Mid-Continent Energy Exchange - Amazon Web Servicesinfo.mceeauction.com.s3.amazonaws.com/...Arikaree_Creek_Pilot_O… · Arikaree Creek Pilot Overriding Royalty Interest in Lincoln

Mid-Continent Energy ExchangeO i l & G a s A s s e t A u c t i o n s

Lot 9 Data PacketArikaree Creek Pilot Overriding Royalty Interest in

Lincoln County, CO

In this Document: Lot Summary

Income and Expenses Production

Lot Summary

County/State: Lincoln County, CO

Legal Description: Sec 15-6S-54W

Acres: 1240

Asset Type: Overriding Royalty Interest

Decimal Interest: 0.00619242

$1,843.54Net Income (13 mo):

Lease Name: Arikaree Creek Pilot

Disclaimer: Bidders must conduct their own due diligence prior to bidding at the auction. Bidders shall rely upon their own evaluations of the properties and not upon any representation either oral or written provided here. This is a summary of information provided by the seller to Mid-Continent Energy Exchange.

Operator: D90 Energy, LLC

Snowbird 9-15 API: 05-073-06358 NE SE Sec 15-6S-54W 6 ARIKAREE CREEK

Blackcomb 3-14 API: 05-073-06602 NE NW Sec 1405S054W 6 ARIKAREE CREEK

Crested Butte 2-14 API: 05-073-06695 NW NE Sec 14-6S-54W 6 ARIKAREE CREEK

Blackcomb 5-14 API: 05-073-06601 SW NW Sec 14-6S-54W 6 ARIKAREE CREEK

Blackcomb 12-14 API: 05-073-06610 NW SW Sec 14-6S-54W 6 ARIKAREE CREEK (inj well)

Snowbird 16-15 API: 05-073-06561 SE SE Sec 15-6S-54W 6 ARIKAREE CREEK (inj well)

Income and Expenses

Summary

Production Months: 13

Net Income: $23,965.99

Net Income Per Month: $1,843.54

ARM ENERGY MANAGEMENT LLC% ExTex Division Order Services4865 Ward Road, Suite 200Wheat Ridge, CO 80033(303)463-8799

Check HistorySummarized by Distribution

For checks dated 01/01/2019 thru 12/31/2019

STEVEN A TEDESCO16482 E BERRY PLACECENTENNIAL, CO 80015

Owner Account: 10743A

Run Date Type & Pct Chk Date Volume Avg$ Gross Taxes Other W/H Net( 10062A) STEAMBOAT HANSEN 8-10: OIL12/2018 O 0.01559615 03/20/2019 130.77 43.03 5,627.01 429.42 0.00 0.00 5,197.59 01/2019 O 0.01559615 03/20/2019 102.03 45.39 4,631.25 353.43 0.00 0.00 4,277.82 01/2019 O 0.00467885 03/20/2019 30.61 45.39 1,389.38 106.03 0.00 0.00 1,283.35 02/2019 O 0.01559615 03/20/2019 85.79 49.25 4,225.24 322.45 0.00 0.00 3,902.79 02/2019 O 0.00467885 03/20/2019 25.74 49.25 1,267.57 96.73 0.00 0.00 1,170.84 03/2019 O 0.01559615 04/19/2019 93.71 52.50 4,919.87 375.46 0.00 0.00 4,544.41 03/2019 O 0.00467885 04/19/2019 28.11 52.50 1,475.96 112.64 0.00 0.00 1,363.32 04/2019 O 0.01559615 05/20/2019 89.65 58.23 5,220.64 398.41 0.00 0.00 4,822.23 04/2019 O 0.01559615 06/20/2019 89.65- 58.23 5,220.64- 398.41- 0.00 0.00 4,822.23-04/2019 O 0.01559615 06/20/2019 90.05 58.25 5,245.54 400.31 0.00 0.00 4,845.23 04/2019 O 0.00467885 05/20/2019 26.90 58.23 1,566.19 119.52 0.00 0.00 1,446.67 04/2019 O 0.00467885 06/20/2019 26.90- 58.23 1,566.19- 119.52- 0.00 0.00 1,446.67-04/2019 O 0.00467885 06/20/2019 27.02 58.25 1,573.66 120.09 0.00 0.00 1,453.57 05/2019 O 0.01559615 06/20/2019 82.19 54.22 4,456.88 340.12 0.00 0.00 4,116.76 05/2019 O 0.00467885 06/20/2019 24.66 54.22 1,337.07 102.04 0.00 0.00 1,235.03 06/2019 O 0.01559615 07/19/2019 89.43 48.50 4,337.36 331.01 0.00 0.00 4,006.35 06/2019 O 0.00467885 07/19/2019 26.83 48.50 1,301.21 99.30 0.00 0.00 1,201.91

Sub-Total: 836.93 49.93 41,788.00 3,189.03 0.00 0.00 38,598.97

From: ARM ENERGY MANAGEMENT LLC Check History by DistributionTo: STEVEN A TEDESCO 01/15/2020 02:21 pm Page 2

Run Date Type & Pct Chk Date Volume Avg$ Gross Taxes Other W/H Net( 10066A) KNOSS 6-21: OIL02/2019 O 0.01000000 03/20/2019 2.39 41.96 100.27 6.61 0.00 0.00 93.66 02/2019 O 0.01000000 03/20/2019 2.39 41.96 100.27 6.61 0.00 0.00 93.66 08/2019 O 0.01000000 09/20/2019 2.01 35.60 71.60 4.72 0.00 0.00 66.88 08/2019 O 0.01000000 09/20/2019 2.01 35.60 71.60 4.72 0.00 0.00 66.88

Sub-Total: 8.80 39.06 343.74 22.66 0.00 0.00 321.08

( 10072A) CRAIG 4-4 BATTERY: OIL02/2019 O 0.01250000 03/20/2019 5.84 41.96 244.85 16.26 0.00 0.00 228.59 02/2019 O 0.00750000 03/20/2019 3.50 41.96 146.91 9.76 0.00 0.00 137.15 03/2019 O 0.01250000 04/19/2019 3.15 45.13 142.09 9.44 0.00 0.00 132.65 03/2019 O 0.00750000 04/19/2019 1.89 45.14 85.26 5.67 0.00 0.00 79.59 04/2019 O 0.01250000 05/20/2019 4.56 51.17 233.57 15.52 0.00 0.00 218.05 04/2019 O 0.00750000 05/20/2019 2.74 51.17 140.14 9.31 0.00 0.00 130.83 05/2019 O 0.01250000 06/20/2019 3.09 47.67 147.21 9.78 0.00 0.00 137.43 05/2019 O 0.00750000 06/20/2019 1.85 47.67 88.33 5.87 0.00 0.00 82.46 06/2019 O 0.01250000 07/19/2019 6.23 35.62 221.75 14.73 0.00 0.00 207.02 06/2019 O 0.00750000 07/19/2019 3.74 35.62 133.05 8.84 0.00 0.00 124.21 07/2019 O 0.01250000 08/20/2019 6.21 38.43 238.53 15.84 0.00 0.00 222.69 07/2019 O 0.00750000 08/20/2019 3.72 38.43 143.12 9.51 0.00 0.00 133.61 08/2019 O 0.01250000 09/20/2019 3.07 35.60 109.31 7.26 0.00 0.00 102.05 08/2019 O 0.00750000 09/20/2019 1.84 35.60 65.59 4.36 0.00 0.00 61.23

