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Well ID: 34-029-21885 | Loading map...
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Country: United States | |
State: Ohio | |
County: Columbiana | |
Municipality: Fairfield Township | |
Operator Name: HILCORP ENERGY COMPANY | |
Well Pad ID: US-OH-001409 | |
Farm/Lease Name: FAIRFIELD-UNKEFER | |
License Status: Producing | |
License Date: 2016-11-04 | |
Spud Date: 2016-11-12 | |
Spud Drilling Contractor: H&P DRILLING | |
Final Drill Date: 2017-01-26 | |
Well Total Depth: 16104.00 ft | |
Configuration: Horizontal | |
Latitude: 40.820000 | |
Longitude: -80.690000 |
For data sources see[1]
Well Status | Well Status Date | Comment |
---|---|---|
APP | 2016-11-04 | Proposed Formations:UTICA THRU POINT PLEASANT, Issued Date:11/4/2016, Expired Date:11/4/2018 12:00:00 PM, Drilling unit acres:798.5, Proposed Well Type:OG, Proposed Well Class:POOL |
Correction to Well | 2016-12-16 | CHANGE IN CASING PROGRAM |
Reached Total Depth | 2017-01-26 | |
Correction to Well | 2017-05-12 | UPDATED TARGET/TAKEPOINT/ACREAGE AS DRILLED PLAT FEES RCVD 5/8/17-ALE |
Completion Report Received | 2017-05-22 | |
Record Last Modified | 2018-04-06 | |
Construction Permit Expires | 2018-11-04 |
For data sources see[2]
Perforation Date | Interval Top (ft) | Interval Base (ft) | Number of Shots |
---|---|---|---|
2017-04-12 | 8781 | 8956 | 0 |
2017-04-12 | 15782 | 15982 | 45 |
15782 | 15982 | 45 | |
8781 | 8956 | 0 | |
8781 | 8956 | 0 |
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 | 02/28/2017 | 03/13/2017 | 8297 | 15,221,300.0 | 0 |
Job Number | Trade Name | Supplier | Purpose | Ingredient Name | CAS Number | Additive Percentage by Mass | Job Percentage by Mass | Mass Used (lb) |
---|---|---|---|---|---|---|---|---|
1 | Other Chemical(s) | Listed Above | See Trade Name(s) List | 2-Ethylhexanol | 104-76-7 | 10 | 0.000145135 | 210.67 |
Alcohols, C14-15, ethoxylated | 68951-67-7 | 5 | 0.00007257 | 105.335 | ||||
Water | 7732-18-5 | 44.3 | 0.00614652 | 8921.94 | ||||
Coconut oil acid diethanolamine | 68603-42-9 | 5 | 0.00007257 | 105.335 | ||||
Alcohols, C12-16, ethoxylated | 68551-12-2 | 1.5 | 0.00124074 | 1800.99 | ||||
Ethylene glycol | 107-21-1 | 40 | 0.00371655 | 5394.74 | ||||
Phosphino carboxylic acid polymer | 71050-62-9 | 3 | 0.000278741 | 404.606 | ||||
Hexamethylene Triamine Penta (Methylene
Phosphonic Acid) |
34690-00-1 | 3 | 0.000278741 | 404.606 | ||||
Hydrochloric Acid (Hydrogen Chloride) | 7647-01-0 | 28 | 0.00701551 | 10183.3 | ||||
Oleic Acid Diethanolamide | 93-83-4 | 1.5 | 0.00124074 | 1800.99 | ||||
Petroleum Distillate | 64742-47-8 | 20 | 0.0165432 | 24013.2 | ||||
Copolymer of Maleic and Acrylic Acid | 52255-49-9 | 10 | 0.000929138 | 1348.69 | ||||
Fatty acids, tall oil | 61790-12-3 | 5 | 0.00007257 | 105.335 | ||||
Ammonium chloride ((NH4)Cl) | 12125-02-9 | 2 | 0.00165432 | 2401.32 | ||||
DETA phosphonate | 15827-60-8 | 3 | 0.000278741 | 404.606 | ||||
2-Propyn-1-ol | 107-19-7 | 5 | 0.00007257 | 105.335 | ||||
Olefin | Not Assigned | 5 | 0.00007257 | 105.335 | ||||
2,2-Dibromo-3-nitrilopropionamide | 10222-01-2 | 5.8 | 0.000799186 | 1160.05 | ||||
Methanol | 67-56-1 | 35 | 0.000507972 | 737.343 | ||||
NEFE-180 | Chemplex | Corrosion Inhibitor/Iron Control | Fatty acids, tall oil | 61790-12-3 | 5 | 0.00007257 | 105.335 | |
2-Propyn-1-ol | 107-19-7 | 5 | 0.00007257 | 105.335 | ||||
Acetic acid | 64-19-7 | 65 | 0.000943376 | 1369.35 | ||||
Methanol | 67-56-1 | 35 | 0.000507972 | 737.343 | ||||
Olefin | Not Assigned | 5 | 0.00007257 | 105.335 | ||||
Coconut oil acid diethanolamine | 68603-42-9 | 5 | 0.00007257 | 105.335 | ||||
Alcohols, C14-15, ethoxylated | 68951-67-7 | 5 | 0.00007257 | 105.335 | ||||
2-Ethylhexanol | 104-76-7 | 10 | 0.000145135 | 210.67 | ||||
Hydrochloric Acid (28%) | FSTI | Acidizing | Water | 7732-18-5 | 72 | 0.0180399 | 26185.7 | |
Hydrochloric Acid (Hydrogen Chloride) | 7647-01-0 | 28 | 0.00701551 | 10183.3 | ||||
