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Wellbore #00 Wellbore Classification: OW Status: PR - 4/1/2025 Measured TD: 8310 ft. Vertical TD: 8299 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: OW PR - 4/1/2025 | | Wellbore Permit | DIRECTIONAL | | Permit #: | | Expiration Date: | 7/17/2016 | | Proposed Top PZ Location: | Sec:35 Twp: 5S 54W | Footage: 611 FSL 2021 FWL | | Bottom Hole Location: | Sec:35 Twp: 5S 54W | Footage: 611 FSL 2021 FWL | | Proposed Depth/Form: | 9009 ft. | | Surface Mineral Owner Same: | No | | Mineral Owner: | FEE | Surface Owner: | FEE | | Unit: | | Unit Number: | | | Formation And Spacing: | Code: ATOK , Formation: ATOKA , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: CHRK , Formation: CHEROKEE , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: LGKC , Formation: LANSING-KANSAS CITY , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: MRRW , Formation: MORROW , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: MRTN , Formation: MARMATON , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: MSSP , Formation: MISSISSIPPIAN , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: SPGN , Formation: SPERGEN , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: WFCMP , Formation: WOLFCAMP , 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: 122, Top: 0 ft., Bottom: 350 ft. | | Casing: | String Type: 1ST, Hole Size: 7.875 in., Size: 5.5 in., Top: 0 ft., Depth: 9000 ft., Weight: 17 , Citings Type: PLANNED | | Cement: | Sacks: 1109, Top: 6000 ft., Bottom: 9000 ft. |
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| Wellbore Completed | | Completion Date: | 9/29/2014 | | Spud Date: | 9/8/2014 | Spud Date Is: | ACTUAL | | Measured TD: | 8310 ft. | Measured PB depth: | 8213 ft. | | True Vertical TD: | 8299 ft. | True Vertical PB depth: | 0 ft. | | Top PZ Location: | Sec:35 Twp: 5S 54W | Footage: 611 FSL 2021 FWL | | Bottom Hole Location: | Sec:35 Twp: 5S 54W | Footage: 611 FSL 2021 FWL | | Log Types: | Triple Combo, CBL | | Casing: | String Type: SURF, Hole Size: 12.25 in., Size: 8.625 in., Top: 0 ft., Depth: 360 ft., Weight: 24 , Citings Type: ACTUAL | | Cement: | Sacks: 175, Top: 0 ft., Bottom: 360 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 7.875 in., Size: 5.5 in., Top: 0 ft., Depth: 8304 ft., Weight: 17 , Citings Type: ACTUAL | | Cement: | Sacks: 1219, Top: 0 ft., Bottom: 8304 ft., Determination Method: CBL | | Formation | Interval Top | Log Bottom | Cored | DSTs | | WOLFCAMP | 6181 ft. | | | | | LANSING-KANSAS CITY | 6875 ft. | | | | | MARMATON | 7160 ft. | | | | | CHEROKEE | 7377 ft. | | | | | ATOKA | 7686 ft. | | | | | MORROW | 7853 ft. | | | | | MISSISSIPPIAN | 7996 ft. | | | | | SPERGEN | 8032 ft. | | | |
Formation SPGN Formation Classification: OW Status: AB - 10/10/2014 Interval Top: 8072 ft. Interval Bottom: 8124 ft.| Completed Information for Formation SPERGEN | | 1st Production Date: | N/A | Choke Size: | | | Formation Name: | SPERGEN | Commingled: | | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 10/5/2014 | Treatment End Date: | 10/7/2014 | | Treatment Summary: | Simpson is also included in this formation but not a combo choice available.
Perf'd 8,114' - 8,124' & 8,072' - 8,080'
Acidized with 30 bbls of 7.5% HCL with inhibitors loading hole Switched to 63 bbls of 2% KCI water flush | | Total fluid used in treatment (bbls): | 93 | Max pressure during treatment (psi): | 2600 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 30 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | 163 | | Fresh water used in treatment (bbls): | 63 | Disposition method For flowback: | RECYCLE | | Total proppant used (lbs): | | Green completions techniques utilized: | Yes | | Reason green techniques Not utilized: |
| | Tubing Size: | 2.875 in. | Tubing Setting Depth: | 8067 ft. | | Tubing Packer Depth: | 8051 ft. | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation SPGN. |
| | Perforation Data: | | Interval Top: | 8072 ft. | # Of Holes: | 108 | | Interval Bottom: | 8124 ft. | Hole Size: | 0.48 in. |
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Formation CHRK Formation Classification: OW Status: AB - 1/31/2018 Interval Top: 7426 ft. Interval Bottom: 7429 ft.| Completed Information for Formation CHEROKEE | | 1st Production Date: | 10/30/2014 | Choke Size: | | | Formation Name: | CHEROKEE | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 3/9/2015 | Treatment End Date: | 3/11/2015 | | Treatment Summary: | Cherokee previously reported producing.
