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Home My WebLink About223-029Originated: Delivered to:1-Jan-26Alaska Oil & Gas Conservation Commiss01Jan26-NR !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDCD4-588 50-103-20853-00-00 223-029 Colville River WL IPROF-WFL FINAL FIELD 10-Dec-251F-10 50-029-20984-00-00 183-105 Kuparuk River WL IPROF-LEE FINAL FIELD 11-Dec-253J-10 50-029-21467-00-00 185-250 Kuparuk River WL PPROF FINAL FIELD 25-Dec-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please 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" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T41231T41232T41233CD4-58850-103-20853-00-00223-029Colville RiverWLIPROF-WFLFINAL FIELD10-Dec-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2026.01.02 08:01:12 -09'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\XO17P42L\2025-06-27_22226_CD4-588_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22226 CRU CD4-588 50-103-20553-00 Injection Profile 27-Jun-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 223-029 T40632 7/3/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.03 09:29:41 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\XO17P42L\2025-06-26_22225_CD4-588_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22225 CRU CD4-588 50-103-20553-00 Injection Profile 26-Jun-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 223-029 T40632 7/3/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.03 09:28:51 -08'00' 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD4-588 (PTD 223-029) Date:Wednesday, February 5, 2025 4:43:25 PM Attachments:image001.png AnnComm Surveillance TIO for CD4-588.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, February 5, 2025 4:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD4-588 (PTD 223-029) Chris, CRU CD4-588 (PTD 223-029) was reported by operations for exceeding the max operating pressure allowance (MOPA) for the OA (max at 1012 psi) on 02/04/2025. The OA has been bled down to 600 psi and is stable. The production casing is 7.625” 2.7lb/ft, L80 with a burst rating of 6890 psi. CPAI plans to conduct initial diagnostics with follow up remediation as needed. A wellbore schematic and 90-day TIO trend are attached. Let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD4-588 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-588 2024-11-17 300.0 1000 700.0 IA CD4-588 2025-01-28 980.0 550 -430.0 OA CD4-588 2025-02-04 1000.0 558 -442.0 OA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD4-588 8/1/2023 oberr Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Se A1 Injection Valve, Post Perfs CD4-588 1/27/2025 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: 12 stage frac completed 8/9/23-8/12/23 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 Conductor2018.50 54.4 133.4 133.4 154.19 X65 Surface 13 3/8 12.42 54.4 2,764.5 2,404.6 68.00 L80 HYD563 Intermediate 19 5/8 8.68 51.6 10,125.7 3,479.4 47.00 T95 H563 Intermediate 27 5/8 6.88 9,918.5 14,225.5 4,059.2 29.70 L-80 TSH 523 Liner 4 1/2 3.96 13,109.3 19,680.4 4,365.6 12.60 P110S H563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 13,115.5 Set Depth … 3,861.1 String Max No… 4 1/2 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) 49.2 49.20.00 Hanger 11.000 FMC 4-1/2" Tubing Hanger Hydril HYD 563 Min ID 3.92" FMC TC-EMS3.958 1,353.21,333.5 22.42 Nipple - X4.500NIPPLE,LANDING,4 1/2","X", H563 HES X Nipple 3.813 3,232.12,630.668.73 Mandrel – GAS LIFT 4.500 4-1/2" x 1" KBG4-5 GLM, 12.6# H563 Camco KBG4-5 3.865 12,758.5 3,800.280.62 Sleeve - Sliding 4.500 Sliding Sleeve, CMD, 4.5" x 3.813" GX profile, Vam Top, Down to open Baker Nexo-23.813 12,818.4 3,810.2 80.22 Mandrel – GAS LIFT 4.500 4-1/2" x 1" KBG4-5 GLM, 12.6# H563 Camco KBG4-53.865 12,886.1 3,821.7 80.25 Gauge / Pump Sensor 4.500 Schlumberger Downhole Gauge Mandrel 4-1/2 w/ Metris Evolve Single Gauge, 12.6# H563 1044021 49 3.920 12,951.2 3,832.7 80.26 PACKER 6.880 HAL TNT Packer,PN 713TNT7517-Z 7-5/8", 26.4#-39#, 4 1/2, 12.6# VAM TOP HES TNT 3.856 13,021.1 3,844.6 80.15 Nipple - DB 4.500 NIPPLE,LANDING,4 1/2","DB",3.750", H563 SLB DB-6 nipple 3.750 13,084.2 3,855.6 79.84 Sub - Shear Out - SOS 5.750 Interwell IRBD-PO, 4-1/2, 4140, H563 SHEARED 8/7/23 3.910 13,106.6 3,859.5 79.72 Locator 5.290 Mechanical Locator (6.4" OD)Baker 3.900 13,107.2 3,859.7 79.72 Locator 5.630 Mechanical locator shear sub (Shear screws 1.00' below locator) Baker 3.900 13,112.2 3,860.5 79.71 Shoe - Mule 4.500 HES Self orienting mule shoe HES 4.120 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 1,353.2 1,333.5 22.42 INJ VALVE 4.5" A1 Injection Valve on 3.813" X-lock (42" OAL) Camco A1 HYS- 123 1/27/2025 1.250 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) 3,232.12,630.668.73 1 DMY BK 1 1/27/2024 SLB 12,818.4 3,810.280.22 2 DMY BK 1 7/7/2023 SLB 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) 13,123.2 3,862.5 79.71 Packer 6.400 Baker SLZXP (HRD-E) Packer SLZXP LTP H29647004 8 4.800 13,131.7 3,864.0 79.71 Nipple - RS 6.050 RS Nipple R/S Nipple 10553458 4.260 13,134.0 3,864.4 79.72 XO Reducing 5.530 Crossover 5-1/2" H563 pin x 4- 1/2" 12.6# H563 pin, 110 MYS material 3.910 13,994.6 4,018.8 79.91 Packer - Swell 4.500 Baker Oil Swell Packer #B15, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.950 14,256.4 4,064.5 80.21 Packer - Swell 4.500 Baker Oil Swell Packer #B14, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.960 14,400.9 4,089.5 79.98 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #5, 4-1/2" 12.6# C110 HYD563 AU 107343- 000060 3.505 14,597.2 4,123.6 80.07 Packer - Swell 4.500 Baker Oil Swell Packer #B13, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.950 14,825.9 4,163.280.08 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #4, 4-1/2" 12.6# C110 HYD563 AU 107343- 000055 3.505 14,988.4 4,189.381.81 Packer - Swell 4.500 Baker Oil Swell Packer #B12, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.980 15,174.8 4,209.9 85.60 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #3, 4-1/2" 12.6# C110 HYD563 **OPEN 8/11/23** AU 107343- 000046 3.505 CD4-588, 1/28/2025 5:32:55 AM Vertical schematic (actual) Liner; 13,109.3-19,680.4 Shoe - Float; 19,675.6-19,680.4 Hydraulic fracture; 19,429.0 Packer - Swell; 19,245.4- 19,266.1 Hydraulic fracture; 19,037.0 Packer - Swell; 18,851.4- 18,872.1 Hydraulic fracture; 18,640.0 Packer - Swell; 18,453.9- 18,474.6 Hydraulic fracture; 18,243.0 Packer - Swell; 18,056.4- 18,077.1 Hydraulic fracture; 17,889.0 Packer - Swell; 17,661.5- 17,682.2 Hydraulic fracture; 17,492.0 Packer - Swell; 17,306.9- 17,326.5 Hydraulic fracture; 17,095.0 Packer - Swell; 16,828.4- 16,848.7 Hydraulic fracture; 16,663.0 Packer - Swell; 16,521.0- 16,541.5 Hydraulic fracture; 16,351.0 Packer - Swell; 16,168.9- 16,188.7 Sleeve - Frac; 15,959.9- 15,962.0 Hydraulic fracture; 15,959.0 Packer - Swell; 15,773.6- 15,794.3 Sleeve - Frac; 15,565.7- 15,567.8 Hydraulic fracture; 15,565.0 Packer - Swell; 15,380.8- 15,400.6 Sleeve - Frac; 15,174.8- 15,176.8 Hydraulic fracture; 15,174.0 Packer - Swell; 14,988.4- 15,009.0 Sleeve - Frac; 14,825.9- 14,828.0 Packer - Swell; 14,597.2- 14,618.5 Sleeve - Frac; 14,400.9- 14,403.0 Packer - Swell; 14,256.4- 14,276.7 Intermediate 2 ; 9,918.5- 14,225.5 Shoe; 14,222.2-14,225.5 Packer - Swell; 13,994.6- 14,015.6 Collar - Landing ; 13,930.8- 13,931.9 Nipple - RS; 13,131.7-13,134.0 Hanger; 13,127.2-13,131.7 Packer; 13,123.2-13,127.2 Shoe - Mule; 13,112.2 Locator; 13,107.2 Locator; 13,106.6 Sub - Shear Out - SOS; 13,084.2 Nipple - DB; 13,021.1 PACKER; 12,951.1 Gauge / Pump Sensor; 12,886.1 Mandrel – GAS LIFT; 12,818.4 Sleeve - Sliding; 12,758.5 Intermediate 1; 51.6-10,125.7 Shoe - Float; 10,122.5-10,125.7 Liner; 9,931.0-9,932.2 Liner; 9,922.8-9,931.0 Hanger; 9,918.5-9,922.8 Mandrel – GAS LIFT; 3,232.1 Surface; 54.4-2,764.5 Shoe - Float; 2,762.3-2,764.5 INJ VALVE; 1,353.2 Nipple - X; 1,353.2 Annular Fluid - Diesel; 52.0- 1,500.0; 6/6/2023 Annular Fluid - Diesel; 49.2- 1,496.0; 7/7/2023 Conductor; 54.4-133.4 Casing Hanger; 51.6-53.0 Hanger; 49.2 WNS INJ KB-Grd (ft) 54.02 RR Date 7/7/2023 Other Elev… CD4-588 ... TD Act Btm (ftKB) 20,427.0 Well Attributes Field Name NARWHAL Wellbore API/UWI 501032085300 Wellbore Status INJ Max Angle & MD Incl (°) 90.39 MD (ftKB) 17,547.41 WELLNAME WELLBORE 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) 15,380.8 4,218.7 88.78 Packer - Swell 4.500 Baker Oil Swell Packer #B11, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.980 15,565.7 4,222.4 88.84 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #2, 4-1/2" 12.6# C110 HYD563 **OPEN 8/11/23** AU 107343- 000043 3.505 15,773.6 4,225.4 89.95 Packer - Swell 4.500 Baker Oil Swell Packer #A10, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.970 15,959.9 4,225.4 89.84 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #1, 4-1/2" 12.6# C110 HYD563 **OPEN 8/11/23** AU 107343- 000041 3.505 16,168.9 4,226.2 89.00 Packer - Swell 4.500 Baker Oil Swell Packer #A9, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.960 16,351.5 4,232.4 87.79Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #9, 4-1/2" 12.6# C110 HYD563, ball OD 3.284" **OPEN 8/11/23** Frac sleeve H80934000 8 3.251 16,521.1 4,238.8 87.33 Packer - Swell 4.500 Baker Oil Swell Packer #A8, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.980 16,663.4 4,245.3 87.85 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #8, 4-1/2" 12.6# C110 HYD563, ball OD 3.241" **OPEN 8/11/23** Frac sleeve H80934000 9 3.207 16,828.4 4,249.988.57 Packer - Swell 4.500 Baker Oil Swell Packer #A7, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.970 17,095.8 4,257.3 88.50 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #7, 4-1/2" 12.6# C110 HYD563, ball OD 3.197" **OPEN 8/10/23** Frac sleeve H80934001 0 3.164 17,306.9 4,261.089.56 Packer - Swell 4.500 Baker Oil Swell Packer #A6, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.990 17,492.1 4,261.4 90.29 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #6, 4-1/2" 12.6# C110 HYD563, ball OD 3.154" **OPEN 8/10/23** Frac sleeve H80934001 1 3.122 17,661.5 4,260.9 89.58 Packer - Swell 4.500 Baker Oil Swell Packer #A5, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.960 17,889.3 4,267.388.04 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #5, 4-1/2" 12.6# C110 HYD563, ball OD 3.112" **OPEN 8/10/23** Frac sleeve H80934001 2 3.080 18,056.4 4,271.4 88.94 Packer - Swell 4.500 Baker Oil Swell Packer #A4, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.980 18,243.0 4,275.2 88.90 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #4, 4-1/2" 12.6# C110 HYD563, ball OD 3.070" **OPEN 8/10/23** Frac sleeve H80934001 3 3.038 18,453.9 4,281.887.14 Packer - Swell 4.500 Baker Oil Swell Packer #A3, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.950 18,640.3 4,293.5 86.13 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #3, 4-1/2" 12.6# C110 HYD563, ball OD 3.028" **OPEN 8/9/23** Frac sleeve H80934001 4 2.997 18,851.4 4,309.0 84.84 Packer - Swell 4.500 Baker Oil Swell Packer #2, 4-1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.950 19,037.7 4,328.183.91 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #2, 4-1/2" 12.6# C110 HYD563, ball OD 2.987" **OPEN 8/9/23** Frac sleeve H80934001 5 2.956 19,245.4 4,348.6 84.63 Packer - Swell 4.500 Baker Oil Swell Packer #1, 4-1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.960 19,429.2 4,361.6 87.60 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #1, 4-1/2" 12.6# C110 HYD563, ball OD 2.598" **OPEN 8/8/23** Frac sleeve H80934002 5 2.571 Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 19,429.019,432.9 1 Hydraulic fracture 8/9/2023 206,250.0204,380.03,776.93 3,994.12 19,037.0 19,040.9 2 Hydraulic fracture 8/9/2023 206,250.0 210,614.0 2,059.93 2,283.72 18,640.0 18,643.9 3 Hydraulic fracture 8/9/2023 156,020.0 156,024.0 1,746.62 1,912.40 18,243.0 18,246.9 4 Hydraulic fracture 8/10/2023 156,020.0 158,511.0 1,958.26 2,126.67 17,889.017,892.9 5 Hydraulic fracture 8/10/2023 156,020.0157,247.01,490.55 1,657.62 17,492.017,495.9 6 Hydraulic fracture 8/10/2023 156,000.0156,716.01,408.36 1,574.87 17,095.017,098.9 7 Hydraulic fracture 8/10/2023 156,000.0156,706.01,518.33 1,684.83 16,663.016,666.9 8 Hydraulic fracture 8/11/2023 156,000.0158,147.01,367.74 1,535.76 16,351.0 16,354.9 9 Hydraulic fracture 8/11/2023 156,000.0 155,639.0 1,235.45 1,400.82 15,959.0 15,961.1 10 Hydraulic fracture 8/11/2023 156,000.0 156,580.0 1,863.48 2,029.80 CD4-588, 1/28/2025 5:32:58 AM Vertical schematic (actual) Liner; 13,109.3-19,680.4 Shoe - Float; 19,675.6-19,680.4 Hydraulic fracture; 19,429.0 Packer - Swell; 19,245.4- 19,266.1 Hydraulic fracture; 19,037.0 Packer - Swell; 18,851.4- 18,872.1 Hydraulic fracture; 18,640.0 Packer - Swell; 18,453.9- 18,474.6 Hydraulic fracture; 18,243.0 Packer - Swell; 18,056.4- 18,077.1 Hydraulic fracture; 17,889.0 Packer - Swell; 17,661.5- 17,682.2 Hydraulic fracture; 17,492.0 Packer - Swell; 17,306.9- 17,326.5 Hydraulic fracture; 17,095.0 Packer - Swell; 16,828.4- 16,848.7 Hydraulic fracture; 16,663.0 Packer - Swell; 16,521.0- 16,541.5 Hydraulic fracture; 16,351.0 Packer - Swell; 16,168.9- 