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34-055-22144

Well Details

Well ID: 34-055-22144
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Country: United States
State: Ohio
County: Geauga
Municipality: Burton Township
Operator Name: EQUITY OIL & GAS FUNDS INC
Well Pad ID:
Farm/Lease Name: SUTYAK UNIT
License Status: Producing
License Date: 2013-01-18
Spud Date: 2012-07-13
Spud Drilling Contractor: POULSON DRILLING
Final Drill Date: 2012-07-17
Well Total Depth: 4206.00 ft
Configuration: Vertical
Latitude: 41.440000
Longitude: -81.110000

For data sources see[1]

Well History

Well Status Well Status Date Comment
APP 2012-07-05 Proposed Formations:CLINTON, Issued Date:7/5/2012, Expired Date:7/5/2014 12:00:00 PM, Drilling unit acres:50.35, Proposed Well Type:OG, Proposed Well Class:POOL
Reached Total Depth 2012-07-17 WELL IS CURRENTLY ONLY PRODUCING FLOWBACK/BRINE AS PER CONVERSATION WITH EQUITY OIL & GAS FUNDS.
Completion Report Received 2012-09-26 WELL IS CURRENTLY ONLY PRODUCING FLOWBACK/BRINE AS PER CONVERSATION WITH EQUITY OIL & GAS FUNDS.
APP 2013-01-18 Proposed Formations:CLINTON, Issued Date:1/18/2013, Expired Date:1/18/2015 12:00:00 PM, Drilling unit acres:50.35, Proposed Well Type:OG, Proposed Well Class:
Construction Permit Expires 2015-01-18 WELL IS CURRENTLY ONLY PRODUCING FLOWBACK/BRINE AS PER CONVERSATION WITH EQUITY OIL & GAS FUNDS.
Record Last Modified 2017-10-24 WELL IS CURRENTLY ONLY PRODUCING FLOWBACK/BRINE AS PER CONVERSATION WITH EQUITY OIL & GAS FUNDS.

For data sources see[2]

Perforation Treatments

Perforation Date Interval Top (ft) Interval Base (ft) Number of Shots
2012-10-11 3985 4047 63
3985 4047 63
3985 4047 63

For data sources see[3]

Stimulations Data

Stimulation Date Chemical Agent Chemical Agent Concentration (%) Fracking Fluid Volume Mass of Proppant Used (lb) Fracking Company Comments
2012-08-29 H2O 15 79686 Gal 40000 Producers Service Corporation
H2O 0 79686 Gal 40000 Producers Service Corporation

For data sources see[4]

Production Data

Period Operator Name Gas Quantity (mcf) Oil Quantity (bbl) Production Days
2014 EQUITY OIL & GAS FUNDS INC 1060.00 0.00 215
2015 EQUITY OIL & GAS FUNDS INC 1431.00 138.00 365
2016 EQUITY OIL & GAS FUNDS INC 999.00 135.00 365
2017 EQUITY OIL & GAS FUNDS INC 1127.00 21.00 365

For data sources see[5] [6]

Waste Data

Period Operator Name Waste Type Quantity (bbl) Production Days
2014 EQUITY OIL & GAS FUNDS INC Brine 527 215
2015 EQUITY OIL & GAS FUNDS INC Brine 217 365
2016 EQUITY OIL & GAS FUNDS INC Brine 166 365
2017 EQUITY OIL & GAS FUNDS INC Brine 106 365

For data sources see[7] [8]