Sub-Total: 51.42 41.61 2,139.71 142.15 0.00 0.00 1,997.56

( 10073A) CRAIG 12-33 BATTERY: OIL04/2019 O 0.00750000 05/20/2019 0.84 51.18 43.06 3.06 0.00 0.00 40.00

Sub-Total: 0.84 51.18 43.06 3.06 0.00 0.00 40.00

( 10221A) ARIKAREE CREEK PILOT UNIT: OIL12/2018 O 0.00619242 01/22/2019 48.61 43.03 2,091.70 159.63 0.00 0.00 1,932.07 01/2019 O 0.00619242 02/20/2019 46.89 45.39 2,128.58 162.45 0.00 0.00 1,966.13 02/2019 O 0.00619242 03/20/2019 40.02 49.25 1,971.17 150.43 0.00 0.00 1,820.74 03/2019 O 0.00619242 04/19/2019 41.83 52.50 2,196.08 167.60 0.00 0.00 2,028.48 04/2019 O 0.00619242 05/20/2019 38.90 58.23 2,264.97 172.85 0.00 0.00 2,092.12 04/2019 O 0.00619242 06/20/2019 38.90- 58.23 2,264.97- 172.85- 0.00 0.00 2,092.12-04/2019 O 0.00619242 06/20/2019 38.99 58.25 2,271.35 173.34 0.00 0.00 2,098.01 05/2019 O 0.00619242 06/20/2019 38.82 54.22 2,105.16 160.66 0.00 0.00 1,944.50 06/2019 O 0.00619242 07/19/2019 38.32 48.50 1,858.69 141.84 0.00 0.00 1,716.85

Sub-Total: 293.49 49.82 14,622.73 1,115.95 0.00 0.00 13,506.78


Run Date Type & Pct Chk Date Volume Avg$ Gross Taxes Other W/H Net( 10230A) JOHN CRAIG 1-2: OIL10/2018 O 0.01625000 01/22/2019 12.37 65.67 812.02 62.06 0.00 0.00 749.96 10/2018 O 0.01625000 01/22/2019 12.37 65.67 812.02 62.06 0.00 0.00 749.96 11/2018 O 0.01625000 01/22/2019 12.14 50.56 613.56 46.90 0.00 0.00 566.66 11/2018 O 0.01625000 01/22/2019 12.14 50.56 613.56 46.90 0.00 0.00 566.66 12/2018 O 0.01625000 01/22/2019 14.08 43.03 605.81 46.31 0.00 0.00 559.50 12/2018 O 0.01625000 01/22/2019 14.08 43.03 605.81 46.31 0.00 0.00 559.50 01/2019 O 0.01625000 02/20/2019 16.30 45.39 739.89 56.56 0.00 0.00 683.33 01/2019 O 0.01625000 02/20/2019 16.30 45.39 739.89 56.56 0.00 0.00 683.33 02/2019 O 0.01625000 03/20/2019 13.18 49.25 649.36 49.63 0.00 0.00 599.73 02/2019 O 0.01625000 03/20/2019 13.18 49.25 649.36 49.63 0.00 0.00 599.73 03/2019 O 0.01625000 04/19/2019 14.02 52.50 736.08 56.26 0.00 0.00 679.82 03/2019 O 0.01625000 04/19/2019 14.02 52.50 736.08 56.26 0.00 0.00 679.82 04/2019 O 0.01625000 05/20/2019 13.83 58.23 805.48 61.57 0.00 0.00 743.91 04/2019 O 0.01625000 06/20/2019 13.83- 58.23 805.48- 61.57- 0.00 0.00 743.91-04/2019 O 0.01625000 06/20/2019 13.79 58.25 803.43 61.41 0.00 0.00 742.02 04/2019 O 0.01625000 05/20/2019 13.83 58.23 805.48 61.57 0.00 0.00 743.91 04/2019 O 0.01625000 06/20/2019 13.83- 58.23 805.48- 61.57- 0.00 0.00 743.91-04/2019 O 0.01625000 06/20/2019 13.79 58.25 803.43 61.41 0.00 0.00 742.02 05/2019 O 0.01625000 06/20/2019 11.67 54.22 632.77 48.37 0.00 0.00 584.40 05/2019 O 0.01625000 06/20/2019 11.67 54.22 632.77 48.37 0.00 0.00 584.40 06/2019 O 0.01625000 07/19/2019 12.69 48.50 615.35 47.04 0.00 0.00 568.31 06/2019 O 0.01625000 07/19/2019 12.69 48.50 615.35 47.04 0.00 0.00 568.31

Sub-Total: 240.47 51.63 12,416.54 949.08 0.00 0.00 11,467.46

( 10231A) JOHN CRAIG 10-10: OIL10/2018 O 0.01625000 01/22/2019 3.62 65.67 237.97 18.18 0.00 0.00 219.79 10/2018 O 0.01625000 01/22/2019 3.62 65.67 237.97 18.18 0.00 0.00 219.79 11/2018 O 0.01625000 01/22/2019 3.56 50.55 179.78 13.74 0.00 0.00 166.04 11/2018 O 0.01625000 01/22/2019 3.56 50.55 179.78 13.74 0.00 0.00 166.04 12/2018 O 0.01625000 01/22/2019 3.49 43.03 150.12 11.48 0.00 0.00 138.64 12/2018 O 0.01625000 01/22/2019 3.49 43.03 150.12 11.48 0.00 0.00 138.64 01/2019 O 0.01421875 03/20/2019 3.12 45.39 141.65 10.83 0.00 0.00 130.82 01/2019 O 0.01421875 03/20/2019 3.12 45.39 141.65 10.83 0.00 0.00 130.82 02/2019 O 0.01421875 03/20/2019 2.32 49.25 114.17 8.72 0.00 0.00 105.45 02/2019 O 0.01421875 03/20/2019 2.32 49.25 114.17 8.72 0.00 0.00 105.45 03/2019 O 0.01421875 04/19/2019 1.63 52.50 85.79 6.56 0.00 0.00 79.23 03/2019 O 0.01421875 04/19/2019 1.63 52.50 85.79 6.56 0.00 0.00 79.23 04/2019 O 0.01421875 05/20/2019 1.93 58.23 112.59 8.61 0.00 0.00 103.98 04/2019 O 0.01421875 06/20/2019 1.93- 58.23 112.59- 8.61- 0.00 0.00 103.98-