16,188.7 Sleeve - Frac; 15,959.9- 15,962.0 Hydraulic fracture; 15,959.0 Packer - Swell; 15,773.6- 15,794.3 Sleeve - Frac; 15,565.7- 15,567.8 Hydraulic fracture; 15,565.0 Packer - Swell; 15,380.8- 15,400.6 Sleeve - Frac; 15,174.8- 15,176.8 Hydraulic fracture; 15,174.0 Packer - Swell; 14,988.4- 15,009.0 Sleeve - Frac; 14,825.9- 14,828.0 Packer - Swell; 14,597.2- 14,618.5 Sleeve - Frac; 14,400.9- 14,403.0 Packer - Swell; 14,256.4- 14,276.7 Intermediate 2 ; 9,918.5- 14,225.5 Shoe; 14,222.2-14,225.5 Packer - Swell; 13,994.6- 14,015.6 Collar - Landing ; 13,930.8- 13,931.9 Nipple - RS; 13,131.7-13,134.0 Hanger; 13,127.2-13,131.7 Packer; 13,123.2-13,127.2 Shoe - Mule; 13,112.2 Locator; 13,107.2 Locator; 13,106.6 Sub - Shear Out - SOS; 13,084.2 Nipple - DB; 13,021.1 PACKER; 12,951.1 Gauge / Pump Sensor; 12,886.1 Mandrel – GAS LIFT; 12,818.4 Sleeve - Sliding; 12,758.5 Intermediate 1; 51.6-10,125.7 Shoe - Float; 10,122.5-10,125.7 Liner; 9,931.0-9,932.2 Liner; 9,922.8-9,931.0 Hanger; 9,918.5-9,922.8 Mandrel – GAS LIFT; 3,232.1 Surface; 54.4-2,764.5 Shoe - Float; 2,762.3-2,764.5 INJ VALVE; 1,353.2 Nipple - X; 1,353.2 Annular Fluid - Diesel; 52.0- 1,500.0; 6/6/2023 Annular Fluid - Diesel; 49.2- 1,496.0; 7/7/2023 Conductor; 54.4-133.4 Casing Hanger; 51.6-53.0 Hanger; 49.2 WNS INJ CD4-588 ... WELLNAME WELLBORE Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 15,565.015,567.111Hydraulic fracture 8/11/2023 156,000.0157,000.01,560.711,727.43 15,174.0 15,176.1 12 Hydraulic fracture 8/11/2023 156,000.0 180,112.0 1,812.17 2,003.43 CD4-588, 1/28/2025 5:33:01 AM Vertical schematic (actual) Liner; 13,109.3-19,680.4 Shoe - Float; 19,675.6-19,680.4 Hydraulic fracture; 19,429.0 Packer - Swell; 19,245.4- 19,266.1 Hydraulic fracture; 19,037.0 Packer - Swell; 18,851.4- 18,872.1 Hydraulic fracture; 18,640.0 Packer - Swell; 18,453.9- 18,474.6 Hydraulic fracture; 18,243.0 Packer - Swell; 18,056.4- 18,077.1 Hydraulic fracture; 17,889.0 Packer - Swell; 17,661.5- 17,682.2 Hydraulic fracture; 17,492.0 Packer - Swell; 17,306.9- 17,326.5 Hydraulic fracture; 17,095.0 Packer - Swell; 16,828.4- 16,848.7 Hydraulic fracture; 16,663.0 Packer - Swell; 16,521.0- 16,541.5 Hydraulic fracture; 16,351.0 Packer - Swell; 16,168.9- 16,188.7 Sleeve - Frac; 15,959.9- 15,962.0 Hydraulic fracture; 15,959.0 Packer - Swell; 15,773.6- 15,794.3 Sleeve - Frac; 15,565.7- 15,567.8 Hydraulic fracture; 15,565.0 Packer - Swell; 15,380.8- 15,400.6 Sleeve - Frac; 15,174.8- 15,176.8 Hydraulic fracture; 15,174.0 Packer - Swell; 14,988.4- 15,009.0 Sleeve - Frac; 14,825.9- 14,828.0 Packer - Swell; 14,597.2- 14,618.5 Sleeve - Frac; 14,400.9- 14,403.0 Packer - Swell; 14,256.4- 14,276.7 Intermediate 2 ; 9,918.5- 14,225.5 Shoe; 14,222.2-14,225.5 Packer - Swell; 13,994.6- 14,015.6 Collar - Landing ; 13,930.8- 13,931.9 Nipple - RS; 13,131.7-13,134.0 Hanger; 13,127.2-13,131.7 Packer; 13,123.2-13,127.2 Shoe - Mule; 13,112.2 Locator; 13,107.2 Locator; 13,106.6 Sub - Shear Out - SOS; 13,084.2 Nipple - DB; 13,021.1 PACKER; 12,951.1 Gauge / Pump Sensor; 12,886.1 Mandrel – GAS LIFT; 12,818.4 Sleeve - Sliding; 12,758.5 Intermediate 1; 51.6-10,125.7 Shoe - Float; 10,122.5-10,125.7 Liner; 9,931.0-9,932.2 Liner; 9,922.8-9,931.0 Hanger; 9,918.5-9,922.8 Mandrel – GAS LIFT; 3,232.1 Surface; 54.4-2,764.5 Shoe - Float; 2,762.3-2,764.5 INJ VALVE; 1,353.2 Nipple - X; 1,353.2 Annular Fluid - Diesel; 52.0- 1,500.0; 6/6/2023 Annular Fluid - Diesel; 49.2- 1,496.0; 7/7/2023 Conductor; 54.4-133.4 Casing Hanger; 51.6-53.0 Hanger; 49.2 WNS INJ CD4-588 ... WELLNAME WELLBORE C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-01-17_22635_CRU_CD4-588_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22635 CRU CD4-588 50-103-20853-00 Coil Flag 17-Jan-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 223-029 T40014 1/24/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.24 11:07:40 -09'00' Originated: Delivered to:5-Jul-24 Alaska Oil & Gas Conservation Commiss 05Jul24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24 2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24 1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24 CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24 CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24 3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24 2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24 2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24 2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24 MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24 MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39122 T39123 T39124 T39125 T39126 T39127 T39128 T39129 T39130 T39131 T39132 T39133 CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.05 10:30:21 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 11, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-588 COLVILLE RIV UNIT CD4-588 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/11/2024 CD4-588 50-103-20853-00-00 223-029-0 W SPT 3833 2230290 1500 686 687 685 686 387 485 485 482 INITAL P Brian Bixby 3/1/2024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD4-588 Inspection Date: Tubing OA Packer Depth 1340 2200 2165 2160IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240302042051 BBL Pumped:2 BBL Returned:2 Thursday, April 11, 2024 Page 1 of 1          TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7 th Avenue, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska RE:CD4-588 DATE: 02/01/2024 Transmitted: North Slope, Colville River Unit, Alaska Via SFTP upload Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: CD4-588 e-transmittal well folder Receipt: Date: Alaska/IT Data Services-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 CD4-588 PTD: 223-029 T38471 2/5/2024Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.05 11:01:43 -09'00' DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC NoNo YesMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 8/15/20232770 20427 Electronic Data Set, Filename: 50-103-20853-00- 00_CD4-588_G5_G8_RAW_LAS_20427ft MD.las 37930ED Digital Data DF 8/15/2023 Electronic File: 50-103-20853-00-00_CD4- 588_MUDLOG_20427 MD 2 INCH.pdf 37930ED Digital Data DF 8/15/2023 Electronic File: 50-103-20853-00-00_CD4- 588_MUDLOG_20427 MD 5 INCH.pdf 37930ED Digital Data DF 8/15/2023 Electronic File: CD4-588 Cutting Descriptions.xlsx37930EDDigital Data DF 9/6/202362 20426 Electronic Data Set, Filename: CD4- 588_Drilling_Mechanics_Depth_Recorded_Mode _62.5ft-20427ft.las 37977ED Digital Data DF 9/6/202345066 45068 Electronic Data Set, Filename: CD4-588 Drilling_Mechanics_Time_Data_LWD001.las 37977ED Digital Data DF 9/6/202345072 45080 Electronic Data Set, Filename: CD4- 588_Drilling_Mechanics_Time_Data_LWD002.las 37977ED Digital Data DF 9/6/202345083 45091 Electronic Data Set, Filename: CD4- 588_Drilling_Mechanics_Time_Data_LWD003.las 37977ED Digital Data DF 9/6/202345095 45108 Electronic Data Set, Filename: CD4- 588_Drilling_Mechanics_Time_Data_LWD004.las 37977ED Digital Data DF 9/6/202362 2769 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_LWD001 .las 37977ED Digital Data DF 9/6/2023120 2589 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD001.las 37977ED Digital Data DF 9/6/20232652 10136 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_LWD002 .las 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 1 of 13 Supplied by Op Supplied by Op 50-103-20853-00-, 00_CD4-588_G5_G8_RAW_LAS_20427ft MD.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/20232700 10134 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_LWD002 _MADPass.las 37977ED Digital Data DF 9/6/20232700 10134 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD002.las 37977ED Digital Data DF 9/6/202310080 14230 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_LWD003 .las 37977ED Digital Data DF 9/6/202310100 14226 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_LWD003 _MADPass.las 37977ED Digital Data DF 9/6/202314150 20426 Electronic Data Set, Filename: CD4- 588_MagniSphere_Service_Recorded_Mode_LW D004.las 37977ED Digital Data DF 9/6/202314000 20253 Electronic Data Set, Filename: CD4- 588_MagniSphere_Service_Recorded_Mode_MA DPass_LWD004.las 37977ED Digital Data DF 9/6/202314150 20426 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_LWD004 .las 37977ED Digital Data DF 9/6/202314000 20253 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD004.las 37977ED Digital Data DF 9/6/202362 20426 Electronic Data Set, Filename: CD4- 588_VISION_Service_Recorded_Mode_62.5ft- 20427ft.las 37977ED Digital Data DF 9/6/20236 20426 Electronic Data Set, Filename: CD4- 588_VISION_Service_Real_Time_62.5ft- 20427ft.las 37977ED Digital Data DF 9/6/20230 20427 Electronic Data Set, Filename: CD4- 588_Surveys.las 37977ED Digital Data DF 9/6/20239700 14300 Electronic Data Set, Filename: CD4- 588_SonicScope_Top_of_Cement_Service_RM.l as 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588_EOW Letter.doc37977EDDigital Data DF 9/6/2023 Electronic File: CD4- 588_Drilling_Mechanics_Depth_Recorded_Mode _62.5ft-20427ft.PDF 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 2 of 13 CD4-, 588_VISION_Service_Recorded_Mode_62.5ft-_ 20427ft.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/2023 Electronic File: CD4- 588_Drilling_Mechanics_Time_Recorded_Mode_ LWD001.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_Drilling_Mechanics_Time_Recorded_Mode_ LWD002.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_Drilling_Mechanics_Time_Recorded_Mode_ LWD003.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_Drilling_Mechanics_Time_Recorded_Mode_ LWD004.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Recorded_Mode_ LWD001.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Recorded_Mode_ MADPass_LWD001.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _LWD001.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _MADPass_LWD001.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Recorded_Mode_ LWD001.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Recorded_Mode_ MADPass_LWD001.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _LWD001.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _MADPass_LWD001.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Recorded_Mode_ LWD002.PDF 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 3 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Recorded_Mode_ MADPass_LWD002.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _LWD002.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _LWD002_MAD_Pass.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _MADPass_LWD002.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Recorded_Mode_ LWD002.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Recorded_Mode_ MADPass_LWD002.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _LWD002.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _LWD002_MAD_Pass.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _MADPass_LWD002.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Recorded_Mode_ LWD003.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Recorded_Mode_ MADPass_LWD003.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _LWD003.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _MADPass_LWD003.PDF 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 4 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Recorded_Mode_ LWD003.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Recorded_Mode_ MADPass_LWD003.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _LWD003.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _MADPass_LWD003.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Recorded_Mode_ LWD004.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Recorded_Mode_ MADPass_LWD004.Pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _LWD004.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _MADPass_LWD004.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Recorded_Mode_ LWD004.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Recorded_Mode_ MADPass_LWD004.Pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _LWD004.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _MADPass_LWD004.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588_MagniSphere- ALL_Services_2in_MD_Memory_Drilling_Data_L WD004.PDF 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 5 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/2023 Electronic File: CD4-588_MagniSphere- ALL_Services_2in_MD_Memory_MAD_Pass_Dat a_LWD004.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588_MagniSphere- ALL_Services_5in_MD_Memory_Drilling_Data_L WD004.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588_MagniSphere- ALL_Services_5in_MD_Memory_MAD_Pass_Dat a_LWD004.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_MagniSphere_Service_2in_MD_Memory_Dri lling_Data_LWD004.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_MagniSphere_Service_2in_MD_Memory_M AD_Pass_Data_LWD004.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_MagniSphere_Service_5in_MD_Memory_Dri lling_Data_LWD004.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_MagniSphere_Service_5in_MD_Memory_M AD_Pass_Data_LWD004.