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Wellbore #00 Wellbore Classification: OW Status: SI - 3/1/2024 Measured TD: 8190 ft. Vertical TD: 8187 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: OW SI - 3/1/2024 | | Wellbore Permit | | | Permit #: | | Expiration Date: | 4/4/2021 | | Proposed Depth/Form: | 8190 ft. | | Surface Mineral Owner Same: | No | | Mineral Owner: | FEE | Surface Owner: | FEE | | Unit: | | Unit Number: | | | Formation And Spacing: | Code: DKTA , Formation: DAKOTA , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: ENRD , Formation: ENTRADA , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: FRTR , Formation: FRONTIER , Order: , Unit Acreage: , Drill Unit: | | Formation And Spacing: | Code: LKTA , Formation: LAKOTA , Order: , Unit Acreage: , Drill Unit: | | Casing: | String Type: CONDUCTOR, Hole Size: 24 in., Size: 16 in., Top: 0 ft., Depth: 40 ft., Weight: , Citings Type: PLANNED | | Cement: | Sacks: 50, Top: 0 ft., Bottom: 40 ft. | | Casing: | String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 802 ft., Weight: 36 , Citings Type: PLANNED | | Cement: | Sacks: 450, Top: 0 ft., Bottom: 802 ft. | | Casing: | String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 8185 ft., Weight: 26 , Citings Type: PLANNED | | Cement: | Sacks: 820, Top: , Bottom: 8185 ft. |
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| Wellbore Completed | | Completion Date: | 6/30/2008 | | Spud Date: | 6/15/2008 | Spud Date Is: | ACTUAL | | Measured TD: | 8190 ft. | Measured PB depth: | 8143 ft. | | True Vertical TD: | 8187 ft. | True Vertical PB depth: | 8140 ft. | | Log Types: | QUAD-COMBO, GR DEN/NEU, ARRAY IND, SONIC (BHC) 8000-803, CBL, HVCL, MUD | | Casing: | String Type: CONDUCTOR, Hole Size: 24 in., Size: 16 in., Top: 0 ft., Depth: 40 ft., Weight: , Citings Type: ACTUAL | | Cement: | Sacks: 0, Top: 0 ft., Bottom: 40 ft., Determination Method: | | Casing: | String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 802 ft., Weight: 36 , Citings Type: ACTUAL | | Cement: | Sacks: 450, Top: 0 ft., Bottom: 802 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 8185 ft., Weight: 23 , Citings Type: ACTUAL | | Cement: | Sacks: 820, Top: 0 ft., Bottom: 8185 ft., Determination Method: CBL | | Formation | Interval Top | Log Bottom | Cored | DSTs | | TERTIARY | 0 ft. | | N | N | | SUDDUTH COAL | 2895 ft. | | N | N | | SUSSEX | 5072 ft. | | N | N | | SHANNON | 5450 ft. | | N | N | | NIOBRARA | 6766 ft. | | N | N | | FRONTIER | 7297 ft. | | N | N | | MOWRY | 7630 ft. | | N | N | | DAKOTA | 7730 ft. | | N | N | | LAKOTA | 7829 ft. | | | | | MORRISON | 7904 ft. | | N | N |
Formation LKTA Formation Classification: DSPW Status: CM - 6/4/2019 Interval Top: 7830 ft. Interval Bottom: 7902 ft.| Completed Information for Formation LAKOTA | | 1st Production Date: | 10/2/2017 | Choke Size: | | | Formation Name: | LAKOTA | Commingled: | Yes | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 9/14/2017 | Treatment End Date: | 9/14/2017 | | Treatment Summary: | SD tried an acid job but was only able to pump 55 gals of mutual solvents w/30 bbls of fresh water/KCl combo before we had equipment failure and stopped the job. | | Total fluid used in treatment (bbls): | 32 | 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): | 10 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 22 | 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: | 11/8/2016 | Treatment End Date: | 11/8/2016 | | Treatment Summary: | 3715 gal fresh water & 7327 gal 15% HCL acid | | Total fluid used in treatment (bbls): | 263 | Max pressure during treatment (psi): | 4160 | | Total gas used in treatment (mcf): | 0 | Fluid density (lbs/gal): | 8.60 | | Type Of gas: | | Number Of staged intervals: | 4 | | Total acid used in treatment (bbls): | 174 | Min frac gradient (psi/ft): | 0.73 | | Recycled water used in treatment (bbls): | 0 | Total flowback volume recovered (bbls): | 0 | | Fresh water used in treatment (bbls): | 89 | Disposition method For flowback: | | | Total proppant used (lbs): | 0 | 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 LKTA. |
| | Perforation Data: | | Interval Top: | 7830 ft. | # Of Holes: | 288 | | Interval Bottom: | 7902 ft. | Hole Size: | 0.58 in. |
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Formation DK-LK Formation Classification: DSPW Status: SI - 3/1/2024 Interval Top: 7730 ft. Interval Bottom: 7902 ft.| Completed Information for Formation DAKOTA-LAKOTA | | 1st Production Date: | 10/2/2017 | Choke Size: | | | Formation Name: | DAKOTA-LAKOTA | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 9/28/2018 | Treatment End Date: | 9/28/2018 | | Treatment Summary: | 36 bbls 15% NEFE HCL acid and 2603 bbls total crosslink water used and 131,900 lbs total 20/40 sand.
