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225-058
T R A N S M I T T A LL FROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7 th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska RE: 3S-719PB1 225-058 DATE:10/13/2025 Transmitted: 3S-719PB1 Via SFTP Transmittall instructions: please promptly sign, scan, and e-mail to AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM CC: 3S-719PB1- e-transmittal well folder Receipt: Date: Alaska/IT-Data Services |ConocoPhillips Alaska | 225-058 T40990 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.13 11:20:40 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 21148 feet feet true vertical 4203 feet feet Effective Depth measured 21148 feet 9334 feet true vertical 4203 feet 4041 feet Perforation depth Measured depth 18954 - 18964 feet True Vertical depth 4190' TVD feet Tubing (size, grade, measured and true vertical depth)4-1/2"L-80 9,517' MD 4069' TVD HES TNT 9,334' MD 4,041' TVD Packers and SSSV (type, measured and true vertical depth)Baker ZXP 9,511' MD 4,068' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 3048 2550 Burst Collapse 2470 4790 7850 5210 6890 10860 measured TVD Production Liner 8418 977 12961 Casing Structural 3930 4092 4-1/2" 8687 9684 21148 4203 Plugs Junk measured 8,374,842lbs 16/20 LWC proppant, 63,000lbs 100M, 887,177 gals seawater, 1,349,155 gals fresh water, 2802 psi final pressure Length 80 2979 132Conductor Surface Intermediate 20" 10-3/4" N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL380107, ADL025544, ADL025551 Coyote Oil Pool ConocoPhillips Alaska, Inc. P.O. Box 100360, Anchorage, Alaska 99510-0360 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 225-058 50-103-20919-00-00 Size 132 0 0 psi0 0 1891 psi (BHG)0 2802 psi (BHG) 7-5/8" 11590 7-5/8" KRU 3S-719 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 21,015 - 10,931' MD 0 psi measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 325-476 Sr Pet Eng: 9210 Sr Pet Geo:Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Completions Engineer Madeline Woodard madeline.e.woodard@cop.com 907-265-6086 Coyote Oil Pool p k ft t Fra O s O 225 6. A G L PG , C Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:18 am, Sep 29, 2025 Digitally signed by Madeline Woodard DN: CN=Madeline Woodard, E=madeline.e.woodard@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.09.29 08:08:11-08'00' Foxit PDF Editor Version: 13.1.6 Madeline Woodard J.Lau 11/6/25 CDW 09/29/2025 RBDMS JSB 100225 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set GLVs, pulled RBP 3S-719 9/21/2025 rmoore22 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Conductor 20 18.50 40.2 120.0 120.0 78.67 x65 Surface 10 3/4 9.95 40.2 2,766.7 2,550.0 45.50 L-80 Hyd 563 Intermediate 7 5/8 6.88 38.3 9,684.3 4,092.0 29.70 L-80 Hyd563 Liner 4 1/2 3.96 9,511.3 21,148.0 4,203.5 12.60 P110 Hyd 563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 37.1 Set Depth … 9,517.3 String Max No… 4 1/2 Set Depth … 4,069.0 Tubing Description Tubing – Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 37.1 37.1 0.00 Hanger 11.000 4 1/2" StreamFlo Tubing Hanger/Pup StreamF lo DMLX 3.900 2,292.7 2,232.9 37.69 Mandrel 4.500 4 1/2" Camco KBG 4-5 GLM Camco KBG4-5 3.865 3,850.0 3,096.2 69.41 Mandrel 4.500 4 1/2" Camco KBG 4-5 GLM Camco KBG4-5 3.865 7,674.3 3,755.2 80.36 Sleeve - Sliding 4.500 Camco NEXA-2-Sliding Sleeve 4- 1/2",12.6#,L80 Camco KBG4-5 3.813 9,226.9 4,023.8 80.46 Gauge / Pump Sensor 4.500 HAL Opsis DHG Mandrel, 4 1/2",12.6#,L80,H563 HES DHG 3.932 9,334.2 4,041.4 80.86 PACKER 6.880 HES TNT Packer, 7-5/8" x 4- 1/2",12.6#,H563 HES TNT 3.856 9,442.9 4,058.1 81.40 Nipple - DB 4.500 Nipple, Landing 3.750", DB-6, Inconel,H563 SLB DB-6 3.750 9,496.2 4,065.9 81.63 Sub - Ceramic disc 4.500 ** OPENED 8/24/25** Arsenal Glass Disk, 5500 psi shear,H563 Arsenal 5.5k 3.880 9,514.0 4,068.5 81.72 Mule Shoe 4.500 HES Self-Aligning Muleshoe Guide 3.920 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,292.7 2,232.9 37.69 1 GAS LIFT GLV BK 1 1,485.0 9/20/2025 Camco 0.250 3,850.0 3,096.2 69.41 2 GAS LIFT OV BK 1 9/21/2025 Camco 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,511.3 4,068.1 81.70 Nipple - RS 6.050 RS Packoff Seal Nipple Baker RS Packoff Seal Nipple 4.250 10,931.4 4,193.2 87.51 FRAC Sleeve/Port 5.000 **OPENED 9/9/25** Advanced Upstream SP LO/LC Frac Sleeve #20, H563 C110 (SN:358) Adv Upstrea m Limitless 3.450 11,429.3 4,201.9 89.76 FRAC Sleeve/Port 5.000 **OPENED 9/9/25** Advanced Upstream SP LO/LC Frac Sleeve #19, H563 C110 (SN:352) Adv Upstrea m Limitless 3.450 11,969.2 4,200.1 90.40 FRAC Sleeve/Port 5.000 **OPENED 9/9/25** Advanced Upstream SP LO/LC Frac Sleeve #18, H563 C110 (SN:322) Adv Upstrea m Limitless 3.450 12,465.9 4,197.0 90.35 FRAC Sleeve/Port 5.000 **OPENED 9/8/25** Advanced Upstream SP LO/LC Frac Sleeve #17, H563 C110 (SN:309) Adv Upstrea m Limitless 3.450 12,964.4 4,193.4 90.49 FRAC Sleeve/Port 5.000 **OPENED 9/8/25** Advanced Upstream SP LO/LC Frac Sleeve #16, H563 C110 (SN:319) Adv Upstrea m Limitless 3.450 13,462.8 4,189.1 90.47 FRAC Sleeve/Port 5.000 **OPENED 9/8/25** Advanced Upstream SP LO/LC Frac Sleeve #15, H563 C110 (SN:342) Adv Upstrea m Limitless 3.450 13,960.7 4,185.6 90.36 FRAC Sleeve/Port 5.000 **OPENED 9/7/25** Advanced Upstream SP LO/LC Frac Sleeve # 14, H563 C110 (SN:345) Adv Upstrea m Limitless 3.450 14,458.6 4,182.5 90.33 FRAC Sleeve/Port 5.000 **OPENED 9/7/25** Advanced Upstream SP LO/LC Frac Sleeve #13, H563 C110 (SN:346) Adv Upstrea m Limitless 3.450 14,955.9 4,179.4 90.36 FRAC Sleeve/Port 5.000 **OPENED 9/7/25** Advanced Upstream SP LO/LC Frac Sleeve #12, H563 C110 (SN:331) Adv Upstrea m Limitless 3.450 15,454.4 4,176.1 90.35 FRAC Sleeve/Port 5.000 **OPENED 9/6/25** Advanced Upstream SP LO/LC Frac Sleeve #11, H563 C110 (SN:317) Adv Upstrea m Limitless 3.450 15,952.3 4,172.8 90.31 FRAC Sleeve/Port 5.000 **OPENED 9/6/25** Advanced Upstream SP LO/LC Frac Sleeve #10, H563 C110 (SN:341) Adv Upstrea m Limitless 3.450 16,449.5 4,173.3 89.70 FRAC Sleeve/Port 5.000 **OPENED 9/6/25** Advanced Upstream SP LO/LC Frac Sleeve #9, H563 C110 (SN:327) Adv Upstrea m Limitless 3.450 16,988.0 4,176.4 89.54 FRAC Sleeve/Port 5.000 **OPENED 9/5/25** Advanced Upstream SP LO/LC Frac Sleeve #8, H563 C110 (SN:337) Adv Upstrea m Limitless 3.450 17,486.1 4,179.9 89.60 FRAC Sleeve/Port 5.000 **OPENED 9/5/25** Advanced Upstream SP LO/LC Frac Sleeve #7, H563 C110 (SN:312) Adv Upstrea m Limitless 3.450 HORIZONTAL, 3S-719, 9/25/2025 1:50:51 PM M D (ft K B) 38.4 40.0 41.0 88.3 120.1 2,292.7 2,310.0 2,683.1 2,766.7 3,839.9 3,857.0 7,664.0 7,679.1 8,110.9 9,216.9 9,231.0 9,324.1 9,339.6 9,428.1 9,442.9 9,454.7 9,498.0 9,508.9 9,511.2 9,514.1 9,533.8 9,544.6 9,550.2 9,596.1 9,684.4 9,693.9 10,138.1 10,931.4 10,935.4 11,431.8 11,969.2 11,973.1 12,468.2 12,966.5 13,465.2 13,962.9 14,461.0 14,958.0 15,456.7 15,954.7 16,451.8 16,990.2 17,488.2 17,985.2 18,483.9 18,981.6 19,480.3 19,975.7 20,474.1 20,973.8 21,018.7 21,061.7 21,148.0 21,157.2 TV D (ftK B) 38.4 40.0 41.0 88.3 120.1 2,232.7 2,246.3 2,500.8 2,549.9 3,092.3 3,098.3 3,753.5 3,756.0 3,829.1 4,022.1 4,024.5 4,039.7 4,042.1 4,055.8 4,058.0 4,059.8 4,066.1 4,067.7 4,068.0 4,068.5 4,071.3 4,072.9 4,073.7 4,080.0 4,092.0 4,093.2 4,142.1 4,193.0 4,193.2 4,201.9 4,200.1 4,200.1 4,197.0 4,193.4 4,189.1 4,185.6 4,182.5 4,179.4 4,176.1 4,172.8 4,173.3 4,176.4 4,180.0 4,183.3 4,186.7 4,190.3 4,193.6 4,196.0 4,198.4 4,201.9 4,202.3 4,202.7 4,203.5 4,203.6 Incl (°) 0.0 0.0 0.0 0.2 0.3 37.7 38.6 53.3 54.3 69.2 69.6 80.4 80.4 80.0 80.5 80.5 80.8 80.9 81.3 81.4 81.4 81.6 81.7 81.7 81.7 81.8 81.9 81.9 82.1 82.5 82.6 85.1 87.5 87.5 89.8 90.4 90.4 90.3 90.5 90.5 90.4 90.3 90.4 90.4 90.3 89.7 89.5 89.6 89.6 89.6 89.6 89.7 89.7 89.7 89.5 89.5 89.5 89.5 89.5 Vertical schematic (actual) 5-53; Shoe; 4.500; 3.410; 21,144.1; 3.85 5-52; Liner; 4.500; 3.958; 21,061.7; 82.48 5-51; Collar - Landing ; 4.500; 3.030; 21,060.0; 1.68 5-50; Liner; 4.500; 3.958; 21,018.7; 41.27 5-49; Sleeve - Sliding; 4.500; 3.010; 21,015.0; 3.69 5-48; Liner; 4.500; 3.958; 20,973.7; 41.37 5-47; Sleeve - Sliding; 4.500; 3.010; 20,970.0; 3.69 5-46; Liner; 4.500; 3.958; 20,474.0; 495.99 5-45; FRAC Sleeve/Port; 5.000; 3.450; 20,471.7; 2.30 5-44; Liner; 4.500; 3.958; 19,975.7; 496.02 5-43; FRAC Sleeve/Port; 5.000; 3.450; 19,973.4; 2.29 5-42; Liner; 4.500; 3.958; 19,480.2; 493.17 5-41; FRAC Sleeve/Port; 5.000; 3.450; 19,477.9; 2.29 5-40; Liner; 4.500; 3.958; 18,981.7; 496.24 5-39; FRAC Sleeve/Port; 5.000; 3.450; 18,979.4; 2.29 5-38; Liner; 4.500; 3.958; 18,483.8; 495.55 5-37; FRAC Sleeve/Port; 5.000; 3.450; 18,481.5; 2.29 5-36; Liner; 4.500; 3.958; 17,985.4; 496.14 5-35; FRAC Sleeve/Port; 5.000; 3.450; 17,983.1; 2.29 5-34; Liner; 4.500; 3.958; 17,488.3; 494.76 5-33; FRAC Sleeve/Port; 5.000; 3.450; 17,486.1; 2.29 5-32; Liner; 4.500; 3.958; 16,990.2; 495.82 5-31; FRAC Sleeve/Port; 5.000; 3.450; 16,988.0; 2.29 5-30; Liner; 4.500; 3.958; 16,451.8; 536.19 5-29; FRAC Sleeve/Port; 5.000; 3.450; 16,449.5; 2.28 5-28; Liner; 4.500; 3.958; 15,954.6; 494.86 5-27; FRAC Sleeve/Port; 5.000; 3.450; 15,952.3; 2.29 5-26; Liner; 4.500; 3.958; 15,456.7; 495.62 5-25; FRAC Sleeve/Port; 5.000; 3.450; 15,454.4; 2.29 5-24; Liner; 4.500; 3.958; 14,958.1; 496.27 5-23; FRAC Sleeve/Port; 5.000; 3.450; 14,955.9; 2.29 5-22; Liner; 4.500; 3.958; 14,460.9; 494.98 5-21; FRAC Sleeve/Port; 5.000; 3.450; 14,458.5; 2.33 5-20; Liner; 4.500; 3.958; 13,963.0; 495.58 5-19; FRAC Sleeve/Port; 5.000; 3.450; 13,960.7; 2.30 5-18; Liner; 4.500; 3.958; 13,465.1; 495.60 5-17; FRAC Sleeve/Port; 5.000; 3.450; 13,462.8; 2.30 5-16; Liner; 4.500; 3.958; 12,966.6; 496.12 5-15; FRAC Sleeve/Port; 5.000; 3.450; 12,964.4; 2.30 5-14; Liner; 4.500; 3.958; 12,468.2; 496.18 5-13; FRAC Sleeve/Port; 5.000; 3.450; 12,465.9; 2.29 5-12; Liner; 4.500; 3.958; 11,971.5; 494.36 5-11; FRAC Sleeve/Port; 5.000; 3.450; 11,969.2; 2.30 5-10; Liner; 4.500; 3.958; 11,431.6; 537.59 5-9; FRAC Sleeve/Port; 5.000; 3.450; 11,429.3; 2.30 5-8; Liner; 4.500; 3.958; 10,933.7; 495.68 5-7; FRAC Sleeve/Port; 5.000; 3.450; 10,931.4; 2.30 5-6; Liner - Pup; 4.530; 3.958; 10,911.4; 19.93 5-5; Liner; 4.500; 3.958; 9,548.5; 1,362.91 3-7; Shoe - Float; 7.625; 6.875; 9,682.2; 2.12 3-6; Casing; 7.625; 6.875; 9,596.0; 86.19 3-5; Collar - Float; 7.625; 6.875; 9,593.2; 2.83 3-4; Casing; 7.625; 6.875; 9,550.1; 43.04 5-4; Liner - Pup; 4.500; 3.958; 9,544.7; 3.80 5-3; XO Threads (Casing); 5.990; 3.900; 9,543.0; 1.69 5-2; Hanger; 6.440; 4.790; 9,533.7; 9.32 5-1; Nipple - RS; 6.050; 4.250; 9,511.3; 22.42 1-34; Mule Shoe; 4.500; 3.920; 9,514.0; 3.26 1-33; Pup Joint; 4.520; 3.920; 9,510.6; 3.43 1-32; Pup Joint; 5.630; 3.900; 9,508.7; 1.87 1-31; Pup Joint; 5.290; 3.900; 9,508.1; 0.67 1-30; Pup Joint; 4.500; 3.920; 9,498.0; 10.04 1-29; Sub - Ceramic disc; 4.500; 3.880; 9,496.2; 1.87 1-28; Tubing; 4.500; 3.958; 9,454.6; 41.51 1-27; Pup Joint; 4.500; 3.958; 9,444.5; 10.14 1-26; Nipple - DB; 4.500; 3.750; 9,442.9; 1.60 1-25; Pup Joint; 4.500; 3.958; 9,432.8; 10.14 1-24; Tubing; 4.500; 3.958; 9,349.8; 82.98 1-23; Pup Joint; 4.500; 3.906; 9,339.6; 10.15 1-22; PACKER; 6.880; 3.856; 9,334.2; 5.42 1-21; Pup Joint; 4.500; 3.896; 9,324.2; 10.06 1-20; Tubing; 4.500; 3.958; 9,241.2; 82.98 1-19; Tubing; 4.500; 3.902; 9,231.1; 10.07 1-18; Gauge / Pump Sensor; 4.500; 3.932; 9,226.9; 4.25 1-17; Tubing; 4.500; 3.902; 9,216.7; 10.14 3-3; Casing; 7.625; 6.765; 8,686.6; 863.50 1-16; Tubing; 4.500; 3.958; 7,689.3; 1,527.39 1-15; Pup Joint; 4.500; 3.958; 7,679.2; 10.13 1-14; Sleeve - Sliding; 4.500; 3.813; 7,674.3; 4.94 1-13; Pup Joint; 4.500; 3.958; 7,664.1; 10.14 1-12; Tubing; 4.500; 3.958; 3,867.2; 3,796.87 3-2; Casing; 7.625; 6.875; 39.2; 8,647.47 1-11; Pup Joint; 4.500; 3.958; 3,857.1; 10.14 1-10; Mandrel; 4.500; 3.865; 3,850.0; 7.07 1-9; Pup Joint; 4.500; 3.958; 3,839.9; 10.14 1-8; Tubing; 4.500; 3.958; 2,309.9; 1,529.99 2-5; Shoe - Float; 10.750; 9.875; 2,764.3; 2.40 2-4; Casing; 10.750; 9.950; 2,683.1; 81.17 2-3; Collar - Float; 10.750; 9.875; 2,680.0; 3.17 1-7; Pup Joint; 4.500; 3.958; 2,299.8; 10.14 1-6; Mandrel; 4.500; 3.865; 2,292.7; 7.07 1-5; Pup Joint; 4.500; 3.958; 2,282.9; 9.82 2-2; Casing; 10.750; 9.950; 77.9; 2,602.07 1-4; Tubing; 4.500; 3.958; 94.1; 2,188.82 1-3; Pup Joint; 4.500; 3.958; 88.3; 5.73 1-1; Casing Jts; 20.000; 18.500; 40.2; 79.80 1-2; Tubing; 4.500; 3.958; 41.1; 47.23 2-1; Casing - Surface; 10.750; 9.950; 40.2; 37.67 1-1; Hanger; 11.000; 3.900; 37.1; 4.02 3-1; Casing Hanger; 10.850; 6.860; 38.3; 0.82 KUP PROD KB-Grd (ft) 39.80 RR Date 8/14/2025 Other Elev… 3S-719 ... TD Act Btm (ftKB) 21,157.0 Well Attributes Field Name COYOTE Wellbore API/UWI 501032091900 Wellbore Status PROD Max Angle & MD Incl (°) 90.63 MD (ftKB) 11,663.40 WELLNAME WELLBORE3S-719 Annotation End DateH2S (ppm) DateComment Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 17,983.1 4,183.2 89.64 FRAC Sleeve/Port 5.000 **OPENED 9/5/25** Advanced Upstream SP LO/LC Frac Sleeve #6, H563 C110 (SN:334) Adv Upstrea m Limitless 3.450 18,481.5 4,186.6 89.58 FRAC Sleeve/Port 5.000 **OPENED 9/4/25** Advanced Upstream SP LO/LC Frac Sleeve #5, H563 C110 (SN:350) Adv Upstrea m Limitless 3.450 18,979.4 4,190.3 89.58 FRAC Sleeve/Port 5.000 Advanced Upstream SP LO/LC Frac Sleeve #4, H563 C110 (SN:355) Adv Upstrea m Limitless 3.450 19,477.9 4,193.6 89.73 FRAC Sleeve/Port 5.000 ** OPENED 8/26/25** Advanced Upstream SP LO/LC Frac Sleeve #3, H563 C110 (SN:329) Adv Upstrea m Limitless 3.450 19,973.4 4,196.0 89.74 FRAC Sleeve/Port 5.000 ** OPENED 8/25/25** Advanced Upstream SP LO/LC Frac Sleeve #2, H563 C110 (SN:357) Adv Upstrea m Limitless 3.450 20,471.7 4,198.4 89.73 FRAC Sleeve/Port 5.000 ** OPENED 8/25/25**Advanced Upstream SP LO/LC Frac Sleeve #1, H563 C110 (SN:356) Adv Upstrea m Limitless 3.450 20,970.0 4,201.9 89.48 Sleeve - Sliding 4.500 Alpha Toe Sleeve, 4-1/2", 13.5# Q125, Hyd 563, Rupture Disc 16 Baker Alpha P Sleeve 3.010 21,015.0 4,202.3 89.46 Sleeve - Sliding 4.500 ** OPENED 8/24/25** Alpha Toe Sleeve, 4-1/2", 13.5# Q125, Hyd 563, Rupture Disc 15 Baker Alpha P Sleeve 3.010 21,060.0 4,202.7 89.46 Collar - Landing 4.500 Alpha Type II Landing Collar, 4- 1/2", 12.6# Q125, Hyd 563 Baker Alpha Type II 3.030 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 40.2 2,783.0 40.2 2,559.5 Surface String Cement Cement 10-3/4" casing , Line up to cementers. Pressure test lines to 4000 PSI. Pump 100 BBLS 10.5 ppg MudPush. (reciprocate and rotated string 10 rpm) set on hanger, SD and drop bottom plug. Mix and pump 450 BBLs of 11.0 ppg lead cement. (reciprocate and rotated string 10 rpm) set on hanger, Mix and pump 57 BBLs 15.8 ppg of tail cement. Unable to rotate, set back on hanger, (Lost returns 50bbls during pumping tail, Pull off seat and regained returns) set back on hanger, SD and drop top plug. Pump 20 BBLs of FW with cement unit. Swap over to rig and displace cement. (Lost returns at 110 BBLs into displacement, Pull off seat and regained partial returns 9.9ppg cement coming out), unable to place back on seat, pipe free on up stroke but loosing ground slacking off. Shoe at 2,765.84' MD. 74 BBLs cement to surface. Slow rate to 3 BPM. Bump plug at 2375 stks 239 BBLS. FCP 718 PSI. Pressure up to 1308 PSI. Check floats. Good Cement in place @ 03:08 hrs. 6/27/25 Lead wet @ 00:22hrs Tail wet @ 01:58hrs 6/27/2025 8,111.0 9,693.0 3,829.0 4,093.1 Intermediate String 1 Cement Line up to cementers. Load bottom plug #1 and pump 5 bbls of H2O. Test lines to 4500 PSI – test good. Shut Down. Load bottom plug #2 pump 52 BBLS 12.5 PPG Mud Push 5 BPM/460 PSI. Swap to cementers. Pump 90 BBLs 15.3 PPG Tail cement. Shut Down. Load top plug. Cementers pump 10 BBLS FW. Swap to rig pumps. Displace w/ rig at 7 BPM. Slow rate to 3 BPM at 15 BBLs left. Did not bump plug at 5071 Stks. FCP= 436 PSI. Bleed off and check floats. Good. Full returns Cement in place at 11:47 hrs 07-05-2025. 7/5/2025 9,511.0 21,157.0 4,068.1 4,203.6 Production String 1 Cement PJSM for cement job. Pressure test lines to 4500 psi - test good. Pump 50 bbls of 11 ppg of mud push at 2.5 bpm with rig. Pumped 313 bbls of 15.3 ppg cement at 2.5 bpm with SLB. Pump 1 bbl H2O, dropped dart, and pumped 10 bbls of H2O. Displace with rig 234 bbls of CI Brine at 2.5 bpm, 880 psi. Reduce rate to 1.5 bpm, ICP 880 psi and bumped plug at 2767 strokes, FCP 1500 psi and hold for 5 min, bleed of pressure and check floats - float is holding. (Full returns till the last 64bbls pumped, 23bbls lost during last 64bbls pumped) 8/11/2025 HORIZONTAL, 3S-719, 9/25/2025 1:50:52 PM M D (ft K B) 38.4 40.0 41.0 88.3 120.1 2,292.7 2,310.0 2,683.1 2,766.7 3,839.9 3,857.0 7,664.0 7,679.1 8,110.9 9,216.9 9,231.0 9,324.1 9,339.6 9,428.1 9,442.9 9,454.7 9,498.0 9,508.9 9,511.2 9,514.1 9,533.8 9,544.6 9,550.2 9,596.1 9,684.4 9,693.9 10,138.1 10,931.4 10,935.4 11,431.8 11,969.2 11,973.1 12,468.2 12,966.5 13,465.2 13,962.9 14,461.0 14,958.0 15,456.7 15,954.7 16,451.8 16,990.2 17,488.2 17,985.2 18,483.9 18,981.6 19,480.3 19,975.7 20,474.1 20,973.8 21,018.7 21,061.7 21,148.0 21,157.2 TV D (ftK B) 38.4 40.0 41.0 88.3 120.1 2,232.7 2,246.3 2,500.8 2,549.9 3,092.3 3,098.3 3,753.5 3,756.0 3,829.1 4,022.1 4,024.5 4,039.7 4,042.1 4,055.8 4,058.0 4,059.8 4,066.1 4,067.7 4,068.0 4,068.5 4,071.3 4,072.9 4,073.7 4,080.0 4,092.0 4,093.2 4,142.1 4,193.0 4,193.2 4,201.9 4,200.1 4,200.1 4,197.0 4,193.4 4,189.1 4,185.6 4,182.5 4,179.4 4,176.1 4,172.8 4,173.3 4,176.4 4,180.0 4,183.3 4,186.7 4,190.3 4,193.6 4,196.0 4,198.4 4,201.9 4,202.3 4,202.7 4,203.5 4,203.6 Incl (°) 0.0 0.0 0.0 0.2 0.3 37.7 38.6 53.3 54.3 69.2 69.6 80.4 80.4 80.0 80.5 80.5 80.8 80.9 81.3 81.4 81.4 81.6 81.7 81.7 81.7 81.8 81.9 81.9 82.1 82.5 82.6 85.1 87.5 87.5 89.8 90.4 90.4 90.3 90.5 90.5 90.4 90.3 90.4 90.4 90.3 89.7 89.5 89.6 89.6 89.6 89.6 89.7 89.7 89.7 89.5 89.5 89.5 89.5 89.5 Vertical schematic (actual) 5-53; Shoe; 4.500; 3.410; 21,144.1; 3.85 5-52; Liner; 4.500; 3.958; 21,061.7; 82.48 5-51; Collar - Landing ; 4.500; 3.030; 21,060.0; 1.68 5-50; Liner; 4.500; 3.958; 21,018.7; 41.27 5-49; Sleeve - Sliding; 4.500; 3.010; 21,015.0; 3.69 5-48; Liner; 4.500; 3.958; 20,973.7; 41.37 5-47; Sleeve - Sliding; 4.500; 3.010; 20,970.0; 3.69 5-46; Liner; 4.500; 3.958; 20,474.0; 495.99 5-45; FRAC Sleeve/Port; 5.000; 3.450; 20,471.7; 2.30 5-44; Liner; 4.500; 3.958; 19,975.7; 496.02 5-43; FRAC Sleeve/Port; 5.000; 3.450; 19,973.4; 2.29 5-42; Liner; 4.500; 3.958; 19,480.2; 493.17 5-41; FRAC Sleeve/Port; 5.000; 3.450; 19,477.9; 2.29 5-40; Liner; 4.500; 3.958; 18,981.7; 496.24 5-39; FRAC Sleeve/Port; 5.000; 3.450; 18,979.4; 2.29 5-38; Liner; 4.500; 3.958; 18,483.8; 495.55 5-37; FRAC Sleeve/Port; 5.000; 3.450; 18,481.5; 2.29 5-36; Liner; 4.500; 3.958; 17,985.4; 496.14 5-35; FRAC Sleeve/Port; 5.000; 3.450; 17,983.1; 2.29 5-34; Liner; 4.500; 3.958; 17,488.3; 494.76 5-33; FRAC Sleeve/Port; 5.000; 3.450; 17,486.1; 2.29 5-32; Liner; 4.500; 3.958; 16,990.2; 495.82 5-31; FRAC Sleeve/Port; 5.000; 3.450; 16,988.0; 2.29 5-30; Liner; 4.500; 3.958; 16,451.8; 536.19 5-29; FRAC Sleeve/Port; 5.000; 3.450; 16,449.5; 2.28 5-28; Liner; 4.500; 3.958; 15,954.6; 494.86 5-27; FRAC Sleeve/Port; 5.000; 3.450; 15,952.3; 2.29 5-26; Liner; 4.500; 3.958; 15,456.7; 495.62 5-25; FRAC Sleeve/Port; 5.000; 3.450; 15,454.4; 2.29 5-24; Liner; 4.500; 3.958; 14,958.1; 496.27 5-23; FRAC Sleeve/Port; 5.000; 3.450; 14,955.9; 2.29 5-22; Liner; 4.500; 3.958; 14,460.9; 494.98 5-21; FRAC Sleeve/Port; 5.000; 3.450; 14,458.5; 2.33 5-20; Liner; 4.500; 3.958; 13,963.0; 495.58 5-19; FRAC Sleeve/Port; 5.000; 3.450; 13,960.7; 2.30 5-18; Liner; 4.500; 3.958; 13,465.1; 495.60 5-17; FRAC Sleeve/Port; 5.000; 3.450; 13,462.8; 2.30 5-16; Liner; 4.500; 3.958; 12,966.6; 496.12 5-15; FRAC Sleeve/Port; 5.000; 3.450; 12,964.4; 2.30 5-14; Liner; 4.500; 3.958; 12,468.2; 496.18 5-13; FRAC Sleeve/Port; 5.000; 3.450; 12,465.9; 2.29 5-12; Liner; 4.500; 3.958; 11,971.5; 494.36 5-11; FRAC Sleeve/Port; 5.000; 3.450; 11,969.2; 2.30 5-10; Liner; 4.500; 3.958; 11,431.6; 537.59 5-9; FRAC Sleeve/Port; 5.000; 3.450; 11,429.3; 2.30 5-8; Liner; 4.500; 3.958; 10,933.7; 495.68 5-7; FRAC Sleeve/Port; 5.000; 3.450; 10,931.4; 2.30 5-6; Liner - Pup; 4.530; 3.958; 10,911.4; 19.93 5-5; Liner; 4.500; 3.958; 9,548.5; 1,362.91 3-7; Shoe - Float; 7.625; 6.875; 9,682.2; 2.12 3-6; Casing; 7.625; 6.875; 9,596.0; 86.19 3-5; Collar - Float; 7.625; 6.875; 9,593.2; 2.83 3-4; Casing; 7.625; 6.875; 9,550.1; 43.04 5-4; Liner - Pup; 4.500; 3.958; 9,544.7; 3.80 5-3; XO Threads (Casing); 5.990; 3.900; 9,543.0; 1.69 5-2; Hanger; 6.440; 4.790; 9,533.7; 9.32 5-1; Nipple - RS; 6.050; 4.250; 9,511.3; 22.42 1-34; Mule Shoe; 4.500; 3.920; 9,514.0; 3.26 1-33; Pup Joint; 4.520; 3.920; 9,510.6; 3.43 1-32; Pup Joint; 5.630; 3.900; 9,508.7; 1.87 1-31; Pup Joint; 5.290; 3.900; 9,508.1; 0.67 1-30; Pup Joint; 4.500; 3.920; 9,498.0; 10.04 1-29; Sub - Ceramic disc; 4.500; 3.880; 9,496.2; 1.87 1-28; Tubing; 4.500; 3.958; 9,454.6; 41.51 1-27; Pup Joint; 4.500; 3.958; 9,444.5; 10.14 1-26; Nipple - DB; 4.500; 3.750; 9,442.9; 1.60 1-25; Pup Joint; 4.500; 3.958; 9,432.8; 10.14 1-24; Tubing; 4.500; 3.958; 9,349.8; 82.98 1-23; Pup Joint; 4.500; 3.906; 9,339.6; 10.15 1-22; PACKER; 6.880; 3.856; 9,334.2; 5.42 1-21; Pup Joint; 4.500; 3.896; 9,324.2; 10.06 1-20; Tubing; 4.500; 3.958; 9,241.2; 82.98 1-19; Tubing; 4.500; 3.902; 9,231.1; 10.07 1-18; Gauge / Pump Sensor; 4.500; 3.932; 9,226.9; 4.25 1-17; Tubing; 4.500; 3.902; 9,216.7; 10.14 3-3; Casing; 7.625; 6.765; 8,686.6; 863.50 1-16; Tubing; 4.500; 3.958; 7,689.3; 1,527.39 1-15; Pup Joint; 4.500; 3.958; 7,679.2; 10.13 1-14; Sleeve - Sliding; 4.500; 3.813; 7,674.3; 4.94 1-13; Pup Joint; 4.500; 3.958; 7,664.1; 10.14 1-12; Tubing; 4.500; 3.958; 3,867.2; 3,796.87 3-2; Casing; 7.625; 6.875; 39.2; 8,647.47 1-11; Pup Joint; 4.500; 3.958; 3,857.1; 10.14 1-10; Mandrel; 4.500; 3.865; 3,850.0; 7.07 1-9; Pup Joint; 4.500; 3.958; 3,839.9; 10.14 1-8; Tubing; 4.500; 3.958; 2,309.9; 1,529.99 2-5; Shoe - Float; 10.750; 9.875; 2,764.3; 2.40 2-4; Casing; 10.750; 9.950; 2,683.1; 81.17 2-3; Collar - Float; 10.750; 9.875; 2,680.0; 3.17 1-7; Pup Joint; 4.500; 3.958; 2,299.8; 10.14 1-6; Mandrel; 4.500; 3.865; 2,292.7; 7.07 1-5; Pup Joint; 4.500; 3.958; 2,282.9; 9.82 2-2; Casing; 10.750; 9.950; 77.9; 2,602.07 1-4; Tubing; 4.500; 3.958; 94.1; 2,188.82 1-3; Pup Joint; 4.500; 3.958; 88.3; 5.73 1-1; Casing Jts; 20.000; 18.500; 40.2; 79.80 1-2; Tubing; 4.500; 3.958; 41.1; 47.23 2-1; Casing - Surface; 10.750; 9.950; 40.2; 37.67 1-1; Hanger; 11.000; 3.900; 37.1; 4.02 3-1; Casing Hanger; 10.850; 6.860; 38.3; 0.82 KUP PROD 3S-719 ... WELLNAME WELLBORE3S-719 Page 1/6 3S-719 Report Printed: 9/24/2025 Well History API / UWI 5010320919 Legal WellName 3S-719 Field Name COYOTE Well Type Development Original KB/RT Elevation (ft) 64.60 Well Status PROD Daily Operations Start Date Legal WellName Last 24hr Sum AFE / RFE Rig Supervisor 9/21/2025 3S-719 REPLACED ST # 2 @ 3850' RKB W/ 1'' OV (5/16'' PORT) BK LATCH , OBTAIN PASSING 1500 PSI MITT , PULLED CATCHER @ 3877' RKB , PULL RBP @ 3880' RKB. READY FOR COIL. GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW MOORE, RYAN,Wells Supervisor 9/20/2025 3S-719 SET 1'' GLV (1/4'' PORT, 1485 TR ) BK LATCH IN ST #1 @ 2293' RKB. JOB IN PROGRESS. GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW MOORE, RYAN,Wells Supervisor 9/20/2025 3S-719 (MISC) TEST BPV TO 1500 PSI (PASS), POT-T (PASS), SWAP 10K FRAC TREE W/ 5K PRODUCTION TREE (COMPLETE), SHELL TEST PRODUCTION TREE TO 5K (PASSED) GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW RICHWINE, BRUCE,DHD Field Supervisor 9/19/2025 3S-719 DRIFT w/ BLB & 3.75'' G-RING BRUSH FROM 3837' RKB - 3937' RKB, LOCATE GLM ST#2 @ 2292' RKB (37' CORRECTION), SET RBP ME @ 3919' RKB, MIT-T TO 2500 PSI (GOOD TEST), TUBING & IA DDT TO 0 PSI (GOOD TEST), SET 4-1/2 CATCHER (38'' OAL) ON TOP RBP @ 3880' RKB, PULL 1'' DV IN ST#1 @ 2292' RKB. READY FOR TREE C/O. GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW MOORE, RYAN,Wells Supervisor 9/18/2025 3S-719 ARRIVE ON LOCATION TO SECURE WELL FOR TREE SWAP. SPOT IN UNIT AND SUPPORT EQUIPMENT. START MAKING UP LUBRICATOR. JOB IN PROGRESS. GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW MOORE, RYAN,Wells Supervisor 9/9/2025 3S-719 STIMULATE STAGE 19- 21 PER DESIGN w/ 9000 LBS OF 100 MESH & 1193761 LBS OF 16/20 PROPPANT UP TO 10 PPG, TOTAL JOB PROPPANT 1202761 LB, JOB CLEAN VOLUME PUMPED 7418 BBL (RESMETRICS TRACER ADDED PER SCHEDULE) DFIT PUMPED-CLOSURE 2615 PSI STAGES 19-21 PUMPED WITH FW GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor 9/8/2025 3S-719 STIMULATE STAGE 16- 18 PER DESIGN w/ 9000 LBS OF 100 MESH & 1195879 LBS OF 16/20 PROPPANT UP TO 10 PPG, TOTAL JOB PROPPANT 1204879 LB, JOB CLEAN VOLUME PUMPED 7195 BBL (RESMETRICS TRACER ADDED PER SCHEDULE) STAGES 16 - 18 PUMPED WITH FW GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor 9/7/2025 3S-719 STIMULATE STAGE 13- 15 PER DESIGN w/ 9000 LBS OF 100 MESH & 1198936 LBS OF 16/20 PROPPANT UP TO 10 PPG, TOTAL JOB PROPPANT 1207936 LB, JOB CLEAN VOLUME PUMPED 7512 BBL (RESMETRICS TRACER ADDED PER SCHEDULE) DFIT PUMPED WITH NO CLOSURE OBSERVED STAGE 13-15 PUMPED WITH FW GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor 9/6/2025 3S-719 STIMULATE STAGE 10 -12 PER DESIGN w/ 9000 LBS OF 100 MESH & 1198880 LBS OF 16/20 PROPPANT UP TO 10 PPG, TOTAL JOB PROPPANT 1207880 LB, JOB CLEAN VOLUME PUMPED 7450 BBL (RESMETRICS TRACER ADDED PER SCHEDULE) STAGES 10-12 PUMPED WITH FW GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor 9/5/2025 3S-719 STIMULATE STAGE 7- 9 PER DESIGN w/ 9000 LBS OF 100 MESH & 1197499 LBS OF 16/20 PROPPANT UP TO 10 PPG, TOTAL JOB PROPPANT 1206499 LB, JOB CLEAN VOLUME PUMPED 7682 BBL (RESMETRICS TRACER ADDED PER SCHEDULE) GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor 9/4/2025 3S-719 STIMULATE STAGE 5- 6 PER DESIGN w/ 6000 LBS OF 100 MESH & 805760 LBS OF 16/20 PROPPANT UP TO 10 PPG, TOTAL JOB PROPPANT 811760 LB, JOB CLEAN VOLUME PUMPED 5655 BBL (RESMETRICS TRACER ADDED PER SCHEDULE) STAGE 6-HALLIBURTON CHEMICAL ADDITIVE TRAILER HAD MECHANICAL ISSUE, HAD TO FLUSH WELL AND SHUT DOWN. MECHANIC ABLE TO REPAIR, COMPLETED STAGE. GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor Page 2/6 3S-719 Report Printed: 9/24/2025 Well History Daily Operations Start Date Legal WellName Last 24hr Sum AFE / RFE Rig Supervisor 9/3/2025 3S-719 PUMP INJECTION TEST @ 2.5 BPM AT 2300 PSI, 25 BBL DIESEL RIG UP DART LAUNCHER AND REVOLVER, BREAK DOWN IA/OA AND BLEED OFF LINES ON 3S-721 AND MOVE TO 719. TIE IN LINE TO TANKS. RIG UP 4" TREATING LINE AND TIE INTO GOAT HEAD, HANG STAND PIPE, TIE IN DART LAUNCH PUMP INTO EQUALIZATION LINE. RUN RESTRAINTS. BUMP UP SW TEMPS GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor 9/3/2025 3S-719 ***OPERATION CONTINUED FROM 02SEP25*** CONTINUE RIH W/ TTiX CONVEYED PERFORATING GUN. TAG SLEEVE AND/OR DART AT 18979'. LOG UP AND CORRELATE TO CASING TALLY AND TRACTOR BACK DOWN TAGGING UP AGAIN ON SLEEVE. USING TRIPLEX, PUMP DIESEL TO INCREASE TUBING PRESSURE TO 1670 PSI. PULL INTO POSITION AND PERFORATE INTERVAL. POSITIVE INDICATION OF SHOT FIRED - PRESSURE DROP FROM 1670 TO 1140 PSI, TENSION DROP FROM 1730 TO 1600 LBS. PERFORATED INTERVAL = 18954'-18964' CCL TO TOP SHOT = 16.1' CCL STOP DEPTH = 18937.9' ***JOB COMPLETE, READY FOR FRAC*** GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW CONNELLY, JEFF,Wells Supervisor 9/2/2025 3S-719 ***OPERATION CONTINUED FROM 01-SEP-25*** CONTINUE RIH W/ TTiX CONVEYED PERFORATING GUN, MIDNIGHT DEPTH = 18,800', DISTANCE TRACTORED = 9800'. ***OPERATION IN PROGRESS*** GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW CONNELLY, JEFF,Wells Supervisor 9/1/2025 3S-719 RIG UP SLB ELINE AND 3RD PARTY CRANE FOR TTIX CONVEYED PERF. RIH W/ TRACTORS AND 2.88 HSD LOADED 10' W/ S2906D RDX, 6 SPF, 60 DEG PHASE. FELL TO ~3000' RKB AT ~15 FPM, ENGAGE TRACTORS AND CONTINUE RIH, MIDNIGHT DEPTH = 9000', DISTANCE TRACTORED = 6000'. ***OPERATION IN PROGRESS*** GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW CONNELLY, JEFF,Wells Supervisor 8/27/2025 3S-719 RIG UP SLB ELINE AND 3RD PARTY CRANE TO SUPPORT FRAC OPERATIONS WITH TTiX CONVEYED PERFORATING GUN. DUE TO HIGHLY VISCOUS FRAC GEL, BEGIN TRACTORING FROM 2450'. ENCOUNTER HEAVY PICK UP WEIGHTS AND SLOW TRACTOR SPEEDS. DECISION MADE TO RDMO UNTIL FRAC GEL HAS TIME TO BREAK DOWN. GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW CONNELLY, JEFF,Wells Supervisor 8/26/2025 3S-719 MOB AND SPOT IN SLB ELINE UNIT AND 3RD PARTY CRANE. TRAVEL TO DEADHORSE TO COLLECT PERFORATING GUN AND ASSOCIATED M&S FOR PERFORATING RUN. GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW CONNELLY, JEFF,Wells Supervisor 8/26/2025 3S-719 STIMULATE STAGE 4 PER DESIGN w/ 3000 LBS OF 100 MESH & 398056 LBS OF 16/20 PROPPANT UP TO 10 PPG, TOTAL JOB PROPPANT 401056 LB, JOB CLEAN VOLUME PUMPED 2472 BBL (RESMETRICS TRACER ADDED PER SCHEDULE) STAGE 5 DART LANDING OBSERVED WITH NO SLEEVE SHIFT, PSI CAME UP TO 7369 PSI ON SURFACE AND BHP 9153 PSI. ATTEMPT TO BLEED OFF AND PUMP IN MULTIPLE TIMES WITH NO SLEEVE ACTIVATION SEEN. RIG DOWN LAUNCHER AND HARDLINE AROUND WELL IN PREPARATION FOR NEXT STEP GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor 8/25/2025 3S-719 STIMULATE STAGE 1, 3 PER DESIGN w/ 6000 LBS OF 100 MESH & 1123632 LBS OF 16/20 PROPPANT UP TO 10 PPG, TOTAL JOB PROPPANT 1129632 LB, JOB CLEAN VOLUME PUMPED 7336 BBL (PATINA AND RESMETRICS TRACERS ADDED PER SCHEDULE) STAGE 2 CUT SHORT 76834 LBS OF PROPPANT DUE TO HALLIBURTON EQUIPMENT SOFTWARE CRASHING, WELL FLUSHED, STAGED INTO DART DROP FOR INTERVAL 3 GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor 8/24/2025 3S-719 RIG UP DART LAUNCHER AND REVOLVER, SPOT/RIG UP IA AND BLEED OFF TANKS, RIG UP PRV SKID, IA/OA, HANG STAND PIPE, RIG UP DART LAUNCH EQUALIZATION LINE, RIG UP FRONT YARD IRON GKA.00529.W00 1.CO.IS;GKA.005 29.W001.CO.IF;G KA.00529.W001. CO.IW FAUR, DAN,Wells Supervisor Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 08/25/2025 Job End Date: 09/09/2025 State: Alaska County: Harrison Bay API Number: 50-103-20919-00-00 Operator Name:ConocoPhillips Company/Burlington Resources Well Name and Number: 3S-719 Latitude: 70.394403 Longitude: -150.194444 Datum: NAD27 Federal Well: NO Indian Well: NO True Vertical Depth: 4203 Total Base Water Volume (gal)*: 2184950 Total Base Non Water Volume: 0 Water Source Percent Surface Water, < 1000TDS 60.14% Other, > 1000TDS 39.86% Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Comments BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CarboLite 16/20 Carbo Ceramics Proppant CAT-3 ACTIVATOR Halliburton Activator Ceramic Proppant - Wanli Wanli Proppant Fresh Water Operator Base Fluid Legend LD- 6450 MultiChem Completion/Stimulation LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPT 2002- 2054 ResMetrics Tracer OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker Patina Energy Flow Insurance Copper Patina Energy Additive Sand- Common White-100 Mesh, SSA-2 Halliburton Proppant SEAWATER (SG 8.52)Operator Base Fluid WG-36 GELLING AGENT Halliburton Gelling Agent WPT 1001- 1052 ResMetrics Tracer Items above are Trade Names. Items below are the individual ingredients. Water 7732-18-5 100.00000 41.39113 None Ceramic materials and wares, chemicals 66402-68-4 100.00000 27.10925 Water 7732-18-5 95.00000 25.97735 None Corundum 1302-74-5 60.00000 2.13559 Mullite 1302-93-8 40.00000 1.42373 Sodium chloride 7647-14-5 5.00000 1.36723 None Crystalline silica, quartz 14808-60-7 100.00000 0.23165 Guar gum 9000-30-0 100.00000 0.22761 None Calcium chloride, dihyrate 10035-04-8 60.00000 0.05297 None Ethanol 64-17-5 60.00000 0.03849 None Monoethanolamine, boric acid salt 26038-87-9 100.00000 0.03732 None Heavy aromatic petroleum naphtha 64742-94-5 30.00000 0.01925 None Oxyalkylated nonyl phenolic resin Proprietary 30.00000 0.01925 None Sodium hydroxide 1310-73-2 30.00000 0.01381 None Ethylene glycol 107-21-1 30.00000 0.01120 None Ammonium persulfate 7727-54-0 100.00000 0.00944 None EDTA/Copper chelate Proprietary 30.00000 0.00838 None Oxyalkylated phenolic resin Proprietary 10.00000 0.00642 None Acrylamide sodium acrylate copolymer 25085-02-3 5.00000 0.00441 None Poly(oxy-1,2- ethanediyl), alpha-(4- nonylphenyl)-omega- hydroxy-, branched 127087-87- 0 5.00000 0.00321 None Naphthalene 91-20-3 5.00000 0.00321 None Oxylated phenolic resin Proprietary 30.00000 0.00283 None 2-Bromo-2- nitropropane-1,3-diol 52-51-7 100.00000 0.00148 None Ammonium chloride 12125-02-9 5.00000 0.00140 None 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00064 None Glycol Ether Proprietary 85.00000 0.00052 None Sodium chloride 7647-14-5 1.00000 0.00046 None Ammonia 7664-41-7 1.00000 0.00028 None Confidential Proprietary 20.00000 0.00019 None Proprietary Non- Hazardous Proprietary 100.00000 0.00016 None Ethylene glycol 107-21-1 20.00000 0.00013 None C.I. pigment Orange 5 3468-63-1 1.00000 0.00009 None Polymer Proprietary 0.10000 0.00009 None 2,7- Naphthalenedisulfonic acid, 3-hydroxy-4-(4- sulfor-1-naphthalenyl) azo -, trisodium salt 915-67-3 0.10000 0.00004 None * Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) Hydraulic Fracturing Fluid Product Component Information Disclosure 2025-08-25 Alaska 5010320919-00-00 CONOCOPHILLIPS 3S 719 -150.19759043 70.39409809 NAD83 none Oil 4206 2,184,950 Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Ingredient Mass lbs Comments Company First Name Last Name Email Phone SEAWATER (SG 8.52)Operator Base Fluid Density = 8.52 BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CAT-3 ACTIVATOR Halliburton Activator Legend LD-6450 MultiChem Completion/Stimulatio n LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker WG-36 GELLING AGENT Halliburton Gelling Agent Ceramic Proppant - Wanli Wanli Proppant Sand-Common White-100 Mesh, SSA-2 Halliburton Proppant CarboLite 16/20 Carbo Ceramics Proppant Fresh Water Operator Base Fluid OPT 2002-2054 ResMetrics Tracer Patina Energy Flow Insurance Copper Patina Energy Tracer WPT 1001-1052 ResMetrics Tracer Ingredients Water 7732-18-5 100.00%41.39113%11302914 Ceramic Materials and Wares, Chemicals 66402-68-4 100.00%27.10925%7402878 Water 7732-18-5 95.00%25.97735%7093784 Corundum 1302-74-5 60.00%2.13559%583179 Mullite 1302-93-8 40.00%1.42373%388786 Sodium chloride 7647-14-5 5.00%1.36723%373358 Crystalline silica, quartz 14808-60-7 100.00%0.23165%63258 Guar gum 9000-30-0 100.00%0.22761%62155 Calcium chloride, dihyrate 10035-04-8 60.00%0.05297%14465 Ethanol 64-17-5 60.00%0.03849%10511 Monoethanolamine borate 26038-87-9 100.00%0.03732%10191 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.01925%5256 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871- 6226 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.01925%5256 Sodium hydroxide 1310-73-2 30.00%0.01381%3772 Ethylene glycol 107-21-1 30.00%0.01120%3058 Ammonium persulfate 7727-54-0 100.00%0.00944%2579 EDTA/Copper chelate Proprietary 30.00%0.00838%2290 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Oxyalkylated phenolic resin Proprietary 10.00%0.00642%1752 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Copolymer of acrylamide and sodium acrylate 25085-02-3 5.00%0.00441%1206 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00321%876 Naphthalene 91-20-3 5.00%0.00321%876 Oxylated phenolic resin Proprietary 30.00%0.00283%774 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00148%405 Ammonium chloride 12125-02-9 5.00%0.00140%382 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00064%176 Glycol Ether Proprietary 85.00%0.00052%143 ResMetrics Product Stewardship info@resmetri cs.com 8325921900 Sodium chloride 7647-14-5 1.00%0.00046%126 Ammonia 7664-41-7 1.00%0.00028%77 Confidential Proprietary 20.00%0.00019%52 ResMetrics Product Stewardship info@resmetri cs.com 8325921900 Proprietary Non-Hazardous Proprietary 100.00%0.00016%45 Patina Energy Julie Harrish julie@patinae nergy.com 8327140836 Ethylene Glycol 107-21-1 20.00%0.00013%35 C.I. pigment Orange 5 3468-63-1 1.00%0.00009%26 Polymer Proprietary 0.10%0.00009%25 MultiChem Ana Djuric Ana.Djuric@ Halliburton.co m 281-871- 5747 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00004%11 * Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.5 All component information listed was obtained from the supplier’s Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this Production Type: True Vertical Depth (TVD): Total Water Volume (gal)*: MSDS and Non-MSDS Ingredients are listed below the green line Well Name and Number: Longitude: Latitude: Long/Lat Projection: Indian/Federal: Fracture Date State: County: API Number: Operator Name: information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Sales Order# Prepared By: Steven Sanders James Campbell Nanook Crew 910285054 Intervals 1-21 Coyote Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user’s own risk. 3S-719 Conoco Phillips Harrison Bay County, AK Post Job Report Stimulation Treatment API: 50-103-20919 Prepared for: Dan Faur September 9, 2025 Coyote Formation 27# & 30# Delta Frac Table of Contents Section Page(s) Executive Summary Actual Design Wellbore Information Interval Summary Fluid System-Proppant Summary Interval 1 Plots Interval 2 Plots Interval 3 Plots Interval 4 Plots Interval 5 Plots Interval 6 Plots Interval 7 Plots Interval 8 Plots Interval 9 Plots Interval 10 Plots Interval 11 Plots Interval 12 Plots Interval 13 Plots Interval 14 Plots Interval 15 Plots Interval 16 Plots Interval 17 Plots Interval 18 Plots Interval 19 Plots Interval 20 Plots Interval 21 Plots Appendix Planned Design Well Summary Chemical Summary Event Log 8.25 Event Log 8.26 Event Log 9.4 Event Log 9.5 Event Log 9.6 Event Log 9.7 Event Log 9.8 Event Log 9.9 Water Straps 8.25 Water Straps 8.26 Water Straps 9.4 Water Straps 9.5 Water Straps 9.6 Water Straps 9.7 Water Straps 9.8 Water Straps 9.9 Water Analysis 8.25 Water Analysis 8.26 Water Analysis 8.30 Water Analysis 9.5 Water Analysis 9.6 Water Analysis 9.7 Water Analysis 9.8 Water Analysis 9.9 Real-Time QC Prejob Break Test Fann 15 - Interval 1 Fann 15 - Interval 2 Fann 15 - Interval 3 Fann 15 - Interval 4 Fann 15 - Interval 5 Fann 15 - Interval 6 Fann 15 - Interval 7 Fann 15 - Interval 8 Fann 15 - Interval 9 Fann 15 - Interval 10 Fann 15 - Interval 11 Fann 15 - Interval 12 Fann 15 - Interval 13 Fann 15 - Interval 14 Fann 15 - Interval 15 127 - 135 103 - 106 107 - 110 111 - 118 119 - 122 123 - 126 140 - 143 136 - 139 4 5 - 9 10 67 - 70 71 - 78 79 - 90 11 - 52 53 54 - 62 63 - 66 91 - 94 95 - 102 144 - 151 152 - 155 156 - 159 160 - 168 169 - 172 173 - 176 177 178 - 182 183 184 185 186 187 188 189 190 191 192 193 194 195 196 197 198 199 200 201 202 203 204 205 206 207 208 209 210 211 212 213 214 215 216 217 218 219 220 221 222 223 224 225 Conoco Phillips - 3S-719 TOC 2 Fann 15 - Interval 16 Fann 15 - Interval 17 Fann 15 - Interval 18 Fann 15 - Interval 19 Fann 15 - Interval 20 Fann 15 - Interval 21 Sand Sieve Analysis 231 232 230 226 227 228 229 Conoco Phillips - 3S-719 TOC 3 829,190 gallons of 27# Delta Frac 80,718 gallons of 27# Linear 16,820 gallons of Seawater 1,264,430 gallons of 30# Delta Frac 117,184 gallons of 30# Linear 6,932,900 pounds of CarboLite 16/20 Ceramic 63,000 pounds of 100M 1,477,400 pounds of Wanli 16/20 Ceramic 790,851 gallons of 27# Delta Frac 82,466 gallons of 27# Linear 13,860 gallons of Seawater 1,233,298 gallons of 30# Delta Frac 115,857 gallons of 30# Linear 7,402,878 pounds of CarboLite 16/20 Ceramic 63,000 pounds of 100M 971,964 pounds of Wanli 16/20 Ceramic Thank you, Steven Sanders William Martin Senior Technical Professional Senior Technical Professional Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. Engineering Executive Summary On August 25, 2025 a stimulation treatment was performed in the Coyote formation on the 3S-719 well in Harrison Bay County, AK. The 3S-719 was a 21 stage Horizontal Sleeve Design. The proposed treatment consisted of: The actual treatment fully completed 20 of 21 stages. 0 stages were skipped, 0 stage screened out and 1 stages were cut short of design. The actual treatment consisted of: A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids. While pumping interval 02, an inssue with equipment software caused the Interval to be cut short. During interval 3, the sand type changed from Wanli 16/20 Ceramic to CarboLite 16/20 Ceramic. On 8/26, while seating the dart for interval 05, the sleeve did not shift. Pressure was bled off on surface six times while trying to shear the sleeve. Eline made an unsuccessful attempt to perforate the well; the crew then rigged down to move to another well. The crew rigged back up once Eline was able to perforate and create a flowpath for injection. During interval 6, the job had to be shut down in order to trouble shoot an issue with the Liquid Management System; the job was resumed and the interval completed. Starting with interval 9, the water changed from Seawater to Freshwater for the remainder of the job. The fluid system was changed to accomodate the freshwater; the system was based off of lab tests conducted in Prudhoe Bay as well as field confirmation testing on location. Conoco Phillips - 3S-719 Executive Summary 4 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDEBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In-1-2 Seawater Prime Up Pressure Test 5.0 1,000 756 18 180.151-3 Shut-In Shut-In-1-4 27# Linear DFIT 10.0 1,680 1,684 40 40 1.00 1.00 1.00 27.00 1.000.151-5 Shut-In Shut-In-1-6 27# Delta Frac Establish Stable Fluid 15.0 8,400 6,203 148 148 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-7 27# Delta Frac Pad 20.0 23,960 23,958 570 570 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-8 27# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,413 153 156 3,000 3,000 0.45 1.00 0.77 1.00 1.00 27.00 1.000.151-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20.0 5,150 4,566 109 109 10,300 6,644 0.45 1.00 0.75 1.00 1.00 27.00 1.000.151-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20.0 8,540 8,578 204 204 34,160 30,029 0.45 1.00 0.75 1.00 1.00 27.00 1.000.151-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20.0 8,260 8,085 193 193 49,560 45,135 0.45 1.00 0.75 1.00 1.00 27.00 1.000.151-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20.0 12,940 13,144 313 313 90,580 92,151 0.45 1.00 0.75 1.00 1.00 27.00 1.000.151-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20.0 11,600 11,434 272 272 92,800 95,221 0.45 1.00 0.75 1.00 1.00 27.00 1.000.151-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20.0 8,000 7,908 188 188 72,000 75,915 0.45 1.00 0.75 1.00 1.00 27.00 1.000.151-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20.0 5,060 6,175 147 147 50,600 52,573 0.45 1.00 0.75 1.00 1.00 27.00 1.000.151-16 27# Linear Spacer and Dart Drop 20.0 2,940 2,209 53 53 1.00 1.00 1.00 27.00 1.00 0.152-1 27# Linear Pre-Pad 20.0 2,100 2,426 58 58 1.00 1.00 1.00 27.00 1.000.152-2 27# Delta Frac Establish Stable Fluid 20.0 8,400 3,842 91 91 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-3 27# Delta Frac Pad 20.0 23,960 23,953 570 570 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-4 27# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,022 143 147 3,000 3,000 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20.0 5,150 5,178 123 123 10,300 9,828 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20.0 8,540 8,642 206 206 34,160 32,484 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20.0 8,260 8,351 199 199 49,560 47,823 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20.0 12,940 12,936 308 308 90,580 90,727 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20.0 11,600 11,459 273 273 92,800 96,303 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20.0 8,000 7,959 190 190 72,000 46,463 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20.0 5,060 - 50,600 0.45 1.00 0.75 1.00 1.00 27.00 1.000.152-12 27# Linear Spacer and Dart Drop 20.0 1,470 1,930 46 46 1.00 1.00 1.00 27.00 1.00 0.153-1 27# Linear Pre-Pad 20.0 2,100 2,100 50 50 1.00 1.00 1.00 27.00 1.000.153-2 27# Delta Frac Establish Stable Fluid 20.0 8,400 3,796 90 90 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-3 27# Delta Frac Pad 20.0 23,960 23,549 561 561 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-4 27# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 10,649 254 257 3,000 3,000 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20.0 5,150 5,958 142 142 10,300 14,154 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20.0 8,540 8,597 205 205 34,160 33,085 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20.0 8,260 8,340 199 199 49,560 48,314 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20.0 12,940 14,888 354 354 90,580 105,327 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20.0 11,600 9,518 227 227 92,800 77,619 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,940 189 267 72,000 73,147 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,217 148 200 50,600 48,912 0.45 1.00 0.75 1.00 1.00 27.00 1.000.153-12 27# Linear Flush 20.0 13,464 13,510 322 322 1.00 1.00 1.00 27.00 1.000.153-13 Seawater Freeze Protect 5.0 1,260 -0.153-14 Shut-In Shut-In-4-1 Seawater Prime Up Pressure Test 5.0 1,000 756 18 180.154-2 Shut-In Shut-In-4-3 27# Linear Spacer and Dart Drop 15.0 1,260 3,300 79 79 1.00 1.00 1.00 27.00 1.000.154-4 27# Delta Frac Establish Stable Fluid 20.0 8,400 6,115 146 146 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-5 27# Delta Frac Pad 20.0 23,960 23,972 571 571 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-6 27# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,108 145 149 3,000 3,000 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-7 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,224 124 131 10,300 6,666 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-8 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,631 206 240 34,160 32,750 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-9 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,363 199 250 49,560 47,570 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,963 309 404 90,580 89,997 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,620 277 375 92,800 92,957 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-12 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 8,063 192 267 72,000 70,301 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-13 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 8,021 191 252 50,600 57,815 0.45 1.00 0.60 1.00 1.00 27.00 1.000.154-14 27# Linear Spacer and Dart Drop 20.0 1,470 1,454 35 35 1.00 1.00 1.00 27.00 1.000.155-1 27# Linear Pre-Pad 20.0 2,100 2,100 50 50 1.00 1.00 1.00 27.00 1.000.155-2 27# Delta Frac Establish Stable Fluid 20.0 8,400 5,005 119 119 0.45 1.00 0.60 1.00 1.00 27.00 1.000.155-3 27# Delta Frac Pre-Pad 20.0 23,960 4,009 95 95 0.45 1.00 0.60 1.00 1.00 27.00 1.000.155-4 Seawater Prime Up Pressure Test 5.0 1,000 798 19 190.600.155-5 Shut-In Shut-In-5-6 27# Delta Frac Establish Stable Fluid 20.0 8,400 5,415 129 129 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-7 27# Delta Frac Pad 20.0 23,960 23,973 571 571 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-8 27# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,022 143 147 3,000 3,000 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-9 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,173 123 134 10,300 10,252 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,509 203 240 34,160 34,854 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,175 195 249 49,560 50,919 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-12 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,818 305 404 90,580 93,484 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-13 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,582 276 374 92,800 92,851 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-14 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,951 189 267 72,000 73,011 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-15 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,048 144 193 50,600 46,513 0.45 1.00 0.70 1.00 1.00 27.00 1.000.155-16 27# Linear Spacer