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Wellbore #00 Wellbore Classification: ERIW Status: IJ - 8/12/2022 Measured TD: 6422 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: ERIW IJ - 8/12/2022 | | Wellbore Permit | | | Permit #: | 10001 | Expiration Date: | 5/8/1970 | | Prop Depth/Form: | | | Surface Mineral Owner Same: | Not available | | Mineral Owner: | FEDERAL | Surface Owner: | Not available | | Unit: | | Unit Number: | D-032678 | | Formation And Spacing: | Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit: |
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| Wellbore Completed | | Completion Date: | 2/14/1970 | | Spud Date: | 1/18/1970 | Spud Date Is: | ACTUAL | | Measured TD: | 6422 ft. | Measured PB depth: | 6400 ft. | | True Vertical TD: | | True Vertical PB depth: | | | Log Types: | NO NEW LOGS | | Casing: | String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 755 ft., Weight: 40.5 , Citings Type: ACTUAL | | Cement: | Sacks: 525, Top: 0 ft., Bottom: 755 ft., Determination Method: VISU | | Casing: | String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 755 ft., Weight: 40.5 , Citings Type: HISTORICAL | | Cement: | Sacks: 525, Top: 0 ft., Bottom: 755 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 9 in., Size: 7 in., Top: 0 ft., Depth: 6422 ft., Weight: 23 , Citings Type: ACTUAL | | Cement: | Sacks: 850, Top: 4795 ft., Bottom: 6422 ft., Determination Method: CBL | | Casing: | String Type: 1ST, Hole Size: 9 in., Size: 7 in., Top: 0 ft., Depth: 6422 ft., Weight: 23 , Citings Type: HISTORICAL | | Cement: | Sacks: 850, Top: , Bottom: 6422 ft., Determination Method: | | Additional Cement: | String Type: 1ST , Top: 2371 ft., Depth: 2365 ft., Bottom: 2454 ft., Sacks: 100, Method: SQUEEZE | | Additional Cement: | String Type: 1ST , Top: 2411 ft., Depth: 2850 ft., Bottom: 2485 ft., Sacks: 50, Method: SQUEEZE | | Additional Cement: | String Type: 1ST , Top: 3700 ft., Depth: 3857 ft., Bottom: 3745 ft., Sacks: 50, Method: SQUEEZE | | Formation | Interval Top | Log Bottom | Cored | DSTs | | DAKOTA | 3215 ft. | | | | | MORRISON | 3293 ft. | | | | | CURTIS | 3900 ft. | | | | | ENTRADA | 4020 ft. | | | | | CARMEL | 4160 ft. | | | | | NAVAJO | 4220 ft. | | | | | CHINLE | 4790 ft. | | | | | SHINARUMP | 4932 ft. | | | | | WEBER | 5648 ft. | | N | N |
Formation WEBR Formation Classification: ERIW Status: IJ - 8/12/2022 Interval Top: 5660 ft. Interval Bottom: 6378 ft.| Completed Information for Formation WEBER | | 1st Production Date: | 3/24/1970 | Choke Size: | | | Formation Name: | WEBER | Commingled: | No | | Production Method: | | | Open Hole Completion: | |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 8/8/2022 | Treatment End Date: | 8/8/2022 | | Treatment Summary: | PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/MUTUAL SOLVENT AND 35 BBLS WATER
CONVERTED TO INJECTION 09/25/1975 | | Total fluid used in treatment (bbls): | 130 | 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): | 95 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 35 | 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: | 10/17/2013 | Treatment End Date: | 10/17/2013 | | Treatment Summary: | PUMPED 4000 GALLONS 15% HCL THRU 1 1/4" COILED TUBING @ 6368' | | Total fluid used in treatment (bbls): | 95 | 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): | | Disposition method For flowback: | | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Date: | 6/11/2010 | | Treatment Summary: | ACID STIMULATION 6-11-2010 PUMPED 4000 GALLONS OF 20% HCI THROUGH1 1 1/4" COILED TUBING AT 6364' AT STARTING PRESSURE 4200 PSI @ .9 BPM. | | Formation Treatment | | Treatment Date: | 11/14/2007 | | Treatment Summary: | ACIDIZE FORMATION WITH 4000 GALLONS 15% HCI, END OF 1 1/4" TUBING @ 6378' |
| | Tubing Size: | 2.875 in. | Tubing Setting Depth: | 5613 ft. | | Tubing Packer Depth: | 5547 ft. | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation WEBR. |
| | Perforation Data: | | Interval Top: | 5660 ft. | # Of Holes: | 81 | | Interval Bottom: | 6378 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) | 38648 |
| GOR | |
| GOR Determination | MCFE |
| Average BOE per Day | 17.959 |
| Average MCFE per Day | 104.185 |
| Federal Financial Assurance | i | Y |
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