Water | Company 1 | Carrier/Base Fluid | Water | 7732-18-5 | 100 | 87.508 | 127,022,000.0 | |
Sand (100 Mesh Proppant) | Taylor Frac | Proppant | Silica Substrate | 14808-60-7 | 100 | 12.3596 | 17,940,500.0 | |
SI-1171LF | WST | Scale Inibitor | Hexamethylene Triamine Penta (Methylene
Phosphonic Acid) |
34690-00-1 | 3 | 0.000278741 | 404.606 | |
Phosphino carboxylic acid polymer | 71050-62-9 | 3 | 0.000278741 | 404.606 | ||||
DETA phosphonate | 15827-60-8 | 3 | 0.000278741 | 404.606 | ||||
Water | 7732-18-5 | 80 | 0.0074331 | 10789.5 | ||||
Ethylene glycol | 107-21-1 | 40 | 0.00371655 | 5394.74 | ||||
Copolymer of Maleic and Acrylic Acid | 52255-49-9 | 10 | 0.000929138 | 1348.69 | ||||
K-BAC 1005 | WST | Biocide | Water | 7732-18-5 | 44.3 | 0.00614652 | 8921.94 | |
Polyethylene glycol | 25322-68-3 | 50 | 0.00693738 | 10069.9 | ||||
2,2-Dibromo-3-nitrilopropionamide | 10222-01-2 | 5.8 | 0.000799186 | 1160.05 | ||||
Plexslick 957 | Solvay | Friction Reducer | Alcohols, C12-16, ethoxylated | 68551-12-2 | 1.5 | 0.00124074 | 1800.99 | |
Water | 7732-18-5 | 60 | 0.0496296 | 72039.5 | ||||
Ammonium chloride ((NH4)Cl) | 12125-02-9 | 2 | 0.00165432 | 2401.32 | ||||
Oleic Acid Diethanolamide | 93-83-4 | 1.5 | 0.00124074 | 1800.99 | ||||
Petroleum Distillate | 64742-47-8 | 20 | 0.0165432 | 24013.2 |
For data sources see[4]
Stimulation Date | Chemical Agent | Chemical Agent Concentration (%) | Fracking Fluid Volume | Mass of Proppant Used (lb) | Fracking Company | Comments |
---|---|---|---|---|---|---|
2017-02-28 | H2O | 7 | 437346 Gal | 0 | STINGRAY PRESSURE PUMPING LLC | STAGE 1/36
STAGES 2-35 SEE IMAGES |
2017-03-12 | H2O | 7 | 409206 Gal | 0 | STINGRAY PRESSURE PUMPING LLC | STAGE 36/36
STAGES 2-35 SEE IMAGES |
For data sources see[5]
Period | Operator Name | Gas Quantity (mcf) | Oil Quantity (bbl) | Production Days |
---|---|---|---|---|
2017 | HILCORP ENERGY COMPANY | 1555943 | 0 | 228 |
2018 | HILCORP ENERGY COMPANY | 1498971 | 0 | 359 |
2019 | HILCORP ENERGY COMPANY | 302346 | 0 | 90 |
Period | Operator Name | Waste Type | Quantity (bbl) | Production Days |
---|---|---|---|---|
2017 | HILCORP ENERGY COMPANY | Brine | 24288 | 228 |
2018 | HILCORP ENERGY COMPANY | Brine | 9740 | 359 |
2019 | HILCORP ENERGY COMPANY | Brine | 1647 | 90 |
Inspection ID | Inspection Date | Inspection Type | Inspection Result | Inspection Comments |
---|---|---|---|---|
-1102608447 | 2017-1-12 0:00: | CS | No Violations | 10.00 |
-1536527785 | 2017-1-25 0:00: | DD | No Violations | 1.50 |
-2102424298 | 2017-7-10 0:00: | PW | No Violations | 1.00 |
-2123964073 | 2017-10-31 0:00 | PW | No Violations | 0.50 |
-24205522 | 2017-10-19 0:00 | PW | No Violations | 0.60 |
-266222546 | 2017-8-31 0:00: | PW | No Violations | 1.00 |
-309163120 | 2016-11-10 0:00 | DD | No Violations | 3.00 |
-50745955 | 2017-2-14 0:00: | CT | No Violations | 1.00 |
-727540674 | 2016-11-14 0:00 | DD | No Violations | |
-900835543 | 2017-1-12 0:00: | CS | No Violations | 14.50 |
0024205522 | 2017-10-19 | Production Wells | No Violations | The purpose of my inspection was to respond to complaint # 5727. I received an E-mail on 10/17/2017 at 20:07 from Mr. Bryan Wisler complaining about the noise from a diesel engine on the Fairfield-Unkefer pad. I stopped at the lease entrance and stopped my truck engine. I could hear stimulation activity from the Elkrun-Scheel pad, but could not hear any noise from the Fairfield-Unkefer pad from my position. I then drove to the entrance to the pad and observed the location of the pump and tanks utilized in water transfer to the Elkrun-Scheel pad. The pump was the only equipment operating at the time of my inspection. The noise from the pump engine was detectable from the entrance. I walked along the East boundary of the location to put myself between the source and Mr. Wislers residence and did not find the need to install ear plugs. While on location I met with Hilcorp consultant Virgil Gilea. Mr. Gilea and I had a conversation at normal levels without the need to raise our voices. I spoke with Mr. Wisler and discussed the situation and communicated that activates should commence on or near 10/26/2017. I will contact Mr. Wisler after stimulation work is finished to close the complaint. |