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_MagniSphere_Service_RM_2in_MD_MADPa ss_LWD004.Pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_MagniSphere_Service_RM_5in_MD_LWD00 4.Pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_MagniSphere_VISION_Service_RM_2in_MD _MADPass_LWD004.Pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_MagniSphere_VISION_Service_RM_5in_MD _LWD004.Pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Recorded_Mode_ 62.5ft-20427ft.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Recorded_Mode _62.5ft-20427ft.PDF 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 6 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Recorded_Mode_ 62.5ft-20427ft.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Recorded_Mode _62.5ft-20427ft.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_MD_Real_Time_62.5ft -20427ft.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_2in_TVD_Real_Time_62.5f t-20427ft.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_MD_Real_Time_62.5ft -20427ft.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_5in_TVD_Real_Time_62.5f t-20427ft.PDF 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD001_AR C8.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD001_GY ROSDI825.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD001_Tru Link.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD001_ARC8.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD001_GYROSDI825.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD001_TruLink.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_LWD001 .dlis 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 7 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_LWD001 .html 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD001.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD001.html 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD002_AR C8.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD002_PD XCEL_900.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD002_SA DN8.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD002_Tru Link.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD002_ARC8.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD002_PDXCEL_900.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD002_SADN8.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD002_TruLink.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_LWD002 .dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_LWD002 .html 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 8 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD002.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD002.html 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD003_Ec oScope.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD003_PD XCEL_675.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD003_Tru Link.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD003_EcoScope.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD003_PDXCEL_675.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD003_TruLink.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_LWD003 .dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_LWD003 .html 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD003.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD003.html 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Real_Time_LWD004_MagniSp here.dlis 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 9 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Real_Time_MADPass_LWD00 4_MagniSphere.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD004_AD N4B.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD004_Ma gniSphere.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_LWD004_PE RISCOPE_475.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD004_ADN4B.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD004_MagniSphere.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_ToolSpecific_Recorded_Mode_MADPass_L WD004_PERISCOPE_475.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_LWD004 .dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_LWD004 .html 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD004.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_MADPas s_LWD004.html 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_62.5ft- 20427ft.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Recorded_Mode_62.5ft- 20427ft.html 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 10 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Real_Time_62.5ft- 20427ft.dlis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_VISION_Service_Real_Time_62.5ft- 20427ft.html 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD27 EOW Compass Surveys [Canvas].txt 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD27 EOW Compass Surveys [Macro].txt 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD27 EOW Compass Surveys [Petrel].txt 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD27 EOW Compass Surveys [Surveys].txt 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD27 EOW Compass Surveys.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD83 EOW Compass Surveys [Canvas].txt 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD83 EOW Compass Surveys [Macro].txt 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD83 EOW Compass Surveys [Petrel].txt 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD83 EOW Compass Surveys [Surveys].txt 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588 NAD83 EOW Compass Surveys.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4-588_Surveys.csv37977EDDigital Data DF 9/6/2023 Electronic File: CD4-588_Surveys.txt37977EDDigital Data DF 9/6/2023 Electronic File: CD4- 588_SonicScope_Top_of_Cement_Service_RM.d lis 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_SonicScope_Top_of_Cement_Service_RM_ 1000MD.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_SonicScope_Top_of_Cement_Service_RM_ 200MD.pdf 37977ED Digital Data Tuesday, October 10, 2023AOGCC Page 11 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval INFORMATION RECEIVED Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date:7/7/2023 Release Date:5/4/2023 DF 9/6/2023 Electronic File: CD4- 588_SonicScope_Top_of_Cement_Service_RM_ 4000MD.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_SonicScope_Top_of_Cement_Service_RM_ 500MD.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4- 588_SonicScope_Top_of_Cement_Service_RM_ 6000MD.pdf 37977ED Digital Data DF 9/6/2023 Electronic File: CD4_588_R4_7.625in_Casing_SonicScope475_ RM_TOC_10000ft_11500ft_PPT.pptx 37977ED Digital Data 7/13/202312200 20127 31852Cuttings Tuesday, October 10, 2023AOGCC Page 12 of 13 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20853-00-00Well Name/No.COLVILLE RIV UNIT CD4-588 Completion Status WAGINCompletion Date 7/7/2023 Permit to Drill 2230290 Operator ConocoPhillips Alaska, Inc. MD 20427 TVD 4376 Current Status WAGIN 10/10/2023 UIC Yes Compliance Reviewed By:Date: Tuesday, October 10, 2023AOGCC Page 13 of 13 M. Guhl 10/10/2023 TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE:: CD4-588 Permit: 223-029 DATE: 09/08/2023 Transmitted: North Slope, Colville River Unit, Alaska Via SFTP upload Mud log data Revised to include lith% file Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: CD4-588 e-transmittal well folder Receipt: Date: Alaska/IT-Data Support |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 223-029 T37930 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.09.18 09:14:36 -08'00' t>>ED W/η ^Zs/KZZ η&/>ED ^Zs/ ^Z/Wd/KE >/sZ>^Z/Wd/KE ddzW d>K'' K>KZ WZ/Ed^ Ɛ CD4-588 50-103-20853-00-00 223-029 COLVILLE RIVER MWD/LWD/DD VISION SERVICES FINAL FIELD 1 dƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚ ͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺ yͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺ WƌŝŶƚEĂŵĞ ^ŝŐŶĂƚƵƌĞ ĂƚĞ WůĞĂƐĞƌĞƚƵƌŶǀŝĂĐŽƵƌŝĞƌŽƌƐŝŐŶͬƐĐĂŶĂŶĚĞŵĂŝůĂĐŽƉǇƚŽ^ĐŚůƵŵďĞƌŐĞƌ͘ sdƵŽŶŐΛƐůď͘ĐŽŵ ^>ƵĚŝƚŽƌͲ dƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚƐŝŐŶĂƚƵƌĞĐŽŶĨŝƌŵƐƚŚĂƚĂƉĂĐŬĂŐĞ;ďŽǆ͕ ĞŶǀĞůŽƉĞ͕ĞƚĐ͘ͿŚĂƐďĞĞŶƌĞĐĞŝǀĞĚĂŶĚƚŚĞĐŽŶƚĞŶƚƐŽĨƚŚĞƉĂĐŬĂŐĞ ŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚƚŽŵĂƚĐŚƚŚĞŵĞĚŝĂŶŽƚĞĚĂďŽǀĞ͘dŚĞƐƉĞĐŝĨŝĐ ĐŽŶƚĞŶƚŽĨƚŚĞƐĂŶĚͬŽƌŚĂƌĚĐŽƉǇƉƌŝŶƚƐŵĂǇŽƌŵĂǇŶŽƚŚĂǀĞďĞĞŶ ǀĞƌŝĨŝĞĚĨŽƌĐŽƌƌĞĐƚŶĞƐƐŽƌƋƵĂůŝƚǇůĞǀĞůĂƚƚŚŝƐƉŽŝŶƚ͘ η^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ PTD:223-029 T37977 Kayla Junke 9/6/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.06 16:00:48 -08'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ ConocoPhillips Alaska, Inc. Development Exploratory 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 20,427 feet feet true vertical 4,375 feet feet Effective Depth measured 20,427 feet 13,126 / 12,951 feet true vertical 4,375 feet 3,862 / 3,832 feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 4.5" 12.6# L80 13,115' MD 3,861' TVD SLZXP LTP 13,126' MD 3,862' TVD Packers and SSSV (type, measured and true vertical depth) HAL TNT 12,951' MD 3,832' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Contact Email: Authorized Title: Contact Phone: 5090 4790, 11080 5020 8150 6890, 12620 Burst Collapse 2260 135 2405 3479 4059 4-1/2" 10125 14226 19,680 4365 7-5/8" measuredPlugs Junk measured 1.953 MMlbs 20/40 Wan-Li Ceramic proppant, 54,000 lbs of 100 Mesh, 4387 bbls of seawater, and 250 treating pressure/2700 BHG pressure. Length 135 2764 Size Conductor Surface Intermediate 20" 13-3/8" 9-5/8" Intermediate Liner 10125 4313 6554 Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 223-029 50-103-20853-00-00 Job logs attached 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL380077, ADL384211, ADL380081 Colville Delta - Narwhal Undefined Oil P.O. Box 100360 Anchorage, AK 99510-03603. Address: CD4-588 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 00 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 135 2764 15,174' - 19,433' MD 0 Structural TVD 323-415 Sr Pet Eng: 9210 Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 0 11590 907-265-6462 Baskoro Tejo baskoro.tejo@cop.com Completions Engineer t Fra O O 223 6. A PG , R Form 10-404 Revised 10/2021 Submit Within 30 days of Operations August 15, 2023DDDDDDDigiigiigiigitaltaltalttal the foregoing gggg is true and c By Grace Christianson at 1:24 pm, Aug 15, 2023 Prepared By: Keegan Lambe James Campbell Nannook Crew Intervals 1-12 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 users own risk. CD4-588 Conoco Phillips Harrison Bay County, AK Post Job Report Stimulation Treatment API: 50-103-20853 Prepared for: Baskoro Tejo August 11, 2023 Narwal Formation 30# Delta Table of Contents Section Page(s) Executive Summary Wellbore Information Actual Design 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 Appendix Well Summary Chemical Summary Planned Design Water Straps 8-7 Water Straps 8-10 Water Straps 8-11 Water Analysis Aug 07 Water Analysis Aug 08 Water Analysis Aug 10 Water Analysis Aug 11 Real-Time QC Event Log 8-6 Event Log 8-7 Event Log 8-8 Event Log 8-10 Event Log 8-11 Prejob Break Test Day 1 Prejob Break Test Day 2 Fann 15 Minute Interval 1 Fann 15 Minute Interval 2 Fann 15 Minute Interval 3 Fann 15 Minute Interval 4 Fann 15 Minute Interval 5 Fann 15 Minute Interval 6 Fann 15 Minute Interval 7 Fann 15 Minute Interval 8 Fann 15 Minute Interval 9 Fann 15 Minute Interval 10 Fann 15 Minute Interval 11 Fann 15 Minute Interval 12 Lab Testing 130 131 132 133 125 126 127 128 129 120 121 122 123 124 115 116 117 118 119 110 111 112 113 114 102 103 - 106 107 108 109 84 - 87 88 - 91 92 - 95 96 - 99 100 101 3 4 5 - 8 51 - 54 55 - 63 64 - 67 9 - 27 28 29 - 46 47 - 50 68 - 71 72 - 75 76 - 83 Conoco Phillips - CD4-588 TOC 2 720,770 gallons of 30# Delta Frac 97,059 gallons of 30# Linear 4,000 gallons of Seawater 1,920,060 pounds of Wanli 20/40 Ceramic 52,500 pounds of 100M 759,311 gallons of 30# Delta Frac 151,840 gallons of 30# Linear 4,387 gallons of Seawater 1,953,600 pounds of Wanli 20/40 Ceramic 54,000 pounds of 100M Thank you, Keegan Lambe Alexander Bentz Senior Technical Professional 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 07, 2023 a stimulation treatment was performed in the Narwal formation on the CD4-588 well in Harrison Bay County, AK. The CD4-588 was a 12 stage Horizontal Sleeve Design. The proposed treatment consisted of: The actual treatment fully completed 12 of 12 stages. 0 stages were skipped, 0 stage screened out and 0 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: A CoP dispensation was in place due to the drilling activities on CD4-586 and the proximity of CD4-588. Interval 1 was adjusted after there was an issue with a water tank going empty. Job was pumped successfully using the wet proppant. Screws were adjusted based on the wet/dry proppant concentrations. Adjusted pump schedules as per CoP. Intervals 10,11,12 were the AU darts, intervals 1-9 were Baker balls. Balls were dropped at rate in crosslink after consistent seats observed. Backup dart Launched on interval 10 after muted shift. 