10 | |
Spud Date: 2012-04-12 | |
Spud Drilling Contractor: PATTERSON DRILLING | |
Final Drill Date: 2012-04-25 | |
Well Total Depth: 12969.00 ft | |
Configuration: Horizontal | |
Latitude: 40.610000 | |
Longitude: -80.760000 |
For data sources see[1]
Well Status | Well Status Date | Comment |
---|---|---|
APP | 2012-02-24 | Proposed Formations:, Issued Date:2/24/2012, Expired Date:2/23/2014 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:COND, Proposed Well Class:O |
APP | 2012-03-06 | Proposed Formations:POINT PLEASANT, Issued Date:3/6/2012, Expired Date:3/6/2014 12:00:00 PM, Drilling unit acres:148, Proposed Well Type:OG, Proposed Well Class:EDPW |
Reached Total Depth | 2012-04-25 | TEMPORARY INACTIVE CHECKLIST REC'D FROM COMPANY 05/02/2016/12/1/16--REC'D TA2 CHECK LIST |
Correction to Well | 2012-11-02 | UNIT SIZE DECREASED TO 116.81 ACRES. CORRECTION TO TARGET INFORMATION (FROM AS DRILLED SURVEY PLAT): FOOTAGE & X-Y COORDINATES. |
APP | 2015-06-05 | Proposed Formations:POINT PLEASANT, Issued Date:6/5/2015, Expired Date:6/4/2017 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:OG, Proposed Well Class: |
Correction to Well | 2016-04-29 | CGANEH IN ACREAGE, TAKEPOINT PER AS DRILLED PLAT-ALE |
APP | 2017-05-10 | Proposed Formations:POINT PLEASANT, Issued Date:5/10/2017, Expired Date:5/10/2019 12:00:00 PM, Drilling unit acres:0, Proposed Well Type:OG, Proposed Well Class: |
Construction Permit Expires | 2018-05-10 | TEMPORARY INACTIVE CHECKLIST REC'D FROM COMPANY 05/02/2016/12/1/16--REC'D TA2 CHECK LIST |
Completion Report Received | 2018-12-11 | TEMPORARY INACTIVE CHECKLIST REC'D FROM COMPANY 05/02/2016/12/1/16--REC'D TA2 CHECK LIST |
Record Last Modified | 2018-12-19 | TEMPORARY INACTIVE CHECKLIST REC'D FROM COMPANY 05/02/2016/12/1/16--REC'D TA2 CHECK LIST |
For data sources see[2]
Perforation Date | Interval Top (ft) | Interval Base (ft) | Number of Shots |
---|---|---|---|
2014-03-19 | 8939 | 12830 | 245 |
8939 | 12830 | 245 | |
8939 | 12830 | 245 |
For data sources see[3]
Job Number | Job Start Date | Job End Date | True Vertical Depth (ft) | Total Water Volume (gal) | Total Non-Water Volume (gal) |
---|---|---|---|---|---|
1 | 05/29/2012 | 05/29/2012 | 8364.00 | 3,213,420.0 |
Job Number | Trade Name | Supplier | Purpose | Ingredient Name | CAS Number | Additive Percentage by Mass | Job Percentage by Mass | Mass Used (lb) |
---|---|---|---|---|---|---|---|---|
1 | Additional Ingredients Not Listed on MSDS | |||||||
HVG01 (TURQUOISE-1 BULK) | FTS International | Gelling Agent | Guar gum | 9000-30-0 | 50.00 | 0.05 | ||
Quartz | 14808-60-7 | 2.00 | 0.00230000 | |||||
Distillates, petroleum, hydrotreated light | 64742-47-8 | 55.00 | 0.06 | |||||
Ethoxylated propoxylated C12-14 alcohols | 68439-51-0 | 2.00 | 0.00230000 | |||||
Borate XL Instant XL (BXL02) | FTS International | Crosslinker | Sodium metaborate tetrahydrate | 10555-76-7 | 25.00 | 0.00472000 | ||
Potassium hydroxide | 1310-58-3 | 12.00 | 0.00226000 | |||||
Boric acid | 10043-35-3 | 15.00 | 0.00283000 | |||||
Ottawa Sand | Proppant | Quartz | 14808-60-7 | 100.00 | 12.27 | |||
FE 200 | FTS International | Iron Control Agent | Ethylenediaminetetraacetic acid tetrasodium salt hydrate | 64-02-8 | 41.00 | 0.00124000 | ||
Glycine, N,N-bis(carboxymethyl)-, trisodium salt | 5064-31-3 | 2.00 | 0.00006000 | |||||
Sodium hydroxide | 1310-73-2 | 1.90 | 0.00006000 | |||||
APB-01 Ammonium Persulfate Breaker | FTS International | Breaker | Peroxydisulfuric acid, diammonium salt | 7727-54-0 | 100.00 | 0.00210000 | ||
10.1 - 15 HCL | FTS International | Acid | Hydrochloric acid | 7647-01-0 | 15.00 | 0.08 | ||
