Wellbore #00 Wellbore Classification: GW Status: PR - 4/26/2019 Measured TD: 14495 ft. Vertical TD: 7186 ft.| Wellbore Data for Original Wellbore | Wellbore Classification: GW PR - 4/26/2019 | | Wellbore Permit | HORIZONTAL | | Permit #: | | Expiration Date: | 4/4/2014 | | Proposed Top PZ Location: | Sec:9 Twp: 2N 66W | Footage: 1982 FNL 2461 FEL | | Bottom Hole Location: | Sec:4 Twp: 2N 66W | Footage: 615 FNL 2446 FEL | | Proposed Depth/Form: | 14464 ft. | | Surface Mineral Owner Same: | Yes | | Mineral Owner: | FEE | Surface Owner: | FEE | | Unit: | | Unit Number: | | | Formation And Spacing: | Code: NBRR , Formation: NIOBRARA , Order: 407 , Unit Acreage: 480, Drill Unit: GWA | | Casing: | String Type: CONDUCTOR, Hole Size: 22 in., Size: 16 in., Top: 0 ft., Depth: 80 ft., Weight: 30 , Citings Type: PLANNED | | Cement: | Sacks: 80, Top: 0 ft., Bottom: 80 ft. | | Casing: | String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 800 ft., Weight: 40 , Citings Type: PLANNED | | Cement: | Sacks: 198, Top: 0 ft., Bottom: 800 ft. | | Casing: | String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 7589 ft., Weight: 26 , Citings Type: PLANNED | | Cement: | Sacks: 928, Top: 500 ft., Bottom: 7589 ft. | | Casing: | String Type: 2ND, Hole Size: 6.125 in., Size: 4.5 in., Top: 0 ft., Depth: 14482 ft., Weight: , Citings Type: PLANNED | | Cement: | Sacks: , Top: , Bottom: | | Casing: | String Type: 1ST LINER, Hole Size: 3.92 in., Size: 3.74 in., Top: 7320 ft., Depth: 13750 ft., Weight: 8.8 , Citings Type: PLANNED | | Cement: | Sacks: , Top: , Bottom: |
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| Wellbore Completed | | Completion Date: | 5/6/2012 | | Spud Date: | 4/10/2012 | Spud Date Is: | ACTUAL | | Measured TD: | 14495 ft. | Measured PB depth: | 14316 ft. | | True Vertical TD: | 7186 ft. | True Vertical PB depth: | 7156 ft. | | Top PZ Location: | Sec:9 Twp: 2N 66W | Footage: 1982 FNL 2461 FEL | | Bottom Hole Location: | Sec:4 Twp: 2N 66W | Footage: 615 N 2446 E | | Log Types: | Isolation Scanner Cement Evaluation Log/ GeoLogPlot | | Casing: | String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 972 ft., Weight: , Citings Type: ACTUAL | | Cement: | Sacks: 285, Top: 0 ft., Bottom: 985 ft., Determination Method: CALC | | Casing: | String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 7637 ft., Weight: , Citings Type: ACTUAL | | Cement: | Sacks: 645, Top: 2900 ft., Bottom: 7655 ft., Determination Method: CBL | | Casing: | String Type: 2ND, Hole Size: 6.125 in., Size: 4.5 in., Top: 0 ft., Depth: 14482 ft., Weight: , Citings Type: ACTUAL | | Cement: | Sacks: 500, Top: 5782 ft., Bottom: 14495 ft., Determination Method: CALC | | Formation | Interval Top | Log Bottom | Cored | DSTs | | SUSSEX | 4410 ft. | | | | | NIOBRARA | 7160 ft. | | | |
Formation NBRR Formation Classification: OW Status: PR - 4/26/2019 Interval Top: 7654 ft. Interval Bottom: 14315 ft.| Completed Information for Formation NIOBRARA | | 1st Production Date: | 8/14/2012 | Choke Size: | | | Formation Name: | NIOBRARA | Commingled: | No | | Production Method: | | | Open Hole Completion: | No |