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. MO-67 was diluted at a 3:1 ratio during the job. The reported chemical volumes for MO-67 are what actually was pumped through the LA. New MO-67 was mixed on 8/11 after the concentration was needed to be increased on 8/10 during the job. 100M ran out early from Castle on 8/11, 20/40 was pumped in place in the 0.5ppg stages. All proppant was pumped from castles, leaving them empty in preparation of rig down. Conoco Phillips - CD4-588 Executive Summary 3 Conoco Phillips NarwalCD4-58850-103-20853Description 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 0 13,109 8,379 8,430Tubing4.5 3.958 12.6 L-80 0.6392 13,109 19,675 4,197 8,430Total19,67512,576ft0.55ft84.0ftft0.55ft84.0ftTop 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)Toe19,429 19,433 4,3611Narwhal84.04:44:00 PM 5:26:00 PM 34 280 486-156.31,968 3,924 1,956 3,139 5,287 2,148 15.019,037 19,041 4,3282Narwhal83.89:48:00 AM 10:00:00 AM 2,775 3,015 3,0613.72,971 5,446 2,475 3,369 6,435 3,066 10.818,640 18,644 4,2943Narwhal83.611:26:00 AM 11:39:00 AM 5,089 5,323 5,3720.73,126 5,387 2,261 3,352 5,907 2,555 10.318,243 18,247 4,2754Narwhal83.51:15:00 PM 1:35:00 PM 1 229 2708.91,369 4,141 2,772 2,727 5,804 3,077 10.217,889 17,893 4,2675Narwhal83.53:19:00 PM 3:32:00 PM 2,109 2,331 2,386-4.73,302 5,425 2,123 3,421 6,239 2,818 10.317,492 17,496 4,2616Narwhal83.44:30:00 PM 4:45:00 PM 3,752 3,968 4,025-6.82,726 5,422 2,696 3,121 6,117 2,996 10.217,095 17,099 4,2577Narwhal83.45:39:00 PM 5:50:00 PM 5,330 5,540 5,5900.22,598 5,390 2,792 3,017 6,610 3,593 10.216,663 16,667 4,2458Narwhal83.38:15:00 AM 8:33:00 AM 1 204 2504.41,988 4,730 2,742 2,700 5,814 3,114 10.116,351 16,355 4,2329Narwhal83.39:26:00 AM 9:37:00 AM 1,517 1,716 1,766-0.22,426 5,077 2,651 2,935 6,221 3,286 10.015,959 15,961 4,22510Narwhal83.210:24:00 AM 11:37:00 AM 3,252 3,445 3,4877.91,596 3,395 1,799 2,723 4,487 1,764 15.315,565 15,567 4,22211Narwhal83.212:40:00 PM 12:50:00 PM 4,944 5,131 5,16812.91,809 1,872 63 2,927 3,101 174 15.3Heel15,174 15,176 4,21012Narwhal83.21:54:00 PM 2:04:00 PM 6,671 6,852 6,88912.91,548 1,781 233 2,700 2,974 274 15.3260.2253.6248.8242.9236.9230.99,69910,92710,65110,45210,2019,94911,915 283.711,66111,43511,181Displacement to Top Sleeve/Perf (gal)(BBLS)12,419 295.712,168 289.7277.6272.3266.2Interval #1Max Pressure (psi)6,500Isolation TypeSwell PackerTreatment TubularsCustomerFormationLeaseAPIDateTemperature DataTemp. Gradient (°F/100 ft)BHST (°F)Directional Data4,2652,23719,675Directional Data2,2378/7/2023KOPTemperature DataSleeve/Perf Depth Sleeves78910112345612Temp. Gradient (°F/100 ft)BHST (°F)TVD at Bottom PerfMD at Bottom Perf4,36119,433KOPAvg. TVDTotal MDConoco Phillips - CD4-588 Wellbore Information 4 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.29231755LEASECD4-588SALES ORDEBHST (°F)84LONG-150.9875829FORMATIONNarwalDATE Max Pressure (psi)6500Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In-1-2 Seawater Prime Up Pressure Test 5.0 1,000 -0.151-3 Shut-In Shut-In-1-4 Seawater Arsenal Sleeve Shift 5.0 1,260 2,665 63 630.151-5 30# Linear Spacer and Ball Drop 15.0 1,260 1,453 35 35 1.00 30.00 2.00 0.151-6 30# Linear Displace Ball to Seat 15.0 12,419 14,508 345 345 1.00 30.00 2.00 0.151-7 30# Linear Spacer and Ball Drop 10.0 1,260 - 1.00 30.00 2.00 0.151-8 30# Linear Displace Ball to Seat 15.0 12,419 4,691 112 112 1.00 30.00 2.00 0.151-9 30# Linear DFIT 10 1,680 1,614 38 38 1.00 30.00 2.00 0.151-10 Shut-In Shut-In-1-11 30# Linear Step Rate Test 15 8,400 2,858 68 68 1.00 30.00 2.00 0.151-12 30# Delta Frac Minifrac - Establish Fluid 25 8,400 4,852 116 116 0.50 1.00 0.25 30.00 2.00 0.151-13 30# Delta Frac Minifrac - Treatment 25 6,300 6,478 154 154 0.50 1.00 0.25 30.00 2.00 0.151-14 30# Linear Minifrac - Flush 25 12,419 13,042 311 311 1.00 30.00 2.00 0.151-15 Shut-In Shut-In-1-16 30# Delta Frac Establish Stable Fluid 15 8,400 4,955 118 118 0.50 1.00 0.25 30.00 1.50 0.151-17 30# Delta Frac Pad 25 15,000 14,876 354 354 0.50 1.00 0.25 30.00 1.50 0.151-18 30# Delta Frac Proppant Laden Fluid 100M 0.50 30 12,500 15,133 360 368 6,250 6,630 0.50 1.00 0.25 30.00 1.50 0.151-19 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 30 8,000 8,002 191 199 8,000 7,614 0.50 1.00 0.25 30.00 1.50 0.151-20 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 30 8,000 8,096 193 211 16,000 17,082 0.50 1.00 0.25 30.00 1.50 0.151-21 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 30 10,500 10,490 250 285 31,500 32,727 0.50 1.00 0.25 30.00 1.50 0.151-22 30# Linear Sweep 30 13,605 324 324 1.00 30.00 2.00 0.151-23 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 30 12,000 11,681 278 322 48,000 40,898 0.50 1.00 0.25 30.00 2.00 0.151-24 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 30 9,100 9,106 217 268 45,500 48,328 0.50 1.00 0.25 30.00 2.00 0.151-25 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 30 8,500 9,149 218 272 51,000 51,101 0.50 1.00 0.25 30.00 2.00 0.151-26 30# Delta Frac Spacer and Ball Drop 15 1,260 1,377 33 33 0.50 1.00 0.25 30.00 2.00 0.152-1 30# Delta Frac Pad 25.0 15,000 15,143 361 361 0.50 1.00 0.25 30.00 1.50 0.152-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 30.0 12,500 12,582 300 306 6,250 5,827 0.50 1.00 0.25 30.00 1.50 0.152-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 30.0 8,000 8,019 191 200 8,000 8,122 0.50 1.00 0.25 30.00 1.50 0.152-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 30.0 8,000 7,993 190 209 16,000 17,293 0.50 1.00 0.25 30.00 1.50 0.152-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 30.0 10,500 10,488 250 286 31,500 34,213 0.50 1.00 0.25 30.00 1.50 0.152-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 30.0 12,000 11,969 285 339 48,000 50,923 0.50 1.00 0.25 30.00 2.00 0.152-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 30.0 9,100 9,109 217 268 45,500 47,724 0.50 1.00 0.25 30.00 2.00 0.152-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 30.0 8,500 8,604 205 254 51,000 46,512 0.50 1.00 0.25 30.00 2.00 0.152-9 30# Delta Frac Spacer and Ball Drop 25.0 1,260 2,610 62 62 0.50 1.00 0.25 30.00 2.00 0.153-1 30# Delta Frac Pad 15.0 10,000 13,520 322 322 0.50 1.00 0.22 30.00 1.50 0.153-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 11,089 264 268 4,000 4,081 0.50 1.00 0.22 30.00 1.50 0.153-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,011 72 74 3,000 2,543 0.50 1.00 0.22 30.00 1.50 0.153-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,085 73 80 6,000 5,738 0.50 1.00 0.22 30.00 1.50 0.153-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 5,000 5,009 119 135 15,000 14,949 0.50 1.00 0.22 30.00 1.50 0.153-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 7,500 7,512 179 212 30,000 30,985 0.50 1.00 0.22 30.00 2.00 0.153-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 7,000 6,998 167 206 35,000 37,266 0.50 1.00 0.22 30.00 2.00 0.153-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 6,000 5,897 140 180 36,000 37,156 0.50 1.00 0.22 30.00 2.00 0.153-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,860 4,735 113 137 27,020 23,306 0.50 1.00 0.22 30.00 2.00 0.153-10 30# Linear Flush 25.0 12,545 12,502 298 298 1.00 30.00 2.00 0.153-11 Shut-In Shut-In-50-103-208530908772785Liquid Additives Dry AdditivesInterval 1Narwhal@ 19429 - 19432.86 ft 84 °FInterval 2Narwhal@ 19037 - 19040.86 ft 83.8 °FInterval 3Narwhal@ 18640 - 18643.86 ft 83.6 °FConoco Phillips - CD4-588 Actual Design 5 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.29231755LEASECD4-588SALES ORDEBHST (°F)84LONG-150.9875829FORMATIONNarwalDATE Max Pressure (psi)6500Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)50-103-208530908772785Liquid Additives Dry Additives4-1 Shut-In Shut-In-4-2 Seawater Prime Up Pressure Test 5.0 1,000 966 23 230.154-3 Shut-In Shut-In-4-4 30# Linear Spacer and Ball Drop 15.0 1,260 1,160 28 28 1.00 30.00 2.00 0.154-5 30# Linear Displace Ball to Seat 15.0 11,661 10,481 250 250 1.00 30.00 2.00 0.154-6 30# Linear DFIT 15.0 1,680 1,618 39 39 1.00 30.00 2.00 0.154-7 Shut-In Shut-In-1.504-8 30# Delta Frac Establish Stable Fluid 15.0 8,400 11,232 267 267 0.50 1.00 0.35 30.00 1.50 0.154-9 30# Delta Frac Pad 25.0 10,000 9,982 238 238 0.50 1.00 0.35 30.00 1.50 0.154-10 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 9,059 216 219 4,000 3,381 0.50 1.00 0.40 30.00 1.50 0.154-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 2,989 71 74 3,000 3,106 0.50 1.00 0.45 30.00 1.50 0.154-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,031 72 79 6,000 6,779 0.50 1.00 0.50 30.00 2.00 0.154-13 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 5,000 4,998 119 136 15,000 16,207 0.50 1.00 0.50 30.00 2.00 0.154-14 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 7,500 7,496 178 211 30,000 30,814 0.50 1.00 0.60 30.00 2.00 0.154-15 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 7,000 7,001 167 204 35,000 35,505 0.50 1.00 0.60 30.00 2.00 0.154-16 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 6,000 5,988 143 182 36,000 37,355 0.50 1.00 0.60 30.00 2.00 0.154-17 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,860 4,898 117 144 27,020 25,364 0.50 1.00 0.60 30.00 2.00 0.154-18 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,348 32 32 0.50 1.00 0.60 30.00 2.00 0.155-1 30# Delta Frac Pad 25.0 10,000 14,172 337 337 0.50 1.00 0.60 30.00 1.50 0.155-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 10,206 243 247 4,000 3,633 0.50 1.00 0.60 30.00 1.50 0.155-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,008 72 75 3,000 2,911 0.50 1.00 0.60 30.00 1.50 0.155-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,026 72 78 6,000 5,999 0.50 1.00 0.60 30.00 1.50 0.155-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 5,000 5,000 119 135 15,000 14,845 0.50 1.00 0.60 30.00 1.50 0.155-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 7,500 7,482 178 211 30,000 30,714 0.50 1.00 0.60 30.00 2.00 0.155-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 7,000 7,039 168 205 35,000 35,358 0.50 1.00 0.60 30.00 2.00 0.155-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 6,000 5,999 143 180 36,000 34,721 0.50 1.00 0.60 30.00 2.00 0.155-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,860 5,348 127 158 27,020 29,066 0.50 1.00 0.60 30.00 2.00 0.155-10 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,323 32 32 0.50 1.00 0.60 30.00 2.00 0.156-1 30# Delta Frac Pad 25.0 5,500 13,186 314 314 0.50 1.00 0.60 30.00 1.50 0.156-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 9,108 217 221 4,000 3,921 0.50 1.00 0.60 30.00 1.50 0.156-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,014 72 75 3,000 2,629 0.50 1.00 0.60 30.00 1.50 0.156-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 2,986 71 77 6,000 5,358 0.50 1.00 0.60 30.00 1.50 0.156-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 4,500 4,503 107 121 13,500 12,937 0.50 1.00 0.60 30.00 1.50 0.156-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,500 5,506 131 154 22,000 21,309 0.50 1.00 0.60 30.00 2.00 0.156-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 7,010 7,015 167 205 35,050 35,704 0.50 1.00 0.60 30.00 2.00 0.156-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,250 4,232 101 128 25,500 25,891 0.50 1.00 0.60 30.00 2.00 0.156-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,850 3,853 92 120 26,950 26,508 0.50 1.00 0.60 30.00 2.00 0.156-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 4,203 100 124 20,000 22,459 0.50 1.00 0.60 30.00 2.00 0.156-11 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,545 37 37 0.50 1.00 0.60 30.00 2.00 0.157-1 30# Delta Frac Pad 25.0 5,500 7,019 167 167 0.50 1.00 0.60 30.00 1.50 0.157-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 9,952 237 241 4,000 3,838 0.50 1.00 0.60 30.00 1.50 0.157-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,010 72 74 3,000 2,588 0.50 1.00 0.60 30.00 1.50 0.157-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 2,985 71 77 6,000 5,707 0.50 1.00 0.60 30.00 1.50 0.157-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 4,500 4,502 107 121 13,500 13,426 0.50 1.00 0.60 30.00 1.50 0.157-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,500 5,505 131 155 22,000 22,163 0.50 1.00 0.60 30.00 2.00 0.157-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 7,010 7,018 167 204 35,050 34,774 0.50 1.00 0.60 30.00 2.00 0.157-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 4,250 4,225 101 127 25,500 25,210 0.50 1.00 0.60 30.00 2.00 0.157-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 3,850 3,840 91 120 26,950 26,719 0.50 1.00 0.60 30.00 2.00 0.157-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,500 4,159 99 123 20,000 22,281 0.50 1.00 0.60 30.00 2.00 0.157-11 30# Linear Flush 25.0 11,557 11,555 275 275 1.00 30.00 2.00 0.157-12 Shut-In Shut-In-Interval 4Narwhal@ 18243 - 18246.86 ft 83.5 °FInterval 6Narwhal@ 17492 - 17495.86 ft 83.4 °FInterval 7Narwhal@ 17095 - 17098.86 ft 83.4 °FInterval 5Narwhal@ 17889 - 17892.86 ft 83.5 °FConoco Phillips - CD4-588 Actual Design 6 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.29231755LEASECD4-588SALES ORDEBHST (°F)84LONG-150.9875829FORMATIONNarwalDATE Max Pressure (psi)6500Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)50-103-208530908772785Liquid