and Dart Drop 20.0 1,470 2,912 69 69 1.00 1.00 1.00 27.00 1.00 0.1550-103-20919910285054Liquid AdditivesDry AdditivesInterval 1Coyote@ 21015.03 - 21019.03 ft 104.1 °FInterval 2Coyote@ 20471.68 - 20475.68 ft 104.1 °FInterval 3Coyote@ 19973.37 - 19977.37 ft 104.1 °FInterval 4Coyote@ 19477.91 - 19481.91 ft 104 °FInterval 5Coyote@ 18979.38 - 18983.38 ft 104 °FConoco Phillips - 3S-719Actual Design5 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDEBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)50-103-20919910285054Liquid AdditivesDry Additives6-1 27# Linear Pre-Pad 20.0 2,100 2,118 50 50 1.00 1.00 1.00 27.00 1.00 0.156-2 27# Delta Frac Establish Stable Fluid 20.0 8,400 7,801 186 186 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-3 27# Delta Frac Pad 20.0 23,960 23,976 571 571 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-4 27# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 5,991 143 146 3,000 3,000 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-5 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 6,512 155 167 10,300 11,722 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-6 27# Linear Flush 20.0 12,612 12,619 300 300 1.00 1.00 1.00 27.00 1.000.156-7 Shut-In Shut-In-6-8 27# Delta Frac Establish Stable Fluid 20.0 8,400 2,541 61 61 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-9 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,197 124 134 10,300 9,428 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 13,832 329 370 34,160 38,049 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,365 199 252 49,560 50,003 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-12 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 11,458 273 359 90,580 81,333.00 0.45 1.00 0.70 1.00 1.00 27.001.000.156-13 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,601 276 374 92,800 92,269 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-14 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,971 190 267 72,000 72,361 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-15 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,267 149 199 50,600 47,350 0.45 1.00 0.70 1.00 1.00 27.00 1.000.156-16 27# Linear Flush 20.0 12,612 12,542 299 299 1.00 1.00 1.00 27.00 1.000.156-17 Seawater Freeze Protect 5.0 1,260 1,260 30 300.156-18 Shut-In Shut-In-7-1 Seawater Prime Up Pressure Test 5.0 1,000 798 19 190.157-2 Shut-In Shut-In-7-3 27# Linear Spacer and Dart Drop 15.0 1,470 996 24 24 1.00 1.00 1.00 27.00 1.000.157-4 27# Linear Displacement 20.0 12,294 11,517 274 274 1.00 1.00 1.00 27.00 1.000.157-5 27# Linear DFIT 10.0 1,680 867 21 21 1.00 1.00 1.00 27.00 1.000.157-6 Shut-In Shut-In-7-7 27# Delta Frac Establish Stable Fluid 20.0 8,400 4,701 112 112 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-8 27# Delta Frac Pad 20.0 23,960 23,976 571 571 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-9 27# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 5,989 143 146 3,000 3,000 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,189 124 134 10,300 9,866 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,598 205 240 34,160 32,818 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-12 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,270 197 250 49,560 49,660 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-13 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,844 306 404 90,580 92,893 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-14 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,596 276 375 92,800 93,030 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-15 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 8,012 191 267 72,000 71,850 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-16 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,496 155 209 50,600 51,342 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-17 27# Linear Spacer and Dart Drop 20.0 2,898 2,918 69 69 1.00 1.00 1.00 27.00 1.000.158-1 27# Linear Pre-Pad 20.0 2,100 2,180 52 52 1.00 1.00 1.00 27.00 1.000.158-2 27# Delta Frac Establish Stable Fluid 20.0 8,400 5,225 124 124 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-3 27# Delta Frac Pad 20.0 23,960 23,963 571 571 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-4 27# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,018 143 147 3,000 3,000 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-5 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,187 124 134 10,300 9,855 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-6 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,617 205 240 34,160 32,472 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-7 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,315 198 250 49,560 48,762 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-8 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,989 309 405 90,580 90,005 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-9 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,556 275 375 92,800 93,610 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,984 190 267 72,000 72,750 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 5,796 138 191 50,600 49,630 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-12 27# Linear Spacer and Dart Drop 20.0 2,898 3,084 73 73 1.00 1.00 1.00 27.00 1.00 0.159-1 30# Linear Pre-Pad 20.0 2,100 2,249 54 54 1.00 1.00 30.00 1.25 0.159-2 30# Delta Frac Establish Stable Fluid 20.0 8,400 5,470 130 130 0.50 1.00 0.70 1.00 30.00 1.25 0.159-3 30# Delta Frac Pad 20.0 23,960 23,973 571 571 0.50 1.00 0.70 1.00 30.00 1.25 0.159-4 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 5,984 142 146 3,000 3,000 0.50 1.00 0.70 1.00 30.00 1.25 0.159-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,165 123 134 10,300 10,399 0.50 1.00 0.70 1.00 30.00 1.25 0.159-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,528 203 240 34,160 34,522 0.50 1.00 0.70 1.00 30.00 1.25 0.159-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,241 196 249 49,560 50,006 0.50 1.00 0.70 1.00 30.00 1.25 0.159-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,908 307 405 90,580 91,848 0.50 1.00 0.70 1.00 30.00 1.25 0.159-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,607 276 375 92,800 92,586 0.50 1.00 0.70 1.00 30.00 1.25 0.159-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,992 190 267 72,000 72,260 0.50 1.00 0.70 1.00 30.00 1.25 0.159-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 5,919 141 191 50,600 47,101 0.50 1.00 0.70 1.00 30.00 1.25 0.159-12 30# Linear Flush 20.0 11,658 11,642 277 277 1.00 1.00 30.00 1.25 0.159-13 Seawater Freeze Protect 5.0 1,260 1,260 30 300.159-14 Shut-In Shut-In-Interval 6Coyote@ 18481.54 - 18485.54 ft 104 °FInterval 7Coyote@ 17983.11 - 17987.11 ft 103.9 °FInterval 8Coyote@ 17486.06 - 17490.06 ft 103.9 °FInterval 9Coyote@ 16987.95 - 16991.95 ft 103.9 °FConoco Phillips - 3S-719Actual Design6 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDEBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)50-103-20919910285054Liquid AdditivesDry Additives10-1 Seawater Prime Up Pressure Test 5.0 1,000 798 19 190.1510-2 Shut-In Shut-In-10-3 30# Linear Spacer and Dart Drop 15.0 1,470 1,126 27 27 1.00 1.00 30.00 1.250.1510-4 30# Delta Frac Establish Stable Fluid 20.0 8,400 5,013 119 119 0.50 1.00 1.00 1.00 30.00 1.250.1510-5 30# Delta Frac Pad 20.0 23,960 23,967 571 571 0.50 1.00 2.00 1.00 30.00 1.250.1510-6 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 5,999 143 146 3,000 3,000 0.50 1.00 1.80 1.00 30.00 1.250.1510-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,174 123 134 10,300 10,230 0.50 1.00 1.00 1.00 30.00 1.250.1510-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,574 204 240 34,160 33,518 0.50 1.00 1.00 1.00 30.00 1.250.1510-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,321 198 249 49,560 48,255 0.50 1.00 1.00 1.00 30.00 1.250.1510-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,895 307 404 90,580 91,645 0.50 1.00 1.00 1.00 30.00 1.250.1510-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,629 277 375 92,800 92,141 0.50 1.00 1.00 1.00 30.00 1.250.1510-12 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,927 189 267 72,000 73,611 0.50 1.00 1.00 1.00 30.00 1.250.1510-13 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,196 148 201 50,600 50,664 0.50 1.00 1.00 1.00 30.00 1.250.1510-14 30# Linear Spacer and Dart Drop 20.0 2,268 2,230 53 53 1.00 1.00 30.00 1.250.1511-1 30# Linear Pre-Pad 20.0 2,100 2,243 53 53 1.00 1.00 30.00 1.250.1511-2 30# Delta Frac Establish Stable Fluid 20.0 8,400 6,139 146 146 0.50 1.00 1.00 1.00 30.00 1.250.1511-3 30# Delta Frac Pad 20.0 23,960 23,953 570 570 0.50 1.00 1.00 1.00 30.00 1.250.1511-4 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,006 143 146 3,000 3,000 0.50 1.00 1.00 1.00 30.00 1.250.1511-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,168 123 134 10,300 10,421 0.50 1.00 1.00 1.00 30.00 1.250.1511-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,633 206 240 34,160 32,319 0.50 1.00 1.00 1.00 30.00 1.250.1511-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,348 199 250 49,560 47,796 0.50 1.00 1.00 1.00 30.00 1.250.1511-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,927 308 405 90,580 91,158 0.50 1.00 1.00 1.00 30.00 1.250.1511-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,566 275 375 92,800 94,043 0.50 1.00 1.00 1.00 30.00 1.250.1511-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 8,006 191 267 72,000 71,913 0.50 1.00 1.00 1.00 30.00 1.250.1511-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,521 155 211 50,600 52,406 0.50 1.00 1.00 1.00 30.00 1.250.1511-12 30# Linear Spacer and Dart Drop 20.0 2,268 2,246 53 53 1.00 1.00 30.00 1.25 0.1512-1 30# Linear Pre-Pad 20.0 2,100 2,245 53 53 1.00 1.00 30.00 1.250.1512-2 30# Delta Frac Establish Stable Fluid 20.0 8,400 5,716 136 136 0.50 1.00 1.00 1.00 30.00 1.250.1512-3 30# Delta Frac Pad 20.0 23,960 23,966 571 571 0.50 1.00 1.00 1.00 30.00 1.250.1512-4 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,014 143 146 3,000 3,000 0.50 1.00 1.00 1.00 30.00 1.250.1512-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,153 123 134 10,300 10,341 0.50 1.00 1.00 1.00 30.00 1.250.1512-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,583 204 240 34,160 33,531 0.50 1.00 1.00 1.00 30.00 1.250.1512-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,322 198 249 49,560 48,035 0.50 1.00 1.00 1.00 30.00 1.250.1512-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,993 309 405 90,580 90,048 0.50 1.00 1.00 1.00 30.00 1.250.1512-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,566 275 375 92,800 93,614 0.50 1.00 1.00 1.00 30.00 1.250.1512-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,994 190 267 72,000 72,057 0.50 1.00 1.00 1.00 30.00 1.250.1512-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,240 149 202 50,600 50,530 0.50 1.00 1.00 1.00 30.00 1.250.1512-12 30# Linear Flush 20.0 10,678 10,702 255 255 1.00 1.00 30.00 1.250.1512-13 Seawater Freeze Protect 5.0 1,260 1,260 30 300.1512-14 Shut-In Shut-In-13-1 Seawater Prime Up Pressure Test 5.0 1,000 798 19 190.1513-2 Shut-In Shut-In-13-3 30# Linear Spacer and Dart Drop 15.0 1,260 896 21 21 1.00 1.00 30.00 1.250.1513-4 30# Linear Displace Dart to Seat 15.0 10,359 9,777 233 233 1.00 1.00 30.00 1.250.1513-5 30# Linear DFIT 10.0 840 869 21 21 1.00 1.00 30.00 1.250.1513-6 Shut-In Shut-In-13-7 30# Delta Frac Establish Stable Fluid 15.0 8,400 3,293 78 78 0.50 1.00 1.00 1.00 30.00 1.250.1513-8 30# Delta Frac Pad 20.0 23,960 23,976 571 571 0.50 1.00 1.40 1.00 30.00 1.250.1513-9 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,005 143 146 3,000 3,000 0.50 1.00 1.40 1.00 30.00 1.250.1513-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,161 123 134 10,300 10,395 0.50 1.00 1.40 1.00 30.00 1.250.1513-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,591 205 240 34,160 33,407 0.50 1.00 1.40 1.00 30.00 1.250.1513-12 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,286 197 249 49,560 48,915 0.50 1.00 1.40 1.00 30.00 1.250.1513-13 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,954 308 405 90,580 90,699 0.50 1.00 1.40 1.00 30.00 1.250.1513-14 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,514 274 375 92,800 94,980 0.50 1.00 1.40 1.00 30.00 1.250.1513-15 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,989 190 267 72,000 72,434 0.50 1.00 1.40 1.00 30.00 1.250.1513-16 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 5,863 140 191 50,600 48,211 0.50 1.00 1.40 1.00 30.00 1.250.1513-17 30# Linear Spacer and Dart Drop 20.0 2,268 2,287 54 54 1.00 1.00 30.00 1.250.1514-1 30# Linear Pre-Pad 20.0 2,100 2,333 56 56 1.00 1.00 30.00 1.250.1514-2 30# Delta Frac Establish Stable Fluid 20.0 8,400 4,937 118 118 0.50 1.00 1.40 1.00 30.00 1.250.1514-3 30# Delta Frac Pad 20.0 23,960 23,979 571 571 0.50 1.00 1.40 1.00 30.00 1.250.1514-4 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 5,996 143 146 3,000 3,000 0.50 1.00 1.40 1.00 30.00 1.250.1514-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,173 123 134 10,300 10,363 0.50 1.00 1.40 1.00 30.00 1.250.1514-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,592 205 240 34,160 33,397 0.50 1.00 1.40 1.00 30.00 1.250.1514-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,298 198 249 49,560 48,825 0.50 1.00 1.40 1.00 30.00 1.250.1514-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,958 309 404 90,580 90,265 0.50 1.00 1.40 1.00 30.00 1.250.1514-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,569 275 375 92,800 93,484 0.50 1.00 1.40 1.00 30.00 1.250.1514-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,938 189 267 72,000 73,601 0.50 1.00 1.40 1.00 30.00 1.250.1514-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,069 145 197 50,600 49,790 0.50 1.00 1.40 1.00 30.00 1.250.1514-12 30# Linear Spacer and Dart Drop 20.0 2,268 2,185 52 52 1.00 1.00 30.00 1.25 0.15Interval 10Coyote@ 16449.48 - 16453.48 ft 103.8 °FInterval 11Coyote@ 15952.33 - 15956.33 ft 103.8 °FInterval 12Coyote@ 15454.42 - 15458.42 ft 103.8 °FInterval 13Coyote@ 14955.86 - 14959.86 ft 103.9 °FInterval 14Coyote@ 14458.55 - 14462.55 ft 103.9 °FConoco Phillips - 3S-719Actual Design7 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDEBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)50-103-20919910285054Liquid AdditivesDry Additives15-1 30# Linear Pre-Pad 20.0 2,100 2,258 54 54 1.00 1.00 30.00 1.25 0.1515-2 30# Delta Frac Establish Stable Fluid 20.0 8,400 4,672 111 111 0.50 1.00 1.40 1.00 30.00 1.250.1515-3 30# Delta Frac Pad 20.0 23,960 23,963 571 571 0.50 1.00 1.40 1.00 30.00 1.250.1515-4 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,004 143 146 3,000 3,000 0.50 1.00 1.40 1.00 30.00 1.250.1515-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,152 123 134 10,300 10,423 0.50 1.00 1.40 1.00 30.00 1.250.1515-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,612 205 240 34,160 32,729 0.50 1.00 1.40 1.00 30.00 1.250.1515-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,343 199 249 49,560 47,705 0.50 1.00 1.40 1.00 30.00 1.250.1515-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,978 309 405 90,580 90,151 0.50 1.00 1.40 1.00 30.00 1.250.1515-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,659 278 375 92,800 91,742 0.50 1.00 1.40 1.00 30.00 1.250.1515-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,982 190 267 72,000 72,307 0.50 1.00 1.40 1.00 30.00 1.250.1515-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,659 159 217 50,600 55,061 0.50 1.00 1.40 1.00 30.00 1.250.1515-12 30# Linear Flush 20.0 9,723 9,747 232 232 1.00 1.00 30.00 1.250.1515-13 Seawater Freeze Protect 5.0 1,260 1,260 30 300.1515-14 Shut-In Shut-In-16-1 Seawater Prime Up Pressure Test 5.0 1,000 798 19 190.1516-2 Shut-In Shut-In-16-3 30# Linear Spacer and Dart Drop 15.0 1,260 903 22 22 1.00 1.00 30.00 1.250.1516-4 30# Linear Establish Stable Fluid 15.0 8,400 4,431 106 106 1.00 1.00 30.00 1.250.1516-5 30# Delta Frac Pad 20.0 23,960 23,965 571 571 0.50 1.00 1.10 1.00 30.00 1.250.1516-6 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,025 143 147 3,000 3,000 0.50 1.00 1.10 1.00 30.00 1.250.1516-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,154 123 134 10,300 10,259 0.50 1.00 1.10 1.00 30.00 1.250.1516-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,572 204 240 34,160 33,781 0.50 1.00 1.10 1.00 30.00 1.250.1516-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,288 197 249 49,560 49,089 0.50 1.00 1.10 1.00 30.00 1.250.1516-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,899 307 404 90,580 91,230 0.50 1.00 1.10 1.00 30.00 1.250.1516-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,532 275 375 92,800 94,399 0.50 1.00 1.10 1.00 30.00 1.250.1516-12 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,942 189 267 72,000 73,337 0.50 1.00 1.10 1.00 30.00 1.250.1516-13 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 5,813 138 188 50,600 46,386 0.50 1.00 1.10 1.00 30.00 1.250.1516-14 30# Linear Spacer and Dart Drop 20.0 2,268 2,208 53 53 1.00 1.00 30.00 1.250.1517-1 30# Linear Pre-Pad 20.0 2,100 2,348 56 56 1.00 1.00 30.00 1.250.1517-2 30# Delta Frac Establish Stable Fluid 20.0 8,400 3,633 87 87 0.50 1.00 1.10 1.00 30.00 1.250.1517-3 30# Delta Frac Pad 20.0 23,960 23,969 571 571 0.50 1.00 1.10 1.00 30.00 1.250.1517-4 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 5,987 143 146 3,000 3,000 0.50 1.00 1.10 1.00 30.00 1.250.1517-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,156 123 134 10,300 10,268 0.50 1.00 1.10 1.00 30.00 1.250.1517-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,586 204 240 34,160 33,456 0.50 1.00 1.10 1.00 30.00 1.250.1517-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,311 198 250 49,560 48,656 0.50 1.00 1.10 1.00 30.00 1.250.1517-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,951 308 404 90,580 90,456 0.50 1.00 1.10 1.00 30.00 1.250.1517-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,549 275 375 92,800 94,205 0.50 1.00 1.10 1.00 30.00 1.250.1517-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,925 189 267 72,000 73,872 0.50 1.00 1.10 1.00 30.00 1.250.1517-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 5,451 130 180 50,600 47,384 0.50 1.00 1.10 1.00 30.00 1.250.1517-12 30# Linear Spacer and Dart Drop 20.0 2,268 2,546 61 61 1.00 1.00 30.00 1.25 0.1518-1 30# Linear Pre-Pad 20.0 2,100 2,793 67 67 1.00 1.00 30.00 1.25 0.1518-2 30# Delta Frac Establish Stable Fluid 20.0 8,400 4,380 104 104 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-3 30# Delta Frac Pad 20.0 23,960 23,975 571 571 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-4 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 5,992 143 146 3,000 3,000 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,134 122 133 10,300 10,467 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,563 204 240 34,160 34,046 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,285 197 250 49,560 49,244 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,878 307 404 90,580 92,160 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,553 275 375 92,800 93,824 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,976 190 267 72,000 72,604 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 5,696 136 185 50,600 46,303 0.50 1.00 0.70 1.00 30.00 1.25 0.1518-12 30# Linear Flush 20.0 8,767 8,737 208 208 1.00 1.00 30.00 1.25 0.1518-13 Seawater Freeze Protect 5.0 1,260 1,260 30 300.1518-14 Shut-In Shut-In-19-1 Seawater Prime Up Pressure Test 5.0 1,000 798 19 190.1519-2 Shut-In Shut-In-19-3 30# Linear Spacer and Dart Drop 15.0 1,260 973 23 23 1.00 1.00 30.00 1.25 0.1519-4 30# Linear Displace Dart to Seat 15.0 7,644 7,952 189 189 1.00 1.00 30.00 1.25 0.1519-5 30# Linear DFIT 5.0 630 622 15 15 1.00 1.00 30.00 1.25 0.1519-6 Shut-In Shut-In-19-7 30# Delta Frac Establish Stable Fluid 20.0 8,400 3,497 83 83 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-8 30# Delta Frac Pad 20.0 23,960 23,968 571 571 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-9 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,023 143 147 3,000 3,000 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,186 123 134 10,300 9,878 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,624 205 240 34,160 32,558 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-12 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,361 199 250 49,560 47,517 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-13 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,946 308 404 90,580 90,456 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-14 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,621 277 375 92,800 92,611 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-15 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 7,993 190 267 72,000 72,213 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-16 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 7,296 174 231 50,600 53,870 0.50 1.00 0.60 1.00 30.00 1.25 0.1519-17 30# Linear Spacer and Dart Drop 20.0 1,470 2,190 52 52 1.00 1.00 30.00 1.25 0.15Interval 15Coyote@ 13960.67 - 13964.67 ft 103.9 °FInterval 18Coyote@ 12465.88 - 12469.88 ft 104.1 °FInterval 19Coyote@ 11969.22 - 11973.22 ft 104.1 °FInterval 17Coyote@ 12964.35 - 12968.35 ft 104 °FInterval 16Coyote@ 13462.77 - 13466.77 ft 104 °FConoco Phillips - 3S-719Actual Design8 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDEBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)50-103-20919910285054Liquid AdditivesDry Additives20-1 30# Linear Pre-Pad 20.0 2,100 2,210 53 53 1.00 1.00 30.00 1.25 0.1520-2 30# Delta Frac Establish Stable Fluid 20.0 8,400 3,901 93 93 0.50 1.00 0.60 1.00 30.00 1.250.1520-3 30# Delta Frac Pad 20.0 23,960 23,946 570 570 0.50 1.00 0.75 1.00 30.00 1.250.1520-4 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 6,043 144 147 3,000 3,000 0.50 1.00 1.00 1.00 30.00 1.250.1520-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,194 124 134 10,300 9,479 0.50 1.00 1.00 1.00 30.00 1.250.1520-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,645 206 240 34,160 32,169 0.50 1.00 1.00 1.00 30.00 1.250.1520-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,335 198 250 49,560 48,167 0.50 1.00 1.00 1.00 30.00 1.250.1520-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,975 309 404 90,580 89,956 0.50 1.00 1.00 1.00 30.00 1.250.1520-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,663 278 375 92,800 91,533 0.50 1.00 1.00 1.00 30.00 1.250.1520-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 8,005 191 267 72,000 72,084 0.50 1.00 1.00 1.00 30.00 1.250.1520-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,482 154 212 50,600 54,370 0.50 1.00 1.00 1.00 30.00 1.250.1520-12 30# Linear Spacer and Dart Drop 20.0 1,470 2,201 52 52 1.00 1.00 30.00 1.25 0.1521-1 30# Linear Pre-Pad 20.0 2,100 2,931 70 70 1.00 1.00 30.00 1.250.1521-2 30# Delta Frac Establish Stable Fluid 20.0 8,400 2,630 63 63 0.50 1.00 0.60 1.00 30.00 1.250.1521-3 30# Delta Frac Pad 20.0 23,960 23,960 570 570 0.50 1.00 0.60 1.00 30.00 1.250.1521-4 30# Delta Frac Conditioning Pad 100M 0.50 20.0 6,000 5,988 143 146 3,000 3,000 0.50 1.00 0.60 1.00 30.00 1.250.1521-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20.0 5,150 5,180 123 134 10,300 9,678 0.50 1.00 0.60 1.00 30.00 1.250.1521-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20.0 8,540 8,667 206 240 34,160 32,007 0.50 1.00 0.60 1.00 30.00 1.250.1521-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20.0 8,260 8,320 198 249 49,560 48,339 0.50 1.00 0.60 1.00 30.00 1.250.1521-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20.0 12,940 12,921 308 404 90,580 91,179 0.50 1.00 0.60 1.00 30.00 1.250.1521-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20.0 11,600 11,592 276 374 92,800 92,709 0.50 1.00 0.60 1.00 30.00 1.250.1521-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20.0 8,000 8,041 191 267 72,000 71,065 0.50 1.00 0.60 1.00 30.00 1.250.1521-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20.0 5,060 6,694 159 215 50,600 52,652 0.50 1.00 0.60 1.00 30.00 1.250.1521-12 30# Linear Flush 20.0 7,787 7,777 185 185 1.00 1.00 30.00 1.250.1521-13 Seawater Freeze Protect 5.0 1,260 1,260 30 300.1521-14 Shut-In Shut-In-2,308,342 2,236,332 53,246 61,076 8,473,300 8,371,650Design Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-II BE-6829,190 790,851 6,932,900 7,308,855 7,402,878(gal) (gal) (gal) (gal) (gal) (lbs) (lbs)(lbs)80,718 82,466 63,000 63,000 63,000 Initial Design Material Volume 1,005.4 2,291.5 1,682.9 909.9 2,291.5 66,015.9 2,636.9346.316,820 13,860 1,477,400 999,795 971,964 Actual Design Material Volume 972.5 2,222.5 1,802.8 873.3 2,222.5 64,054.2 2,559.8335.4- - - Physical Material Volume Pumped 1,003 2,305 1880 915 2,253 62155 2,5794051,264,430 1,233,298 - - - Physical Material Volume Deviance 3% 4% 4% 5% 1% -3% 1%21%117,184 115,857** IFS numbers for proppant are taken from software calculations based on multiple variablesMicroMotion Volume Pumped 1,034 2,301 1,883 916 2,095 61,469 2,648 ---** Proppant is billed from Weight Ticket volumesMicroMotion Volume Deviance 6% 4% 4% 5% -6% -4% 3% ----Fluid Type27# Delta Frac27# LinearSeawaterFreeze Protect30# Delta FracProppant TypearboLite 16/20 Ceram100MWanli 16/20 Ceramic-Interval 20Coyote@ 11429.33 - 11433.33 ft 104.1 °FInterval 21Coyote@ 10931.35 - 10935.35 ft 104 °F30# Linear--Conoco Phillips - 3S-719Actual Design9 Conoco Phillips Coyote3S-71950-103-20919*Exceeds 80% of burst pressure*Description OD (in) ID (in) Wt (#) GradeFUF (gal/ft) MD Top (ft) MD Btm (ft) Volume (gal)Tubular Burst Pressure (psi)Tubing4.5 3.958 12.6 L-80 0.6392 - 21,123 13,502 8,430Tubing4.5 3.958 12.6 L-80 0.6392 21,123.00 0 8,430Total21,12313,502ft1.05ft105.0ftft1.05ft104.1ft Top MD (ft) Btm MD (ft)Average TVD (ft)Interval #Formation DescriptorAverage Interval Temperature (F)Ball Drop Time (HH:MM)Ball Hit Time (HH:MM)JSV Drop (bbl)JSV Slow Down (bbl)JSV Hit (bbl)Early (bbl)Surface Seat Pressure (psi)Surface Peak Pressure (psi)Surface Differential (psi)BH Seat Pressure (psi)BH Peak Pressure (psi)BH Differential (psi)Rate at Shift (bpm)Toe21015.0 21019.0 4,2021Coyote104.1alpha alpha alpha alpha alpha alpha alpha alpha alpha alpha alpha alpha alpha20471.7 20475.7 4,1982Coyote104.111:56:40 AM 12:12:53 PM 2,819 3,081 3,10525.62,410 5,166 2,756 3,366 5,899 2,533 14.619973.4 19977.4 4,1963Coyote104.12:07:03 PM 2:22:13 PM 5,375 5,629 5,65722.02,703 5,795 3,092 3,380 6,292 2,912 14.619477.9 19481.9 4,1944Coyote104.08:14:09 AM 8:32:44 AM 28 274 31014.42,813 5,527 2,714 3,430 6,255 2,825 15.018979.4 18983.4 4,1905Coyote104.010:42:29 AM 10:55:03 AM 2,901 3,140 3,16326.82,637 7,369 4,732 7,964 9,153 1,189 20.918481.5 18485.5 4,1876Coyote104.012:33:28 PM 12:47:17 PM 2,782 3,013 3,05013.32,359 5,379 3,020 3,188 6,119 2,931 15.017983.1 17987.1 4,1837Coyote103.98:12:14 AM 8:29:10 AM 18 242 27417.71,692 4,426 2,734 3,060 5,687 2,627 15.317486.1 17490.1 4,1808Coyote103.911:24:49 AM 11:37:48 AM 3,100 3,316 3,34818.12,163 5,233 3,070 3,045 6,139 3,094 14.516988.0 16992.0 4,1769Coyote103.91:48:34 PM 2:01:09 PM 5,936 6,145 6,17915.52,333 5,487 3,154 3,099 5,811 2,712 14.616449.5 16453.5 4,17310Coyote103.87:57:42 AM 8:13:52 AM 20 220 2637.32,793 5,597 2,804 3,068 6,083 3,015 14.915952.3 15956.3 4,17311Coyote103.810:23:26 AM 10:34:56 AM 2,846 3,039 3,07216.82,228 5,058 2,830 3,086 5,829 2,743 15.115454.4 15458.4 4,17612Coyote103.812:47:26 PM 12:58:40 PM 5,713 5,898 5,93216.22,171 5,253 3,082 2,999 5,644 2,645 15.014955.9 14959.9 4,17913Coyote103.97:52:48 AM 8:07:15 AM 17 195 23410.61,520 4,533 3,013 2,902 5,461 2,559 15.114458.6 14462.6 4,18314Coyote103.910:59:20 AM 11:09:48 AM 2,992 3,162 3,19418.02,090 4,888 2,798 2,996 5,498 2,502 14.813960.7 13964.7 4,18615Coyote103.91:20:34 PM 1:30:43 PM 5,808 5,970 6,00416.52,056 6,745 4,689 3,067 7,374 4,307 14.713462.8 13466.8 4,18916Coyote104.07:34:35 AM 7:47:48 AM 19 174 2158.92,313 5,269 2,956 2,919 5,750 2,831 14.612964.4 12968.4 4,19317Coyote104.09:56:20 AM 10:05:50 AM 2,761 2,908 2,94216.32,109 5,482 3,373 3,010 6,000 2,990 14.712465.9 12469.9 4,19718Coyote104.112:16:27 PM 12:25:33 PM 5,538 5,678 5,71314.72,315 5,613 3,298 3,037 6,069 3,032 14.711969.2 11973.2 4,20019Coyote104.17:47:32 AM 7:58:59 AM 19 151 19011.21,638 4,971 3,333 2,989 5,819 2,830 15.011429.3 11433.3 4,20220Coyote104.110:43:57 AM 10:52:27 AM 2,986 3,110 3,14514.91,903 4,951 3,048 2,984 5,738 2,754 14.4Heel10931.4 10935.4 4,19321Coyote104.01:06:14 PM 1:14:46 PM 5,790 5,906 5,9497.42,068 6,149 4,081 2,857 6,796 3,939 14.7204.9197.3189.7182.2173.9273.7266.1258.5250.3242.8235.2166.48,2877,9687,6517,3066,9879,8789,5609,2428,9248,60511,49511,17710,85910,51510,19712,767304.012,45012,13211,813Displacement to Top Sleeve/Perf (gal)(BBLS)13,433319.813,085311.6296.4288.8281.3Interval #1Max Pressure (psi)8,500Isolation TypeCemented LinerTreatment TubularsCustomerFormationLeaseAPIDateTemperature DataTemp. Gradient (°F/100 ft)BHST (°F)Directional Data4,1882,23721,123Directional Data2,2378/25/2025KOPTemperature DataSleeve/Perf DepthSleeves227.6220.0212.578910112345617181920211213141516Temp. Gradient (°F/100 ft)BHST (°F)TVD at Bottom PerfMD at Bottom Perf4,20221,019KOPAvg. TVDTotal MDConoco Phillips - 3S-719 Wellbore Information10 8/25/25 8:50 8/25/25 11:56 187 min alpha bpm alpha psi alpha psi alpha bbl 21.1 bpm 4,146 psi 4,820 psi 19.7 bpm 3,491 psi 3,228 psi 4,298 psi 1,684 hhp 512 psi 0 psi 741 psi 11.19 ppg 6 6 34 % 34 % 21 cP 82 F 8.8 DFIT 6.711 bpm 2069 psi 3478 psi 10.56 bpm 2542 psi 3880 psi 2615 psi 0.622 psi/ft 2581 psi 2548 psi 2505 psi 3,000 lbs 397,668 lbs 400,668 lbs 400,668 lbs Total Proppant Pumped* : Proppant Summary Minifrac Average Pressure: Minifrac Average DH Pressure: Average Visc: Average Temp: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Interval Summary 3S-719 - Coyote - Interval 1 Interval Summary Start Date/Time: End Date/Time: Average Surface Pressure: Average Rate: Max OA Pressure: Pumps Starting Stage: Pad Percentage Design Average Missile HHP: Initial BH Pressure (Breakdown): Average BH Pressure: Pumps Ending Stage: Max Proppant Concentration: Pump Time: ISDP: Final Fracture Gradient: Final 10 min: Minifrac Max Surface Pressure: 100M Pumped: Final 15 min: Proppant in Formation: Minifrac Max DH Pressure: Final 5 min: Dart/Ball Early : Average pH: Minifrac Average Rate: Pad Percentage Actual Wanli 16/20 Ceramic Pumped: Diagnostic method Average Missile Pressure: Minifrac Max Rate: Open Well Pressure: Initial OA Pressure: Conoco Phillips - 3S-719 Interval Summary 11 4,146 96,464 gal 2,297 bbls 3,893 gal 93 bbls 756 gal 18 bbls 756 gal 18 bbls 23,958 gal 570 bbls 6,413 gal 153 bbls 59,890 gal 1,426 bbls 2,209 gal 53 bbls 6,203 gal 148 bbls 1,684 gal 40 bbls 101,250 gal 2,411 bbls 101,113 gal 2,407 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep:Dan Faur William Martin Treatment Slurry Volume (Calculated): Total Clean Fluid Volume: Prime Up Pressure Test Fluid Summary (by fluid description) Fluid Summary (by stage description) Establish Stable Fluid Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Spacer and Dart Drop Volume: Interval Status: Cody Strong Derek Osselburn Prior to frac rigging up, the arsenal disk and alpha sleeve was opened. A DFIT was pumped and pressure decline monitored for 40 minutes. Closure was found to be 2,476 psi on the downhole gauge. There was an abnormal pressure increase after resuming pumping for the main treatment. The interval was pumped to completion. DFIT Volume: Madeline Woodard Conditioning Pad Volume: Proppant Laden Fluid Volume: Pad Volume: 27# Delta Frac Volume: 27# Linear Volume: Seawater Volume: Conoco Phillips - 3S-719 Interval Summary 12 8/25/25 11:56 8/25/25 14:07 130 min 14.6 bpm 5,166 psi 5,899 psi 26 bbl 21.0 bpm 4,500 psi 4,876 psi 19.8 bpm 3,565 psi 3,300 psi 4,265 psi 1,729 hhp 739 psi 746 psi 9.92 ppg 6 5 34 % 36 % 20 cP 86 F 8.7 3,000 lbs 323,628 lbs 326,628 lbs 326,628 lbs 100M Pumped: Total Proppant Pumped* : Wanli 16/20 Ceramic Pumped: Proppant Summary Interval Summary Start Date/Time: End Date/Time: Pump Time: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Dart/Ball Early : Max Rate: Max Surface Pressure: Max BH Pressure: Average Rate: Average Missile Pressure: Average Surface Pressure: 3S-719 - Coyote - Interval 2 Average BH Pressure: Average Missile HHP: Initial OA Pressure: Max OA Pressure: Max Proppant Concentration: Pumps Starting Stage: Pumps Ending Stage: Average Visc: Average Temp: Average pH: Pad Percentage Design Pad Percentage Actual Proppant in Formation: Conoco Phillips - 3S-719 Interval Summary 13 5,166 88,342 gal 2,103 bbls 4,356 gal 104 bbls 2,426 gal 58 bbls 23,953 gal 570 bbls 6,022 gal 143 bbls 54,525 gal 1,298 bbls 1,930 gal 46 bbls 3,842 gal 91 bbls 92,835 gal 2,210 bbls 92,698 gal 2,207 bbls Cut Short Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Status: During 8 ppg proppant, pump 454 was neutralled for valves and seats. During 9 ppg, ACE 1 stopped reading. In prior experiences, when ACE 1 is rebooted it neutrals the pumps, the decision was made to cut screws on the blender before rebooting ACE. ACE 1 was resumed without issue and the stage was marked "cut short" and the dart loaded and dropped for interval 3. *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number.Dan Faur Treatment Slurry Volume (Calculated): Total Clean Fluid Volume: William Martin Cody Strong Derek Osselburn Madeline Woodard 27# Delta Frac Volume: 27# Linear Volume: Conditioning Pad Volume: Proppant Laden Fluid Volume: Spacer and Dart Drop Volume: Establish Stable Fluid Volume: Fluid Summary (by fluid description) Fluid Summary (by stage description) Pre-Pad Volume: Pad Volume: Conoco Phillips - 3S-719 Interval Summary 14 8/25/25 14:07 8/25/25 16:47 160 min 14.6 bpm 5,795 psi 6,292 psi 22 bbl 21.1 bpm 4,240 psi 4,788 psi 20.0 bpm 3,624 psi 3,383 psi 4,369 psi 1,776 hhp 700 psi 746 psi 10.70 ppg 5 5 32 % 34 % 20 cP 85 F 8.7 2624 psi 0.625 psi/ft 2604 psi 2592 psi 2584 psi 122,059 lbs 3,000 lbs 278,499 lbs 403,558 lbs 403,558 lbs Total Proppant Pumped* : Proppant in Formation: 3S-719 - Coyote - Interval 3 End Date/Time: Max BH Pressure: Average Rate: Initial BH Pressure (Breakdown): Dart/Ball Early : Max Rate: Max Surface Pressure: Pump Time: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Start Date/Time: Pad Percentage Design Pad Percentage Actual Final Fracture Gradient: Average Visc: Initial OA Pressure: ISDP: Average Missile HHP: Average Temp: Average Missile Pressure: Average Surface Pressure: Average BH Pressure: Pumps Starting Stage: Pumps Ending Stage: Average pH: Final 5 min: Wanli 16/20 Ceramic Pumped: 100M Pumped: Max OA Pressure: Max Proppant Concentration: Interval Summary CarboLite 16/20 Ceramic Pumped: Proppant Summary Final 10 min: Final 15 min: Conoco Phillips - 3S-719 Interval Summary 15 5,795 99,452 gal 2,368 bbls 15,610 gal 372 bbls 2,100 gal 50 bbls 23,549 gal 561 bbls 10,649 gal 254 bbls 61,458 gal 1,463 bbls 13,510 gal 322 bbls 3,796 gal 90 bbls 120,643 gal 2,872 bbls 115,062 gal 2,740 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Establish Stable Fluid Volume: 27# Delta Frac Volume: William Martin Cody Strong Derek Osselburn Treatment Slurry Volume (Calculated): Interval Status: During 7 ppg proppant, a new schedule was loaded into Octiv which caused the stage count to restart and the screw to momentarily stop. They were immediatley turned back on but the proppant concentration dropped to 4 ppg before going back to design. Stage pumped to completion. *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Fluid Summary (by fluid description) Proppant Laden Fluid Volume: Flush Volume: Madeline Woodard Dan Faur Fluid Summary (by stage description) Pre-Pad Volume: Conditioning Pad Volume: 27# Linear Volume: Pad Volume: Total Clean Fluid Volume: Conoco Phillips - 3S-719 Interval Summary 16 8/26/25 8:06 8/26/25 10:42 156 min 15.0 bpm 5,527 psi 6,255 psi 14 bbl 21.1 bpm 3,844 psi 4,454 psi 20.1 bpm 3,582 psi 3,365 psi 4,256 psi 1,766 hhp 544 psi 262 psi 440 psi 9.99 ppg 6 6 34 % 27 % 22 cP 81 F 8.77 398,056 lbs 3,000 lbs 401,056 lbs 401,056 lbs Max BH Pressure: Proppant Summary CarboLite 16/20 Ceramic Pumped: Total Proppant Pumped* : Pad Percentage Design Average Surface Pressure: Pumps Starting Stage: 100M Pumped: Max OA Pressure: Max Proppant Concentration: Average Visc: Average Temp: Average pH: Initial OA Pressure: Initial Surface Pressure (Breakdown): End Date/Time: Pump Time: 3S-719 - Coyote - Interval 4 Interval Summary Start Date/Time: Initial BH Pressure (Breakdown): Open Well Pressure: Dart/Ball Early : Max Rate: Average Rate: Average Missile Pressure: Average BH Pressure: Average Missile HHP: Pumps Ending Stage: Pad Percentage Actual Initial Rate (Breakdown): Proppant in Formation: Max Surface Pressure: Conoco Phillips - 3S-719 Interval Summary 17 5,527 99,080 gal 2,359 bbls 4,754 gal 113 bbls 756 gal 18 bbls 756 gal 18 bbls 23,972 gal 571 bbls 6,108 gal 145 bbls 62,885 gal 1,497 bbls 4,754 gal 113 bbls 6,115 gal 146 bbls 122,480 gal 2,916 bbls 104,590 gal 2,490 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Madeline Woodard Dan Faur William Martin Cody Strong During 7+ ppg sand stages, proppant concentration fluctuated due to wet sand in the hopper due to rainy weather on location. Interval pumped to completion. Derek Osselburn Pad Volume: Conditioning Pad Volume: Treatment Slurry Volume (Calculated): Proppant Laden Fluid Volume: Fluid Summary (by stage description) Establish Stable Fluid Volume: Total Clean Fluid Volume: Interval Status: Prime Up Pressure Test 27# Linear Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Fluid Summary (by fluid description) Seawater Volume: Spacer and Dart Drop Volume: 27# Delta Frac Volume: Conoco Phillips - 3S-719 Interval Summary 18 9/4/25 9:55 9/4/25 12:33 158 min 20.9 bpm 7,369 psi 9,153 psi 27 bbl 20.7 bpm 3,789 psi 4,422 psi 19.7 bpm 3,533 psi 3,320 psi 4,165 psi 1,706 hhp 866 psi 670 psi 694 psi 9.63 ppg 6 6 28 % 28 % 23.33 cP 93 F 8.77 401,884 lbs 3,000 lbs 404,884 lbs 404,884 lbs End Date/Time: Max BH Pressure: Average Surface Pressure: Interval Summary Proppant Summary CarboLite 16/20 Ceramic Pumped: 100M Pumped: 3S-719 - Coyote - Interval 5 Average BH Pressure: Initial OA Pressure: Max Proppant Concentration: Start Date/Time: Pad Percentage Design Average Rate: Proppant in Formation: Average Missile HHP: Open Well Pressure: Average Visc: Max Surface Pressure: Average pH: Pad Percentage Actual Pump Time: Pumps Starting Stage: Pumps Ending Stage: Average Missile Pressure: Max OA Pressure: Initial BH Pressure (Breakdown): Dart/Ball Early : Average Temp: Initial Surface Pressure (Breakdown): Max Rate: Total Proppant Pumped* : Initial Rate (Breakdown): Conoco Phillips - 3S-719 Interval Summary 19 7,369 3,789 104,680 gal 2,492 bbls 5,012 gal 119 bbls 798 gal 19 bbls 798 gal 19 bbls 6,109 gal 145 bbls 23,973 gal 571 bbls 6,022 gal 143 bbls 60,256 gal 1,435 bbls 2,912 gal 69 bbls 10,420 gal 248 bbls 128,551 gal 3,061 bbls 110,490 gal 2,631 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Fluid Summary (by fluid description) Fluid Summary (by stage description) Treatment Slurry Volume (Calculated): Conditioning Pad Volume: 27# Linear Volume: Seawater Volume: Pad Volume: Prime Up Pressure Test Steven Sanders *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Rodrigo Ruysschaert Dan Faur James Campbell Total Clean Fluid Volume: Craig Karpinski On 8/26, while seating the dart for interval 05, the sleeve did not shift. Pressure was bled off on surface six times and while trying to shear the sleeve. Crew rigged down and moved to another well after wireline had an unsuccessful run when tyring to perforate. On 9/3 wireline was able to perforate at depths 18,954' and 18,964'. Upon restarting interval 5, during the Establish Stable Fluid stage, OctivConnect was not reading rate so the job was shut down. The instrument skid in OctivConnect was changed and the job resumed; HES NPT 11 minutes. While pumping the sand stages, pump 454 had two minor rate fluctuations due to cavitation. Establish Stable Fluid Volume: 27# Delta Frac Volume: Spacer and Dart Drop Volume: Pre-Pad Volume: Proppant Laden Fluid Volume: Interval Status: Conoco Phillips - 3S-719 Interval Summary 20 9/4/25 12:33 9/4/25 16:28 235 min 15.0 bpm 5,379 psi 6,119 psi 13 bbl 21.1 bpm 3,576 psi 4,232 psi 19.1 bpm 3,093 psi 2,888 psi 3,915 psi 1,449 hhp 697 psi 712 psi 10.20 ppg 6 6 27 % 25 % 24.33 cP 90.2 F 8.86 2622 psi 0.626 psi/ft 2617 psi 2602 psi 2591 psi 402,515 lbs 3,000 lbs 405,515 lbs 405,515 lbs Pump Time: Initial Rate (Breakdown): Average Missile HHP: 3S-719 - Coyote - Interval 6 Interval Summary Average pH: Final 5 min: Final 10 min: Proppant Summary Pumps Starting Stage: Max Rate: Average Missile Pressure: ISDP: Average Rate: Proppant in Formation: Average Visc: Average Surface Pressure: Average BH Pressure: 100M Pumped: Pumps Ending Stage: CarboLite 16/20 Ceramic Pumped: Pad Percentage Design Average Temp: Total Proppant Pumped* : Final Fracture Gradient: Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Dart/Ball Early : Final 15 min: End Date/Time: Max Surface Pressure: Max BH Pressure: Max OA Pressure: Max Proppant Concentration: Pad Percentage Actual Initial OA Pressure: Start Date/Time: Conoco Phillips - 3S-719 Interval Summary 21 5,379 3,576 111,512 gal 2,655 bbls 27,279 gal 650 bbls 1,260 gal 30 bbls 2,118 gal 50 bbls 23,976 gal 571 bbls 5,991 gal 143 bbls 71,203 gal 1,695 bbls 25,161 gal 599 bbls 1,260 gal 30 bbls 10,342 gal 246 bbls 158,140 gal 3,765 bbls 140,051 gal 3,335 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Fluid Summary (by fluid description) Fluid Summary (by stage description) Establish Stable Fluid Volume: Freeze Protect Volume: Treatment Slurry Volume (Calculated): Pre-Pad Volume: Conditioning Pad Volume: Interval Status: Flush Volume: Pad Volume: While pumping 2ppg, the batteries on the LMS started smoking so the sand screws were cut and the well was flushed. The batteries were replaced and the job was resumed. A total of 17,220 gallons were designated as Poor Quality Fluid. The job design was changed to take out the sand pumped during the 2ppg stage, ~12,000 lbs, from the 7 ppg stage. When starting back on sand, the sand screws were still filled with sand and were struggling with siezing up. The hopper was emptied to allow the screws to clear out fully before resuming the 4 ppg sand stage. Steven Sanders Craig Karpinski James Campbell *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Rodrigo Ruysschaert Dan Faur Proppant Laden Fluid Volume: Seawater Volume: Total Clean Fluid Volume: 27# Delta Frac Volume: 27# Linear Volume: Conoco Phillips - 3S-719 Interval Summary 22 9/5/25 8:10 9/5/25 11:24 195 min 15.3 bpm 4,426 psi 5,687 psi 18 bbl 20.5 bpm 3,311 psi 4,116 psi 19.5 bpm 3,047 psi 2,885 psi 3,839 psi 1,456 hhp 619 psi 673 psi 694 psi 10.70 ppg 6 6 28 % 28 % 23 cP 86 F 8.8 DFIT 9.900 bpm 1627 psi 3122 psi 10 bpm 1707 psi 3193 psi 2425 psi 0.580 psi/ft 401,459 lbs 3,000 lbs 404,459 lbs 404,459 lbs Interval Summary Final Fracture Gradient: Pump Time: Max Rate: Initial BH Pressure (Breakdown): Start Date/Time: Open Well Pressure: Pumps Ending Stage: 100M Pumped: Minifrac Max DH Pressure: ISDP: Average pH: Max Proppant Concentration: Dart/Ball Early : Minifrac Average Pressure: Pad Percentage Actual Initial OA Pressure: Pad Percentage Design Pumps Starting Stage: Proppant Summary Proppant in Formation: Average Visc: Max Surface Pressure: Max BH Pressure: Average Rate: Average Missile Pressure: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Minifrac Average DH Pressure: Max OA Pressure: Total Proppant Pumped* : Minifrac Max Surface Pressure: Minifrac Max Rate: Average BH Pressure: Average Surface Pressure: CarboLite 16/20 Ceramic Pumped: Minifrac Average Rate: Average Temp: Average Missile HHP: Diagnostic method 3S-719 - Coyote - Interval 7 End Date/Time: Conoco Phillips - 3S-719 Interval Summary 23 95,671 gal 2,278 bbls 16,298 gal 388 bbls 798 gal 19 bbls 798 gal 19 bbls 23,976 gal 571 bbls 5,989 gal 143 bbls 61,005 gal 1,453 bbls 11,517 gal 274 bbls 3,914 gal 93 bbls 4,701 gal 112 bbls 867 gal 21 bbls 130,809 gal 3,114 bbls 112,767 gal 2,685 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: DFIT Volume: Treatment Slurry Volume (Calculated): Total Clean Fluid Volume: Interval Status: A DFIT was pumped prior to starting interval 7; the closure pressure was determined to be 2472 psi on the downhole gauge. Interval completed as per design. Fluid Summary (by fluid description) Rodrigo Ruysschaert 27# Delta Frac Volume: Dan Faur Prime Up Pressure Test Establish Stable Fluid Volume: Steven Sanders James Campbell Fluid Summary (by stage description) Craig Karpinski 27# Linear Volume: Spacer and Dart Drop Volume: Pad Volume: Proppant Laden Fluid Volume: Seawater Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Displacement Volume: Conditioning Pad Volume: Conoco Phillips - 3S-719 Interval Summary 24 9/5/25 11:24 9/5/25 13:48 144 min 14.5 bpm 5,233 psi 6,139 psi 18 bbl 20.7 bpm 3,473 psi 4,172 psi 19.8 bpm 3,260 psi 3,074 psi 3,987 psi 1,582 hhp 673 psi 692 psi 10.50 ppg 6 6 28 % 28 % 23.78 cP 84.6 F 8.73 397,084 lbs 3,000 lbs 400,084 lbs 400,084 lbs CarboLite 16/20 Ceramic Pumped: 100M Pumped: Proppant Summary Interval Summary 3S-719 - Coyote - Interval 8 Average Visc: Total Proppant Pumped* : Average Missile HHP: Pad Percentage Actual Pad Percentage Design Initial Surface Pressure (Breakdown): Start Date/Time: Initial BH Pressure (Breakdown): Average pH: Average Surface Pressure: Max Rate: Pumps Starting Stage: Proppant in Formation: Average Temp: Average Missile Pressure: Initial Rate (Breakdown): Max Surface Pressure: Pumps Ending Stage: Average Rate: Max Proppant Concentration: Average BH Pressure: Max OA Pressure: Initial OA Pressure: Max BH Pressure: Dart/Ball Early : End Date/Time: Pump Time: Conoco Phillips - 3S-719 Interval Summary 25 95,650 gal 2,277 bbls 5,264 gal 125 bbls 2,180 gal 52 bbls 23,963 gal 571 bbls 6,018 gal 143 bbls 60,444 gal 1,439 bbls 3,084 gal 73 bbls 5,225 gal 124 bbls 118,761 gal 2,828 bbls 100,914 gal 2,403 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Steven Sanders Dan Faur Craig Karpinski James Campbell Rodrigo Ruysschaert 27# Delta Frac Volume: Interval Status: Interval completed as per design. Treatment Slurry Volume (Calculated): Proppant Laden Fluid Volume: Fluid Summary (by fluid description) Pad Volume: 27# Linear Volume: Conditioning Pad Volume: Fluid Summary (by stage description) *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Spacer and Dart Drop Volume: Pre-Pad Volume: Establish Stable Fluid Volume: Total Clean Fluid Volume: Conoco Phillips - 3S-719 Interval Summary 26 9/5/25 13:48 9/5/25 16:21 153 min 14.6 bpm 5,487 psi 5,811 psi 16 bbl 20.8 bpm 3,888 psi 4,247 psi 20.0 bpm 3,532 psi 3,307 psi 3,965 psi 1,731 hhp 669 psi 695 psi 10.09 ppg 6 6 28 % 28 % 25 cP 88.3 F 9.12 398,722 lbs 3,000 lbs 401,722 lbs 401,722 lbs Start Date/Time: End Date/Time: Pump Time: Average Temp: Max Proppant Concentration: Pumps Starting Stage: Average Surface Pressure: 3S-719 - Coyote - Interval 9 Initial BH Pressure (Breakdown): Average pH: Total Proppant Pumped* : Max Surface Pressure: Max BH Pressure: Initial Rate (Breakdown): Max Rate: Pumps Ending Stage: Initial Surface Pressure (Breakdown): Proppant Summary CarboLite 16/20 Ceramic Pumped: Average Missile Pressure: Interval Summary Dart/Ball Early : Average Visc: Pad Percentage Design Max OA Pressure: Proppant in Formation: Initial OA Pressure: Average Rate: 100M Pumped: Pad Percentage Actual Average Missile HHP: Average BH Pressure: Conoco Phillips - 3S-719 Interval Summary 27 1,260 gal 30 bbls 95,787 gal 2,281 bbls 13,891 gal 331 bbls 2,249 gal 54 bbls 23,973 gal 571 bbls 5,984 gal 142 bbls 60,360 gal 1,437 bbls 11,642 gal 277 bbls 1,260 gal 30 bbls 5,470 gal 130 bbls 128,858 gal 3,068 bbls 110,938 gal 2,641 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Steven Sanders Craig Karpinski Treatment Slurry Volume (Calculated): Rodrigo Ruysschaert Dan Faur Flush Volume: Pre-Pad Volume: Establish Stable Fluid Volume: Freeze Protect Volume: Conditioning Pad Volume: Proppant Laden Fluid Volume: Seawater Volume: Fluid Summary (by stage description) Fluid Summary (by fluid description) 30# Delta Frac Volume: Interval Status: Pad Volume: James Campbell The fluid system on this interval was adjusted in order to pump freshwater from D-pit. Total Clean Fluid Volume: 30# Linear Volume: Conoco Phillips - 3S-719 Interval Summary 28 9/6/25 7:55 9/6/25 10:23 148 min 14.9 bpm 5,597 psi 6,083 psi 7 bbl 20.8 bpm 3,919 psi 4,073 psi 19.9 bpm 3,422 psi 3,124 psi 3,813 psi 1,669 hhp 550 psi 658 psi 689 psi 10.75 ppg 6 6 28 % 28 % 25 cP 87.6 F 9.37 400,064 lbs 3,000 lbs 403,064 lbs 403,064 lbs Initial BH Pressure (Breakdown): Pad Percentage Actual Pumps Starting Stage: Dart/Ball Early : Average Visc: Pad Percentage Design Max OA Pressure: Average pH: Average BH Pressure: Average Surface Pressure: Interval Summary Pump Time: Start Date/Time: 3S-719 - Coyote - Interval 10 End Date/Time: Average Missile HHP: Open Well Pressure: CarboLite 16/20 Ceramic Pumped: Initial OA Pressure: Max Proppant Concentration: 100M Pumped: Average Temp: Initial Surface Pressure (Breakdown): Proppant Summary Average Missile Pressure: Average Rate: Total Proppant Pumped* : Proppant in Formation: Max Surface Pressure: Max BH Pressure: Pumps Ending Stage: Max Rate: Initial Rate (Breakdown): Conoco Phillips - 3S-719 Interval Summary 29 798 gal 19 bbls 95,695 gal 2,278 bbls 3,356 gal 80 bbls 798 gal 19 bbls 23,967 gal 571 bbls 5,999 gal 143 bbls 60,716 gal 1,446 bbls 3,356 gal 80 bbls 5,013 gal 119 bbls 117,829 gal 2,805 bbls 99,849 gal 2,377 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Craig Karpinski James Campbell *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Rodrigo Ruysschaert Dan Faur Treatment Slurry Volume (Calculated): Total Clean Fluid Volume: Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. During the beginning of the stage, the MO-67 concentration needed to be adjusted (raising and then lowering) to get the pH above a 9.0. The LA for LD-6450 could not maintain a stable rate so LD-6450 was moved to a different LA. Seawater Volume: 30# Linear Volume: Proppant Laden Fluid Volume: Pad Volume: Conditioning Pad Volume: Establish Stable Fluid Volume: Spacer and Dart Drop Volume: Fluid Summary (by fluid description) Interval Status: Fluid Summary (by stage description) Steven Sanders Prime Up Pressure Test 30# Delta Frac Volume: Conoco Phillips - 3S-719 Interval Summary 30 9/6/25 10:23 9/6/25 12:47 144 min 15.1 bpm 5,058 psi 5,829 psi 17 bbl 20.8 bpm 3,531 psi 4,031 psi 19.9 bpm 3,154 psi 2,789 psi 3,571 psi 1,538 hhp 678 psi 691 psi 10.60 ppg 6 6 28 % 28 % 26 cP 79.6 F 9.42 400,056 lbs 3,000 lbs 403,056 lbs 403,056 lbs Pad Percentage Design Average Surface Pressure: Max OA Pressure: Max BH Pressure: Average Rate: Average BH Pressure: Interval Summary Proppant Summary Total Proppant Pumped* : Proppant in Formation: Pumps Ending Stage: Pump Time: Initial BH Pressure (Breakdown): Dart/Ball Early : 3S-719 - Coyote - Interval 11 End Date/Time: Max Proppant Concentration: Average Visc: Average Temp: Max Rate: CarboLite 16/20 Ceramic Pumped: Average pH: Pad Percentage Actual Initial OA Pressure: Pumps Starting Stage: 100M Pumped: Start Date/Time: Average Missile HHP: Initial Rate (Breakdown): Average Missile Pressure: Initial Surface Pressure (Breakdown): Max Surface Pressure: Conoco Phillips - 3S-719 Interval Summary 31 97,267 gal 2,316 bbls 4,489 gal 107 bbls 2,243 gal 53 bbls 23,953 gal 570 bbls 6,006 gal 143 bbls 61,169 gal 1,456 bbls 2,246 gal 53 bbls 6,139 gal 146 bbls 119,735 gal 2,851 bbls 101,756 gal 2,423 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Fluid Summary (by stage description) Establish Stable Fluid Volume: Pre-Pad Volume: Pad Volume: Spacer and Dart Drop Volume: Treatment Slurry Volume (Calculated): Total Clean Fluid Volume: Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. Rodrigo Ruysschaert Dan Faur Craig Karpinski James Campbell *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. 