Run Date Type & Pct Chk Date Volume Avg$ Gross Taxes Other W/H Net04/2019 O 0.01421875 06/20/2019 1.93 58.25 112.24 8.58 0.00 0.00 103.66 04/2019 O 0.01421875 05/20/2019 1.93 58.23 112.59 8.61 0.00 0.00 103.98 04/2019 O 0.01421875 06/20/2019 1.93- 58.23 112.59- 8.61- 0.00 0.00 103.98-04/2019 O 0.01421875 06/20/2019 1.93 58.25 112.24 8.58 0.00 0.00 103.66 05/2019 O 0.01421875 06/20/2019 1.16 54.22 62.68 4.79 0.00 0.00 57.89 05/2019 O 0.01421875 06/20/2019 1.16 54.22 62.68 4.79 0.00 0.00 57.89

Sub-Total: 41.65 52.07 2,168.80 165.76 0.00 0.00 2,003.04

GOLDEN TRADING & TRANSPORT LLC% ExTex Division Order Services4865 Ward Road, Suite 200Wheat Ridge, CO 80033(303)463-8799

Check HistorySummarized by Distribution

For checks dated 01/01/2019 thru 12/31/2019

STEVEN A TEDESCO16482 E BERRY PLACECENTENNIAL, CO 80015

Owner Account: 10024

Run Date Type & Pct Chk Date Volume Avg$ Gross Taxes Other W/H Net(R100399) SNOWBIRD BATTERY: OIL07/2019 O 0.03250000 08/20/2019 42.04 50.72 2,131.89 142.51 0.00 0.00 1,989.38 07/2019 O 0.03250000 09/20/2019 42.04- 50.72 2,131.89- 142.51- 0.00 0.00 1,989.38-07/2019 O 0.03250000 09/20/2019 42.04 50.72 2,131.89 142.51 0.00 0.00 1,989.38

Sub-Total: 42.04 50.72 2,131.89 142.51 0.00 0.00 1,989.38

(R100400) STEAMBOAT BATTERY: OIL07/2019 O 0.01559615 08/20/2019 77.63 50.72 3,937.13 263.18 0.00 0.00 3,673.95 07/2019 O 0.01559615 09/20/2019 77.63- 50.72 3,937.13- 263.18- 0.00 0.00 3,673.95-07/2019 O 0.01559615 09/20/2019 77.63 50.72 3,937.13 263.18 0.00 0.00 3,673.95 07/2019 O 0.00467885 08/20/2019 23.29 50.72 1,181.14 78.95 0.00 0.00 1,102.19 07/2019 O 0.00467885 09/20/2019 23.29- 50.72 1,181.14- 78.95- 0.00 0.00 1,102.19-07/2019 O 0.00467885 09/20/2019 23.29 50.72 1,181.14 78.95 0.00 0.00 1,102.19 08/2019 O 0.01559615 09/20/2019 83.91 48.01 4,029.03 269.33 0.00 0.00 3,759.70 08/2019 O 0.00467885 09/20/2019 25.17 48.01 1,208.71 80.80 0.00 0.00 1,127.91 09/2019 O 0.01559615 10/21/2019 83.35 50.14 4,179.16 279.37 0.00 0.00 3,899.79 09/2019 O 0.00467885 10/21/2019 25.01 50.14 1,253.75 83.81 0.00 0.00 1,169.94 10/2019 O 0.01559615 11/20/2019 76.66 47.18 3,616.59 241.76 0.00 0.00 3,374.83 10/2019 O 0.00467885 11/20/2019 23.00 47.18 1,084.98 72.53 0.00 0.00 1,012.45 11/2019 O 0.01559615 12/20/2019 60.28 50.24 3,028.65 202.45 0.00 0.00 2,826.20 11/2019 O 0.00467885 12/20/2019 18.09 50.24 908.60 60.74 0.00 0.00 847.86

Sub-Total: 496.40 49.21 24,427.74 1,632.92 0.00 0.00 22,794.82

From: GOLDEN TRADING & TRANSPORT LLC Check History by DistributionTo: STEVEN A TEDESCO 01/15/2020 02:20 pm Page 2

Run Date Type & Pct Chk Date Volume Avg$ Gross Taxes Other W/H Net(R100409) JOHN CRAIG 1-2: OIL10/2019 O 0.03250000 11/20/2019 21.91 47.18 1,033.54 69.09 0.00 0.00 964.45 11/2019 O 0.03250000 12/20/2019 14.61 50.24 733.93 49.06 0.00 0.00 684.87

Sub-Total: 36.52 48.40 1,767.47 118.15 0.00 0.00 1,649.32

(R100414) JOHN CRAIG 6-2 BATTERY: OIL07/2019 O 0.02500000 08/20/2019 15.82 50.72 802.11 53.62 0.00 0.00 748.49 07/2019 O 0.02500000 09/20/2019 15.82- 50.72 802.11- 53.62- 0.00 0.00 748.49-07/2019 O 0.02500000 10/21/2019 15.82- 50.72 802.11- 53.62- 0.00 0.00 748.49-07/2019 O 0.02500000 09/20/2019 15.82 50.72 802.11 53.62 0.00 0.00 748.49 07/2019 O 0.00750000 08/20/2019 4.74 50.72 240.63 16.08 0.00 0.00 224.55 07/2019 O 0.00750000 09/20/2019 4.74- 50.72 240.63- 16.08- 0.00 0.00 224.55-07/2019 O 0.00750000 10/21/2019 4.74- 50.72 240.63- 16.08- 0.00 0.00 224.55-07/2019 O 0.00750000 09/20/2019 4.74 50.72 240.63 16.08 0.00 0.00 224.55 08/2019 O 0.02500000 09/20/2019 21.88 48.01 1,050.43 70.22 0.00 0.00 980.21 08/2019 O 0.02500000 10/21/2019 16.09- 48.01 772.34- 51.63- 0.00 0.00 720.71-08/2019 O 0.00750000 09/20/2019 6.56 48.01 315.13 21.07 0.00 0.00 294.06 08/2019 O 0.00750000 10/21/2019 4.83- 48.01 231.70- 15.49- 0.00 0.00 216.21-

Sub-Total: 7.53 48.02 361.52 24.17 0.00 0.00 337.35

(R100415) CRAIG 4-4: OIL11/2019 O 0.02000000 12/20/2019 4.77 49.32 235.20 15.73 0.00 0.00 219.47

Sub-Total: 4.77 49.32 235.20 15.73 0.00 0.00 219.47

(R10221) ARIKAREE CREEK PILOT UNIT-ACPU: OIL08/2019 O 0.00619242 09/20/2019 41.58 48.01 1,996.60 133.47 0.00 0.00 1,863.13 09/2019 O 0.00619242 10/21/2019 37.77 50.14 1,893.84 126.60 0.00 0.00 1,767.24 10/2019 O 0.00619242 11/20/2019 39.16 47.18 1,847.19 123.47 0.00 0.00 1,723.72 11/2019 O 0.00619242 12/20/2019 31.63 50.24 1,589.14 106.23 0.00 0.00 1,482.91

