|
|
| |
|
|
|
|
Wellbore #00 Wellbore Classification: ERIW Status: IJ - 11/14/2024 Measured TD: 6650 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: ERIW IJ - 11/14/2024 | | Wellbore Permit | | | Permit #: | 100001 | Expiration Date: | 5/11/1980 | | Proposed Depth/Form: | | | Surface Mineral Owner Same: | Not available | | Mineral Owner: | FEDERAL | Surface Owner: | Not available | | Unit: | | Unit Number: | D-032703 | | Formation And Spacing: | Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit: |
| | |
| Wellbore Completed | | Completion Date: | 6/1/1980 | | Spud Date: | 6/22/1946 | Spud Date Is: | ACTUAL | | Measured TD: | 6650 ft. | Measured PB depth: | 6647 ft. | | True Vertical TD: | | True Vertical PB depth: | | | Log Types: | | | Casing: | String Type: SURF, Hole Size: 16 in., Size: 10.75 in., Top: 0 ft., Depth: 1017 ft., Weight: 40.5 , Citings Type: ACTUAL | | Cement: | Sacks: 650, Top: 0 ft., Bottom: 1017 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 10.75 in., Size: 7 in., Top: 0 ft., Depth: 6262 ft., Weight: 23 , Citings Type: ACTUAL | | Cement: | Sacks: 1250, Top: 0 ft., Bottom: 6262 ft., Determination Method: CALC | | Casing: | String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 6114 ft., Weight: 17 , Citings Type: ACTUAL | | Cement: | Sacks: 200, Top: 0 ft., Bottom: 6114 ft., Determination Method: VISU | | Casing: | String Type: 1ST LINER, Hole Size: , Size: 5 in., Top: 6114 ft., Depth: 6647 ft., Weight: 18 , Citings Type: ACTUAL | | Cement: | Sacks: 200, Top: 6114 ft., Bottom: 6647 ft., Determination Method: | | Casing: | String Type: TAPER, Hole Size: 7 in., Size: 5 in., Top: 6114 ft., Depth: 6647 ft., Weight: 18 , Citings Type: ACTUAL | | Cement: | Sacks: 200, Top: 6114 ft., Bottom: 6647 ft., Determination Method: CALC | | Formation | Interval Top | Log Bottom | Cored | DSTs | | NIOBRARA | 2340 ft. | 3286 ft. | N | N | | FRONTIER | 3286 ft. | 3558 ft. | N | N | | MOWRY | 3558 ft. | 3645 ft. | N | N | | DAKOTA | 3645 ft. | 3729 ft. | N | N | | MORRISON | 3729 ft. | 4440 ft. | N | N | | CURTIS | 4440 ft. | 4540 ft. | N | N | | ENTRADA | 4540 ft. | 4687 ft. | N | N | | CARMEL | 4687 ft. | 4740 ft. | N | N | | NAVAJO | 4740 ft. | 5355 ft. | N | N | | CHINLE | 5355 ft. | 5484 ft. | N | N | | SHINARUMP | 5484 ft. | 5575 ft. | N | N | | MOENKOPI | 5575 ft. | 6258 ft. | N | N | | WEBER | 6258 ft. | 6650 ft. | N | N |
Formation WEBR Formation Classification: ERIW Status: IJ - 11/14/2024 Interval Top: 6280 ft. Interval Bottom: 6604 ft.| Completed Information for Formation WEBER | | 1st Production Date: | 6/15/1972 | Choke Size: | | | Formation Name: | WEBER | Commingled: | No | | Production Method: | | | Open Hole Completion: | |
| | Formation Treatment | | Treatment Type: | | | Treatment Date: | 4/29/2025 | Treatment End Date: | N/A | | Treatment Summary: | Well work to to squeeze casing leaks, decision made to run 5.5" tie back liner from 6114 to surface. Return to injection pending an approved form 21.
Correction to bottom perf from previous form 5A.
Converted to Injection 06-15-1972 | | 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: | 11/13/2024 | Treatment End Date: | 11/13/2024 | | Treatment Summary: | PUMPED 2000 GALLONS (47.6 BBLS ) 15% HCL W/SOLVENT AND 35 FRESH WATER
Converted to injection 06-15-1972 | | Total fluid used in treatment (bbls): | 82 | Max pressure during treatment (psi): | 2262 | | 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): | 0 | 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: | 9/21/2019 | Treatment End Date: | 9/21/2019 | | Treatment Summary: | PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 2.8 BBLLS 6% CITRIC ACID, 40 BBLS WATER | | Total fluid used in treatment (bbls): | 90 | Max pressure during treatment (psi): | 2300 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | | | Total acid used in treatment (bbls): | 50 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | 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 Date: | 2/22/2008 | | Treatment Summary: | ACID STIMULATION 2/22/2008 PUMPED 21.5 BBLS 15% HCL THROUGH TUBING |
| | Tubing Size: | 2.875 in. | Tubing Setting Depth: | 6273 ft. | | Tubing Packer Depth: | 6085 ft. | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation WEBR. |
| | Perforation Data: | | Interval Top: | 6280 ft. | # Of Holes: | 249 | | Interval Bottom: | 6604 ft. | Hole Size: | 0.5 in. |
|
|
|
|
|
|
|
| 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 | Y |
|
|