30# Linear Volume: Fluid Summary (by fluid description) Steven Sanders Conditioning Pad Volume: 30# Delta Frac Volume: Proppant Laden Fluid Volume: Interval Status: Conoco Phillips - 3S-719 Interval Summary 32 9/6/25 12:47 9/6/25 15:18 151 min 15.0 bpm 5,253 psi 5,644 psi 16 bbl 21.0 bpm 3,704 psi 4,081 psi 20.2 bpm 3,304 psi 2,967 psi 3,645 psi 1,636 hhp 679 psi 702 psi 10.50 ppg 6 6 28 % 28 % 25 cP 81.4 F 9.53 398,156 lbs 3,000 lbs 401,156 lbs 401,156 lbs Pumps Starting Stage: Max Proppant Concentration: Pump Time: 3S-719 - Coyote - Interval 12 Interval Summary Initial BH Pressure (Breakdown): Average Missile HHP: Initial Surface Pressure (Breakdown): Max OA Pressure: Average pH: Max Rate: Initial OA Pressure: End Date/Time: Dart/Ball Early : Max BH Pressure: Average Visc: Average Surface Pressure: Start Date/Time: Average Rate: Average Missile Pressure: Pad Percentage Actual Initial Rate (Breakdown): Average BH Pressure: Proppant Summary 100M Pumped: Max Surface Pressure: Total Proppant Pumped* : CarboLite 16/20 Ceramic Pumped: Pumps Ending Stage: Pad Percentage Design Proppant in Formation: Average Temp: Conoco Phillips - 3S-719 Interval Summary 33 1,260 gal 30 bbls 96,547 gal 2,299 bbls 12,947 gal 308 bbls 2,245 gal 53 bbls 23,966 gal 571 bbls 6,014 gal 143 bbls 60,851 gal 1,449 bbls 10,702 gal 255 bbls 1,260 gal 30 bbls 5,716 gal 136 bbls 128,649 gal 3,063 bbls 110,754 gal 2,637 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Craig Karpinski Dan Faur Establish Stable Fluid Volume: Freeze Protect Volume: Total Clean Fluid Volume: Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. Steven Sanders Fluid Summary (by fluid description) Fluid Summary (by stage description) 30# Delta Frac Volume: Interval Status: Pad Volume: Flush Volume: Conditioning Pad Volume: James Campbell *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Rodrigo Ruysschaert 30# Linear Volume: Treatment Slurry Volume (Calculated): Seawater Volume: Pre-Pad Volume: Proppant Laden Fluid Volume: Conoco Phillips - 3S-719 Interval Summary 34 9/7/25 7:50 9/7/25 10:59 189 min 15.1 bpm 4,533 psi 5,461 psi 11 bbl 20.6 bpm 3,445 psi 3,835 psi 19.6 bpm 3,008 psi 2,731 psi 3,545 psi 1,445 hhp 539 psi 547 psi 690 psi 10.80 ppg 6 6 28 % 28 % 26 cP 78.9 F 9.17 DFIT 9.900 bpm 1430 psi 2919 psi 10.09 bpm 1517 psi 2998 psi 2580 psi 0.617 psi/ft 399,041 lbs 3,000 lbs 402,041 lbs 402,041 lbs Minifrac Average Pressure: Minifrac Average DH Pressure: Interval Summary End Date/Time: Average Missile HHP: Pad Percentage Design Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Max Surface Pressure: Max Proppant Concentration: Pad Percentage Actual ISDP: Final Fracture Gradient: Total Proppant Pumped* : Average Visc: Initial OA Pressure: Average Surface Pressure: Initial BH Pressure (Breakdown): Average Missile Pressure: Minifrac Max DH Pressure: Pump Time: 3S-719 - Coyote - Interval 13 Minifrac Max Rate: Max BH Pressure: Minifrac Max Surface Pressure: Pumps Ending Stage: Open Well Pressure: Diagnostic method Pumps Starting Stage: Average Rate: Proppant Summary Dart/Ball Early : Max OA Pressure: Average pH: Minifrac Average Rate: Average Temp: Start Date/Time: Max Rate: CarboLite 16/20 Ceramic Pumped: Average BH Pressure: 100M Pumped: Proppant in Formation: Conoco Phillips - 3S-719 Interval Summary 35 798 gal 19 bbls 93,632 gal 2,229 bbls 13,829 gal 329 bbls 798 gal 19 bbls 9,777 gal 233 bbls 23,976 gal 571 bbls 6,005 gal 143 bbls 60,358 gal 1,437 bbls 3,183 gal 76 bbls 3,293 gal 78 bbls 126,193 gal 3,005 bbls 108,259 gal 2,578 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: 30# Linear Volume: Proppant Laden Fluid Volume: Fluid Summary (by stage description) Treatment Slurry Volume (Calculated): Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. A DFIT was pumped and a closure signature could not clearly be seen in the analysis. The CoP engineer then gave an estimated closure pressure of 2508 psi at the downhole gauge. Steven Sanders Craig Karpinski James Campbell Fluid Summary (by fluid description) Rodrigo Ruysschaert Dan Faur *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Total Clean Fluid Volume: Spacer and Dart Drop Volume: Conditioning Pad Volume: Displace Dart to Seat Volume: 30# Delta Frac Volume: Pad Volume: Seawater Volume: Prime Up Pressure Test Establish Stable Fluid Volume: Interval Status: Conoco Phillips - 3S-719 Interval Summary 36 9/7/25 10:59 9/7/25 13:20 141 min 14.8 bpm 4,888 psi 5,498 psi 18 bbl 20.7 bpm 3,258 psi 3,788 psi 20.0 bpm 2,946 psi 2,611 psi 3,442 psi 1,444 hhp 681 psi 685 psi 10.40 ppg 6 6 28 % 28 % 26 cP 81.4 F 9.28 399,725 lbs 3,000 lbs 402,725 lbs 402,725 lbs Initial Surface Pressure (Breakdown): Total Proppant Pumped* : Proppant in Formation: Interval Summary Start Date/Time: 3S-719 - Coyote - Interval 14 Max Rate: Max BH Pressure: CarboLite 16/20 Ceramic Pumped: Pump Time: Average pH: End Date/Time: Average Temp: Dart/Ball Early : Max Surface Pressure: Average Missile HHP: Pumps Starting Stage: Average BH Pressure: 100M Pumped: Max OA Pressure: Max Proppant Concentration: Initial Rate (Breakdown): Average Visc: Initial OA Pressure: Proppant Summary Pad Percentage Actual Initial BH Pressure (Breakdown): Average Surface Pressure: Pad Percentage Design Average Rate: Average Missile Pressure: Pumps Ending Stage: Conoco Phillips - 3S-719 Interval Summary 37 95,509 gal 2,274 bbls 4,518 gal 108 bbls 2,333 gal 56 bbls 23,979 gal 571 bbls 5,996 gal 143 bbls 60,597 gal 1,443 bbls 2,185 gal 52 bbls 4,937 gal 118 bbls 117,992 gal 2,809 bbls 100,027 gal 2,382 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Spacer and Dart Drop Volume: Conditioning Pad Volume: Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. Fluid Summary (by stage description) Craig Karpinski James Campbell *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. 30# Delta Frac Volume: Proppant Laden Fluid Volume: Pad Volume: Fluid Summary (by fluid description) Pre-Pad Volume: 30# Linear Volume: Steven Sanders Rodrigo Ruysschaert Dan Faur Treatment Slurry Volume (Calculated): Total Clean Fluid Volume: Interval Status: Establish Stable Fluid Volume: Conoco Phillips - 3S-719 Interval Summary 38 9/7/25 13:20 9/7/25 15:51 151 min 14.7 bpm 6,745 psi 7,374 psi 16 bbl 20.9 bpm 3,482 psi 3,834 psi 19.6 bpm 3,008 psi 2,731 psi 3,545 psi 1,445 hhp 673 psi 690 psi 10.40 ppg 6 6 28 % 28 % 25 cP 79.3 F 9.36 2663 psi 0.636 psi/ft 2760 psi 2758 psi 2755 psi 400,118 lbs 3,000 lbs 403,118 lbs 403,118 lbs Dart/Ball Early : 3S-719 - Coyote - Interval 15 Interval Summary Average Missile Pressure: Pad Percentage Actual Pumps Ending Stage: Pad Percentage Design End Date/Time: Max BH Pressure: Max Rate: Initial Surface Pressure (Breakdown): Initial Rate (Breakdown): Average Missile HHP: Initial BH Pressure (Breakdown): Average BH Pressure: Pump Time: Max Surface Pressure: Average Surface Pressure: Final 10 min: Average Visc: Average pH: CarboLite 16/20 Ceramic Pumped: Proppant Summary Total Proppant Pumped* : Proppant in Formation: Final 15 min: Average Temp: Initial OA Pressure: Max OA Pressure: Max Proppant Concentration: 100M Pumped: Pumps Starting Stage: Final 5 min: Final Fracture Gradient: Start Date/Time: ISDP: Average Rate: Conoco Phillips - 3S-719 Interval Summary 39 3,482 6,745 1,260 gal 30 bbls 96,024 gal 2,286 bbls 12,005 gal 286 bbls 2,258 gal 54 bbls 23,963 gal 571 bbls 6,004 gal 143 bbls 61,385 gal 1,462 bbls 9,747 gal 232 bbls 1,260 gal 30 bbls 4,672 gal 111 bbls 127,271 gal 3,030 bbls 109,289 gal 2,602 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. While seating the dart, pressure rose and kicked out one pump (bringing rate to 10 bpm); stage continued on as per design. 30# Delta Frac Volume: 30# Linear Volume: Freeze Protect Volume: Fluid Summary (by fluid description) Treatment Slurry Volume (Calculated): Total Clean Fluid Volume: Interval Status: Craig Karpinski James Campbell Pad Volume: Conditioning Pad Volume: Fluid Summary (by stage description) Flush Volume: Steven Sanders Proppant Laden Fluid Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Establish Stable Fluid Volume: Rodrigo Ruysschaert Dan Faur Seawater Volume: Pre-Pad Volume: Conoco Phillips - 3S-719 Interval Summary 40 9/8/25 7:32 9/8/25 9:56 144 min 14.6 bpm 5,269 psi 5,750 psi 9 bbl 20.4 bpm 3,050 psi 3,591 psi 19.9 bpm 2,907 psi 2,597 psi 3,378 psi 1,418 hhp 703 psi 668 psi 692 psi 10.40 ppg 6 6 28 % 28 % 26 cP 80 F 9.28 398,481 lbs 3,000 lbs 401,481 lbs 401,481 lbs Max Proppant Concentration: Pad Percentage Design Average Visc: Pump Time: Average Surface Pressure: Average Temp: Proppant in Formation: Average pH: Pumps Starting Stage: Start Date/Time: Average BH Pressure: Average Rate: End Date/Time: Max BH Pressure: Interval Summary Pad Percentage Actual Initial OA Pressure: Initial BH Pressure (Breakdown): Dart/Ball Early : Average Missile HHP: Open Well Pressure: Max OA Pressure: Pumps Ending Stage: Max Surface Pressure: CarboLite 16/20 Ceramic Pumped: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): 100M Pumped: Average Missile Pressure: Proppant Summary Max Rate: 3S-719 - Coyote - Interval 16 Total Proppant Pumped* : Conoco Phillips - 3S-719 Interval Summary 41 798 gal 19 bbls 90,190 gal 2,147 bbls 7,542 gal 180 bbls 798 gal 19 bbls 23,965 gal 571 bbls 6,025 gal 143 bbls 60,200 gal 1,433 bbls 3,111 gal 74 bbls 4,431 gal 106 bbls 116,439 gal 2,772 bbls 98,530 gal 2,346 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Steven Sanders Craig Karpinski James Campbell *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Rodrigo Ruysschaert Dan Faur Establish Stable Fluid Volume: Total Clean Fluid Volume: Fluid Summary (by fluid description) Spacer and Dart Drop Volume: Conditioning Pad Volume: Proppant Laden Fluid Volume: Prime Up Pressure Test Pad Volume: Treatment Slurry Volume (Calculated): 30# Linear Volume: Interval Status: Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. 30# Delta Frac Volume: Fluid Summary (by stage description) Seawater Volume: Conoco Phillips - 3S-719 Interval Summary 42 9/8/25 9:56 9/8/25 12:16 140 min 14.7 bpm 5,482 psi 6,000 psi 16 bbl 20.7 bpm 3,359 psi 3,587 psi 19.9 bpm 3,003 psi 2,653 psi 3,305 psi 1,465 hhp 669 psi 688 psi 10.90 ppg 6 6 28 % 28 % 26 cP 82.8 F 9.42 398,297 lbs 3,000 lbs 401,297 lbs 401,297 lbs 3S-719 - Coyote - Interval 17 Interval Summary Average pH: Proppant Summary Average Rate: Proppant in Formation: Average Missile Pressure: Initial Rate (Breakdown): Dart/Ball Early : CarboLite 16/20 Ceramic Pumped: 100M Pumped: Total Proppant Pumped* : End Date/Time: Max Proppant Concentration: Average BH Pressure: Start Date/Time: Pumps Ending Stage: Pad Percentage Design Pad Percentage Actual Max Surface Pressure: Initial BH Pressure (Breakdown): Average Visc: Average Temp: Max OA Pressure: Average Surface Pressure: Max Rate: Initial OA Pressure: Max BH Pressure: Initial Surface Pressure (Breakdown): Pumps Starting Stage: Average Missile HHP: Pump Time: Conoco Phillips - 3S-719 Interval Summary 43 93,518 gal 2,227 bbls 4,894 gal 117 bbls 2,348 gal 56 bbls 23,969 gal 571 bbls 5,987 gal 143 bbls 59,929 gal 1,427 bbls 2,546 gal 61 bbls 3,633 gal 87 bbls 116,313 gal 2,769 bbls 98,412 gal 2,343 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Pad Volume: Spacer and Dart Drop Volume: 30# Delta Frac Volume: 30# Linear Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Rodrigo Ruysschaert Dan Faur Conditioning Pad Volume: Proppant Laden Fluid Volume: Fluid Summary (by fluid description) Total Clean Fluid Volume: Establish Stable Fluid Volume: Treatment Slurry Volume (Calculated): Pre-Pad Volume: Fluid Summary (by stage description) Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. Steven Sanders Craig Karpinski James Campbell Interval Status: Conoco Phillips - 3S-719 Interval Summary 44 9/8/25 12:16 9/8/25 14:44 148 min 14.7 bpm 5,613 psi 6,069 psi 15 bbl 20.9 bpm 2,960 psi 3,473 psi 20.1 bpm 2,821 psi 2,510 psi 3,242 psi 1,390 hhp 667 psi 685 psi 10.60 ppg 6 6 28 % 28 % 26 cP 80.9 F 9.3 398,648 lbs 3,000 lbs 401,648 lbs 401,648 lbs Proppant Summary 100M Pumped: Interval Summary Average Temp: Average pH: Average BH Pressure: Pumps Starting Stage: Pumps Ending Stage: Start Date/Time: Average Surface Pressure: Dart/Ball Early : Initial BH Pressure (Breakdown): Pad Percentage Design Max Proppant Concentration: Pad Percentage Actual Average Missile Pressure: Max Rate: Average Missile HHP: Max BH Pressure: Initial Surface Pressure (Breakdown): 3S-719 - Coyote - Interval 18 Pump Time: Initial Rate (Breakdown): Average Rate: End Date/Time: Initial OA Pressure: Max OA Pressure: Max Surface Pressure: CarboLite 16/20 Ceramic Pumped: Total Proppant Pumped* : Proppant in Formation: Average Visc: Conoco Phillips - 3S-719 Interval Summary 45 1,260 gal 30 bbls 94,432 gal 2,248 bbls 11,530 gal 275 bbls 2,793 gal 67 bbls 23,975 gal 571 bbls 5,992 gal 143 bbls 60,085 gal 1,431 bbls 8,737 gal 208 bbls 1,260 gal 30 bbls 4,380 gal 104 bbls 125,139 gal 2,979 bbls 107,222 gal 2,553 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Steven Sanders Total Clean Fluid Volume: 30# Linear Volume: 30# Delta Frac Volume: Craig Karpinski Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. Pre-Pad Volume: James Campbell Dan Faur Interval Status: Freeze Protect Volume: Conditioning Pad Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Treatment Slurry Volume (Calculated): Flush Volume: Pad Volume: Rodrigo Ruysschaert Establish Stable Fluid Volume: Proppant Laden Fluid Volume: Seawater Volume: Fluid Summary (by stage description) Fluid Summary (by fluid description) Conoco Phillips - 3S-719 Interval Summary 46 9/9/25 7:43 9/9/25 10:44 181 min 15.0 bpm 4,971 psi 5,819 psi 11 bbl 20.4 bpm 2,958 psi 3,424 psi 19.6 bpm 2,679 psi 2,396 psi 3,203 psi 1,287 hhp 945 psi 665 psi 685 psi 9.99 ppg 6 6 28 % 27 % 26 cP 79.7 F 9.1 DFIT 5.000 bpm 1193 psi 2811 psi 5.2 bpm 1198 psi 2818 psi 2796 psi 0.666 psi/ft 399,103 lbs 3,000 lbs 402,103 lbs 402,103 lbs Minifrac Max Rate: Final Fracture Gradient: Diagnostic method Minifrac Average Pressure: Minifrac Average Rate: ISDP: Average Temp: Minifrac Max Surface Pressure: Average Missile Pressure: Average pH: Minifrac Average DH Pressure: Average BH Pressure: Total Proppant Pumped* : CarboLite 16/20 Ceramic Pumped: Interval Summary Average Visc: Start Date/Time: End Date/Time: Dart/Ball Early : Pumps Starting Stage: Max Rate: Initial Rate (Breakdown): Max BH Pressure: Average Rate: Pad Percentage Actual Max Surface Pressure: Pump Time: Open Well Pressure: Initial OA Pressure: Initial BH Pressure (Breakdown): Max OA Pressure: Proppant in Formation: 100M Pumped: Average Missile HHP: Max Proppant Concentration: Pumps Ending Stage: 3S-719 - Coyote - Interval 19 Initial Surface Pressure (Breakdown): Average Surface Pressure: Pad Percentage Design Minifrac Max DH Pressure: Proppant Summary Conoco Phillips - 3S-719 Interval Summary 47 798 gal 19 bbls 95,515 gal 2,274 bbls 11,737 gal 279 bbls 798 gal 19 bbls 7,952 gal 189 bbls 23,968 gal 571 bbls 6,023 gal 143 bbls 62,027 gal 1,477 bbls 3,163 gal 75 bbls 3,497 gal 83 bbls 622 gal 15 bbls 125,987 gal 3,000 bbls 108,050 gal 2,573 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Status: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Establish Stable Fluid Volume: Rodrigo Ruysschaert Dan Faur 30# Linear Volume: Proppant Laden Fluid Volume: Spacer and Dart Drop Volume: Fluid Summary (by stage description) James Campbell Total Clean Fluid Volume: 30# Delta Frac Volume: Treatment Slurry Volume (Calculated): DFIT Volume: Fluid Summary (by fluid description) Pad Volume: Prime Up Pressure Test Displace Dart to Seat Volume: Seawater Volume: Conditioning Pad Volume: Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. A DFIT was pumped prior to the stage and closure pressure was determined to be 2615 psi on the downhole gauge. During the 6 ppg sand stage, pump 458 starting fluctuating rate due to cavitation. The rate eventually stabilized after ~90 bbls; a sand slug was the suspected cause of the cavitation. Steven Sanders Craig Karpinski Conoco Phillips - 3S-719 Interval Summary 48 9/9/25 10:44 9/9/25 13:06 142 min 14.4 bpm 4,951 psi 5,738 psi 15 bbl 20.8 bpm 3,049 psi 3,293 psi 19.8 bpm 2,626 psi 2,318 psi 3,077 psi 1,274 hhp 674 psi 685 psi 10.40 ppg 6 6 28 % 28 % 26 cP 80.6 F 9.1 397,758 lbs 3,000 lbs 400,758 lbs 400,758 lbs Total Proppant Pumped* : Proppant in Formation: Interval Summary Start Date/Time: End Date/Time: Max BH Pressure: Average Rate: Average Missile Pressure: Average Surface Pressure: Average pH: Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Dart/Ball Early : Max Rate: Proppant Summary CarboLite 16/20 Ceramic Pumped: 100M Pumped: Pumps Ending Stage: Average BH Pressure: Pump Time: Pad Percentage Design Average Temp: Max OA Pressure: Pad Percentage Actual Average Missile HHP: Initial OA Pressure: 3S-719 - Coyote - Interval 20 Max Surface Pressure: Max Proppant Concentration: Average Visc: Initial Rate (Breakdown): Pumps Starting Stage: Conoco Phillips - 3S-719 Interval Summary 49 95,189 gal 2,266 bbls 4,411 gal 105 bbls 2,210 gal 53 bbls 23,946 gal 570 bbls 6,043 gal 144 bbls 61,299 gal 1,460 bbls 2,201 gal 52 bbls 3,901 gal 93 bbls 117,477 gal 2,797 bbls 99,600 gal 2,371 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Conditioning Pad Volume: Spacer and Dart Drop Volume: Pad Volume: Pre-Pad Volume: Fluid Summary (by fluid description) Fluid Summary (by stage description) 30# Delta Frac Volume: James Campbell *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Rodrigo Ruysschaert Dan Faur Proppant Laden Fluid Volume: Total Clean Fluid Volume: 30# Linear Volume: Interval Status: Steven Sanders Craig Karpinski Treatment Slurry Volume (Calculated): Establish Stable Fluid Volume: Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. Conoco Phillips - 3S-719 Interval Summary 50 9/9/25 13:06 9/9/25 15:33 147 min 14.7 bpm 6,149 psi 6,796 psi 7 bbl 20.6 bpm 3,093 psi 3,485 psi 20.0 bpm 2,531 psi 2,249 psi 3,050 psi 1,241 hhp 651 psi 671 psi 10.10 ppg 6 6 28 % 28 % 24 cP 79.2 F 9.2 2831 psi 0.675 psi/ft 2815 psi 2811 psi 2802 psi 397,629 lbs 3,000 lbs 400,629 lbs 400,629 lbs Interval Summary Proppant Summary CarboLite 16/20 Ceramic Pumped: Final 10 min: Start Date/Time: End Date/Time: Pump Time: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Dart/Ball Early : Max Rate: Initial OA Pressure: Max OA Pressure: Proppant in Formation: ISDP: 100M Pumped: Average Missile HHP: Final 5 min: Pumps Ending Stage: Average Visc: Max BH Pressure: Pad Percentage Design Final 15 min: Average pH: Average BH Pressure: Pumps Starting Stage: Average Temp: Average Missile Pressure: Average Surface Pressure: Pad Percentage Actual Average Rate: Max Proppant Concentration: 3S-719 - Coyote - Interval 21 Max Surface Pressure: Final Fracture Gradient: Total Proppant Pumped* : Conoco Phillips - 3S-719 Interval Summary 51 1,260 gal 30 bbls 93,993 gal 2,238 bbls 10,708 gal 255 bbls 2,931 gal 70 bbls 23,960 gal 570 bbls 5,988 gal 143 bbls 61,415 gal 1,462 bbls 7,777 gal 185 bbls 1,260 gal 30 bbls 2,630 gal 63 bbls 123,832 gal 2,948 bbls 105,961 gal 2,523 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Total Clean Fluid Volume: Fluid Summary (by fluid description) Fluid Summary (by stage description) Conditioning Pad Volume: Flush Volume: Freeze Protect Volume: Proppant Laden Fluid Volume: Pre-Pad Volume: 30# Linear Volume: 30# Delta Frac Volume: Seawater Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Pad Volume: Treatment Slurry Volume (Calculated): Steven Sanders Craig Karpinski James Campbell Rodrigo Ruysschaert Dan Faur Interval Status: Establish Stable Fluid Volume: Freshwater from D-Pit was pumped on the interval; the fluid system was changed from the original design in order to be compatible with the freshwater. Conoco Phillips - 3S-719 Interval Summary 52 CustomerFormationLeaseAPIDateWell SummaryCarboLite 16/20 Cerami100MTotal Proppantrface PressRate Visc Temp pHrface PressRate bbl gal bbl gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs13228 19.7 21 82 8.8 4146 21.1 2,297 3,893 93 756 18 101,113 2,407 3,000 400,668 23300 19.8 20 86 8.7 4500 21.0 2,103 4,356 104 92,698 2,207 3,000 326,628 33383 20.0 20 85 8.7 4240 21.1 2,368 15,610 372 115,062 2,740 122,059 3,000 403,558 43365 20.1 22 81 8.8 3844 21.1 2,359 4,754 113 756 18 104,590 2,490 398,056 3,000 401,056 53320 19.7 23 93 8.8 3789 20.7 2,492 5,012 119 798 19 110,490 2,631 401,884 3,000 404,884 62888 19.1 24 90 8.9 3576 21.1 2,655 27,279 650 1,260 30 140,051 3,335 402,515 3,000 405,515 72885 19.5 23 86 8.8 3311 20.5 2,278 16,298 388 798 19 112,767 2,685 401,459 3,000 404,459 83074 19.8 24 85 8.7 3473 20.7 2,277 5,264 125 100,914 2,403 397,084 3,000 400,084 93307 20.0 25 88 9.1 3888 20.8 1,260 30 95,787 2,281 13,891 331 110,938 2,641 398,722 3,000 401,722 103124 19.9 25 88 9.4 3919 20.8 798 19 95,695 2,278 3,356 80 99,849 2,377 400,064 3,000 403,064 112789 19.9 26 80 9.4 3531 20.897,267 2,316 4,489 107 101,756 2,423 400,056 3,000 403,056 122967 20.2 25 81 9.5 3704 21.0 1,260 30 96,547 2,299 12,947 308 110,754 2,637 398,156 3,000 401,156 132731 19.6 26 79 9.2 3445 20.6 798 19 93,632 2,229 13,829 329 108,259 2,578 399,041 3,000 402,041 142611 20.0 26 81 9.3 3258 20.795,509 2,274 4,518 108 100,027 2,382 399,725 3,000 402,725 152731 19.6 25 79 9.4 3482 20.9 1,260 30 96,024 2,286 12,005 286 109,289 2,602 400,118 3,000 403,118 162597 19.9 26 80 9.3 3050 20.4 798 19 90,190 2,147 7,542 180 98,530 2,346 398,481 3,000 401,481 172653 19.9 26 83 9.4 3359 20.793,518 2,227 4,894 117 98,412 2,343 398,297 3,000 401,297 182510 20.1 26 81 9.3 2960 20.9 1,260 30 94,432 2,248 11,530 275 107,222 2,553 398,648 3,000 401,648 192396 19.6 26 80 9.1 2958 20.4 798 19 95,515 2,274 11,737 279 108,050 2,573 399,103 3,000 402,103 202318 19.8 26 81 9.1 3049 20.895,189 2,266 4,411 105 99,600 2,371 397,758 3,000 400,758 212249 20.0 24 79 9.2 3093 20.6 1,260 30 93,993 2,238 10,708 255 105,961 2,523 397,629 3,000 400,629 Minimum2103 3893 93 756 18 90190 2147 3356 80 92698 2207 122059 3000 326628 Average2354 10308 245 990 24 94869 2259 8912 212 106492 2536 384677 3000 398650 Maximum2655 27279 650 1260 30 97267 2316 13891 331 140051 3335 402515 3000 405515 CarboLite 16/20 Cerami100M Total ProppantPressure Rate Visc Temp pH Pressure Rate bbl gal bbl gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs TotalPlanned19,743 80,718 1,922 16,820 400 0 0 1,264,430 30,105 117,184 2,790 2,308,342 54,961 7,332,900 63,000 8,473,300Recorded3136 19.8 23 85 8.96 4500 21.1 18,830 82,466 1,963 13,860 330 0 0 1,233,298 29,364 115,857 2,759 2,236,332 53,246 7,308,855 63,000 8,371,650Weight Tickets7,402,878 63,000 8,437,842** Proppant is billed from Weight Ticket volumes** IFS numbers for proppant are taken from software calculations based on Total FluidFluidsProppantsFluidsProppants30# Delta FracTotal FluidFreeze Protect30# Delta FracFreeze Protect30# LinearAverage MaxSeawater30# Linear27# Delta Frac27# Linear27# Delta Frac27# LinearIntervalAverage MaxSeawaterAugust 25, 202550-103-209193S-719CoyoteConoco Phillips Conoco Phillips - 3S-719 Fluid System-Proppant Summary53 <-Paste Interval 1 Plots HereePRV Test - 8.25.258/25/202507:3407:3607:3807:4007:4207:4407:468/25/202507:48Time01000200030004000500060007000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)27654Global Event Log4567Intersection IntersectionePRV - Primary Tubing ePRV - Secondary TubingePRV - Primary IA ePRV - Secondary IA07:35:00 07:42:3907:44:22 07:47:34TP TP1047 977.8970.6 959.1TPP TPP1051 629.0359.4 333.7IGKP IGKP100.00 12001200 1200Conoco Phillips - 3S-719 Interval 1 Plots54 <-Paste Interval 1 Plots HerePressure Test - 8.25.258/26/202507:3607:3807:4007:428/26/202507:44Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)1211109Global Event Log9101112Intersection IntersectionPressure Test - Locals Pressure Test - GlobalPressure Test - Max Pressure Test - Pass07:35:18 07:35:2007:38:46 07:43:38TP TP1301 13189476 9387TPP TPP1265 13459559 9465PP1335 13749543 9446INSITE for Stimulation v7.3.005-Sep-25 20:32Conoco Phillips - 3S-719 Interval 1 Plots55 <-Paste Interval 1 Plots HereADP Chemical Plots - Bucket Test 8.25.258/25/202506:04:0006:04:2006:04:4006:05:0006:05:2006:05:408/25/202506:06:00Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)ABConoco Phillips - 3S-719 Interval 1 Plots56 <-Paste Interval 1 Plots HereBlender & LMS Chemical Plot - Bucket Test 8.25.258/25/202506:1506:2006:2506:3006:3506:408/25/202506:45Time0.00.51.01.52.02.53.0A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABAConoco Phillips - 3S-719 Interval 1 Plots57 Treatment Plot - Interval 01 DFIT8/25/202508:5009:0009:1009:208/25/202509:30Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD654Conoco Phillips - 3S-719 Interval 1 Plots58 Treatment Plot - Interval 018/25/202509:3010:0010:3011:0011:308/25/202512:00Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD32116151413128111098762Conoco Phillips - 3S-719 Interval 1 Plots59 ADP Chemical Plots - Interval 018/25/202509:4010:0010:2010:4011:0011:2011:408/25/202512:00Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB32116151413128111098762Conoco Phillips - 3S-719 Interval 1 Plots60 Blender & LMS Chemical Plot - Interval 018/25/202509:4010:0010:2010:4011:0011:2011:408/25/202512:00Time0.00.51.01.52.02.53.0A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABA2116151413128111098762Conoco Phillips - 3S-719 Interval 1 Plots61 Net Pressure Plot - Interval 0167892345678910100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2467 psi 0 Time = 08/25/25 09:30:00 1Time-160.16NetPr0.000Slope0.000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 25-Aug-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 1 Plots62 <-Paste Interval 2 Plots HereTreatment Plot - Interval 028/25/202512:0012:3013:0013:3014:008/25/202514:30Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD3112109876543211632Conoco Phillips - 3S-719 Interval 2 Plots63 <-Paste Interval 2 Plots HereADP Chemical Plots - Interval 028/25/202512:0012:2012:4013:0013:2013:408/25/202514:00Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB112109876543211632Conoco Phillips - 3S-719 Interval 2 Plots64 <-Paste Interval 2 Plots HereBlender & LMS Chemical Plot - Interval 028/25/202512:0012:2012:4013:0013:2013:408/25/202514:00Time0.00.51.01.52.02.53.0A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABA112109876543211632Conoco Phillips - 3S-719 Interval 2 Plots65 <-Paste Interval 2 Plots HereNet Pressure Plot - Interval 0267892345678910100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2467 psi 0 Time = 08/25/25 12:05:00 1Time-315.16NetPr0.000Slope0.000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 25-Aug-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 2 Plots66 <-Paste Interval 3 Plots HereTreatment Plot - Interval 038/25/202514:0014:3015:0015:3016:008/25/202516:30Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD1211109818765431123Conoco Phillips - 3S-719 Interval 3 Plots67 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 038/25/202514:2014:4015:0015:2015:4016:0016:208/25/202516:40Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB1211109818765431123Conoco Phillips - 3S-719 Interval 3 Plots68 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 038/25/202514:2014:4015:0015:2015:4016:0016:208/25/202516:40Time0.00.51.01.52.02.53.0A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABA12111098187654313Conoco Phillips - 3S-719 Interval 3 Plots69 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 0367892345678910100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2467 psi 0 Time = 08/25/25 14:15:00 1Time-445.16NetPr0.000Slope0.000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 25-Aug-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 3 Plots70 <-Paste Interval 3 Plots HereePRV Test - 8.26.258/26/202507:2707:2807:2907:3007:3107:3207:338/26/202507:34Time01000200030004000500060007000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)8765Global Event Log5678Intersection IntersectionePRV - Primary Tubing ePRV - Primary IAePRV - Secondary Tubing ePRV - Secondary IA07:27:28 07:28:5607:31:19 07:32:41TP TP700.9 612.5716.4 756.9TPP TPP760.0 336.8759.6 729.9IGKP IGKP800.0 800.0800.0 800.0Conoco Phillips - 3S-719 Interval 4 Plots71 <-Paste Interval 3 Plots HerePressure Test - 8.26.258/26/202507:3607:3807:4007:4207:448/26/202507:46Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)1211109Global Event Log9101112Intersection IntersectionPressure Test - Locals Pressure Test - GlobalPressure Test - Max Pressure Test - Pass07:35:18 07:35:2007:38:46 07:43:38TP TP1301 13189476 9387TPP TPP1265 13459559 9465IGKP IGKP800.0 25.009500 9500PKP PKP500.4 500.49451 9451Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 26-Aug-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 4 Plots72 <-Paste Interval 3 Plots HereADP Chemical Plots - Bucket Test 8.26.258/26/202506:4406:4506:4606:4706:4806:4906:5006:518/26/202506:52Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)ABConoco Phillips - 3S-719 Interval 4 Plots73 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Bucket Test 8.26.258/26/202506:5006:5507:0007:0507:1007:1507:208/26/202507:25Time0.00.51.01.52.02.53.0A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABA14Conoco Phillips - 3S-719 Interval 4 Plots74 Treatment Plot - Interval 048/26/202508:3009:0009:3010:008/26/202510:30Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD321113121110987654325Conoco Phillips - 3S-719 Interval 4 Plots75 ADP Chemical Plots - Interval 048/26/202508:2008:4009:0009:2009:4010:0010:208/26/202510:40Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB321113121110987654325Conoco Phillips - 3S-719 Interval 4 Plots76 Blender & LMS Chemical Plot - Interval 048/26/202508:2008:4009:0009:2009:4010:0010:208/26/202510:40Time0.00.51.01.52.02.53.0A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABA321113121110987654325Conoco Phillips - 3S-719 Interval 4 Plots77 Net Pressure Plot - Interval 047892100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2467 psi 0 Time = 08/26/25 07:04:32 1Time-9.04NetPr0.000Slope0.000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 26-Aug-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 4 Plots78 <-Paste Interval 3 Plots HereTreatment Plot - Interval 058/26/202510:5011:0011:1011:2011:308/26/202511:40Time010002000300040005000600070008000900010000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD3132115INSITE for Stimulation v7.3.005-Sep-25 21:04Conoco Phillips - 3S-719 Interval 5 Plots79 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 058/26/202508:3009:0009:3010:008/26/202510:30Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB321113121110987654325INSITE for Stimulation v7.3.005-Sep-25 20:49Conoco Phillips - 3S-719 Interval 5 Plots80 <-Paste Interval 3 Plots HereBlender Chemical Plot - Interval 058/26/202510:4210:4410:4610:4810:5010:5210:548/26/202510:56Time01234A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABA32115INSITE for Stimulation v7.3.005-Sep-25 20:57Conoco Phillips - 3S-719 Interval 5 Plots81 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 05Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2467 psi 0 Time = 08/26/25 07:04:32 150.950.0000.000INSITE for Stimulation v7.3.005-Sep-25 21:05Conoco Phillips - 3S-719 Interval 5 Plots82 ePRV Test - 9.4.259/4/202507:2107:2207:2307:2407:2507:2607:279/4/202507:28Time01000200030004000500060007000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)6543Global Event Log3456Intersection IntersectionePRV - Primary Tubing ePRV - Secondary TubingePRV - Primary IA ePRV - Secondary IA07:21:23 07:23:4907:26:09 07:27:49TP TP1576 15941605 1601TPP TPP1632 16721120 1024IGKP IGKP1200 15002000 2000Conoco Phillips - 3S-719 Interval 5 Plots83 Pressure Test - 9.4.259/4/202507:3607:3807:4007:4207:4407:469/4/202507:48Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)10987Global Event Log78910Intersection IntersectionTesting Globals Testing LocalsPressure Test - Max Pressure Test - Pass07:35:25 07:35:3107:40:28 07:46:05TP TP250.9 273.49466 9455TPP TPP269.5 307.79580 9526IGKP IGKP25.00 90009500 9500PKP PKP500.4 198.29500 9500Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 04-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 5 Plots84 ADP Chemical Plots - Bucket Test 9.4.259/4/202507:0107:0207:0307:0407:0507:0607:079/4/202507:08Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)ABConoco Phillips - 3S-719 Interval 5 Plots85 Blender & LMS Chemical Plot - Bucket Test 9.4.259/4/202506:5006:5206:5406:5606:5807:0007:0207:049/4/202507:06Time0.00.20.40.60.81.01.21.41.61.82.0A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABAConoco Phillips - 3S-719 Interval 5 Plots86 Treatment Plot - Interval 59/4/202510:0010:2010:4011:0011:2011:4012:0012:209/4/202512:40Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD32112113121110987654316Conoco Phillips - 3S-719 Interval 5 Plots87 ADP Chemical Plots - Interval 59/4/202510:0010:3011:0011:3012:0012:3013:009/4/202513:30Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB125432112113121110987654316Conoco Phillips - 3S-719 Interval 5 Plots88 Blender & LMS Chemical Plot - Interval 59/4/202510:0010:2010:4011:0011:2011:4012:0012:209/4/202512:40Time0.00.20.40.60.81.01.21.41.61.82.0A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABA2112113121110987654316Conoco Phillips - 3S-719 Interval 5 Plots89 Net Pressure Plot - Interval 58923456789210100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2460 psi 0 Time = 09/04/25 09:50:22 1-154.040.0000.000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 04-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 5 Plots90 <-Paste Interval 3 Plots HereTreatment Plot - Interval 69/4/202512:3013:0013:3014:0014:3015:0015:3016:009/4/202516:30Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD121112111098765211254321121136Conoco Phillips - 3S-719 Interval 6 Plots91 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 69/4/202512:3013:0013:3014:0014:3015:0015:3016:009/4/202516:30Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB121112111098765211254321121136Conoco Phillips - 3S-719 Interval 6 Plots92 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 69/4/202512:3013:0013:3014:0014:3015:0015:3016:009/4/202516:30Time0.00.20.40.60.81.01.21.41.61.82.0A012345BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)AAABA121112111098765211254321121136Conoco Phillips - 3S-719 Interval 6 Plots93 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 6234Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2460 psi 0 Time = 09/04/25 09:50:22 1-154.040.0000.000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 04-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 6 Plots94 <-Paste Interval 3 Plots HereePRV Test - 9.5.259/5/202507:1407:1607:1807:2007:2207:249/5/202507:26Time01000200030004000500060007000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)6543Global Event Log3456Intersection IntersectionePRV - Primary Tubing ePRV - Primary IAePRV - Secondary Tubing ePRV - Secondary IA07:15:03 07:21:2807:23:59 07:25:34TP TP864.8 868.1921.2 917.3TPP TPP879.0 913.2817.8 1102IGKP IGKP2000 20002000 2000Conoco Phillips - 3S-719 Interval 7 Plots95 <-Paste Interval 3 Plots HerePressure Test - 9.5.259/5/202507:2807:3007:3207:3407:3607:389/5/202507:40Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)10987Global Event Log78910Intersection IntersectionTesting Globals Testing LocalsPressure Test - Max Pressure Test - Pass07:27:39 07:27:4507:32:33 07:37:28TP TP1088 10889540 9503TPP TPP863.1 894.29600 9548IGKP IGKP25.00 75009611 9611PKP PKP500.4 702.29600 9600Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 05-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 7 Plots96 <-Paste Interval 3 Plots HereADP Chemical Plots - Bucket Test 9.5.259/5/202506:3906:4006:4106:4206:439/5/202506:44Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)ABConoco Phillips - 3S-719 Interval 7 Plots97 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Bucket Test 9.5.259/5/202506:4006:5007:0007:1007:209/5/202507:30Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA7Conoco Phillips - 3S-719 Interval 7 Plots98 Treatment Plot - Interval 79/5/202508:3009:0009:3010:0010:3011:009/5/202511:30Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD3211716151413121110987154318Conoco Phillips - 3S-719 Interval 7 Plots99 ADP Chemical Plots - Interval 79/5/202508:3009:0009:3010:0010:3011:009/5/202511:30Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB211716151413121110987154318Conoco Phillips - 3S-719 Interval 7 Plots100 Blender & LMS Chemical Plot - Interval 79/5/202508:3009:0009:3010:0010:3011:009/5/202511:30Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA211716151413121110987154318Conoco Phillips - 3S-719 Interval 7 Plots101 Net Pressure Plot - Interval 767892100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2472 psi 0 Time = 09/05/25 07:09:50 115.000.0000.000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 05-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 7 Plots102 <-Paste Interval 3 Plots HereTreatment Plot - Interval 89/5/202511:3012:0012:3013:0013:309/5/202514:00Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD3211211211109876543211798Conoco Phillips - 3S-719 Interval 8 Plots103 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 89/5/202511:2011:4012:0012:2012:4013:0013:209/5/202513:40Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB3211211211109876543211798Conoco Phillips - 3S-719 Interval 8 Plots104 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 89/5/202511:2011:4012:0012:2012:4013:0013:209/5/202513:40Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA3211211211109876543211798Conoco Phillips - 3S-719 Interval 8 Plots105 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 834Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2472 psi 0 Time = 09/05/25 07:09:50 115.000.0000.000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 05-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 8 Plots106 <-Paste Interval 3 Plots HereTreatment Plot - Interval 99/5/202514:0014:3015:0015:3016:009/5/202516:30Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD121110987654321121129Conoco Phillips - 3S-719 Interval 9 Plots107 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 99/5/202514:0014:2014:4015:0015:2015:4016:009/5/202516:20Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB121110987654321121129Conoco Phillips - 3S-719 Interval 9 Plots108 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 99/5/202513:4014:0014:2014:4015:0015:2015:4016:009/5/202516:20Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA121110987654321121129Conoco Phillips - 3S-719 Interval 9 Plots109 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 95Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2472 psi 0 Time = 09/05/25 07:09:50 115.000.0000.000Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 05-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 9 Plots110 <-Paste Interval 3 Plots HereePRV Test - 9.6.259/6/202507:1007:1107:1207:1307:1407:1507:1607:179/6/202507:18Time01000200030004000500060007000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)6543Global Event Log3456Intersection IntersectionePRV - Primary Tubing ePRV - Primary IAePRV - Secondary Tubing ePRV - Secondary Tubing07:10:59 07:13:2907:15:39 07:17:35TP TP32.65 10681097 1089TPP TPP983.1 10891132 1075IGKP IGKP1500 15001500 1500Conoco Phillips - 3S-719 Interval 10 Plots111 <-Paste Interval 3 Plots HerePressure Test - 9.6.259/6/202507:2207:2407:2607:2807:309/6/202507:32Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)10987Global Event Log78910Intersection IntersectionTesting Globals Testing LocalsPressure Test - Max Pressure Test - Pass07:21:25 07:21:3207:24:44 07:30:34TP TP1078 10789543 9488TPP TPP573.5 596.89618 9537IGKP IGKP25.00 93009500 9500PKP PKP500.4 487.19500 9500Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 06-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 10 Plots112 <-Paste Interval 3 Plots HereADP Chemical Plots - Bucket Test 9.6.259/6/202506:4406:4606:4806:5006:529/6/202506:54Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300D Conc (gal/Mgal)ABConoco Phillips - 3S-719 Interval 10 Plots113 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Bucket Test 9-69/6/202506:4506:5006:559/6/202507:00Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)Cat-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABAConoco Phillips - 3S-719 Interval 10 Plots114 Treatment Plot - Interval 109/6/202508:0008:3009:0009:3010:009/6/202510:30Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD32112114131211109876543111Conoco Phillips - 3S-719 Interval 10 Plots115 ADP Chemical Plots - Interval 109/6/202508:0008:2008:4009:0009:2009:4010:009/6/202510:20Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300D Conc (gal/Mgal)AB2112114131211109876543111Conoco Phillips - 3S-719 Interval 10 Plots116 Blender & LMS Chemical Plot - Interval 109/6/202508:0008:2008:4009:0009:2009:4010:009/6/202510:20Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)Cat-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA2112114131211109876543111Conoco Phillips - 3S-719 Interval 10 Plots117 Net Pressure Plot - Interval 1067892100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2472 psi 0 Time = 09/06/25 07:01:39 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 06-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 10 Plots118 <-Paste Interval 3 Plots HereTreatment Plot - Interval 119/6/202510:3011:0011:3012:0012:309/6/202513:00Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD321121110987654321121141211Conoco Phillips - 3S-719 Interval 11 Plots119 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 119/6/202510:2010:4011:0011:2011:4012:0012:209/6/202512:40Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300D Conc (gal/Mgal)AB321121110987654321121141211Conoco Phillips - 3S-719 Interval 11 Plots120 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 119/6/202510:2010:4011:0011:2011:4012:0012:209/6/202512:40Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)Cat-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA21121110987654321121141211Conoco Phillips - 3S-719 Interval 11 Plots121 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 113Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2472 psi 0 Time = 09/06/25 07:01:39 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 06-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 11 Plots122 <-Paste Interval 3 Plots HereTreatment Plot - Interval 129/6/202513:0013:3014:0014:309/6/202515:00Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD1211109876543211212Conoco Phillips - 3S-719 Interval 12 Plots123 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 129/6/202513:0013:2013:4014:0014:2014:4015:009/6/202515:20Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300D Conc (gal/Mgal)AB1211109876543211212Conoco Phillips - 3S-719 Interval 12 Plots124 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 129/6/202513:0013:2013:4014:0014:2014:4015:009/6/202515:20Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)Cat-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA1211109876543211212Conoco Phillips - 3S-719 Interval 12 Plots125 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 1245Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2472 psi 0 Time = 09/06/25 07:01:39 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 06-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 12 Plots126 <-Paste Interval 3 Plots HereePRV Test - 9.7.259/7/202507:0807:0907:1007:1107:1207:1307:149/7/202507:15Time01000200030004000500060007000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)6543Global Event Log3456Intersection IntersectionePRV - Primary Tubing ePRV - Primary IAePRV - Secondary Tubing ePRV - Secondary IA07:08:44 07:10:1607:12:14 07:13:54TP TP993.5 984.91048 1040TPP TPP1056 1081982.2 1123IGKP IGKP1500 15001500 1500Conoco Phillips - 3S-719 Interval 13 Plots127 <-Paste Interval 3 Plots HerePressure Test - 9.7.259/7/202507:1607:1807:2007:2207:249/7/202507:26Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)10987Global Event Log78910Intersection IntersectionTesting Globals Testing LocalsPressure Test - Max Pressure Test - Pass07:15:52 07:15:5807:17:28 07:24:03TP TP1033 10339591 9506TPP TPP725.6 742.49689 9577IGKP IGKP25.00 96009600 9600PKP PKP500.4 612.49600 9600Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 07-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 13 Plots128 <-Paste Interval 3 Plots HereADP Chemical Plots - Bucket Test 9.7.259/7/202506:53:3006:54:0006:54:3006:55:0006:55:3006:56:0006:56:3006:57:009/7/202506:57:30Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)ABConoco Phillips - 3S-719 Interval 13 Plots129 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Bucket Test 9.7.259/7/202506:5007:0007:1007:209/7/202507:30Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABAConoco Phillips - 3S-719 Interval 13 Plots130 Treatment Plot - Interval 13 - DFIT9/7/202507:5007:5508:0008:0508:109/7/202508:15Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD7543Conoco Phillips - 3S-719 Interval 13 Plots131 Treatment Plot - Interval 139/7/202508:3009:0009:3010:0010:309/7/202511:00Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD32117161514131211109814Conoco Phillips - 3S-719 Interval 13 Plots132 ADP Chemical Plots - Interval 139/7/202508:0008:3009:0009:3010:0010:309/7/202511:00Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB21171615141312111098754314Conoco Phillips - 3S-719 Interval 13 Plots133 Blender & LMS Chemical Plot - Interval 139/7/202508:0008:3009:0009:3010:0010:309/7/202511:00Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)Cat-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA21171615141312111098754314Conoco Phillips - 3S-719 Interval 13 Plots134 Net Pressure Plot - Interval 13234567892100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2508 psi 0 Time = 09/07/25 07:32:58 1Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 07-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 13 Plots135 <-Paste Interval 3 Plots HereTreatment Plot - Interval 149/7/202511:0011:3012:0012:3013:009/7/202513:30Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD321121110987654321171514Conoco Phillips - 3S-719 Interval 14 Plots136 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 149/7/202511:0011:2011:4012:0012:2012:4013:009/7/202513:20Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB321121110987654321171514Conoco Phillips - 3S-719 Interval 14 Plots137 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 149/7/202508:4009:0009:2009:4010:0010:2010:409/7/202511:00Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA32117161514131211109814Conoco Phillips - 3S-719 Interval 14 Plots138 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 143Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2508 psi 0 Time = 09/07/25 07:32:58 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 07-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 14 Plots139 <-Paste Interval 3 Plots HereTreatment Plot - Interval 159/7/202513:3014:0014:3015:0015:309/7/202516:00Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD1211109876543211215Conoco Phillips - 3S-719 Interval 15 Plots140 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 159/7/202513:2013:4014:0014:2014:4015:0015:209/7/202515:40Time01020304050A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB1211109876543211215Conoco Phillips - 3S-719 Interval 15 Plots141 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 159/7/202513:2013:4014:0014:2014:4015:0015:209/7/202515:40Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA1211109876543211215Conoco Phillips - 3S-719 Interval 15 Plots142 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 1545Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2508 psi 0 Time = 09/07/25 07:32:58 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 07-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 15 Plots143 <-Paste Interval 3 Plots HereePRV Test - 9.8.259/8/202506:5706:5806:5907:0007:0107:0207:0307:049/8/202507:05Time01000200030004000500060007000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)6543Global Event Log3456Intersection IntersectionePRV - Primary Tubing ePRV - Primary IAePRV - Secondary Tubing ePRV - Secondary IA06:57:53 06:59:3207:02:41 07:04:14TP TP926.9 915.5893.7 886.1TPP TPP992.1 975.11006 974.6IGKP IGKP1500 15001500 1500Conoco Phillips - 3S-719 Interval 16 Plots144 <-Paste Interval 3 Plots HerePressure Test - 9.8.259/8/202507:0807:1007:1207:149/8/202507:16Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)10987Global Event Log78910Intersection IntersectionTesting Globals Testing LocalsPressure Test - Max Pressure Test - Pass07:07:06 07:07:1207:08:32 07:14:45TP TP874.0 873.79546 9412TPP TPP692.2 709.39656 9475IGKP IGKP25.00 96009600 9600PKP PKP500.4 603.69600 9600Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 08-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 16 Plots145 <-Paste Interval 3 Plots HereADP Chemical Plots - Bucket Test 9.8.259/8/202506:43:3006:44:0006:44:3006:45:0006:45:3006:46:0006:46:309/8/202506:47:00Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)ABConoco Phillips - 3S-719 Interval 16 Plots146 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Bucket Test 9.8.259/8/202506:2006:2506:3006:359/8/202506:40Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABAConoco Phillips - 3S-719 Interval 16 Plots147 Treatment Plot - Interval 169/8/202507:3008:0008:3009:0009:309/8/202510:00Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD3211413121110987654311716Conoco Phillips - 3S-719 Interval 16 Plots148 ADP Chemical Plots - Interval 169/8/202507:4008:0008:2008:4009:0009:2009:409/8/202510:00Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB3211413121110987654311716Conoco Phillips - 3S-719 Interval 16 Plots149 Blender & LMS Chemical Plot - Interval 169/8/202507:4008:0008:2008:4009:0009:2009:409/8/202510:00Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA3211413121110987654311716Conoco Phillips - 3S-719 Interval 16 Plots150 Net Pressure Plot - Interval 164567892100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2508 psi 0 Time = 09/08/25 06:50:41 1Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 08-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 16 Plots151 <-Paste Interval 3 Plots HereTreatment Plot - Interval 179/8/202510:0010:2010:4011:0011:2011:4012:009/8/202512:20Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD321121110987654321141817Conoco Phillips - 3S-719 Interval 17 Plots152 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 179/8/202510:0010:2010:4011:0011:2011:4012:009/8/202512:20Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB21121110987654321141817Conoco Phillips - 3S-719 Interval 17 Plots153 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 179/8/202510:0010:2010:4011:0011:2011:4012:009/8/202512:20Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA21121110987654321141817Conoco Phillips - 3S-719 Interval 17 Plots154 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 1723Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2508 psi 0 Time = 09/08/25 06:50:41 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 08-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 17 Plots155 <-Paste Interval 3 Plots HereTreatment Plot - Interval 189/8/202512:2012:4013:0013:2013:4014:0014:209/8/202514:40Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD1211109876543211218Conoco Phillips - 3S-719 Interval 18 Plots156 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 189/8/202512:2012:4013:0013:2013:4014:0014:209/8/202514:40Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB1211109876543211218Conoco Phillips - 3S-719 Interval 18 Plots157 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 189/8/202512:2012:4013:0013:2013:4014:0014:209/8/202514:40Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA1211109876543211218Conoco Phillips - 3S-719 Interval 18 Plots158 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 184Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2508 psi 0 Time = 09/08/25 06:50:41 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 08-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 18 Plots159 <-Paste Interval 3 Plots HereePRV Test - 9.9.259/9/202507:0207:0307:0407:0507:0607:0707:0807:099/9/202507:10Time01000200030004000500060007000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)5432Global Event Log2345Intersection IntersectionePRV - Primary Tubing ePRV - Primary IAePRV - Secondary Tubing ePRV - Secondary IA07:03:31 07:05:2107:07:46 07:09:08TP TP1082 11541182 1170TPP TPP1128 12141025 1023IGKP IGKP2000 20002000 2000Conoco Phillips - 3S-719 Interval 19 Plots160 <-Paste Interval 3 Plots HerePressure Test - 9.9.259/9/202507:1507:1607:1707:1807:1907:2007:2107:229/9/202507:23Time010002000300040005000600070008000900010000Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi)Pop-off (psi)5432Global Event Log2345Intersection IntersectionTesting Locals Test GlobalsPressure Test - Max Pressure Test - Pass07:14:46 07:14:5207:16:41 07:22:06TP TP1141 11419532 9435TPP TPP165.7 877.39610 9495IGKP IGKP9600 25.009600 9600PKP PKP500.4 500.49600 9600Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 19 Plots161 <-Paste Interval 3 Plots HereADP Chemical Plots - Bucket Test 9.9.259/9/202506:4906:5006:5106:5206:539/9/202506:54Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)ABConoco Phillips - 3S-719 Interval 19 Plots162 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Bucket Test 9.9.259/9/202506:1606:1706:1806:1906:2006:2106:2206:239/9/202506:24Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA191Conoco Phillips - 3S-719 Interval 19 Plots163 Treatment Plot - Interval 19 - Dart Seat & DFIT9/9/202507:4007:4507:5007:5508:0008:059/9/202508:10Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD5431Conoco Phillips - 3S-719 Interval 19 Plots164 Treatment Plot - Interval 199/9/202508:3009:0009:3010:0010:309/9/202511:00Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD3211716151413121110987120Conoco Phillips - 3S-719 Interval 19 Plots165 ADP Chemical Plots - Interval 199/9/202508:0008:3009:0009:3010:009/9/202510:30Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB32117161514131211109871543120Conoco Phillips - 3S-719 Interval 19 Plots166 Blender & LMS Chemical Plot - Interval 199/9/202507:0007:3008:0008:3009:0009:3010:009/9/202510:30Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA32117161514131211109871543120Conoco Phillips - 3S-719 Interval 19 Plots167 Net Pressure Plot - Interval 19234567892100Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2615 psi 0 Time = 09/09/25 07:58:41 1Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 19 Plots168 <-Paste Interval 3 Plots HereTreatment Plot - Interval 209/9/202511:0011:3012:0012:309/9/202513:00Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD31121110987654321172120Conoco Phillips - 3S-719 Interval 20 Plots169 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 209/9/202510:4011:0011:2011:4012:0012:2012:409/9/202513:00Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB31121110987654321172120Conoco Phillips - 3S-719 Interval 20 Plots170 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 209/9/202510:4011:0011:2011:4012:0012:2012:409/9/202513:00Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA31121110987654321172120Conoco Phillips - 3S-719 Interval 20 Plots171 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 2023Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2615 psi 0 Time = 09/09/25 07:58:41 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 20 Plots172 <-Paste Interval 3 Plots HereTreatment Plot - Interval 219/9/202513:0013:2013:4014:0014:2014:4015:009/9/202515:20Time0100020003000400050006000A0102030405060B02468101214161820C0255075100125150DTreating Pressure (psi)Slurry Rate (bpm)Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal)Gauge BH Pres (psi)Actual BH Temp (°F)ABCCAD121110987654311221Conoco Phillips - 3S-719 Interval 21 Plots173 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 219/9/202513:0013:2013:4014:0014:2014:4015:0015:209/9/202515:40Time05101520253035A0.00.20.40.60.81.01.21.41.61.82.0BWG-36 Conc (lb/Mgal)Losurf-300 Conc (gal/Mgal)AB121110987654311221Conoco Phillips - 3S-719 Interval 21 Plots174 <-Paste Interval 3 Plots HereBlender & LMS Chemical Plot - Interval 219/9/202513:0013:2013:4014:0014:2014:4015:0015:209/9/202515:40Time0.00.51.01.52.02.53.0A0.00.20.40.60.81.01.21.41.61.82.0BLD-6450 Conc (gal/Mgal)CAT-3 Conc (gal/Mgal)BC-140 X2 Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal)MO-67 Conc (gal/Mgal)BAABA121110987654311221Conoco Phillips - 3S-719 Interval 21 Plots175 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 2123Time (min)2345678923456789100100010000A-5-4-3-2-1012345CNet Gauge BH Pres (psi)A Closure Pressure = 2615 psi 0 Time = 09/09/25 10:29:17 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUSJob Date: 09-Sep-2025Sales Order #: 0910285054Well Description: 3S-719 3S-719UWI: 50-103-20919Conoco Phillips - 3S-719 Interval 21 Plots176 Sales Order# - - - - - - - - - - Real-Time QC Sand Sieve Analysis Fann 15 Minute Prejob Break Test Water Analysis Planned Design Stimulation Treatment Appendix Well Summary Chemical Summary Event Log Water Straps Prepared for: Dan Faur September 9, 2025 Harrison Bay County, AK 910285054Conoco Phillips 3S-719Intervals 1-21 Coyote Coyote Formation API: 50-103-20919 Conoco Phillips - 3S-719 Appendix 177 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDERBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In2:34:02 1-2 Seawater Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:34:02 0.151-3 Shut-In Shut-In2:29:16 1-4 27# Linear DFIT 10 1,680 40 40 0:04:00 2:29:16 1.00 1.00 1.00 27.00 1.000.151-5 Shut-In Shut-In2:25:16 1-6 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 2:25:16 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-7 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:56 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-8 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:43:25 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 123 10,300 0:06:41 1:36:06 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 203 34,160 0:12:01 1:29:25 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 197 49,560 0:12:31 1:17:24 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 308 90,580 0:20:19 1:04:52 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 276 92,800 0:18:51 0:44:33 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 190 72,000 0:13:26 0:25:42 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 120 50,600 0:08:46 0:12:16 0.45 1.00 0.50 1.00 1.00 27.00 1.000.151-16 27# Linear Spacer and Dart Drop 20 2,940 70 70 0:03:30 0:03:30 1.00 1.00 1.00 27.00 1.00 0.152-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 1.00 1.00 27.00 1.000.152-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 123 10,300 0:06:41 1:34:21 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 203 34,160 0:12:01 1:27:40 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 197 49,560 0:12:31 1:15:39 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 308 90,580 0:20:19 1:03:07 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 276 92,800 0:18:51 0:42:48 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 190 72,000 0:13:26 0:23:57 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 120 50,600 0:08:46 0:10:31 0.45 1.00 0.50 1.00 1.00 27.00 1.000.152-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 1.00 1.00 27.00 1.00 0.153-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:42:58 1.00 1.00 1.00 27.00 1.000.153-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:40:28 0.45 1.00 0.50 1.00 1.00 27.00 1.000.153-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:30:28 0.45 1.00 0.50 1.00 1.00 27.00 1.000.153-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 2:01:56 0.45 1.00 0.50 1.00 1.00 27.00 1.000.153-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 123 10,300 0:06:41 1:54:38 0.45 1.00 0.50 1.00 1.00 27.00 1.000.153-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 203 34,160 0:12:01 1:47:57 0.45 1.00 0.50 1.00 1.00 27.00 1.000.153-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 197 49,560 0:12:31 1:35:55 0.45 1.00 0.50 1.00 1.00 27.00 1.000.153-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 308 90,580 0:20:19 1:23:24 0.45 1.00 0.50 1.00 1.00 27.00 1.000.153-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 276 92,800 0:18:51 1:03:05 0.45 1.00 0.50 1.00 1.00 27.00 1.000.153-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:44:14 0.45 1.00 0.50 1.00 1.00 27.001.000.153-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:30:48 0.45 1.00 0.50 1.00 1.00 27.001.000.153-12 27# Linear Flush 20 13,464 321 321 0:16:02 0:22:02 1.00 1.00 1.00 27.00 1.000.153-13 Seawater Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 0.153-14 Shut-In Shut-In4-1 Seawater Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:26:57 0.154-2 Shut-In Shut-In2:22:11 4-3 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:22:11 1.00 1.00 1.00 27.00 1.000.154-4 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-5 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-6 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 123 10,300 0:06:41 1:34:21 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 203 34,160 0:12:01 1:27:40 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 197 49,560 0:12:31 1:15:39 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 308 90,580 0:20:19 1:03:07 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 276 92,800 0:18:51 0:42:48 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 190 72,000 0:13:26 0:23:57 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 120 50,600 0:08:46 0:10:31 0.45 1.00 0.50 1.00 1.00 27.00 1.000.154-14 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 1.00 1.00 27.00 1.000.155-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 3:05:58 1.00 1.00 1.00 27.00 1.000.155-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 3:03:28 0.45 1.00 0.50 1.00 1.00 27.00 1.000.155-3 27# Delta Frac Pre-Pad 20 23,960 570 570 0:28:31 2:53:28 0.45 1.00 0.50 1.00 1.00 27.00 1.000.155-4 Seawater Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:24:57 0.155-5 Shut-In Shut-In2:20:11 5-6 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 1.00 1.00 27.00 1.000.155-7 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 1.00 1.00 27.00 1.000.155-8 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 1.00 1.00 27.00 1.000.155-9 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 1.00 1.00 27.00 1.000.155-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 1.00 1.00 27.001.000.155-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 1.00 1.00 27.001.000.155-12 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 1.00 1.00 27.001.000.155-13 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 1.00 1.00 27.001.000.155-14 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 1.00 1.00 27.001.000.155-15 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 1.00 1.00 27.001.000.155-16 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 1.00 1.00 27.00 1.00 0.158/25/25Liquid AdditivesDry Additives50-103-20919910285054Interval 1Coyote@ 21015.03 - 21019.03 ft 104.1 °FInterval 2Coyote@ 20471.68 - 20475.68 ft 104.1 °FInterval 3Coyote@ 19973.37 - 19977.37 ft 104.1 °FInterval 4Coyote@ 19477.91 - 19481.91 ft 104 °FInterval 5Coyote@ 18979.38 - 18983.38 ft 104 °FConoco Phillips - 3S-719Planned Design178 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDERBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)8/25/25Liquid AdditivesDry Additives50-103-209199102850546-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 3:13:39 1.00 1.00 1.00 27.00 1.00 0.156-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 3:11:09 0.45 1.00 0.50 1.00 1.00 27.00 1.000.156-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 3:01:09 0.45 1.00 0.50 1.00 1.00 27.00 1.000.156-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 2:32:38 0.45 1.00 0.50 1.00 1.00 27.00 1.000.156-5 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 2:25:20 0.45 1.00 0.50 1.00 1.00 27.00 1.000.156-6 27# Linear Flush 20 12,612 300 300 0:15:01 2:18:38 1.00 1.00 1.00 27.00 1.000.156-7 Shut-In Shut-In2:03:37 6-8 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:03:37 0.45 1.00 0.50 1.00 1.00 27.00 1.000.156-9 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:53:37 0.45 1.00 0.50 1.00 1.00 27.00 1.000.156-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:46:56 0.45 1.00 0.50 1.00 1.00 27.001.000.156-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:34:55 0.45 1.00 0.50 1.00 1.00 27.001.000.156-12 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:22:23 0.45 1.00 0.50 1.00 1.00 27.001.000.156-13 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 1:02:04 0.45 1.00 0.50 1.00 1.00 27.001.000.156-14 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:43:13 0.45 1.00 0.50 1.00 1.00 27.001.000.156-15 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:29:47 0.45 1.00 0.50 1.00 1.00 27.001.000.156-16 27# Linear Flush 20 12,612 300 300 0:15:01 0:21:01 1.00 1.00 1.00 27.00 1.000.156-17 Seawater Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 0.156-18 Shut-In Shut-In7-1 Seawater Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:47:37 0.157-2 Shut-In Shut-In2:42:51 7-3 27# Linear Spacer and Dart Drop 15 1,470 35 35 0:02:20 2:42:51 1.00 1.00 1.00 27.00 1.000.157-4 27# Linear Displacement 20 12,294 293 293 0:14:38 2:40:31 1.00 1.00 1.00 27.00 1.000.157-5 27# Linear DFIT 10 1,680 40 40 0:04:00 2:25:53 1.00 1.00 1.00 27.00 1.000.157-6 Shut-In Shut-In2:21:53 7-7 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:21:53 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-8 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:53 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-9 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:43:22 0.45 1.00 0.70 1.00 1.00 27.00 1.000.157-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:36:03 0.45 1.00 0.70 1.00 1.00 27.001.000.157-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:29:22 0.45 1.00 0.70 1.00 1.00 27.001.000.157-12 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:17:21 0.45 1.00 0.70 1.00 1.00 27.001.000.157-13 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:04:49 0.45 1.00 0.70 1.00 1.00 27.001.000.157-14 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:44:30 0.45 1.00 0.70 1.00 1.00 27.001.000.157-15 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:25:39 0.45 1.00 0.70 1.00 1.00 27.001.000.157-16 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:12:13 0.45 1.00 0.70 1.00 1.00 27.001.000.157-17 27# Linear Spacer and Dart Drop 20 2,898 69 69 0:03:27 0:03:27 1.00 1.00 1.00 27.00 1.000.158-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:24:23 1.00 1.00 1.00 27.00 1.000.158-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:21:53 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:53 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:43:22 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-5 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:36:03 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-6 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:29:22 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-7 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:17:21 0.45 1.00 0.70 1.00 1.00 27.00 1.000.158-8 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:04:49 0.45 1.00 0.70 1.00 1.00 27.001.000.158-9 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:44:30 0.45 1.00 0.70 1.00 1.00 27.001.000.158-10 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:25:39 0.45 1.00 0.70 1.00 1.00 27.001.000.158-11 27# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:12:13 0.45 1.00 0.70 1.00 1.00 27.001.000.158-12 27# Linear Spacer and Dart Drop 20 2,898 69 69 0:03:27 0:03:27 1.00 1.00 1.00 27.00 1.00 0.159-1 30# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:40:49 1.00 1.00 30.00 1.25 0.159-2 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:38:19 0.50 1.00 1.00 1.00 30.00 1.25 0.159-3 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:28:19 0.50 1.00 1.00 1.00 30.00 1.25 0.159-4 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:59:47 0.50 1.00 1.00 1.00 30.00 1.25 0.159-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:52:29 0.50 1.00 1.00 1.00 30.00 1.25 0.159-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:45:48 0.50 1.00 1.00 1.00 30.00 1.25 0.159-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:33:46 0.50 1.00 1.00 1.00 30.00 1.25 0.159-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:21:15 0.50 1.00 1.00 1.00 30.00 1.250.159-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 1:00:56 0.50 1.00 1.00 1.00 30.00 1.250.159-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:42:05 0.50 1.00 1.00 1.00 30.00 1.250.159-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:28:39 0.50 1.00 1.00 1.00 30.00 1.250.159-12 30# Linear Flush 20 11,658 278 278 0:13:53 0:19:53 1.00 1.00 30.00 1.25 0.159-13 Seawater Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 0.159-14 Shut-In Shut-InInterval 9Coyote@ 16987.95 - 16991.95 ft 103.9 °FInterval 6Coyote@ 18481.54 - 18485.54 ft 104 °FInterval 7Coyote@ 17983.11 - 17987.11 ft 103.9 °FInterval 8Coyote@ 17486.06 - 17490.06 ft 103.9 °FConoco Phillips - 3S-719Planned Design179 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDERBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)8/25/25Liquid AdditivesDry Additives50-103-2091991028505410-1 Seawater Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:28:14 0.1510-2 Shut-In Shut-In2:23:28 10-3 30# Linear Spacer and Dart Drop 15 1,470 35 35 0:02:20 2:23:28 1.00 1.00 30.00 1.250.1510-4 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:21:08 0.50 1.00 1.00 30.00 1.250.1510-5 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:08 0.50 1.00 0.70 1.00 30.00 1.250.1510-6 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:42:37 0.50 1.00 0.70 1.00 30.00 1.250.1510-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:35:18 0.50 1.00 0.70 1.00 30.00 1.250.1510-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:28:37 0.50 1.00 0.70 1.00 30.00 1.250.1510-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:16:36 0.50 1.00 0.70 1.00 30.00 1.250.1510-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:04:04 0.50 1.00 0.70 1.00 30.00 1.250.1510-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:43:45 0.50 1.00 0.70 1.00 30.00 1.250.1510-12 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:24:54 0.50 1.00 0.70 1.00 30.00 1.250.1510-13 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:11:28 0.50 1.00 0.70 1.00 30.00 1.250.1510-14 30# Linear Spacer and Dart Drop 20 2,268 54 54 0:02:42 0:02:42 1.00 1.00 30.00 1.250.1511-1 30# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:23:38 1.00 1.00 30.00 1.250.1511-2 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:21:08 0.50 1.00 1.00 1.00 30.00 1.250.1511-3 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:08 0.50 1.00 1.00 1.00 30.00 1.250.1511-4 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:42:37 0.50 1.00 1.00 1.00 30.00 1.250.1511-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:35:18 0.50 1.00 1.00 1.00 30.00 1.250.1511-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:28:37 0.50 1.00 1.00 1.00 30.00 1.250.1511-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:16:36 0.50 1.00 1.00 1.00 30.00 1.250.1511-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:04:04 0.50 1.00 1.00 1.00 30.00 1.250.1511-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:43:45 0.50 1.00 1.00 1.00 30.00 1.250.1511-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:24:54 0.50 1.00 1.00 1.00 30.00 1.250.1511-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:11:28 0.50 1.00 1.00 1.00 30.00 1.250.1511-12 30# Linear Spacer and Dart Drop 20 2,268 54 54 0:02:42 0:02:42 1.00 1.00 30.00 1.25 0.1512-1 30# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:39:39 1.00 1.00 30.00 1.250.1512-2 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:37:09 0.50 1.00 1.00 1.00 30.00 1.250.1512-3 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:27:09 0.50 1.00 1.00 1.00 30.00 1.250.1512-4 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:58:37 0.50 1.00 1.00 1.00 30.00 1.250.1512-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:51:19 0.50 1.00 1.00 1.00 30.00 1.250.1512-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:44:38 0.50 1.00 1.00 1.00 30.00 1.250.1512-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:32:36 0.50 1.00 1.00 1.00 30.00 1.250.1512-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:20:05 0.50 1.00 1.00 1.00 30.00 1.250.1512-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:59:46 0.50 1.00 1.00 1.00 30.00 1.250.1512-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:40:55 0.50 1.00 1.00 1.00 30.00 1.250.1512-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:27:29 0.50 1.00 1.00 1.00 30.00 1.250.1512-12 30# Linear Flush 20 10,678 254 254 0:12:43 0:18:43 1.00 1.00 30.00 1.250.1512-13 Seawater Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 0.1512-14 Shut-In Shut-In13-1 Seawater Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:49:40 0.1513-2 Shut-In Shut-In2:44:55 13-3 30# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:44:55 1.00 1.00 30.00 1.250.1513-4 30# Linear Displace Dart to Seat 15 10,359 247 247 0:16:27 2:42:55 1.00 1.00 30.00 1.250.1513-5 30# Linear DFIT 10 840 20 20 0:02:00 2:26:28 1.00 1.00 30.00 1.250.1513-6 Shut-In Shut-In2:24:28 13-7 30# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 2:24:28 0.50 1.00 1.00 1.00 30.00 1.250.1513-8 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:08 0.50 1.00 1.00 1.00 30.00 1.250.1513-9 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:42:37 0.50 1.00 1.00 1.00 30.00 1.250.1513-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:35:18 0.50 1.00 1.00 1.00 30.00 1.250.1513-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:28:37 0.50 1.00 1.00 1.00 30.00 1.250.1513-12 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:16:36 0.50 1.00 1.00 1.00 30.00 1.250.1513-13 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:04:04 0.50 1.00 1.00 1.00 30.00 1.250.1513-14 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:43:45 0.50 1.00 1.00 1.00 30.00 1.250.1513-15 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:24:54 0.50 1.00 1.00 1.00 30.00 1.250.1513-16 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:11:28 0.50 1.00 1.00 1.00 30.00 1.250.1513-17 30# Linear Spacer and Dart Drop 20 2,268 54 54 0:02:42 0:02:42 1.00 1.00 30.00 1.250.1514-1 30# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:23:38 1.00 1.00 30.00 1.250.1514-2 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:21:08 0.50 1.00 1.00 1.00 30.00 1.250.1514-3 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:08 0.50 1.00 1.00 1.00 30.00 1.250.1514-4 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:42:37 0.50 1.00 1.00 1.00 30.00 1.250.1514-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:35:18 0.50 1.00 1.00 1.00 30.00 1.250.1514-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:28:37 0.50 1.00 1.00 1.00 30.00 1.250.1514-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:16:36 0.50 1.00 1.00 1.00 30.00 1.250.1514-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:04:04 0.50 1.00 1.00 1.00 30.00 1.250.1514-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:43:45 0.50 1.00 1.00 1.00 30.00 1.250.1514-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:24:54 0.50 1.00 1.00 1.00 30.00 1.250.1514-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:11:28 0.50 1.00 1.00 1.00 30.00 1.250.1514-12 30# Linear Spacer and Dart Drop 20 2,268 54 54 0:02:42 0:02:42 1.00 1.00 30.00 1.25 0.15Interval 12Coyote@ 15454.42 - 15458.42 ft 103.8 °FInterval 13Coyote@ 14955.86 - 14959.86 ft 103.9 °FInterval 14Coyote@ 14458.55 - 14462.55 ft 103.9 °FInterval 10Coyote@ 16449.48 - 16453.48 ft 103.8 °FInterval 11Coyote@ 15952.33 - 15956.33 ft 103.8 °FConoco Phillips - 3S-719Planned Design180 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDERBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)8/25/25Liquid AdditivesDry Additives50-103-2091991028505415-1 30# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:38:31 1.00 1.00 30.00 1.25 0.1515-2 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:36:01 0.50 1.00 1.00 1.00 30.00 1.250.1515-3 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:26:01 0.50 1.00 1.00 1.00 30.00 1.250.1515-4 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:57:29 0.50 1.00 1.00 1.00 30.00 1.250.1515-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:50:11 0.50 1.00 1.00 1.00 30.00 1.250.1515-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:43:30 0.50 1.00 1.00 1.00 30.00 1.250.1515-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:31:28 0.50 1.00 1.00 1.00 30.00 1.250.1515-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:18:57 0.50 1.00 1.00 1.00 30.00 1.250.1515-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:58:38 0.50 1.00 1.00 1.00 30.00 1.250.1515-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:39:47 0.50 1.00 1.00 1.00 30.00 1.250.1515-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:26:21 0.50 1.00 1.00 1.00 30.00 1.250.1515-12 30# Linear Flush 20 9,723 232 232 0:11:34 0:17:34 1.00 1.00 30.00 1.250.1515-13 Seawater Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 0.1515-14 Shut-In Shut-In16-1 Seawater Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:31:14 0.1516-2 Shut-In Shut-In2:26:28 16-3 30# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:26:28 1.00 1.00 30.00 1.250.1516-4 30# Linear Establish Stable Fluid 15 8,400 200 200 0:13:20 2:24:28 1.00 1.00 30.00 1.250.1516-5 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:08 0.50 1.00 1.00 1.00 30.00 1.250.1516-6 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:42:37 0.50 1.00 1.00 1.00 30.00 1.250.1516-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:35:18 0.50 1.00 1.00 1.00 30.00 1.250.1516-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:28:37 0.50 1.00 1.00 1.00 30.00 1.250.1516-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:16:36 0.50 1.00 1.00 1.00 30.00 1.250.1516-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:04:04 0.50 1.00 1.00 1.00 30.00 1.250.1516-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:43:45 0.50 1.00 1.00 1.00 30.00 1.250.1516-12 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:24:54 0.50 1.00 1.00 1.00 30.00 1.250.1516-13 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:11:28 0.50 1.00 1.00 1.00 30.00 1.250.1516-14 30# Linear Spacer and Dart Drop 20 2,268 54 54 0:02:42 0:02:42 1.00 1.00 30.00 1.250.1517-1 30# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:23:38 1.00 1.00 30.00 1.250.1517-2 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:21:08 0.50 1.00 1.00 1.00 30.00 1.250.1517-3 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:08 0.50 1.00 1.00 1.00 30.00 1.250.1517-4 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:42:37 0.50 1.00 1.00 1.00 30.00 1.250.1517-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:35:18 0.50 1.00 1.00 1.00 30.00 1.250.1517-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:28:37 0.50 1.00 1.00 1.00 30.00 1.250.1517-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:16:36 0.50 1.00 1.00 1.00 30.00 1.250.1517-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:04:04 0.50 1.00 1.00 1.00 30.00 1.250.1517-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:43:45 0.50 1.00 1.00 1.00 30.00 1.250.1517-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:24:54 0.50 1.00 1.00 1.00 30.00 1.250.1517-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:11:28 0.50 1.00 1.00 1.00 30.00 1.250.1517-12 30# Linear Spacer and Dart Drop 20 2,268 54 54 0:02:42 0:02:42 1.00 1.00 30.00 1.25 0.1518-1 30# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:37:22 1.00 1.00 30.00 1.25 0.1518-2 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:34:52 0.50 1.00 1.00 1.00 30.00 1.25 0.1518-3 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:24:52 0.50 1.00 1.00 1.00 30.00 1.25 0.1518-4 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:56:21 0.50 1.00 1.00 1.00 30.00 1.25 0.1518-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:49:03 0.50 1.00 1.00 1.00 30.00 1.250.1518-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:42:21 0.50 1.00 1.00 1.00 30.00 1.250.1518-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:30:20 0.50 1.00 1.00 1.00 30.00 1.250.1518-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:17:49 0.50 1.00 1.00 1.00 30.00 1.250.1518-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:57:29 0.50 1.00 1.00 1.00 30.00 1.250.1518-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:38:38 0.50 1.00 1.00 1.00 30.00 1.250.1518-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:25:12 0.50 1.00 1.00 1.00 30.00 1.25 0.1518-12 30# Linear Flush 20 8,767 209 209 0:10:26 0:16:26 1.00 1.00 30.00 1.25 0.1518-13 Seawater Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 0.1518-14 Shut-In Shut-In19-1 Seawater Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:42:05 0.1519-2 Shut-In Shut-In2:37:19 19-3 30# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:37:19 1.00 1.00 30.00 1.25 0.1519-4 30# Linear Displace Dart to Seat 15 7,644 182 182 0:12:08 2:35:19 1.00 1.00 30.00 1.25 0.1519-5 30# Linear DFIT 5 630 15 15 0:03:00 2:23:11 1.00 1.00 30.00 1.25 0.1519-6 Shut-In Shut-In2:20:11 19-7 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.50 1.00 1.00 1.00 30.00 1.25 0.1519-8 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.50 1.00 1.00 1.00 30.00 1.25 0.1519-9 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.50 1.00 1.00 1.00 30.00 1.25 0.1519-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.50 1.00 1.00 1.00 30.00 1.250.1519-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.50 1.00 1.00 1.00 30.00 1.250.1519-12 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.50 1.00 1.00 1.00 30.00 1.250.1519-13 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.50 1.00 1.00 1.00 30.00 1.25 0.1519-14 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.50 1.00 1.00 1.00 30.00 1.25 0.1519-15 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.50 1.00 1.00 1.00 30.00 1.250.1519-16 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.50 1.00 1.00 1.00 30.00 1.25 0.1519-17 30# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 1.00 30.00 1.25 0.15Interval 15Coyote@ 13960.67 - 13964.67 ft 103.9 °FInterval 16Coyote@ 13462.77 - 13466.77 ft 104 °FInterval 17Coyote@ 12964.35 - 12968.35 ft 104 °FInterval 18Coyote@ 12465.88 - 12469.88 ft 104.1 °FInterval 19Coyote@ 11969.22 - 11973.22 ft 104.1 °FConoco Phillips - 3S-719Planned Design181 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.3940981LEASE3S-719SALES ORDERBHST (°F)105LONG-150.1975904FORMATIONCoyoteDATE Max Pressure (psi)8500*Exceeds 80% of burst pressure*Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)8/25/25Liquid AdditivesDry Additives50-103-2091991028505420-1 30# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 1.00 30.00 1.25 0.1520-2 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.50 1.00 1.00 1.00 30.00 1.250.1520-3 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.50 1.00 1.00 1.00 30.00 1.250.1520-4 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.50 1.00 1.00 1.00 30.00 1.250.1520-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.50 1.00 1.00 1.00 30.00 1.250.1520-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.50 1.00 1.00 1.00 30.00 1.250.1520-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.50 1.00 1.00 1.00 30.00 1.250.1520-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.50 1.00 1.00 1.00 30.00 1.250.1520-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.50 1.00 1.00 1.00 30.00 1.250.1520-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.50 1.00 1.00 1.00 30.00 1.250.1520-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.50 1.00 1.00 1.00 30.00 1.250.1520-12 30# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 1.00 30.00 1.25 0.1521-1 30# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:36:12 1.00 1.00 30.00 1.250.1521-2 30# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:33:42 0.50 1.00 1.00 1.00 30.00 1.250.1521-3 30# Delta Frac Pad 20 23,960 570 570 0:28:31 2:23:42 0.50 1.00 1.00 1.00 30.00 1.250.1521-4 30# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:55:11 0.50 1.00 1.00 1.00 30.00 1.250.1521-5 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:47:53 0.50 1.00 1.00 1.00 30.00 1.250.1521-6 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:41:11 0.50 1.00 1.00 1.00 30.00 1.250.1521-7 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:29:10 0.50 1.00 1.00 1.00 30.00 1.250.1521-8 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:16:39 0.50 1.00 1.00 1.00 30.00 1.250.1521-9 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:56:19 0.50 1.00 1.00 1.00 30.00 1.250.1521-10 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:37:28 0.50 1.00 1.00 1.00 30.00 1.250.1521-11 30# Delta Frac Proppant Laden Fluid CarboLite 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:24:02 0.50 1.00 1.00 1.00 30.00 1.250.1521-12 30# Linear Flush 20 7,787 185 185 0:09:16 0:15:16 1.00 1.00 30.00 1.250.1521-13 Seawater Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 0.1521-14 Shut-In Shut-In2,308,342 54,961 62,391 8,473,300Design Total (gal)Design Total (lbs)BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-II BE-6829,1906,932,900(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs)80,71863,000Initial Design Material Volume 1,005.4 2,291.5 1,682.9 909.9 2,291.5 66,015.9 2,636.9 346.316,8201,477,400-Whole Units to be ordered1,264,430-BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-II BE-6117184(gpm) (gpm) (gpm) (gpm) (gpm) ppm ppm ppm-Max Additive Rate 0.4 0.8 0.8 0.8 0.8 25.2 1.7 0.1-Min Additive Rate0.0Fluid Type27# Delta Frac27# LinearSeawaterFreeze Protect30# Delta Frac---Proppant TypeCarboLite 16/20 Ceramic100MWanli 16/20 Ceramic-30# LinearInterval 21Coyote@ 10931.35 - 10935.35 ft 104 °FInterval 20Coyote@ 11429.33 - 11433.33 ft 104.1 °F6:55:38 Conoco Phillips - 3S-719Planned Design182 Interval DateDesigned Proppant (lbs)Proppant in Formation (lbs)Designed Fluid (bbl)Vol Clean (bbl)Vol Slurry (bbl)Pad Percentage Design Pad Percentage Actual Proppant Aggressiveness (lb/bbl Clean)Notes1 8/25/2025 403,000 400,668 2,465 2407 2,411 33.6 33.7 2792 8/25/2025 403,000 326,628 2,416 2207 2,210 33.6 35.6 249 Design Cut Short - ACE issue3 8/25/2025 403,000 403,558 2,732 2740 2,872 31.6 33.9 274 Swapped to CarboLite mid stage4 8/26/2025 403,000 401,056 2,420 2490 2,916 33.6 27.3 2665 9/4/2025 403,000 404,884 3,210 2631 3,061 28.0 27.8 280Dart seat pressured out pumps. Eline perforated to allow injection6 9/4/2025 413,300 405,515 3,334 3335 3,765 26.6 25.2 237 LMS issues, shut down mid stage to resolve7 9/5/2025 403,000 404,459 2,792 2685 3,114 28.0 27.6 276 Swapped to freshwater8 9/5/2025 403,000 400,084 2,450 2403 2,828 28.0 27.8 276 Pumped with freshwater9 9/5/2025 403,000 401,722 2,689 2641 3,068 28.0 27.8 277 Pumped with freshwater10 9/6/2025 403,000 403,064 2,444 2377 2,805 28.0 27.7 277 Pumped with freshwater11 9/6/2025 403,000 403,056 2,435 2423 2,851 28.0 27.6 275 Pumped with freshwater12 9/6/2025 403,000 401,156 2,665 2637 3,063 28.0 27.7 275 Pumped with freshwater13 9/7/2025 403,000 402,041 2,706 2578 3,005 28.0 27.8 278 Pumped with freshwater14 9/7/2025 403,000 402,725 2,435 2382 2,809 28.0 27.7 277 Pumped with freshwater15 9/7/2025 403,000 403,118 2,643 2602 3,030 28.0 27.5 274 Pumped with freshwater16 9/8/2025 403,000 401,481 2,439 2346 2,772 28.0 27.9 278 Pumped with freshwater17 9/8/2025 403,000 401,297 2,435 2343 2,769 28.0 27.9 279 Pumped with freshwater18 9/8/2025 403,000 401,648 2,620 2553 2,979 28.0 27.9 279 Pumped with freshwater19 9/9/2025 403,000 402,103 2,617 2573 3,000 28.0 27.4 270 Pumped with freshwater20 9/9/2025 403,000 400,758 2,416 2371 2,797 28.0 27.6 273 Pumped with freshwater21 9/9/2025 403,000 400,629 2,597 2523 2,948 28.0 27.5 272 Pumped with freshwater 3S-719 Interval HighlightsConoco Phillips - 3S-719Well Summary183 CustomerConoco Phillips FormationCoyoteLease3S-719API50-103-20919DateInterval Summary - Chemicals BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-II BE-6(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs)Prime Up00000000145 105 75 105 105 2835 105 72240 100 70 100 100 2561 100 0350 125 85 115 115 2993 115 0450 110 60 105 100 2097 110 48544 106 82 99 104 2709 102 18666 128 46 161 150 3919 150 25749 167 80 125 117 3317 117 20841 134 82 105 124 2510 105 16940 70 48 0 88 3002 175 181055 150 176 0 126 2961 124 181146 91 92 0 91 2873 127 201261 109 97 0 109 3285 149 101335 110 119 0 115 3143 125 101445 135 140 0 101 3036 120 101546 74 139 0 106 3116 155 101663 115 112 0 84 2873 122 101746 135 75 0 95 3166 123 401846 93 75 0 104 2998 105 141942 95 60 0 116 3219 134 152045 80 94 0 95 2713 125 152148 73 73 0 108 2829 91 16Total 1003 2305 1880 915 2253 62155 2579 405w/o Prime Up1003 2305 1880 915 2253 62155 2579 405Interval8/25/2025Dry AdditivesLiquid AdditivesConoco Phillips - 3S-719 Chemical Summary184 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres 1 05:58:53 (08/25/25) Start Job Starting Job 0 0 0 0 0 1 05:58:53 (08/25/25) Next Treatment Treatment Interval 1 0 0 0 0 0 2 6:56:24 Other Other 0 -1 -7 0 1887 3 7:22:33 Prime Pumps Prime Pumps 0 100 139 0 1884 4 7:34:59 Pressure Test ePRV - Primary Tubing 0 1047 1051 0 1884 5 7:42:38 Pressure Test ePRV - Secondary Tubing 0 978 629 0 1884 6 7:44:22 Pressure Test ePRV - Primary IA 0 971 359 0 1884 7 7:47:34 Pressure Test ePRV - Secondary IA 0 959 334 0 1884 8 7:51:07 Pressure Test Pressure Test - Global 0 949 118 0 1884 9 7:51:42 Pressure Test Pressure Test - Locals 0 948 119 0 1884 10 7:56:22 Pressure Test Pressure Test - Max' 0 9459 9525 0 1884 11 8:00:54 Pressure Test Pressure Test - Pass 0 9413 9485 0 1884 12 8:21:31 Other Octiv Troubleshoot 0 20 3 0 1994 13 8:49:41 Open Well Open Well 0 512 425 0 1934 14 8:52:06 Other Start DFIT 1.12 1444 1554 2.5 3034 15 8:57:47 ISIP ISIP 40.1 955 919 0 2615 16 9:02:44 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 40.1 913 854 0 2581 17 9:07:46 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 40.1 881 810 0 2548 18 9:12:45 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 40.1 842 772 0 2505 19 9:35:37 Other Resume Pumping 40.11 623 690 0.2 2329 20 9:40:38 Other Abnormal Pressure Spike 95.93 4658 4898 20.2 5772 21 9:52:36 Alarm Delta Stage At Top Perf = 4 336.87 3352 3619 20.2 4174 22 9:54:36 Alarm Delta Stage At Top Perf = 6 377.52 3339 3578 20.2 4118 23 10:01:57 Alarm Delta Stage At Top Perf = 7 525.03 3335 3584 20.1 4154 24 10:30:20 Alarm Delta Stage At Top Perf = 8 1096.78 2757 3017 20 3866 25 10:38:06 Alarm Delta Stage At Top Perf = 9 1252.15 2884 3147 20 3976 26 10:43:55 Alarm Delta Stage At Top Perf = 10 1368.12 2904 3172 19.8 4078 27 10:55:48 Alarm Delta Stage At Top Perf = 11 1604.95 3063 3333 19.9 4235 28 11:07:40 Alarm Delta Stage At Top Perf = 8 1841.1 3321 3603 19.9 4432 29 11:07:55 Alarm Delta Stage At Top Perf = 12 1846.06 3332 3625 19.9 4442 30 11:28:37 Alarm Delta Stage At Top Perf = 13 2257.82 3464 3747 19.9 4547 