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Wellbore #00 Wellbore Classification: OW Status: PR - 5/1/2017 Measured TD: 8113 ft. Vertical TD: 7397 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: OW PR - 5/1/2017 | | Wellbore Permit | DIRECTIONAL | | Permit #: | | Expiration Date: | 12/20/2012 | | Proposed Top PZ Location: | Sec:17 Twp: 4N 66W | Footage: 2069 FNL 704 FEL | | Bottom Hole Location: | Sec:17 Twp: 4N 66W | Footage: 2018 FNL 613 FEL | | Proposed Depth/Form: | 9685 ft. | | Surface Mineral Owner Same: | No | | Mineral Owner: | FEE | Surface Owner: | FEE | | Unit: | | Unit Number: | | | Formation And Spacing: | Code: JSND , Formation: J SAND , Order: 232-23 , Unit Acreage: 320, Drill Unit: N/2 | | Formation And Spacing: | Code: NB-CD , Formation: NIOBRARA-CODELL , Order: 407-87 , Unit Acreage: 80, Drill Unit: S/2NE/4 | | Casing: | String Type: SURF, Hole Size: 12.25 in., Size: 8.625 in., Top: , Depth: 650 ft., Weight: 24# , Citings Type: PLANNED | | Cement: | Sacks: 500, Top: 0 ft., Bottom: 650 ft. | | Casing: | String Type: 1ST, Hole Size: 8.625 in., Size: 4.5 in., Top: , Depth: 9685 ft., Weight: 11.5# , Citings Type: PLANNED | | Cement: | Sacks: 1200, Top: , Bottom: 9685 ft. |
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| Wellbore Completed | | Completion Date: | 8/2/2012 | | Spud Date: | 7/27/2012 | Spud Date Is: | ACTUAL | | Measured TD: | 8113 ft. | Measured PB depth: | 8078 ft. | | True Vertical TD: | 7397 ft. | True Vertical PB depth: | 7362 ft. | | Top PZ Location: | Sec:17 Twp: 4N 66W | Footage: 2069 FNL 704 FEL | | Bottom Hole Location: | Sec:17 Twp: 4N 66W | Footage: 2018 N 613 E | | Log Types: | Triple Combo
CBL | | Casing: | String Type: SURF, Hole Size: 12.25 in., Size: 8.625 in., Top: 0 ft., Depth: 728 ft., Weight: 24 , Citings Type: ACTUAL | | Cement: | Sacks: 560, Top: 0 ft., Bottom: 728 ft., Determination Method: VISU | | Casing: | String Type: 1ST, Hole Size: 7.875 in., Size: 4.5 in., Top: 0 ft., Depth: 8113 ft., Weight: 11.6 , Citings Type: ACTUAL | | Cement: | Sacks: 875, Top: 535 ft., Bottom: 8113 ft., Determination Method: CALC | | Formation | Interval Top | Log Bottom | Cored | DSTs | | PARKMAN | 3980 ft. | | | | | SUSSEX | 4726 ft. | | | | | SHANNON | 5208 ft. | | | | | NIOBRARA | 7686 ft. | | | | | FORT HAYS | 7926 ft. | | | | | CODELL | 7950 ft. | | | |
Formation CODL Formation Classification: OW Status: CM - 11/5/2012 Interval Top: 7950 ft. Interval Bottom: 7965 ft.| Completed Information for Formation CODELL | | 1st Production Date: | 9/5/2012 | Choke Size: | | | Formation Name: | CODELL | Commingled: | Yes | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | FRACTURE STIMULATION | | Treatment Date: | 8/23/2012 | Treatment End Date: | 8/23/2012 | | Treatment Summary: | MIRU Halliburton open well 33 psi start active pad formation break
at 3516 psi 3.0 bpm FR water pad at 3685 psi at 10.3 bpm begin ISIP
Analysis at 5005 psi 23.6 bpm ISIP 3437 psi 1min 3039 psi 4 min 2481 psi
956 psi leakoff begin FR water 0.25 ppg 30/50 at4967 psi at 41.4 bpm
0.25 at top of perfs at 5006 psi at41.4 bpm begin FR water 0.75 ppg 30/50
at 4944 psi at 41.4 bpm 0.75 at top of perfs at 4907 psi at 41.3 bpm
press increase cut sand sweep well begin FR water 1.25 ppg 30/50 at
5260 psi at 36.0 bpm 1.25 ppg at top of perfs at 4981 psi at 36 bpm
cut sand for sweep at 5355 psi 35.9 bpm proppant re-entering formation
after well sweep at 5409 psi at 44.9 bpm cut saqnd for well sweep at
5711 psi at 44.7 bpm proppant re- entering formation after sweep
at 5891 psi at 48.5 bpm horse power kick out for high press at 6300 psi
screen out suspend job tried to flow well bore capacity would not
shut well in.