Additives Dry Additives8-1 Shut-In Shut-In-8-2 Seawater Prime Up Pressure Test 5.0 1,000 756 18 180.158-3 Shut-In Shut-In-8-4 30# Linear Spacer and Ball Drop 15.0 1,260 776 18 18 1.00 30.00 1.50 0.158-5 30# Delta Frac Establish Stable Fluid 15.0 8,400 5,971 142 142 0.50 1.00 0.25 30.00 1.50 0.158-6 30# Delta Frac Pad 25.0 5,500 5,275 126 126 0.50 1.00 0.25 30.00 1.50 0.158-7 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 8,331 198 202 4,000 3,491 0.50 1.00 0.25 30.00 1.50 0.158-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 2,994 71 75 3,000 3,315 0.50 1.00 0.25 30.00 1.50 0.158-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,002 71 78 6,000 5,802 0.50 1.00 0.25 30.00 1.50 0.158-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 4,500 4,504 107 121 13,500 13,278 0.50 1.00 0.25 30.00 1.50 0.158-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,500 5,549 132 155 22,000 22,015 0.50 1.00 0.25 30.00 2.00 0.158-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,500 5,505 131 160 27,500 26,854 0.50 1.00 0.25 30.00 2.00 0.158-13 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,000 4,993 119 151 30,000 30,280 0.50 1.00 0.25 30.00 2.00 0.158-14 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,000 3,991 95 125 28,000 28,032 0.50 1.00 0.25 30.00 2.00 0.158-15 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,750 4,364 104 131 22,000 25,080 0.50 1.00 0.25 30.00 2.00 0.158-16 30# Delta Frac Spacer and Ball Drop 25.0 1,260 1,434 34 34 0.50 1.00 0.25 30.00 2.00 0.159-1 30# Delta Frac Pad 25.0 5,500 6,515 155 155 0.50 1.00 0.25 30.00 1.509-2 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 9,264 221 225 4,000 4,011 0.50 1.00 0.25 30.00 1.50 0.159-3 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,008 72 74 3,000 2,610 0.50 1.00 0.25 30.00 1.50 0.159-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,021 72 78 6,000 6,071 0.50 1.00 0.25 30.00 1.50 0.159-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 4,500 4,506 107 122 13,500 13,612 0.50 1.00 0.25 30.00 1.50 0.159-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,500 5,506 131 154 22,000 21,623 0.50 1.00 0.25 30.00 2.00 0.159-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,500 5,490 131 160 27,500 27,646 0.50 1.00 0.25 30.00 2.00 0.159-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,000 4,994 119 151 30,000 30,268 0.50 1.00 0.25 30.00 2.00 0.159-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,000 3,992 95 125 28,000 28,054 0.50 1.00 0.25 30.00 2.00 0.159-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,750 4,090 97 120 22,000 21,744 0.50 1.00 0.25 30.00 2.00 0.159-11 30# Linear Spacer and Dart Drop 25.0 1,260 1,503 36 36 1.00 30.00 2.00 0.1510-1 30# Linear Displace Dart to Seat 25.0 10,201 24,582 585 585 1.00 30.00 1.50 0.1510-2 30# Delta Frac Establish Stable Fluid 25.0 8,400 2,158 51 51 0.50 1.00 0.25 30.00 1.50 0.1510-3 30# Delta Frac Pad 25.0 5,500 6,383 152 152 0.50 1.00 0.25 30.00 1.50 0.1510-4 30# Delta Frac Proppant Laden Fluid 100M 0.50 25.0 8,000 8,724 208 210 4,000 1,925 0.50 1.00 0.25 30.00 1.50 0.1510-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,004 72 76 3,000 4,142 0.50 1.00 0.25 30.00 1.50 0.1510-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,189 76 82 6,000 5,980 0.50 1.00 0.25 30.00 1.50 0.1510-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 4,500 4,511 107 121 13,500 12,869 0.50 1.00 0.25 30.00 1.50 0.1510-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,500 5,496 131 154 22,000 21,849 0.50 1.00 0.25 30.00 2.00 0.1510-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,500 5,493 131 160 27,500 27,318 0.50 1.00 0.25 30.00 2.00 0.1510-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,000 5,001 119 151 30,000 29,728 0.50 1.00 0.25 30.00 2.00 0.1510-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,000 4,015 96 125 28,000 27,660 0.50 1.00 0.25 30.00 2.00 0.1510-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,750 4,423 105 132 22,000 25,109 0.50 1.00 0.25 30.00 2.00 0.1510-13 30# Linear Spacer and Dart Drop 25.0 1,260 1,287 31 31 1.00 30.00 2.00 0.1511-1 30# Linear Displace Dart to Seat 15.0 9,949 11,658 278 278 1.00 30.00 1.50 0.1511-2 30# Delta Frac Establish Stable Fluid 15.0 8,400 3,215 77 77 0.50 1.00 0.25 30.00 1.50 0.1511-3 30# Delta Frac Pad 25.0 5,500 6,045 144 144 0.50 1.00 0.25 30.00 1.50 0.1511-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 0.50 25.0 8,000 8,010 191 195 4,000 4,047 0.50 1.00 0.25 30.00 1.50 0.1511-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,009 72 75 3,000 2,963 0.50 1.00 0.25 30.00 1.50 0.1511-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,007 72 78 6,000 5,782 0.50 1.00 0.25 30.00 1.50 0.1511-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 4,500 4,502 107 121 13,500 13,077 0.50 1.00 0.25 30.00 1.50 0.1511-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,500 5,491 131 154 22,000 21,795 0.50 1.00 0.25 30.00 2.00 0.1511-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,500 5,507 131 160 27,500 27,006 0.50 1.00 0.25 30.00 2.00 0.1511-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,000 5,003 119 150 30,000 29,126 0.50 1.00 0.25 30.00 2.00 0.1511-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,000 4,004 95 124 28,000 27,362 0.50 1.00 0.25 30.00 2.00 0.1511-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,750 4,729 113 140 22,000 25,842 0.50 1.00 0.25 30.00 2.00 0.1511-13 30# Linear Spacer and Dart Drop 25.0 1,260 1,370 33 33 1.00 30.00 2.00 0.1512-1 30# Linear Displace Dart to Seat 25.0 9,699 11,287 269 269 1.00 30.00 1.5012-2 30# Delta Frac Establish Stable Fluid 25.0 8,400 3,161 75 75 0.50 1.00 0.25 30.00 1.50 0.1512-3 30# Delta Frac Pad 25.0 5,500 5,911 141 141 0.50 1.00 0.25 30.00 1.50 0.1512-4 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 0.50 25.0 8,000 8,012 191 195 4,000 4,200 0.50 1.00 0.25 30.00 1.50 0.1512-5 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 1.00 25.0 3,000 3,002 71 75 3,000 2,857 0.50 1.00 0.25 30.00 1.50 0.1512-6 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 2.00 25.0 3,000 3,067 73 79 6,000 5,506 0.50 1.00 0.25 30.00 1.50 0.1512-7 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 3.00 25.0 4,500 4,510 107 121 13,500 12,755 0.50 1.00 0.25 30.00 1.50 0.1512-8 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 4.00 25.0 5,500 5,478 130 153 22,000 21,405 0.50 1.00 0.25 30.00 2.00 0.1512-9 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 5.00 25.0 5,500 5,494 131 161 27,500 28,216 0.50 1.00 0.25 30.00 2.00 0.1512-10 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 6.00 25.0 5,000 4,973 118 152 30,000 31,963 0.50 1.00 0.25 30.00 2.00 0.1512-11 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 7.00 25.0 4,000 3,987 95 126 28,000 29,492 0.50 1.00 0.25 30.00 2.00 0.1512-12 30# Delta Frac Proppant Laden Fluid Wanli 20/40 Ceramic 8.00 25.0 2,750 6,939 165 212 22,000 43,718 0.50 1.00 0.25 30.00 2.00 0.1512-13 30# Linear Flush 25.0 10,329 10,290 245 245 1.00 30.00 2.00 0.1512-14 Shut-In Shut-In-865,948 915,538 21,799 23,931 1,972,560 2,007,676Interval 8Narwhal@ 16663 - 16666.86 ft 83.3 °FInterval 9Narwhal@ 16351 - 16354.86 ft 83.3 °FInterval 10Narwhal@ 15959 - 15961.05 ft 83.2 °FInterval 11Narwhal@ 15565 - 15567.05 ft 83.2 °FInterval 12Narwhal@ 15174 - 15176.05 ft 83.2 °FConoco Phillips - CD4-588 Actual Design 7 CUSTOMERConoco Phillips APIBFD (lb/gal)8.54LAT 70.29231755LEASECD4-588SALES ORDEBHST (°F)84LONG-150.9875829FORMATIONNarwalDATE Max Pressure (psi)6500Prop Slurry Design Clean Actual Clean Actual Clean Calculated Slurry Design Prop Calculated Prop BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total TotalCrosslinker Surfactant BufferInterval Number Description Description Description(ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (ppt) (ppt) (ppt)50-103-208530908772785Liquid Additives Dry AdditivesDesign Total (gal)Actual Total (gal)Design Total (lbs)Calculated Total (lbs)Ticket Total (lbs)BC-140X2 Losurf-300D MO-67 WG-36 OPTIFLO-HTE BE-6720,770 759,311 1,920,060 1,966,938 1,953,600(gal) (gal) (gal) (lbs) (lbs)(lbs)97,059 151,840 52,500 40,738 54,000 Initial Design Material Volume 360.4 817.8 180.2 24,534.9 1,416.2122.44,000 4,387 - - - Actual Design Material Volume 379.7 911.2 264.3 27,334.5 1,588.0134.7- - - Physical Material Volume Pumped 375 870 265 24884 1,580 135- - - - - Physical Material Volume Deviance -1% -5% 0% -9% 0% 0%- -** IFS numbers for proppant are taken from software calculations based on multiple variablesMicroMotion Volume Pumped 386 861 276 26,422 1,585 -- -** Proppant is billed from Weight Ticket volumesMicroMotion Volume Deviance 2% -6% 4% -3% 0% -- --Fluid Type30# Delta Frac30# LinearSeawaterFreeze Protect-Proppant TypeWanli 20/40 Ceramic100M-----Conoco Phillips - CD4-588 Actual Design 8 8/9/23 7:39 8/9/23 9:46 127 min 15.0 bpm 3,924 psi 5,287 psi -156 bbl 25.4 bpm 4,867 psi 4,477 psi 22.6 bpm 3,215 psi 3,250 psi 3,630 psi 1,781 hhp 772 psi 411 psi 780 psi 7.01 ppg 3 3 30 % 26 % 23 cP 76.7 F 86 Minifrac 24.300 bpm 2664 psi 3318 psi 25.1 bpm 2762 psi 3478 psi 3299 psi 0.756 psi/ft 2619 psi 2600 psi 2595 psi 197,750 lbs 6,630 lbs 204,380 lbs 204,380 lbs Total Proppant Pumped* : Average Visc: Average Temp: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Interval Summary CD4-588 - Narwal - Interval 1 Interval Summary Start Date/Time: End Date/Time: Average Missile Pressure: Open Well Pressure: Initial OA Pressure: 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: 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: Diagnostic method Pump Time: Pad Percentage Actual Wanli 20/40 Ceramic Pumped: Proppant Summary Minifrac Average Pressure: Minifrac Average DH Pressure: Minifrac Max Rate: ISDP: Final Fracture Gradient: Final 10 min: Conoco Phillips - CD4-588 Interval Summary 9 104,195 gal 2,481 bbls 51,771 gal 1,233 bbls 2,665 gal 63 bbls 19,199 gal 457 bbls 14,876 gal 354 bbls 71,657 gal 1,706 bbls 13,605 gal 324 bbls 2,830 gal 67 bbls 2,858 gal 68 bbls 4,955 gal 118 bbls 4,852 gal 116 bbls 6,478 gal 154 bbls 13,042 gal 311 bbls 1,614 gal 38 bbls 2,665 gal 63 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Sweep Volume: Spacer and Ball Drop Volume: Interval Status: Nathan Brzezinski James Campbell Baskoro Tejo Greg Clayton Alexander Bentz Minifrac - Treatment Volume: Fluid Summary (by fluid description) Fluid Summary (by stage description) Establish Stable Fluid Volume: Displace Ball to Seat Volume: Pad Volume: 30# Delta Frac Volume: 30# Linear Volume: Seawater Volume: Minifrac - Establish Fluid Volume: Proppant Laden Fluid Volume: Prior to starting interval 01, the arsenal sleeve, dfit and minifrac were pumped. Backup ball was dropped for interval 01 but when rate was reestablished to 15bpm the first ball landed. DFIT and minifrac were then pumped. Had to wait on the Drilling rig after completing the minifrac to pump stage 1. On 8/9 interval 01 was resumed, no ball was dropped to resume stage. Lost Blender tub when going to 4 ppg due to air from an empty tank. Completed Stage. With no other issues. *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. Minifrac - Flush Volume: DFIT Volume: Arsenal Sleeve Shift Volume: Step Rate Test Volume: Conoco Phillips - CD4-588 Interval Summary 10 8/9/23 9:46 8/9/23 11:25 99 min 10.8 bpm 5,446 psi 6,435 psi 4 bbl 30.1 bpm 3,898 psi 3,846 psi 24.8 bpm 3,046 psi 3,081 psi 3,467 psi 3,046 hhp 780 psi 788 psi 6.75 ppg 3 3 30 % 29 % 23 cP 78 F 8.7 204,787 lbs 5,827 lbs 210,614 lbs 210,614 lbs 86,517 gal 2,060 bbls 15,143 gal 361 bbls 68,764 gal 1,637 bbls 2,610 gal 62 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Status: While setting up to drop rate for the ball seat operator grabbed rate instead of dropping rate. Interval pumped to design. *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.Greg Clayton Alexander Bentz Nathan Brzezinski James Campbell Baskoro Tejo Wanli 20/40 Ceramic Pumped: 100M Pumped: Total Proppant Pumped* : 30# Delta Frac Volume: Proppant Laden Fluid Volume: Spacer and Ball Drop Volume: CD4-588 - Narwal - Interval 2 Proppant Summary Proppant in Formation: Fluid Summary (by fluid description) Fluid Summary (by stage description) 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: 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 Pad Volume: Conoco Phillips - CD4-588 Interval Summary 11 8/9/23 11:25 8/9/23 12:47 82 min 10.3 bpm 5,387 psi 5,907 psi 1 bbl 25.3 bpm 4,507 psi 3,927 psi 24.7 bpm 3,302 psi 3,340 psi 3,477 psi 1,996 hhp 788 psi 799 psi 7.69 ppg 3 3 30 % 31 % 24 cP 79.3 F 8.6 2847 psi 0.663 psi/ft 2600 psi 2479 psi 2566 psi 151,943 lbs 4,081 lbs 156,024 lbs 156,024 lbs 60,856 gal 1,449 bbls 12,502 gal 298 bbls 13,520 gal 322 bbls 47,336 gal 1,127 bbls 12,502 gal 298 bbls Completed Fluid Summary (by stage description) ISDP: Final Fracture Gradient: 30# Delta Frac Volume: Interval Status: CD4-588 - Narwal - 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: 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: 30# Linear Volume: 100M Pumped: Max OA Pressure: Max Proppant Concentration: Pad Percentage Design Pad Percentage Actual Average Visc: Interval