31 11:37:02 Other Debris Through Pump 2425.28 3520 3804 20 4592 32 11:47:25 Alarm Delta Stage At Top Perf = 14 2632.17 3641 3922 19.9 4703 2 11:56:39 (08/25/25) Next Treatment Treatment Interval 2 2819.17 4066 4257 20.7 4787 33 11:56:40 Drop Ball Drop Dart for Interval 02 2819.17 4065 4257 20.7 4785 34 12:00:12 Alarm Delta Stage At Top Perf = 15 2892.85 3608 3822 20.8 4808 35 12:04:27 Other Rate Dropped for Dart - Mistakingly Early 2981.55 2928 3075 20.7 4214 36 12:12:16 Alarm Delta Stage At Top Perf = 16 3096.51 2422 2620 14.6 3356 37 12:12:52 Ball on Seat Ball on Seat 3105.05 2410 2606 14.6 3366 38 12:13:04 Break Formation Break Formation 3107.96 5165 5578 14.5 4587 39 12:15:43 Alarm Delta Stage At Top Perf = 1 3149.17 2833 3048 19.6 3717 40 12:18:37 Alarm Delta Stage At Top Perf = 2 3206.77 2891 3109 20 3811 41 12:23:12 Alarm Delta Stage At Top Perf = 3 3298.31 3057 3281 20 3976 42 12:51:40 Alarm Delta Stage At Top Perf = 4 3868.37 2962 3224 20 4011 43 12:59:00 Alarm Delta Stage At Top Perf = 5 4014.96 2875 3136 20 4054 44 13:05:42 Alarm Delta Stage At Top Perf = 6 4148.82 2919 3191 20.2 4119 45 13:17:38 Alarm Delta Stage At Top Perf = 7 4389.65 3118 3417 20.1 4266 46 13:30:07 Alarm Delta Stage At Top Perf = 8 4639.79 3634 3961 20 4521 47 13:50:25 Alarm Delta Stage At Top Perf = 9 5045.18 3890 4219 19.9 4775 48 13:53:27 Other Valves on Pump 454 5104.39 3594 3971 16.4 4677 49 14:00:56 Other ACE 1 Shut Down 5249.54 3795 4121 20 4766 50 14:01:36 Other Cut Zone Short After Cutting Screws 5262.98 3835 4124 20.4 4760 51 14:07:03 Drop Ball Drop Dart for Interval 03 5375.42 4010 4213 20.8 4794 3 14:07:07 (08/25/25) Next Treatment Treatment Interval 3 5376.81 3999 4209 20.8 4800 52 14:08:54 Alarm Delta Stage At Top Perf = 10 5413.82 3750 3936 20.8 4796 53 14:16:34 Other Drop Rate until Dart Seat 5573.44 2920 3158 20.9 3812 54 14:21:58 Alarm Delta Stage At Top Perf = 12 5653.28 2694 2907 14.6 3369 55 14:22:12 Ball on Seat Dart on Seat 5656.68 2703 2931 14.5 3380 56 14:22:25 Break Formation Break Formation 5659.83 5790 6042 14.5 6235 57 14:25:08 Alarm Delta Stage At Top Perf = 1 5699.21 3433 3650 14.5 4072 58 14:33:19 Alarm Delta Stage At Top Perf = 3 5839.28 4003 4212 20.4 4594 59 15:00:47 Alarm Delta Stage At Top Perf = 4 6400.2 3121 3335 20.2 4069 60 15:13:42 Alarm Delta Stage At Top Perf = 5 6660.63 3089 3333 20.1 4117 61 15:21:23 Alarm Delta Stage At Top Perf = 6 6814.67 3123 3383 20 4236 62 15:33:25 Alarm Delta Stage At Top Perf = 7 7054.93 3248 3522 20.1 4363 63 15:45:53 Alarm Delta Stage At Top Perf = 8 7305.53 3272 3545 20.1 4399 64 16:04:31 Alarm Delta Stage At Top Perf = 1 7679.25 3380 3668 20 4456 65 16:04:45 Alarm Delta Stage At Top Perf = 8 7683.93 3388 3648 20 4450 66 16:09:12 Alarm Delta Stage At Top Perf = 9 7772.93 3457 3717 20 4526 67 16:24:39 Alarm Delta Stage At Top Perf = 10 8083.05 3609 3891 20.1 4642 68 16:37:40 Alarm Delta Stage At Top Perf = 11 8350.53 3465 3629 21 4658 69 16:47:22 ISIP ISIP 8550.48 827 91 0 2624 70 16:52:21 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 8550.48 64 98 0 2604 71 16:57:21 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 8550.48 0 28 0 2592 72 17:02:22 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 8550.48 46 84 0 2584 Event Log 8.25.25 Conoco Phillips - 3S-719 Event Log 8.25 185 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres 1 05:57:09 (08/26/25) Other Crew Arrived on Location ---- ---- ---- ---- ---- 2 6:04:32 Start Job Starting Job 0 -15 -5 0 0 1 06:04:32 (08/26/25) Next Treatment Treatment Interval 1 0 -15 -5 0 0 3 6:29:37 Pre-Job Safety Meeting Pre-Job Safety Meeting 0 0 -5 0 0 4 7:16:33 Prime Pumps Prime Pumps 0 92 112 0 2121 4 07:17:05 (08/26/25) Next Treatment Treatment Interval 4 0 208 282 0 2121 5 7:27:27 Pressure Test ePRV - Primary Tubing 0 701 760 0 2120 6 7:28:56 Pressure Test ePRV - Primary IA 0 613 337 0 2120 7 7:31:18 Pressure Test ePRV - Secondary Tubing 0 716 760 0 2120 8 7:32:41 Pressure Test ePRV - Secondary IA 0 757 730 0 2120 9 7:35:17 Pressure Test Pressure Test - Locals 0 1301 1265 0 2119 10 7:35:20 Pressure Test Pressure Test - Global 0 1318 1345 0 2119 11 7:38:45 Pressure Test Pressure Test - Max 0 9476 9559 0 2118 12 7:43:38 Pressure Test Pressure Test - Pass 0 9387 9465 0 2117 13 8:06:26 Open Well Open Well 0 544 469 0 2139 14 8:14:09 Drop Ball Drop Ball For Interval 04 28.01 2295 2445 15.2 3431 15 8:32:44 Ball on Seat Ball on Seat 309.54 2813 2999 15 3430 16 8:32:55 Break Formation Break Formation 312.28 5232 5505 14.9 6188 17 8:32:57 Alarm Delta Stage At Top Perf = 2 312.78 5522 5812 14.9 5562 18 8:37:38 Alarm Delta Stage At Top Perf = 3 391.64 3422 3622 20.1 3887 19 8:44:50 Alarm Delta Stage At Top Perf = 4 537.44 3775 3957 20.2 4305 20 9:13:09 Alarm Delta Stage At Top Perf = 5 1109.34 3166 3376 20 4057 21 9:20:32 Alarm Delta Stage At Top Perf = 6 1256.48 3080 3288 19.9 4060 22 9:27:13 Alarm Delta Stage At Top Perf = 7 1390.01 3169 3396 20.1 4186 23 9:39:12 Alarm Delta Stage At Top Perf = 8 1630.57 3278 3521 20.1 4311 24 9:51:40 Alarm Delta Stage At Top Perf = 9 1880.72 3380 3621 20.1 4367 25 10:11:53 Alarm Delta Stage At Top Perf = 10 2286.1 3332 3579 20 4355 26 10:30:40 Alarm Delta Stage At Top Perf = 11 2662.44 3325 3589 20 4373 27 10:42:29 Drop Ball Drop Dart for Interval 05 2901.35 3754 3883 20.7 4439 5 10:42:41 (08/26/25) Next Treatment Treatment Interval 5 2905.27 3751 3860 20.7 4436 28 10:43:30 Alarm Delta Stage At Top Perf = 12 2922.56 3667 3839 20.8 4438 29 10:55:00 Ball on Seat Dart on Seat 3162.28 2643 2806 20.9 3441 30 11:05:03 Other Bleed Down on Surface 3169.89 6572 6633 0 8416 31 11:15:42 Other Bleed Off On Surface 3173.2 6064 6075 0 7788 32 11:18:48 Alarm Delta Stage At Top Perf = 13 3175.46 6183 6484 3.8 6126 33 11:21:05 Other Bleed Off On Surface 3176.65 6008 6058 0 7846 34 11:27:14 Other Bleed Off on Surface 3180.75 6143 6198 0 7988 35 11:33:30 Other Bleed Off on Surface 3185.78 6472 6527 0 8320 36 11:42:06 Other Bleed Off on Surface 3190.7 6207 6259 0 8055 37 11:46:57 Other Rig Down 3190.84 117 306 1.2 4171 38 11:50:31 Alarm Delta Stage At Top Perf = 1 3210.1 287 314 6 4124 Event Log 8.26.25 Conoco Phillips - 3S-719 Event Log 8.26 186 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres 1 06:25:22 (09/04/25) Start Job Starting Job 0 0 0 0 0 1 06:25:22 (09/04/25) Next Treatment Treatment Interval 1 0 0 0 0 0 2 7:06:34 Prime Pumps Prime Pumps 0 65 94 0 2081 3 7:21:22 Pressure Test ePRV - Primary Tubing 0 1576 1632 0 2081 4 7:23:48 Pressure Test ePRV - Secondary Tubing 0 1594 1672 0 2081 5 7:26:08 Pressure Test ePRV - Primary IA 0 1605 1120 0 2081 6 7:27:48 Pressure Test ePRV - Secondary IA 0 1601 1024 0 2081 7 7:35:24 Pressure Test Testing Globals 0 251 270 0 2081 8 7:35:30 Pressure Test Testing Locals 0 273 308 0 2081 9 7:40:27 Pressure Test Pressure Test - Max 0 9466 9580 0 2081 10 7:46:05 Pressure Test Pressure Test - Pass 0 9455 9526 0 2081 5 08:51:28 (09/04/25) Next Treatment Treatment Interval 5 0 90 93 0 2081 11 9:55:51 Open Well Open Well 0 887 802 0 2343 12 10:03:06 Other Octiv not reading rate 54.7 2596 2811 13.8 3738 13 10:19:27 Start Pad Good Xlink (Start Pad)124.38 2560 2732 15.2 3511 14 10:28:41 Alarm Delta Stage At Top Perf = 3 305.43 3024 3218 20.1 3774 15 10:35:09 Alarm Delta Stage At Top Perf = 4 434.71 3553 3758 19.9 4054 16 11:00:43 Other Drop Tracer 942.76 3417 3618 19.8 4130 17 11:03:56 Alarm Delta Stage At Top Perf = 5 1006.7 3347 3567 19.7 4134 18 11:11:22 Alarm Delta Stage At Top Perf = 6 1153.08 3222 3439 19.7 4068 19 11:18:08 Other Pump 454 Cavitating 1284.88 3212 3421 19.3 4162 20 11:18:16 Alarm Delta Stage At Top Perf = 7 1287.38 2997 3239 18.2 4040 21 11:24:55 Other Pump 454 Cavitating 1415.95 3259 3472 20 4192 22 11:30:32 Alarm Delta Stage At Top Perf = 8 1527.64 3281 3517 19.9 4245 23 11:43:04 Alarm Delta Stage At Top Perf = 9 1777.36 3345 3548 19.9 4297 24 11:48:10 Other Drop Tracer 1879.16 3329 3539 20 4289 25 12:03:27 Alarm Delta Stage At Top Perf = 10 2183.43 3314 3537 19.9 4294 26 12:08:59 Other Dart Loaded 2293.43 3307 3549 19.8 4292 27 12:22:24 Alarm Delta Stage At Top Perf = 11 2559.35 3312 3587 19.8 4337 28 12:26:27 Other Shut Gate on Bin 2639.03 3326 3589 19.8 4350 29 12:33:28 Drop Ball Launch Dart 2781.66 3611 3697 20.6 4398 6 12:33:35 (09/04/25) Next Treatment Treatment Interval 6 2784.07 3597 3668 20.6 4403 30 12:35:19 Alarm Delta Stage At Top Perf = 12 2819.73 3379 3457 20.6 4410 31 12:44:05 Other Slow for Dart 3001.22 2545 2685 20.7 3420 32 12:44:54 Alarm Delta Stage At Top Perf = 13 3014.49 2286 2432 14.7 3208 33 12:47:17 Ball on Seat Dart on Seat 3050.46 2359 2496 15.1 3188 34 12:47:28 Break Formation Break Formation 3053.22 5379 5463 15.1 6119 35 12:49:18 Alarm Delta Stage At Top Perf = 1 3083.87 2953 3078 20.1 3627 36 12:49:25 Alarm Delta Stage At Top Perf = 12 3086.21 2945 3073 20.1 3628 37 12:49:26 Alarm Delta Stage At Top Perf = 1 3086.54 2944 3073 20.1 3627 38 12:51:57 Alarm Delta Stage At Top Perf = 2 3136.95 2841 2986 20 3658 39 13:01:14 Alarm Delta Stage At Top Perf = 3 3322.8 2929 3074 20 3723 40 13:28:03 Other LMS Issue; Cutting screws 3858.36 2865 3075 20.2 3731 41 13:29:47 Alarm Delta Stage At Top Perf = 4 3893.7 2869 3092 20.4 3732 42 13:36:56 Alarm Delta Stage At Top Perf = 5 4040.09 2729 2827 20.5 3829 43 13:45:07 Alarm Delta Stage At Top Perf = 12 4208.01 1264 1376 20.5 3323 44 14:43:17 Other Sand Screw Siezing Up 4441.57 2508 2752 19.7 3398 45 14:45:56 Other Emptying Hopper to help clear sand from screw 4494.06 2653 2898 19.7 3543 46 14:46:38 Alarm Delta Stage At Top Perf = 2 4508.29 2704 2959 19.9 3610 47 14:46:39 Other Dropping Rate While Troubleshooting Screw 4508.62 2706 2955 19.9 3612 48 14:50:36 Alarm Delta Stage At Top Perf = 5 4568.77 2851 3048 15.2 3707 49 14:51:29 Other Screws Cleared; Loading Hopper 4581.9 2893 3095 15.1 3737 50 14:57:54 Alarm Delta Stage At Top Perf = 6 4702.85 2983 3225 20 3919 51 15:12:04 Other Pump 177 Cavitating 4985.54 3053 3293 19.9 4030 52 15:16:28 Alarm Delta Stage At Top Perf = 7 5073.21 3125 3399 19.8 4112 53 15:29:03 Alarm Delta Stage At Top Perf = 8 5326.23 3212 3473 20.1 4184 54 15:32:21 Other Drop Tracer 5392.39 3209 3445 20.2 4192 55 15:46:59 Alarm Delta Stage At Top Perf = 9 5686.92 3247 3477 20.1 4197 56 16:05:29 Other Drop Tracer 6057.97 3158 3405 20 4169 57 16:05:42 Alarm Delta Stage At Top Perf = 10 6062.65 3150 3354 20 4167 58 16:10:39 Other Shut Gate on Mover 6161.54 3192 3419 20 4186 59 16:18:52 Alarm Delta Stage At Top Perf = 11 6330.61 3221 3321 20.8 4229 60 16:27:12 Alarm Delta Stage At Top Perf = 12 6504.34 2132 2184 20.9 3350 61 16:27:51 Alarm Delta Stage At Top Perf = 11 6517.93 2055 2120 20.9 3282 62 16:27:52 Alarm Delta Stage At Top Perf = 12 6518.27 2054 2119 20.9 3281 63 16:28:39 ISIP ISIP 6530.95 1059 66 0 2622 64 16:33:41 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 6530.95 108 124 0 2617 65 16:38:40 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 6530.95 38 41 0 2602 66 16:43:40 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 6530.95 6 11 0 2591 Event Log 9.4.25 Conoco Phillips - 3S-719 Event Log 9.4 187 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres 1 6:18:53 Start Job Starting Job 0 0 0 0 0 1 6:18:53 Next Treatment Treatment Interval 1 0 0 0 0 0 2 6:54:14 Prime Pumps Prime Pumps 0 24 -4 0 2092 7 7:05:59 Next Treatment Treatment Interval 7 0 158 148 0 2090 3 7:15:02 Pressure Test ePRV - Primary Tubing 0 865 879 0 2088 4 7:21:28 Pressure Test ePRV - Primary IA 0 868 913 0 2086 5 7:23:59 Pressure Test ePRV - Secondary Tubing 0 921 818 0 2086 6 7:25:34 Pressure Test ePRV - Secondary IA 0 917 1102 0 2086 7 7:27:38 Pressure Test Testing Globals 0 1088 863 0 2085 8 7:27:45 Pressure Test Testing Locals 0 1088 894 0 2085 9 7:32:32 Pressure Test Pressure Test - Max 0 9540 9600 0 2084 10 7:37:27 Pressure Test Pressure Test - Pass 0 9503 9548 0 2083 11 8:10:01 Open Well Open Well 0.28 619 526 0 2138 12 8:11:13 Other Load Dart 3.81 2446 2547 12.9 3611 13 8:12:14 Drop Ball Launch Dart 18.07 2624 2687 14.2 3746 14 8:29:09 Ball on Seat Dart on Seat 274.53 1692 1719 15.3 3060 15 8:29:19 Break Formation Break Formation 277.34 4426 4358 15.3 4823 16 8:30:15 Alarm Delta Stage At Top Perf = 1 291.04 1740 1719 10.2 3181 17 8:30:19 Alarm Delta Stage At Top Perf = 3 291.69 1676 1650 9.8 3149 18 8:32:40 Alarm Delta Stage At Top Perf = 4 315.04 1600 1633 10 3102 19 9:01:12 Open Well Open Well 318.86 702 635 0 2366 20 9:17:53 Alarm Delta Stage At Top Perf = 5 589.43 2798 2953 19.8 3602 21 9:18:56 Alarm Delta Stage At Top Perf = 7 610.02 2887 3022 19.7 3632 22 9:24:32 Alarm Delta Stage At Top Perf = 8 722.28 3144 3283 20 3755 23 9:43:39 Other Drop Tracer 1103.7 3193 3351 19.9 3863 24 9:53:14 Alarm Delta Stage At Top Perf = 9 1293.8 3057 3250 19.8 3835 25 10:00:38 Alarm Delta Stage At Top Perf = 10 1440.15 3006 3198 20 3861 26 10:07:22 Alarm Delta Stage At Top Perf = 11 1574.36 2994 3163 19.8 3940 27 10:19:30 Alarm Delta Stage At Top Perf = 12 1814.6 2764 2935 19.7 3823 28 10:32:11 Alarm Delta Stage At Top Perf = 13 2065.11 2865 3053 19.8 3914 29 10:52:49 Alarm Delta Stage At Top Perf = 14 2471.07 2819 2993 19.6 3942 30 10:59:38 Other Load Dart 2604.96 2824 2993 19.6 3944 31 11:12:02 Alarm Delta Stage At Top Perf = 15 2847.36 2845 3042 19.5 3958 32 11:12:23 Other Drop Tracer 2854.27 2835 3010 19.5 3957 33 11:17:43 Other Shut gate on bin 2958.4 2849 3034 19.5 3969 34 11:24:48 Drop Ball Launch Dart 3100.05 3185 3252 20.3 4049 8 11:24:56 Next Treatment Treatment Interval 8 3102.78 3172 3248 20.3 4050 35 11:25:11 Alarm Delta Stage At Top Perf = 16 3107.9 3148 3214 20.3 4047 36 11:33:10 Start Pad Good Xlink (Start Pad)3271.16 2396 2505 20.5 3433 37 11:34:58 Other Slow for Dart 3308 2291 2395 20.4 3253 38 11:35:33 Alarm Delta Stage At Top Perf = 17 3317.96 2028 2094 14.5 3042 39 11:37:37 Ball on Seat Dart on Seat 3347.7 2163 2279 14.5 3045 40 11:37:48 Break Formation Break Formation 3350.38 5233 5316 14.4 6139 41 11:39:59 Alarm Delta Stage At Top Perf = 1 3387.72 2648 2749 20.1 3453 42 11:42:33 Alarm Delta Stage At Top Perf = 2 3439.49 2669 2785 20.1 3546 43 11:48:45 Alarm Delta Stage At Top Perf = 3 3564.06 2905 3029 20.1 3764 44 12:17:20 Alarm Delta Stage At Top Perf = 4 4134.2 3098 3284 19.7 3924 45 12:24:49 Alarm Delta Stage At Top Perf = 5 4280.68 3063 3258 19.6 3950 46 12:31:38 Alarm Delta Stage At Top Perf = 6 4414.88 3175 3350 19.8 4063 47 12:43:47 Alarm Delta Stage At Top Perf = 7 4655.22 3074 3298 19.7 3996 48 12:56:30 Alarm Delta Stage At Top Perf = 8 4905.79 3147 3345 19.7 4061 49 13:17:07 Alarm Delta Stage At Top Perf = 9 5312.07 3101 3297 19.7 4128 50 13:36:11 Alarm Delta Stage At Top Perf = 10 5688.23 3036 3241 19.7 4106 51 13:42:23 Other Shut bin on gate 5810.24 3061 3292 19.7 4114 52 13:48:34 Drop Ball Launch Dart 5935.58 3389 3468 20.5 4159 9 13:48:39 Next Treatment Treatment Interval 9 5937.3 3383 3453 20.5 4169 53 13:49:13 Alarm Delta Stage At Top Perf = 11 5949.04 3323 3367 20.5 4164 54 13:57:22 Start Pad Good Xlink (Start Pad)6115.93 2661 2856 20.4 3532 55 13:57:48 Alarm Delta Stage At Top Perf = 12 6124.86 2635 2826 20.4 3472 56 13:58:26 Other Slow for dart 6137.57 2606 2788 20.4 3395 57 14:01:08 Ball on Seat Dart on Seat 6179.12 2333 2513 14.6 3099 58 14:01:20 Break Formation Break Formation 6182.07 5487 5730 14.5 5811 59 14:03:14 Alarm Delta Stage At Top Perf = 1 6214.35 3083 3271 20.1 3616 60 14:03:24 Alarm Delta Stage At Top Perf = 12 6217.72 3079 3260 20.1 3605 61 14:03:28 Alarm Delta Stage At Top Perf = 1 6219.07 3081 3274 20 3634 62 14:05:57 Alarm Delta Stage At Top Perf = 2 6269.02 3297 3507 20.1 3797 63 14:12:28 Alarm Delta Stage At Top Perf = 3 6399.45 3316 3527 20.1 3914 64 14:31:59 Other Drop Tracer 6790.95 3291 3490 20 3831 65 14:40:56 Alarm Delta Stage At Top Perf = 4 6970.35 3077 3331 20 3754 66 14:48:16 Alarm Delta Stage At Top Perf = 5 7116.64 3034 3271 19.9 3753 67 14:55:01 Alarm Delta Stage At Top Perf = 6 7250.67 3198 3449 19.8 3877 68 15:07:03 Alarm Delta Stage At Top Perf = 7 7491.1 3369 3623 20 4021 69 15:19:34 Alarm Delta Stage At Top Perf = 8 7741.36 3411 3680 20 4081 70 15:39:55 Alarm Delta Stage At Top Perf = 9 8147.44 3461 3726 19.9 4103 71 15:58:52 Alarm Delta Stage At Top Perf = 10 8523.69 3586 3855 19.9 4185 72 16:05:00 Other Shut gate on bin 8645.03 3548 3838 19.8 4184 73 16:12:13 Alarm Delta Stage At Top Perf = 11 8792.17 3572 3625 20.6 4245 74 16:21:29 Alarm Delta Stage At Top Perf = 12 8983.75 793 827 16.6 3146 75 16:21:38 ISIP ISIP 8983.91 958 46 0 2601 76 16:25:08 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 8983.91 21 11 0 2629 77 16:30:04 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 8983.91 24 102 0 2617 78 16:35:06 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 8983.91 31 22 0 2608 Event Log 9.5.25 Conoco Phillips - 3S-719 Event Log 9.5 188 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres 1 6:10:42 Start Job Starting Job 0 33 -4 0 1958 1 6:10:42 Next Treatment Treatment Interval 1 0 33 -4 0 1958 2 6:57:58 Prime Pumps Prime Pumps 0 33 75 0 1952 3 7:10:59 Pressure Test ePRV - Primary Tubing 0 33 983 0 1950 4 7:13:28 Pressure Test ePRV - Primary IA 0 1068 1089 0 1950 5 7:15:38 Pressure Test ePRV - Secondary Tubing 0 1097 1132 0 1950 6 7:17:34 Pressure Test ePRV - Secondary Tubing 0 1089 1075 0 1949 7 7:21:25 Pressure Test Testing Globals 0 1078 574 0 1949 8 7:21:31 Pressure Test Testing Locals 0 1078 597 0 1949 9 7:24:43 Pressure Test Pressure Test - Max 0 9543 9618 0 1948 10 7:30:33 Pressure Test Pressure Test - Pass 0 9488 9537 0 1948 10 7:32:12 Next Treatment Treatment Interval 10 0 179 102 0 1947 11 7:55:21 Open Well Open Well 0 551 444 0 2060 12 7:56:53 Other Load Dart 7.48 2757 2870 15.2 3897 13 7:57:41 Drop Ball Launch Dart 19.95 2287 2310 15.3 3358 14 8:09:23 Start Pad Good Xlink (Start Pad)195.78 2364 2538 14.9 3031 15 8:13:52 Ball on Seat Dart on Seat 262.35 2793 2971 14.9 3088 16 8:14:03 Break Formation Break Formation 265.09 5597 5668 14.9 6083 17 8:14:14 Alarm Delta Stage At Top Perf = 3 268.06 3413 3498 14.9 3720 18 8:15:47 Alarm Delta Stage At Top Perf = 4 294.85 3597 3752 20.1 3661 19 8:24:31 Alarm Delta Stage At Top Perf = 5 469.7 3906 4088 20 4058 20 8:53:00 Alarm Delta Stage At Top Perf = 6 1041.33 3317 3652 20.1 3940 21 9:00:22 Alarm Delta Stage At Top Perf = 7 1188.32 3007 3289 20.1 3711 22 9:07:06 Alarm Delta Stage At Top Perf = 8 1322.52 2913 3246 19.8 3504 23 9:19:14 Alarm Delta Stage At Top Perf = 9 1562.7 2657 2971 19.8 3607 24 9:31:48 Alarm Delta Stage At Top Perf = 10 1812.94 2790 3137 20.1 3717 25 9:52:04 Alarm Delta Stage At Top Perf = 11 2218.81 2836 3181 20 3784 26 10:00:21 Other Load Dart 2384.53 2786 3132 19.9 3792 27 10:10:56 Alarm Delta Stage At Top Perf = 12 2595.12 2867 3233 19.9 3842 28 10:17:25 Other Shut gate on bin 2723.76 2899 3246 19.8 3879 29 10:23:26 Drop Ball Launch Dart 2846.27 3319 3402 20.8 3950 11 10:23:35 Next Treatment Treatment Interval 11 2849.38 3303 3384 20.8 3955 30 10:23:53 Alarm Delta Stage At Top Perf = 13 2855.61 3274 3345 20.8 3964 31 10:32:20 Other Slow for dart 3031.2 2563 2836 20.8 3354 32 10:33:36 Start Pad Good Xlink (Start Pad)3051.5 2185 2464 15.1 3130 33 10:34:02 Alarm Delta Stage At Top Perf = 14 3058.05 2204 2468 15.1 3117 34 10:34:55 Ball on Seat Dart on Seat 3071.42 2228 2490 15.1 3086 35 10:35:04 Break Formation Break Formation 3073.69 5058 5232 15.1 5829 36 10:37:09 Alarm Delta Stage At Top Perf = 1 3111.27 2523 2810 20.4 3090 37 10:37:17 Alarm Delta Stage At Top Perf = 12 3113.99 2521 2810 20.4 3091 38 10:37:36 Alarm Delta Stage At Top Perf = 1 3120.44 2519 2818 20.4 3095 39 10:40:05 Alarm Delta Stage At Top Perf = 2 3171.06 2579 2851 20.4 3205 40 10:47:15 Alarm Delta Stage At Top Perf = 3 3317.39 2685 2917 20.5 3327 41 11:15:22 Alarm Delta Stage At Top Perf = 4 3887.57 2846 3214 20.1 3385 42 11:22:43 Alarm Delta Stage At Top Perf = 5 4034.19 2816 3209 19.9 3448 43 11:29:28 Alarm Delta Stage At Top Perf = 6 4168.58 2797 3185 19.8 3478 44 11:41:37 Alarm Delta Stage At Top Perf = 7 4408.9 2768 3171 19.7 3570 45 11:54:19 Alarm Delta Stage At Top Perf = 8 4659.05 2732 3114 19.7 3667 46 12:14:57 Alarm Delta Stage At Top Perf = 9 5065.17 2801 3175 19.6 3776 47 12:33:58 Alarm Delta Stage At Top Perf = 10 5442.05 2950 3345 19.9 3907 48 12:37:47 Other Drop Tracer 5518 2954 3372 19.8 3923 49 12:41:33 Other Shut gate on bin 5592.43 2996 3422 19.8 3927 50 12:47:19 Alarm Delta Stage At Top Perf = 11 5710.34 3484 3594 20.7 4011 51 12:47:26 Drop Ball Launch Dart 5712.43 3476 3584 20.7 4012 12 12:47:30 Next Treatment Treatment Interval 12 5713.83 3467 3574 20.7 4021 52 12:55:25 Alarm Delta Stage At Top Perf = 12 5878.53 2572 2852 20.8 3351 53 12:56:12 Start Pad Good Xlink (Start Pad)5894.62 2485 2780 20.7 3248 54 12:58:40 Ball on Seat Dart on Seat 5932.13 2171 2472 15.1 2999 55 12:58:50 Break Formation Break Formation 5934.67 5253 5528 15.1 5644 56 13:00:42 Alarm Delta Stage At Top Perf = 1 5968.06 3089 3386 20.3 3613 57 13:03:19 Alarm Delta Stage At Top Perf = 2 6021.43 3067 3355 20.6 3594 58 13:09:55 Alarm Delta Stage At Top Perf = 3 6157.42 2968 3244 20.6 3457 59 13:30:52 Other Drop Tracer 6589.05 2768 3063 20.6 3288 60 13:37:40 Alarm Delta Stage At Top Perf = 4 6728.09 2697 3040 20.3 3287 61 13:44:58 Alarm Delta Stage At Top Perf = 5 6874.7 2680 3039 20 3336 62 13:51:40 Alarm Delta Stage At Top Perf = 6 7008.71 2786 3156 19.9 3403 63 14:03:48 Alarm Delta Stage At Top Perf = 7 7249.21 2924 3303 19.8 3642 64 14:16:23 Alarm Delta Stage At Top Perf = 8 7499.13 3099 3477 20.1 3811 65 14:36:41 Alarm Delta Stage At Top Perf = 9 7905.52 3155 3548 20 3912 66 14:55:33 Alarm Delta Stage At Top Perf = 10 8282.01 3210 3618 19.9 3948 67 15:02:47 Other Shut gate on bin' 8425.68 3220 3667 19.9 3983 68 15:08:52 Alarm Delta Stage At Top Perf = 11 8549.79 3610 3723 20.7 4055 69 15:18:38 Alarm Delta Stage At Top Perf = 12 8753.37 1053 1086 20.5 3083 70 15:18:48 ISIP ISIP 8753.8 1046 110 0 2617 71 15:23:45 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 8753.8 -40 63 0 2683 72 15:28:32 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 8753.8 -43 171 0 2687 73 15:33:48 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 8753.8 -42 77 0 2688 Event Log 9.6.25 Conoco Phillips - 3S-719 Event Log 9.6 189 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres 1 6:42:01 Start Job Starting Job 0 0 0 0 0 1 6:42:01 Next Treatment Treatment Interval 1 0 0 0 0 0 2 6:55:59 Prime Pumps Prime Pumps 0 25 45 0 0 3 7:08:43 Pressure Test ePRV - Primary Tubing 0 993 1056 0 1949 4 7:10:16 Pressure Test ePRV - Primary IA 0 985 1081 0 1949 5 7:12:14 Pressure Test ePRV - Secondary Tubing 0 1048 982 0 1948 6 7:13:53 Pressure Test ePRV - Secondary IA 0 1040 1123 0 1948 7 7:15:51 Pressure Test Testing Globals 0 1033 726 0 1948 8 7:15:58 Pressure Test Testing Locals 0 1033 742 0 1947 9 7:17:27 Pressure Test Pressure Test - Max 0 9591 9689 0 1947 10 7:24:03 Pressure Test Pressure Test - Pass 0 9506 9577 0 1946 13 7:37:48 Next Treatment Treatment Interval 13 0 108 100 0 1943 11 7:50:51 Open Well Open Well 0 539 445 0 2121 12 7:52:47 Drop Ball Launch Dart 16.79 1708 1801 15 2819 13 8:07:14 Ball on Seat Dart on Seat 233.69 1520 1570 15 2902 14 8:07:24 Break Formation Break Formation 235.97 4533 4479 15 5461 15 8:08:02 Alarm Delta Stage At Top Perf = 3 245.55 1969 2017 15 3350 16 8:10:02 Alarm Delta Stage At Top Perf = 4 266.91 1409 1433 10 2907 17 8:46:27 Start Pad Good Xlink (Start Pad)347.52 1766 1929 14.7 3000 18 8:54:20 Alarm Delta Stage At Top Perf = 5 499.88 2555 2800 19.8 3160 19 8:55:23 Alarm Delta Stage At Top Perf = 7 520.85 2681 2932 19.7 3254 20 8:59:19 Alarm Delta Stage At Top Perf = 8 599.16 3319 3578 20.1 3659 21 9:27:46 Alarm Delta Stage At Top Perf = 9 1170.53 2628 2897 20 3371 22 9:35:06 Alarm Delta Stage At Top Perf = 10 1317.12 2582 2868 20 3426 23 9:41:49 Alarm Delta Stage At Top Perf = 11 1451.31 2639 2921 20 3466 24 9:53:56 Alarm Delta Stage At Top Perf = 12 1691.95 2688 2998 19.8 3563 25 10:06:29 Alarm Delta Stage At Top Perf = 13 1941.78 2676 2990 19.9 3607 26 10:26:56 Alarm Delta Stage At Top Perf = 14 2348.27 2660 2959 19.9 3612 27 10:36:26 Other Load Dart 2536.49 2748 3079 19.8 3685 28 10:45:56 Alarm Delta Stage At Top Perf = 15 2724.82 2883 3205 19.8 3761 29 10:53:09 Other Shut gate on bin 2867.34 2916 3280 19.7 3765 30 10:59:20 Drop Ball Launch Dart 2991.49 3219 3289 20.6 3828 14 10:59:23 Next Treatment Treatment Interval 14 2992.53 3211 3287 20.6 3830 31 10:59:24 Alarm Delta Stage At Top Perf = 16 2993.37 3208 3281 20.6 3828 32 11:07:40 Start Pad Good Xlink (Start Pad)3162.39 1827 1992 15 2981 33 11:08:39 Alarm Delta Stage At Top Perf = 17 3177.1 2068 2309 14.8 3063 34 11:09:47 Ball on Seat Dart on Seat 3193.8 2090 2324 14.8 2996 35 11:09:56 Break Formation Break Formation 3195.79 4862 5006 14.8 4922 36 11:11:57 Alarm Delta Stage At Top Perf = 1 3231.63 2790 3008 20.2 3375 37 11:14:41 Alarm Delta Stage At Top Perf = 2 3286.92 2594 2861 20.3 3278 38 11:20:29 Alarm Delta Stage At Top Perf = 3 3404.59 2590 2849 20.2 3291 39 11:48:46 Alarm Delta Stage At Top Perf = 4 3975.5 2613 2960 20 3275 40 11:56:07 Alarm Delta Stage At Top Perf = 5 4121.95 2610 2960 19.9 3360 41 12:02:52 Alarm Delta Stage At Top Perf = 6 4256.21 2655 3009 19.9 3406 42 12:14:56 Alarm Delta Stage At Top Perf = 7 4496.95 2571 2909 20.1 3453 43 12:27:25 Alarm Delta Stage At Top Perf = 8 4746.98 2498 2841 20 3486 44 12:47:44 Alarm Delta Stage At Top Perf = 9 5153.02 2600 2958 19.9 3578 45 13:06:39 Alarm Delta Stage At Top Perf = 10 5529.24 2670 3059 19.9 3634 46 13:20:05 Alarm Delta Stage At Top Perf = 11 5797.82 3244 3344 20.7 3776 47 13:20:33 Drop Ball Launch Dart 5807.22 3202 3310 20.7 3783 15 13:20:38 Next Treatment Treatment Interval 15 5808.97 3196 3299 20.7 3796 48 13:28:19 Start Pad Good Xlink (Start Pad)5967.96 2335 2617 20.7 3180 49 13:29:38 Alarm Delta Stage At Top Perf = 12 5988.21 2006 2288 14.8 2996 50 13:30:42 Ball on Seat Dart on Seat 6003.91 2056 2340 14.8 3067 51 13:31:00 Break Formation Break Formation 6008.13 6745 7050 14.7 7374 52 13:31:02 Other Pump Kickout 6008.63 5714 6158 14.6 6884 53 13:33:19 Alarm Delta Stage At Top Perf = 1 6040.35 2958 3325 20.2 3605 54 13:35:58 Alarm Delta Stage At Top Perf = 2 6094.1 2695 2986 20.4 3307 55 13:41:25 Alarm Delta Stage At Top Perf = 3 6205.34 2481 2766 20.4 3170 56 14:09:25 Alarm Delta Stage At Top Perf = 4 6775.7 2379 2707 20.2 3158 57 14:16:44 Alarm Delta Stage At Top Perf = 5 6922.47 2552 2955 20 3190 58 14:23:27 Alarm Delta Stage At Top Perf = 6 7056.37 2679 3079 19.9 3276 59 14:35:34 Alarm Delta Stage At Top Perf = 7 7296.7 2651 3056 20 3380 60 14:48:09 Alarm Delta Stage At Top Perf = 8 7546.73 2743 3160 19.9 3486 61 15:08:40 Alarm Delta Stage At Top Perf = 9 7953.19 2849 3274 19.8 3622 62 15:27:40 Alarm Delta Stage At Top Perf = 10 8329.79 2902 3324 19.9 3705 63 15:37:17 Other Shut gate on bin 8520.64 2924 3374 19.8 3698 64 15:41:06 Alarm Delta Stage At Top Perf = 11 8597.65 3287 3654 20.6 3708 65 15:51:33 Alarm Delta Stage At Top Perf = 12 8815.63 924 1055 20.3 3086 66 15:51:42 ISIP ISIP 8816.23 1145 80 0 2663 67 15:56:45 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 8816.23 -7 102 0 2760 68 16:01:31 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 8816.23 -8 288 0 2758 69 16:06:27 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 8816.23 -7 68 0 2755 Event Log 9.7.25 Conoco Phillips - 3S-719 Event Log 9.7 190 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres 1 5:59:44 Start Job Starting Job 0 0 0 0 0 1 5:59:44 Next Treatment Treatment Interval 1 0 0 0 0 0 2 6:46:30 Prime Pumps Prime Pumps 0 22 18 0 1973 3 6:57:53 Pressure Test ePRV - Primary Tubing 0 927 992 0 1971 4 6:59:32 Pressure Test ePRV - Primary IA 0 915 975 0 1971 5 7:02:41 Pressure Test ePRV - Secondary Tubing 0 894 1006 0 1971 6 7:04:14 Pressure Test ePRV - Secondary IA 0 886 975 0 1971 7 7:07:05 Pressure Test Testing Globals 0 874 692 0 1970 8 7:07:11 Pressure Test Testing Locals 0 874 709 0 1970 9 7:08:32 Pressure Test Pressure Test - Max 0 9546 9656 0 1970 10 7:14:44 Pressure Test Pressure Test - Pass 0 9412 9475 0 1969 11 7:32:29 Open Well Open Well 0 704 632 0 2275 16 7:33:17 Next Treatment Treatment Interval 16 1.36 1414 1468 4.6 2924 12 7:34:35 Drop Ball Launch Dart 19.49 1876 1986 15 3003 13 7:41:41 Start Pad Good Xlink (Start Pad)124.86 2070 2354 14.6 2937 14 7:47:47 Ball on Seat Dart on Seat 214.65 2313 2587 14.7 2919 15 7:47:56 Break Formation Break Formation 216.61 5269 5556 14.7 5303 16 7:48:25 Alarm Delta Stage At Top Perf = 1 223.94 2485 2762 14.7 3154 17 7:48:29 Alarm Delta Stage At Top Perf = 3 224.92 2491 2765 14.7 3140 18 7:49:41 Alarm Delta Stage At Top Perf = 4 246.46 2949 3180 20.2 3269 19 7:54:56 Alarm Delta Stage At Top Perf = 5 352.1 2767 3076 20.1 3267 20 8:23:21 Alarm Delta Stage At Top Perf = 6 923.56 2639 2938 20 3299 21 8:30:44 Alarm Delta Stage At Top Perf = 7 1070.78 2526 2838 19.9 3315 22 8:37:27 Alarm Delta Stage At Top Perf = 8 1204.49 2522 2791 19.9 3333 23 8:49:35 Alarm Delta Stage At Top Perf = 9 1445.25 2472 2779 19.8 3371 24 9:02:14 Alarm Delta Stage At Top Perf = 10 1695.5 2473 2774 19.8 3401 25 9:22:47 Alarm Delta Stage At Top Perf = 11 2101.05 2528 2864 19.7 3448 26 9:32:20 Other Load Dart 2288.6 2573 2941 19.6 3461 27 9:41:57 Alarm Delta Stage At Top Perf = 12 2477.38 2614 2994 19.6 3513 28 9:50:20 Other Shut gate on bin 2640.99 2630 3000 19.5 3526 29 9:55:33 Alarm Delta Stage At Top Perf = 13 2745.58 3046 3120 20.4 3564 30 9:56:20 Drop Ball Launch Dart 2761.23 2971 3033 20.4 3576 17 9:56:24 Next Treatment Treatment Interval 17 2762.6 2966 3036 20.4 3579 31 10:02:44 Other Slow for dart 2892.14 2401 2653 20.3 3314 32 10:03:30 Other Slow for dart 2907.38 2367 2615 20.3 3216 33 10:04:43 Alarm Delta Stage At Top Perf = 14 2925.96 2089 2324 14.8 3059 34 10:05:49 Ball on Seat Dart on Seat 2942.23 2109 2342 14.8 3010 35 10:06:00 Break Formation Break Formation 2944.94 5482 5621 14.7 6000 36 10:08:18 Alarm Delta Stage At Top Perf = 1 2978.79 2288 2549 14.8 3061 37 10:11:07 Alarm Delta Stage At Top Perf = 2 3034.63 2630 2880 20.3 3206 38 10:15:22 Alarm Delta Stage At Top Perf = 3 3121.12 2613 2882 20.3 3200 39 10:43:25 Alarm Delta Stage At Top Perf = 4 3691.66 2413 2708 20.2 3116 40 10:50:42 Alarm Delta Stage At Top Perf = 5 3837.98 2388 2696 20 3151 41 10:57:24 Alarm Delta Stage At Top Perf = 6 3972.04 2435 2771 20 3187 42 11:09:30 Alarm Delta Stage At Top Perf = 7 4212.5 2454 2813 19.9 3263 43 11:22:10 Alarm Delta Stage At Top Perf = 8 4462.78 2583 2959 19.7 3346 44 11:42:43 Alarm Delta Stage At Top Perf = 9 4868.9 2872 3298 19.8 3446 45 11:53:39 Other Load Dart 5085.26 2861 3274 19.7 3469 46 12:01:44 Alarm Delta Stage At Top Perf = 10 5245.27 2919 3346 19.7 3509 47 12:10:38 Other Shut gate on bin 5420.32 2871 3289 19.7 3525 48 12:15:15 Alarm Delta Stage At Top Perf = 11 5513.74 3359 3468 20.7 3578 49 12:16:26 Drop Ball Launch Dart 5538.24 3180 3229 20.7 3572 18 12:16:29 Next Treatment Treatment Interval 18 5538.93 3174 3225 20.7 3583 50 12:23:02 Other Slow for dart 5674.97 2511 2828 20.6 3255 51 12:23:07 Alarm Delta Stage At Top Perf = 12 5676.68 2344 2553 20.4 3237 52 12:24:40 Start Pad Good Xlink (Start Pad)5699.88 2278 2574 14.8 3072 53 12:25:33 Ball on Seat Dart on Seat 5712.67 2315 2624 14.8 3037 54 12:25:42 Break Formation Break Formation 5715.13 5613 5900 14.7 6069 55 12:27:34 Alarm Delta Stage At Top Perf = 1 5747.47 2701 2993 20.2 3074 56 12:30:51 Alarm Delta Stage At Top Perf = 2 5813.89 2806 3116 20.2 3169 57 12:36:00 Alarm Delta Stage At Top Perf = 3 5918.05 2843 3152 20.3 3206 58 13:04:11 Alarm Delta Stage At Top Perf = 4 6488.99 2540 2850 20 3125 59 13:11:32 Alarm Delta Stage At Top Perf = 5 6635.86 2472 2806 19.9 3140 60 13:18:14 Alarm Delta Stage At Top Perf = 6 6769.26 2343 2698 19.9 3149 61 13:30:23 Alarm Delta Stage At Top Perf = 7 7009.91 2381 2745 19.8 3186 62 13:42:58 Alarm Delta Stage At Top Perf = 8 7260.29 2392 2746 20.2 3258 63 14:03:08 Alarm Delta Stage At Top Perf = 9 7666.24 2440 2759 20.1 3319 64 14:21:54 Alarm Delta Stage At Top Perf = 10 8042.62 2514 2846 20 3373 65 14:30:47 Other Shut gate on bin 8219.51 2483 2827 19.9 3393 66 14:35:15 Alarm Delta Stage At Top Perf = 11 8310.68 2926 3064 20.8 3431 67 14:44:14 ISIP ISIP 8495.9 1421 149 0 2965 68 14:49:16 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 8495.9 24 117 0 2831 69 14:54:18 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 8495.9 22 44 0 2828 70 14:59:15 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 8495.9 22 52 0 2828 Event Log 9.8.25 Conoco Phillips - 3S-719 Event Log 9.8 191 Seq No. Time Activity Code Comment Job Slurry Vol Treating Pressure Treating Pressure @Pump Slurry Rate Tubing Gauge BH Pres 1 6:16:47 Start Job Starting Job 0 0 0 0 0 1 6:16:47 Next Treatment Treatment Interval 1 0 0 0 0 0 19 6:16:59 Next Treatment Treatment Interval 19 0 23 0 0 0 2 7:03:31 Pressure Test ePRV - Primary Tubing 0 1082 1128 0 0 3 7:05:21 Pressure Test ePRV - Primary IA 0 1154 1214 0 0 4 7:07:46 Pressure Test ePRV - Secondary Tubing 0 1182 1025 0 0 5 7:09:07 Pressure Test ePRV - Secondary IA 0 1170 1023 0 0 6 7:14:45 Other Testing Locals 0 1141 166 0 2274 7 7:14:51 Pressure Test Test Globals 0 1141 877 0 2274 8 7:16:41 Pressure Test Pressure Test - Max 0 9532 9610 0 2274 9 7:22:06 Pressure Test Pressure Test - Pass 0 9435 9495 0 2273 10 7:43:11 Open Well Open Well 0 946 849 0 2497 11 7:47:32 Drop Ball Launch Dart 19.01 1864 1960 14.7 2959 12 7:58:59 Ball on Seat Dart on Seat 190.14 1638 1651 15 2989 13 7:59:08 Break Formation Break Formation 192.39 4971 4810 15 4473 14 7:59:38 Alarm Delta Stage At Top Perf = 3 200.13 1619 1667 15 2998 15 8:03:00 Alarm Delta Stage At Top Perf = 4 223.21 1190 1188 5 2805 16 8:03:50 ISIP ISIP 227.34 939 885 4.7 2796 17 8:29:06 Start Pad Good Xlink (Start Pad)305.77 1802 2023 14.5 2828 18 8:34:40 Alarm Delta Stage At Top Perf = 5 412.78 2366 2637 19.8 2912 19 8:35:26 Alarm Delta Stage At Top Perf = 7 427.91 2413 2686 19.7 2992 20 8:39:39 Alarm Delta Stage At Top Perf = 8 511.03 2512 2796 19.7 3062 21 9:08:10 Alarm Delta Stage At Top Perf = 9 1082.03 2425 2688 20 3138 22 9:15:32 Alarm Delta Stage At Top Perf = 10 1228.69 2361 2637 19.9 3143 23 9:22:17 Alarm Delta Stage At Top Perf = 11 1362.98 2375 2679 19.8 3174 24 9:26:49 Other Pump 458 - Cavitating 1452.18 2255 2623 19.7 3204 25 9:34:37 Alarm Delta Stage At Top Perf = 12 1603.44 2355 2645 20 3231 26 9:47:08 Alarm Delta Stage At Top Perf = 13 1853.69 2383 2714 20 3275 27 10:07:28 Alarm Delta Stage At Top Perf = 14 2259.44 2392 2690 19.9 3305 28 10:18:41 Other Load Dart 2483.03 2395 2723 19.9 3317 29 10:26:24 Alarm Delta Stage At Top Perf = 15 2636.24 2468 2788 19.8 3340 30 10:37:19 Other Shut gate on bin 2852.79 2506 2785 19.8 3370 31 10:39:55 Alarm Delta Stage At Top Perf = 16 2904.29 2567 2839 20.1 3395 32 10:43:56 Drop Ball Launch Dart 2985.74 2784 2866 20.4 3404 20 10:44:01 Next Treatment Treatment Interval 20 2987.1 2775 2857 20.4 3397 33 10:49:54 Other Slow for Dart 3107.17 2127 2321 20.3 3185 34 10:51:19 Alarm Delta Stage At Top Perf = 17 3128.61 1903 2099 14.4 3044 35 10:51:33 Start Pad Good Xlink (Start Pad)3131.73 1905 2100 14.4 3031 36 10:52:27 Ball on Seat Dart on Seat 3144.67 1903 2073 14.4 2984 37 10:52:36 Break Formation Break Formation 3146.84 4951 5121 14.4 4110 38 10:54:31 Alarm Delta Stage At Top Perf = 1 3180.6 2126 2306 19.9 2961 39 10:57:10 Alarm Delta Stage At Top Perf = 2 3233.28 2263 2469 19.8 2984 40 11:01:50 Alarm Delta Stage At Top Perf = 3 3325.95 2267 2470 19.9 3020 41 11:30:30 Alarm Delta Stage At Top Perf = 4 3896.27 2291 2578 19.7 2996 42 11:37:59 Alarm Delta Stage At Top Perf = 5 4043.07 2282 2585 19.5 2993 43 11:44:47 Alarm Delta Stage At Top Perf = 6 4177.03 2266 2602 19.9 3017 44 11:56:58 Alarm Delta Stage At Top Perf = 7 4417.48 2186 2523 19.7 3047 45 12:09:42 Alarm Delta Stage At Top Perf = 8 4667.99 2185 2509 19.7 3077 46 12:30:16 Alarm Delta Stage At Top Perf = 9 5073.81 2379 2701 19.7 3114 47 12:43:19 Other Load Dart 5332.89 2487 2832 19.8 3208 48 12:49:14 Alarm Delta Stage At Top Perf = 10 5450.29 2555 2929 19.8 3225 49 13:00:18 Other Shut gate on bin 5669.48 2601 2986 19.7 3236 50 13:02:46 Alarm Delta Stage At Top Perf = 11 5718.65 2667 3052 20.2 3249 51 13:06:14 Drop Ball Launch Dart 5789.78 2966 3078 20.8 3286 21 13:06:17 Next Treatment Treatment Interval 21 5790.82 2963 3061 20.8 3282 52 13:11:34 Other Slow for dart 5900.91 2129 2411 20.8 3069 53 13:12:59 Start Pad Good Xlink (Start Pad)5922.98 1908 2175 15 2899 54 13:13:03 Alarm Delta Stage At Top Perf = 12 5923.97 1914 2184 14.9 2895 55 13:14:45 Ball on Seat Dart on Seat 5949.3 2068 2348 14.9 2857 56 13:15:03 Break Formation Break Formation 5953.75 6149 6546 14.7 6796 57 13:16:35 Alarm Delta Stage At Top Perf = 1 5976.47 2574 2826 14.9 3185 58 13:20:09 Alarm Delta Stage At Top Perf = 2 6046.19 2774 3040 20.4 3096 59 13:23:13 Alarm Delta Stage At Top Perf = 3 6108.74 2610 2883 20.4 3031 60 13:51:15 Alarm Delta Stage At Top Perf = 4 6679.4 2370 2654 20.2 2978 61 13:58:32 Alarm Delta Stage At Top Perf = 5 6825.93 2188 2448 20 2974 62 14:05:12 Alarm Delta Stage At Top Perf = 6 6959.88 2065 2358 20 2957 63 14:17:16 Alarm Delta Stage At Top Perf = 7 7200.78 2021 2312 20 2988 64 14:29:50 Alarm Delta Stage At Top Perf = 8 7450.96 2066 2355 19.9 3028 65 14:50:19 Alarm Delta Stage At Top Perf = 9 7856.7 2052 2341 19.7 3072 66 15:09:26 Alarm Delta Stage At Top Perf = 10 8232.8 2162 2497 19.6 3118 67 15:20:16 Other Shut gate on bin 8444.67 2183 2504 19.5 3130 68 15:23:09 Alarm Delta Stage At Top Perf = 11 8500.98 2294 2602 20 3161 69 15:33:47 ISIP ISIP 8716.18 1437 441 0 2831 70 15:38:45 Shut-In Pressure @ 5 Minutes Shut-In Pressure @ 5 Minutes 8716.18 109 144 0 2815 71 15:43:45 Shut-In Pressure @ 10 Minutes Shut-In Pressure @ 10 Minutes 8716.18 46 59 0 2811 72 15:48:32 Shut-In Pressure @ 15 Minutes Shut-In Pressure @ 15 Minutes 8716.18 61 67 0 2802 Event Log 9.9.25 Conoco Phillips - 3S-719 Event Log 9.9 192 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels1 Wichita 3J 108 21,000 500 93 12 2,268 542 Wichita 3J 107 21,000 500 91 12 2,268 543 Wichita 3J 105 21,000 500 92 12 2,268 544 Wichita 3J 105 21,000 500 95 12 2,268 545 Wichita 3J 100 20,160 480 96 12 2,268 546 Wichita 3J 103 20,790 495 99 12 2,268 547 Wichita 3J 108 21,000 500 93 12 2,268 548 Wichita 3J 108 21,000 500 93 12 2,268 549 Wichita 3J 108 21,000 500 91 12 2,268 5410 Wichita 3J 108 21,000 500 93 12 2,268 5411 Wichita 3J 106 21,000 500 95 12 2,268 5412 Wichita 3J 108 21,000 500 96 12 2,268 5413 Wichita 3J 109 21,000 500 95 12 2,268 5414 Wichita 3J 110 21,000 500 95 12 2,268 5415 Wichita 3J 108 21,000 500 99 12 2,268 5416 Wichita 3J 109 21,000 500 100 12 2,268 5417 Atigan 3J 108 20,529 489 96 80 15,113 36018 Atigan 3J 103 19,562 466 92 80 15,113 36019 Wichita 3J 103 20,790 495 89 103 20,790 49520 Wichita 3J 103 20,790 495 91 103 20,790 49521 Wichita 3J 101 20,370 485 91 101 20,370 48522 Wichita 3J 104 21,000 500 105 104 21,000 50023 Wichita 3J 104 21,000 500 89 104 21,000 50024 Wichita 3J 103 20,790 495 80 103 20,790 495Gallons Barrels Gallons Barrels Gallons Barrels499,780 11,900 191,254 4,554 308,527 7,346GeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips 3S-7198/25/2025Coyote910285054Conoco Phillips - 3S-719Water Straps 8.25 193 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels1 Wichita 3J 106 21,000 500 99 10 1,890 452 Wichita 3J 107 21,000 500 100 10 1,890 453 Wichita 3J 105 21,000 500 97 10 1,890 454 Wichita 3J 105 21,000 500 97 10 1,890 455 Wichita 3J 104 21,000 500 99 10 1,890 456 Wichita 3J 105 21,000 500 92 10 1,890 457 Wichita 3J 106 21,000 500 90 90 18,060 4308 Wichita 3J 105 21,000 500 93 90 18,060 4309 Wichita 3J 105 21,000 500 92 105 21,000 50010 Wichita 3J 105 21,000 500 92 105 21,000 50011 Wichita 3J 105 21,000 500 90 105 21,000 50012 Wichita 3J 97 19,530 465 91 97 19,530 46513 Wichita 3J 105 21,000 500 97 105 21,000 50014 Wichita 3J 105 21,000 500 94 105 21,000 50015 Wichita 3J 105 21,000 500 92 105 21,000 50016 Wichita 3J 105 21,000 500 93 105 21,000 50017 Atigan 3J 105 19,949 475 92 105 19,949 47518 Atigan 3J 99 18,788 447 92 99 18,788 44719 Wichita 3J 101 20,370 485 84 101 20,370 48520 Wichita 3J 103 20,790 495 89 103 20,790 49521 Wichita 3J 100 20,160 480 90 100 20,160 48022 Wichita 3J 98 19,740 470 104 98 19,740 47023 Wichita 3J 100 20,160 480 85 100 20,160 48024 Wichita 3J 104 21,000 500 80 104 21,000 500Gallons Barrels Gallons Barrels Gallons Barrels495,487 11,797 374,947 8,927 120,540 2,870GeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips 3S-7198/26/2025Coyote910285054Conoco Phillips - 3S-719Water Straps 8.26194 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels24 Wichita 3J 108 21,000 500 99 108 21,000 50023 Wichita 3J 104 21,000 500 100 104 21,000 50022 Wichita 3J 104 21,000 500 97 104 21,000 50021 Wichita 3J 104 21,000 500 97 104 21,000 50020 Wichita 3J 105 21,000 500 99 105 21,000 50019 Wichita 3J 104 21,000 500 92 104 21,000 50018 Wichita 3J 105 21,000 500 90 105 21,000 50017 Atigan 3J 104 19,755 470 93 104 19,755 47016 Atigan 3J 104 19,755 470 92 104 19,755 47015 Atigan 3J 104 19,755 470 92 30 5,277 12614 Atigan 3J 104 19,755 470 90 10 1,627 3913 Atigan 3J 105 19,949 475 91 10 1,627 3912 Atigan 3J 103 19,562 466 97 10 1,627 3911 Atigan 3J 105 19,949 475 94 10 1,627 3910 Atigan 3J 103 19,562 466 92 10 1,627 399 Atigan 3J 105 19,949 475 93 10 1,627 398 Atigan 3J 105 19,949 475 92 10 1,627 397 Atigan 3J 96 18,208 434 92 10 1,627 396 Atigan 3J 101 19,175 457 84 10 1,627 395 Atigan 3J 105 19,949 475 89 10 1,627 394 Atigan 3J 88 16,660 397 90 10 1,627 393 Atigan 3J 96 18,208 434 104 10 1,627 392 Atigan 3J 92 17,434 415 85 10 1,627 391 Atigan 3J 102 19,368 461 80 10 1,627 39Gallons Barrels Gallons Barrels Gallons Barrels473,940 11,284 214,567 5,109 259,373 6,176Conoco Phillips 3S-7199/4/2025Coyote910285054GeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips - 3S-719Water Straps 9.4195 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels24 Wichita 3J 106 21,000 500 87 10 1,890 4523 Wichita 3J 100 20,160 480 93 10 1,890 4522 Wichita 3J 105 21,000 500 101 10 1,890 4521 Wichita 3J 102 20,580 490 97 10 1,890 4520 Wichita 3J 104 21,000 500 97 10 1,890 4519 Wichita 3J 105 21,000 500 90 10 1,890 4518 Wichita 3J 104 21,000 500 88 104 21,000 50017 Atigan 3J 105 19,949 475 90 105 19,949 47516 Atigan 3J 105 19,949 475 87 105 19,949 47515 Atigan 3J 104 19,755 470 90 104 19,755 47014 Atigan 3J 105 19,949 475 93 105 19,949 47513 Atigan 3J 100 18,981 452 90 10 1,627 3912 Atigan 3J 105 19,949 475 92 10 1,627 3911 Atigan 3J 105 19,949 475 87 10 1,627 3910 Atigan 3J 106 20,142 480 92 10 1,627 399 Atigan 3J 104 19,755 470 100 10 1,627 398 Atigan 3J 105 19,949 475 87 10 1,627 397 Atigan 3J 97 18,401 438 92 10 1,627 396 Atigan 3J 93 17,627 420 88 10 1,627 395 Atigan 3J 100 18,981 452 95 10 1,627 394 Atigan 3J 85 16,080 383 90 10 1,627 393 Atigan 3J 10 1,627 39 10 1,627 392 Atigan 3J 95 18,014 429 90 10 1,627 391 Atigan 3J 99 18,788 447 95 10 1,627 39Gallons Barrels Gallons Barrels Gallons Barrels453,585 10,800 133,093 3,169 320,492 7,631GeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips 3S-7199/5/2025Coyote910285054Conoco Phillips - 3S-719Water Straps 9.5196 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels24 Wichita 3J 105 21,000 500 90 10 1,890 4523 Wichita 3J 105 21,000 500 90 50 9,660 23022 Wichita 3J 105 21,000 500 90 105 21,000 50021 Wichita 3J 105 21,000 500 88 105 21,000 50020 Wichita 3J 105 21,000 500 87 105 21,000 50019 Wichita 3J 105 21,000 500 87 105 21,000 50018 Wichita 3J 104 21,000 500 88 104 21,000 50017 Atigan 3J 105 19,949 475 88 105 19,949 47516 Atigan 3J 104 19,755 470 87 104 19,755 47015 Atigan 3J 103 19,562 466 90 10 1,627 3914 Atigan 3J 103 19,562 466 86 10 1,627 3913 Atigan 3J 95 18,014 429 89 10 1,627 3912 Atigan 3J 105 19,949 475 92 10 1,627 3911 Atigan 3J 105 19,949 475 89 10 1,627 3910 Atigan 3J 104 19,755 470 89 10 1,627 399 Atigan 3J 103 19,562 466 95 10 1,627 398 Atigan 3J 106 20,142 480 88 10 1,627 397 Atigan 3J 97 18,401 438 90 10 1,627 396 Atigan 3J 97 18,401 438 99 10 1,627 395 Atigan 3J 99 18,788 447 93 10 1,627 394 Atigan 3J 99 18,788 447 95 10 1,627 393 Atigan 3J 97 18,401 438 95 10 1,627 392 Atigan 3J 96 18,208 434 92 10 1,627 391 Atigan 3J 98 18,595 443 98 10 1,627 391 Atigan 3J 104 19,755 470 104 19,755 4702 Atigan 3J 104 19,755 470 104 19,755 4703 Atigan 3J 104 19,755 470 104 19,755 470Gallons Barrels Gallons Barrels Gallons Barrels532,044 12,668 239,925 5,713 292,118 6,955GeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips 3S-7199/6/2025Coyote910285054Conoco Phillips - 3S-719Water Straps 9.6197 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels24 Wichita 3J 99 19,950 475 89 99 19,950 47523 Wichita 3J 99 19,950 475 90 99 19,950 47522 Wichita 3J 99 19,950 475 91 99 19,950 47521 Wichita 3J 98 19,740 470 92 98 19,740 47020 Wichita 3J 99 19,950 475 89 99 19,950 47519 Wichita 3J 99 19,950 475 93 99 19,950 47518 Wichita 3J 99 19,950 475 86 99 19,950 47517 Atigan 3J 105 19,949 475 85 105 19,949 47516 Atigan 3J 106 20,142 480 90 106 20,142 48015 Atigan 3J 106 20,142 480 86 10 1,627 3914 Atigan 3J 105 19,949 475 86 10 1,627 3913 Atigan 3J 106 20,142 480 86 10 1,627 3912 Atigan 3J 102 19,368 461 88 10 1,627 3911 Atigan 3J 106 20,142 480 87 10 1,627 3910 Atigan 3J 103 19,562 466 89 10 1,627 399 Atigan 3J 104 19,755 470 91 10 1,627 398 Atigan 3J 105 19,949 475 90 10 1,627 397 Atigan 3J 105 19,949 475 88 10 1,627 396 Atigan 3J 105 19,949 475 87 10 1,627 395 Atigan 3J 105 19,949 475 96 10 1,627 394 Atigan 3J 104 19,755 470 90 10 1,627 393 Atigan 3J 105 19,949 475 95 10 1,627 392 Atigan 3J 104 19,755 470 92 10 1,627 391 Atigan 3J 104 19,755 470 95 10 1,627 391 Atigan 3J 104 19,755 470 104 19,755 4702 Atigan 3J 105 19,949 475 105 19,949 4753 Atigan 3J 104 19,755 470 104 19,755 4704 Wichita 3J 104 21,000 500 104 21,000 5005 Wichita 3J 104 21,000 500 104 21,000 5006 Wichita 3J 104 21,000 500 104 21,000 500Gallons Barrels Gallons Barrels Gallons Barrels600,058 14,287 326,396 7,771 273,662 6,516Conoco Phillips 3S-7199/7/2025Coyote910285054GeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips - 3S-719Water Straps 9.7198 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels24 Wichita 3J 98 19,740 470 89 98 19,740 47023 Wichita 3J 95 19,110 455 90 95 19,110 45522 Wichita 3J 99 19,950 475 90 99 19,950 47521 Wichita 3J 98 19,740 470 88 98 19,740 47020 Wichita 3J 99 19,950 475 86 99 19,950 47519 Wichita 3J 98 19,740 470 90 98 19,740 47018 Wichita 3J 99 19,950 475 92 99 19,950 47517 Atigan 3J 105 19,949 475 94 105 19,949 47516 Atigan 3J 105 19,949 475 95 105 19,949 47515 Atigan 3J 106 20,142 480 87 5 714 1714 Atigan 3J 107 20,336 484 88 5 714 1713 Atigan 3J 105 19,949 475 88 5 714 1712 Atigan 3J 102 19,368 461 90 4 532 1311 Atigan 3J 105 19,949 475 90 5 714 1710 Atigan 3J 105 19,949 475 96 5 714 179 Atigan 3J 105 19,949 475 90 5 714 178 Atigan 3J 105 19,949 475 88 5 714 177 Atigan 3J 105 19,949 475 93 5 714 176 Atigan 3J 103 19,562 466 95 6 897 215 Atigan 3J 105 19,949 475 94 5 714 174 Atigan 3J 103 19,562 466 90 5 714 173 Atigan 3J 105 19,949 475 99 5 714 172 Atigan 3J 105 19,949 475 98 5 714 171 Atigan 3J 106 20,142 480 102 7 1,079 261 Atigan 3J 104 19,755 470 104 19,755 4702 Atigan 3J 104 19,755 470 104 19,755 4703 Atigan 3J 104 19,755 470 104 19,755 4704 Atigan 3J 104 19,755 470 104 19,755 4705 Atigan 3J 53 9,743 232 53 9,743 232Gallons Barrels Gallons Barrels Gallons Barrels565,490 13,464 277,922 6,617 287,568 6,847Conoco Phillips 3S-7199/8/2025Coyote910285054GeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips - 3S-719Water Straps 9.8199 Customer:Well:Date:Formation:SO#:Tank Type Water Source Inches Gallons BarrelsTemperature (°F)Inches Gallons Barrels24 Wichita 3J 97 19,530 465 87 6 1,134 2723 Wichita 3J 96 19,320 460 88 6 1,134 2722 Wichita 3J 100 20,160 480 87 5 966 2321 Wichita 3J 95 19,110 455 90 4 756 1820 Wichita 3J 97 19,530 465 86 4 756 1819 Wichita 3J 97 19,530 465 98 5 966 2318 Wichita 3J 96 19,320 460 90 5 966 2317 Atigan 3J 104 19,755 470 91 