Performed a new stimulation -Acidized with 4,000 gallons of 20% gel acid and displaced with 179 bbls of KCL water | | Total fluid used in treatment (bbls): | 274 | Max pressure during treatment (psi): | 2860 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 95 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 179 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 10/10/2014 | Treatment End Date: | 10/14/2014 | | Treatment Summary: | Acidized with 500 gallons of 7.5% acetic acid with additives and 45 bbls of KCI water
Acideized with 500 gallons of 15% HCI with additives and 49 bbls of 2% KCI water | | Total fluid used in treatment (bbls): | 118 | Max pressure during treatment (psi): | 1700 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 24 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | 155 | | Fresh water used in treatment (bbls): | 94 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | | Green completions techniques utilized: | No | | Reason green techniques Not utilized: PIPELINE |
| | 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_OIL | 407 | | BTU_GAS | 1481 | | CALC_BBLS_OIL | 407 | | CALC_GOR | 47 | | CALC_MCF_GAS | 19 | | GRAVITY_OIL | 39 | | MCF_GAS | 19 | | TUBING_PRESS | 72 |
| | Perforation Data: | | Interval Top: | 7426 ft. | # Of Holes: | 18 | | Interval Bottom: | 7429 ft. | Hole Size: | 0.48 in. |
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Formation MRTN Formation Classification: OW Status: PR - 4/1/2025 Interval Top: 7160 ft. Interval Bottom: 7416 ft.| Completed Information for Formation MARMATON | | 1st Production Date: | 10/31/2014 | Choke Size: | | | Formation Name: | MARMATON | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 1/9/2023 | Treatment End Date: | 1/9/2023 | | Treatment Summary: | 1/9/2023 Pumped 1,000 gals 15% NE/FE Acid w/2gals CIA-165; 1 gal SI-4. | | Total fluid used in treatment (bbls): | 67 | Max pressure during treatment (psi): | 50 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 24 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 43 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 1/12/2018 | Treatment End Date: | 1/31/2018 | | Treatment Summary: | Acidized with 500gals 7.5% MCA with 2% KCL flush | | Total fluid used in treatment (bbls): | 58 | Max pressure during treatment (psi): | 1200 | | 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): | 0 | Total flowback volume recovered (bbls): | 0 | | Fresh water used in treatment (bbls): | 46 | Disposition method For flowback: | | | Total proppant used (lbs): | | Green completions techniques utilized: | Yes | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 3/12/2015 | Treatment End Date: | 3/20/2015 | | Treatment Summary: | Marmaton previously reported producing
Performed new stimulation - Acidized with 4,000 gallons of 20% gelled HCL and displaced with 186 bbls of 2% KCl
Added perfs 7160-7165
Acidized with 1250 gallons of 15% HCL and flushed with 83 bbls of 2% KCl | | Total fluid used in treatment (bbls): | 394 | Max pressure during treatment (psi): | 2240 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 125 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | 367 | | Fresh water used in treatment (bbls): | 269 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 10/16/2014 | Treatment End Date: | 10/14/2014 | | Treatment Summary: | Acidize with 22 bbls of 15% HCL with additives and 51 bbls of 2% KCI water | | Total fluid used in treatment (bbls): | 73 | Max pressure during treatment (psi): | 1000 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 22 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | 113 | | Fresh water used in treatment (bbls): | 51 | Disposition method For flowback: | RECYCLE | | Total proppant used (lbs): | | Green completions techniques utilized: | Yes | | Reason green techniques Not utilized: |
| | Tubing Size: | 2.875 in. | Tubing Setting Depth: | 7384 ft. | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | Initial Test Data: | | Test Date: | 1/11/2023 | Test Method: | Swabbing | | Hours Tested: | 4 | Gas Type: | | | Gas Disposal: | | |