0050745955 | 2017-02-14 | Completion Testing | No Violations | The purpose of my inspection was to document the status of completion testing well #2-1885-00-00. On 2/14/2017, I received an E-mail from Stephanie McMurray with Hilcorp Energy stating that hydraulic fracturing was to occur beginning the week of 2/20/2017. At the time of my inspection the drilling rig and related equipment were off location. A steel grate was placed over the cellar to prevent falls. The cellar contained a minimal amount of water. I did not observe any audible or visual leaks from the well head. I met with Hilcorp Energy Senior Wellsite Supervisor Kenneth Shimek to discuss plans for the pad. Mr. Shimek stated that a coil tubing unit was scheduled to make a clean out run on the production casing followed by pressure tests prior to stimulation. Stimulation would be occurring on or before 3/1/2017. I communicated to Mr. Shimek the requirement to notify an inspector at least 24 hours prior to commencing stimulation. I will plan to witness the stimulation work once it commences. |
0266222546 | 2017-08-31 | Production Wells | No Violations | The purpose of my inspection was to conduct a status check and document the annular pressures on well #2-1885. The lease road and pad remained in good repair. Erosion and sedimentation controls remained in place and were functioning. Correct identification was present. The cellar contained fresh water at free board. No leaks were observed. Steel grating was placed over the cellar to prevent falls. The 9.625 and 5.5 annular gauges were plumbed above grade and identified. The 9.625 gauge indicated 0 psi. The 5.5 annular pressure gauge indicated 46 psi. An open top steel box positioned on containment was plumbed to the well heads on location to facilitate choke changes. The box contained production fluid and maintained free board. Production equipment on location specific to #2-1885 consisted of one (1) glycol dehydration unit, one (1) GPU. Common equipment on location consisted of one (1) common dehydration unit and two (2) 400 bbl production water tanks and one vapor recovery unit. The tanks were located within steel containment lined with impervious material. Valves were closed and plumbed to load out valves that were plugged. The containment contained a de minimis volume of fresh water. All equipment on location was functioning as designed. No leaks or spills were observed. No violations were observed during this inspection. |
0309163120 | 2016-11-10 | Drill / Deepen / Reopen | No Violations | The purpose of my inspection was to schedule a pre-spud meeting prior to the commencement of drilling on the Fairfield-Unkefer Pad. On 11/09/2016 I received a phone call from Hilcorp Energy Company (HEC) contracted drilling consultant Bill Mitchell giving notice that HEC planned to prepare for the drilling and setting of conductor casing on 11/10/2016. I communicated to Mr. Mitchell that ODNR-DOGRM was requesting a pre-spud meeting on location to review special permit conditions and establish a line of communication between HEC representatives and ODNR-DOGRM Inspectors during drilling operations. On 11/10/2016, Mr. Mitchell, ODNR-DOGRM Inspectors Michael Dinsmore and Kenneth Frye met to review permit conditions and discuss the processes and procedures that will occur during the active drilling phase on the pad. A review of the Owners proposed casing plan indicated the casing seat depths on the conductor, surface and intermediate casing strings did not correspond with the permitted casing program. After discussion, Mr. Mitchell stated the Owner would revise the proposed casing program to follow the permitted casing program for conductor and surface casing. The intermediate casing seat revision proposed by the operator was deemed acceptable based on intermediate casing seat depths on the Owners previous wells in the nearby area; under the condition that the seating depth would not impair well control efforts. I will plan on being on location to witness the setting of conductor casing. |