104 19,755 47016 Atigan 3J 100 18,981 452 90 100 18,981 45215 Atigan 3J 104 19,755 470 95 104 19,755 47014 Atigan 3J 104 19,755 470 87 104 19,755 47013 Atigan 3J 103 19,562 466 96 103 19,562 46612 Atigan 3J 100 18,981 452 90 100 18,981 45211 Atigan 3J 102 19,368 461 92 102 19,368 46110 Atigan 3J 104 19,755 470 93 104 19,755 4709 Atigan 3J 105 19,949 475 95 4 532 138 Atigan 3J 104 19,755 470 94 4 532 137 Atigan 3J 103 19,562 466 90 4 532 136 Atigan 3J 104 19,755 470 95 4 532 135 Atigan 3J 101 19,175 457 93 5 714 174 Atigan 3J 99 18,788 447 94 5 714 173 Atigan 3J 105 19,949 475 95 5 714 172 Atigan 3J 105 19,949 475 90 5 714 171 Atigan 3J 104 19,755 470 96 5 714 171 Atigan 3J 105 19,949 475 105 19,949 4752 Atigan 3J 105 19,949 475 105 19,949 4753 Atigan 3J 105 19,949 475 105 19,949 4754 Atigan 3J 105 19,949 475 105 19,949 4755 Atigan 3J 105 19,949 475 105 19,949 475Gallons Barrels Gallons Barrels Gallons Barrels568,793 13,543 268,034 6,382 300,759 7,161GeneralBeginning StrapEnding StrapLocation SummaryStarting VolumeEnding VolumeTotal UsedConoco Phillips 3S-7199/9/2025Coyote910285054Conoco Phillips - 3S-719Water Straps 9.9200 SpecificGravityTestingTemperatureDissolved Iron(Fe2+)Chloride(Cl-)Sulfate(SO42-)Calcium(Ca2+)Magnesium(Mg2+)TotalHardnessLinearViscosityWaterpHGelpHPost-CrosslinkpHCrosslink Bacteria- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ ValueTank #H2S present? Y/NHydrometer Digital ThermometerStrip Strip Strip TitrationTotal Hardness Minus CalciumTitration FANN-35 Probe Probe Probe - Mycometer1 N 1.012 0 11,754 800 1,160 160 1,320 26,5442 N 1.014 0 11,754 800 1,120 360 1,480 37,0403 N 1.018 0 11,754 800 1,080 520 1,600 11,7154 N 1.016 0 11,754 800 1,080 440 1,520 38,7075 N 1.012 0 13,480 800 1,000 360 1,360 15,6176 N 1.012 0 9,192 800 1,000 520 1,520 7,9647 N 1.012 0 7,390 800 1,000 320 1,320 33,0418 N 1.012 0 8,220 800 800 360 1,160 28,3129 N 1.012 0 7,390 800 960 520 1,480 28,23110 N 1.012 0 7,390 800 800 400 1,200 30,09011 N 1.010 0 7,390 800 1,080 160 1,240 26,02312 N 1.010 0 7,390 800 1,000 280 1,280 36,70513 N 1.012 0 8,220 800 1,000 0 1,000 88,78314 N 1.012 0 7,390 800 1,040 40 1,080 63,19715 N 1.012 0 9,192 800 1,120 0 1,120 39,01916 N 1.012 0 8,220 800 1,120 120 1,240 34,92117 N 1.012 0 7,920 800 1,000 400 1,400 32,25418 N 1.012 0 7,122 800 1,040 80 1,120 76,34219 N 1.010 0 6,434 800 800 240 1,040 97,24020 N 1.010 0 5,316 800 840 160 1,000 67,56921 N 1.010 0 5,316 800 880 80 960 180,06022 N 1.004 0 1,674 400 360 200 560 38,12623 N 1.006 0 2,306 400 440 40 480 91,67824 N 1.006 0 2,306 400 400 0 400 74,646Average 1.011 0 7,761 750 922 240 1,162 21.2 6.94 7.29 8.68 - 50,159Maximum 1.018 0 13,480 800 1,160 520 1,600 23.0 7.11 7.35 8.75 - 180,060Minimum 1.004 0 1,674 400 360 0 400 20.00 6.88 7.20 8.62 - 7,964Range 0.014 0 11,806 400 800 520 1,200 3.0 0.23 0.15 0.13 - 172,0968.75 y10020.0 7.11 7.31 8.74 y9923.0 6.89 7.26y10521.06.88 7.34 8.62 y8.65 Y10522.0 6.89 7.35 8.6610120.0 6.92 7.20Well Name:3S-719Water Source:3JAlaska District Field QCPrejob Water Analysis on LocationCompany:Conoco Phillips Conoco Phillips - 3S-719Water Analysis 8.25201 SpecificGravityTestingTemperatureDissolved Iron(Fe2+)Chloride(Cl-)Sulfate(SO42-)Calcium(Ca2+)Magnesium(Mg2+)TotalHardnessLinearViscosityWaterpHGelpHPost-CrosslinkpHCrosslink Bacteria- °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ ValueTank #H2S present? Y/NHydrometer Digital ThermometerStrip Strip Strip TitrationTotal Hardness Minus CalciumTitration FANN-35 Probe Probe Probe - Mycometer1 N 1.010 0 7,100 800 360 1,040 1400 713252 N 1.010 0 7,710 800 360 1,120 1480 769653 N 1.010 0 7,710 800 320 1,240 1560 668034 N 1.010 0 7,100 800 400 840 1240 659325 N 1.010 0 7,710 800 400 600 1000 639306 N 1.008 0 5,990 800 480 680 1160 580667 N 1.006 0 5,990 800 600 1,120 1720 599948 N 1.006 0 4,130 800 960 1,040 2000 369519 N 1.008 0 4,560 800 1,600 120 1720 3420310 N 1.006 0 4,560 800 280 1,160 1440 6703911 N 1.008 0 5,000 800 440 1,280 1720 5998912 N 1.006 0 3,740 800 440 560 1000 4230813 N 1.008 0 4,560 800 320 1,240 1560 6089114 N 1.010 0 4,580 800 280 1,000 1280 660415 N 1.010 0 5,000 800 560 520 1080 6058116 N 1.012 0 7,100 800 400 400 800 54429Average 1.009 0 5,784 800 513 873 1,385 21.5 7.09 7.51 8.69 - 55,376Maximum 1.012 0 7,710 800 1,600 1,280 2,000 23.0 7.20 7.60 8.74 - 76,965Minimum 1.006 0 3,740 800 280 120 800 20.00 6.96 7.39 8.66 - 6,604Range 0.006 0 3,970 0 1,320 1,160 1,200 3.0 0.24 0.21 0.08 - 70,360Alaska District Field QCPrejob Water Analysis on LocationCompany:Conoco Phillips Well Name:3S-719Water Source:3J8.69 Y10420.0 7.00 7.48 8.66 Y10321.0 6.96 7.398.68 Y10022.0 7.20 7.56 8.74 Y9923.0 7.18 7.60Conoco Phillips - 3S-719Water Analysis 8.26202 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Post-Crosslink pH Crosslink Bacteria - °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value Tank # H2S present? Y/N Hydrometer Digital Thermometer Strip Strip Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer 1 N 1.010 0 10,352 800 360 1,040 1,400 71,325 2 N 1.010 0 10,352 800 360 1,120 1,480 76,965 3 N 1.008 0 11,754 800 320 1,240 1,560 66,803 4 N 1.012 0 11,754 800 400 840 1,240 65,932 5 N 1.010 0 7,100 800 400 600 1,000 63,930 6 N 1.008 0 7,710 800 480 680 1,160 58,066 7 N 1.006 0 7,710 800 600 1,120 1,720 59,994 8 N 1.006 0 7,100 800 960 1,040 2,000 36,951 9 N 1.008 0 7,710 800 1,600 120 1,720 34,203 10 N 1.006 0 5,990 800 280 1,160 1,440 67,039 11 N 1.008 0 5,990 800 440 1,280 1,720 59,989 12 N 1.006 0 4,130 800 440 560 1,000 42,308 13 N 1.008 0 4,560 800 320 1,240 1,560 60,891 14 N 1.010 0 4,560 800 280 1,000 1,280 6,604 15 N 1.010 0 5,000 800 560 520 1,080 60,581 16 N 1.012 0 3,740 800 400 400 800 54,429 17 N 1.012 0 4,560 800 1,000 400 1,400 32,254 18 N 1.012 0 4,580 800 1,040 80 1,120 76,342 19 N 1.010 0 5,000 800 800 240 1,040 97,240 20 N 1.010 0 7,100 800 840 160 1,000 67,569 21 N 1.010 0 5,316 800 880 80 960 54,690 22 N 1.004 0 1,674 800 360 200 560 38,126 23 N 1.006 0 2,306 800 440 360 800 91,678 24 N 1.006 0 2,306 800 400 400 800 74,646 Average 1.009 0 6,181 800 582 662 1,243 22.0 7.04 7.26 8.70 - 59,106 Maximum 1.012 0 11,754 800 1,600 1,280 2,000 23.0 7.12 7.30 8.75 - 97,240 Minimum 1.004 0 1,674 800 280 80 560 21.00 6.97 7.19 8.60 - 6,604 Range 0.008 0 10,080 0 1,320 1,200 1,440 2.0 0.15 0.11 0.15 - 90,635 Alaska District Field QC Prejob Water Analysis on Location Company:Conoco Phillips Well Name:3S-721 Water Source:CPF3 8.60 Y 90 22.0 7.01 7.29 8.65 92 22.0 7.12 7.25 y 90 23.0 6.97 7.19 8.75 y 8.75 y 100 22.0 7.06 7.30 8.74 y 91 21.0 7.05 7.26 Conoco Phillips - 3S-719 Water Analysis 8.30 203 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Post-Crosslink pH Crosslink Bacteria - °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value Tank # H2S present? Y/N Hydrometer Digital Thermometer Strip Strip Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer 1 N 1.003 80 0 4,130 800 1,000 800 1,800 59,198 2 N 1.004 76 0 7,710 800 1,000 600 1,600 41,756 3 n 1.004 85 0 4,560 800 1,200 600 1,800 38,175 4 N 1.004 80 0 6,520 800 800 1,000 1,800 51,748 5 N 1.003 81 0 4,560 800 960 1,040 2,000 51,873 6 N 1.003 79 0 4,560 800 1,600 600 2,200 37,503 7 N 1.005 80 0 5,480 800 800 1,000 1,800 37,426 8 N 1.005 81 0 5,990 800 1,000 800 1,800 29,482 9 N 1.005 81 0 7,100 800 1,200 800 2,000 36,682 10 N 1.005 81 0 7,710 800 1,200 800 2,000 41,192 23 N 1.010 86 0 7,710 800 1,200 800 2,000 52,597 24 N 1.006 82 0 4,560 800 1,000 800 1,800 45,350 Average 1.005 0 5,883 800 1,080 803 1,883 25.7 7.28 7.47 9.02 - 43,582 Maximum 1.010 0 7,710 800 1,600 1,040 2,200 27.0 7.40 7.53 9.26 - 59,198 Minimum 1.003 0 4,130 800 800 600 1,600 24.00 7.20 7.42 8.61 - 29,482 Range 0.007 0 3,580 0 800 440 600 3.0 0.20 0.11 0.65 - 29,716 Alaska District Field QC Prejob Water Analysis on Location Company:Conoco Phillips Well Name:3S - 719 Water Source:CPF3 26.0 7.4 7.5 9.3 Y 27.0 7.2 7.5 9.2 Y 24.0 7.3 7.4 8.6 Y Conoco Phillips - 3S-719 Water Analysis 9.5 204 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Post-Crosslink pH Crosslink Bacteria - °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value Tank # H2S present? Y/N Hydrometer Digital Thermometer Strip Strip Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer 1 N 1.000 88 0 3,000 400 1,000 1,600 2,600 23,341 2 N 1.000 88 0 3,000 400 1,000 1,400 2,400 25,698 3 N 1.000 88 0 3,000 200 800 1,400 2,200 64,072 4 N 1.000 88 0 3,000 400 800 1,600 2,400 37,182 12 N 1.000 80 0 3,360 200 1,000 1,000 2,000 43,091 13 N 1.000 82 0 3,740 400 1,200 1,200 2,400 36,544 14 N 1.000 79 0 3,000 400 1,200 1,400 2,600 29,329 15 N 1.000 80 0 3,000 400 800 1,200 2,000 25,782 16 N 1.000 81 0 3,000 400 1,000 1,000 2,000 26,871 17 N 1.000 78 0 3,000 200 1,000 1,200 2,200 45,045 18 N 1.000 78 0 3,000 200 1,200 600 1,800 29,837 19 N 1.000 77 0 3,000 400 1,000 1,000 2,000 34,600 20 N 1.000 76 0 3,000 400 800 1,600 2,400 29,138 21 N 1.000 75 0 3,000 400 1,000 1,600 2,600 41,477 22 N 1.000 78 0 3,360 400 1,000 1,600 2,600 29,831 23 N 1.000 79 0 3,360 400 1,000 1,000 2,000 4,997 24 N 1.000 80 0 3,000 200 800 1,000 1,800 5,666 25 N 1.000 81 0 3,740 400 1,000 1,600 2,600 41,417 Average 1.000 0 3,142 344 978 1278 2,256 25.8 7.00 7.30 9.44 - 31,655 Maximum 1.000 0 3,740 400 1,200 1,600 2,600 26.0 7.00 7.40 9.50 - 64,072 Minimum 1.000 0 3,000 200 800 600 1,800 25.00 7.00 7.20 9.40 - 4,997 Range 0.000 0 740 200 400 1,000 800 1.0 0.00 0.20 0.10 - 59,075 Alaska District Field QC Prejob Water Analysis on Location Company:Conoco Phillips Well Name:3S-719 Water Source:CPF3 26.0 7.0 7.2 9.4 Y 26.0 7.0 7.4 9.4 Y 26.0 7.0 7.4 9.5 Y 25.0 7.0 7.2 9.5 Y Conoco Phillips - 3S-719 Water Analysis 9.6 205 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Post-Crosslink pH Crosslink Bacteria - °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value Tank # H2S present? Y/N Hydrometer Digital Thermometer Strip Strip Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer 1 N 1.000 81 0 3,000 400 800 1,000 1,800 7,899 2 N 1.000 82 0 3,000 200 960 1,040 2,000 6,792 3 N 1.000 83 0 3,000 200 1,600 600 2,200 6,837 4 N 1.000 82 0 3,000 400 800 1,000 1,800 7,559 5 N 1.000 81 0 3,000 400 1,000 800 1,800 45,029 6 N 1.000 80 0 3,000 200 1,200 800 2,000 37,771 7 N 1.000 79 0 3,360 400 1,200 1,200 2,400 40,305 8 N 1.000 80 0 3,360 400 1,200 1,200 2,400 6,998 9 N 1.000 79 0 3,000 400 1,200 1,200 2,400 6,076 10 N 1.000 81 0 3,000 200 1,400 1,200 2,600 5,740 11 N 1.000 78 0 3,000 400 1,200 1,200 2,400 6,570 12 N 1.000 77 0 3,000 400 1,000 1,400 2,400 38,287 13 N 1.000 78 0 3,000 400 1,000 1,200 2,200 40,263 14 N 1.000 76 0 3,000 200 1,200 800 2,000 7,080 15 N 1.000 78 0 3,000 400 1,200 1,000 2,200 6,963 24 N 1.000 83 0 3,000 400 1,400 600 2,000 41,266 25 6,425 Average 1.000 0 3,045 338 1,148 1015 2,163 25.0 7.17 7.50 9.60 - 18,698 Maximum 1.000 0 3,360 400 1,600 1,400 2,600 25.0 7.20 7.60 9.60 - 45,029 Minimum 1.000 0 3,000 200 800 600 1,800 25.00 7.10 7.40 9.60 - 5,740 Range 0.000 0 360 200 800 800 800 0.0 0.10 0.20 0.00 - 39,289 Alaska District Field QC Prejob Water Analysis on Location Company:Conoco Phillips Well Name:3S-719 Water Source:CPF3 25.0 7.2 7.4 9.6 Y 25.0 7.2 7.5 9.6 Y 25.0 7.1 7.6 9.6 Y Conoco Phillips - 3S-719 Water Analysis 9.7 206 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Post-Crosslink pH Crosslink Bacteria - °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value Tank # H2S present? Y/N Hydrometer Digital Thermometer Strip Strip Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer 1 N 1.000 82 0 3,000 400 800 1,000 1,800 8,392 2 N 1.000 81 0 3,000 800 960 1,040 2,000 40,264 3 N 1.000 79 0 3,000 400 1,600 600 2,200 32,626 4 N 1.000 79 0 3,000 400 800 1,000 1,800 22,660 5 N 1.000 78 0 3,000 400 1,000 800 1,800 28,776 6 N 1.000 82 0 3,000 400 1,200 800 2,000 17,238 7 N 1.000 79 0 3,000 800 1,200 1,200 2,400 42,088 8 N 1.000 80 0 3,000 200 1,200 1,200 2,400 52,952 9 N 1.000 79 0 3,000 400 1,200 1,200 2,400 28,129 10 N 1.000 82 0 3,000 200 1,400 1,200 2,600 17,254 11 N 1.000 82 0 3,000 400 1,200 1,200 2,400 5,257 12 N 1.000 80 0 3,000 400 1,000 1,400 2,400 7,523 13 N 1.000 81 0 3,000 200 1,000 1,200 2,200 10,538 14 N 1.000 80 0 3,000 400 1,200 800 2,000 18,376 15 N 1.000 79 0 3,000 400 1,200 1,000 2,200 8,904 16 N 1.000 79 0 3,000 400 1,600 800 2,400 8,991 Average 1.000 0 3,000 413 1,160 1028 2,188 25.0 7.08 7.23 9.48 - 21,873 Maximum 1.000 0 3,000 800 1,600 1,400 2,600 26.0 7.10 7.25 9.50 - 52,952 Minimum 1.000 0 3,000 200 800 600 1,800 24.00 7.00 7.20 9.45 - 5,257 Range 0.000 0 0 600 800 800 800 2.0 0.10 0.05 0.05 - 47,696 Alaska District Field QC Prejob Water Analysis on Location Company:Conoco Phillips Well Name:3S-719 Water Source:CPF3 26.0 7.00 7.20 9.45 Y 25.0 7.10 7.25 9.50 Y Y 25.0 7.10 7.20 9.45 Y 24.0 7.10 7.25 9.50 Conoco Phillips - 3S-719 Water Analysis 9.8 207 Specific Gravity Testing Temperature Dissolved Iron (Fe2+) Chloride (Cl-) Sulfate (SO4 2-) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH Post-Crosslink pH Crosslink Bacteria - °F mg/L mg/L mg/L mg/L mg/L mg/L cP - - - (Y/N) BQ Value Tank # H2S present? Y/N Hydrometer Digital Thermometer Strip Strip Strip Titration Total Hardness Minus Calcium Titration FANN-35 Probe Probe Probe - Mycometer 1 N 1.001 87 0 3,000 800 1,200 1,200 2,400 32,745 2 N 1.001 86 0 3,000 800 1,400 800 2,200 11,307 3 N 1.000 87 0 3,000 400 1,200 800 2,000 11,129 4 N 1.001 85 0 3,000 800 1,200 1,200 2,400 32,137 5 N 1.000 85 0 3,000 400 1,200 1,200 2,400 33,274 6 N 1.001 84 0 3,000 400 1,200 1,200 2,400 32,910 7 N 1.000 85 0 3,000 400 1,400 1,200 2,600 36,268 8 N 1.000 83 0 3,000 400 1,200 1,200 2,400 36,695 9 N 1.000 85 0 3,000 400 1,000 1,400 2,400 35,974 10 N 1.006 86 0 21,220 800 1,000 1,200 2,200 38,323 11 N 1.006 85 0 23,190 800 1,200 800 2,000 41,566 12 N 1.006 82 0 13,960 800 1,200 1,000 2,200 38,537 13 N 1.005 79 0 9,360 800 1,600 800 2,400 36,844 14 N 1.006 80 0 16,440 800 1,800 600 2,400 36,062 15 N 1.006 86 0 16,440 800 1,600 800 2,400 32,715 Average 1.003 0 8,507 640 1,293 1027 2,320 24.0 7.10 7.25 9.12 - 32,433 Maximum 1.006 0 23,190 800 1,800 1,400 2,600 25.0 7.10 7.26 9.40 - 41,566 Minimum 1.000 0 3,000 400 1,000 800 2,000 22.00 7.10 7.25 8.60 - 11,129 Range 0.006 0 20,190 400 800 600 600 3.0 0.00 0.01 0.80 - 30,437 Alaska District Field QC Prejob Water Analysis on Location Company:Conoco Phillips Well Name:3S-719 Water Source:CPF3 25.0 7.10 7.26 9.40 Y 25.0 7.10 7.25 9.35 Y Y22.0 7.10 7.25 8.60 Conoco Phillips - 3S-719 Water Analysis 9.9 208 Linear Linear XL XL XL Lip time #NAME? Linear Linear XL XL XL Lip time #NAME? Linear Linear XL XL XL Lip time Interval Stage Visc pH Temp °F pH min Interval Stage Visc pH Temp °F pH min Interval Stage Visc pH Temp °F pH min 1 Pad 22 7.12 78 8.63 11 Pad 25 7.1 82 9.4 0 21 Pad 24 7.2 80 9.2 0 .50# 23 7.3 82 8.92 21 Avg Linear Visc .50# 25 7.2 80 9.4 0 26 Avg Linear Visc .50# 25 7.2 83 9.3 0 2.00# 23 7.3 83 8.98 82.0 Avg XLTemp 2.00# 26 7.2 80 9.4 0 79.6 Avg XLTemp 2.00# 25 7.2 80 9.25 0 4.00# 22 6.8 84 8.89 8.8 Avg XL pH 4.00# 26 7.1 80 9.4 0 9.42 Avg XL pH 4.00# 25 7.1 80 9.2 0 6.00# 20 7 84 8.85 6.00# 26 7.2 80 9.4 0 6.00# 24 7.2 77 9.11 0 7.00# 21 6.92 83 8.78 7.00# 26 7.1 80 9.4 0 7.00# 24 7.2 76 9.21 0 8.00# 20 6.97 78 8.73 8.00# 26 7.2 78 9.35 0 8.00# 24 7.2 77 9.11 0 9.00# 20 6.96 83 8.73 9.00# 26 7.2 78 9.5 0 9.00# 24 7.1 80 9.12 0 10.00# 20 6.94 83 8.68 10.00# 26 7.1 78 9.5 0 10.00# 25 7.1 80 9.12 0 2 Pad 20 6.92 90 8.6 12 Pad 25 7.1 83 9.4 0 22 Pad .50# 19 6.97 86 8.62 .50# 25 7.2 82 9.5 0 .25# 2.00# 21 7 95 8.71 2.00# 25 7.1 84 9.5 0 1.00# 4.00# 19 7.02 86 8.7 20 Avg Linear Visc 4.00# 25 7.1 83 9.5 0 25 Avg Linear Visc 2.00# 6.00# 20 6.88 80 8.77 85.9 Avg XLTemp 6.00# 25 7 82 9.5 0 81.4 Avg XLTemp 3.00# 7.00# 20 6.95 81 8.76 8.7 Avg XL pH 7.00# 24 7 80 9.6 0 9.53 Avg XL pH 4.00# 8.00# 22 6.97 83 8.69 8.00# 25 7.1 81 9.6 0 4.50# 9.00#9.00# 25 7.1 80 9.6 0 5.00# 10.00#10.00# 25 7 78 9.6 0 5.50# 6.00# 6.50# 79 7.00# 3 Pad 22 7.07 87 8.6 13 Pad 25 7 75 9.1 0 23 Pad .50# 20 6.85 82 8.72 .50# 26 7.1 77 9.1 0 .25# 2.00# 19 6.97 87 8.7 2.00# 26 7.1 78 9.2 0 1.00# 4.00# 20 6.89 87 8.67 20 Avg Linear Visc 4.00# 26 7 79 9.2 0 26 Avg Linear Visc 2.00# 6.00# 20 7.01 85 8.69 84.8 Avg XLTemp 6.00# 26 7 80 9.25 0 78.9 Avg XLTemp 3.00# 7.00# 21 6.84 85 8.67 8.7 Avg XL pH 7.00# 26 7.1 80 9.1 0 9.17 Avg XL pH 4.00# 8.00# 20 6.89 82 8.82 8.00# 26 7 80 9.2 0 4.50# 9.00# 20 6.75 86 8.69 9.00# 25 7 80 9.2 0 5.00# 10.00# 20 6.78 82 8.7 10.00# 25 7.1 81 9.2 0 5.50# 6.00# 6.50# 7.00# 4 Pad 22 7.12 87 8.73 14 Pad 25 7.1 80 9.25 0 24 Pad .50# 22 7.21 85 8.8 .50# 25 7 82 9.25 0 .25# 2.00# 22 7.18 84 8.79 2.00# 25 7 85 9.25 0 1.00# 4.00# 22 7.19 83 8.71 22 Avg Linear Visc 4.00# 26 7 85 9.26 0 26 Avg Linear Visc 2.00# 6.00# 22 7.12 78 8.73 81.2 Avg XLTemp 6.00# 26 7.1 85 9.26 0 81.4 Avg XLTemp 3.00# 7.00# 23 7.12 77 8.8 8.77 Avg XL pH 7.00# 26 7 78 9.3 0 9.28 Avg XL pH 4.00# 8.00# 23 7.14 77 8.76 8.00# 26 7 80 9.3 0 4.50# 9.00# 22 7.17 80 8.81 9.00# 26 7.2 80 9.34 0 5.00# 10.00# 21 7.2 80 8.79 10.00# 25 7 78 9.35 0 5.50# 6.00# 6.50# 7.00# 5 Pad 20 7 83 8.8 1 15 Pad 25 7.2 80 9.3 0 25 Pad .50# 25 7.2 95 8.75 0 .50# 25 7.1 81 9.32 0 .25# 2.00# 25 7.2 92 8.8 0 2.00# 25 7.1 85 9.32 0 1.00# 4.00# 25 7.2 95 8.75 0 23.33 Avg Linear Visc 4.00# 25 7 80 9.38 0 25 Avg Linear Visc 2.00# 6.00# 23 7.2 92 8.75 0 93.00 Avg XLTemp 6.00# 26 7 75 9.38 0 79.3 Avg XLTemp 3.00# 7.00# 23 7 95 8.75 0 8.77 Avg XL pH 7.00# 26 7 78 9.39 0 9.36 Avg XL pH 4.00# 8.00# 25 7 95 8.75 0 8.00# 25 7 80 9.4 0 4.50# 9.00# 22 7 95 8.8 0 9.00# 26 7.1 80 9.4 0 5.00# 10.00# 22 7 95 8.8 0 10.00# 25 7.2 75 9.38 0 5.50# 6.00# 6.50# 7.00# 6 Pad 25 7.2 90 8.83 0 16 Pad 24 7.25 82 9.25 0 26 Pad .50# 23 7 90 8.83 0 .50# 27 7.25 88 9.25 0 .25# 2.00# 24 7 90 8.75 0 2.00# 27 7.25 82 9.25 0 1.00# 4.00# 24 7 90 8.8 0 24.00 Avg Linear Visc 4.00# 26 7.27 80 9.22 0 26 Avg Linear Visc 2.00# 6.00# 24 7 88 8.9 0 89.60 Avg XLTemp 6.00# 26 7.2 77 9.3 0 80.0 Avg XLTemp 3.00# 7.00# 8.82 Avg XL pH 7.00# 26 7.25 78 9.3 0 9.28 Avg XL pH 4.00# 8.00#8.00# 26 7.2 78 9.3 0 4.50# 9.00#9.00# 26 7.2 77 9.33 0 5.00# 10.00#10.00# 26 7.2 78 9.3 0 5.50# 6.00# 6.50# 7.00# 7 Pad 24 7 90 8.85 0 17 Pad 25 7.25 80 9.25 0 27 Pad .50# 25 7 85 8.9 0 .50# 25 7.2 86 9.3 0 .25# 2.00# 25 7.1 90 8.75 0 2.00# 26 7.2 87 9.42 0 1.00# 4.00# 25 7 85 8.75 0 23 Avg Linear Visc 4.00# 26 7.2 88 9.45 0 26 Avg Linear Visc 2.00# 6.00# 23 7 90 8.73 0 86.0 Avg XLTemp 6.00# 27 7.25 87 9.47 0 82.8 Avg XLTemp 3.00# 7.00# 23 7 85 8.75 0 8.8 Avg XL pH 7.00# 26 7.25 80 9.5 0 9.42 Avg XL pH 4.00# 8.00# 22 7 85 8.7 0 8.00# 26 7.2 80 9.5 0 4.50# 9.00# 22 7.1 82 8.7 0 9.00# 26 7.2 80 9.45 0 5.00# 10.00# 22 7.1 82 8.7 0 10.00# 26 7.2 77 9.4 0 5.50# 6.00# 6.50# 7.00# 8 Pad 24 7.1 85 8.75 0 18 Pad 27 7.2 85 9.3 0 28 Pad .50# 23 7.2 90 8.65 0 .50# 27 7.2 82 9.3 0 .25# 2.00# 24 7.2 85 8.75 0 2.00# 27 7.2 83 9.32 0 1.00# 4.00# 24 7.1 88 8.75 0 23.78 Avg Linear Visc 4.00# 26 7.2 80 9.35 0 26 Avg Linear Visc 2.00# 6.00# 23 7 85 8.7 0 84.67 Avg XLTemp 6.00# 26 7.2 82 9.37 0 80.9 Avg XLTemp 3.00# 7.00# 23 7.1 80 8.75 0 8.73 Avg XL pH 7.00# 26 7.2 78 9.32 0 9.3 Avg XL pH 4.00# 8.00# 24 7.1 82 8.75 0 8.00# 26 7.15 80 9.32 0 4.50# 9.00# 24 7.1 82 8.75 0 9.00# 26 7.2 78 9.35 0 5.00# 10.00# 25 7 85 8.7 0 10.00# 26 7.2 80 9.35 0 5.50# 6.00# 6.50# 7.00# 9 Pad 25 7.2 90 8.75 0 19 Pad 23 7.2 80 9.1 0 29 Pad .50# 25 7.1 90 8.75 0 .50# 24 7.2 79 9 0 .25# 2.00# 25 7.2 90 9.2 0 2.00# 28 7.2 83 9.1 0 1.00# 4.00# 26 7.2 88 9.2 0 25 Avg Linear Visc 4.00# 26 7.2 82 9.1 0 26 Avg Linear Visc 2.00# 6.00# 25 7.1 85 9.25 0 88.3 Avg XLTemp 6.00# 27 7.1 80 9.08 0 79.7 Avg XLTemp 3.00# 7.00# 26 7.1 87 9.23 0 9.12 Avg XL pH 7.00# 26 7.1 80 9.12 0 9.1 Avg XL pH 4.00# 8.00# 26 7 90 9.22 0 8.00# 25 7.1 76 9.1 0 4.50# 9.00# 25 7 85 9.2 0 9.00# 25 7.2 77 9.11 0 5.00# 10.00# 25 7.2 90 9.25 0 10.00# 26 7.2 80 9.1 0 5.50# 6.00# 6.50# 7.00# 10 Pad 23 7.5 93 8.7 0 20 Pad 25 7.2 87 8.9 0 30 Pad .50# 23 7.2 90 9.1 0 .50# 27 7.2 85 9.1 0 .25# 2.00# 25 7.2 90 9.7 0 2.00# 26 7.2 84 9.1 0 1.00# 4.00# 25 7.1 88 9.6 0 25 Avg Linear Visc 4.00# 27 7.2 80 9.1 0 25 Avg Linear Visc 2.00# 6.00# 25 7.1 87 9.5 0 87.6 Avg XLTemp 6.00# 25 7.2 75 9.11 0 80.6 Avg XLTemp 3.00# 7.00# 25 7.2 85 9.5 0 9.37 Avg XL pH 7.00# 25 7.1 77 9.14 0 9.1 Avg XL pH 4.00# 8.00# 25 7.2 85 9.4 0 . 8.00# 24 7.1 77 9.15 0 4.50# 9.00# 25 7.1 85 9.4 0 9.00# 25 7.2 80 9.12 0 5.00# 10.00# 25 7 85 9.4 0 10.00# 25 7.1 80 9.1 0 5.50# 6.00# 6.50# 7.00# Customer:CONOCO PHILLIPS Wellname & #:3S-719 Date: Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Conoco Phillips - 3S-719 Real-Time QC 209 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Test #1Test #2Test #3Test #4time (hr:min) -->00:00 01:00 02:00 03:00 04:00 05:00 10:00 15:00 20:00 25:00 30:00 45:00 1:00 1:15 1:30 1:45 2:00 2:15 2:30 2:45 3:00 3:30 4:00 4:30 5:00 5:30 6:006:30Test #1 (cp) -->6172 3086 2469 2345 2716 1728 2222 2247 1777 2148 2197 1852 2345 2098 1975 1901 1679 1481 1234 1111 815 667 247 123 74 0 0 0Dial Reading25012510095110709091728789759585807768605045332710 5 3Test #2 (cp) -->0000000000000000000000000000Dial ReadingTest #3 (cp) -->0000000000000000000000000000Dial ReadingTest #4 (cp) -->0000000000000000000000000000Dial Readingstarted 1538878.801.0027.001.000.801.000.451.00Temp 0FPHLOSURF-300DWG-36CAT-3MO-67LD-6450BC-140X2OptiFlo-IIDD.. MartinezHydration Visc:2395Temperature was held at 115 degres for the duration of the testAll chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:6.98CoyoteHydration pH:7.243S-719Stage(s):Break Test105Water Source:3JALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:8/24/2025ConocoPhillipsProject No:0100020003000400050006000700000:00 02:00 04:00 10:00 20:00 30:00 1:00 1:30 2:00 2:30 3:00 4:00 5:006:00Viscosity (cp)Time (min:sec)Prejob Crosslink Break Tests27# - Opti II @ 1.0Fluid is broken at 200cpConoco Phillips - 3S-719Prejob Break Test210 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):1105Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:ConocoPhillipsProject No:DD.. MartinezHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:7.30CoyoteTemp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450848.631.000.451.000.751.0027.001.000500100015002000250030003500400000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 1 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 1211 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):2105Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:ConocoPhillipsProject No:DD.. MartinezHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:7.25CoyoteTemp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450888.761.000.451.000.751.0027.001.00010002000300040005000600000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 2 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 2212 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):3105Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:ConocoPhillipsProject No:DD.. MartinezHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:7.09CoyoteHydration pH:22.00Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450958.701.000.451.000.751.0027.001.000100020003000400050006000700000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 3 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 3213 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad.50 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):4140Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:ConocoPhillipsProject No:DD.. MartinezHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450948.771.000.451.000.801.0027.001.0005001000150020002500300035004000450000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 4 Crosslink Tests.50 ppg0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 4214 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad.50 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):5105Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/4/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450908.801.000.451.000.701.0027.001.0005001000150020002500300035004000450000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 5 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 5215 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad.50 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):6105Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/4/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450878.851.000.451.000.801.0027.001.0005001000150020002500300035004000450000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 6 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 6216 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):7105Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/5/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450888.851.000.451.000.701.0027.001050010001500200025003000350000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 7 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 7217 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):8Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/5/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450938.751.000.451.000.701.0027.001050010001500200025003000350000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 8 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 8218 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):9Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/5/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450938.761.000.500.000.701.2530.001050010001500200025003000350040004500500000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 9 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 9219 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):10Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/6/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450968.701.000.500.001.001.2530.001050010001500200025003000350040004500500000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 10 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 10220 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):11Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/6/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450999.401.000.500.001.001.2530.0010500100015002000250030003500400000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 11 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 11221 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):12Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/6/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450899.401.000.500.001.001.2530.001010002000300040005000600000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 12 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 12222 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):13Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/7/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450909.101.000.500.001.401.2530.00105001000150020002500300035004000450000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 13 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 13223 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):14Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/7/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450909.251.000.500.001.401.2530.001050010001500200025003000350000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 14 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 14224 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):15Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/7/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450909.301.000.500.001.401.2530.00105001000150020002500300035004000450000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 15 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 15225 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):16Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/8/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:CoyoteHydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450909.251.000.500.001.101.2530.00101000200030004000500060007000800000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 16 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 16226 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):17Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/8/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450909.251.000.500.001.101.2530.00101000200030004000500060007000800000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 17 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 17227 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):18Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/8/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:Hydration pH:Temp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450909.301.000.500.000.701.2530.001050010001500200025003000350040004500500000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 18 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 18228 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):19105Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/9/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:22All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:7.30CoyoteTemp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450849.101.000.500.000.601.2530.0010100020003000400050006000700000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 19 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp0100020003000400050006000700000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 19 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 19229 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):1105Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/9/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:7.30CoyoteTemp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450848.901.000.500.001.001.2530.001050010001500200025003000350040004500500000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 20 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp050010001500200025003000350040004500500000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 20 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 20230 Company:Well Name:BHST (ºF):Depth:Formation:Analyst:cp @Lot Number--->Pad0.5 ppg 1 ppg 2 ppg3 ppg4 ppg3S-719Stage(s):1105Water Source:CPF3ALASKA DISTRICT LABORATORY15 Minute Fann Model 35 Crosslinked Fluid ReportFluid System: Date:9/9/2025ConocoPhillipsProject No:EE.. BRITTONHydration Visc:All chemical concentrations below are in gallons per thousand / pounds per thousandWater pH:7.30CoyoteTemp 0FPHLOSURF-300DBC-140X2CAT3MO-67Optiflo-IIWG-36LD6450849.201.000.500.000.601.2530.0010100020003000400050006000700000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 20 Crosslink TestsPad1 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cp0100020003000400050006000700000:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00Viscosity (cp)Time (min:sec)Zone 21 Crosslink TestsPad0.5 ppg2 ppg3 ppg4 ppg5 ppgFluid is broken at 200cpConoco Phillips - 3S-719Fann 15 - Interval 21231 Company: Well: Sand Type Date Tested Total Sample Size Seive Weight Seive Weight 100.0 g Sieve Size Before Sand With sand WT. rtn'd % rtn'd % API Spec 12 355.4 355.4 0 0.0% 0.00% <0.1% 16 340.3 348.4 8.1 8.1% 18 303.4 381.4 78 78.0% 20 296.6 309.9 13.3 13.3% 25 419.6 420.2 0.6 0.6% 30 281.7 281.7 0 0.0% 40 407.9 407.9 0 0.0% Pan 306.8 306.8 0 0.0% 0.00% <1.0% Total: 100 100% Conoco Phillips 3S-719 16/20 Proppant 8/26/2025 Ceramic Proppant Sieves Sample: 16 / 20 - 7/6/2025 91.90%>/= 90% Conoco Phillips - 3S-719 Sand Sieve Analysis 232 T R A N S M I T T A LL FROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7 th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska RE: 3S-719PB1 225-058 DATE:9/26/2025 Transmitted: 3S-719PB1 Via SFTP Transmittall instructions: please promptly sign, scan, and e-mail to AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM CC: 3S-719PB1- e-transmittal well folder Receipt: Date: Alaska/IT-Data Services |ConocoPhillips Alaska | 225-058 T40928 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.26 12:37:50 -08'00' Originated: Delivered to:11-Sep-25Alaska Oil & Gas Conservation Commiss11Sep25-NR ! "# $$%$ !&$$'($)*%+ ($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3T-616 50-103-20899-00-00 224-138 Kuparuk River WL TTiX-FSI FINAL FIELD 30-Aug-253S-719 50-103-20919-00 225-058 Kuparuk River WL TTiX-HSD FINAL FIELD 3-Sep-25CD2-40 50-103-20464-00-00 203-126 Colville River WL Patch FINAL FIELD 7-Sep-25CD2-21 50-103-20504-00-00 204-245 Colville River WL Patch FINAL FIELD 7-Sep-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8 " ! - +" 8 # !(3 . 8 ) "3 8 # !9 3 : 8" +8 6 8 8 " 8 # !;" " 3 - 3 " 3 ""+ 3 + < +3!% T40870T40871T40872T408733S-71950-103-20919-00225-058Kuparuk RiverWLTTiX-HSDFINAL FIELD3-Sep-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.09.12 08:32:59 -08'00' T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Sep 05, 2025 AOGCC Attention: Meredith Guhl 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. KRU 3S-719 /3S-719PB1 Kuparuk River API #: 50-103-20919-00-00/50-103-20919-70-00 Permit No: 225-047 Rig: Doyon 25 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Hampton, Jerissa AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Luis G Arismendi Luis.arismendi@bakerhughes.com 225-058 KRU 3S-719: T40852 KRU 3S-719PB1: T40853 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.05 08:37:56 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?KRU 3S-719 Yes No 9. Property Designation (Lease Number):10. Field: Coyote Oil Pool Coyote Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 21148 4203.00 21148 4203.00 1972 None None Casing Collapse Structural Conductor Surface 2470 Intermediate 4790 Intermediate 7850 Liner 9210 Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Madeline Woodard Contact Email:madeline.e.woodard@cop.com Contact Phone: 907-265-6086 Authorized Title:Completions Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng ADL380107, ADL025544, ADL025551 Kuparuk Field STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska Inc.225-058 P.O. Box 100360, Anchorage, Alaska 99510-0360 50-103-20919-00-00 Will perfs require a spacing exception due to property boundaries? Current Pools:Proposed Pools: CO 819 PRESENT WELL CONDITION SUMMARY MPSP (psi):Plugs (MD): Length Size MD TVD Burst 80 20"132.0 132.0 8417.8 7-5/8"8687.0 3930.00 6890 2978.5 10-3/4"3048.0 2550.00 5210 12960.8 4-1/2"21148.0 4203.00 11590 976.6 7-5/8"9684.0 4092.00 10860 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Perforation Depth MD (ft):Perforation Depth TVD (ft):Tubing Size:Tubing Grade:Tubing MD (ft): 4-1/2"L-80 9516 Halliburton TNT Prod Packer Baker ZXP, No SSSV TNT packer: 9330 ft MD/4041 ft TVD ZXP packer: 9511 ft MD/4068 ft TVD 8/24/2025 Authorized Name and Digital Signature with Date: AOGCC USE ONLY Suspension Expiration Date: Subsequent Form Required: m n s _ 2 66 tc N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:05 am, Aug 12, 2025 Digitally signed by Madeline Woodard DN: CN=Madeline Woodard, E=madeline.e.woodard@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.11 16:34:54-08'00' Foxit PDF Editor Version: 13.1.6 Madeline Woodard 325-476 VTL 8/21/2025 CDW 08/14/2025 10-404 Schematic shows 2767' MD / 2550' TVD SFD SFD 8/21/2025 DSR-8/14/25 8/24/2025 Fracture Stimulate *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.21 16:28:25 -08'00'08/21/25 RBDMS JSB 082225 Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). August 11, 2025 VIA E-MAIL To: Operator and Owners (shown on Exhibit 2) Re: Notice of Operations for 3S-719 Well ADL 380107, ADL 025544 & ADL 025551 Kuparuk River Unit, Alaska CPAI Contract No. 203828 Pursuant to 20 AAC 25.283, ConocoPhillips Alaska, Inc. (“CPAI”) as Operator of the Kuparuk River Unit, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing in accordance with 20 AAC 25.280 (“Application”) for the 3S- 719 Well (the “Well”). The Application will be filed with the Alaska Oil and Gas Conservation Commission on or about August 11, 2025. The Well is currently planned to be drilled as a directional horizontal well on lease ADL 380107, ADL 025544 and ADL 025551 as depicted on Exhibit 1, and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 2,537’ 1,158’ T12N R8E 18 Umiat Top Open Interval 2,064’ 3,244’ T12N R7E 13 Umiat Bottomhole 2,567’ 2,150’ T12N R7E 25 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well (“Notification Area”), which includes the reservoir section. Exhibit 2 is a list of the names and addresses of all owners, landowners, surface owners, and operators of record at the time of this Application for all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, Ryan C. King, CPL Staff Land Negotiator Attachments: Exhibits 1 & 2 Ryan C. King, CPL Staff Land Negotiator Land & Business Development P.O. Box 100630 Anchorage, AK 99510-0360 Office: 907-265-6106 Fax: 907-263-4966 ryan.c.king@cop.com BCC: Madeline Woodard Brian Buck Jason C. Parker John Evans Patrick Perfetta Exhibit 1 Exhibit 2 List of the names and addresses of all owners, landowners, surface owners, and operators of record of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO-1480 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attn: GKA Asset Development Manager Owner (Non-Operator): ConocoPhillips Alaska II, Inc. ExxonMobil Alaska Production Inc. 700 G Street, Suite ATO 1226 PO Box 196601 Anchorage, Alaska 99510 Anchorage, AK 99519 Attn: GKA Asset Development Manager Attn: Todd Griffith Landowners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501 Attention: Derek Nottingham, Director Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501 Attention: Derek Nottingham, Director Section 2 – Plat 20 AAC 25.283 (2)(A) Plat 1: Wells within 1/2 mile Table 1: Wells within 1/2 miles (2)(C) Business Unit ID Business Area ID Field Name API * Well Name Status Symbology Well in Frac Port 1/2 mi Buffer Open Interval in Frac Port 1/2 mi Buffer KUP KRU KUPARUK RIVER UNIT 501032036100 PALM 1 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032036101 3S-26 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032043000 3S-07 ACTIVE Oil KUP KRU KUPARUK RIVER UNIT 501032043200 3S-09 ACTIVE Injector Miscible Water Alternating Gas KUP KRU KUPARUK RIVER UNIT 501032043300 3S-18 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032043900 3S-14 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032044000 3S-10 PA Plugged and Abandoned KUP TOROK TOROK 501032069500 3S-620 ACTIVE Oil Yes Yes KUP KRU KUPARUK RIVER UNIT 501032044400 3S-15 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032044500 3S-16 ACTIVE Injector Miscible Water Alternating Gas KUP KRU KUPARUK RIVER UNIT 501032044600 3S-22 PA Plugged and Abandoned Yes Yes KUP KRU KUPARUK RIVER UNIT 501032044800 3S-17 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032044801 3S-17A PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032045000 3S-08 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032045001 3S-08A PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032045002 3S-08B PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032045003 3S-08C ACTIVE Oil KUP KRU KUPARUK RIVER UNIT 501032045060 3S-08CL1 ACTIVE Oil KUP KRU KUPARUK RIVER UNIT 501032045070 3S-08CL1PB1 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032045200 3S-21 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032045300 3S-23 PA Plugged and Abandoned Yes - P&A Yes - P&A KUP KRU KUPARUK RIVER UNIT 501032045301 3S-23A SUSP Suspended Yes - Suspended Yes - Suspended KUP KRU KUPARUK RIVER UNIT 501032045400 3S-06 PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032045401 3S-06A PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032045600 3S-24 PA Plugged and Abandoned Yes - P&A Yes - P&A KUP KRU KUPARUK RIVER UNIT 501032045601 3S-24A PA Plugged and Abandoned Yes - P&A Yes - P&A KUP COYOTE COYOTE 501032045602 3S-24B PA Plugged and Abandoned KUP KRU KUPARUK RIVER UNIT 501032045800 3S-03 SUSP Suspended KUP KRU KUPARUK RIVER UNIT 501032046000 3S-19 SUSP Suspended Yes - Suspended Yes - Suspended KUP TOROK TOROK 501032073500 3S-613 ACTIVE Injector Produced Water Yes Yes KUP COYOTE COYOTE 501032090500 3T-731 ACTIVE Oil Yes Yes KUP TOROK TOROK 501032090600 3S-602 ACTIVE Oil KUP COYOTE COYOTE 501032090700 3T-730 ACTIVE Injector Produced Water Yes Yes KUP TOROK TOROK 501032084200 3S-625 ACTIVE Injector Produced Water Yes Yes KUP TOROK TOROK 501032084400 3S-615 ACTIVE Oil Yes Yes KUP COYOTE COYOTE 501032091000 3S-723 ACTIVE Oil KUP COYOTE COYOTE 501032091100 3S-721 ACTIVE Oil Yes Yes KUP COYOTE COYOTE 501032091300 3S-703 ACTIVE Oil KUP COYOTE COYOTE 501032091500 3S-705 ACTIVE Oil KUP COYOTE COYOTE 501032084700 3S-701 PA Plugged and Abandoned KUP COYOTE COYOTE 501032084701 3S-701A ACTIVE Injector Produced Water Yes Yes KUP COYOTE COYOTE 501032084800 3S-704 ACTIVE Oil KUP TOROK TOROK 501032086400 3S-617 ACTIVE Injector Produced Water KUP TOROK TOROK 501032077400 3S-611 ACTIVE Oil KUP TOROK TOROK 501032077470 3S-611PB1 PA Plugged and Abandoned KUP TOROK TOROK 501032086800 3S-624 ACTIVE Oil KUP TOROK TOROK 501032087000 3S-606 ACTIVE Injector Produced Water KUP TOROK TOROK 501032077700 3S-612 ACTIVE Injector Miscible Water Alternating Gas KUP TOROK TOROK 501032087500 3S-610 ACTIVE Oil KUP TOROK TOROK 501032087800 3S-626 ACTIVE Injector Miscible Water Alternating Gas KUP TOROK TOROK 501032087870 3S-626PB1 PA Plugged and Abandoned KUP COYOTE COYOTE 501032088400 3S-718 ACTIVE Oil KUP COYOTE COYOTE 501032088600 3S-722 ACTIVE Injector Produced Water KUP COYOTE COYOTE 501032090300 3S-714 ACTIVE Oil 3S-24B PA Plugged and Abandoned 3S-620 54 wells, 14 in frac zone. CDW 3S-22 3S-19 3S-719PB1. 3S-615 SECTION 3 – FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no known underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 5 of the Area Injection Order AIO 45- Coyote Oil Pool, which states “An aquifer exemption is not necessary for this project because the total dissolve solids of the water in the COP is over 21,000 mg/l, and the KRU has a valid aquifer exemption from the US EPA under 40 CFR 147.102(b)(3).” ypj KRU has a valid aquifer exemption from the US EPA under 40 CFR 147.102(b)(3).” SECTION 4 – PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 – DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) See Wellbore schematic for casing and cement details. 403 form shows 3048' MD / 2550' TVD SFD SECTION 6 – ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4” casing cement pump report on 6/27/2025 shows that the cement job was pumped with 450 barrels of 11.0 ppg lead cement and 57 barrels 15.8 ppg tail cement, displaced with 9.5 ppg mud. The plug bumped and pressured up to 1308psi and floats held. Returns were lost after 50bbls of tail cement was pumped, but the hanger was picked up and returns regained. 110bbls into the displacement, returns were lost again and only partially regained when the hanger was picked up. The hanger was unable to be landed again and 74bbls of contaminated cement returned to surface. A cement top job was completed in the 10-3/4” x conductor annulus with 20bbls of 11.0ppg DeepCrete cement pumped after 3/4” tubing tagged TOC at 107.7’ RKB. The 7-5/8” casing cement report on 7/5/2025 shows that the job was pumped with 90 barrels of 15.3ppg cement. The cement was displaced with 9.5ppg mud. The plugs did not bump, but floats were checked and were holding. Full returns were observed throughout the job. A sonic log indicated the cement top at 7,740’ MD / 3,766’ TVD / 3,702’ TVDSS (2088’ MD / 343’ TVD above the Coyote). Summary All casing is cemented in accordance with 20 AAC 25.030. SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 6/28/2025 the 10-3/4” casing was pressure tested to 3,500 psi for 30 minutes On 7/6/2025 the 7-5/8” intermediate casing was pressure tested to 4,000 psi for 30 minutes. The 4-1/2” tubing will be pressure tested to 4,100 psi for 30 minutes prior to rig down. The 7-5/8” casing by 4-1/2” tubing annulus will be pressure tested to 3,850 psi for 30 minutes prior to rig down. The 4-1/2” tubing will be pressure tested to 4,100 psi for 30 minutes and the 7-5/8” casing by 4-1/2” tubing annulus will be pressure tested to 3,850 psi for 30 minutes post-rig. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,075 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7-5/8" Annulus pressure test 3,850 4-1/2" Tubing pressure Test 4,075 Electronic PRV 8,075 Highest pump trip 7,575 4,100 4,075 SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight, ppf Grade API Burst, psi API Collapse, psi 10-3/4” 45.5 L-80 5,209 2,474 7-5/8” 29.7 L-80 6,885 4,789 7-5/8” 33.7 P-110S 10,860 7,870 4-1/2” 12.6 P-110S 11,590 9,210 4-1/2” 12.6 L-80 8,430 7,500 Table 2: Wellbore pressure ratings Stimulation Surface Rig-Up Kuparuk 10K Frac Tree SECTION 9 – DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the gross Coyote interval, has an average thickness greater than 440 ft TVD over the course of the lateral section of well 3S-719, from where it intersects the top formation at 9,828’ MD to TD of the well. At the heel of the well it has a gross thickness of ~220’ thickening to ~670’ at the toe of the well. The Coyote interval is comprised of thinly interbedded sandstone and siltstone layers. The sandstone and siltstone components are litharenites, moderately to well sorted, and are of the size range from silt to very fine sand. The estimated fracture pressure for the Coyote interval is approximately 12.9-16.1 ppg based on FIT/LOT data. The overlying confining interval is represented by distal toe of slope (deep marine) claystone with thin siltstone beds of the Cretaceous Seabee Formation. This interval is present in thicknesses of ~200’ TVT in the vicinity of the 3S-719 wellbore. The top of the confining intervals starts at ~3,824’ TVDSS (8,463’ MD). It should be noted that slope to basin shales and siltstones are present from the top of the Seabee formation to the surface casing shoe at 2,783’ MD. This interval acts as a continuation of the upper confining interval. Currently, there is limited data of the fracture gradient of the overlying Seabee formation, however, further data collection is planned. CPAI has completed a LOT in the overlying confining interval at 3,944’ TVDSS to 14.0ppg (0.728 psi/ft). CPAI also estimates the fracture closure pressure gradient to be 0.67 psi/ft based on diagnostic fracture injection testing (DFIT). The fracture gradient of the overlying Seabee formation will be greater than the fracture closure pressure gradient of 0.67 psi/ft and the leak off point of 0.73 psi/ft, per the figure below. Based on our dynamic fracture modeling, the fracture could propagate into the overlying interval, which was observed in the 3S-24B vertical well. The log results from the 3S-24B showed 34’ of potential fracture growth into the overburden compared to the ~200’ of TVT of the overlying zone. Additionally, geomechanical testing completed on the overburden core proved there is no remaining conductivity within a fracture that propagates into the overlying zone due to proppant embedment and interaction of the frac fluid with the rock. Post-frac injection will be at or below the fracture closure pressure (Pc) of the overlying seal which is less than the fracture propagation pressure (FPP). We have also lowered the lateral landing depth for the horizontal wells based on thickness of the gross package to be deeper than the perforation in the 3S-24B vertical well. The lower confining interval of the Coyote comprises slope to basin floor mudstones of the Torok formation, which are present in thicknesses of ~650’ TVT in the vicinity of the 3S-719 wellbore. This same confining zone forms the upper confining interval of the Kuparuk River Unit, Torok Oil Pool. The estimated fracture gradient for this section ranges from 15-18 ppg. The base of the gross Coyote interval is estimated from seismic to be at ~5,097 ft TVDSS at the heel, and ~5,197’ ft TVDSS at the toe of the well. The estimated formation pressure within the Coyote interval is 1,680 – 1,785 psi at a depth of 4,045’ TVDSS. g top formation at 9,828’ MD SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) ConocoPhillips has formed the opinion, based on the following assessments for each well’s mechanical condition, seismic, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & cement assessments for all wells that transect the confining zone are listed in the AOR submitted with this sundry application. A summary of the condition of each well is listed below: 3S-23/3S-23A: 3S-23 was originally drilled in 2003 and the main wellbore was abandoned in 2006 by cementing the perforations, cutting and pulling the 3-1/2” tubing, and the 7” casing at 4,149’ MD. A kick off plug was then set from 4,423’ MD with 43bbls of 17.0ppg Class G cement. This KOP isolated the Coyote from above. The 3S- 23A wellbore was then kicked off at 4,090’ MD after tagging cement at 3,696’ MD. 3S-23A was drilled to TD and completed for in the Kuparuk sand. Estimated TOC for the intermediate casing was 9,471’ MD/5,638’ TVD/5,581’ TVDSS. Plug and Abandonment operations on 3S-23A began on 4/30/2023 and were completed 1/6/2025. A cement retainer was set at 10,315’ MD via coil tubing and 80 bbls of 15.8ppg class G cement was pumped below the retainer and 2 bbls on top of the retainer. Cement was tagged at 10,048’ SLMD and a passing MIT-T and MIT-IA was performed and witnessed by AOGCC on 5/9/2023. The tubing was then cut at 9,805’ MD and the tubing pulled out of hole. A bridge plug was set at 6,718’ MD in the 7” casing and the 7” casing was perforated from 6,692’-6,542’ MD. Coil was utilized to perf wash and cement with 70bbls of 15.8ppg cement pumped into the perforations. TOC was tagged at 6,370’ SLMD in the 7” casing and a MIT-T performed to 1500 psi. TOC was determined in the annulus at 6,542’ MD / 4,030 TVD / 3,972’ TVDSS via log (58’ TVD above the Coyote). Coil was used to pump 40 bbls of 15.8ppg cement in the 7” casing. The TOC was tagged at 5,616’ MD and a MIT performed, witnessed by AOGCC on 2/14/2024. The top cement job was performed on 2/27/2024 with 239 bbls of 15.8ppg Class G cement and the 7” casing was cemented to surface. Integrity issues were then seen and the cement in the 7” casing was milled/underreamed to 4,255’ MD. A CIBP was set at 4,240’ MD and tested to 1,670 psi, witnessed by AOGCC on 12/18/2024. Cement was then pumped above the CIBP to surface using 52bbls of 15.8ppg premium lead cement and 130bbls of 15.8ppg tail cement. The 7” x 9-5/8” OA was cemented via down squeeze with 103bbls of 15.8ppg Permafrost cement (surface to 9-5/8” shoe) on 9/26/2023.The final abandonment was completed on 1/6/2025, witnessed by AOGCC. 