| Test Type | Measure |
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| BBLS_H2O | 22 | | BBLS_OIL | 1 | | BTU_GAS | 1481 | | CALC_BBLS_H2O | 528 | | CALC_BBLS_OIL | 24 | | CALC_GOR | 47 | | CALC_MCF_GAS | 19 | | GRAVITY_OIL | 39 | | MCF_GAS | 19 | | TUBING_PRESS | 75 |
| | Perforation Data: | | Interval Top: | 7160 ft. | # Of Holes: | 90 | | Interval Bottom: | 7416 ft. | Hole Size: | 0.41 in. |
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Formation MT-CRK Formation Classification: OW Status: CM - 3/21/2015 Interval Top: 7160 ft. Interval Bottom: 7429 ft.| Completed Information for Formation MARMATON-CHEROKEE | | 1st Production Date: | N/A | Choke Size: | | | Formation Name: | MARMATON-CHEROKEE | Commingled: | | | Production Method: | | | Open Hole Completion: | |
| | Tubing Size: | 2.875 in. | Tubing Setting Depth: | 7490 ft. | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | Initial Test Data: | | Test Date: | 3/21/2015 | Test Method: | Pumping | | Hours Tested: | 24 | Gas Type: | DRY | | Gas Disposal: | FLARED | |
| Test Type | Measure |
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| BBLS_H2O | 258 | | BBLS_OIL | 55 | | BTU_GAS | 1618 | | CALC_BBLS_H2O | 258 | | CALC_BBLS_OIL | 55 | | CALC_GOR | 382 | | CALC_MCF_GAS | 21 | | CASING_PRESS | 40 | | GRAVITY_OIL | 39 | | MCF_GAS | 21 | | TUBING_PRESS | 40 |
| | Perforation Data: | | Interval Top: | 7160 ft. | # Of Holes: | 84 | | Interval Bottom: | 7429 ft. | Hole Size: | |
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Formation LGKC Formation Classification: OW Status: AB - 1/31/2018 Interval Top: 6882 ft. Interval Bottom: 6888 ft.| Completed Information for Formation LANSING-KANSAS CITY | | 1st Production Date: | 5/1/2017 | Choke Size: | | | Formation Name: | LANSING-KANSAS CITY | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | | | Treatment Date: | 5/16/2017 | Treatment End Date: | N/A | | Treatment Summary: | Perforated only | | 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: |
| | 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 LGKC. |
| | Perforation Data: | | Interval Top: | 6882 ft. | # Of Holes: | 36 | | Interval Bottom: | 6888 ft. | Hole Size: | 0.45 in. |
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Formation LKCMCK Formation Classification: OW Status: CM - 5/4/2017 Interval Top: 6882 ft. Interval Bottom: 7429 ft.| Completed Information for Formation LANSING-KANSAS CITY-MARMATON-CHEROKEE | | 1st Production Date: | N/A | Choke Size: | | | Formation Name: | LANSING-KANSAS CITY-MARMATON-CHEROKEE | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | | | Treatment Date: | 5/4/2017 | Treatment End Date: | N/A | | Treatment Summary: | Submitting testing info only... | | 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: |
| | Tubing Size: | 2.875 in. | Tubing Setting Depth: | 7494 ft. | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | Initial Test Data: | | Test Date: | 5/4/2017 | Test Method: | Pumping | | Hours Tested: | 24 | Gas Type: | WET | | Gas Disposal: | FLARED | |
| Test Type | Measure |
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| BBLS_H2O | 358 | | BTU_GAS | 1251 | | CALC_BBLS_H2O | 358 | | CALC_MCF_GAS | 1 | | CASING_PRESS | 13 | | MCF_GAS | 1 | | TUBING_PRESS | 60 |
| | Perforation Data: | | Interval Top: | 6882 ft. | # Of Holes: | 120 | | Interval Bottom: | 7429 ft. | Hole Size: | |
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| Reported Plugged | N | |
| Out Of Service Repurposed | N | |
| Out Of Service | N | |
| Inactive Exception | N | |
| Noticed Inactive | N | |
| Defined Inactive | N | |
| Low Producing | N | |
| Total Oil Produced (Barrels) | 1847 |
| Total Gas Produced (MCF) | 0 |
| GOR | |
| GOR Determination | BOE |
| Average BOE per Day | 5.035 |
| Average MCFE per Day | 29.206 |
| Federal Financial Assurance | i | |
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