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Wellbore #00 Wellbore Classification: OW Status: PR - 4/29/2018 Measured TD: 18403 ft. Vertical TD: 7192 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: OW PR - 4/29/2018 | | Wellbore Permit | HORIZONTAL | | Permit #: | | Expiration Date: | 5/13/2019 | | Proposed Top PZ Location: | Sec:33 Twp: 3N 65W | Footage: 229 FNL 929 FEL | | Bottom Hole Location: | Sec:9 Twp: 2N 65W | Footage: 359 FNL 909 FEL | | Proposed Depth/Form: | 18294 ft. | | Surface Mineral Owner Same: | No | | Mineral Owner: | FEE | Surface Owner: | FEE | | Unit: | | Unit Number: | | | Formation And Spacing: | Code: CARL , Formation: CARLILE , Order: , Unit Acreage: 800, Drill Unit: GWA | | Formation And Spacing: | Code: CODL , Formation: CODELL , Order: , Unit Acreage: 800, Drill Unit: GWA | | Formation And Spacing: | Code: FTHYS , Formation: FORT HAYS , Order: , Unit Acreage: 800, Drill Unit: GWA | | Formation And Spacing: | Code: NBRR , Formation: NIOBRARA , Order: , Unit Acreage: 800, Drill Unit: GWA | | Casing: | String Type: CONDUCTOR, Hole Size: 26 in., Size: 16 in., Top: 0 ft., Depth: 40 ft., Weight: 42.1 , Citings Type: PLANNED | | Cement: | Sacks: 30, Top: 0 ft., Bottom: 40 ft. | | Casing: | String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 1500 ft., Weight: 36 , Citings Type: PLANNED | | Cement: | Sacks: 590, Top: 0 ft., Bottom: 1500 ft. | | Casing: | String Type: 1ST, Hole Size: 7.875 in., Size: 5.5 in., Top: 0 ft., Depth: 18284 ft., Weight: 17 , Citings Type: PLANNED | | Cement: | Sacks: 2170, Top: , Bottom: 18284 ft. |
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| Wellbore Completed | | Completion Date: | 10/10/2017 | | Spud Date: | 7/25/2017 | Spud Date Is: | ACTUAL | | Measured TD: | 18403 ft. | Measured PB depth: | 18390 ft. | | True Vertical TD: | 7192 ft. | True Vertical PB depth: | 7192 ft. | | Top PZ Location: | Sec:33 Twp: 3N 65W | Footage: 229 FNL 929 FEL | | Bottom Hole Location: | Sec:9 Twp: 2N 65W | Footage: 359 FNL 909 FEL | | Log Types: | MWD, CBL, (CNL in 123-44792) | | Casing: | String Type: CONDUCTOR, Hole Size: 26 in., Size: 16 in., Top: 0 ft., Depth: 106 ft., Weight: 42 , Citings Type: ACTUAL | | Cement: | Sacks: 64, Top: 0 ft., Bottom: 106 ft., Determination Method: VISU | | Casing: | String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 1886 ft., Weight: 36 , Citings Type: ACTUAL | | Cement: | Sacks: 674, Top: 0 ft., Bottom: 1886 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 7.875 in., Size: 5.5 in., Top: 0 ft., Depth: 18391 ft., Weight: 20 , Citings Type: ACTUAL | | Cement: | Sacks: 1900, Top: 160 ft., Bottom: 18391 ft., Determination Method: CBL | | Formation | Interval Top | Log Bottom | Cored | DSTs | | SUSSEX | 4628 ft. | | | | | SHARON SPRINGS | 7030 ft. | | | | | NIOBRARA | 7120 ft. | | | | | FORT HAYS | 7668 ft. | | | | | CODELL | 7760 ft. | | | | | CARLILE | 9125 ft. | | | |
Formation NBRR Formation Classification: OW Status: CM - 3/24/2021 Interval Top: 13600 ft. Interval Bottom: 14019 ft.| Completed Information for Formation NIOBRARA | | 1st Production Date: | N/A | Choke Size: | | | Formation Name: | NIOBRARA | Commingled: | Yes | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | FRACTURE STIMULATION | | Treatment Date: | 3/25/2021 | Treatment End Date: | N/A | | Treatment Summary: | 13600-14019 | | 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: | FRACTURE STIMULATION | | Treatment Date: | 12/31/2017 | Treatment End Date: | 1/10/2018 | | Treatment Summary: | PERF AND FRAC FROM 7824-18330.