0727540674 | 2016-11-14 | Drill / Deepen / Reopen | No Violations | The purpose of my inspection was to witness the drilling and setting of conductor casing. HAD #589 spud well #2-1885 on 11/12/2016 . The owner contracted HAD Drilling Rig # 589 to drill and set 20 conductor casing utilizing the concentric drilling method. Rig #589 utilized a steel half round tank for drilling returns. The drilling contractor utilized absorbent material to solidify the drill cuttings. No pits were excavated. Hilcorp Representative Bill Mitchell reported a total of 180 of conductor was set below ground surface. HAD Rig # 589 also drilled a mousehole to 60 below ground level. |
0853334603 | 2017-07-17 | Production Wells | No Violations | The purpose of my inspection was in response to complaint # 5645. The complainant, Mr. Bryan Wisler, stated that he was audibly detecting periodic noises that were described to sound like pressure releases. While on location I witnessed Hilcorp Energy representatives changing chokes in the well to optimize production. After shutting the well in from production, trapped pressure in the flow line was released to an open top tank placed on containment. The release was brief and did not necessitate hearing protection when standing at a distance. I will contact the complainant to explain the source of his observation. |
0900835543 | 2017-01-12 | Casing String Witnessed | No Violations | The purpose of my inspection was to witness the cementing of the 13.375 surface casing. Upon arrival, I conducted a walk around inspection of the drilling pad and equipment. Erosion and sedimentation controls remained in place and working. I did not observe any spills either on or off of the containment. After checking in with the company representative (Bill Mitchell) to obtain the total measured depth, pipe tally and pump schedule, I realized that the depth drilled to set surface casing was not at least fifty feet below the deepest USDW according to the permitted casing plan. The total measured depth of the 17.5 open hole measured from the kelly bushing was approximately 12 feet short of the regulated depth. After bringing the issue to Mr. Mitchells attention, Mr. Mitchell acknowledged the situation and directed the drilling crew to drill to a total measured depth of 642 to allow for the casing seat to be at least fifty (50) feet below the base of the deepest USDW (Big Injun Sandstone) in the area. After drilling to the new total depth and circulating the hole clean, the casing crew was rigged up and ran 642 of 13.375 54.5 lb./ft. J-55 casing. The shoe track was composed of a multi-bowl casing shoe, one full joint of surface casing and a float collar. Six centralizers were installed on the casing string. Power Torque Services was contracted to run the casing into the hole. After the casing was ran to total depth, Baker Hughes was rigged up to perform the cement job. Baker Hughes re-established circulation and pumped 551 sacks or 118 barrels of 15.6 pound per gallon, 1.20 cubic feet yield cement. After displacing with water to the float collar, approximately 22 barrels of cement were returned to surface. After bumping the plug, the rig pressured up to 1500 psi for 30 minutes to pressure test the casing. The pressure test passed and the floats held when pressure was released. |