Inspection Data

Inspections Performed

Inspection ID Inspection Date Inspection Type Inspection Result Inspection Comments
-1509516656 2013-6-21 0:00: PL No Violations
-597419086 2012-7-16 0:00: DD No Violations
-721288143 2013-10-17 0:00 PL No Violations
0597419086 2012-07-16 Drill / Deepen / Reopen No Violations My inspection today found: Drill depth was 2700. The rig was actively drilling on air. The pits were in good repair, with sufficient free board. Drainage was controlled on location. The lease road was stable. No equipment fluid leaks noted. I reviewed the geolograph. Operator had waited the required 8 hours before breaking the head off of the surface casing. Operator marked that they tested the BOP. Review of the BOP during inspection found it, in place and chained to the sub floor. No movement of the BOP was noted. Airhead was in place. Discharge line was 60 feet in length. Permit was posted in the dog house. Site was in compliance with ORC 1509.
0721288143 2013-10-17 Preliminary Restoration No Violations My inspection found that there has been no changes since my last inspection. I will contact the company and find out when the well will be completed or plugged.
0907493885 2015-03-10 Production Wells No Violations My inspection found the well to be equipped with a pumpjack unit. The tank battery consists of a 210 BBL production tank, a 50 BBL poly brine tank, and a mechanical separator. The production tank is vented through a charcoal filter and into a spark arrestor. The proper identification is located on the tank battery. The lease road is in stable condition.
0928363410 2012-07-13 Drill / Deepen / Reopen No Violations I was on site today to check the progress of the drilling of the conductor hole. Poulson Drilling on location drilling the hole. The Sharon Sandstone top was 9 feet. My inspection found that the driller was losing fluid. Drill depth was 60 feet. Operator estimated the zone taking fluid was at 55 feet. I reviewed water well records for the homes in the area. Water well records indicated a zone of mud, interbedded in the sandstone at approximately 53 feet. The operator was not losing circulation but was losing fluid. During my inspection the operator mixed two slugs of starch to condition the hole. After the two volumes of starch were ran, the hole continued to lose fluid. The operator had lost circulation material (LCM) in route to the location. The operator mixed mud based gel in an attempt to condition the hole and seal off lost circulation zone. Operator pumped mud at 500psi, maintaining circulation. Circulation was maintained but the hole continued to take fluid. I advised the rig hand Jimmy Dixon that it would be in the best interest of the aquifer to shut down and wait until LCM was on site. Jimmy agreed and spoke to Roy Poulson about shutting down and waiting on LCM. Rig shut down, LCM arrived on location, operator began to mix mud and LCM. I reviewed the materials on location. The materials were as follows: Drill Star which is corn based starch. Multiseal which is a cellophane, nut shells, ground paper and cedar fibers, Bentonite, Bentonite extend which is a concentrated lime, caustic for pH adjustments and Dicks Mud Seal which is waste paper, wood pulp and clay. Operator discussed a change in the conductor casing program with me during inspection. Roy advised he was going to drill below the base of the Sharon and set conductor. I had advised Roy that offset wells had lost circulation at the base of the Sharon. I agreed with changes to the casing program.
1139129515 2012-07-13 Drill / Deepen / Reopen No Violations I was on location at 17:45 for conductor cementing. The operator drilled to 200 feet. The bottom of the Sharon Sandstone was 178 feet. Operator lost 900 to 1000 barrels of fluid. The following products were used to maintain circulation and condition the hole: 5500 pounds of Bentonite clay, 4 bags of Mulitseal, 3 bags of cotton seed hulls, 160 pounds of Dicks Mud Seal, 1000 pounds of Drill Star starch, one sack caustic and one bag of bentonite extender. Operator had the front of the drill pit half full of fresh water gel before cementing. Petroset Cementing on location to cement conductor casing. Casing was set at 187 feet KB. Operator broke circulation with gel from the pit, and ran the total pit volume to condition hole. Petroset Cementing hooked up to the casing, broke circulation and mixed cement until it returned to surface. Petroset displaced cement, during cementing I had the operator dam off the flow ditch. Approximately 8 barrels of cement held back in the ditch and cellar. Cement fell back after cementing was complete. Approximately 6 barrels of cement was used from the ditch to keep cement at surface. Cement stabilized and held at surface. I waited on site .5 hours to assure that the cement held at surface. At this time the cement had stabilized and was starting to set up. I informed the operator that cement head is not to be broken off for a minimum of 8 hours and left location.