Water | 7732-18-5 | 85.00 | 0.50 | |||||
100 Mesh Sand, Ottawa Sand | Nalco | Proppant | No Non-MSDS Listed Components | |||||
EC6110A | Nalco | Antibacterial Agent | Ethanol | 64-17-5 | 5.00 | 0.00107000 | ||
Glutaraldehyde | 111-30-8 | 60.00 | 0.01 | |||||
Quaternary Ammonium Compounds | 10.00 | 0.00213000 | ||||||
EC6110A, EC6629A | Nalco | Anti-Bacterial Agent, Scale Inhibitor | Proprietary Quaternary Ammonium Salt | |||||
Methanol | 67-56-1 | |||||||
Water | 7732-18-5 | |||||||
Proprietary Acrylate Polymer | ||||||||
B10 (HIGH PH BUFFER) | FTS International | pH Adjusting Agent | Potassium hydroxide | 1310-58-3 | 20.00 | 0.00594000 | ||
Carbonic acid, dipotassium salt | 584-08-7 | 48.00 | 0.01 | |||||
EC6629A | Nalco | Scale Inhibitor | No Hazardous Components | 0.00 | ||||
10.1 - 15 HCL, APB01 (AMMONIUM
PERSUFATE BREAKER), B10 (HIGH PH BUFFER), BXL02 Borate XL, CI-150, FE 200, FRW-200, HVG01 (TURQUOISE-1 BULK), LTB-01 |
FTS International | Acid, Breaker, Corrosion Inhibitor, Cross Linker, Friction Reducer, Gelling Agent, Iron Control Agent, pH Adjusting Agent | Proprietary Iron Control Additive (FE-200L) | |||||
Water | 7732-18-5 | |||||||
Proprietary Breaker (APB01) Additive | ||||||||
Proprietary Breaker Additive (LTB-1) | ||||||||
Proprietary Corrosion Inhibitor Additive (CI-150) | ||||||||
Proprietary Friction Reducer Additive
(FRW-200 and FRW-200W) |
||||||||
CI-150 (Corrosion Inhibitor) | FTS International | Corrosion Inhibitor | Isopropanol | 67-63-0 | 60.00 | 0.00060000 | ||
N,N-Dimethylformamide | 68-12-2 | 10.00 | 0.00010000 | |||||
Proprietary Organic Amine Resin Salt | 30.00 | 0.00030000 | ||||||
Proprietary Quaternary Ammonium Compound | 10.00 | 0.00010000 | ||||||
Proprietary Aromatic Aldehyde | 10.00 | 0.00010000 | ||||||
LT Encapsulated AP Breaker (LTB01) | FTS International | Breaker | Peroxydisulfuric acid, diammonium salt | 7727-54-0 | 100.00 | 0.07 | ||
Dioxide) | ||||||||
Quartz | 14808-60-7 | 25.00 | 0.01 | |||||
Proprietary Cured Acrylic Resin | 25.00 | 0.01 | ||||||
Fresh Water | Carrier/Base Fluid | 84.50 | ||||||
FRW-200 | FTS International | Friction Reducer | Distillates, petroleum, hydrotreated light | 64742-47-8 | 26.00 | 0.01 | ||
100 Mesh Sand | Proppant | Quartz | 14808-60-7 | 100.00 | 2.28 |
For data sources see[4]
Stimulation Date | Chemical Agent | Chemical Agent Concentration (%) | Fracking Fluid Volume | Mass of Proppant Used (lb) | Fracking Company | Comments |
---|---|---|---|---|---|---|
2012-06-01 | H2O | 15 | 14402 Bbl | 624849 | Frac Tech Services | STAGE 3
35 SHOTS |
2012-06-02 | H2O | 15 | 9784 Bbl | 667791 | Frac Tech Services | STAGE 6
35 SHOTS |
2012-05-29 | H2O | 15 | 10304 Bbl | 689180 | Frac Tech Services | STAGE 1
35 SHOTS |
2012-06-02 | H2O | 15 | 11109 Bbl | 661532 | Frac Tech Services | STAGE 7
35 SHOTS |
2012-06-01 | H2O | 15 | 10667 Bbl | 677848 | Frac Tech Services | STAGE 5
35 SHOTS |
2012-06-01 | H2O | 15 | 9440 Bbl | 665104 | Frac Tech Services | STAGE 4
35 SHOTS |
2012-05-31 | H2O | 15 | 9871 Bbl | 665555 | Frac Tech Services | STAGE 2
35 SHOTS |
For data sources see[5]
Period | Operator Name | Gas Quantity (mcf) | Oil Quantity (bbl) | Production Days |
---|---|---|---|---|
2013 | CHESAPEAKE EXPLORATION LLC | 0 | 0 | 0 |
2014 | CHESAPEAKE EXPLORATION LLC | 0 | 0 | 0 |
2015 | CHESAPEAKE EXPLORATION LLC | 0 | 0 | 0 |
2016 | CHESAPEAKE EXPLORATION LLC | 0 | 0 | 0 |
2017 | CHESAPEAKE EXPLORATION LLC | 0 | 0 | 61 |
2018 | CHESAPEAKE EXPLORATION LLC | 159550 | 0 | 31 |
2019 | CHESAPEAKE EXPLORATION LLC | 98115 | 0 | 77 |
Period | Operator Name | Waste Type | Quantity (bbl) | Production Days |
---|---|---|---|---|