Summary Initial OA Pressure: Proppant Laden Fluid Volume: Flush Volume: Proppant Summary Total Proppant Pumped* : Proppant in Formation: Fluid Summary (by fluid description) Pad Volume: Final 10 min: Final 15 min: Wanli 20/40 Ceramic Pumped: Conoco Phillips - CD4-588 Interval Summary 12 Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Alexander Bentz Nathan Brzezinski James Campbell Stage Completed without issues *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.Baskoro Tejo Greg Clayton Conoco Phillips - CD4-588 Interval Summary 13 8/10/23 13:12 8/10/23 15:33 141 min 10.2 bpm 4,141 psi 5,804 psi 9 bbl 25.4 bpm 4,145 psi 3,765 psi 21.9 bpm 2,735 psi 2,754 psi 3,259 psi 1,470 hhp 570 psi 628 psi 797 psi 7.84 ppg 3 3 30.1 % 30.7 % 24 cP 82.6 F 8.4 DFIT 155,130 lbs 3,381 lbs 158,511 lbs 158,511 lbs 68,022 gal 1,620 bbls 13,259 gal 316 bbls 966 gal 23 bbls 10,481 gal 250 bbls 9,982 gal 238 bbls 45,460 gal 1,082 bbls 2,508 gal 60 bbls 11,232 gal 267 bbls 1,618 gal 39 bbls Completed Proppant Laden Fluid Volume: Spacer and Ball Drop Volume: Fluid Summary (by fluid description) Seawater Volume: Fluid Summary (by stage description) Establish Stable Fluid Volume: Interval Status: Displace Ball to Seat Volume: Pad Volume: DFIT Volume: Proppant Summary Wanli 20/40 Ceramic Pumped: Total Proppant Pumped* : Pad Percentage Design Average Surface Pressure: Pumps Starting Stage: Diagnostic method 100M Pumped: Max OA Pressure: Max Proppant Concentration: Average Visc: Average Rate: Average Missile Pressure: Average BH Pressure: Average Missile HHP: Pumps Ending Stage: Pad Percentage Actual Max Surface Pressure: Initial BH Pressure (Breakdown): Pump Time: Open Well Pressure: Initial OA Pressure: Max BH Pressure: Initial Surface Pressure (Breakdown): End Date/Time: CD4-588 - Narwal - Interval 4 Interval Summary Start Date/Time: Dart/Ball Early : Max Rate: Average Temp: Average pH: 30# Delta Frac Volume: Initial Rate (Breakdown): Proppant in Formation: 30# Linear Volume: Conoco Phillips - CD4-588 Interval Summary 14 Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Baskoro Tejo Greg Clayton Keegan Lambe Nathan Brzezinski After injection through the wellhead was established ball was dropped via the acid pump. While displacing the ball issues with the IA pop-offs were noticed to be having issues holding pressure. Maintained IA pressure with little red until ball was seated. Pumped a DFIT post ball seat. IA pop-offs were adjusted while well was shut in for DFIT monitoring. After rate was established crosslink was established. Crosslink pH took significant adjustments to maintain target pH. Adjusted screws as needed to maintain concentration. Noted that switching back and forth effected the proppant concentration. Interval Pumped to design. 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. Conoco Phillips - CD4-588 Interval Summary 15 8/10/23 15:33 8/10/23 16:45 72 min 10.3 bpm 5,425 psi 6,239 psi -5 bbl 25.5 bpm 3,561 psi 3,666 psi 23.5 bpm 2,990 psi 3,025 psi 3,371 psi 1,724 hhp NA psi 792 psi 821 psi 7.42 ppg 3 3 30.0 % 35.9 % 23 cP 86 F 8.5 153,614 lbs 3,633 lbs 157,247 lbs 157,247 lbs 62,603 gal 1,491 bbls 14,172 gal 337 bbls 47,108 gal 1,122 bbls 1,323 gal 32 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: End Date/Time: Max BH Pressure: Average Surface Pressure: Interval Summary Proppant Summary Fluid Summary (by fluid description) Fluid Summary (by stage description) Wanli 20/40 Ceramic Pumped: 100M Pumped: CD4-588 - Narwal - Interval 5 Average BH Pressure: Initial OA Pressure: Max Proppant Concentration: Start Date/Time: Pad Percentage Design Average Rate: Proppant in Formation: Pad Volume: Keegan Lambe Average Missile HHP: Open Well Pressure: Average Visc: Max Surface Pressure: Pumps Starting Stage: Pumps Ending Stage: Nathan Brzezinski 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.Baskoro Tejo Greg Clayton Interval Status: Ball seat observed. Adjusted linear viscosity to maintain between 23-24cP. Held pad long to observe ball seat. Interval pumped to design. Proppant Laden Fluid Volume: 30# Delta Frac Volume: Average pH: Total Proppant Pumped* : Initial Rate (Breakdown): Spacer and Ball Drop Volume: Pump Time: Average Missile Pressure: Max OA Pressure: Initial BH Pressure (Breakdown): Dart/Ball Early : Average Temp: Initial Surface Pressure (Breakdown): Max Rate: Pad Percentage Actual Conoco Phillips - CD4-588 Interval Summary 16 8/10/23 16:45 8/10/23 17:50 65 min 10.2 bpm 5,422 psi 6,117 psi -7 bbl 25.6 bpm 3,147 psi 3,527 psi 24.2 bpm 2,835 psi 2,864 psi 3,226 psi 1,680 hhp NA psi 810 psi 812 psi 8.44 ppg 3 3 25.0 % 33.9 % 24 cP 86.2 F 8.5 152,795 lbs 3,921 lbs 156,716 lbs 156,716 lbs 59,151 gal 1,408 bbls 13,186 gal 314 bbls 44,420 gal 1,058 bbls 1,545 gal 37 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Pump Time: Initial Rate (Breakdown): Average Missile HHP: CD4-588 - Narwal - Interval 6 Interval Summary Average pH: Proppant Summary Fluid Summary (by fluid description) Fluid Summary (by stage description) Pumps Starting Stage: Max Rate: Average Missile Pressure: Average Rate: Interval Status: Pad held until ball seat observed. Interval pumped to design. Launched ball for interval 7 at rate. Keegan Lambe Nathan Brzezinski 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. Baskoro Tejo Greg Clayton Pad Percentage Design Pad Volume: Wanli 20/40 Ceramic Pumped: Open Well Pressure: Start Date/Time: Average Visc: Average Temp: Pumps Ending Stage: 30# Delta Frac Volume: Initial OA Pressure: Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Dart/Ball Early : Average BH Pressure: Proppant Laden Fluid Volume: End Date/Time: Max Surface Pressure: Max BH Pressure: Max OA Pressure: Proppant in Formation: Total Proppant Pumped* : Max Proppant Concentration: Pad Percentage Actual Spacer and Ball Drop Volume: 100M Pumped: Average Surface Pressure: Conoco Phillips - CD4-588 Interval Summary 17 8/10/23 17:50 8/10/23 18:48 58 min 10.2 bpm 5,390 psi 6,610 psi 0 bbl 25.6 bpm 2,972 psi 3,196 psi 24.9 bpm 2,627 psi 2,655 psi 3,095 psi 1,601 hhp NA psi 807 psi 829 psi 8.72 ppg 3 3 25 % 29.1 % 24 cP 91 F 85 2591 psi 0.609 psi/ft 2572 psi 2563 psi 2556 psi 152,868 lbs 3,838 lbs 156,706 lbs 156,706 lbs 52,215 gal 1,243 bbls 11,555 gal 275 bbls 7,019 gal 167 bbls 45,196 gal 1,076 bbls 11,555 gal 275 bbls Completed Max Proppant Concentration: Average Temp: Average Missile HHP: Average BH Pressure: Average Surface Pressure: Interval Status: Fluid Summary (by fluid description) 30# Delta Frac Volume: Interval Summary Final Fracture Gradient: ISDP: Average pH: Pad Percentage Actual Initial OA Pressure: Pad Percentage Design Pumps Starting Stage: Max Rate: Initial BH Pressure (Breakdown): Start Date/Time: CD4-588 - Narwal - Interval 7 End Date/Time: Dart/Ball Early : Final 5 min: Proppant Summary Open Well Pressure: Pumps Ending Stage: Final 10 min: Max OA Pressure: 30# Linear Volume: Wanli 20/40 Ceramic Pumped: Max Surface Pressure: Max BH Pressure: Average Rate: Average Missile Pressure: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): 100M Pumped: Final 15 min: Total Proppant Pumped* : Proppant in Formation: Proppant Laden Fluid Volume: Pump Time: Flush Volume: Pad Volume: Fluid Summary (by stage description) Average Visc: Conoco Phillips - CD4-588 Interval Summary 18 Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Started 100M per schedule. Interval pumped to design. Baskoro Tejo Greg Clayton Nathan Brzezinski James Campbell Keegan Lambe *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. Conoco Phillips - CD4-588 Interval Summary 19 8/11/23 8:13 8/11/23 9:37 84 min 10.1 bpm 4,730 psi 5,814 psi 4 bbl 25.6 bpm 3,187 psi 3,200 psi 24.1 bpm 2,505 psi 2,524 psi 3,021 psi 1,480 hhp 580 psi 436 psi 773 psi 8.51 ppg 3 3 25.5 % 24.8 % 23 cP 79.5 F 8.5 154,656 lbs 3,491 lbs 158,147 lbs 158,147 lbs 55,913 gal 1,331 bbls 776 gal 18 bbls 756 gal 18 bbls 5,275 gal 126 bbls 43,233 gal 1,029 bbls 2,210 gal 53 bbls 5,971 gal 142 bbls Completed Pad Percentage Actual 30# Linear Volume: Pad Volume: Pumps Starting Stage: Proppant Summary Wanli 20/40 Ceramic Pumped: 100M Pumped: Fluid Summary (by fluid description) Max OA Pressure: Pumps Ending Stage: Fluid Summary (by stage description) Average Temp: Pad Percentage Design Total Proppant Pumped* : Interval Status: Interval Summary CD4-588 - Narwal - Interval 8 Max Rate: Average Rate: Max Proppant Concentration: Average BH Pressure: Average pH: Proppant in Formation: Establish Stable Fluid Volume: Open Well Pressure: Initial OA Pressure: Average Missile Pressure: Initial BH Pressure (Breakdown): Initial Rate (Breakdown): Max Surface Pressure: End Date/Time: Pump Time: Average Missile HHP: Max BH Pressure: Dart/Ball Early : Spacer and Ball Drop Volume: Initial Surface Pressure (Breakdown): Start Date/Time: 30# Delta Frac Volume: Seawater Volume: Average Surface Pressure: Average Visc: Proppant Laden Fluid Volume: Conoco Phillips - CD4-588 Interval Summary 20 Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Keegan Lambe Nathan Brzezinski 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.Baskoro Tejo Greg Clayton Injection was established prior to dropping ball. Ball seat observed. Mixed new tote of MO-67 and tested prior to start of day. Adjusted LA on ADP to target a 24cP downhole viscosity. Conoco Phillips - CD4-588 Interval Summary 21 8/11/23 9:37 8/11/23 10:34 57 min 10.0 bpm 5,077 psi 6,221 psi 0 bbl 25.6 bpm 2,906 psi 3,075 psi 24.8 bpm 2,396 psi 2,417 psi 2,953 psi 1,456 hhp NA psi 773 psi 801 psi 8.53 ppg 3 3 25.5 % 27.8 % 25 cP 79 F 8.5 151,628 lbs 4,011 lbs 155,639 lbs 155,639 lbs 50,386 gal 1,200 bbls 1,503 gal 36 bbls 6,515 gal 155 bbls 43,871 gal 1,045 bbls 1,503 gal 36 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Summary Open Well Pressure: Proppant Summary Wanli 20/40 Ceramic Pumped: Fluid Summary (by fluid description) Fluid Summary (by stage description) Average pH: Spacer and Dart Drop Volume: 30# Delta Frac Volume: 30# Linear Volume: CD4-588 - Narwal - Interval 9 Average Missile Pressure: Pumps Ending Stage: Pad Volume: Average Missile HHP: Initial OA Pressure: Average Rate: 100M Pumped: Max Rate: Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Average BH Pressure: Start Date/Time: End Date/Time: Pump Time: Max Surface Pressure: Max BH Pressure: Initial Rate (Breakdown): Proppant in Formation: *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. Keegan Lambe Nathan Brzezinski Baskoro Tejo Greg Clayton Total Proppant Pumped* : Proppant Laden Fluid Volume: Average Temp: Max Proppant Concentration: Pumps Starting Stage: Average Surface Pressure: Pad Percentage Actual Average Visc: Pad Percentage Design James Campbell Interval Status: Interval pumped to design. Dart/Ball Early : Max OA Pressure: Conoco Phillips - CD4-588 Interval Summary 22 8/11/23 10:34 8/11/23 12:50 136 min 15.3 bpm 3,395 psi 4,487 psi 8 bbl 25.4 bpm 4,427 psi 5,139 psi 23.6 bpm 3,127 psi 3,159 psi 3,725 psi 1,807 hhp NA psi 801 psi 816 psi 8.78 ppg 3 3 25.5 % 26.6 % 25 cP 78.4 F 8.4 154,655 lbs 1,925 lbs 156,580 lbs 156,580 lbs 52,397 gal 1,248 bbls 25,869 gal 616 bbls 0 gal 0 bbls 24,582 gal 585 bbls 6,383 gal 152 bbls 43,856 gal 1,044 bbls 2,158 gal 51 bbls Completed Interval Summary Pump Time: Initial Surface Pressure (Breakdown): Max Rate: Total Proppant Pumped* : Proppant in Formation: Fluid Summary (by fluid description) 30# Linear Volume: Average Missile HHP: Open Well Pressure: Initial OA Pressure: Initial BH Pressure (Breakdown): Pad Percentage Actual Pumps Starting Stage: Dart/Ball Early : 30# Delta Frac Volume: Average Visc: Pad Percentage Design Max OA Pressure: Wanli 20/40 Ceramic Pumped: Fluid Summary (by stage description) Average pH: Average BH Pressure: Initial Rate (Breakdown): Start Date/Time: CD4-588 - Narwal - Interval 10 End Date/Time: Max Surface Pressure: Max BH Pressure: Pumps Ending Stage: Proppant Summary 100M Pumped: Interval Status: Average Temp: Max Proppant Concentration: Average Missile Pressure: Average Rate: Pad Volume: Establish Stable Fluid Volume: Proppant Laden Fluid Volume: Displace Dart to Seat Volume: Displace Ball to Seat Volume: Average Surface Pressure: Conoco Phillips - CD4-588 Interval Summary 23 Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Keegan Lambe Nathan Brzezinski 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.Baskoro Tejo Greg Clayton Signature observed 12.5bbl early. Hard shut down post seat for water analysis. Dropped back up dart and displaced in linear. Backup Dart seat observed. Significantly higher pressure during the pad/100M stage. Pumped fluid at reduced rate (21bpm) until pressure break was observed, Significant pressure relief when 100M hit. 100M bin ran empty after 1925lbs pumped, continued to pump 0.5ppg 20/40 in place. Conoco Phillips - CD4-588 Interval Summary 24 8/11/23 12:50 8/11/23 14:03 73 min 15.3 bpm 1,872 psi 3,101 psi 13 bbl 25.7 bpm 2,773 psi 2,997 psi 23.5 bpm 2,106 psi 2,123 psi 2,784 psi 1,211 hhp NA psi 795 psi 806 psi 8.22 ppg 3 3 25.5 % 25.3 % 24 cP 80.6 F 8.4 157,000 lbs 0 lbs 157,000 lbs 157,000 lbs 52,522 gal 1,251 bbls 13,028 gal 310 bbls 11,658 gal 278 bbls 6,045 gal 144 bbls 43,262 gal 1,030 bbls 1,370 gal 33 bbls 3,215 gal 77 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Fluid Summary (by stage description) Establish Stable Fluid Volume: Pad Volume: Spacer and Dart Drop Volume: Displace Dart to Seat Volume: Muted Dart seat observed. 