| | Total fluid used in treatment (bbls): | 3966 | Max pressure during treatment (psi): | 6992 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | 1 | | Total acid used in treatment (bbls): | 24 | Min frac gradient (psi/ft): | 0.00 | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 3890 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | 86727 | 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: | 7950 ft. | # Of Holes: | 45 | | Interval Bottom: | 7965 ft. | Hole Size: | 0.4285714 in. |
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Formation NB-CD Formation Classification: OW Status: PR - 5/1/2017 Interval Top: 7694 ft. Interval Bottom: 7965 ft.| Completed Information for Formation NIOBRARA-CODELL | | 1st Production Date: | 9/5/2012 | Choke Size: | | | Formation Name: | NIOBRARA-CODELL | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Tubing Size: | | Tubing Setting Depth: | | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | Initial Test Data: | | Test Date: | 9/5/2012 | Test Method: | FLOWING | | Hours Tested: | 24 | Gas Type: | SHALE | | Gas Disposal: | SOLD | |
| Test Type | Measure |
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| BBLS_OIL | 16 | | BTU_GAS | 1395 | | CALC_BBLS_OIL | 16 | | CALC_GOR | 13125 | | CALC_MCF_GAS | 210 | | CASING_PRESS | 1325 | | GRAVITY_OIL | 59 | | MCF_GAS | 210 |
| | Perforation Data: | | Interval Top: | 7694 ft. | # Of Holes: | 117 | | Interval Bottom: | 7965 ft. | Hole Size: | 0.4285714 in. |
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Formation NBRR Formation Classification: OW Status: CM - 11/5/2012 Interval Top: 7694 ft. Interval Bottom: 7838 ft.| Completed Information for Formation NIOBRARA | | 1st Production Date: | 9/5/2012 | Choke Size: | | | Formation Name: | NIOBRARA | Commingled: | Yes | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | FRACTURE STIMULATION | | Treatment Date: | 8/29/2012 | Treatment End Date: | 8/29/2012 | | Treatment Summary: | MIRU Halliburton call for Max press 7000 psi kickouts 7000 psi
Open well 1630 psi break formation 4399 psi pump 10 bbl pad
24 bbls 15 % HCl 60 bbl active pad 60 bbl FR pad isip 3766 psi 1 min 3686 psi
4 min 3627 psi leakoff 139 psi resume FR water at 5651 psi at 60.4 bpm
begin 1.0 ppg 30/50 at 5744 psi at 58.0 bpm 1.0 ppg at perfs at 5528 psi
at 56.3 bpm begin 2.0 ppg 30/50 at 5685 psi at 57.9 bpm 2.0 ppg at perfs
at 5694 psi at 55.4 bpm begin 3.0 ppg 30/50 at 5213 psi at 51.7 bpm
3.0 ppg at perfs at 5202 psi at 51.7 bpm begin 4.0 ppg 30/50 at 4873 psi
at 51.5 bpm 4.0 ppg at perfs at 4827 psi at 51.3 bpm begin 4.0 ppg
CRC at 4739 psi at 50.7 bpm flush 126 bbl FR water ISIP 3743 psi 5 min
3355 psi 10 min 3315 psi avg press 5391 psi rate 51.5 bpm max press
5900 psi rate 60.6 bpm pumped 242,900 # 30/50 ottawa 8000 # crc 20/40.
LOAD TO RECOVER 4,349.7 BBLS
| | Total fluid used in treatment (bbls): | 4214 | Max pressure during treatment (psi): | 5900 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | | | Type Of gas: | | Number Of staged intervals: | 1 | | Total acid used in treatment (bbls): | 24 | Min frac gradient (psi/ft): | 3766.00 | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | | | Fresh water used in treatment (bbls): | 1577 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | 251720 | 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 NBRR. |
| | Perforation Data: | | Interval Top: | 7694 ft. | # Of Holes: | 72 | | Interval Bottom: | 7838 ft. | Hole Size: | 0.4285714 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) | 106 |
| Total Gas Produced (MCF) | 3734 |
| GOR | 35226 |
| GOR Determination | MCFE |
| Average BOE per Day | 2.047 |
| Average MCFE per Day | 11.872 |
| Federal Financial Assurance | i | |
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