2013 | CHESAPEAKE EXPLORATION LLC | Brine | 0 | 0 |
2014 | CHESAPEAKE EXPLORATION LLC | Brine | 0 | 0 |
2015 | CHESAPEAKE EXPLORATION LLC | Brine | 0 | 0 |
2016 | CHESAPEAKE EXPLORATION LLC | Brine | 0 | 0 |
2017 | CHESAPEAKE EXPLORATION LLC | Brine | 0 | 61 |
2018 | CHESAPEAKE EXPLORATION LLC | Brine | 1446 | 31 |
2019 | CHESAPEAKE EXPLORATION LLC | Brine | 4679 | 77 |
Inspection ID | Inspection Date | Inspection Type | Inspection Result | Inspection Comments |
---|---|---|---|---|
-1304842455 | 2018-10-1 0:00: | PW | No Violations | 0.30 |
-185119563 | 2014-12-11 0:00 | PL | No Violations | |
-1947458216 | 2016-3-31 0:00: | PW | No Violations | |
-430893416 | 2018-8-16 0:00: | PW | No Violations | |
-540608564 | 2016-6-22 0:00: | PW | No Violations | 2.50 |
-573024275 | 2017-12-14 0:00 | PW | No Violations | |
-614840385 | 2017-8-29 0:00: | PW | No Violations | 0.50 |
-962867974 | 2016-11-30 0:00 | PW | No Violations | 1.00 |
0185119563 | 2014-12-11 | Preliminary Restoration | No Violations
-established ground cover. The soil stockpile is well stabilized with vegetation. Crops, woodlands and/or underbrush are growing normally outside the area of disturbance. Drainage and erosion controls outside the pad are in place and functioning. A closed-loop, above-ground drilling pit system was used, so there are no earthen pits requiring closure. Preliminary restoration has not passed pending installation of production equipment. | |
0331093815 | 2018-12-03 | Production Wells | No Violations | The purpose of my inspection was to conduct a status check on well #1716. At the time of my inspection the well had been placed into production. Correct identification was posted at the well head. The cellar was holding freshwater and had a grate in place to prevent falls. The intermediate annular gauge indicated 0 psi. The production casing annular gauge indicated 145 psi. The digital 5.5 production casing gauge indicated 900 psi. The digital tubing pressure gauge indicated 902 psi. No leaks were observed. Equipment on location consisted of two (2) GPU with sand knock out, one (1) meter station, one (1) hydrate inhibitor tank, one (1) SCADA station and two (2) 400 bbl production tanks. The hydrate inhibitor tank was on containment. No leaks or evidence of leaks were witnessed with the production or metering equipment. The production tanks were located in an above ground imperviously lined steel containment. The containment contained freshwater. Valves were closed and plugged. No violations were observed during this inspection. |
0430893416 | 2018-08-16 | Production Wells | No Violations | The purpose of my inspection was to conduct a status check on well #2-1716. Well identification signage was present at the entrance. The location was enclosed by a locked perimeter fence that remained in good repair. At the time of my inspection the well was not yet turned into production. All well head valves remained closed and locked out with tags. Pressure gauges on the intermediate casing annulus indicated 0 psi. The production casing annulus indicated 300 psi. The casing pressure gauge indicated 3500 psi. The tubing indicated 300 psi. Equipment on location consisted of two (2) GPU units, one (1) solar powered generator and two (2) 400 bbl production tanks. The sales line was not connected on the pad yet. The production tanks were contained within an impervious lined corrugated steel above ground containment. No violations were observed during this inspection. |
0540608564 | 2016-06-22 | Production Wells | No Violations | My purpose for inspection was to conduct a second year temporary inactive well status inspection.