1102608447 | 2017-01-12 | Casing String Witnessed | No Violations | The purpose of my inspection was to witness the cementing of the 13.375 surface casing string. I arrived on location and discovered the 17.5 open hole had been drilled to a total measured depth of 602 kelly bushing height or 578 below ground level. The well permit casing program specifies a minimum casing seat depth for the surface casing string of 590 below ground level, or 617 feet kelly bushing height in order to set the casing 50 feet below the deepest USDW (Big Injun sandstone) in the area. I discussed the situation with Northeast Regional Supervisor Thomas Hill who confirmed the depth requirement. I informed drilling consultant Bill Mitchell of the situation and he agreed that the current setting would be short. Mr. Mitchell directed the drilling crew to drill the open hole deeper to satisfy the permit requirement. H&P 225 drilled the 17.5 open hole to a total measured depth of 642.05 feet kelly bushing height. The casing crew, Power Torque Services, installed 642.05 feet of 13.375 OD. Baker Hughes rigged up cement equipment, re-established circulation and pumped a 60 bbl freshwater spacer followed by 550 sxs of 15.6 ppg, 1.20 yield Class A cement. After releasing the plug, Baker pumped 15 bbls of displacement before turning displacement over to the rig. The rig pump approximately 77 bbls to displace and land the plug. After landing the plug, the rig pressure tested the casing to 1500 psi for 30 minutes. |
1337870843 | 2017-03-29 | Surface Facility Construction | No Violations | The purpose of my inspection was to conduct a status check on the construction of production equipment following hydraulic fracturing. Per Hilcorp Senior Wellsite Supervisor Kenneth Shimek, tubing installation had been completed. At the time of my inspection, production equipment construction was in process. There was some minor ponding of fresh water around the well heads. Erosion and sedimentation controls remained in place and functioning. I did not observe water migrating off of the pad or creating erosion or sedimentation concerns. No violations were observed during this inspection. |
1479322519 | 2016-11-10 | Drill / Deepen / Reopen | No Violations | I was on location with Columbiana County DOGRM Inspector Ken Frye to conduct a pre-spud meeting on this horizontal well pad. We met with Hilcorp Energys Company man, Bill Mitchell, to discuss the logistics of the drilling and casing program. HAD Incorporated was on location and rigging up the Foremost 24 drilling rig to concentrically drill and drive the 20 conductor casing for this well and the #13H (PN #21887). In discussing Hilcorps drilling plans with Bill, it was found that the conductor and surface casing setting depths varied greatly from what was required on the issued horizontal well permit. The Companys plan was to set 100 of 20 conductor casing and 460 of 13.375 surface casing while the State issued permit called for 175 and 790 respectively. We had some discussions and I contacted Mike McCormac (permitting) and Aaron Evelsizor (Geologist) in Columbus for justification and clarification of the permitted setting depths for these casing strings. After reviewing the permits with Mike and Aaron, it was decided that the 175 of conductor casing was necessary in order to protect the surrounding water wells that were tapping an aquifer at approximately 120 below ground level. The 790 of surface casing is also required to get 50 below, and protect, the Big Injun Sand which is considered potable water (less than 10,000 mg/l dissolved solids) in this portion of the State. I informed Bill that the setting depths indicated on the permit for the conductor and surface casing strings are required and cannot be varied. Bill made some phone calls to Hilcorp and informed us that the strings would be set at this depth. HAD will need to bring more drill pipe and conductor casing to location to reach the required depth for the #s 1 and 13. HAD will begin installing the conductor casing tomorrow (11/11/2016). |