20/40 plumped in place of 100M. Interval pumped to design. Interval Summary Proppant Summary Fluid Summary (by fluid description) Total Proppant Pumped* : Proppant in Formation: Pumps Ending Stage: Pump Time: Initial BH Pressure (Breakdown): Dart/Ball Early : 30# Delta Frac Volume: Interval Status: Average Missile HHP: CD4-588 - Narwal - Interval 11 Wanli 20/40 Ceramic Pumped: Average pH: Pad Percentage Actual Keegan Lambe Nathan Brzezinski 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. Baskoro Tejo Greg Clayton Pad Percentage Design Average Surface Pressure: Pumps Starting Stage: Max BH Pressure: Average Rate: Average BH Pressure: Max OA Pressure: 30# Linear Volume: Open Well Pressure: Initial OA Pressure: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): 100M Pumped: Average Temp: Average Visc: Max Surface Pressure: Average Missile Pressure: Proppant Laden Fluid Volume: Start Date/Time: Max Proppant Concentration: Max Rate: End Date/Time: Conoco Phillips - CD4-588 Interval Summary 25 8/11/23 14:03 8/11/23 15:29 86 min 15.3 bpm 1,781 psi 2,974 psi 13 bbl 25.7 bpm 2,922 psi 3,078 psi 21.0 bpm 2,180 psi 2,197 psi 2,868 psi 1,120 hhp NA psi 778 psi 778 psi 8.87 ppg 3 3 25.5 % 23.9 % 24 cP 77.9 F 8.4 2681 psi 0.637 psi/ft 2585 psi 2563 psi 2548 psi 180,112 lbs 0 lbs 180,112 lbs 180,112 lbs 54,534 gal 1,298 bbls 21,577 gal 514 bbls 11,287 gal 269 bbls 5,911 gal 141 bbls 45,462 gal 1,082 bbls 10,290 gal 245 bbls 3,161 gal 75 bbls Completed Pumps Starting Stage: Max Proppant Concentration: Pump Time: Start Date/Time: Average Rate: Average Missile Pressure: Final Fracture Gradient: Pad Percentage Actual Initial Rate (Breakdown): Average BH Pressure: Dart/Ball Early : Max BH Pressure: Max OA Pressure: Average Visc: CD4-588 - Narwal - Interval 12 Interval Summary Average pH: Max Rate: Open Well Pressure: Initial OA Pressure: Pumps Ending Stage: Pad Percentage Design Proppant Summary Fluid Summary (by fluid description) 30# Delta Frac Volume: Fluid Summary (by stage description) Final 5 min: Total Proppant Pumped* : 30# Linear Volume: Max Surface Pressure: End Date/Time: Initial BH Pressure (Breakdown): Average Missile HHP: Initial Surface Pressure (Breakdown): Proppant Laden Fluid Volume: Average Temp: Displace Dart to Seat Volume: Average Surface Pressure: Interval Status: Pad Volume: Proppant in Formation: 100M Pumped: ISDP: Final 10 min: Wanli 20/40 Ceramic Pumped: Final 15 min: Establish Stable Fluid Volume: Flush Volume: Conoco Phillips - CD4-588 Interval Summary 26 Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Dart was launched in Linear. Shut down post muted shift for water hammer analysis. Pumped all proppant remaining on location. Held 8ppg long until proppant was displaced. Keegan Lambe Nathan Brzezinski 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.Baskoro Tejo Greg Clayton Conoco Phillips - CD4-588 Interval Summary 27 CustomerFormationLeaseAPIDateWell SummaryWanli 20/40 Ceramic 100MTotal ProppantSurface Pressure Rate Visc Temp pH Surface Pressure Rate bbl gal bbl gal bbl gal bbl lbs lbs lbs13250 22.6 23 76.7 86.0 4867 25.4 2,481 51,771 1,233 2,665 63 158,631 3,777 197,750 6,630 204,380 23081 24.8 23 78 8.7 3898 30.1 2,060 86,517 2,060 204,787 5,827 210,614 33340 24.7 24 79 8.6 4507 25.3 1,449 12,502 298 73,358 1,747 151,943 4,081 156,024 42754 21.9 24 83 8.4 4145 25.4 1,620 13,259 316 966 23 82,247 1,958 155,130 3,381 158,511 53025 23.5 23 86 8.5 3561 25.5 1,491 62,603 1,491 153,614 3,633 157,247 62864 24.2 24 86 8.5 3147 25.6 1,408 59,151 1,408 152,795 3,921 156,716 72655 24.9 24 91 85.0 2972 25.6 1,243 11,555 275 63,770 1,518 152,868 3,838 156,706 82524 24.1 23 80 8.5 3187 25.6 1,331 776 18 756 18 57,445 1,368 154,656 3,491 158,147 92417 24.8 25 79 8.5 2906 25.6 1,200 1,503 36 51,889 1,235 151,628 4,011 155,639 103159 23.6 25 78 8.4 4427 25.4 1,248 25,869 616 78,266 1,863 154,655 1,925 156,580 112123 23.5 24 81 8.4 2773 25.7 1,251 13,028 310 65,550 1,561 157,000 157,000 122197 21.0 24 78 8.4 2922 25.7 1,298 21,577 514 76,111 1,812 180,112 180,112 Minimum1200 776 18 756 18 51889 1235 151628 1925 155639 Average1507 16871 402 1462 35 76295 1817 163912 4074 167306 Maximum2481 51771 1233 2665 63 158631 3777 204787 6630 210614 Wanli 20/40 Ceramic 100M Total ProppantPressure Rate Visc Temp pH Pressure Rate bbl gal bbl gal bbl gal bbl lbs lbs TotalPlanned17,161 97,059 2,311 4,000 95 821,829 19,567 1,928,060 44,500 1,972,560Recorded2782 23.6 24 81 #### 4867 30.1 18,079 151,840 3,615 4,387 104 915,538 21,799 1,966,938 40,738 2,007,676Weight Tickets1,953,600 54,000 2,007,600** Proppant is billed from Weight Ticket volumes** IFS numbers for proppant are taken from software calculations based on Total FluidFluids ProppantsFluids ProppantsTotal FluidAverage MaxSeawater30# Delta Frac 30# Linear30# Delta Frac 30# LinearIntervalAverage MaxSeawaterAugust 07, 202350-103-20853CD4-588NarwalConoco Phillips Conoco Phillips - CD4-588 Fluid System-Proppant Summary 28 Hydraulic Fracturing Fluid Product Component Information Disclosure 2023-08-07 Alaska Harrison Bay 50-103-20853 CONOCOPHILLIPS CD4 588 -150.9875 70.2923 NAD83 none Oil 4375 915538 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) Halliburton Base Fluid Water 7732-18-5 100.00%79.22322%7800384 Density = 8.52 Halliburton BC-140 X2 Halliburton Initiator Listed Below Listed Below 0 BE-6(TM) Bactericide Halliburton Microbiocide Listed Below Listed Below 0 LoSurf-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA LVT-200 Baker Hughes Additive Listed Below Listed Below 0 NA MO-67 Halliburton pH Control Listed Below Listed Below 0 OPTIFLO-HTE Halliburton Breaker Listed Below Listed Below 0 NA SP BREAKER Halliburton Breaker Listed Below Listed Below 0 WG-36 GELLING AGENT Halliburton Gelling Agent Listed Below Listed Below 0 Ceramic Proppant - Wanli Wanli Proppant Listed Below Listed Below 0 NA Sand-Common White-100 Mesh, SSA-2 Halliburton Proppant Listed Below Listed Below 0 GPT 3000-3014 ResMetrics Tracer Listed Below Listed Below 0 NA OPT 2000-2050 ResMetrics Tracer Listed Below Listed Below 0 NA WPT 1000-1050 ResMetrics Tracer Listed Below Listed Below 0 NA Ingredients Listed Above Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00067%67 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00004%4 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00137%135 C.I. Pigment Red 5 6410-41-9 1.00%0.00016%16 Confidential Proprietary 10.00%0.00010%10 ResMetrics Product Stewardship info@resmetr ics.com 8325921900 Confidential Proprietary 100.00%0.00203%200 ResMetrics Product Stewardship info@resmetr ics.com 8325921900 Corundum 1302-74-5 65.00%12.89691%1269840 Crystalline silica, quartz 14808-60-7 100.00%0.55326%54474 Cured acrylic resin Proprietary 1.00%0.00016%16 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 Distillates (petroleum), hydrotreated light 64742-47-8 100.00%0.00000%0 Ethanol 64-17-5 60.00%0.04029%3968 Ethylene glycol 107-21-1 30.00%0.01161%1143 Glycol Ether Proprietary 85.00%0.00083%82 ResMetrics Product Stewardship info@resmetr ics.com 8325921900 Guar gum 9000-30-0 100.00%0.25273%24884 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.02015%1984 Hemicellulase 9025-56-3 5.00%0.00080%79 Monoethanolamine borate 26038-87-9 100.00%0.03870%3810 Mullite 1302-93-8 45.00%8.92863%879120 Naphthalene 91-20-3 5.00%0.00336%331 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02015%1984 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Oxyalkylated phenolic resin Proprietary 10.00%0.00672%662 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00336%331 Polyamine Proprietary 30.00%0.00481%474 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Propylene Glycol 57-55-6 20.00%0.00020%20 Sodium chloride 7647-14-5 5.00%3.96123%390027 Sodium hydroxide 1310-73-2 30.00%0.00214%211 Sodium persulfate 7775-27-1 100.00%0.00000%0 Sodium sulfate 7757-82-6 0.10%0.00000%0 Walnut hulls NA 100.00%0.01605%1580 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Water 7732-18-5 100.00%0.01955%1925 * 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 1.3 All component information listed was obtained from the suppliers 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 Administrations (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: Page 1/1Procedure CloseoutCD4-588Primary Job TypeSUPPORT OTHER OPERATIONSStart Date8/3/2023End Date8/13/2023Final Job StatusCOMPLETEDTotal Time Log Hours (hr)180.96SummaryNetwork/Order Number Project Desc Estimator10451714 CD4-588 - Frac - FracStart Date ZX Code Time Log Hrs (hr)Cum Time Log (days) Last 24hr Sum8/3/2023 ZX02 Fracturing 12.00 0.50 RIGGED GOATHEAD & 4" IRON TO WELLHEAD. READY TO INSTALL LAUNCHER.8/4/2023 ZX02 Fracturing 12.00 1.00 GNWF RIGGED UP LAUNCHER & LAUNCH VALVES. WELL SUPPORT RIGGED UP IA, OA & FLOWLINE. IN PROGRESS8/5/2023 ZX02 Fracturing 12.00 1.50 HAL->> RUN ALL TRANSDUCER CABLES & CHECK COMMS. RIG UP BALL LAUNCH PUMP. SLB REP HOOKED UP DHG.LOIL ->> HEAT WATER IN ALL 20 TANKS TO 90 DEGREES. FINISH INSTALLING ALL RESTRIANTS. WELL SUPPORT ->> RIG UP BALL LAUNCH LINE AND INSTALL REDRESSED MECHANICAL PRV'S & PRESSURE TESTED 2" IRON.IN PROGRESS8/6/2023 ZX02 Fracturing 17.99 2.25 PREP EQUIPMENT TO PUMP WHILE WAITING ON EPRV'S, BALLS & TRACER TO BE FLOWN OVER. INSTALL EPRV'S & PRESSURE TEST FRAC TO 7500 PSI **GOOD TEST**. IN PROGRESS8/7/2023 ZX02 Fracturing 23.99 3.25 SHEAR INTERWELL GLASS DISC. DELAYED START WAITING ON DISPENSATION WITH DRILLING OPS ON OFFSET WELL.LAUNCHED PRIMARY BALL FOR STAGE #1, NO SEAT OBSERVED. DROP BACK UP BALL FOR STAGE #1, SAW PRIMARY BALL LAND 157 BBLS LATE.PERFORM DFIT, SRT & MINI FRAC. IN PROGRESS8/8/2023 ZX02 Fracturing 18.00 4.00 UNABLE TO PUMP DUE TO THE RIG TROUBLESHOOTING MPD SYSTEM & THE BHA IS OFF BOTTOM. PER THE DISPENSTATION, WE WON'T FRAC UNLESS THE BHA IS ON BOTTOM. IN PROGRESS 8/9/2023 ZX02 Fracturing 18.99 4.79 STIMULATE STAGE #1 (**HAD WATER ISSUE GOING INTO 4 PPG**) PUMPED 6630 LBS OF 100 MESH & 197,750 LBS OF 20/40 PROPPANT UP TO 7.01 PPG. (RESMETRIC TRACER ADDED PER SCHEDULE)STIMULATE STAGE #2 PER DESIGN w/ 5827 LBS OF 100 MESH & 204,787 LBS OF 20/40 PROPPANT UP TO 6.75 PPG. (RESMETRIC TRACER ADDED PER SCHEDULE)STIMULATE STAGE #3 PER DESIGN w/ 4081 LBS OF 100 MESH & 151,943 LBS OF 20/40 PROPPANT UP TO 7.69 PPG. (RESMETRIC TRACER ADDED PER SCHEDULE). IN PROGRESS8/10/2023 ZX02 Fracturing 23.99 5.79 **DELAYED START DUE EQUIPMENT MAINTENANCE**PUMP DFIT IN STAGE #4STIMULATE STAGE #4 PER DESIGN w/ 3381 LBS OF 100 MESH & 155,130 LBS OF 20/40 PROPPANT UP TO 7.84 PPG. (RESMETRIC TRACER ADDED PER SCHEDULE)STIMULATE STAGE #5 PER DESIGN w/ 3633 LBS OF 100 MESH & 153,604 LBS OF 20/40 PROPPANT UP TO 7.42 PPG. (RESMETRIC TRACER ADDED PER SCHEDULE)STIMULATE STAGE #6 PER DESIGN w/ 3921 LBS OF 100 MESH & 152,795 LBS OF 20/40 PROPPANT UP TO 8.44 PPG. (RESMETRIC TRACER ADDED PER SCHEDULE)STIMULATE STAGE #7 PER DESIGN w/ 3838 LBS OF 100 MESH & 152,868 LBS OF 20/40 PROPPANT UP TO 8.72 PPG. (RESMETRIC TRACER ADDED PER SCHEDULE). IN PROGRESS8/11/2023 ZX02 Fracturing 18.00 6.54 STIMULATE STAGE #8 PER DESIGN w/ 3491 LBS OF 100 MESH & 154,656 LBS OF 20/40 PROPPANT UP TO 8.51 PPG. STIMULATE STAGE #9 PER DESIGN w/ 4011 LBS OF 100 MESH & 154,655 LBS OF 20/40 PROPPANT UP TO 8.53 PPG.