There are two wells on the pad (10H and 1H). The sign board posted at the lease entrance displayed signs with the well name, address, permit number and emergency contact information. The lease road was graveled and in good repair. Erosion and sedimentation controls were in place and ground cover was well established along the road. I walked the entire location and found the well pad constructed with an earthen berm perimeter in good repair, being stabilized with well-established vegetation. Erosion and sedimentation controls are in place and functioning. The well pad was found to be enclosed by a chain link fence with barbed wire at the top. The primary entrance and escape doors were found locked. The surface of the well pad consists of gravel and is in good repair. A perimeter drain was installed and both stand pipes were found open. Soil stockpile is stabilized with well-established vegetation. The 10H well was constructed with 120 of 20 conductor, 576 of 13 3/8 surface casing, 2608 of 9 5/8 intermediate casing and 12, 962.9 of 5 1/2 production casing. Drilling was completed 4/25/2012. The well was stimulated on 5/29/2012 and completed with 7580.6 of 2 7/8 tubing. The well head was constructed with a Christmas tree valve assembly and found to be protected by a perimeter of concrete Jersey barriers. Well identification signage was displayed. A cellar grate was in place to prevent falls. The cellar contained water with approximately 5 feet of freeboard. The production casing gauge showed 0 psi. The intermediate and surface casing gauges indicated 0 psi. Neither gauge is identified as to which casing string it belongs. Identification determination was based upon position on the wellhead. No sheen or leaking gas was observed on the water in the cellar. The mousehole was cemented. Gate valves are chained and locked except for the uppe |
0573024275 | 2017-12-14 | Production Wells | No Violations | The purpose of my inspection was to conduct a status check on well #2-1716. ODNR-DOGRM Northeast District Supervisor Stephen Ochs was present during the inspection. Correct identification was present at the entrance. The security fence was found locked. The security fence remained in good repair with no signs of vandalism. The earthen berm around the pad remained stable. Correct identification was posted at the well head. The 9.625 and 5.5 annular pressure gauges were open. The 9.625 annular gauge indicated 0 psi. The 5.5 annular gauge indicated 600 psi. No leaks were observed. The production tree gate valves remained closed, chained and locked. Well #2-1716 currently has a valid temporary inactive status permit. No violations were observed during this inspection. |
0614840385 | 2017-08-29 | Production Wells | No Violations | The purpose of my inspection was to conduct a status check on well #2-1716. The well had a valid temporary inactive status permit. The lease road and pad surface was composed of crushed gravel and remained in good repair. Correct identification was posted at the entrance and well head. A locked chain link fence remained around the pad. The well head was protected by jersey barriers. The cellar contained freshwater with no sheen. Steel grate covered the cellar to prevent falls. The annular gauges were plumbed above grade and identified. The 9.625 and 5.5 annular valves were open. The 9.625 gauge indicated 0 psi. The 5.5 annulus gauge identified 580 psi. The 5.5 production casing was equipped with a Christmas tree valve assembly. The production casing gauge and tubing indicated 0 psi. Gate valves were chained and locked. No leaks were observed. I will contact Chesapeake Regulatory Affairs Manager Jody Jones concerning the 5.5 annular casing pressure. |
0893395978 | 2018-08-27 | Production Wells | No Violations | The purpose of my inspection was to conduct a status check on well #2-1716. Well identification signage was present at the entrance. The location was enclosed by a locked perimeter fence that remained in good repair. At the time of my inspection the well was still not turned into production. All well head valves remained closed and locked out with tags. Pressure gauges on the intermediate casing annulus indicated 0 psi. The production casing annulus indicated 320 psi. The casing pressure gauge indicated 3650 psi. The tubing indicated 0 psi. Equipment on location consisted of two (2) GPU units, one (1) solar powered generator and two (2) 400 bbl production tanks. The sales line was not connected on the pad yet. The production tanks were contained within an impervious lined corrugated steel above ground containment. The electric utility was brought to the pad to power the security camera but was not connected. I will schedule a follow-up inspection once the well is turned over to sales. |
