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Wellbore #00 Wellbore Classification: OW Status: SI - 3/1/2022 Measured TD: 8360 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: OW SI - 3/1/2022 | | Wellbore Permit | | | Permit #: | | Expiration Date: | 5/28/2017 | | Proposed Depth/Form: | 8500 ft. | | Surface Mineral Owner Same: | No | | Mineral Owner: | FEE | Surface Owner: | FEE | | Unit: | | Unit Number: | | | Formation And Spacing: | Code: CMBR , Formation: CAMBRIAN , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: CRTC , Formation: CRETACEOUS , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: MSSP , Formation: MISSISSIPPIAN , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: ORDV , Formation: ORDOVICIAN , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: PENN , Formation: PENNSYLVANIAN , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: PRMN , Formation: PERMIAN , Order: , Unit Acreage: , Drill Unit: | | Casing: | String Type: SURF, Hole Size: 12.25 in., Size: 8.625 in., Top: 0 ft., Depth: 350 ft., Weight: 24 , Citings Type: PLANNED | | Cement: | Sacks: 132, Top: 0 ft., Bottom: 350 ft. | | Casing: | String Type: 1ST, Hole Size: 7.875 in., Size: 5.5 in., Top: 0 ft., Depth: 8500 ft., Weight: 17 , Citings Type: PLANNED | | Cement: | Sacks: 1191, Top: 6000 ft., Bottom: 8500 ft. |
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| Wellbore Completed | | Completion Date: | 9/21/2015 | | Spud Date: | 9/1/2015 | Spud Date Is: | ACTUAL | | Measured TD: | 8360 ft. | Measured PB depth: | 8240 ft. | | True Vertical TD: | | True Vertical PB depth: | | | Log Types: | Triple Combo | | Casing: | String Type: SURF, Hole Size: 12.25 in., Size: 8.625 in., Top: 0 ft., Depth: 351 ft., Weight: 24 , Citings Type: ACTUAL | | Cement: | Sacks: 127, Top: 0 ft., Bottom: 351 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 7.875 in., Size: 5.5 in., Top: 0 ft., Depth: 8352 ft., Weight: 17 , Citings Type: ACTUAL | | Cement: | Sacks: 1290, Top: 72 ft., Bottom: 8352 ft., Determination Method: CBL | | Additional Cement: | String Type: 1ST , Top: 7133 ft., Depth: 7146 ft., Bottom: 7146 ft., Sacks: 50, Method: SQUEEZE | | Additional Cement: | String Type: 1ST , Top: 7133 ft., Depth: 7146 ft., Bottom: 7146 ft., Sacks: 40, Method: SQUEEZE | | Formation | Interval Top | Log Bottom | Cored | DSTs | | NIOBRARA | 3570 ft. | | | | | DAKOTA | 4555 ft. | | | | | WOLFCAMP | 6153 ft. | | | | | LANSING-KANSAS CITY | 6932 ft. | | | | | MARMATON | 7132 ft. | | | | | CHEROKEE | 7387 ft. | | | | | ATOKA | 7616 ft. | | | | | MORROW | 7872 ft. | | | | | ST LOUIS | 7988 ft. | | | | | SPERGEN | 8078 ft. | | | | | SIMPSON | 8231 ft. | | | |
Formation STLS Formation Classification: OW Status: SI - 3/1/2022 Interval Top: 8058 ft. Interval Bottom: 8077 ft.| Completed Information for Formation ST LOUIS | | 1st Production Date: | 11/19/2015 | Choke Size: | | | Formation Name: | ST LOUIS | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 9/15/2016 | Treatment End Date: | 9/16/2016 | | Treatment Summary: | See information given with Marmaton - Formations are commingled so treatment was given to both | | Total fluid used in treatment (bbls): | | Max pressure during treatment (psi): | | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | | Disposition method For flowback: | | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 9/25/2015 | Treatment End Date: | 9/30/2015 | | Treatment Summary: | Acidized with 2,100 gallons of 15% HCI containing 60 gals of RAS-10(non emulsifier, anti sludge) 8 gallons of iron control, 10 gallons of corrosion inhibitor, 4 gallons of scale inhibitor and 1 gallon of biocide. Displaced with 50 bbls of 2% KCL water.