48 BBL 15% HCL ACID, 650 BBL 7.5% HCL ACID, 9,034 BBL PUMP DOWN, 179,665 BBL SLICKWATER, 189,397 TOTAL FLUID, 3,999,191# 40/70 OTTAWA/ST. PETERS, 3,999,191# TOTAL SAND. | | Total fluid used in treatment (bbls): | 189397 | Max pressure during treatment (psi): | 7843 | | Total gas used in treatment (mcf): | 0 | Fluid density (lbs/gal): | 8.30 | | Type Of gas: | | Number Of staged intervals: | 26 | | Total acid used in treatment (bbls): | 698 | Min frac gradient (psi/ft): | 0.84 | | Recycled water used in treatment (bbls): | 0 | Total flowback volume recovered (bbls): | 2936 | | Fresh water used in treatment (bbls): | 188699 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | 3999191 | Green completions techniques utilized: | Yes | | Reason green techniques Not utilized: |
| | Tubing Size: | | Tubing Setting Depth: | | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | Initial Test Data: | | Test Date: | N/A | Test Method: | | | Hours Tested: | | Gas Type: | | | Gas Disposal: | | |
| Test Type | Measure |
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| BBLS_H2O | 159 | | BBLS_OIL | 320 | | BTU_GAS | 1256 | | CALC_BBLS_H2O | 159 | | CALC_BBLS_OIL | 320 | | CALC_GOR | 2781 | | CALC_MCF_GAS | 890 | | CASING_PRESS | 2500 | | GRAVITY_OIL | 61 | | MCF_GAS | 890 | | TUBING_PRESS | 1800 |
| | Perforation Data: | | Interval Top: | 13600 ft. | # Of Holes: | 552 | | Interval Bottom: | 14019 ft. | Hole Size: | 0.44 in. |
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Formation FTHYS Formation Classification: OW Status: CM - 3/25/2021 Interval Top: 10740 ft. Interval Bottom: 14371 ft.| Completed Information for Formation FORT HAYS | | 1st Production Date: | N/A | Choke Size: | | | Formation Name: | FORT HAYS | Commingled: | Yes | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | FRACTURE STIMULATION | | Treatment Date: | 3/25/2021 | Treatment End Date: | N/A | | Treatment Summary: | 10740-11651, 12308-12897, 13378-13399, 14019-14371 | | 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: |
| | Tubing Size: | | Tubing Setting Depth: | | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation FTHYS. |
| | Perforation Data: | | Interval Top: | 10740 ft. | # Of Holes: | 552 | | Interval Bottom: | 14371 ft. | Hole Size: | 0.44 in. |
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Formation CARL Formation Classification: OW Status: CM - 3/25/2021 Interval Top: 9127 ft. Interval Bottom: 15511 ft.| Completed Information for Formation CARLILE | | 1st Production Date: | N/A | Choke Size: | | | Formation Name: | CARLILE | Commingled: | Yes | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | FRACTURE STIMULATION | | Treatment Date: | 3/25/2021 | Treatment End Date: | N/A | | Treatment Summary: | 9127-9296, 15287-15511 | | 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: |
| | Tubing Size: | | Tubing Setting Depth: | | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation CARL. |
| | Perforation Data: | | Interval Top: | 9127 ft. | # Of Holes: | 552 | | Interval Bottom: | 15511 ft. | Hole Size: | 0.44 in. |
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Formation CODL Formation Classification: OW Status: CM - 3/25/2021 Interval Top: 7824 ft. Interval Bottom: 18330 ft.| Completed Information for Formation CODELL | | 1st Production Date: | N/A | Choke Size: | | | Formation Name: | CODELL | Commingled: | Yes | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | FRACTURE STIMULATION | | Treatment Date: | 3/25/2021 | Treatment End Date: | N/A | | Treatment Summary: | 7824-9127, 9296-10740, 11651-12308, 12897-13378, 13399-13600, 14371-15287, 15511-18330 | | 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: |
| | Tubing Size: | | Tubing Setting Depth: | | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | No Initial Test Data was found for formation CODL. |
| | Perforation Data: | | Interval Top: | 7824 ft. | # Of Holes: | 552 | | Interval Bottom: | 18330 ft. | Hole Size: | 0.44 in. |
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Formation NFCC Formation Classification: OW Status: PR - 4/29/2018 Interval Top: 7824 ft. Interval Bottom: 18330 ft.| Completed Information for Formation NIOBRARA-FORT HAYS-CODELL-CARLILE | | 1st Production Date: | 3/29/2018 | Choke Size: | | | Formation Name: | NIOBRARA-FORT HAYS-CODELL-CARLILE | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | FRACTURE STIMULATION | | Treatment Date: | 12/31/2017 | Treatment End Date: | 1/10/2018 | | Treatment Summary: | PERF AND FRAC FROM 7824-18330.
48 BBL 15% HCL ACID, 650 BBL 7.5% HCL ACID, 9,034 BBL PUMP DOWN, 179,665 BBL SLICKWATER, 189,397 TOTAL FLUID,
3,999,191# 40/70 OTTAWA/ST. PETERS, 3,999,191# TOTAL SAND. | | Total fluid used in treatment (bbls): | 189397 | Max pressure during treatment (psi): | 7843 | | Total gas used in treatment (mcf): | 0 | Fluid density (lbs/gal): | 8.30 | | Type Of gas: | | Number Of staged intervals: | 26 | | Total acid used in treatment (bbls): | 698 | Min frac gradient (psi/ft): | 0.84 | | Recycled water used in treatment (bbls): | 0 | Total flowback volume recovered (bbls): | 2936 | | Fresh water used in treatment (bbls): | 188699 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | 3999191 | Green completions techniques utilized: | Yes | | Reason green techniques Not utilized: |
| | Tubing Size: | 2.375 in. | Tubing Setting Depth: | 7254 ft. | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | Initial Test Data: | | Test Date: | 4/29/2018 | Test Method: | Flowing | | Hours Tested: | 24 | Gas Type: | WET | | Gas Disposal: | SOLD | |
| Test Type | Measure |
|---|
| BBLS_H2O | 159 | | BBLS_OIL | 320 | | BTU_GAS | 1256 | | CALC_BBLS_H2O | 159 | | CALC_BBLS_OIL | 320 | | CALC_GOR | 2781 | | CALC_MCF_GAS | 890 | | CASING_PRESS | 2500 | | GRAVITY_OIL | 61 | | MCF_GAS | 890 | | TUBING_PRESS | 1800 |
| | Perforation Data: | | Interval Top: | 7824 ft. | # Of Holes: | 552 | | Interval Bottom: | 18330 ft. | Hole Size: | 0.44 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) | 8751 |
| Total Gas Produced (MCF) | 95029 |
| GOR | 10859 |
| GOR Determination | BOE |
| Average BOE per Day | 68.793 |
| Average MCFE per Day | 398.991 |
| Federal Financial Assurance | i | |
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