| | Total fluid used in treatment (bbls): | 2603 | Max pressure during treatment (psi): | 4696 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | 8.33 | | Type Of gas: | | Number Of staged intervals: | 1 | | Total acid used in treatment (bbls): | 36 | Min frac gradient (psi/ft): | 0.85 | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | 0 | | Fresh water used in treatment (bbls): | 2567 | Disposition method For flowback: | | | Total proppant used (lbs): | 131900 | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: PIPELINE | | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 9/12/2017 | Treatment End Date: | 9/14/2017 | | Treatment Summary: | SD tried an acid job but was only able to pump 55 gals of mutual solvents w/30 bbls of fresh water/KCl combo before we had equipment failure and stopped the job. | | Total fluid used in treatment (bbls): | 32 | 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): | 10 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 22 | 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: | 11/8/2016 | Treatment End Date: | 11/8/2016 | | Treatment Summary: | 6,090 gal. Fresh water & 12,012 gal 15% HCL acid | | Total fluid used in treatment (bbls): | 431 | Max pressure during treatment (psi): | 4160 | | Total gas used in treatment (mcf): | 0 | Fluid density (lbs/gal): | 8.60 | | Type Of gas: | | Number Of staged intervals: | 7 | | Total acid used in treatment (bbls): | 286 | Min frac gradient (psi/ft): | 0.73 | | Recycled water used in treatment (bbls): | 0 | Total flowback volume recovered (bbls): | 0 | | Fresh water used in treatment (bbls): | 145 | Disposition method For flowback: | | | Total proppant used (lbs): | 0 | 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 DK-LK. |
| | Perforation Data: | | Interval Top: | 7730 ft. | # Of Holes: | 472 | | Interval Bottom: | 7902 ft. | Hole Size: | 0.58 in. |
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Formation DKTA Formation Classification: DSPW Status: CM - 6/4/2019 Interval Top: 7730 ft. Interval Bottom: 7776 ft.| Completed Information for Formation DAKOTA | | 1st Production Date: | 10/2/2017 | Choke Size: | | | Formation Name: | DAKOTA | Commingled: | Yes | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 9/12/2017 | Treatment End Date: | 9/14/2017 | | Treatment Summary: | SD tried an acid job but was only able to pump 55 gals of mutual solvents w/30 bbls of fresh water/KCl combo before we had equipment failure and stopped the job. | | Total fluid used in treatment (bbls): | 32 | 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): | 10 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 22 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | | Green completions techniques utilized: | Yes | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 11/8/2016 | Treatment End Date: | 11/8/2016 | | Treatment Summary: | 2375 gal fresh water & 4,662 gal 15% HCL acid | | Total fluid used in treatment (bbls): | 168 | Max pressure during treatment (psi): | 4160 | | Total gas used in treatment (mcf): | 0 | Fluid density (lbs/gal): | 8.60 | | Type Of gas: | | Number Of staged intervals: | 3 | | Total acid used in treatment (bbls): | 111 | Min frac gradient (psi/ft): | 0.73 | | Recycled water used in treatment (bbls): | 0 | Total flowback volume recovered (bbls): | 0 | | Fresh water used in treatment (bbls): | 57 | Disposition method For flowback: | | | Total proppant used (lbs): | 0 | 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 DKTA. |
| | Perforation Data: | | Interval Top: | 7730 ft. | # Of Holes: | 184 | | Interval Bottom: | 7776 ft. | Hole Size: | 0.58 in. |
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Formation FRTR Formation Classification: DSPW Status: SI - 3/1/2024 Interval Top: 7297 ft. Interval Bottom: 7351 ft.| Completed Information for Formation FRONTIER | | 1st Production Date: | N/A | Choke Size: | | | Formation Name: | FRONTIER | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 4/19/2019 | Treatment End Date: | 5/5/2019 | | Treatment Summary: | Perforated the Frontier from 7297-7351'. Swabbed back 73 bbls of formation fluid. Pumped acid stimulation with 574 bbls of 15% NEFE HCl and 73 bbls of treated water. Pumped step rate test with 1415 bbls of treated water.
| | Total fluid used in treatment (bbls): | 2062 | Max pressure during treatment (psi): | 4025 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | 8.43 | | Type Of gas: | | Number Of staged intervals: | 1 | | Total acid used in treatment (bbls): | 574 | Min frac gradient (psi/ft): | 0.75 | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | 73 | | Fresh water used in treatment (bbls): | 1488 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | 0 | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: PIPELINE |
| | Tubing Size: | 3.5 in. | Tubing Setting Depth: | 7287 ft. | | Tubing Packer Depth: | 7270 ft. | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation FRTR. |
| | Perforation Data: | | Interval Top: | 7297 ft. | # Of Holes: | 216 | | Interval Bottom: | 7351 ft. | Hole Size: | 0.56 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
03/30/2023 |
| Defined Inactive (UIC) | Y | Last Use
04/30/2019 |
| Low Producing | N | |
| 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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