Sub-Total: 150.14 48.80 7,326.77 489.77 0.00 0.00 6,837.00

(R102300) JOHN CRAIG 1-2: OIL07/2019 O 0.03250000 10/21/2019 20.42 50.72 1,035.52 69.22 0.00 0.00 966.30 08/2019 O 0.03250000 10/21/2019 20.56 48.01 987.26 66.00 0.00 0.00 921.26 09/2019 O 0.03250000 10/21/2019 24.67 50.14 1,236.92 82.69 0.00 0.00 1,154.23

Sub-Total: 65.65 49.65 3,259.70 217.91 0.00 0.00 3,041.79

(R102310) JOHN CRAIG 10-10: OIL07/2019 O 0.02843750 10/21/2019 0.12 50.74 6.32 0.43 0.00 0.00 5.89 08/2019 O 0.02843750 10/21/2019 0.31 48.01 14.69 0.98 0.00 0.00 13.71

From: GOLDEN TRADING & TRANSPORT LLC Check History by DistributionTo: STEVEN A TEDESCO 01/15/2020 02:20 pm Page 3

Run Date Type & Pct Chk Date Volume Avg$ Gross Taxes Other W/H Net09/2019 O 0.02843750 10/21/2019 1.81 50.14 90.98 6.08 0.00 0.00 84.90

Sub-Total: 2.25 49.88 111.99 7.49 0.00 0.00 104.50

Production

COGIS - WELL Information

Scout Card Related Insp. MIT GIS Doc COA Wellbore Orders

Surface Location Data for API # 05-073-06602 Status: PR 4/30/2015 Well Name/No: BLACKCOMB #3-14 (click well name for production)Operator: D90 ENERGY LLC - 10706Status Date: 4/30/2015 1:20:30 PM Federal or State Lease #:FacilityID: 436848 LocationID: 436849County: LINCOLN #073 Location: NENW 14 6S54W 6 PMField: ARIKAREE CREEK - #2914 Elevation: 5,219 ft.Planned Location 642 FNL 2120 FWL Lat/Long: 39.53409/-103.40923 Lat/Long Source: Field Measured As Drilled Location Footages Not Available Lat/Long: 39.53409/-103.40923 Lat/Long Source: Field Measured

Wellbore Data for Sidetrack #00 Status: PR 4/30/2015Spud Date: 10/8/2014 Spud Date is: ACTUAL

Wellbore PermitPermit #: Expiration Date: 4/19/2016 7:13:08 PMProp Depth/Form: 9000 Surface Mineral Owner Same:Mineral Owner: FEE Surface Owner: FEE Unit: Unit Number:Formation and Spacing: Code: ATOK , Formation: ATOKA , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: CHRK , Formation: CHEROKEE , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: LGKC , Formation: LANSING-KANSAS CITY , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: MRTN , Formation: MARMATON , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: MS-SP , Formation: MISSISSIPPIAN-SPERGEN , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: WFCMP , Formation: WOLFCAMP , Order: , Unit Acreage: , Drill Unit: Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 350, Weight: 24 Cement: Sacks: 122, Top: 0, Bottom: 350, Determination Method: Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 9000, Weight: 17 Cement: Sacks: 1109, Top: 6000, Bottom: 9000, Determination Method:

Wellbore CompletedCompletion Date: 10/28/2014Measured TD: 8271 Measured PB depth: 8165True Vertical TD: True Vertical PB depth:Log Types: Triple ComboCasing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 353, Weight: 24 Cement: Sacks: 175, Top: 0, Bottom: 353, Determination Method: VISU Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8271, Weight: 17 Cement: Sacks: 1200, Top: 930, Bottom: 8271, Determination Method: CBL

Formation Log Top Log Bottom Cored DSTs WOLFCAMP 6196

LANSING-KANSAS CITY 6887MARMATON 7195CHEROKEE 7397

ATOKA 7569SPERGEN 8062

Completed information for formation SPGN Status: PR 4/30/2015 1st Production Date: 11/18/2014 Choke Size:Status Date: 4/30/2015 Open Hole Completion: NCommingled: N Production Method:Formation Name: SPERGEN Status: PRFormation Treatment Treatment Type:Treatment Date: 3/24/2015 Treatment End Date: 3/25/2015Treatment summary: Perf'd 8,118'-8,126'- added to original perforationsTotal 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):Produced 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:Treatment Date: 11/6/2014 Treatment End Date: 11/6/2014Treatment summary: Perforated only

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):Produced water used in treatment (bbls): Disposition method for flowback:Total proppant used (lbs): Green completions techniques utilized:Reason green techniques not utilized: Tubing Size: 2.875 Tubing Setting Depth: 8041Tubing Packer Depth: 7951 Tubing Multiple Packer:Open Hole Top: Open Hole Bottom: Initial Test Data:Test Date: 3/28/2015 Test Method: Pumping Hours Tested: 24 Gas Type: DRY Gas Disposal: FLARED

Test Type Measure BBLS_H2O 167 BBLS_OIL 181 BTU_GAS 677 CALC_BBLS_H2O 167 CALC_BBLS_OIL 181 CALC_GOR 165 CALC_MCF_GAS 30 CASING_PRESS 45 GRAVITY_OIL 29 MCF_GAS 30 TUBING_PRESS 54 Perforation Data: Interval Bottom: 8126 Interval Top: 8110 # of Holes: 76 Hole Size: 0.5



Surface Location Data for API # 05-073-06695 Status: SI 2/1/2018 Well Name/No: CRESTED BUTTE #2-14 (click well name for production)Operator: D90 ENERGY LLC - 10706Status Date: 2/1/2018 Federal or State Lease #:FacilityID: 441914 LocationID: 441913County: LINCOLN #073 Location: NWNE 14 6S54W 6 PMField: ARIKAREE CREEK - #2914 Elevation: 5,201 ft.Planned Location 1003 FNL 2115 FEL Lat/Long: 39.53314/-103.40486 Lat/Long Source: Field Measured As Drilled Location Footages Not Available Lat/Long: 39.53315/-103.40485 Lat/Long Source: Field Measured

Wellbore Data for Sidetrack #00 Status: SI 2/1/2018Spud Date: 9/1/2015 Spud Date is: ACTUAL

Wellbore PermitPermit #: Expiration Date: 5/28/2017 6:42:53 PMProp Depth/Form: 8500 Surface Mineral Owner Same:Mineral Owner: FEE Surface Owner: FEE Unit: Unit Number:Formation and Spacing: Code: CMBR , Formation: CAMBRIAN , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: CRTC , Formation: CRETACEOUS , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: MSSP , Formation: MISSISSIPPIAN , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: ORDV , Formation: ORDOVICIAN , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: PENN , Formation: PENNSYLVANIAN , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: PRMN , Formation: PERMIAN , Order: , Unit Acreage: , Drill Unit: Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 350, Weight: 24 Cement: Sacks: 132, Top: 0, Bottom: 350, Determination Method: Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8500, Weight: 17 Cement: Sacks: 1191, Top: 6000, Bottom: 8500, Determination Method:

Wellbore CompletedCompletion Date: 9/21/2015Measured TD: 8360 Measured PB depth: 8240True Vertical TD: True Vertical PB depth:Log Types: Triple ComboCasing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 351, Weight: 24 Cement: Sacks: 127, Top: 0, Bottom: 351, Determination Method: VISU Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8352, Weight: 17 Cement: Sacks: 1290, Top: 72, Bottom: 8352, Determination Method: CBL Additional Cement: String Type: 1ST , Top: 7133, Depth: 7146, Bottom: 7146, Sacks: 50, Method: SQUEEZE Additional Cement: String Type: 1ST , Top: 7133, Depth: 7146, Bottom: 7146, Sacks: 40, Method: SQUEEZE

Formation Log Top Log Bottom Cored DSTs NIOBRARA 3570

DAKOTA 4555WOLFCAMP 6153


ATOKA 7616MORROW 7872ST LOUIS 7988SPERGEN 8078SIMPSON 8231

Completed information for formation MRTN Status: SI 2/1/2018 1st Production Date: 11/19/2015 Choke Size:Status Date: 2/1/2018 Open Hole Completion: NCommingled: Y Production Method:Formation Name: MARMATON Status: SIFormation Treatment Treatment Type: ACID JOBTreatment Date: 9/15/2016 Treatment End Date: 9/16/2016Treatment summary: Acidized with 500 gallons of 7 1/2% HCL followed by 4 bbls of production water with 5 gallons of surfactant added. Displaced with 38.5 bbls of production water .Total fluid used in treatment (bbls): 54 Max pressure during treatment (psi): 30Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:

Total acid used in treatment (bbls): 12 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): 42 Total flowback volume recovered (bbls): 94Produced water used in treatment (bbls): 0 Disposition method for flowback: DISPOSALTotal proppant used (lbs): 0 Green completions techniques utilized: FalseReason green techniques not utilized: PIPELINEFormation Treatment Treatment Type: ACID JOBTreatment Date: 10/5/2015 Treatment End Date: 11/6/2015Treatment summary: Acidized with 12 bbls of 15% HCI containing 12 gallons of RAS-92 (anti-sludge, demulsifier) 2 gallons of iron control, 1 gallon scale inhibitor & 2.5 gallons of corrosion inhibitor. Displaced with 43 bbls of 2% KCI waterTotal fluid used in treatment (bbls): 55 Max pressure during treatment (psi): 2300Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:Total acid used in treatment (bbls): 12 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 87Produced water used in treatment (bbls): 43 Disposition method for flowback: DISPOSALTotal proppant used (lbs): Green completions techniques utilized: FalseReason green techniques not utilized: Tubing Size: 2.875 Tubing Setting Depth: 8148Tubing Packer Depth: 7200 Tubing Multiple Packer:Open Hole Top: Open Hole Bottom: Initial Test Data:Test Date: 9/17/2016 Test Method: Pump Hours Tested: 24 Gas Type: WET Gas Disposal: FLARED

Test Type Measure BBLS_H2O 27 BBLS_OIL 15 BTU_GAS 694 CALC_BBLS_H2O 27 CALC_BBLS_OIL 15 CALC_GOR 67 CALC_MCF_GAS 1 GRAVITY_OIL 36 MCF_GAS 1 TUBING_PRESS 55 Perforation Data: Interval Bottom: 7367 Interval Top: 7330 # of Holes: 230 Hole Size: 0.45

Completed information for formation STLS Status: SI 2/1/2018 1st Production Date: 11/19/2015 Choke Size:Status Date: 2/1/2018 Open Hole Completion: NCommingled: Y Production Method:Formation Name: ST LOUIS Status: SIFormation Treatment Treatment Type: ACID JOBTreatment Date: 9/15/2016 Treatment End Date: 9/16/2016Treatment summary: See information given with Marmaton - Formations are commingled so treatment was given to bothTotal 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):Produced 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 JOBTreatment Date: 9/25/2015 Treatment End Date: 9/30/2015Treatment summary: Acidized with 2,100 gallons of 15% HCI containing 60 gals of RAS-10(non emulsifier, anti sludge) 8 gallons of iron control, 10 gallons of corrosion inhibitor, 4 gallons of scale inhibitor and 1 gallon of biocide. Displaced with 50 bbls of 2% KCL water. Daily test values are inputted on the Marmaton tabTotal fluid used in treatment (bbls): 100 Max pressure during treatment (psi): 700Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:Total acid used in treatment (bbls): 50 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 54Produced water used in treatment (bbls): 50 Disposition method for flowback: DISPOSALTotal proppant used (lbs): Green completions techniques utilized: FalseReason 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 STLS . Perforation Data: Interval Bottom: 8077 Interval Top: 8058 # of Holes: 114 Hole Size: 0.45



Surface Location Data for API # 05-073-06601 Status: PR 12/12/2016 Well Name/No: BLACKCOMB #5-14 (click well name for production)Operator: D90 ENERGY LLC - 10706Status Date: 12/12/2016 8:19:32 AM Federal or State Lease #:FacilityID: 436847 LocationID: 436846County: LINCOLN #073 Location: SWNW 14 6S54W 6 PMField: ARIKAREE CREEK - #2914 Elevation: 5,182 ft.Planned Location 1996 FNL 1097 FWL Lat/Long: 39.53034/-103.41275 Lat/Long Source: Field Measured As Drilled Location Footages Not Available Lat/Long: 39.53034/-103.41275 Lat/Long Source: Field Measured

Wellbore Data for Sidetrack #00 Status: PR 12/12/2016Spud Date: 8/21/2014 Spud Date is: ACTUAL

Wellbore Permit DIRECTIONAL

Permit #: Expiration Date: 4/19/2016 7:17:42 PMProp Depth/Form: 9000 Surface Mineral Owner Same:Mineral Owner: FEE Surface Owner: FEE Unit: Unit Number:Formation and Spacing: Code: ATOK , Formation: ATOKA , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: CHRK , Formation: CHEROKEE , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: LGKC , Formation: LANSING-KANSAS CITY , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: MRTN , Formation: MARMATON , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: MS-SP , Formation: MISSISSIPPIAN-SPERGEN , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: WFCMP , Formation: WOLFCAMP , Order: , Unit Acreage: , Drill Unit: Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 350, Weight: 24 Cement: Sacks: 122, Top: 0, Bottom: 350, Determination Method: Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 9000, Weight: 17 Cement: Sacks: 1109, Top: 6000, Bottom: 9000, Determination Method:

Wellbore CompletedCompletion Date: 9/13/2014Measured TD: 8365 Measured PB depth:True Vertical TD: 8354 True Vertical PB depth: 8354Top PZ Location: Sec: 14 Twp: 6S 54W Footage: 1837 N 890 W Depth Bottom Hole Location: Sec: 14 Twp: 6S 54W Footages: 1837 FNL 890 FWL Depth Log Types: Triple Combo, CBLCasing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 352, Weight: 24 Cement: Sacks: 175, Top: 0, Bottom: 358, Determination Method: VISU Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8359, Weight: 17 Cement: Sacks: 1164, Top: 550, Bottom: 8365, Determination Method: CBL

Formation Log Top Log Bottom Cored DSTs WOLFCAMP 6168


ATOKA 7558SPERGEN 8024

Completed information for formation SPGN Status: PR 12/12/2016 1st Production Date: 10/5/2014 Choke Size:Status Date: 12/12/2016 Open Hole Completion: NCommingled: N Production Method:Formation Name: SPERGEN Status: PRFormation Treatment Treatment Type: ACID JOBTreatment Date: 11/21/2016 Treatment End Date: 11/29/2016Treatment summary: Pumped 6,000 gals 2% KCL with acetone, ethanol, @% KCL, anit sludge, Iron control, scale inhibitor & biocide. Also dropped 70 bio balls. Displaced with 30 bbls of 2% KCL. Total fluid used in treatment (bbls): 217 Max pressure during treatment (psi): 2460Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:Total acid used in treatment (bbls): 44 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 213Produced water used in treatment (bbls): 173 Disposition method for flowback: DISPOSALTotal proppant used (lbs): Green completions techniques utilized:Reason green techniques not utilized: PIPELINE

Formation Treatment Treatment Type:Treatment Date: 9/22/2014 Treatment End Date: 9/22/2014Treatment summary: Perforated onlyTotal 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):Produced water used in treatment (bbls): Disposition method for flowback:Total proppant used (lbs): Green completions techniques utilized:Reason green techniques not utilized: Tubing Size: 2.875 Tubing Setting Depth: 8028Tubing Packer Depth: 8027 Tubing Multiple Packer:Open Hole Top: Open Hole Bottom: Initial Test Data:Test Date: 12/10/2016 Test Method: Pump Hours Tested: 24 Gas Type: WET Gas Disposal: FLARED

Test Type Measure BBLS_H2O 149 BBLS_OIL 106 BTU_GAS 758 CALC_BBLS_H2O 149 CALC_BBLS_OIL 106 CALC_GOR 198 CALC_MCF_GAS 21 CASING_PRESS 52 GRAVITY_OIL 36 MCF_GAS 21 TUBING_PRESS 2200 Perforation Data: Interval Bottom: 8087 Interval Top: 8068 # of Holes: 76 Hole Size: 0.52



Surface Location Data for API # 05-073-06610 Status: IJ 12/22/2016 Well Name/No: BLACKCOMB #12-14 (click well name for production)Operator: D90 ENERGY LLC - 10706Status Date: 12/22/2016 Federal or State Lease #:FacilityID: 437313 LocationID: 437317County: LINCOLN #073 Location: NWSW 14 6S54W 6 PMField: ARIKAREE CREEK - #2914 Elevation: 5,195 ft.Planned Location 2245 FSL 640 FWL Lat/Long: 39.5274/-103.41428 Lat/Long Source: Field Measured As Drilled Location Footages Not Available Lat/Long: 39.5274/-103.41428 Lat/Long Source: Field Measured

Wellbore Data for Sidetrack #00 Status: IJ 12/22/2016Spud Date: 6/13/2014 Spud Date is: ACTUAL

Wellbore PermitPermit #: Expiration Date: 11/26/2018 5:44:43 PMProp Depth/Form: 8445 Surface Mineral Owner Same:Mineral Owner: FEE Surface Owner: FEE Unit: Unit Number:Formation and Spacing: Code: ATOK , Formation: ATOKA , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: CHRK , Formation: CHEROKEE , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: LGKC , Formation: LANSING-KANSAS CITY , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: MRTN , Formation: MARMATON , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: MS-SP , Formation: MISSISSIPPIAN-SPERGEN , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: SPGN , Formation: SPERGEN , Order: 556-2 , Unit Acreage: 600, Drill Unit: Formation and Spacing: Code: WFCMP , Formation: WOLFCAMP , Order: , Unit Acreage: , Drill Unit: Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 351, Weight: 24 Cement: Sacks: 175, Top: 0, Bottom: 351, Determination Method: Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8443, Weight: 17 Cement: Sacks: 1218, Top: 940, Bottom: 8443, Determination Method:

Wellbore CompletedCompletion Date: 8/14/2014Measured TD: 8445 Measured PB depth: 8351True Vertical TD: True Vertical PB depth:Log Types: Ind/Dens/Neut.Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 351, Weight: 24 Cement: Sacks: 175, Top: 0, Bottom: 351, Determination Method: VISU Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8443, Weight: 17 Cement: Sacks: 1218, Top: 940, Bottom: 8443, Determination Method: CBL

Formation Log Top Log Bottom Cored DSTs NIOBRARA 3745

WOLFCAMP 6128LANSING-KANSAS CITY 6858

MARMATON 7201CHEROKEE 7403

ATOKA 7559MORROW 7817SPERGEN 8045

Completed information for formation MRTN Status: AB 12/22/2016 1st Production Date: 12/17/2014 Choke Size:Status Date: 12/22/2016 Open Hole Completion: NCommingled: N Production Method:Formation Name: MARMATON Status: ABFormation Treatment Treatment Type:Treatment Date: 11/1/2016 Treatment End Date: 12/13/2016Treatment summary: Perf'd formation for cement squeeze prep 11-1-16 7,316' - 7,321' 20 holes 11-7-16 7,320' - 7,324' 4 holes 11-16-16 7,320' 2 holesTotal 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):Produced 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:Treatment Date: 8/10/2016 Treatment End Date: 8/26/2016Treatment summary: Mix and pump 30 sx 6.1 bbls Class G cement with 0.2% C-15 fluid loss, 1.15 cu ft/sk yield. 15.8 ppg (squeeze) Pressured tested squeeze and also previous perfs that were squeezed 7,313'-7,326' re-squeezing lower perfs Perf'd 7,319'-7,321' 8 holes Pump 30sx 6.1bbls Class G cement with 0.2% C-15 fluid loss, 1.15 cu ft/sk yield 15.8 ppg - pressure tested and held.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):Produced 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 JOBTreatment Date: 10/28/2014 Treatment End Date: 12/16/2014Treatment summary: Acidize with 2,000 gallons of 15% HCL and 44 bbls of 2% KCL water Squeezed initial perfs of 7,316' - 7,326' Re-perf'd 7,316'- 7,326' Acidized with 2,500 galons of 15% HCL and displaced with 50 bbls of 2% KCI-Squeezed again and closed perfs Perf'd 7220-7228 Acidized with 29 bbls of 15% HCL displaced with 51 bbls of 2@ KCI waterTotal fluid used in treatment (bbls): 281 Max pressure during treatment (psi): 1800Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:Total acid used in treatment (bbls): 136 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 243Produced water used in treatment (bbls): 145 Disposition method for flowback: DISPOSALTotal proppant used (lbs): Green completions techniques utilized:Reason green techniques not utilized: PIPELINETubing 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 BBLS_H2O 175 BBLS_OIL 28 CALC_BBLS_H2O 175 CALC_BBLS_OIL 28 CASING_PRESS 22 GRAVITY_OIL 38 TUBING_PRESS 45 Perforation Data: Interval Bottom: 7326 Interval Top: 7220 # of Holes: 202 Hole Size: 0.48