3S-24/3S-24A/3S-24B: 3S-24 was originally drilled in 2003. The intermediate casing was set at 11,255’ MD / 5,083’ TVDSS and cemented with 75bbls of 12.0ppg LiteCrete cement. No losses were observed during the job. For gauge hole, the calculated TOC is 7,934’ MD/3,844’ TVDSS. The main wellbore was abandoned in 2004 by cementing the perforations (13,294-13,332’ MD) through a retainer, pulling the 3-1/2” tubing and using a whipstock to sidetrack out of the 7” intermediate casing at 10,509’ MD (top of window). The 3S-24A wellbore was drilled to TD and a 3-1/2” liner was run and cemented in place (12,513’ MD / 5,944’ TVDSS). 3-1/2” tubing was run for the upper completion and the 3-1/2” liner was perforated to target the Kuparuk sand. 3S-24A was then abandoned in 2021 for the 3S-24B sidetrack. The abandonment included cementing the perfs off via a retainer at 12,000’ MD. 15bbls of 15.8ppg Class G cement was pumped below the retainer and 14.4bbls of 15.8ppg Class G cement above the retainer. The following day, an additional 30bbls of 15.8ppg Class G cement was pumped down the tubing and up the IA via an open sliding sleeve. AOGCC witnessed the tag of the cement plug with slickline at 9,292’ SLMD and witnessed an MIT-T to 1500psi and an MIT-IA to 2500 psi on 10/21/21. The tubing was then cut at 7478’ MD and pulled out of hole. A CIBP was set at 7,320’ MD via E-line and the 7” casing tested to 2000psi for 10 minutes. The 3S-24B was then sidetracked via a whipstock with top of window (TOW) at 7,301’ MD/3,607’ TVDSS. The sidetrack was completed with 4-1/2” liner cemented in place with 37.8bbls of 15.8ppg Class G cement at 8,714’ MD/4,927’ TVD/4,871’ TVDSS. No losses were observed during the job. A 4-1/2” upper completion tubing string was then run and stabbed into the 4-1/2” liner. The liner was then logged for cement quality and perforated and stimulated at 7,944-7,953’ MD (4,157’-4,166’ TVD) and 7,957’- 7,963’ MD (4,170’-4,176’ TVD). Cement log results indicated TOC at 7,140’ MD/3601’ TVD/3546’ TVDSS which 3S-22 identified. 3S-24B is 492’ TVD above the Coyote. The well was then abandoned in 2023. The abandonment operations included setting a cement retainer at 7,680’ MD and pumping 25.6bbls of 15.8ppg Class G cement below the retainer and 12bbls above the retainer to isolate the perforations. AOGCC witnessed the tag of TOC at 6,923’ MD RKB with slickline. AOGCC also witnessed an MIT-T to 2000psi on 8/13/23. The tubing was then punched from 6,850- 6,854’ MD and 6,812-6,818’ MD. The tubing and IA were then cemented with 253 bbls of 15.8ppg Class G cement via the tubing punches. Cement was seen at surface at 233 bbls of cement away and an additional 20bbls was pumped. An OA down squeeze was performed on the 9-5/8” x 7” annulus with 148bbls of 15.8ppg Permafrost cement. The final abandonment operations were completed and witnessed by AOGCC on 10/1/2023. 3S-613: The 7-5/8” casing cement report on 5/2/2016 shows that the 2-stage job was pumped as designed, indicating competent cementing operations. The first stage consisted of 47bbls of 15.8ppg cement and plugs bumped and floats held. The second stage consisted of 189bbls of 15.8ppg cement and the plug bumped and floats held. Full returns were seen throughout both jobs. A SonicScope was run to determine TOC, but the log began at estimated TOC and no free ringing pipe was logged to help determine a clear TOC. Interpretation shows a potential TOC at 6,095’ MD/3,711’ TVD/3,646’ TVDSS from the log. 3S-615: The 7-5/8” intermediate casing was cemented with 200 barrels of 15.3 ppg lead cement with BMII and 33 barrels of 15.3 ppg tail cement. The plug bumped and floats held. No losses observed during the job. A cement bond log indicates competent cement with a cement top @ 5,620 MD / 3,340’ TVD / 3,279’ TVDSS. 3S-625: The 7-5/8” intermediate casing was cemented with 297 barrels of 15.3ppg cement with BMII. The plug did not bump and 50% of shoe track volume was pumped, floats did hold. Losses totaled 21 barrels during the job. A cement bond log indicates competent cement with a cement top @ 7,850’ MD (3,970’ TVD / 3,908’ TVDSS). 3S-701A: The 7-5/8" Casing cement report on 1/20/2023 shows that the job was pumped as designed with 69bbls of 15.3ppg cement. Plugs bumped and pressured up and floats held. No losses were observed during the job. A cement bond log indicates competent cement with a cement top @ 6800’ MD (3723’ TVD/3,659’ TVDSS), which is 423’ TVD above the Coyote. 3S-719PB1: The 3S-719PB1 was a lateral originally drilled but the production liner was unable to get to bottom. The liner hanger/packer and some of the liner was cut and fished out of hole. A kick off plug was placed using 46.1bbls of 16.5ppg cement on 7/25/25. Losses were observed during the displacement with indications of stuck pipe and pack offs. 26bbls of fluid was lost but then 13bbls breathed back. A total of 13bbls of fluid was lost during the plug setting and displacement. The cement stringer was then used to tag TOC after waiting on it to reach compressive strength. TOC tagged at 9,428’ MD with 12klbs. 3S-721: The 7-5/8” intermediate casing was cemented with 72 barrels of 15.3ppg cement. The plugs bumped and floats held. Full returns were observed during the job. A SonicScope was run and logged competent cement with a cement top @ 7,918’ MD / 3,727’ TVD / 3,662’ TVDSS (2445’ MD / 382’ TVD above the Coyote). 3T-730: The 7-5/8” x 4-1/2” casing cement report on 4/30/2025 shows that the job was pumped with 60 barrels of 13.5ppg clean cement, 530 bbls of 13.5ppg cement with Bridge Maker II, and 60 bbls of 13.5ppg clean tail cement. The cement was displaced with 9.7ppg CI brine. The plug bumped and pressure was held at 1150 psi for 5 minutes. Pressure was then bled off and floats checked with floats holding. No losses were observed during the job. A cement bond log indicated the cement top at 4,520’ MD / 3,949’ TVD (507’ MD / 153’ TVD above the Coyote). 3T-731: The 7-5/8” x 4-1/2” production casing was cemented with 50 barrels of 14.8ppg clean cement, 540 bbls of 14.8ppg cement with Bridge Maker II, and 50 bbls of 14.8ppg clean cement. The plug bumped and floats held. Losses were observed during the job. A cement bond log indicated the cement top at 12,750’ MD. A remedial cement job was pumped with 50 bbls of 14.8ppg clean cement, 217 bbls of 14.8ppg cement w/ Bridge Maker II, and 253 bbls of 14.8ppg clean cement through the perforation at 12,725’ MD. The cement was over 3S-620 identified. displaced and 520bbls of fluid was lost during the job. After cement reached 500 psi compressive strength, the cement top was logged at 4,010’ MD / 3,717’ TVD (834’ MD / 389’ TVD above the Coyote). SECTION 11 – LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that one fault transect the Coyote reservoir within one half mile radius of the 3S-719 wellbore trajectory. This fault is north of the heel of the 3S-719 wellbore. This fault was encountered at 11,700’ MD in the 3T-731 well and is interpreted to have a throw of 10 – 20’ where it intersects the 3T-731 wellbore. This fault has an interpreted ~W – E strike and is downthrown to the south. This fault is interpreted to lose throw into the confining interval above the Coyote reservoir. it should not affect overburden integrity and therefore its presence should not interfere with containment. If there is any indication that a propagated fracture has intersected the mapped fault (or any other faults unmapped to date) during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 3S-719 was completed in 2025 as a horizontal producer in the Coyote formation. The well was completed with a 4.5” tubing upper completion and a 4-1/2” production liner with dart actuated sliding sleeves in the lateral. Injection will be established into the well and the first stage treated. A dart will be dropped for stage 2 to initiate treatment. Once each stage is complete, a dart will be dropped for each subsequent stage. These darts will provide isolation from the previous stage and allow fracturing from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre- existing conditions. 2. Ensure the frac tree was tested to 10,000 psi on the rig. 3. Ensure all pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to ~2,000’ TVD. 4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 5. MIRU 25 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100ºF seawater. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 10,000 psi using a pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Bring up pumps and increase annulus pressure to 3,500 psi as the tubing pressures up. 10. Pump the frac job per the attached Halliburton pump schedule at 20-22 bpm with a maximum expected treating pressure of 7,075 psi. 11. RDMO Halliburton Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. The well is ready for post-frac well prep/production tree installation and flowback (after Slickline and Coiled Tubing Cleanout). Stage Job Size (lb) Top MD (ft) Top TVD (ft) Propped Half- Length (ft) Fracture Height (ft) Avg Fracture Width (in) 1 403,000 21,015 4,022 470 180 0.379 2 403,000 20,472 4,018 460 180 0.386 3 403,000 19,973 4,016 460 180 0.388 4 403,000 19,478 4,014 470 180 0.389 5 403,000 18,979 4,010 480 180 0.390 6 403,000 18,482 4,007 480 180 0.386 7 403,000 17,983 4,003 480 180 0.382 8 403,000 17,486 4,000 490 180 0.381 9 403,000 16,988 3,996 500 180 0.384 10 403,000 16,449 3,993 500 180 0.383 11 403,000 15,952 3,993 500 180 0.383 12 403,000 15,454 3,996 490 180 0.383 13 403,000 14,956 3,999 500 180 0.381 14 403,000 14,459 4,003 490 180 0.380 15 403,000 13,961 4,006 470 180 0.382 16 403,000 13,463 4,009 470 180 0.381 17 403,000 12,964 4,013 450 180 0.384 18 403,000 12,466 4,017 450 180 0.386 19 403,000 11,969 4,020 440 180 0.382 20 403,000 11,429 4,022 440 180 0.380 21 403,000 10,931 4,013 450 180 0.381 Disclaimer Notice: KRU 3S-719 This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39426745LEASE3S-705SALES ORDERBHST (°F)LONG-150.1954682FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In2:53:22 1-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:53:22 1-3 Shut-In Shut-In2:48:36 1-4 27# Linear Arsenal Sleeve Shift 5 1,260 30 30 0:06:00 2:48:36 1.00 2.00 1.00 27.00 2.000.151-5 27# Linear DFIT 10 1,680 40 40 0:04:00 2:42:36 1.00 2.00 1.00 27.00 2.000.151-6 27# Linear Step Rate Test 15 8,400 200 200 0:13:20 2:38:36 1.00 2.00 1.00 27.00 2.000.151-7 Shut-In Shut-In2:25:16 1-8 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 2:25:16 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-9 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:11:56 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-10 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:43:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:36:06 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:29:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:17:24 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:04:52 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:44:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:25:42 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-17 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:12:16 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-18 27# Linear Spacer and Dart Drop 20 2,940 70 70 0:03:30 0:03:30 1.00 2.00 1.00 27.00 2.00 0.152-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 3:07:32 1.00 2.00 1.00 27.00 2.000.152-2 27# Delta Frac Minifrac - Establish Fluid 20 8,400 200 200 0:10:00 3:05:02 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-3 27# Delta Frac Minifrac - Treatment 20 16,180 385 385 0:19:16 2:55:02 0.45 1.0000 0.50 2.00 1.00 27.00 2.000.152-4 27# Linear Flush 20 13,085 312 312 0:15:35 2:35:46 1.00 2.00 1.00 27.00 2.000.152-5 Shut-In Shut-In2:20:11 2-6 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-7 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-8 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-16 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.00 0.153-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:42:08 1.00 2.00 1.00 27.00 2.000.153-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:39:38 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:29:38 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 2:01:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:53:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:47:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:35:06 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:22:34 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 1:02:15 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:43:24 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:29:58 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-12 27# Linear Flush 20 12,767 304 304 0:15:12 0:21:12 1.00 2.00 1.00 27.00 2.000.153-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 3-14 Shut-In Shut-InInterval 1Coyote@ 21015.03 - 21019.03 ft - °FInterval 2Coyote@ 20471.68 - 20475.68 ft - °FInterval 3Coyote@ 19973.37 - 19977.37 ft - °FLiquid AdditivesDry Additives50-103-20915Conoco Phillips - 3S-705Planned Design1 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39426745LEASE3S-705SALES ORDERBHST (°F)LONG-150.1954682FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-209154-1 Shut-In Shut-In3:07:33 4-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 3:07:33 4-3 Shut-In Shut-In3:02:47 4-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 3:02:47 1.00 2.00 1.00 27.00 2.000.154-5 27# Linear Displace Dart to Seat 15 12,450 296 296 0:19:46 3:00:47 1.00 2.00 1.00 27.00 2.000.154-6 27# Linear DFIT 10 2,100 50 50 0:05:00 2:41:01 1.00 2.00 1.00 27.00 2.000.154-7 Shut-In Shut-In2:36:01 4-8 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 2:36:01 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-9 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.154-10 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-11 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-12 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-17 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-18 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-19 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-20 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.155-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.155-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.00 0.156-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:41:00 1.00 2.00 1.00 27.00 2.000.156-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:38:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:28:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:59:59 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:52:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:45:59 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:33:58 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:21:26 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 1:01:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:42:16 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:28:50 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-12 27# Linear Flush 20 11,813 281 281 0:14:04 0:20:04 1.00 2.00 1.00 27.00 2.000.156-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 6-14 Shut-In Shut-InInterval 4Coyote@ 19477.91 - 19481.91 ft - °FInterval 5Coyote@ 18979.38 - 18983.38 ft - °FInterval 6Coyote@ 18481.54 - 18485.54 ft - °FConoco Phillips - 3S-705Planned Design2 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39426745LEASE3S-705SALES ORDERBHST (°F)LONG-150.1954682FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-209157-1 Shut-In Shut-In3:06:02 7-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 3:06:02 7-3 Shut-In Shut-In3:01:16 7-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 3:01:16 1.00 2.00 1.00 27.00 2.000.157-5 27# Linear Displace Dart to Seat 15 11,495 274 274 0:18:15 2:59:16 1.00 2.00 1.00 27.00 2.000.157-6 27# Linear DFIT 10 2,100 50 50 0:05:00 2:41:01 1.00 2.00 1.00 27.00 2.000.157-7 Shut-In Shut-In2:36:01 7-8 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 2:36:01 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-9 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.157-10 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-11 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-12 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-17 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-18 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-19 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-20 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.158-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.158-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-4 27# Delta Frac Conditioning Pad 100M 0.5000 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.00 0.159-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:39:52 1.00 2.00 1.00 27.00 2.000.159-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:37:22 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:27:22 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:58:50 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:51:32 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:44:51 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:32:49 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:20:18 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:59:59 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:41:08 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:27:42 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-12 27# Linear Flush 20 10,859 259 259 0:12:56 0:18:56 1.00 2.00 1.00 27.00 2.000.159-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 9-14 Shut-In Shut-InInterval 9Coyote@ 16987.95 - 16991.95 ft - °FInterval 7Coyote@ 17983.11 - 17987.11 ft - °FInterval 8Coyote@ 17486.06 - 17490.06 ft - °FConoco Phillips - 3S-705Planned Design3 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39426745LEASE3S-705SALES ORDERBHST (°F)LONG-150.1954682FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-2091510-1 Shut-In Shut-In3:04:28 10-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 3:04:28 10-3 Shut-In Shut-In2:59:43 10-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:59:43 1.00 2.00 1.00 27.00 2.000.1510-5 27# Linear Displace Dart to Seat 15 10,515 250 250 0:16:41 2:57:43 1.00 2.00 1.00 27.00 2.000.1510-6 27# Linear DFIT 10 2,100 50 50 0:05:00 2:41:01 1.00 2.00 1.00 27.00 2.000.1510-7 Shut-In Shut-In2:36:01 10-8 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 2:36:01 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-9 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.1510-10 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-11 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-12 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-17 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-18 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-19 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-20 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1511-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.1511-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.00 0.1512-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:38:42 1.00 2.00 1.00 27.00 2.000.1512-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:36:12 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:26:12 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:57:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:50:22 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:43:41 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:31:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:19:08 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:58:49 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:39:58 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:26:32 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-12 27# Linear Flush 20 9,878 235 235 0:11:46 0:17:46 1.00 2.00 1.00 27.00 2.000.1512-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 12-14 Shut-In Shut-InInterval 10Coyote@ 16449.48 - 16453.48 ft - °FInterval 11Coyote@ 15952.33 - 15956.33 ft - °FInterval 12Coyote@ 15454.42 - 15458.42 ft - °FConoco Phillips - 3S-705Planned Design4 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39426745LEASE3S-705SALES ORDERBHST (°F)LONG-150.1954682FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-2091513-1 Shut-In Shut-In3:02:57 13-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 3:02:57 13-3 Shut-In Shut-In2:58:12 13-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:58:12 1.00 2.00 1.00 27.00 2.000.1513-5 27# Linear Displace Dart to Seat 15 9,560 228 228 0:15:10 2:56:12 1.00 2.00 1.00 27.00 2.000.1513-6 27# Linear DFIT 10 2,100 50 50 0:05:00 2:41:01 1.00 2.00 1.00 27.00 2.000.1513-7 Shut-In Shut-In2:36:01 13-8 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 2:36:01 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-9 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.1513-10 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-11 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-12 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-17 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-18 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-19 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-20 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1514-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.1514-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.00 0.1515-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:37:34 1.00 2.00 1.00 27.00 2.000.1515-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:35:04 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:25:04 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:56:32 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:49:14 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:42:32 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:30:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:18:00 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:57:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:38:50 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:25:24 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-12 27# Linear Flush 20 8,924 212 212 0:10:37 0:16:37 1.00 2.00 1.00 27.00 2.000.1515-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 15-14 Shut-In Shut-InInterval 13Coyote@ 14955.86 - 14959.86 ft - °FInterval 14Coyote@ 14458.55 - 14462.55 ft - °FInterval 15Coyote@ 13960.67 - 13964.67 ft - °FConoco Phillips - 3S-705Planned Design5 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39426745LEASE3S-705SALES ORDERBHST (°F)LONG-150.1954682FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-2091516-1 Shut-In Shut-In3:01:26 16-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 3:01:26 16-3 Shut-In Shut-In2:56:41 16-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:56:41 1.00 2.00 1.00 27.00 2.000.1516-5 27# Linear Displace Dart to Seat 15 8,605 205 205 0:13:40 2:54:41 1.00 2.00 1.00 27.00 2.000.1516-6 27# Linear DFIT 10 2,100 50 50 0:05:00 2:41:01 1.00 2.00 1.00 27.00 2.000.1516-7 Shut-In Shut-In2:36:01 16-8 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 2:36:01 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-9 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.1516-10 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-11 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-12 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-17 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-18 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-19 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-20 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1517-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.1517-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.00 0.1518-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:36:25 1.00 2.00 1.00 27.00 2.000.1518-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:33:55 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:23:55 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:55:24 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:48:06 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:41:24 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:29:23 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:16:51 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:56:32 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:37:41 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:24:15 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-12 27# Linear Flush 20 7,968 190 190 0:09:29 0:15:29 1.00 2.00 1.00 27.00 2.000.1518-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 18-14 Shut-In Shut-InInterval 16Coyote@ 13462.77 - 13466.77 ft - °FInterval 17Coyote@ 12964.35 - 12968.35 ft - °FInterval 18Coyote@ 12465.88 - 12469.88 ft - °FConoco Phillips - 3S-705Planned Design6 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39426745LEASE3S-705SALES ORDERBHST (°F)LONG-150.1954682FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-2091519-1 Shut-In Shut-In2:59:56 19-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:59:56 19-3 Shut-In Shut-In2:55:10 19-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:55:10 1.00 2.00 1.00 27.00 2.000.1519-5 27# Linear Displace Dart to Seat 15 7,651 182 182 0:12:09 2:53:10 1.00 2.00 1.00 27.00 2.000.1519-6 27# Linear DFIT 10 2,100 50 50 0:05:00 2:41:01 1.00 2.00 1.00 27.00 2.000.1519-7 Shut-In Shut-In2:36:01 19-8 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 2:36:01 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-9 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.1519-10 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-11 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-12 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-17 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-18 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-19 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-20 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1520-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:22:41 1.00 2.00 1.00 27.00 2.000.1520-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:20:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:10:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:41:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:34:21 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:27:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:15:39 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:03:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:42:48 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:10:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.00 0.1521-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:35:15 1.00 2.00 1.00 27.00 2.000.1521-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:32:45 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-3 27# Delta Frac Pad 20 23,960 570 570 0:28:31 2:22:45 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:54:14 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 5,150 123 134 10,300 0:06:41 1:46:56 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 8,540 203 240 34,160 0:12:01 1:40:14 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 8,260 197 249 49,560 0:12:31 1:28:13 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 12,940 308 404 90,580 0:20:19 1:15:41 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 11,600 276 375 92,800 0:18:51 0:55:22 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 8,000 190 267 72,000 0:13:26 0:36:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 5,060 120 174 50,600 0:08:46 0:23:05 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1521-12 27# Linear Flush 20 6,987 166 166 0:08:19 0:14:19 1.00 2.00 1.00 27.00 2.000.1521-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 21-14 Shut-In Shut-In2,385,018 56,786 65,775 8,463,000Design Total (gal)Design Total (lbs)BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-II BE-62,131,0908,400,000(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs)238,10863,000Initial Design Material Volume 959.0 2,369.2 1,065.5 4,738.4 2,369.2 63,968.3 4,738.4 355.4-15,820- 0.2839 Whole Units to be ordered--BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-II BE-6-(gpm) (gpm) (gpm) (gpm) (gpm) ppm ppm ppm-Max Additive Rate 0.4 0.8 0.4 1.7 0.8 22.7 1.7 0.1-Min Additive Rate9:10:19 Interval 19Coyote@ 11969.22 - 11973.22 ft - °FInterval 20Coyote@ 11429.33 - 11433.33 ft - °FInterval 21Coyote@ 10931.35 - 10935.35 ft - °FProppant TypeWanli 16/20 Ceramic100M---Fluid Type27# Delta Frac27# LinearSeawaterFreeze Protect----Conoco Phillips - 3S-705Planned Design7 Hydraulic Fracturing Fluid Product Component Information Disclosure 2025-07-24 Alaska HARRISON BAY 50-103-20919-00-00 CONOCOPHILLIPS 3S 719 -150.19759043 70.39409809 NAD83 none Oil 4,206 2265768.1 Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Ingredient Mass lbs Comments Company First Name Last Name Email Phone Produced Water (Density 8.5)Operator Base Fluid Density = 8.50 SEAWATER (SG 8.52)Operator Base Fluid Density = 8.52 BA-20 BUFFERING AGENT Halliburton Buffer BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CAT-3 ACTIVATOR Halliburton Activator CL-28M CROSSLINKER Halliburton Crosslinker Legend LD-6450 MultiChem Completion/Stimulati on LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker WG-36 GELLING AGENT Halliburton Gelling Agent Ceramic Proppant - Wanli Wanli Proppant SAND, COMMON BROWN 100 MESH Halliburton Proppant Flow Insurance Brass Patina Energy Tracer Flow Insurance Copper Patina Energy Tracer Fresh Water Operator Base Fluid GPT 3000-3014 ResMetrics Tracer OPT 2002-2054 ResMetrics Tracer WPT 1001-1052 ResMetrics Tracer Ingredients Water 7732-18-5 95.00%66.56954%19304336 Corundum 1302-74-5 60.00%17.38006%5040000 Mullite 1302-93-8 40.00%11.58671%3360000 Sodium chloride 7647-14-5 5.00%3.50366%1016018 Water 7732-18-5 100.00%0.38182%110725 Guar gum 9000-30-0 100.00%0.22059%63968 Crystalline silica, quartz 14808-60-7 100.00%0.21889%63475 Calcium chloride, dihyrate 10035-04-8 60.00%0.05245%15209 EDTA/Copper chelate Proprietary 30.00%0.04088%11855 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871- 6226 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Ethanol 64-17-5 60.00%0.03725%10803 Monoethanolamine borate 26038-87-9 100.00%0.03360%9744 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.01863%5402 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.01863%5402 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Ammonium persulfate 7727-54-0 100.00%0.01634%4739 Sodium hydroxide 1310-73-2 30.00%0.01167%3384 Ethylene glycol 107-21-1 30.00%0.01008%2924 Ammonium chloride 12125-02-9 5.00%0.00681%1976 Oxyalkylated phenolic resin Proprietary 10.00%0.00621%1801 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Oxylated phenolic resin Proprietary 30.00%0.00490%1422 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Copolymer of acrylamide and sodium acrylate 25085-02-3 5.00%0.00437%1268 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00310%901 Naphthalene 91-20-3 5.00%0.00310%901 Ammonia 7664-41-7 1.00%0.00136%396 Flow Insurance Copper Proprietary 100.00%0.00127%368 Patina Energy Product Stewardship test@patinae nergy.com 7205324886 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00122%355 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00062%181 Glycol Ether Proprietary 85.00%0.00049%143 ResMetrics Product Stewardship info@resmetri cs.com 8325921900 Sodium chloride 7647-14-5 1.00%0.00039%113 Confidential Proprietary 100.00%0.00023%67 ResMetrics Product Stewardship info@resmetri cs.com 8325921900 C.I. pigment Orange 5 3468-63-1 1.00%0.00016%48 Flow Insurance Brass Proprietary 100.00%0.00015%45 Patina Energy Julie Harrish julie@patinae nergy.com 8327140836 Ethylene Glycol 107-21-1 20.00%0.00012%35 Polymer Proprietary 0.10%0.00009%26 MultiChem Ana Djuric Ana.Djuric@ Halliburton.co m 281-871- 5747 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00003%10 Ammonium acetate 631-61-8 100.00%0.00003%10 Water 7732-18-5 100.00%0.00003%9 Borate salts Proprietary 60.00%0.00002%7 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Acetic acid 64-19-7 30.00%0.00001%3 Inorganic mineral 1317-65-3 5.00%0.00000%1 Potassium chloride 7447-40-7 5.00%0.00000%1 Inorganic mineral Proprietary 1.00%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Polymer Proprietary 1.00%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Gluteraldehyde 111-30-8 1.00%0.00000%1 Calcium magnesium carbonate 16389-88-1 1.00%0.00000%1 Sodium bisulfate 7681-38-1 0.10%0.00000%1 Methanesulfonic acid, 1-hydroxy-, sodium salt 870-72-4 0.10%0.00000%1 Magnesium nitrate 10377-60-3 0.01%0.00000%1 Magensium chloride 7786-30-3 0.01%0.00000%1 5-Chloro-2-methyl-3(2H)- Isothaiazolone 26172-55-4 0.01%0.00000%1 2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00000%1 * Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.5 All component information listed was obtained from the supplier’s Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Production Type: True Vertical Depth (TVD): Total Water Volume (gal)*: MSDS and Non-MSDS Ingredients are listed below the green line Well Name and Number: Longitude: Latitude: Long/Lat Projection: Indian/Federal: Fracture Date State: County: API Number: Operator Name: SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) After the fracture stimulation, ConocoPhillips (“CPAI”) plans to flowback the well for cleanup purposes for an estimated 7 to 14 days. The flowback liquids will be routed through a portable test separator then onto either CPF3 or Drill Site 3S’s facilities. Once the well’s flowback liquids meet CPF3 criteria all liquids will be routed to CPF3. CPAI plans to limit the flowback time to what is necessary to achieve conforming production liquids. 21 interval, 66000 bbl, 8.4 M lb frac. CDW 08/14/2025 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Woodard, Madeline E To:Davies, Stephen F (OGC) Cc:Loepp, Victoria T (OGC); Hobbs, Greg S Subject:RE: [EXTERNAL]KRU 3S-719 (PTD 225-058, Sundry 325-476) - Question Date:Wednesday, August 20, 2025 6:54:48 AM Steve, The top of fish in the 3S-719PB1is at 10,140’ MD. The base of the cement plug is at 10,126’ MD. The cement report indicates there were some losses during the job, but TOC was tagged inside the intermediate casing shoe after waiting on it to reach compressive strength. TOC tagged at 9,428’ MD with 12klbs prior to kicking off the new wellbore. The cement report can also be found in the Share File site we set up under GKA -> 3S -> 3S-719 -> Cement -> Production -> 3S-719PB1 KO plug. ConocoPhillips does not think the lost wellbore will interfere with hydraulic fracturing fluids in 3S-719. Both wellbores are oriented along maximum horizontal stress to promote longitudinal fracture growth. ConocoPhillips thinks the risk of a misaligned fracture and intersection of the 3S-719PB1 is low. If this intersection were to happen, a significant decrease in treating pressure would occur and the treatment would go to flush. Thanks! Madeline From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, August 19, 2025 6:16 PM To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]KRU 3S-719 (PTD 225-058, Sundry 325-476) - Question CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello Madeline, I'm reviewing ConocoPhillips Alaska, Inc.'s Sundry Application to fracture KRU 3S-719 and I have a few questions. For the nearby plugback 3S-719PB1, could you please provide the depth for the top of the fish left in that hole and the depths of the top and base of the cement plug placed in that wellbore? Since 3S-719PB1 lies only about 200’ from the 3S-719 well, does CPAI have any concerns that the lost wellbore will interfere with hydraulic fracturing fluids in 3S-719? Please provide details. Thank You and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov SAMPLE TRANSMITTAL TO: AOGCC 333 WEST 7TH SUITE 100 ANCH. AK. 99501 279-1433 OPERATOR: CPAI SAMPLE TYPE: Dry Cuttings SAMPLES SENT: 3S-719 V V)*� 9700 - 21123 5 Boxes SENT BY: M. McCRACKEN has-osB lg39 DATE: 07/31/2025 AIR BILL: N/A CPAI: CPA12025073101 CHARGE CODE: NIA NAME: 3S-719 NUMBER OF BOXES: 5 Boxes UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY OF THIS FORM TO: REC 1�b� RECEi -1 IUL 3 1 2025 AOGCC CONOCOPHILLIPS, ALASKA 700 G ST ATO-380 ANCHORAGE, AK. 99510 ATTN:MIKE McCRACKEN Mike.mccracken@conocophillips.com w'311zs WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDCOLOR PRINTS E-Delivery3S-721 50-103-20911-00-00 225-025 KUPARUK RIVER MWD/LWD/DD TOP OF CEMENT FINAL FIELD 7-May-25 13T-613 50-103-20914-00-00 225-036 KUPARUK RIVER MWD/LWD/DD TOP OF CEMENT FINAL FIELD 23-May-25 13T-605 50-103-20917-00-00 225-051 KUPARUK RIVER MWD/LWD/DD TOP OF CEMENT FINAL FIELD 21-Jun-25 13S-719 50-103-20919-00-00 225-058 KUPARUK RIVER MWD/LWD/DD TOP OF CEMENT FINAL FIELD 15-Jul-25 1Transmittal Receipt________________________________ X____________________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.aurana@slb.comSLB Auditor - A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point.# Schlumberger-PrivateT40687T40688T40689T406903S-71950-103-20919-00-00225-058KUPARUK RIVERMWD/LWD/DDTOP OF CEMENTFINAL FIELD15-Jul-251Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.28 08:43:18 -08'00' From:Loepp, Victoria T (OGC) To:Abby Warren Cc:Dewhurst, Andrew D (OGC); Kate Dodson; AOGCC Records (CED sponsored) Subject:Re: [EXTERNAL]Re: 3S-719 (PTD:225-058) - Cut and pull 4-1/2" liner, perform sidetrack, and re-drill lateral. VERBAL APPROVAL Date:Monday, July 21, 2025 3:36:06 PM Attachments:3S-719 Current Status WBD 7.21.25.pdf 3S-719 Updated Sidetrack WBD 7.21.25.pdf Abby, Approval is granted for the plan below to make 2 cuts in the liner and attempt to pull. Victoria Sent from my iPhone On Jul 21, 2025, at 2:58 PM, Warren, Abby <Abby.Warren@conocophillips.com> wrote: Good afternoon Victoria, Over the weekend on 3S-719 we attempted multiple cuts of the liner 500’ outside of the intermediate shoe but have been unsuccessful in pulling the liner so far. Our plan forward is to make two cuts in the liner (~500’ outside the intermediate shoe and just below the hanger) and then pull two different sections of liner. If successful, then we will plan to proceed forward with the remediation plan discussed Friday. If not, we will be seeking approval for a new remediation plan. Attached are wellbore diagrams showing the current status of the well and the proposed sidetrack plan. We are planning to submit the sundry once we have made forward progress on retrieving the liner to avoid submitting multiple sundries if we are unable to move forward. Please reach out if you have any questions. Thanks, Abby Warren Staff Drilling Engineer C: 907-240-9293 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, July 18, 2025 8:16 PM To: Johnson, Cameron <Cameron.Johnson2@conocophillips.com> Cc: Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Dodson, Kate <Kate.Dodson@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com>; Warren, Abby <Abby.Warren@conocophillips.com>; Kelley, Trevor <Trevor.Kelley@conocophillips.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]Re: 3S-719 (PTD:225-058) - Cut and pull 4-1/2" liner, perform sidetrack, and re-drill lateral. VERBAL APPROVAL CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Approval is granted to cut and pull the production liner as outlined below. Please submit a change of approved sundry under the original PTD(225-058) for the following scope: 1. Cut and pull production liner 2. Sidetrack under the existing PTD 3. Redrill lateral using the existing PTD number. Include in the sundry: 1. Request for a variance for alternate plug placement utilizing the new production liner cement for the plug back. 2. New directional survey and any updated information such as changes to the cementing program and updated depths. 3. Submit this sundry as soon as possible. A new PTD will not be required. Victoria Sent from my iPhone On Jul 18, 2025, at 4:49 PM, Johnson, Cameron <Cameron.Johnson2@conocophillips.com> wrote: CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Victoria, The 6-1/2” production section of the 3S-719 well was drilled to a total depth of 21,123’ MD. The BHA was pulled out of the hole and laid down. The 4-1/2” liner was run to 20,070’ MD, where no further progress could be made. While working pipe, the 4-1/2” liner, overpull was observed, and the string is now stuck. Attempts have been made to free the string; all without success. The rig has been unable to establish circulation due to a pack off around the string. The plan forward will be to cut and pull the 4- 1/2” liner from ~500’ below the 7-5/8” intermediate casing shoe, perform a sidetrack, and re-drill the lateral. The proposed operational steps for the well are as follows: 1. Mechanically release the running tool from the liner hanger. 2. Pull out of the hole with the 4” drill pipe and lay down the running tool. 3. Cut the 4-1/2” liner at ~10,184’ MD (500’ outside the 7-5/8” casing shoe). 4. Retrieve the liner hanger and cut section of the 4-1/2” liner. 5. Sidetrack off the existing wellbore ~200-300’ outside of the 7-5/8” intermediate casing shoe. 6. Drill the sidetrack production lateral, parallel to the existing production lateral, to a bottom hole location 100-200’ to the west of the existing wellbore (within 500’ of the original bottomhole location). 7. Run and cement the 4-1/2” lower completion with frac sleeves. Please find a schematic attached. Please note that depths may change slightly as the new wellplan is developed. The existing wellbore will not be plugged back with cement. The cement behind the 7-5/8” casing has been logged (previously communicated) with a top of cement at 7740’ MD / 3766’ MD. This provides 2087’ MD / 341’ TVD of cement above the Coyote formation, providing adequate isolation of the reservoir. The sidetrack will be completed with a cemented 4-1/2” liner with frac sleeves. The orientation of the wellbores are such that they are aligned as best as possible with maximum horizontal stress. In the new wellbore, the heel most frac sleeve will target a depth below where it aligns with the azimuth of the maximum horizontal stress to avoid any uncertainty in growth of the fracture. ConocoPhillips views the risk of contact between fractures from the new wellbore and the abandoned wellbore is minimal. Questions 1. Does the AOGCC give verbal permission to move forward with the plan outlined above? A 10-403 will be submitted for the cut and pull. 2. Will the side-track require a new PTD or will it be covered by a sundry? 