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Wellbore #00 Wellbore Classification: ERIW Status: IJ - 5/18/2022 Measured TD: 6673 ft. Vertical TD: 6673 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: ERIW IJ - 5/18/2022 | | Wellbore Permit | | | Permit #: | 011238 | Expiration Date: | 6/26/2002 | | Proposed Depth/Form: | | | Surface Mineral Owner Same: | Yes | | Mineral Owner: | FEDERAL | Surface Owner: | FEDERAL | | Unit: | | Unit Number: | | | Formation And Spacing: | Code: WEBR , Formation: WEBER , Order: 2-38 , Unit Acreage: , Drill Unit: | | Casing: | String Type: SURF, Hole Size: , Size: 13.375 in., Top: , Depth: 373 ft., Weight: 40 , Citings Type: PLANNED | | Cement: | Sacks: 270, Top: 0 ft., Bottom: 373 ft. | | Casing: | String Type: 1ST, Hole Size: , Size: 7 in., Top: , Depth: 3810 ft., Weight: 23 , Citings Type: PLANNED | | Cement: | Sacks: , Top: 0 ft., Bottom: 3810 ft. |
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| Wellbore Completed | | Completion Date: | 4/5/2002 | | Spud Date: | 3/5/2002 | Spud Date Is: | ACTUAL | | Measured TD: | 6673 ft. | Measured PB depth: | | | True Vertical TD: | 6673 ft. | True Vertical PB depth: | | | Log Types: | NO NEW LOGS | | Casing: | String Type: SURF, Hole Size: , Size: 13.375 in., Top: 0 ft., Depth: 373 ft., Weight: 40 , Citings Type: ACTUAL | | Cement: | Sacks: 270, Top: , Bottom: , Determination Method: | | Casing: | String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6538 ft., Weight: , Citings Type: HISTORICAL | | Cement: | Sacks: 0, Top: 0 ft., Bottom: , Determination Method: | | Casing: | String Type: 2ND, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 5567 ft., Weight: 23 , Citings Type: ACTUAL | | Cement: | Sacks: , Top: , Bottom: , Determination Method: | | Casing: | String Type: 3RD, Hole Size: , Size: 7 in., Top: 5567 ft., Depth: 6539 ft., Weight: 20 , Citings Type: ACTUAL | | Cement: | Sacks: 900, Top: , Bottom: , Determination Method: | | Casing: | String Type: 1ST LINER, Hole Size: , Size: 5.5 in., Top: 0 ft., Depth: 6448 ft., Weight: 17 , Citings Type: ACTUAL | | Cement: | Sacks: 270, Top: , Bottom: , Determination Method: | | Formation | Interval Top | Log Bottom | Cored | DSTs | | NIOBRARA | 2620 ft. | 2800 ft. | N | N | | FRONTIER | 3572 ft. | | N | N | | MOWRY | 3825 ft. | | N | N | | DAKOTA | 3904 ft. | | N | N | | MORRISON | 4000 ft. | | N | N | | CURTIS | 4718 ft. | | N | N | | ENTRADA | 4820 ft. | | N | N | | CARMEL | 4962 ft. | | N | N | | NAVAJO | 5019 ft. | | N | N | | CHINLE | 5655 ft. | | N | N | | SHINARUMP | 5752 ft. | | N | N | | MOENKOPI | 5855 ft. | 6075 ft. | N | N | | WEBER | 6535 ft. | | N | N |
Formation WEBR Formation Classification: ERIW Status: IJ - 5/18/2022 Interval Top: 6448 ft. Interval Bottom: 6539 ft.| Completed Information for Formation WEBER | | 1st Production Date: | 5/25/1947 | Choke Size: | | | Formation Name: | WEBER | Commingled: | No | | Production Method: | | | Open Hole Completion: | Yes |
| | Formation Treatment | | Treatment Type: | ACID JOB | | Treatment Date: | 5/16/2022 | Treatment End Date: | 5/16/2022 | | Treatment Summary: | PUMPED 4000 GALLONS (95 BBLS) 15% HCL WITH SOLVENT AND 35 BBLS FRESH WATER | | Total fluid used in treatment (bbls): | 130 | 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): | 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: | 4/4/2020 | Treatment End Date: | 4/4/2020 | | Treatment Summary: | PUMPED 4000 GALLONS (95 BBLS) 15% HCL WITH SOLVENT AND 38 BBLS FRESH WATER | | Total fluid used in treatment (bbls): | 133 | 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): | 95 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 38 | 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: | 5/15/2014 | Treatment End Date: | 5/15/2014 | | Treatment Summary: | ACID STIMULATION | | 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): | 95 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 50 | 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: | 7/6/2012 | Treatment End Date: | 7/6/2012 | | Treatment Summary: | ACID STIMULATION 7/6/2012 PUMPED 4000 GALLONS 15% HCL AT 3.7 BPM @ 1400 PSI | | 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): | 95 | Min frac gradient (psi/ft): | | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 50 | Disposition method For flowback: | | | Total proppant used (lbs): | | Green completions techniques utilized: | -- | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Date: | 7/29/2010 | | Treatment Summary: | ACID STIMULATION 7/29/2010 PUMPED 4000GALLONS OF 20% HCI THROUGH TUBING AT 6444.2 AT 2.5 BPM@660PSI.' | | Formation Treatment | | Treatment Date: | 2/8/2008 | | Treatment Summary: | ACIDIZE FORMATION WITH 4015 GALLONS HEATED 15% HCL, EOT @ 6360 |
| | Tubing Size: | 2.875 in. | Tubing Setting Depth: | 6444 ft. | | Tubing Packer Depth: | 6331 ft. | Tubing Multiple Packer: | | | Open Hole Top: | 6448 ft. | Open Hole Bottom: | 6539 ft. | | No Initial Test Data was found for formation WEBR. |
| | Perforation Data: | | Interval Top: | 6448 ft. | # Of Holes: | | | Interval Bottom: | 6539 ft. | Hole Size: | |
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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) | 189298 |
| GOR | |
| GOR Determination | MCFE |
| Average BOE per Day | 89.858 |
| Average MCFE per Day | 521.185 |
| Federal Financial Assurance | i | Y |
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