Completed information for formation SPGN Status: IJ 1/9/2017 1st Production Date: N/A Choke Size:Status Date: 1/9/2017 Open Hole Completion: NCommingled: N Production Method:Formation Name: SPERGEN Status: IJFormation Treatment Treatment Type:Treatment Date: 1/9/2017 Treatment End Date: N/ATreatment summary: 1st injection - Changing status to injection wellTotal 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):Produced 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:Treatment Date: 12/30/2016 Treatment End Date: N/ATreatment summary: No treatment performed. Waiting on approval to commence injection.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):Produced 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 JOBTreatment Date: 8/22/2016 Treatment End Date: 8/26/2016Treatment summary: Perf'd 8,072'-8,090' w/ 6spf, 108 holes, 4" scallop gun, 26gm shot, .46" EHD 51.3" penetration (listed since different info that initial perf info reported) Pump premixed 1,000 gallons Acetone, 750 gallons acetone, 750 gallons ethanol, 6,000 gals 2% KCl w/ 6.5 gals RAS-92 (anti sludge) 12 gal IC-75 (iron control) 7 gal SI-4 (scale inhibitor), 18 gal B-172 (biocide) & 150 bio balls Total fluid used in treatment (bbls): 212 Max pressure during treatment (psi): 1750Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:Total acid used in treatment (bbls): 61 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 372Produced water used in treatment (bbls): 151 Disposition method for flowback: DISPOSALTotal proppant used (lbs): Green completions techniques utilized: TrueReason green techniques not utilized: Formation Treatment Treatment Type: ACID JOBTreatment Date: 8/24/2015 Treatment End Date: 8/27/2015Treatment summary: Treated well with 12,000 gal 2% KCL mixed w/2,000 gal acetone and 1,000 gal ethanol and 100 bio balls. Displaced with 23 bbls of 2% KClTotal fluid used in treatment (bbls): 385 Max pressure during treatment (psi): 2580Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:Total acid used in treatment (bbls): 76 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 0Produced water used in treatment (bbls): 309 Disposition method for flowback: DISPOSALTotal proppant used (lbs): Green completions techniques utilized:Reason green techniques not utilized: PIPELINEFormation Treatment Treatment Type: ACID JOBTreatment Date: 4/17/2015 Treatment End Date: 4/24/2015Treatment summary: Re-perforated original perfs Acidized with 4500 gallons of 2% KCL mixed with 1000 gallons of Acetone and 500 gallons of ethanol. Displaced with 46 bbls of 2% KCL. Dropped 80 bio balls throughout the job.Total fluid used in treatment (bbls): 189 Max pressure during treatment (psi): 3450Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:Total acid used in treatment (bbls): 36 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 264Produced water used in treatment (bbls): 153 Disposition method for flowback: DISPOSALTotal proppant used (lbs): Green completions techniques utilized:Reason green techniques not utilized: PIPELINEFormation Treatment Treatment Type:Treatment Date: 8/20/2014 Treatment End Date: 8/20/2014Treatment summary: Perforated onlyTotal 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):Produced 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: Initial Test Data:Test Date: N/A Test Method: Hours Tested: Gas Type: Gas Disposal:

Test Type Measure BBLS_H2O 262 BBLS_OIL 2 BTU_GAS 820 CALC_BBLS_H2O 262 CALC_BBLS_OIL 2 CALC_GOR 1000 CALC_MCF_GAS 2

CASING_PRESS 48 GRAVITY_OIL 36 MCF_GAS 2 TUBING_PRESS 65 Perforation Data: Interval Bottom: 8090 Interval Top: 8072 # of Holes: 208 Hole Size: 0.53



Surface Location Data for API # 05-073-06561 Status: IJ 1/1/2020 Well Name/No: SNOWBIRD #16-15 (click well name for production)Operator: D90 ENERGY LLC - 10706Status Date: 1/1/2020 Federal or State Lease #:FacilityID: 434880 LocationID: 434879County: LINCOLN #073 Location: SESE 15 6S54W 6 PMField: ARIKAREE CREEK - #2914 Elevation: 5,241 ft.Planned Location 620 FSL 772 FEL Lat/Long: 39.52291/-103.41915 Lat/Long Source: Field Measured As Drilled Location Footages Not Available Lat/Long: 39.52291/-103.41915 Lat/Long Source: Field Measured

Wellbore Data for Sidetrack #00 Status: IJ 1/1/2020Spud Date: 9/25/2014 Spud Date is: ACTUAL

Wellbore PermitPermit #: Expiration Date: 11/26/2018 5:44:43 PMProp Depth/Form: 8400 Surface Mineral Owner Same:Mineral Owner: FEE Surface Owner: FEE Unit: Unit Number:Formation and Spacing: Code: ABCK , Formation: ARBUCKLE , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: ATOK , Formation: ATOKA , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: CHRK , Formation: CHEROKEE , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: KDRK , Formation: KINDERHOOK , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: MRRW , Formation: MORROW , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: MRTN , Formation: MARMATON , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: SPGN , Formation: SPERGEN , Order: 556-2 , Unit Acreage: 600, Drill Unit: Formation and Spacing: Code: STLS , Formation: ST LOUIS , Order: , Unit Acreage: , Drill Unit: Formation and Spacing: Code: WRSW , Formation: WARSAW , Order: , Unit Acreage: , Drill Unit: Casing: String Type: SURF , Hole Size: 12.5, Size: 9.625, Top: 0, Depth: 332, Weight: 36 Cement: Sacks: 185, Top: 0, Bottom: 332, Determination Method: Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8400, Weight: 17 Cement: Sacks: 1635, Top: 0, Bottom: 8400, Determination Method:

Wellbore CompletedCompletion Date: 10/13/2014Measured TD: 8400 Measured PB depth:True Vertical TD: True Vertical PB depth:Log Types: Triple ComboCasing: String Type: SURF , Hole Size: 12.5, Size: 9.625, Top: 0, Depth: 332, Weight: 36 Cement: Sacks: 185, Top: 0, Bottom: 332, Determination Method: VISU Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8400, Weight: 17 Cement: Sacks: 1635, Top: 0, Bottom: 8400, Determination Method: VISU