1. This application will be submitted once a new directional plan has been developed. Regards, Cam Johnson | Drilling Engineer | ConocoPhillips AlaskaM: 907.223.6277 | M: 907.720.3162 | ANO-938, 700 G Street,Anchorage, AK /ŶƚĞƌŵĞĚŝĂƚĞ/ĂƐŝŶŐϳͲϱͬϴΗϮϵ͘ϳη>ϴϬ,ϱϲϯнϴϬϬΖϯϯ͘ϳηWϭϭϬ^,ϱϲϯ,ĞĂǀLJ,ĞĞůϵϲϴϰΖDͬϰϬϵϮΖdsĂƐĞWĞƌŵϭϳϯϮΖDͬϭϳϭϰΖds/ŶƚĞƌŵĞĚŝĂƚĞ/dK;ůŽŐŐĞĚͿϳϳϰϬΖDͬϯϳϲϲΖds^ƵƌĨĂĐĞĂƐŝŶŐϭϬͲϯͬϰΗϰϱ͘ϱη>ϴϬ,ϱϲϯϮϳϲϳΖDͬϮϱϱϬΖdsĞŵĞŶƚĞĚƚŽ^ƵƌĨĂĐĞ>ĞĂĚ͗ϭϭ͘ϬƉƉŐĞĞƉZ d ͮdĂŝů͗ϭϱ͘ϴƉƉŐůĂƐƐ'ϮϬΗϵϰη,ϰϬ/ŶƐƵůĂƚĞĚŽŶĚƵĐƚŽƌϭϮϬΖDͬdsWƌŽĚƵĐƚŝŽŶdK>ϴϰϭϵΖDͬϯϴϴϯΖdsϯ^ͲϳϭϵƵƌƌĞŶƚ^ƚĂƚƵƐ;ϳ͘Ϯϭ͘ϮϱͿWƌŽĚƵĐĞƌdŽƉŽLJŽƚĞϵϴϮϳΖDͬϰϭϬϳΖdsϯ^ͲϳϭϵK,dϮϭϭϮϯΖDͬϰϮϬϮΖdsWƌŽĚƵĐƚŝŽŶ>ŝŶĞƌĞƉƚŚϮϬϬϮϰΖDdŽƉ<ϯϵϱϴϳΖDͬϰϬϳϱ͘ϲΖds /ŶƚĞƌŵĞĚŝĂƚĞ/ĂƐŝŶŐϳͲϱͬϴΗϮϵ͘ϳη>ϴϬ,ϱϲϯнϴϬϬΖϯϯ͘ϳηWϭϭϬ^,ϱϲϯ,ĞĂǀLJ,ĞĞůϵϲϴϰΖDͬϰϬϵϮΖdsĂƐĞWĞƌŵϭϳϯϮΖDͬϭϳϭϰΖds/ŶƚĞƌŵĞĚŝĂƚĞ/dK;ůŽŐŐĞĚͿϳϳϰϬΖDͬϯϳϲϲΖds^ƵƌĨĂĐĞĂƐŝŶŐϭϬͲϯͬϰΗϰϱ͘ϱη>ϴϬ,ϱϲϯϮϳϲϳΖDͬϮϱϱϬΖdsĞŵĞŶƚĞĚƚŽ^ƵƌĨĂĐĞ>ĞĂĚ͗ϭϭ͘ϬƉƉŐĞĞƉZ d ͮdĂŝů͗ϭϱ͘ϴƉƉŐůĂƐƐ'ϮϬΗϵϰη,ϰϬ/ŶƐƵůĂƚĞĚŽŶĚƵĐƚŽƌϭϮϬΖDͬdsWƌŽĚƵĐƚŝŽŶdK>WƌŽĚƵĐƚŝŽŶ>ŝŶĞƌdŽƉW<ZϵϱϵϴΖDͬϰϬϴϳΖWƌŽĚƵĐƚŝŽŶ>ŝŶĞƌϰͲϭͬϮΗϭϮ͘ϲηWϭϭϬͲ^,ϱϲϯϮϭϭϮϯΖDͬϰϮϬϮΖdsϯ^Ͳϳϭϵ^ŝĚĞƚƌĂĐŬWƌŽƉŽƐĞĚWƌŽĚƵĐĞƌhƉƉĞƌŽŵƉůĞƚŝŽŶ͗ϭ͘ϮĞĂ͘'ĂƐ>ŝĨƚDĂŶĚƌĞůƐϮ͘^>E yͲϮ^ůŝĚŝŶŐ^ůĞĞǀĞϯ͘, ^KƉƐŝƐ^ŝŶŐůĞŽǁŶŚŽůĞ'ĂƵŐĞϰ͘, ^ϳͲϱͬϴΗdžϰͲϭͬϮΗdEdWĂĐŬĞƌϱ͘ƌƐĞŶĂůϱ͕ϱϬϬƉƐŝ'ůĂƐƐŝƐŬ^Ƶďϲ͘^>ϯ͘ϳϱΗEŝƉƉůĞWƌŽĨŝůĞϳ͘, ^^ĞůĨͲůŝŐŶŝŶŐDƵůĞƐŚŽĞǁŝƚŚĂŬĞƌ^ŚĞĂƌ>ŽĐĂƚŽƌ>ŽǁĞƌŽŵƉůĞƚŝŽŶ͗ϭ͘ĂŬĞƌ&ůĞdžůŽĐŬ>ŝŶĞƌ,ĂŶŐĞƌͬyWWĂĐŬĞƌϮ͘h&ƌĂĐ^ůĞĞǀĞƐϰ͘ŝƚĂĚĞůDK^^ŚŽĞdŽƉŽLJŽƚĞϵϴϮϳΖDͬϰϭϬϳΖdsϯ^Ͳϳϭϵ;ĞdžŝƐƚŝŶŐͿϮϭϭϮϯΖDͬϰϮϬϮΖdsϯ^Ͳϳϭϵ^dϭ 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk River Field Coyote Oil Pool Coyote Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 21123 4204 21123 4204 1504 NA 10140 Casing Collapse Structural Conductor Surface 2470 Intermediate 4790 Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Abby Warren Contact Email: Contact Phone: 907-240-9293 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7/19/2025 2002411605 4025 6.5 10-3/4" 7-5/8"9684' 2767' 11439 2767' 420521123 9684 6890 52102550' 4205 4.5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL380107 / ADL025544 / ADL025551 225-058 P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20919-00-00 ConocoPhillips Alaska Inc Proposed Pools: 3S-719 MD TVD Burst AOGCC USE ONLY Victoria Loepp 7/18/2025 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):Perforation Depth MD (ft): abby.warren@conocophillips.com Drilling Engineer Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-437 By Grace Christianson at 7:45 am, Jul 25, 2025 X X NO X VTL 7/25/2025 file w/PTD 10-407 Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig Annular preventer test to 2500 psig. All conditions of approval on original PTD approval apply. A.Dewhurst25JUL25GKC for JLC 7/25/25 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date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pplication for Sundry Approval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est(-)/East(+) (5500 usft/in)-10500-8750-7000-5250-3500-175001750South(-)/North(+) (3500 usft/in)3S-7233S-243S-24A3S-24B3S-213S-7213S-033S-701A3 S -22 3S-7193S-6133S-6063S-611PB13S-7183S-2 6 3S-7033S-6123S-6103S-6243S-740 (I15) wp033S-08CL1PB13S-7043S-17 A 3S-083S-08B3S-08A 3S-08CL13S-153S-173S-6203S-23A3S -2 33S-6173S-6153S-6253S-741 (P15) wp023T-7303T-7313S-7054-1/2" Production Liner3S-719A wp01-1000010002000300040005000True Vertical Depth (2000 usft/in)0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 Vertical Section at 208.65° (2500 usft/in)4-1/2" Production Liner3S-719A wp01Start DLS 1.50 TFO 85.22Start DLS 3.25 TFO -44.45Start DLS 3.25 TFO -85.31Start DLS 2.50 TFO -72.60Start DLS 1.00 TFO 84.14Start DLS 1.00 TFO 34.54Start DLS 1.00 TFO -177.98Start DLS 1.00 TFO 179.54TD at 21157.62Top Coyote (Top Nanushuk), K3SECTION DETAILSSecMD Inc AziTVD+N/-S+E/-W Dleg TFaceVSect1 9718.09 82.86 209.92 4096.26 649.79 -6799.96 0.00 0.00 2689.722 9800.00 82.88 206.63 4106.43 578.22 -6838.46 3.98 -89.77 2770.983 9890.66 83.00 208.00 4117.56 498.28 -6879.75 1.50 85.22 2860.924 9940.66 83.00 208.00 4123.66 454.47 -6903.05 0.00 0.00 2910.555 10031.86 85.12 205.92 4133.10 373.62 -6944.17 3.25 -44.45 3001.216 10147.03 85.12 205.92 4142.89 270.41 -6994.32 0.00 0.00 3115.837 11039.47 88.00 177.00 4197.60 -593.34 -7169.05 3.25 -85.31 3957.628 11292.52 89.90 170.96 4202.24 -844.83 -7142.54 2.50 -72.60 4165.619 11448.83 89.90 170.96 4202.51 -999.20 -7117.99 0.00 0.00 4289.3210 11546.90 90.00 171.94 4202.60 -1096.18 -7103.41 1.00 84.14 4367.4411 11595.23 90.40 172.21 4202.43 -1144.04 -7096.75 1.00 34.54 4406.2512 16013.22 90.40 172.21 4171.74 -5521.20 -6498.25 0.00 0.00 7960.6813 16053.05 90.00 172.20 4171.60 -5560.66 -6492.85 1.00 -177.98 7992.7214 16089.10 89.64 172.20 4171.71 -5596.38 -6487.96 1.00 179.54 8021.7215 21157.62 89.64 172.20 4203.60 -10617.94 -5800.35 0.00 0.00 12098.95Azimuths to True NorthMagnetic North: 13.63°Magnetic FieldStrength: 57158.4nTDip Angle: 80.59°Date: 7/19/2025Model: BGGM2025TMREFERENCE INFORMATIONCoordinate(N/E) Reference: Well 3S-719, True NorthVertical (TVD) Reference: Doyon 25 Actual KB (24.8+39.8) @ 64.60usft (Doyon 25)Section (VS) Reference: Slot - (0.00N, 0.00E)Measured Depth Reference: Doyon 25 Actual KB (24.8+39.8) @ 64.60usft (Doyon 25)Calculation Method: Minimum CurvatureConocoPhillips Alaska Inc_KuparukProject:Kuparuk River Unit_2Well: 3S-719Site: Kuparuk 3S PadWellbore: 3S-719ADesign: 3S-719A wp01MD Annotation9718.099800.009890.669940.6610031.8610147.0311039.4711292.5211448.8311546.9011595.2316013.2216053.0516089.1021157.62SURVEY PROGRAMDepth From Depth To Survey/PlanTool120.75 1386.45 Survey #1 (3S-719)r.5 SDI_URSA11453.29 2705.25 Survey #2 (3S-719)MWD+IFR2+SAG+MS2791.50 9669.00 Survey #3 (3S-719)MWD+IFR2+SAG+MS9718.09 9718.09 Survey #4 (3S-719) MWD+IFR2+SAG+MS9718.09 21157.62 3S-719A wp01 (3S-719A) MWD+IFR2+SAG+MSCASING DETAILSTVD MD NameSize4203.54 21148.32 4-1/2" Production Liner4.500LOCATION INFORMATION:Ground Level: 24.80Northing: 5993626.99Easting: 1616133.23Lattitude: 70° 23' 38.746 NLongitude: 150° 11' 51.299 WPROJECT DETAILS: Kuparuk River Unit_2Geodetic System: US State Plane 1983Datum: North American Datum 1983Ellipsoid: GRS 1980Zone: Alaska Zone 4System Datum: Mean Sea Level3S-719A wp01 SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 9718.09 82.86 209.92 4096.26 649.79 -6799.96 0.00 0.00 2689.722 9800.00 82.88 206.63 4106.43 578.22 -6838.46 3.98 -89.77 2770.983 9890.66 83.00 208.00 4117.56 498.28 -6879.75 1.50 85.22 2860.924 9940.66 83.00 208.00 4123.66 454.47 -6903.05 0.00 0.00 2910.555 10031.86 85.12 205.92 4133.10 373.62 -6944.17 3.25 -44.45 3001.216 10147.03 85.12 205.92 4142.89 270.41 -6994.32 0.00 0.00 3115.837 11039.47 88.00 177.00 4197.60 -593.34 -7169.05 3.25 -85.31 3957.628 11292.52 89.90 170.96 4202.24 -844.83 -7142.54 2.50 -72.60 4165.619 11448.83 89.90 170.96 4202.51 -999.20 -7117.99 0.00 0.00 4289.3210 11546.90 90.00 171.94 4202.60 -1096.18 -7103.41 1.00 84.14 4367.4411 11595.23 90.40 172.21 4202.43 -1144.04 -7096.75 1.00 34.54 4406.2512 16013.22 90.40 172.21 4171.74 -5521.20 -6498.25 0.00 0.00 7960.6813 16053.05 90.00 172.20 4171.60 -5560.66 -6492.85 1.00 -177.98 7992.7214 16089.10 89.64 172.20 4171.71 -5596.38 -6487.96 1.00 179.54 8021.7215 21157.62 89.64 172.20 4203.60 -10617.94 -5800.35 0.00 0.00 12098.95151530304545606075759090901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [usft]98009875994910024100981017310249103261040410481105603S-71998009875994910024100981017310249103261040410481105603S-719Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: 3S-719Wellbore: 3S-719APlan: 3S-719A wp01ANTI-COLLISION SETTINGSInterpolation Method: MD, interval: 25.00Depth Reference: 9800.00 To 21157.62Results Limited By: Ellipse Separation: 1000.00Reference: 3S-719A wp01 (3S-719/3S-719A)REFERENCE INFORMATIONCalculation Method: Minimum CurvatureError System: ISCWSAScan Method: Trav. Cylinder NorthError Surface: Combined Pedal CurveWarning Method: Error Ratio090009000 1000010000 1100011000 1200012000 1500015000 2000020000 25000From Colour To MDDepth Range: 9800.00 To 21157.623S-719A wp013S-719A wp01SURVEY PROGRAMDepth From Depth ToSurvey/PlanTool120.75 1386.45 Survey #1 (3S-719)r.5 SDI_URSA11453.29 2705.25 Survey #2 (3S-719)MWD+IFR2+SAG+MS2791.50 9669.00 Survey #3 (3S-719)MWD+IFR2+SAG+MS9718.09 9718.09 Survey #4 (3S-719)MWD+IFR2+SAG+MS9718.09 21157.62 3S-719A wp01 (3S-719A)MWD+IFR2+SAG+MS ! ! "# $% " % " !&'!$ % " (")* + ! , -. !"#$%#$&'("#() * ! & /0- , + ,- - . / 1 !"#$%#$&'("#() * ! & 2- , -01-/ 3 4 , ! 2--3 3+ 0 & ! 2 5 5 . 4 )- !* 2 1 6 -1 3 2 7 1-11 $ 5 ,3- 3$ -01-/65 , 61- 7 " 280 1 -9 * - 1 -99 - * ! !! 8 1 ! +! + *! !! ' ! 4 !* 9 !* 6! &* 2 )#$: ! )#)))- 66 # " * 6((6"$#) * )#)) * ):;$#"$5 ):;")# 5 5 !! + *! +! 9 !* 4 !* :9;5 :4; !! 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VERBAL APPROVAL kickoff plug Date:Thursday, July 24, 2025 3:00:38 PM Abby, Approval is granted to proceed with the kick off plug. The sundry for the sidetrack is expected today. The old lateral is PB1 and the new lateral is 3S-719. Victoria Sent from my iPhone On Jul 24, 2025, at 2:53ௗPM, Warren, Abby <Abby.Warren@conocophillips.com> wrote: Good afternoon Victoria The rig successfully pulled the liner from the cut. The TOL is now at 10,140’ MD. Below are the operations steps and plan forward. The sundry will be submitted today 1. Pump a 56 bbls 16.5ppg kick off cement plug 2. Sidetrack off the existing wellbore ~200-300’ outside of the 7-5/8” intermediate casing shoe. 3. Drill the sidetrack production lateral, parallel to the existing production lateral, to a bottom hole location 100-200’ to the west of the existing wellbore (within 500’ of the original bottomhole location). 4. Run and cement the 4-1/2” lower completion with frac sleeves. One question, should the old lateral be PB1 and this new lateral be 3S-719? CPAI is requesting verbal approval to continue with operations and pumping the 16.5 ppg cement kick off plug. Thank you Abby Warren 907-240-9293 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, July 21, 2025 3:36 PM To: Warren, Abby <Abby.Warren@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Dodson, Kate <Kate.Dodson@conocophillips.com>; AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: Re: [EXTERNAL]Re: 3S-719 (PTD:225-058) - Cut and pull 4-1/2" liner, perform sidetrack, and re-drill lateral. VERBAL APPROVAL Abby, Approval is granted for the plan below to make 2 cuts in the liner and attempt to pull. Victoria Sent from my iPhone On Jul 21, 2025, at 2:58ௗPM, Warren, Abby <Abby.Warren@conocophillips.com> wrote: Good afternoon Victoria, Over the weekend on 3S-719 we attempted multiple cuts of the liner 500’ outside of the intermediate shoe but have been unsuccessful in pulling the liner so far. Our plan forward is to make two cuts in the liner (~500’ outside the intermediate shoe and just below the hanger) and then pull two different sections of liner. If successful, then we will plan to proceed forward with the remediation plan discussed Friday. If not, we will be seeking approval for a new remediation plan. Attached are wellbore diagrams showing the current status of the well and the proposed sidetrack plan. We are planning to submit the sundry once we have made forward progress on retrieving the liner to avoid submitting multiple sundries if we are unable to move forward. Please reach out if you have any questions. Thanks, Abby Warren Staff Drilling Engineer C: 907-240-9293 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, July 18, 2025 8:16 PM To: Johnson, Cameron <Cameron.Johnson2@conocophillips.com> Cc: Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Dodson, Kate <Kate.Dodson@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com>; Warren, Abby <Abby.Warren@conocophillips.com>; Kelley, Trevor <Trevor.Kelley@conocophillips.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]Re: 3S-719 (PTD:225-058) - Cut and pull 4-1/2" liner, perform sidetrack, and re-drill lateral. VERBAL APPROVAL CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Approval is granted to cut and pull the production liner as outlined below. Please submit a change of approved sundry under the original PTD(225-058) for the following scope: 1. Cut and pull production liner 2. Sidetrack under the existing PTD 3. Redrill lateral using the existing PTD number. Include in the sundry: 1. Request for a variance for alternate plug placement utilizing the new production liner cement for the plug back. 2. New directional survey and any updated information such as changes to the cementing program and updated depths. 3. Submit this sundry as soon as possible. A new PTD will not be required. Victoria CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Sent from my iPhone On Jul 18, 2025, at 4:49ௗPM, Johnson, Cameron <Cameron.Johnson2@conocophillips.com> wrote: Victoria, The 6-1/2” production section of the 3S-719 well was drilled to a total depth of 21,123’ MD. The BHA was pulled out of the hole and laid down. The 4-1/2” liner was run to 20,070’ MD, where no further progress could be made. While working pipe, the 4-1/2” liner, overpull was observed, and the string is now stuck. Attempts have been made to free the string; all without success. The rig has been unable to establish circulation due to a pack off around the string. The plan forward will be to cut and pull the 4-1/2” liner from ~500’ below the 7-5/8” intermediate casing shoe, perform a sidetrack, and re-drill the lateral. The proposed operational steps for the well are as follows: 1. Mechanically release the running tool from the liner hanger. 2. Pull out of the hole with the 4” drill pipe and lay down the running tool. 3. Cut the 4-1/2” liner at ~10,184’ MD (500’ outside the 7-5/8” casing shoe). 4. Retrieve the liner hanger and cut section of the 4-1/2” liner. 5. Sidetrack off the existing wellbore ~200-300’ outside of the 7-5/8” intermediate casing shoe. 6. Drill the sidetrack production lateral, parallel to the existing production lateral, to a bottom hole location 100-200’ to the west of the existing wellbore (within 500’ of the original bottomhole location). 7. Run and cement the 4-1/2” lower completion with frac sleeves. Please find a schematic attached. Please note that depths may change slightly as the new wellplan is developed. The existing wellbore will not be plugged back with cement. The cement behind the 7-5/8” casing has been logged (previously communicated) with a top of cement at 7740’ MD / 3766’ MD. This provides 2087’ MD / 341’ TVD of cement above the Coyote formation, providing adequate isolation of the reservoir. The sidetrack will be completed with a cemented 4-1/2” liner with frac sleeves. The orientation of the wellbores are such that they are aligned as best as possible with maximum horizontal stress. In the new wellbore, the heel most frac sleeve will target a depth below where it aligns with the azimuth of the maximum horizontal stress to avoid any uncertainty in growth of the fracture. ConocoPhillips views the risk of contact between fractures from the new wellbore and the abandoned wellbore is minimal. Questions 1. Does the AOGCC give verbal permission to move forward with the plan outlined above? A 10-403 will be submitted for the cut and pull. 2. Will the side-track require a new PTD or will it be covered by a sundry? 1. This application will be submitted once a new directional plan has been developed. Regards, Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ANO-938, 700 G Street, Anchorage, AK STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3S-719 JBR 08/01/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Test went well 22 Accumulator bottles with a 1000psi precharge avg. Test Results TEST DATA Rig Rep:E. Potter/B. WillardOperator:ConocoPhillips Alaska, Inc.Operator Rep:K. Herring/P. Angelle Rig Owner/Rig No.:Doyon 25 PTD#:2250580 DATE:6/28/2025 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopKPS250629110101 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 1504 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 7-5/8"P #2 Rams 1 Blind/Shear P #3 Rams 1 2-7/8" x 5" V P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"P Kill Line Valves 2 3-1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P1850 200 PSI Attained P13 Full Pressure Attained P101 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1983 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P14 #1 Rams P6 #2 Rams P6 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 Test charts attached 3S-719 6/28/2025 Tested to 250PSI/5 Min, 5000PSI/5 Min RIG 25 BOP TEST 250/5000 W/ 7 5/8” & 5” 7 5/8” Test Joint #1 –ANNULAR PREVENTER T/ 3500 PSI FOLLOWING TESTS T/ 5000 PSI #2- UPR’S (7 5/8” SBR), LIBOP CMV’S #1, 13, 14, 15, & 4” KILL LINE VALVE “RIG FLOOR” #3- CMV’S # 2,10, 12 UPPER PIPE RAMS, UIBOP, HCR KILL #4 –CMV’S # 9, 6, 11, DART VALVE, MANUAL KILL #5 –CMV’S # 5, 7, 8, FOSV #1 #6 –CMV. # 3 & 5” FOSV #2 #7 –CMV # 4 #8- CHOKE HCR #9- MANUAL CHOKE #10A & 10B EACH T/2,000 PSI HOLD & BLEED T/ 1500 PSI #11- BLIND RAMS 5” Test Joint #12- ANNULAR T/ 3500 PSI #13- LPR’S T/ 5,000 PSI BOPE Test - Doyon 25 KRU 3S-719 PTD 2250580 AOGCC Insp # bopKPS250629110101 6/28/2025 2025-0627_Surface_Csg_TopJob_KRU_3S-719_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 06/29/2025 P. I. Supervisor FROM: Km StJohn SUBJECT: Surface Casing Cement Top Job Petroleum Inspector KRU 3S-719 ConocoPhillips Alaska Inc. PTD 2250580; Sundry 325-392 06/27/2025: I went to Doyon 25 over KRU 3S-719. They did not get cement to surface after running the surface casing. The procedure for pumping the top job cement was discussed with Keith Herring (CPAI Company Man) and Brandon Willard (Doyon 25 Tool Pusher). They ran in the conductor by surface casing annulus to get a tag on the top of cement. The deepest tag was at 63 feet; they calculated about 10 barrels to bring cement back to surface, SLB’s cement weight was 11.0 ppg. Cement will be displaced with 10.2 ppg drilling mud. They started pumping slowly thru the ½-inch conduit run in the conductor by surface casing annulus and set at 62 feet. Cement returns started showing at surface after pumping 7 barrels; the returning weight was 10.7 ppg. They continued pumping until 11bbls of cement away and a weight of 10.8 ppg was attained and there was good clean cement at surface. The total fluid pumped was 20 bbls. Overall, a good cement top-off in the conductor by surface casing annulus. Attachments: Photo 2025-0627_Surface_Csg_TopJob_KRU_3S-719_ksj Page 2 of 2 Surface Casing Top Job – KRU 3S-719 (PTD 2250580) Photo by AOGC Inspector K. StJohn 6/27/2025 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?KRU 3S-719 Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): Casing Collapse Structural Conductor Surface 2470 Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:cameron.johnson2@cop.com Contact Phone: 907-223-6277 Authorized Title:Senior Drilling Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Cameron Johnson Remedial Cement Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Coyote Oil Pool PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade:Tubing MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL380107 / ADL025544 / ADL025551 225-058 P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20919-00-00 ConocoPhillips Alaska Inc. Kuparuk River Field Length Size Proposed Pools: TVD BurstMD 5210 120 2550 120 2766 20 10.75 80 2726 Perforation Depth MD (ft):Perforation Depth TVD (ft): 6/27/2025 m n P 2 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-392 By Gavin Gluyas at 1:12 pm, Jun 27, 2025 file with PTD 10-407 Top Job SFD 6/30/2025 DSR-6/30/25 X Must meet all conditions of approval on original PTD approval, PTD 225-058, approved on 6/20/2025. VTL 7/7/2025 Victoria Loepp 6/27/2025 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.07 15:21:30 -08'00'07/07/25 RBDMS JSB 070925 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Telephone 907-276-1215 June 27, 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Application for Sundry Approval KRU 3S-719 (PTD:225-058), Remedial Surface Casing Cement Dear Sir or Madam, ConocoPhillips Alaska, Inc. seeks sundry approval for KRU 3S-719 well on the 3S drilling pad, with operations beginning 06/27/2025. Lost circulation was encountered while cementing the 10-3/4” Surface Casing, and approval is being requested to perform a remedial cement job. The primary cementing operation is summarized below. 1. 10-3/4” Surface casing was run to set depth, and the hole was conditioned for cementing. 2. 100 bbls of 10.5 ppg Mud Push, a plug was dropped, 450 bbls of 11.0 ppg Lead Cement, and 58 bbls of 15.8 ppg Tail Cement was pumped. A plug was dropped and kicked out with 20 bbls of fresh water. a. 50 bbls into the tail cement, a decrease in flow out was observed. The hanger was picked up off seat, and returns were regained. 3. The rig displaced the cement with 239 bbls of 9.5 ppg Spud Mud a. A reduction in returns was observed 110 bbls into displacement. Again, the hanger was picked off seat and partial returns were regained. The rig was unable to land the hanger again. b. It was estimated that 74 bbls of contaminated cement was returned to surface. 4. 1” tubing was run into the surface casing by conductor annulus and resistance/tag was observed at 46’ below surface, indicating a TOC near surface. ConocoPhillips is seeking approval to perform a remedial “top job” on the annulus. A detailed plan forward is outlined below. Please find attached the information for your review. Pertinent information attached to this application includes the following: 1.Form 10-403 Application for Sundry Approval as required by 20 AAC 25.030 2.Detailed plan forward. If you have any questions or require further information, please contact Cameron Johnson at (907) 223-6277 (Cameron.johnson2@conocophillips.com) or Greg Hobbs at 907-263-4749 (greg.s.hobbs@conocophillips.com). Regards, Cameron Johnson Senior Drilling Engineer cc: 3S-719 Well File / Jenna Taylor ATO 1732 Will Earhart ATO 1552 Johnson Njoku ATO 1532 Greg Hobbs ATO 1504 3S-719 AOGCC 10-403 Application for Sundry 6/27/2025 Proposed Change of Approved Program Past Operations 1. Run 1” tubing string down annulus to tag TOC to determine cement volume to load out. x Tagged at 46’ MD 2. L/D 1” tubing string. Future Operations 3. Mobilize top job cementing equipment and contingency slips. 4. Mobilize cement and SLB cementing crew. 5. Run 1” tubing string down annulus to tag TOC. To be witnessed by Kam St John of AOGCC. 6. Circulate fresh water around while preparing to cement 7. Pump 11.0 ppg DeepCrete until cement is returned to surface. To be witnessed by Kam St John of AOGCC. 8. L/D 1” tubing string 9. Set 10-3/4” casing on contingency slips 10. Continue with originally programmed plan forward x Nipple up wellhead x Nipple up BOPE x Test BOPE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Loepp, Victoria T (OGC) To:Cameron Johnson Cc:AOGCC Permitting (CED sponsored) Subject:Re: 3S-719 PTD #225-058 - Surface Casing Cement Report - Remediation Notification Date:Friday, June 27, 2025 2:52:53 PM Cameron, Approval is granted to proceed with this top job as outlined in your submitted sundry. Thank you, Victoria Sent from my iPhone On Jun 27, 2025, at 11:04ௗAM, Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> wrote: Thank you for the update Sent from my iPhone On Jun 27, 2025, at 9:59ௗAM, Johnson, Cameron <Cameron.Johnson2@conocophillips.com> wrote: Victoria, Doyon 25 ran and cemented the 10-3/4” surface casing on 3S-719 last night. Please find an operational overview below. Cementing Summary 100 bbls of 10.5 ppg Mud Push II spacer Drop bottom plug 450 bbls of 11.0 ppg DeepCrete Lead Cement 58 bbls of 15.8 ppg Class G Tail Cement Drop top plug Kick plug out with 20 bbls of fresh water Displaced with 239 bbls of 9.5 ppg Spud Mud The cement was in place at 03:08 hrs on June 27th 2025. After 50 bbls of tail cement was pumped, returns were lost. The hanger was picked up and returns were regained. 110 bbls into the displace returns were again lost. The hanger was picked up and partial returns were regained. The rig was unable to re-land the hanger. ~74 bbls of contaminated cement was returned, indicating that the cement is near surface. The annulus between the 10-3/4” casing and the conductor will be inspected by lowering a T-Bar into the annulus, resistance was encountered at 38.5’. I will follow up shortly with a 10-403 outlining the remediation plan. The drilling supervisor will make notifications to the AOGCC inspectors in accordance with Industry Guidance Bulletin 13-01. Attached: SLB cement Treatment report Please let me know if you have any questions. Thank you, Cam Johnson | Drilling Engineer | ConocoPhillips Alaska M: 907.223.6277 | M: 907.720.3162 | ANO-938, 700 G Street, Anchorage, AK <3S-719 Surface Cement Treatment Report.pdf> CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:AOGCC Permitting (CED sponsored) To:AOGCC Records (CED sponsored) Subject:FW: 3S-719 PTD #225-058 - Surface Casing Cement Report - Remediation Notification Date:Friday, June 27, 2025 2:56:18 PM From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, June 27, 2025 2:53 PM To: Cameron Johnson <Cameron.Johnson2@conocophillips.com> Cc: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Subject: Re: 3S-719 PTD #225-058 - Surface Casing Cement Report - Remediation Notification Cameron, Approval is granted to proceed with this top job as outlined in your submitted sundry. Thank you, Victoria Sent from my iPhone On Jun 27, 2025, at 11:04 AM, Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> wrote: Thank you for the update Sent from my iPhone On Jun 27, 2025, at 9:59 AM, Johnson, Cameron <Cameron.Johnson2@conocophillips.com> wrote: Victoria, Doyon 25 ran and cemented the 10-3/4” surface casing on 3S-719 last night. Please find an operational overview below. Cementing Summary 1. 100 bbls of 10.5 ppg Mud Push II spacer 2. Drop bottom plug 3. 450 bbls of 11.0 ppg DeepCrete Lead Cement 4. 58 bbls of 15.8 ppg Class G Tail Cement 5. Drop top plug 6. Kick plug out with 20 bbls of fresh water 7. Displaced with 239 bbls of 9.5 ppg Spud Mud The cement was in place at 03:08 hrs on June 27th 2025. After 50 bbls of tail cement was pumped, returns were lost. The hanger was picked up and returns were regained. 110 bbls into the displace returns were again lost. The hanger was picked up and partial returns were regained. The rig was unable to re-land the hanger. ~74 bbls of contaminated cement was returned, indicating that the cement is near surface. The annulus between the 10-3/4” casing and the conductor will be inspected by lowering a T-Bar into the annulus, resistance was encountered at 38.5’. I will follow up shortly with a 10-403 outlining the remediation plan. The drilling supervisor will make notifications to the AOGCC inspectors in accordance with Industry Guidance Bulletin 13-01. Attached: 1. SLB cement Treatment report Please let me know if you have any questions. Thank you, Cam Johnson | Drilling Engineer | ConocoPhillips AlaskaM: 907.223.6277 | M: 907.720.3162 | ANO-938, 700 G Street,Anchorage, AK <3S-719 Surface Cement Treatment Report.pdf> Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Kuparuk River Field, Coyote Oil Pool, KRU 3S-719 Conoco Phillips Alaska, Inc. Permit to Drill Number: 225-058 Surface Location: 2539 FNL, 1158 FEL, S18 T12N, R8E, UM Bottomhole Location: 2602 FSL, 1959 FEL, S25 T12N R7E, UM Dear Mr.Brillon: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCCreserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCCspecifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED thisthday of June 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.20 13:05:51 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5.Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 21,119 TVD: 4206 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property:14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 64.3 15. Distance to Nearest Well Open Surface: x- 476101 y- 5993876 Zone- 4 24.8 to Same Pool: 1322' to 3S-721 16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94# H40 Welded 120 40 40 120 120 13-1/2" 10-3/4" 45.5# L80 H563 2624 40 40 2624 2472 9-7/8" 7-5/8" 29.7# L80 H563 8973 40 40 8973 3990 9-7/8" 7-5/8" 33.7# P110S H563 800 8973 3990 9773 4112 6-1/2" 4-1/2" 12.6# P110-S H563 11521 9598 4087 21119 4206 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Chris Brillon Contact Email:abby.warren@cop.com Wells Engineering Manager Contact Phone: 907-240-9293 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Kuparuk River Field Coyote Oil Pool 7/1/2025 1909' to ADL392374 1443 sx of 15.3 ppg Class G + Add's 364sx of 15.3 ppg Class G + Adds 1264 sx of 11.0 ppg DeepCRETE + 272 sx of 15.8 ppg Class G 1504 If checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Authorized Title: Authorized Signature: Abby Warren Commission Use Only See cover letter for other requirements. Perforation Depth MD (ft): Perforation Depth TVD (ft): Liner Production Intermediate Surface Conductor/Structural Casing Length Size Cement Volume MD Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks (including stage data) 1925 P.O. Box 100360 Anchorage, Alaska, 99510-0360 2539 FNL, 1158 FEL, S18 T12N, R8E, UM ADL380107 / ADL025544 / ADL025551 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska Inc 59-52-180 3S-719 3164 FNL, 3376 FEL, S13, T12N, R7E, UM 2602 FSL, 1959 FEL, S25 T12N R7E, UM 2448 / 2560 / 2560 GL / BF Elevation above MSL (ft): Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No h Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No No &ŽƌŵϭϬͲϰϬϭZĞǀŝƐĞĚϯͬϮϬϮϭ This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 6//2025 SFD 225-058 50-103-20919-00-00 SFD 6/14/2025 SFD By Grace Christianson at 8:31 am, Jun 16, 20258:31 am, Jun 16, 2025 DSR-6/18/25 Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig Annular preventer test to 2500 psig Intermediate I cement evaluation may use SonicScope under the attached Conditions of Approval Surface casing LOT and annular LOT to the AOGCC as soon as available BOPE testing on a 21-day interval is approved with the attached conditions Review results of cement evaluation logs with AOGCC as soon as available Diverter variance granted per 20 AAC 25.035(h)(2) VTL 6/16/2025 X ($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.20 13:06:08 -08'00' 06/20/25 06/20/25 RBDMS JSB 062325 <Zhϯ^Ͳϳϭϵ Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. .58'66 CPAI’s request to allow BOPE testing on a 21-day interval is approved with the following conditions: - CPAI must continue to implement the Between Wells Maintenance Program as approved by AOGCC. - The initial test after rigging up BOPE to drill a well must be to the rated working pressure as provided in API Standard 53. - CPAI is encouraged to take advantage of opportunities to test within the 21-day time limit. - CPAI must adhere to original equipment manufacturer recommendations and replacement parts for BOPE. - Requests for extensions beyond 21 days must include justification with supporting information demonstrating the additional time is necessary for well control purposes or to mitigate a stuck drill string. 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD: 21,119 TVD: 4206 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 64.3 15. Distance to Nearest Well Open Surface: x- 476193 y- 5993898 Zone- 4 24.8 to Same Pool: 1322' to 3S-721 16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94# H40 Welded 120 40 40 120 120 13-1/2" 10-3/4" 45.5# L80 H563 2624 40 40 2624 2472 9-7/8" 7-5/8" 29.7# L80 H563 8973 40 40 8973 3990 9-7/8" 7-5/8" 33.7# P110S H563 800 8973 3990 9773 4112 6-1/2" 4-1/2" 12.6# P110-S H563 11521 9598 4087 21119 4206 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Chris Brillon Contact Email:abby.warren@cop.com Wells Engineering Manager Contact Phone: 907-240-9293 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Kuparuk River Field Coyote Oil Pool 7/1/2025 1909' to ADL392374 1443 sx of 15.3 ppg Class G + Add's 364sx of 15.3 ppg Class G + Adds 1264 sx of 11.0 ppg DeepCRETE + 272 sx of 15.8 ppg Class G 1504 If checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Authorized Title: Authorized Signature: Abby Warren Commission Use Only See cover letter for other requirements. Perforation Depth MD (ft): Perforation Depth TVD (ft): Liner Production Intermediate Surface Conductor/Structural Casing Length Size Cement Volume MD Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks (including stage data) 1925 P.O. Box 100360 Anchorage, Alaska, 99510-0360 2540 FNL, 1159 FEL, S18 T12N, R8E, UM ADL380107 / ADL025544 / ADL025551 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska Inc 59-52-180 3S-719 3164 FNL, 3376 FEL, S13, T12N, R7E, UM 2602 FSL, 1959 FEL, S25 T12N R7E, UM 2448 / 2560 / 2560 GL / BF Elevation above MSL (ft): Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Gavin Gluyas at 3:15 pm, May 28, 2025 476101 Yes Superseded by updated 10-401 form. Updated SHL. See attached emails. -A.Dewhurst 05JUN25 50-103-20919-00-00 SFD 225-058 5993876 ! " #" # $ % #& ## ' ( ) ** + " ), -, Re: Application for Permit to Drill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ecommend approving requested variance of diverter requirement. SFD 5/28/2025 Application for Permit to Drill ! " # $ % % &' ( ) 6. $ ( * # + ( ( , * , 9. '- * # $ . ' - ( ' /" $ 13. $ & ( ' 0 1 . % ( 2 06/20/25/ 5/28/2025 Requirements of 20 AAC 25.005 (f) !! "# $ $ %$ Requirements of 20 AAC 25.005(c)(2) $ & '()*&'+)*,(-,+*./ NAD27 Northing: &,01 Easting: 0 1 RKB Elevation 0 12/) Pad Elevation 1,2/) + $ " 01 30 4 0 '()*0'+)*(-+*./ NAD27 Northing: 5993277.65 Easting: 0 &1, Measured Depth, RKB: &3/ True Vertical Depth, RKB: 34 True Vertical Depth, SS: 34 + 2 3+4 0 ')*&'+)*&(-+*./ NAD27 Northing: &,&1 Easting: &&1,0 Measured Depth, RKB:3/ True Vertical Depth, RKB: 34 True Vertical Depth, SS: 34 0006606066/20/25// 5/28/2025 060066/20/25//00606066/20/25// 5/28/2025 Requirements of 20 AAC 25.005(c)(13) 1 /5-.6& 7 ! $ 8 $" 1 1 - %"!$ *$ $$1 1 9: " %! ! $ !* !"$/"$1;)< % #= -9-+9 <>1 1 -"$ # 9 :" %" 1-" #! "# $! 1 &1 5? + %@" !#9 %" =&9,8" ! 7 *&9,:'?-* $ #$9,8A&8 4?-21 See section 4 for ram configuration justification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equirements of 20 AAC 25.005(c)(3 & 7) ? $$ 7 # 6& 6& "? + B@" !!$ " ! 7 * A$*&9,: $$6 #* $9 #$7 # $ %$ " % % #$ 1 / ! #$ " % # $%6! $ &/ " 1< / ! ! ! 1 . ''( %.%'8 ' ! #A #"#! " ! " * ! *? +#" 7 ! 7 * "$ %= 1 @" !!$ ! ! # D$ ! !*" % %% "$*A ! ! ! # $ D$# # $$ 1 1 $ # 1 " 6! # 9 ( " 7 ; > &9,:' A$-# ? $9 -#; > 4?-2; > 8 " 7 ; > 4?-2; > ? $9 -#; > 4?-2; > 5 @"$ 7 $ 7 @" #"$ &1 &; >;> % $1* % $ % % 6$ "% " 71 ! 7 "6$ $ ;,*0 *0*0*0*0 *0 *00* * > & 2 ! !$" 1( " $6 % $ % % 6$ 1 & 2 Recommend approving requested variance of diverter requirement.SFD @"7 $ 7 @" # 0*0 ( " $6 % $ % % 6$ , 5/28/2025 0 % &' ( Requirements of 20 AAC 25.005(c)(4) 3'4 : 6 2 : $ ; /A #"# " " ;/> $ # $ = &2 8" ! " B$ # % %% $ " &2 8 # ! ! " A %! %% $ " / $/ $ = [( ×0.052 ) ] × = ( ) × 28 *< 5 ' " % $ % 9% ..% 5 7 #9%! 9 < < 5 1! 9 += 5 "4 ! % -E? 28 * 5 ' # " A %! < < 5 1! 9 %! $"$ " /A #"# " " ;/> $ %= C D 7 " / psi // D/4' ppg " ppg | psi /4 " ppg | psi / $ psi / $ psi .-'9: : 1 ,1 & 0 ,1 *, , 5(9,: 9 : 0 ,1, * ,1, *,, * *&&* - 09: &9,: ,1, *,, 0 ,1, *& *& *0*& 3 4 1 ; !$ A! $! 6 %D1 3(4 $ 2 - 2 - > 1 > 1 2 2 " $ $$ ? ; %CD $"## 6 5/28/2025 6. $ ( * # + Requirements of 20 AAC 25.005 (c)(5) " % $! #) '5 $ ) 9'5! $" !B ## 1 ( ( Requirements of 20 AAC 25.005 (c)(6) %$ # % % # OD (in) Hole Size (in) Weight (lb/ft) Grade 1Cement Program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equirements of 20 AAC 25.005(c)(8)) " 5 #$ $" C D 9: 9,:09: % D 9 :&9,: 9: 6!!%,1010!!% 1 1 !!% 1 1 !!% 4 ) O19 && ,0 ,0 '"4 69@& 0& 0& 5 19 & (9 (9 / " 19 0 (9 (9 5'" $) 9 # P & (9 (9 CC'" $) 9 # 9 P P !C,1&1& 1&Q 1 1& 1 9< - (9 0&9&Q 9 0&9&Q 9 $ 0 8 !"$/"$ "$ " 71E ! 7 6R 9@ $ %$ " % %1-$" 7 6! # %1/ #"$ % S 1 !!%6" $ 6#$$ " 61 # 8 ('6# "$1+" %$ %6!"#! % %" !$#A # D %" $ " 7 61/ #"$ % #1 1 !!%$! ! $$$ " # $$1 0 8 D! $" 7 $ $ ('6# % $1 1 !!%1/ 7 $$ % B! " $" % 61 % #6&/"$6# 1 %" $! $ !! ! %" $ &1 1 5/28/2025 9. '- * # $ Requirements of 20 AAC 25.005 (c)(9) (9!! A! 6 % ! 1 . ' Requirements of 20 AAC 25.005 (c)(10) (9!! A! 6 % ! 1 - ( ' Requirements of 20 AAC 25.005 (c)(11) (9!! 1 /" $ Requirements of 20 AAC 25.005 (c)(12) +7 $ $ % !B*5 1 ## 1 13. $ & ( ' Requirements of 20 AAC 25.005 (c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wp05 Plan Summary 3S-719 (P02) wp05 3S-03 3S-06 3S-06A 3S-08 3S-08A 3S-08B 3S-08C 3S-08CL1 3S-08CL1PB1 3S-093S-10 3S-14 3S-15 3S-16 3S-17 3S-17A 3S-18 3S-19 3S-21 3S-223S-233S-23A 3S-24 3S-24A 3S-24B 3S-26PALM 1 3S-606 3S-610 3S-611 3S-611PB1 3S-612 3S-613 3S-615 3S-617 3S-620 3S-624 3S-625 3S-626 3S-626PB1 3S-701 3S-701A 3S-704 3S-714 3S-718 3S-721 3S-722 3S-723 3S-705 (I12) wp09.1 3S-727 (P23A) wp033S-728 (I09) wp04 3S-729 (I22A) wp033S-730 (P10) wp04 3S-731 (P07) wp04 3S-732 (I10) wp05 3S-733 (I07) wp04 3S-735 (P11) wp04 3S-740 (I15) wp03 3S-741 (P15) wp02 3T-731 3S-703 0 4 Dogleg Severity0 3000 6000 9000 12000 15000 18000 21000 Measured Depth 10-3/4" Surface Casing 7" Intermediate Casing 4-1/2" Production Liner 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] 3S-14 3S-16 3S-173S-17A 3S-18 3S-19 3S-21 3S-22 3S-23 3S-23A 3S-26 PALM 13S-613 3S-615 3S-617 3S-620 3S-624 3S-714 3S-718 3S-721 3S-722 3S-723 3S-727 (P23A) wp03 3S-728 (I09) wp04 3S-729 (I22A) wp03 0 4500 True Vertical Depth0 2000 4000 6000 8000 10000 12000 Vertical Section at 207.85° 10-3/4" Surface Casing 7" Intermediate Casing 4-1/2" Production Liner 0 28 55 Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 21000 Measured Depth Equivalent Magnetic Distance DDI 7.374 SURVEY PROGRAM Date: 2019-05-03T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.00 1500.00 3S-719 (P02) wp05 (3S-719)r.5 SDI_URSA1 1500.00 2625.00 3S-719 (P02) wp05 (3S-719)MWD+IFR2+SAG+MS2625.00 9798.00 3S-719 (P02) wp05 (3S-719)MWD+IFR2+SAG+MS 9798.00 21123.28 3S-719 (P02) wp05 (3S-719)MWD+IFR2+SAG+MS Surface Location Ground / 24.80 North / 5993626.99 East / 1616133.23 CASING DETAILS TVD MD Name 2472.30 2624.97 10-3/4" Surface Casing 4111.96 9798.00 7" Intermediate Casing 4203.76 21116.17 4-1/2" Production Liner Mag Model & Date:BGGM2025 23-Jun-25 Magnetic North is 13.66° East of True North (Magnetic Declination) Mag Dip & Field Strength:80.60° 57161.25nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 400.00 1.50 220.00 399.99 -1.00 -0.84 1.50 220.00 1.28 Start DLS 2.00 TFO 0.00 4 500.00 3.50 220.00 499.89 -4.34 -3.65 2.00 0.00 5.54 Start 250.00 hold at 500.00 MD 5 750.00 3.50 220.00 749.42 -16.04 -13.46 0.00 0.00 20.46 Start Drop -2.00 6 925.00 0.00 0.00 924.31 -20.13 -16.89 2.00 180.00 25.69 Start Build 2.50 7 1529.99 15.12 310.00 1522.30 30.90 -77.71 2.50 310.00 8.97 Start 103.59 hold at 1529.99 MD 8 1633.58 15.12 310.00 1622.30 48.27 -98.41 0.00 0.00 3.29 Start DLS 3.00 TFO -10.00 9 2624.97 44.71 302.97 2472.30 327.46 -499.09 3.00 -10.00 -56.40 Start 20.00 hold at 2624.97 MD 10 2644.97 44.71 302.97 2486.51 335.11 -510.90 0.00 0.00 -57.65 Start DLS 2.50 TFO -33.60 11 4270.51 80.93 281.56 3223.51 827.88 -1832.81 2.50 -33.60 124.14 Start 3262.18 hold at 4270.51 MD 12 7532.69 80.93 281.56 3738.00 1473.33 -4988.84 0.00 0.00 1027.68 Start DLS 3.25 TFO -94.92 13 10824.71 88.00 174.00 4196.82 -422.95 -7044.56 3.25 -94.92 3664.62 Start 200.00 hold at 10824.71 MD 14 11024.71 88.00 174.00 4203.80 -621.73 -7023.67 0.00 0.00 3830.63 Start 20.00 hold at 11024.71 MD 15 11044.71 88.00 174.00 4204.50 -641.61 -7021.58 0.00 0.00 3847.23 Start DLS 1.50 TFO -40.72 16 11256.88 90.41 171.92 4207.44 -852.13 -6995.59 1.50 -40.72 4021.23 Start 4646.16 hold at 11256.88 MD 17 15903.04 90.41 171.92 4173.95 -5452.10 -6342.92 0.00 0.00 7783.62 Start DLS 1.00 TFO 178.12 18 15944.36 90.00 171.94 4173.80 -5493.01 -6337.12 1.00 178.12 7817.08 Start DLS 1.00 TFO 179.82 19 15977.66 89.67 171.94 4173.90 -5525.98 -6332.45 1.00 179.82 7844.05 Start 5145.62 hold at 15977.66 MD 20 21123.28 89.67 171.94 4203.80 -10620.67 -5610.91 0.00 0.00 12011.70 TD at 21123.28 FORMATION TOP DETAILS TVDPath Formation 1399.80 Top Ugnu 1713.80 Base Permafrost 2018.80 Top West Sak 2458.80 Base West Sak 2665.80 Campanian Sand (C-80) 3371.80 C-50 3936.80 C-35 4123.80 Top Coyote (Top Nanushuk), K3 Plan 24.8+39 @ 63.80usft (Doyon 25) Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: Plan: 3S-719 (P02)Wellbore: 3S-719Design: 3S-719 (P02) wp05-10000-50000South(-)/North(+) (2500 usft/in)-10000 -5000 0 5000 10000West(-)/East(+) (2500 usft/in)3S-719 T1 1320 ft3S-719 T2 1320 ft3S-719 P03 T2 0328243S-719 P02 T2 0411243S-719 P02 T1 0328243 S -0 33S-063S-06A3S-083S-08A3S-08B3 S -0 8 C 3S-08CL13S-08CL1PB13S-093S-103S-143S-153S -163S-173 S -1 7 A 3S-183S-193S-213 S -2 2 3 S -23 3S-23A3S-243S-24A3S-24B3 S -2 6 PALM 13S-6063S-6103S-6113S-611PB13S-6123S-6133S-6153S-6173S-6203S-6243S-6253S-6263S-7013S-701A3S-7033S-7043S-7143S-7183S-7213S-7223S-7233S-729 (I22A) wp033S-731 (P07) wp043S-733 (I07) wp043S-740 (I15) wp033S-741 (P15) wp023T-7315001000150020002500300035004 0 0 0 42073S-719 (P02) wp05Plan View with offset wells06/20/25 Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: Plan: 3S-719 (P02)Wellbore: 3S-719Design: 3S-719 (P02) wp05-10000-50000South(-)/North(+) (2500 usft/in)-10000 -5000 0 5000 10000West(-)/East(+) (2500 usft/in)3S-719 T1 1320 ft3S-719 T2 1320 ft3S-719 P03 T2 0328243S-719 P02 T2 0411243S-719 P02 T1 0328245001000150020002500300035004 0 0 0 42073S-719 (P02) wp05Plan View 019003800True Vertical Depth (950 usft/in)0 3000 6000 9000 12000Vertical Section at 207.85° (1500 usft/in)10-3/4" Surface Casing7" Intermediate Casing4-1/2" Production Liner100020003000400050006000700080009000100001100012000 13000 14000 15000160001700018000190002000021000Plan: 3S-719 (P02) wp05Start Build 1.50Start DLS 2.00 TFO 0.00Start 250.00 hold at 500.00 MDStart Drop -2.00Start Build 2.50Start 103.59 hold at 1529.99 MDStart DLS 3.00 TFO -10.00Start 20.00 hold at 2624.97 MDStart DLS 2.50 TFO -33.60Start 3262.18 hold at 4270.51 MDStart DLS 3.25 TFO -94.92Start 200.00 hold at 10824.71 MDStart 20.00 hold at 11024.71 MDStart DLS 1.50 TFO -40.72Start 4646.16 hold at 11256.88 MDStart DLS 1.00 TFO 178.12Start DLS 1.00 TFO 179.82Start 5145.62 hold at 15977.66 MDTD at 21123.28Section View Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: Plan: 3S-719 (P02)Wellbore: 3S-719Design: 3S-719 (P02) wp05 ! ! 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B % 90 .3 + &C 20 - C = & 5++ , . 5++ , + , . %&'( ) *&' + , - 2 0 .3 @ < + @ 4 39 500 500 800 800 1200 1200 1500 1500 2000 2000 2500 2500 3000 3000 5000 5000 10000 10000 22000 3S-719 (P02) wp05 Plan Summary 3S-719 (P02) wp05 3S-03 3S-06 3S-06A 3S-08 3S-08A 3S-08B 3S-08C 3S-08CL1 3S-08CL1PB1 3S-093S-10 3S-14 3S-15 3S-16 3S-17 3S-17A 3S-18 3S-19 3S-21 3S-223S-233S-23A 3S-24 3S-24A 3S-24B 3S-26PALM 1 3S-606 3S-610 3S-611 3S-611PB1 3S-612 3S-613 3S-615 3S-617 3S-620 3S-624 3S-625 3S-626 3S-626PB1 3S-701 3S-701A 3S-704 3S-714 3S-718 3S-721 3S-722 3S-723 3S-705 (I12) wp09.1 3S-727 (P23A) wp033S-728 (I09) wp04 3S-729 (I22A) wp033S-730 (P10) wp04 3S-731 (P07) wp04 3S-732 (I10) wp05 3S-733 (I07) wp04 3S-735 (P11) wp04 3S-740 (I15) wp03 3S-741 (P15) wp02 3T-731 3S-703 0 4 Dogleg Severity0 3000 6000 9000 12000 15000 18000 21000 Measured Depth 10-3/4" Surface Casing 7" Intermediate Casing 4-1/2" Production Liner 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] 3S-14 3S-16 3S-173S-17A 3S-18 3S-19 3S-21 3S-22 3S-23 3S-23A 3S-26 PALM 13S-613 3S-615 3S-617 3S-620 3S-624 3S-714 3S-718 3S-721 3S-722 3S-723 3S-727 (P23A) wp03 3S-728 (I09) wp04 3S-729 (I22A) wp03 0 4500 True Vertical Depth0 2000 4000 6000 8000 10000 12000 Vertical Section at 207.85° 10-3/4" Surface Casing 7" Intermediate Casing 4-1/2" Production Liner 0 28 55 Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 21000 Measured Depth Equivalent Magnetic Distance DDI 7.374 SURVEY PROGRAM Date: 2019-05-03T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.00 1500.00 3S-719 (P02) wp05 (3S-719)r.5 SDI_URSA1 1500.00 2625.00 3S-719 (P02) wp05 (3S-719)MWD+IFR2+SAG+MS2625.00 9798.00 3S-719 (P02) wp05 (3S-719)MWD+IFR2+SAG+MS 9798.00 21123.28 3S-719 (P02) wp05 (3S-719)MWD+IFR2+SAG+MS Surface Location North / 5993626.83 East / 1616133.10 Ground / 24.80 CASING DETAILS TVD MD Name 2472.30 2624.97 10-3/4" Surface Casing 4111.96 9798.00 7" Intermediate Casing 4203.76 21116.17 4-1/2" Production Liner Mag Model & Date:BGGM2025 23-Jun-25 Magnetic North is 13.66° East of True North (Magnetic Declination) Mag Dip & Field Strength:80.60° 57161.25nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 400.00 1.50 220.00 399.99 -1.00 -0.84 1.50 220.00 1.28 Start DLS 2.00 TFO 0.00 4 500.00 3.50 220.00 499.89 -4.34 -3.65 2.00 0.00 5.54 Start 250.00 hold at 500.00 MD 5 750.00 3.50 220.00 749.42 -16.04 -13.46 0.00 0.00 20.46 Start Drop -2.00 6 925.00 0.00 0.00 924.31 -20.13 -16.89 2.00 180.00 25.69 Start Build 2.50 7 1529.99 15.12 310.00 1522.30 30.90 -77.71 2.50 310.00 8.97 Start 103.59 hold at 1529.99 MD 8 1633.58 15.12 310.00 1622.30 48.27 -98.41 0.00 0.00 3.29 Start DLS 3.00 TFO -10.00 9 2624.97 44.71 302.97 2472.30 327.46 -499.09 3.00 -10.00 -56.40 Start 20.00 hold at 2624.97 MD 10 2644.97 44.71 302.97 2486.51 335.11 -510.90 0.00 0.00 -57.65 Start DLS 2.50 TFO -33.60 11 4270.51 80.93 281.56 3223.51 827.88 -1832.81 2.50 -33.60 124.14 Start 3262.18 hold at 4270.51 MD 12 7532.69 80.93 281.56 3738.00 1473.33 -4988.84 0.00 0.00 1027.68 Start DLS 3.25 TFO -94.92 13 10824.71 88.00 174.00 4196.82 -422.95 -7044.56 3.25 -94.92 3664.62 Start 200.00 hold at 10824.71 MD 14 11024.71 88.00 174.00 4203.80 -621.73 -7023.67 0.00 0.00 3830.63 Start 20.00 hold at 11024.71 MD 15 11044.71 88.00 174.00 4204.50 -641.61 -7021.58 0.00 0.00 3847.23 Start DLS 1.50 TFO -40.72 16 11256.88 90.41 171.92 4207.44 -852.13 -6995.59 1.50 -40.72 4021.23 Start 4646.16 hold at 11256.88 MD 17 15903.04 90.41 171.92 4173.95 -5452.10 -6342.92 0.00 0.00 7783.62 Start DLS 1.00 TFO 178.12 18 15944.36 90.00 171.94 4173.80 -5493.01 -6337.12 1.00 178.12 7817.08 Start DLS 1.00 TFO 179.82 19 15977.66 89.67 171.94 4173.90 -5525.98 -6332.45 1.00 179.82 7844.05 Start 5145.62 hold at 15977.66 MD 20 21123.28 89.67 171.94 4203.80 -10620.67 -5610.91 0.00 0.00 12011.70 TD at 21123.28 FORMATION TOP DETAILS TVDPath Formation 1399.80 Top Ugnu 1713.80 Base Permafrost 2018.80 Top West Sak 2458.80 Base West Sak 2665.80 Campanian Sand (C-80) 3371.80 C-50 3936.80 C-35 4123.80 Top Coyote (Top Nanushuk), K3 Plan 24.8+39 @ 63.80usft (Doyon 25) Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: Plan: 3S-719 (P02)Wellbore: 3S-719Design: 3S-719 (P02) wp05-10000-50000South(-)/North(+) (2500 usft/in)-10000 -5000 0 5000 10000West(-)/East(+) (2500 usft/in)3S-719 T1 1320 ft3S-719 T2 1320 ft3S-719 P03 T2 0328243S-719 P02 T2 0411243S-719 P02 T1 0328243 S -033S-063S-06A3S-083S-08A3S-08B3 S -0 8 C 3S-08CL13S-08CL1PB13S-093S-103S-143S-153S -163S-173 S -1 7 A 3S-183S-193S-213 S -2 2 3 S -23 3S-23A3S-243S-24A3S-24B3 S -2 6 PALM 13S-6063S-6103S-6113S-611PB13S-6123S-6133S-6153S-6173S-6203S-6243S-6253S-6263S-7013S-701A3S-7033S-7043S-7143S-7183S-7213S-7223S-7233S-729 (I22A) wp033S-731 (P07) wp043S-733 (I07) wp043S-740 (I15) wp033S-741 (P15) wp023T-7315001000150020002500300035004 0 0 0 42073S-719 (P02) wp05Plan View with offset wells Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: Plan: 3S-719 (P02)Wellbore: 3S-719Design: 3S-719 (P02) wp05-10000-50000South(-)/North(+) (2500 usft/in)-10000 -5000 0 5000 10000West(-)/East(+) (2500 usft/in)3S-719 T1 1320 ft3S-719 T2 1320 ft3S-719 P03 T2 0328243S-719 P02 T2 0411243S-719 P02 T1 0328245001000150020002500300035004 0 0 0 42073S-719 (P02) wp05Plan View 019003800True Vertical Depth (950 usft/in)0 3000 6000 9000 12000Vertical Section at 207.85° (1500 usft/in)10-3/4" Surface Casing7" Intermediate Casing4-1/2" Production Liner100020003000400050006000700080009000100001100012000 13000 14000 15000160001700018000190002000021000Plan: 3S-719 (P02) wp05Start Build 1.50Start DLS 2.00 TFO 0.00Start 250.00 hold at 500.00 MDStart Drop -2.00Start Build 2.50Start 103.59 hold at 1529.99 MDStart DLS 3.00 TFO -10.00Start 20.00 hold at 2624.97 MDStart DLS 2.50 TFO -33.60Start 3262.18 hold at 4270.51 MDStart DLS 3.25 TFO -94.92Start 200.00 hold at 10824.71 MDStart 20.00 hold at 11024.71 MDStart DLS 1.50 TFO -40.72Start 4646.16 hold at 11256.88 MDStart DLS 1.00 TFO 178.12Start DLS 1.00 TFO 179.82Start 5145.62 hold at 15977.66 MDTD at 21123.28Section View Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: Plan: 3S-719 (P02)Wellbore: 3S-719Design: 3S-719 (P02) wp05 WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3S-719Initial Class/TypeDEV / PENDGeoArea890Unit11160On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250580Field & Pool:KUPARUK RIVER, COYOTE OIL - 490120NA1Permit fee attachedYesSurface Location lies within ADL0380107; Top Productive Interval lies in ADL0392959;2Lease number appropriateYesTD lies within ADL0025551.3Unique well name and numberYesKUPARUK RIVER, COYOTE OIL - 490120 - governed by CO 6184Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80' conductor18Conductor string providedYesSC set at 2624 ' MD19Surface casing protects all known USDWsYes188% excess20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgYes22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYes26Adequate wellbore separation proposedYesDiverter variance per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax reservoir pressure is 1925 psig(8.8 ppg emw); will drill w/ 9.0-10.0 EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1504 psig; will test BOPs to 5000 psig initially and subsequently to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYes33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)NoH2S measures required: KRU 3S-718 measured 50 ppm H2S on 11/15/202435Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure range is 0.452 to 0.457 psi/ft (8.7 to 8.8 ppg EMW). Operator's planned mud program36Data presented on potential overpressure zonesNAappears sufficient to control anticipated pressures and maintain wellbore stability.37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate14-Jun-25ApprVTLDate16-Jun-25ApprSFDDate14-Jun-25AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 6/20/2025
