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Wellbore #00 Wellbore Classification: ERIW Status: IJ - 12/1/2021 Measured TD: 6660 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: ERIW IJ - 12/1/2021 | | Wellbore Permit | | | Permit #: | 10001 | Expiration Date: | 9/5/1980 | | Prop Depth/Form: | | | Surface Mineral Owner Same: | Not available | | Mineral Owner: | FEDERAL | Surface Owner: | Not available | | Unit: | | Unit Number: | D-032675 | | Formation And Spacing: | Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit: |
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| Wellbore Completed | | Completion Date: | 5/20/1985 | | Spud Date: | 6/9/1946 | Spud Date Is: | ACTUAL | | Measured TD: | 6660 ft. | Measured PB depth: | 6645 ft. | | True Vertical TD: | | True Vertical PB depth: | | | Log Types: | | | Casing: | String Type: CONDUCTOR, Hole Size: 24 in., Size: 16 in., Top: 12 ft., Depth: 57 ft., Weight: 55 , Citings Type: ACTUAL | | Cement: | Sacks: 110, Top: 0 ft., Bottom: 57 ft., Determination Method: VISU | | Casing: | String Type: SURF, Hole Size: 13.75 in., Size: 10.75 in., Top: 12 ft., Depth: 988 ft., Weight: 40.5 , Citings Type: ACTUAL | | Cement: | Sacks: 750, Top: 0 ft., Bottom: 988 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 10.75 in., Size: 7 in., Top: 0 ft., Depth: 6322 ft., Weight: 23 , Citings Type: ACTUAL | | Cement: | Sacks: 1250, Top: 0 ft., Bottom: 6322 ft., Determination Method: VISU | | Casing: | String Type: S.C. 1.1, Hole Size: , Size: , Top: , Depth: 1038 ft., Weight: , Citings Type: ACTUAL | | Cement: | Sacks: 400, Top: 0 ft., Bottom: 1038 ft., Determination Method: CALC | | Casing: | String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 6245 ft., Weight: 17 , Citings Type: ACTUAL | | Cement: | Sacks: 305, Top: 0 ft., Bottom: 6245 ft., Determination Method: VISU | | Casing: | String Type: OPEN HOLE, Hole Size: 7 in., Size: , Top: 6322 ft., Depth: 6660 ft., Weight: , Citings Type: ACTUAL | | Cement: | Sacks: , Top: , Bottom: , Determination Method: | | Formation | Interval Top | Log Bottom | Cored | DSTs | | NIOBRARA | 2561 ft. | 3325 ft. | N | N | | FRONTIER | 3325 ft. | 3584 ft. | N | N | | MOWRY | 3584 ft. | 3678 ft. | N | N | | DAKOTA | 3678 ft. | 3750 ft. | N | N | | MORRISON | 3750 ft. | 4479 ft. | N | N | | CURTIS | 4479 ft. | 4584 ft. | N | N | | ENTRADA | 4584 ft. | 4720 ft. | N | N | | CARMEL | 4720 ft. | 4772 ft. | N | N | | NAVAJO | 4772 ft. | 5410 ft. | N | N | | CHINLE | 5410 ft. | 5535 ft. | N | N | | SHINARUMP | 5535 ft. | 5612 ft. | N | N | | MOENKOPI | 5612 ft. | 6292 ft. | N | N | | WEBER | 6292 ft. | 6660 ft. | N | N |
Formation WEBR Formation Classification: ERIW Status: IJ - 12/1/2021 Interval Top: 6322 ft. Interval Bottom: 6604 ft.| Completed Information for Formation WEBER | | 1st Production Date: | 5/20/1985 | Choke Size: | | | Formation Name: | WEBER | Commingled: | No | | Production Method: | | | Open Hole Completion: | Yes |
| | Formation Treatment | | Treatment Type: | | | Treatment Date: | 11/10/2021 | Treatment End Date: | N/A | | Treatment Summary: | Perfs from 6606-6632. Pulled injection string, drilled out the old 5-1/2” fiberglass liner to 6604’, perforated the 7” casing @ 1038’ and performed a bradenhead squeeze w/ 400 sxs. Ran new 5-1/2” 17#, L-80 liner from 0’-6245’, cemented w/ 305 sxs, and then ran the new injection string. All cement tops in this well should now say 0’ by visual since we did the bradenhead squeeze on the 7” and got returns while cementing the liner. | | 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: | 8/4/2020 | Treatment End Date: | 8/4/2020 | | Treatment Summary: | PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT, 80 BBLS WATER | | Total fluid used in treatment (bbls): | 128 | Max pressure during treatment (psi): | 2400 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 48 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 80 | 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: | 12/17/2017 | Treatment End Date: | 12/17/2017 | | Treatment Summary: | PUMPED 48 BBLS 15% HCL WITH 1.5 BBLS SOLVENT AND CORRISON INHIBITOR AND 154 BBLS WATER. CONVERTED TO INJECTION 5/20/1985 | | Total fluid used in treatment (bbls): | 203 | Max pressure during treatment (psi): | 2400 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 48 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 154 | 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: | 6/30/2016 | Treatment End Date: | 6/30/2016 | | Treatment Summary: | PUMPED 2.8 BBLS MUTUAL SOLVENT, 47.2 BBLS 15% HCL AND 320 BBLS WATER AT STARTING RATE 4 BPM AT 2400 PSI. | | Total fluid used in treatment (bbls): | 370 | Max pressure during treatment (psi): | 2443 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 47 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 320 | Disposition method For flowback: | | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Date: | 3/16/2010 | | Treatment Summary: | ACID STIMULATION 3/16/2010 PUMPED 4000 GALLONS OF 20% HCI THROUGH END OF TUBING 6645' AT STARTING PRESSURE OF 900 PSI |
| | Tubing Size: | 2.875 in. | Tubing Setting Depth: | 6298 ft. | | Tubing Packer Depth: | 6179 ft. | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation WEBR. |
| | Perforation Data: | | Interval Top: | 6322 ft. | # Of Holes: | 16 | | Interval Bottom: | 6604 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 | N | |
| Low Producing | N | |
| Total Oil Produced (Barrels) | 0 |
| Total Gas Produced (MCF) | 192539 |
| GOR | |
| GOR Determination | MCFE |
| Average BOE per Day | 89.775 |
| Average MCFE per Day | 520.699 |
| Federal Financial Assurance | i | Y |
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