Formation Log Top Log Bottom Cored DSTs NIOBRARA 3740FORT HAYS 4098

CARLILE 4216GREEN RIVER 4387X BENTONITE 4518

D SAND 4620J SAND 4658

SKULL CREEK 4740CHEYENNE 4898MORRISON 4921DOCKUM 5170LYKINS 5594BLAINE 5687LYONS 5769

WOLFCAMP 6186NEVA 6471

FORAKER 6559VIRGIL 6741

SHAWNEE 6795HEEBNER 6897

LANSING-KANSAS CITY 6910MARMATON 7221

CHEROKEE 7455ATOKA 7633

MORROW 7860ST LOUIS 8047SPERGEN 8106WARSAW 8106

KINDERHOOK 8173ARBUCKLE 8250

Completed information for formation CHRK Status: AB 11/8/2016 1st Production Date: 11/10/2014 Choke Size:Status Date: 11/8/2016 Open Hole Completion: NCommingled: N Production Method:Formation Name: CHEROKEE Status: ABFormation Treatment Treatment Type:Treatment Date: 10/12/2016 Treatment End Date: N/ATreatment summary: Previously reported - AB CHRK 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):Produced 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 JOBTreatment Date: 10/22/2014 Treatment End Date: 10/23/2014Treatment summary: Acidized with 500 gallons of 15% HCI and displaced with 45 bbls of 2% KCI waterTotal fluid used in treatment (bbls): 57 Max pressure during treatment (psi): 1310Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:Total acid used in treatment (bbls): 12 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): 45 Total flowback volume recovered (bbls): 72Produced water used in treatment (bbls): Disposition method for flowback: DISPOSALTotal 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 CHRK . Perforation Data: Interval Bottom: 7431 Interval Top: 7428 # of Holes: 18 Hole Size: 0.48

Completed information for formation MRTN Status: AB 11/8/2016 1st Production Date: 11/10/2014 Choke Size:Status Date: 11/8/2016 Open Hole Completion:Commingled: Production Method:Formation Name: MARMATON Status: ABFormation Treatment Treatment Type:Treatment Date: 10/12/2016 Treatment End Date: N/ATreatment summary: Previously reported -AB MRTNTotal 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):Produced 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:Treatment Date: 10/4/2016 Treatment End Date: 10/18/2016Treatment summary: No formation treatment done - SqueezeTotal 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):

Produced 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 JOBTreatment Date: 10/27/2014 Treatment End Date: 10/31/2014Treatment summary: Acidized with 1200 gallons of 15% HCI and displaced with 45 bbls of 2% KCI water in perf's 7,396'-7,404' Came uphole and Perf'd 7,266'-7,274'- Acidized with another 1200 gallons of 15% HCI and displaced with 44 bbls of 2% KCI waterTotal fluid used in treatment (bbls): 146 Max pressure during treatment (psi): 1100Total gas used in treatment (mcf): Fluid density (lbs/gal):Type of gas: Number of staged intervals:Total acid used in treatment (bbls): 57 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 140Produced water used in treatment (bbls): 89 Disposition method for flowback: DISPOSALTotal 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 MRTN . Perforation Data: Interval Bottom: 7404 Interval Top: 7266 # of Holes: 96 Hole Size: 0.48

Completed information for formation MT-CRK Status: CM 11/8/2016 1st Production Date: N/A Choke Size:Status Date: 11/8/2016 Open Hole Completion: NCommingled: Production Method:Formation Name: MARMATON-CHEROKEE Status: CMFormation Treatment Treatment Type:Treatment Date: 10/12/2016 Treatment End Date: N/ATreatment summary: No formation treatment done - Squeeze AB commingled zone 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):Produced 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: Initial Test Data:Test Date: N/A Test Method: Hours Tested: Gas Type: Gas Disposal:

Test Type Measure BBLS_OIL 521 CALC_BBLS_OIL 521 CASING_PRESS 3 GRAVITY_OIL 38 TUBING_PRESS 60 Perforation Data: Interval Bottom: 7431 Interval Top: 7266 # of Holes: 114 Hole Size: 0.48

Completed information for formation SPGN Status: IJ 11/8/2016 1st Production Date: 11/11/2016 Choke Size:Status Date: 11/8/2016 Open Hole Completion: NCommingled: N Production Method:Formation Name: SPERGEN Status: IJFormation Treatment Treatment Type:Treatment Date: 1/26/2017 Treatment End Date: N/ATreatment summary: Treatment previously reported -changing status to injecting Adjusted tubing 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):Produced 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 JOBTreatment Date: 10/17/2016 Treatment End Date: 10/18/2016Treatment summary: Perf'd Lower SPGN adding depth 8,160' - 8,174' (84 holes) Drilled out CIBP @ 8,130' that abandoned the SPGN back on 10/22/14. 300 bbls produced water with additives 111 gallons pumped (Biocide - scale inhibitor & iron sequestering agent)Total fluid used in treatment (bbls): 303 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): 3 Min frac gradient (psi/ft):Recycled water used in treatment (bbls): 300 Total flowback volume recovered (bbls): 0Produced 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 JOBTreatment Date: 10/21/2014 Treatment End Date: 10/22/2014Treatment summary: Perf'd 8,141' - 8,146'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):Produced water used in treatment (bbls): Disposition method for flowback:Total proppant used (lbs): Green completions techniques utilized:Reason green techniques not utilized: Tubing Size: 2.875 Tubing Setting Depth: 8085Tubing Packer Depth: 8082 Tubing Multiple Packer:Open Hole Top: Open Hole Bottom:No Initial Test Data was found for formation SPGN . Perforation Data: Interval Bottom: 8174 Interval Top: 8141 # of Holes: 114 Hole Size: 0.52

Order Search

New Search

Return Count: 2

Cause

Number

Order

NumberOrder Date

Field

Code

Field

NameFormation Description

556 1 03-07-2016 SPGN

Approves request for an order to among other things: an approximate 1240-

acre enhanced recovery unit, the Arikaree Creek State Unit, and unitized

operations are hereby approved, for the production of oil, gas, and

associated hydrocarbons from the Mississippian Spergen Formation.

556 2 06-07-2016 SPGN

Approves Nighthawk's request for an order to among other things: amend

the description of the unit area in Order No. 556-1, determine that

conditions set forth in Order No. 556-1 have been satisfied, which Order

established the Arikaree Creek State Unit for the unitization of the

Mississippian Spergen Formation in the Application Lands, Lincoln County,

Colorado.

Documents

Mid-Continent Energy Exchange - Amazon Web Servicesinfo.mceeauction.com.s3.amazonaws.com/...Arikaree_Creek_Pilot_O… · Arikaree Creek Pilot Overriding Royalty Interest in Lincoln