Daily test values are inputted on the Marmaton tab | | Total fluid used in treatment (bbls): | 100 | Max pressure during treatment (psi): | 700 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 50 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | 54 | | Fresh water used in treatment (bbls): | 50 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | | Green completions techniques utilized: | No | | Reason green techniques Not utilized: |
| | Tubing Size: | | Tubing Setting Depth: | | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation STLS. |
| | Perforation Data: | | Interval Top: | 8058 ft. | # Of Holes: | 114 | | Interval Bottom: | 8077 ft. | Hole Size: | 0.45 in. |
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Formation MRTN Formation Classification: OW Status: SI - 3/1/2022 Interval Top: 7330 ft. Interval Bottom: 7367 ft.| Completed Information for Formation MARMATON | | 1st Production Date: | 11/19/2015 | Choke Size: | | | Formation Name: | MARMATON | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 9/15/2016 | Treatment End Date: | 9/16/2016 | | Treatment Summary: | Acidized with 500 gallons of 7 1/2% HCL followed by 4 bbls of production water with 5 gallons of surfactant added. Displaced with 38.5 bbls of production water . | | Total fluid used in treatment (bbls): | 54 | Max pressure during treatment (psi): | 30 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 12 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | 42 | Total flowback volume recovered (bbls): | 94 | | Fresh water used in treatment (bbls): | 0 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | 0 | Green completions techniques utilized: | No | | Reason green techniques Not utilized: PIPELINE | | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 10/5/2015 | Treatment End Date: | 11/6/2015 | | Treatment Summary: | Acidized with 12 bbls of 15% HCI containing 12 gallons of RAS-92 (anti-sludge, demulsifier) 2 gallons of iron control, 1 gallon scale inhibitor & 2.5 gallons of corrosion inhibitor.
Displaced with 43 bbls of 2% KCI water | | Total fluid used in treatment (bbls): | 55 | Max pressure during treatment (psi): | 2300 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 12 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | 87 | | Fresh water used in treatment (bbls): | 43 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | | Green completions techniques utilized: | No | | Reason green techniques Not utilized: |
| | Tubing Size: | | Tubing Setting Depth: | | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | Initial Test Data: | | Test Date: | N/A | Test Method: | | | Hours Tested: | | Gas Type: | | | Gas Disposal: | | |
| Test Type | Measure |
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| BBLS_H2O | 27 | | BBLS_OIL | 15 | | BTU_GAS | 694 | | CALC_BBLS_H2O | 27 | | CALC_BBLS_OIL | 15 | | CALC_GOR | 67 | | CALC_MCF_GAS | 1 | | GRAVITY_OIL | 36 | | MCF_GAS | 1 | | TUBING_PRESS | 55 |
| | Perforation Data: | | Interval Top: | 7330 ft. | # Of Holes: | 230 | | Interval Bottom: | 7367 ft. | Hole Size: | 0.45 in. |
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| Reported Plugged | N | |
| Out Of Service Repurposed | N | |
| Out Of Service | N | |
| Inactive Exception | N | |
| Noticed Inactive | Y | Noticed Date
11/05/2024 |
| Defined Inactive (SI ) | Y | Defined Inactive
01/31/2018 |
| Low Producing | Y | Production Period
12/2024 - 11/2025 |
| Total Oil Produced (Barrels) | 0 |
| Total Gas Produced (MCF) | 0 |
| GOR | |
| GOR Determination | |
| Average BOE per Day | 0.000 |
| Average MCFE per Day | 0.000 |
| Federal Financial Assurance | i | |
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