1488207683 | 2017-02-27 | Production Wells | No Violations | The purpose of my inspection was to witness the hydraulic fracturing of well #2-1885. I received notification from Hilcorp Energy Senior Wellsite Supervisor Kenneth Shimek that stimulation was to begin the morning of 2/27/2017. The lease road and well pad remained stable and in good repair. At the time of my inspection, Hilcorp Energy was still in the process of having contracted service companies begin activities. I walked around the location and found the fresh water transfer frac tanks to be on containment. The containment was free of rips or tears. No free standing fluid was inside the containment. Fresh water is being transferred to the location from two separate privately owned water source. The Owner has installed containment on the well pad under all pressure pumping related equipment. I did not observe any leaks or tears on the containment. I did not observe any spills or free standing fluid. Secondary containment is in place under the chemical storage totes and blender trucks. Currently inspected fire extinguishers were placed in the front of each pump truck on location. |
1536527785 | 2017-01-25 | Drill / Deepen / Reopen | No Violations | The purpose of my inspection was to inspect the 5.5 production casing prior to installation and discuss the upcoming production casing cement job with the company representative, Bill Mitchell. Production casing on location was new, marked Made in U.S.A. The casing was identified as P-110 grade 20 lb./ft. casing with buttress threads. Centralizers to be installed on the casing were rigid, straight blade steel. Per Mr. Mitchell, O-Tex would be the service company for cementing. Mr. Mitchell and I discussed the proposed slurry and volume schedule I received on 01/25/2017. We agreed that based on current mud weight (10.7 pound per gallon), that the proposed slurry weights needed to be increased to remove as much drilling mud as possible and provide for a more effective cement job. I will plan on witnessing the cementing of the 5.5 production casing string. |
1729872156 | 2016-11-15 | Drill / Deepen / Reopen | No Violations | The purpose for my inspection was to witness the cellar cementing operations. The Owner contracted HAD Drilling Inc. to install 10 feet diameter and 10 feet deep cellars around the conductor casing. Dickey cement delivered Redi-Mix cement and Inspector Michael Dinsmore and myself witnessed approximately 1 foot of concrete get poured into the base of the cellar. Hilcorp Representative Bill Mitchell reported the HAD had also poured concrete into the mousehole to seal the bottom. I requested and witnessed additional cement being poured into the mousehole. |
2102424298 | 2017-07-10 | Production Wells | No Violations | The purpose of my inspection was to respond to complaint # 5645. The complainant, Mr. Bryan Wisler stated that he was hearing loud pressure release noises coming from the pad. While on location I did not experience any sounds of excessive pressure release. I did observe that a gas dehydration unit was removed from location. I called and spoke with Hilcorp Energy wellsite supervisor Kenneth Shimek regarding the complaint and equipment. Mr. Shimek stated that the unit had been removed and that the production system was blew down and sent to the vapor recovery flare. He continued any other releases were due to choke changes on the well to optimize production. While on location I did not experience any audible pressure releases. I will contact Mr. Wisler concerning the source and cause of the release. |
2123964073 | 2017-10-31 | Production Wells | No Violations | The purpose of my inspection was to document the status of complaint # 5727. At the time of my inspection, stimulation activities on the Elkrun-Scheel Pad had concluded and water transfer equipment including the pump was moved off of location. A total of eight 500 bbl frac tanks remained on location. While on location I e-mailed Mr. Whisler about the current status of the complaint. Mr. Whisler replied with a thank you for assistance. |
853334603 | 2017-7-17 0:00: | PW | No Violations | 1.50 |
For data sources see[10]