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Wellbore #00 Wellbore Classification: DSPW Status: IJ - 4/3/2025 Measured TD: 6517 ft. Vertical TD: 6517 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: DSPW IJ - 4/3/2025 | | Wellbore Permit | | | Permit #: | 100001 | Expiration Date: | 4/30/1974 | | Proposed Depth/Form: | | | Surface Mineral Owner Same: | Not available | | Mineral Owner: | FEE | Surface Owner: | Not available | | Unit: | | Unit Number: | | | Formation And Spacing: | Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit: |
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| Wellbore Completed | | Completion Date: | 3/7/1974 | | Measured TD: | 6517 ft. | Measured PB depth: | 6490 ft. | | True Vertical TD: | 6517 ft. | True Vertical PB depth: | | | Casing: | String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 772 ft., Weight: 40.5 , Citings Type: ACTUAL | | Cement: | Sacks: 525, Top: 0 ft., Bottom: 772 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6517 ft., Weight: 23 , Citings Type: ACTUAL | | Cement: | Sacks: 700, Top: , Bottom: 6517 ft., Determination Method: CALC | | Casing: | String Type: 2ND, Hole Size: 5.5 in., Size: 5 in., Top: 5464 ft., Depth: 6506 ft., Weight: 18 , Citings Type: ACTUAL | | Cement: | Sacks: 100, Top: 5464 ft., Bottom: 6506 ft., Determination Method: CALC | | Casing: | String Type: 1ST LINER, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 5484 ft., Weight: 17 , Citings Type: ACTUAL | | Cement: | Sacks: 225, Top: , Bottom: 5484 ft., Determination Method: | | Additional Cement: | String Type: 1ST , Top: 2116 ft., Depth: 3208 ft., Bottom: 3208 ft., Sacks: 1500, Method: Squeeze | | Formation | Interval Top | Log Bottom | Cored | DSTs | | DAKOTA | 3164 ft. | | | | | MORRISON | 3278 ft. | | | | | CURTIS | 3895 ft. | | | | | ENTRADA | 3997 ft. | | | | | CARMEL | 4157 ft. | | | | | NAVAJO | 4223 ft. | | | | | CHINLE | 4794 ft. | | | | | SHINARUMP | 4978 ft. | | | | | WEBER | 5660 ft. | | | |
Formation WEBR Formation Classification: ERIW Status: IJ - 4/3/2025 Interval Top: 5669 ft. Interval Bottom: 6451 ft.| Completed Information for Formation WEBER | | 1st Production Date: | 8/20/1974 | Choke Size: | | | Formation Name: | WEBER | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | | | Treatment Date: | 4/29/2025 | Treatment End Date: | N/A | | Treatment Summary: | Well work to repair well, replacing tubing and packer. Well to be returned to injection pending an approved form 21.
Note correction to perforations on 11/1981 well work. | | 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: | 3/26/2025 | Treatment End Date: | 3/26/2025 | | Treatment Summary: | Pumped 4000 gallons (95.2 bbls) 15 % HCL w/solvent and 40 bbls Fresh water. | | Total fluid used in treatment (bbls): | 135 | Max pressure during treatment (psi): | 2321 | | 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): | 0 | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 40 | Disposition method For flowback: | | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Type: | | | Treatment Date: | 12/13/2014 | Treatment End Date: | 12/13/2014 | | Treatment Summary: | PUMPED 4000 GALLONS 15% HCL THROUGH COILED TUBING AT 5413' | | Total fluid used in treatment (bbls): | 295 | 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): | 95 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 200 | 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: | 5811 ft. | | Tubing Packer Depth: | 5365 ft. | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation WEBR. |
| | Perforation Data: | | Interval Top: | 5669 ft. | # Of Holes: | 135 | | Interval Bottom: | 6451 ft. | Hole Size: | 0.5 in. |
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| Reported Plugged | N | |
| Out Of Service Repurposed | N | |
| Out Of Service | N | |
| Inactive Exception | N | |
| Noticed Inactive | N | |
| Defined Inactive (UIC) | Y | Defined Inactive
04/30/2023 |
| 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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