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Wellbore #00 Wellbore Classification: ERIW Status: IJ - 5/25/2022 Measured TD: 6631 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: ERIW IJ - 5/25/2022 | | Wellbore Permit | | | Permit #: | 10001 | Expiration Date: | 2/24/2000 | | Prop Depth/Form: | | | Surface Mineral Owner Same: | Not available | | Mineral Owner: | FEDERAL | Surface Owner: | Not available | | Unit: | | Unit Number: | D-051529 | | Formation And Spacing: | Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit: |
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| Wellbore Completed | | Completion Date: | 5/19/1946 | | Spud Date: | 3/1/1946 | Spud Date Is: | ACTUAL | | Measured TD: | 6631 ft. | Measured PB depth: | 6530 ft. | | True Vertical TD: | | True Vertical PB depth: | | | Log Types: | CBL | | Log Types: | | | Casing: | String Type: SURF, Hole Size: , Size: 13.375 in., Top: 0 ft., Depth: 352 ft., Weight: 48 , Citings Type: ACTUAL | | Cement: | Sacks: 300, Top: 0 ft., Bottom: 300 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6094 ft., Weight: 20,23 , Citings Type: ACTUAL | | Cement: | Sacks: 1600, Top: 2430 ft., Bottom: 6094 ft., Determination Method: CBL | | Casing: | String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 5997 ft., Weight: 17 , Citings Type: ACTUAL | | Cement: | Sacks: 285, Top: 2890 ft., Bottom: 5997 ft., Determination Method: CBL | | Casing: | String Type: 1ST LINER, Hole Size: 7 in., Size: 5 in., Top: 5997 ft., Depth: 6631 ft., Weight: 18 , Citings Type: ACTUAL | | Cement: | Sacks: 200, Top: 5997 ft., Bottom: 6631 ft., Determination Method: CALC | | Casing: | String Type: TAPER, Hole Size: 7 in., Size: 5 in., Top: 5997 ft., Depth: 6631 ft., Weight: 18 , Citings Type: ACTUAL | | Cement: | Sacks: 200, Top: 5997 ft., Bottom: 6631 ft., Determination Method: CALC | | Additional Cement: | String Type: 1ST , Top: 1446 ft., Depth: 1698 ft., Bottom: 2140 ft., Sacks: 200, Method: SQUEEZE | | Additional Cement: | String Type: 1ST , Top: , Depth: 1519 ft., Bottom: , Sacks: 200, Method: SQUEEZE | | Formation | Interval Top | Log Bottom | Cored | DSTs | | J-NIOBRARA | 2350 ft. | 2515 ft. | N | N | | FRONTIER | 3228 ft. | | N | N | | MOWRY | 3500 ft. | | N | N | | DAKOTA | 3592 ft. | | N | N | | MORRISON | 3670 ft. | | N | N | | CURTIS | 4354 ft. | | N | N | | ENTRADA | 4450 ft. | | N | N | | CARMEL | 4590 ft. | | N | N | | NAVAJO | 4650 ft. | | N | N | | SHINARUMP | 5380 ft. | | N | N | | MOENKOPI | 5450 ft. | 5660 ft. | N | N | | WEBER | 6094 ft. | | N | N |
Formation WEBR Formation Classification: ERIW Status: IJ - 5/25/2022 Interval Top: 6103 ft. Interval Bottom: 6576 ft.| Completed Information for Formation WEBER | | 1st Production Date: | 5/20/1946 | Choke Size: | | | Formation Name: | WEBER | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 5/18/2022 | Treatment End Date: | 5/18/2022 | | Treatment Summary: | PUMPED 2000 GALLONS (47.6 BBLS) WITH 15% HCL AND 6% CITRIC ACID AND 35 BBLS OF WATER.
CONVERTED TO INJECTION 2/21/1974
| | Total fluid used in treatment (bbls): | 82 | Max pressure during treatment (psi): | 2900 | | 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): | 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: | 7/8/2021 | Treatment End Date: | 7/8/2021 | | Treatment Summary: | PUMPED 2000 GALLONS (47.6 BBLS) WITH 15% HCL AND 6% CITRIC ACID AND 40 BBLS OF WATER.
CONVERTED TO INJECTION 2/21/1974 | | Total fluid used in treatment (bbls): | 87 | Max pressure during treatment (psi): | 2113 | | 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): | 40 | Disposition method For flowback: | | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Type: | | | Treatment Date: | 2/22/2019 | Treatment End Date: | N/A | | Treatment Summary: | WELLWORK TO RUN 5 1/2" CASING FROM SURFACE TO 5997' ANS CEMENT IN PLACE. A COGCC WITNESSED MIT IS SCHEDULED FOR 12/4/2018. THIS WELL WILL BE RETURNED TO ACTIVE INJECTION UPON APPROVAL OF ONLINE FORM 21.
THIS WELL WAS CONVERTED TO INJECTION 2/21/1974. | | 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: | 12/5/2018 | Treatment End Date: | 12/5/2018 | | Treatment Summary: | PUMPED 2000 GALLONS 15% HCL WITH 90 GALLONS SOLVENT, FLUSH WITH 182 BBLS WATER. FIRST INJECTION 2/21/1974. | | Total fluid used in treatment (bbls): | 229 | Max pressure during treatment (psi): | 1400 | | 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): | 182 | Disposition method For flowback: | | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Date: | 4/8/2009 | | Treatment Summary: | ACIDIZE FORMATION WITH 4000 GALLONS HEATED 20% HCL, AT END OF COILED TUBING @ 6499. |
| | Tubing Size: | 2.875 in. | Tubing Setting Depth: | 6013 ft. | | Tubing Packer Depth: | 5944 ft. | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation WEBR. |
| | Perforation Data: | | Interval Top: | 6103 ft. | # Of Holes: | 365 | | Interval Bottom: | 6576 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) | 177840 |
| GOR | |
| GOR Determination | MCFE |
| Average BOE per Day | 83.874 |
| Average MCFE per Day | 486.468 |
| Federal Financial Assurance | i | Y |
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