1342183268 2012-07-12 Drill / Deepen / Reopen No Violations I was on site today to witness pit construction. The permit is subject to Areas of Thin Glacial Till Overlying Fractured Bedrock Aquifers conditions. The soil the pits were constructed in was clay. The soil was dry, no water encountered. Sand and gravel and fractured bedrock was not encountered during construction of the pits. During the inspection I had rig crew staff cut roots from the edges of the pit. Pit liners that were brought onto site were re-enforced liners. The lease road was stable. The lease road was topped with 57 limestone to the location. During inspection, I informed the driller Roy Paulson that the cellar must be liquid tight after surface is set. Surface casing and conductor casing was brought onto site during inspection. Conductor was new R-3 32lb pipe. Four joints of the surface casing were new R-3 20lb pipe. The remainder of the casing was used R-2 23lb pipe. I contacted the supplier of the pipe, (North East.) I spoke to Rick at North East, he stated the pipe was from 1960 vintage cable tool holes, the pipe was tested to 1000psi and drift tested. Casing to be set at approximately 440 feet, (.403 X 440 = 177psi maximum pressure, 177psi X 1.2= 213 minimum internal yield pressure.) I inspected the casing on the trailer, there was thin scale and pitting on the outside, original paint could still be seen on the casing, no noted integrity issues. Casing threads were in good condition. I contact the owner and requested a copy of the casig test before casing is set. Permit was posted in the dog house. Operator was filling fresh water tank on location, the source of the water was the Cuyahoga River, the same source of water will be used to fill the work pit.
1342615322 2012-07-18 Drill / Deepen / Reopen No Violations My inspection found: the long string cemented in place. There was a bull plug in the top of the 4.5 inch casing. Water was weeping out of the vent hole on the bull plug. Pits liners are in good repair. There is 8 inches of freeboard in the blow pit. Rain and possible server thunderstorms are forecasted for today. Water line on the blow pit liner shows that the operator was less than an inch from breaching. Operator will be contacted to pull water out of the pits. Lease road is stable. Site is stable. Rig mast is down and rig is locked up. Dogs are in place on pipe trailers. 10:00am Operator was contacted to have additional fluid removed from pit.
1342711157 2012-07-14 Drill / Deepen / Reopen No Violations I was on site today to witness the cementing of the surface casing. Operator ran 230 feet of used R-2 23lb casing and 168.8 feet of new R-3 20lb casing. New casing was ran first. The top of the Berea was 320 the bottom was 350. The operator set the surface at 405 KB or 399 GL. During drilling, the hole took fluid at the bottom of the Berea. Pertroset Cementing Services on location to cement the casing. Operator broke circulation, ran 100lb of gel and one bag of hulls ahead of the cement. Cement ran and displaced, 10 barrels of good cement returned to surface. Cement fell back after job was complete. Cement was held back in the flow ditch and cellar. Cement was allowed to flow back into the annulus space. There was sufficient cement in the ditch to top annulus off, cement stabilized after 20 minutes.
1343218492 2012-07-25 Drill / Deepen / Reopen No Violations On 7/25/2012, I conducted an inspection of the pit solidification for DNR Inspector Tom Hill. My inspection found two semi-trucks with lime, I witnessed the lime dumped into the pits, andWade Pol Contracting, Inc. mixing lime into the pits.
1343309672 2012-07-26 Drill / Deepen / Reopen No Violations On 7/26/2012, I conducted an inspection for DNR Inspector Tom Hill. My inspection found the pits solidified and closed, all drilling equipment removed, and the site graded.
1488795350 2014-07-31 Preliminary Restoration No Violations My inspection found the well in production. The well is equipped with a pumpjack unit. The tank battery consists of a 210 BBL production tank, a 50 BBL poly brine tank, and a mechanical separator. The production tank is vented through a charcoal filter and into a spark arrestor. The proper identification is located on the tank battery. The 500 BBL tanks have been removed from the location. The trees are all cut to 10 ft lengths and stacked for the landowner to cut into firewood. The area has been graded, seeded, and vegetation has been established. The lease road has new stone run up to the pumpjack for access. Preliminary restoration can be passed.
1509516656 2013-06-21 Preliminary Restoration No Violations My inspection found the pump jack and rods had been removed from the well. There was two 500 BBL tanks on location. The tank battery consists of a 210 BBL production tank and a 50 BBL poly brine tank. There is a 5 gallon charcoal filter on the vent stack of the production tank. The proper identification is located on the tank battery. After a phone call to Elaine from Equity Oil, I was informed the well had a polymer job done on it. They will redo the perforations and try fracing the well one more time.
907493885 2015-3-10 0:00: PW No Violations
928363410 2012-7-13 0:00: DD No Violations

For data sources see[9]

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. ↑ "Risk Based Data Management System - tblStimulation Table". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  5. ↑ "Risk Based Data Management System - Production Table - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  6. ↑ "Combined Production - Oil and Gas Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  7. ↑ "Risk Based Data Management System - Production Table - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  8. ↑ "Combined Production - Brine Data". Ohio Department of Natural Resources. 2020-11-16. Retrieved 2020-11-16. 
  9. ↑ "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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