| | Formation Treatment | | Treatment Type: | FRACTURE STIMULATION | | Treatment Date: | 10/21/2018 | Treatment End Date: | 10/22/2018 | | Treatment Summary: | No additional stages perf'ed. Treated with 62,828 bbl fresh water, 76 bbl HCl, 61 bbl additives (FRP-4CS, ACI-97 and ASF-67) with 1,594,285 proppant. | | Total fluid used in treatment (bbls): | 62965 | Max pressure during treatment (psi): | 9127 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | 8.34 | | Type Of gas: | | Number Of staged intervals: | 28 | | Total acid used in treatment (bbls): | 76 | Min frac gradient (psi/ft): | 0.89 | | Recycled water used in treatment (bbls): | | Total flowback volume recovered (bbls): | 617 | | Fresh water used in treatment (bbls): | 62889 | Disposition method For flowback: | DISPOSAL | | Total proppant used (lbs): | 1594285 | Green completions techniques utilized: | Yes | | Reason green techniques Not utilized: | | Formation Treatment | | Treatment Type: | FRACTURE STIMULATION | | Treatment Date: | 7/10/2012 | Treatment End Date: | 8/21/2012 | | Treatment Summary: | FRAC STAGE 1. with 1,392 bbls Hybrid fluid system placing 500 lbs proppant. Frac stage 2. Pumped 1531 bbls. slick water and 445 bbls. X-link gel with 17,376# 40/70 sand, sand, total 17,376#). Set frac plug #1 @ 13,984'. Frac stage 3. Pumped 1,487 bbls. slick water and 2,761bbls. X-link gel with 18,215# 40/70 sand, 221,14# 30/50 sand, and 24,224# 20/40 sand,total 263,586#).Set CFP 2 at 13,749’. Frac stage 4. Pumped 1,472 bbls. slick water and 2,746 bbls. X-link gel with 17,501# 40/70 sand, 222,047# 30/50 sand, and 12,873# 20/40 sand, total 252,420#).5# 40/70 sand. Set frac plug #3 @ 13,749'.Set CFP 4 at 13,517’. Frac stage 5. Pumped 1,455 bbls. slick water and 2,750 bbls. X-link gel with 18,515# 40/70 sand, 222,230# 30/50 sand, and 20,104# 20/40 sand, total 260849#). Set CFP 5 at 13,285’. Frac stage 6. Pumped 1,432 bbls. slick water and 2,720 bbls. X-link gel with 18,070# 40/70 sand, 219,000# 30/50 sand, and 12,841# 20/40 sand, total 249,910#. Set CFP 6 at 13,052’. Frac stage 7. Pumped 1,420 bbls. slick water and 2,732 bbls. X-link gel with 17,861# 40/70 sand, 220,188# 30/50 sand, and 12,840# 20/40 sand, total 250,889#. Set CFP 7 at 12,821’. Frac stage 8. Pumped 1,386 bbls. slick water and 2,749 bbls. X-link gel with 17,296# 40/70 sand, 221,159# 30/50 sand, and 12,840# 20/40 sand, total 251,295#. Frac stage 9. Pumped 1,495 bbls. slick water and 2,706 bbls. X-link gel with 17,387# 40/70 sand, 219,703# 30/50 sand, and 12,840# 20/40 sand, total 249,930#. Set CFP 8 at 12,821’. Set CFP 9 at 12,357’. Frac stage 10. Pumped 1,402 bbls. slick water and 2,742 bbls. X-link gel with 17,771# 40/70 sand, 223,866# 30/50 sand, and 12,846# 20/40 sand, total 254,482#. Set CFP 10 at 12,124’. Frac stage 11. Pumped 1,404 bbls. slick water and 2,690 bbls. X-link gel with 17,742# 40/70 sand, 219,878# 30/50 sand, and 12,847# 20/40 sand, total 250,467#. Set CFP 11 at 11,888’. Frac stage 12. Pumped 1,392 bbls. slick water and 2,745 bbls. X-link gel with 17,426# 40/70 sand, 222563# 30/50 sand, and 12,850# 20/40 sand, total 252838#. Set CFP 12 at 11,654’. Frac stage 13. Pumped 1,382 bbls. slick water and 2,700 bbls. X-link gel with 17,737# 40/70 sand, 219,287# 30/50 sand, and 12,879# 20/40 sand, total 249,903#. Set CFP 13 at 11,418’. Frac stage 14. Pumped 1,376 bbls. slick water and 2,730 bbls. X-link gel with 17,472# 40/70 sand, 221,313# 30/50 sand, and 12,909# 20/40 sand, total 251,694#. Set CFP 14 at 11,183’. Frac stage 15. Pumped 1,372 bbls. slick water and 2,752 bbls. X-link gel with 17,480# 40/70 sand, 222,587# 30/50 sand, and 12,838# 20/40 sand, total 252,904#. Set CFP 15 at 10,946’. Frac stage 16. Pumped 1,360 bbls. slick water and 2,733 bbls. X-link gel with 17,273# 40/70 sand, 221,618# 30/50 sand, and 12,840# 20/40 sand, total 251,7314#. Set CFP 16 at 10,701’. Frac stage 