0962867974 | 2016-11-30 | Production Wells | No Violations | The purpose of my inspection was to conduct a status check on well #2-1716. The well is currently in temporary inactive status. Correct well identification remains present at the entrance and well head. Lease access and the well pad facilities remain in good repair. No other equipment is on the pad. The Owner raised and identified the 9.625 intermediate annular casing pressure gauge and the 5.5 production annular casing pressure gauge. The intermediate annular casing gauge indicated 0 psi. The production casing annular gauge indicated 400 psi. Maximum allowable annular surface pressure (MAASP) at the surface per ORC 1501:9-1-08 (N) (2) is 790 psi. The production casing valve was closed. Both production casing and tubing pressure gauges indicated 0 psi. I will continue to monitor casing pressures on a regular basis to ensure compliance. |
1255319515 | 2018-07-30 | Production Wells | No Violations | The purpose of my inspection was to document the status of well #2-1716. At the time of my inspection the owner was in the process of turning the well over to production. Operators were on location to install and connect gas processing units, telemetry and production tanks. The well remained shut-in. The annular pressure gauge on the 9.625 intermediate casing was closed and indicated 0 psi. The annular pressure gauge on the 5.5 production casing was closed and indicated 280 psi. While on location I met Chesapeake instrument and electrical technician Robby Alexander. Mr. Alexander reported the pad was planned to be in production within 30 days. I will schedule a follow-up inspection to document the location after production is established. |
1304842455 | 2018-10-01 | Production Wells | No Violations | The purpose of my inspection was to document the status of well #2-1716. At the time of my inspection the owners contractor was still completing the sales line. The production valves remained in the closed position. Gates valves were chained and locked. The intermediate annular gauge indicated 0 psi. The production annular gauge indicated 350 psi. No leaks were observed. I will schedule a follow-up inspection to document the status of the well once the well is placed into production. No violations were observed during this inspection. |
1335455622 | 2012-04-26 | Drill / Deepen / Reopen | No Violations | I received a telephone call from adjacent landowner Ben Morucci regarding black cloudy water when turning on his water. The water cleared if left running for a short time. He noted that Chesapeake was drilling a well within approximately 500 of his water well at his cabin. He had had a comprehensive water study done by the Columbiana County Department of Health prior to the drilling. He indicated that he had turned down Chesapeakes offer to perform a pre-drilling analysis. We discussed his options. Upon further discussion, Mr. Morucci indicated that the cloudiness seemed related to use of his hot water, and he would replace the hot water tank and see if the problem was resolved. The water tank is in a cabin on his property. He will re-contact the ODNR if the problem continues after the water tank in replaced. His office number is 330-758-8050. |
1877168842 | 2015-03-11 | Production Wells | No Violations
-established ground cover. The soil stockpile is well stabilized with vegetation. Drainage and erosion controls at the pad are in place and functioning. I emailed Steve Ault of Chesapeake on 4/24/2015 about the identification signs. He replied on 4/27/2015 that they had located the wellhead identification signs and they would be installed within the week. I recommend temporary inactive status be granted. | |
1947458216 | 2016-03-31 | Production Wells | No Violations | I was on location for a status check. My inspection found the access road gate locked and the
access road in good repair. The pad is fenced and all man doors were locked. An identification sign is posted at the access road entrance and well. The #10H is not in production. The well is equipped with a christmas tree valve assembly. The equipment on the pad consists of the following: Site fenced and man doors locked |
331093815 | 2018-12-3 0:00: | PW | No Violations | 0.50 |
893395978 | 2018-8-27 0:00: | PW | No Violations |
For data sources see[10]