17. Pumped 1367 bbls. slick water and 2,734 bbls. X-link gel with 17,492# 40/70 sand, 222003# 30/50 sand, and 12,888# 20/40 sand, total 252383#. Set CFP 17 at 10,451’. Frac stage 18. Pumped 1149 bbls. slick water and 2,756 bbls. X-link gel with 17,310# 40/70 sand, 221,654# 30/50 sand, and 12,794# 20/40 sand, total 251,758#. Set frac plug #18 @ 10,201', Frac stage 19. Pumped 1348 bbls. slick water and 2,709 bbls. X-link gel with 17,292# 40/70 sand, 219,923# 30/50 sand, and 12840# 20/40 sand, total 250055#. Set CFP 19 at 9,921’. Frac stage 20. Pumped 1,353 bbls. slick water and 2,700 bbls. X-link gel with 17,302# 40/70 sand, 220,143# 30/50 sand, and 12,840# 20/40 sand, total 250,285#. Set CFP 20 at 9,713’. Frac stage 21. Pumped 1,337 bbls. slick water and 2,721 bbls. X-link gel with 17,334# 40/70 sand, 218,511# 30/50 sand, and 12,804# 20/40 sand, total 248,649#. Set CFP 21 at 9,65’. Frac stage 22. Pumped 1341 bbls. slick water and 2716 bbls. X-link gel with 17,384# 40/70 sand, 220153# 30/50 sand, and 12,840# 20/40 sand, total 250378#. Set CFP 22 at 9,215’. Frac stage 23. Pumped 1,334 bbls. slick water and 2,710 bbls. X-link gel with 17,343# 40/70 sand, 220,364# 30/50 sand, and 12,840# 20/40 sand, total 250547#. Set CFP 23 at 8,966’. Frac stage 24. Pumped 1,789 bbls. slick water and 0 bbls. X-link gel with 6,612# 40/70 sand, total 6,612#. Set CFP 24 at 8,716’. Frac stage 25. Pumped 776 bbls. slick water and 259 bbls. linear gel with 4,526# 40/70 sand. Set frac plug #25 @ 8,466', Frac stage 26. Pumped 1,932 bbls. slick water and 3,260 bbls. X-link gel with 27,071# 40/70 sand, 263,744# 30/50 sand, and 15,393# 20/40 sand, total 306,209#. Set frac plug #26 @ 8,179', Frac stage 27. Pumped 1,551 bbls. slick water and 3,479 bbls. X-link gel with 20,754# 40/70 sand, 256,669# 30/50 sand, and 20,136# 20/40 sand, total 297,559#. Set frac plug #27 @ 7,886', Frac stage 28. Pumped 1,051 bbls. slick water and 3,329 bbls. X-link gel with 22,969# 40/70 sand, 264,045# 30/50 sand, and 22,580# 20/40 sand, total 309,594#. Set CBP @ 6420'. Drilled kill plug and drill plugs.
| | Total fluid used in treatment (bbls): | 115269 | Max pressure during treatment (psi): | 8460 | | Total gas used in treatment (mcf): | | Fluid density (lbs/gal): | 8.34 | | Type Of gas: | | Number Of staged intervals: | 28 | | Total acid used in treatment (bbls): | | Min frac gradient (psi/ft): | 0.92 | | Recycled water used in treatment (bbls): | 115269 | Total flowback volume recovered (bbls): | 8627 | | Fresh water used in treatment (bbls): | | Disposition method For flowback: | RECYCLE | | Total proppant used (lbs): | | Green completions techniques utilized: | Yes | | Reason green techniques Not utilized: |
| | Tubing Size: | 2.375 in. | Tubing Setting Depth: | 7329 ft. | | Tubing Packer Depth: | | Tubing Multiple Packer: | | | Open Hole Top: | | Open Hole Bottom: | | | Initial Test Data: | | Test Date: | 12/4/2018 | Test Method: | Flowing | | Hours Tested: | 24 | Gas Type: | WET | | Gas Disposal: | SOLD | |
| Test Type | Measure |
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| BBLS_H2O | 256 | | BBLS_OIL | 396 | | BTU_GAS | 1319 | | CALC_BBLS_H2O | 256 | | CALC_BBLS_OIL | 396 | | CALC_GOR | 3194 | | CALC_MCF_GAS | 1265 | | CASING_PRESS | 1950 | | GRAVITY_OIL | 49 | | MCF_GAS | 1265 | | TUBING_PRESS | 1150 |
| | Perforation Data: | | Interval Top: | 7654 ft. | # Of Holes: | 1440 | | Interval Bottom: | 14315 ft. | Hole Size: | 0.38 in. |
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