**ADVANCED UPSTREAM DART STAGES**LAUNCH PRIMARY AU DART. SEE MUTED SEAT. PUMP BACK UP DART & SEE SLEEVE SHIFT. STIMULATE STAGE #10 (**RAN OUT OF 100 MESH ~10K LBS EARLY. SUBSTITUE w/ 0.5 PPG OF 20/40) PUMPED 1925 LBS OF 100 MESH & 154,655 LBS OF 20/40 PROPPANT UP TO 8.78 PPG. STIMULATE STAGE #11 (NO 100 MESH) PUMP 157,000 LBS OF 20/40 PROPPANT UP TO 8.4 PPG.STIMULATE STAGE #12 (NO 100 MESH) PUMP 180,112 LBS OF 20/40 PROPPANT UP TO 8.87 PPG. 24,000 LBS OVER DESIGNRESMETRIC TRACER ADDED TO EACH STAGE PER DESIGN. FRAC COMPLETE.8/12/2023 ZX02 Fracturing 12.00 7.04 RIG DOWN LAUNCHER AND FRONT YARD WITH CRANE. RIG DOWN EPRV MANIFOLD, 3" IRON & 4" IRON BACK TO MISSILE. ROAD PUMPS, BLENDER & ADP TO MT6. IN PROGRESS8/13/2023 ZX02 Fracturing 12.00 7.54 RIGGED DOWN CASTLES & TANK FARM. JOB COMPLETE TTT RR AA NN SS MM II TT TT AA LL FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: CD4-588 Permit: 223-029 DATE: 08/14/2023 Transmitted: North Slope, Colville River Unit, Alaska Via SFTP upload Mud log data Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: CD4-588 e-transmittal well folder Receipt: Date: Alaska/IT-Data Support |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 PTD: 223-029 T37930 8/15/2023Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.15 09:18:13 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 8. Date TD Reached: 16. Well Name and Number: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 18.9 BF: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 19. DNR Approval Number: Surface: Zone- 4 TPI: Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20" X65 133'50bbl 13-3/8 L-80 2405' 9-5/8" T-95 3479' 7-5/8" L-80 4059' 4 1/2" P11OS 4366' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Liner (7/1/2023): 13109'MD/3860'TVD - 19680'MD/4366'TVD Gas-Oil Ratio:Choke Size: suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, 54' 54' Per 20 AAC 25.283 (i)(2) attach electronic information 47 14226' 52' 3457' 154 68 133' 52' 10126' SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 13109' 42" 12.6 Colville River Field/ Narwhal Undefined Oil Pool ADL384211, ADL380081 LONS 97-007 54' 30 54' 9919' 2765' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): WT. PER FT.GRADE CEMENTING RECORD 1279'MD/1279'TVD SETTING DEPTH TVD TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 7/7/2023 223-029 50-103-20853-00-00 CRU CD4-588 5/19/2023 N/A 72.9 P.O.Box 100360, Anchorage, AK 99510-0360 6/25/2023 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Tail: 124.5bbl 15.8ppg Class G 8.5"x9 7/8" TUBING RECORD 19680' Lead: 175.5 bbl 15.8ppg Class G 3860' 12-1/4" 6.5' 13116'4.5 12951'MD/3833' TVD 13123'MD/3863' TVD BOTTOM 16" Lead: 395bbl 11ppg Class G Tail: 72bbl 15.8ppg Class G CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 11. Total Depth MD/TVD: 20427'MD/4376'TVD 4a. Location of Well (Governmental Section): Surface: 2456' FSL, 162' FWL S19 T11N R5E Top of Productive Interval: 2222' FSL, 1682' FWL S21 T11N R5E Total Depth:2225' FSL,4722' FWL S28 T11N R5E x- 378408 x- 390165 x- 393140 y- 5957581 y-5957166 y- 5951846 Completed 7/7/2023 JSB RBDMS JSB 090623 G mudlog Received 8/8/2023 DSR-9/11/23VTL 9/21/2023 SFD 9/20/2023 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1279 1279 C-40 2463 2213 2835 2835 3743 2763 C-10 6451 6451 K3 13049 3849 14314 4075 20427 4376 31. List of Attachments: Directional Survey, Well Schematic, Cement Operations, Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Digital Signature with Date: General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. C-30 Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS C-20 If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Formation Name at TD: Narwhal Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Top of Productive Interval: Narwhal Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Contact Name:Jenna Taylor Contact Email:jenna.l.taylor@conocophillips.com Contact Phone:907-263-4522 Authorized Title: Wells Analyst Digitally signed by Jenna TaylorDN: CN=Jenna Taylor, E=jenna.l.taylor@conocophillips.com Reason: I am the author of this document Location: Date: 2023.09.05 10:44:51-08'00' Foxit PDF Editor Version: 12.1.2 Jenna Taylor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:CD4-588 8/1/2023 oberr 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 54.4 133.4 133.4 154.19 X65 Surface 13 3/8 12.42 54.4 2,764.5 2,404.6 68.00 L80 HYD563 Intermediate 1 9 5/8 8.68 51.6 10,125.7 3,479.4 47.00 T95 H563 Intermediate 2 7 5/8 6.88 9,918.5 14,225.5 4,059.2 29.70 L-80 TSH 523 Liner 4 1/2 3.96 13,109.3 19,680.4 4,365.6 12.60 P110S H563 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 0.0 Set Depth … 13,115.5 Set Depth … 3,861.1 String Ma… 4 1/2 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) 49.2 49.2 0.00 Hanger 11.000 FMC 4-1/2" Tubing Hanger Hydril HYD 563 Min ID 3.92" FMC TC-EMS 3.958 1,353.2 1,333.5 22.42 Nipple - DB, XN, DS, D 4.500 NIPPLE,LANDING,4 1/2","X",3.813", H563 HES X Nipple 3.813 3,232.1 2,630.6 68.73 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM w/ DCK-2 SOV @ 2K, 12.6# H563 BEK Latch Camco KBG4-5 3.865 12,758.5 3,800.2 80.62 Sleeve - Sliding 4.500 Sliding Sleeve, CMD, 4.5" x 3.813" GX profile, Vam Top, Down to open Baker Nexo-2 3.813 12,818.4 3,810.2 80.22 Mandrel 4.500 4-1/2" x 1" KBG4-5 GLM w/ Dummy Valve, 12.6# H563 BK Latch Camco KBG4-5 3.865 12,886.1 3,821.7 80.25 Gauge / Pump Sensor 4.500 Schlumberger Downhole Gauge Mandrel 4-1/2 w/ Metris Evolve Single Gauge, 12.6# H563 1044021 49 3.920 12,951.2 3,832.7 80.26 PACKER 4.500 HAL TNT Packer,PN 713TNT7517-Z 7-5/8", 26.4#-39#, 4 1/2, 12.6# VAM TOP HES TNT 3.856 13,021.1 3,844.6 80.15 Nipple - DB, XN, DS, D 4.500 NIPPLE,LANDING,4 1/2","DB",3.750", H563 SLB DB-6 nipple 3.750 13,084.2 3,855.6 79.84 Sub - Shear Out - SOS 5.750 Interwell IRBD-PO, 4-1/2, 4140, H563 3.910 13,106.6 3,859.5 79.72 Locator 5.290 Mechanical Locator (6.4" OD) Baker 3.900 13,107.2 3,859.7 79.72 Locator 5.630 Mechanical locator shear sub (Shear screws 1.00' below locator) Baker 3.900 13,112.2 3,860.5 79.71 Shoe - Mule 4.500 HES Self orienting mule shoe HES 4.120 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) 3,232.1 2,630.6 68.73 1 PROD DMY 1 0.0 8/1/2023 0.000 12,818.4 3,810.2 80.22 2 PROD DMY 1 0.0 7/7/2023 SLB 0.000 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) 13,123.2 3,862.5 79.71 Packer 6.400 Baker SLZXP (HRD-E) Packer SLZXP LTP H29647004 8 4.800 13,131.7 3,864.0 79.71 Nipple - RS 6.050 RS Nipple R/S Nipple 10553458 4.260 13,134.0 3,864.4 79.72 XO Reducing 5.530 Crossover 5-1/2" H563 pin x 4- 1/2" 12.6# H563 pin, 110 MYS material 3.910 13,994.6 4,018.8 79.91 Packer - Swell 4.500 Baker Oil Swell Packer #B15, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.950 14,256.4 4,064.5 80.21 Packer - Swell 4.500 Baker Oil Swell Packer #B14, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.960 14,400.9 4,089.5 79.98 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #5, 4-1/2" 12.6# C110 HYD563 Advance d Upstrea m 107343- 000060 3.505 14,597.2 4,123.6 80.07 Packer - Swell 4.500 Baker Oil Swell Packer #B13, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.950 14,825.9 4,163.2 80.08 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #4, 4-1/2" 12.6# C110 HYD563 Advance d Upstrea m 107343- 000055 3.505 14,988.4 4,189.3 81.81 Packer - Swell 4.500 Baker Oil Swell Packer #B12, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.980 15,174.8 4,209.9 85.60 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #3, 4-1/2" 12.6# C110 HYD563 Advance d Upstrea m 107343- 000046 3.505 15,380.8 4,218.7 88.78 Packer - Swell 4.500 Baker Oil Swell Packer #B11, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.980 15,565.7 4,222.4 88.84 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #2, 4-1/2" 12.6# C110 HYD563 Advance d Upstrea m 107343- 000043 3.505 15,773.6 4,225.4 89.95 Packer - Swell 4.500 Baker Oil Swell Packer #A10, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.970 CD4-588, 8/2/2023 9:20:49 AM Vertical schematic (actual) Liner; 13,109.3-19,680.4 Intermediate 2 ; 9,918.5- 14,225.5 Nipple - DB, XN, DS, D; 13,021.1 PACKER; 12,951.1 Mandrel; 12,818.4 Sleeve - Sliding; 12,758.5 Intermediate 1; 51.6-10,125.7 Mandrel; 3,232.1 Surface; 54.4-2,764.5 Nipple - DB, XN, DS, D; 1,353.2 Conductor; 54.4-133.4 Hanger; 49.2 WNS PROD KB-Grd (ft) 54.02 RR Date 7/7/2023 Other Elev… CD4-588 ... TD Act Btm (ftKB) 20,427.0 Well Attributes Field Name NARWHAL Wellbore API/UWI 501032085300 Wellbore Status PROD Max Angle & MD Incl (°) 90.39 MD (ftKB) 17,547.41 WELLNAME WELLBORECD4-588 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) 15,959.9 4,225.4 89.84 Sleeve - Frac 5.000 Advanced Upstream frac sleeve #1, 4-1/2" 12.6# C110 HYD563 Advance d Upstrea m 107343- 000041 3.505 16,168.9 4,226.2 89.00 Packer - Swell 4.500 Baker Oil Swell Packer #A9, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.960 16,351.5 4,232.4 87.79 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #9, 4-1/2" 12.6# C110 HYD563, ball OD 3.284" Frac sleeve H80934000 8 3.700 16,521.1 4,238.8 87.33 Packer - Swell 4.500 Baker Oil Swell Packer #A8, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.980 16,663.4 4,245.3 87.85 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #8, 4-1/2" 12.6# C110 HYD563, ball OD 3.241" Frac sleeve H80934000 9 3.710 16,828.4 4,249.9 88.57 Packer - Swell 4.500 Baker Oil Swell Packer #A7, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.970 17,095.8 4,257.3 88.50 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #7, 4-1/2" 12.6# C110 HYD563, ball OD 3.197" Frac sleeve H80934001 0 3.710 17,306.9 4,261.0 89.56 Packer - Swell 4.500 Baker Oil Swell Packer #A6, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.990 17,492.1 4,261.4 90.29 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #6, 4-1/2" 12.6# C110 HYD563, ball OD 3.154" Frac sleeve H80934001 1 3.710 17,661.5 4,260.9 89.58 Packer - Swell 4.500 Baker Oil Swell Packer #A5, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.960 17,889.3 4,267.3 88.04 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #5, 4-1/2" 12.6# C110 HYD563, ball OD 3.112" Frac sleeve H80934001 2 3.700 18,056.4 4,271.4 88.94 Packer - Swell 4.500 Baker Oil Swell Packer #A4, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.980 18,243.0 4,275.2 88.90 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #4, 4-1/2" 12.6# C110 HYD563, ball OD 3.070" Frac sleeve H80934001 3 3.700 18,453.9 4,281.8 87.14 Packer - Swell 4.500 Baker Oil Swell Packer #A3, 4- 1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.950 18,640.3 4,293.5 86.13 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #3, 4-1/2" 12.6# C110 HYD563, ball OD 3.028" Frac sleeve H80934001 4 3.710 18,851.4 4,309.0 84.84 Packer - Swell 4.500 Baker Oil Swell Packer #2, 4-1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.950 19,037.7 4,328.1 83.91 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #2, 4-1/2" 12.6# C110 HYD563, ball OD 2.987" Frac sleeve H80934001 5 3.700 19,245.4 4,348.6 84.63 Packer - Swell 4.500 Baker Oil Swell Packer #1, 4-1/2" 12.6# P110S HYD563 (with Hydroform 4.5 x 5.75) Baker 3.960 19,429.2 4,361.6 87.60 Sleeve - Frac 5.660 Baker Hughes CMB 2 frac sleeve #1, 4-1/2" 12.6# C110 HYD563, ball OD 2.598" Frac sleeve H80934002 5 3.710 CD4-588, 8/2/2023 9:20:52 AM Vertical schematic (actual) Liner; 13,109.3-19,680.4 Intermediate 2 ; 9,918.5- 14,225.5 Nipple - DB, XN, DS, D; 13,021.1 PACKER; 12,951.1 Mandrel; 12,818.4 Sleeve - Sliding; 12,758.5 Intermediate 1; 51.6-10,125.7 Mandrel; 3,232.1 Surface; 54.4-2,764.5 Nipple - DB, XN, DS, D; 1,353.2 Conductor; 54.4-133.4 Hanger; 49.2 WNS PROD CD4-588 ... WELLNAME WELLBORECD4-588 Page 1/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/8/2023 00:00 5/8/2023 07:00 7.00 MIRU, MOVE MOB P Continue preparing rig for move to CD4, clean all interconnects, blow down steam & water system.Move motor complex & spot out of way. Rig down pipe shed and move away from sub base. Continue with drill floor skid check list. Rig down CPU & prep to move out of the way of pits complex. 0.0 0.0 5/8/2023 07:00 5/8/2023 10:00 3.00 MIRU, MOVE MOB P Complete pre-skid check list. Skid drill floor into transport position. Lock down skid rams. 0.0 0.0 5/8/2023 10:00 5/8/2023 11:00 1.00 MIRU, MOVE MOB P Unpin sub base from BOP module. 0.0 0.0 5/8/2023 11:00 5/8/2023 12:00 1.00 MIRU, MOVE MOB P Jack up sub base & remove rig mats from under front of sub. 0.0 0.0 5/8/2023 12:00 5/8/2023 16:00 4.00 MIRU, MOVE MOB P Drive sub base away from BOP module & spot at the entrance of the pad. 0.0 0.0 5/8/2023 16:00 5/8/2023 18:00 2.00 MIRU, MOVE MOB P Install transport tongue on BOP module. Walk CPU away from pits module. Transition wheels on CPU to move position. 0.0 0.0 5/8/2023 18:00 5/8/2023 20:00 2.00 MIRU, MOVE MOB P Prep sub base to begin move to CD4. 0.0 0.0 5/8/2023 20:00 5/9/2023 00:00 4.00 MIRU, MOVE MOB P Move sub base from CD2 to CD4 about a quarter mile from intersection. 0.0 0.0 5/9/2023 00:00 5/9/2023 09:00 9.00 MIRU, MOVE MOB T Observed large bubble on side wall of front ODS tire on sub base. Mobilize spare tire & tire crew. Replace tire, torque all nuts to spec, & inflate to 125 psi. 0.0 0.0 5/9/2023 09:00 5/9/2023 10:00 1.00 MIRU, MOVE MOB P Continue moving sub base to CD4. 0.0 0.0 5/9/2023 10:00 5/9/2023 11:00 1.00 MIRU, MOVE MOB P Shuffle mats to cover bridges. Add gravel fill on edges of mats for transition. 0.0 0.0 5/9/2023 11:00 5/9/2023 17:00 6.00 MIRU, MOVE MOB P Continue moving sub base towards CD4, stopping at guard shack at CD4 / CD5 intersection. 0.0 0.0 5/9/2023 17:00 5/9/2023 20:00 3.00 MIRU, MOVE MOB P Park sub base at CD4 / CD5 intersection. Shuffle mats from behind sub base to CD4 access road, between guard shack and CD4 pad. 0.0 0.0 5/9/2023 20:00 5/9/2023 22:00 2.00 MIRU, MOVE MOB P Continue moving sub base towards CD4, from guard shack at CD4 / CD5 intersection to CD4 pad. Pull onto CD4 and stage sub base for other modules to move in. 0.0 0.0 5/9/2023 22:00 5/10/2023 00:00 2.00 MIRU, MOVE MOB P Prepare motor & pump modules to move from CD2 to CD4. 0.0 0.0 5/10/2023 00:00 5/10/2023 03:00 3.00 MIRU, MOVE MOB P Move motor & pump modules from CD2 to CD4 & stage the same. 0.0 0.0 5/10/2023 03:00 5/10/2023 08:00 5.00 MIRU, MOVE MOB P Prepare BOP & pit modules for move. Hook up trucks to modules. Hoist out riggers & pull off CD2-361. Pin braces. 0.0 0.0 5/10/2023 08:00 5/10/2023 09:00 1.00 MIRU, MOVE MOB P Move BOP & pit modules near intersection of CD2 access road & CD4 road. 0.0 0.0 5/10/2023 09:00 5/10/2023 10:00 1.00 MIRU, MOVE MOB P Wait for aviation clearance. 0.0 0.0 5/10/2023 10:00 5/10/2023 12:00 2.00 MIRU, MOVE MOB P Move BOP & pit modules to CD4 and stage in front of CD4-588. 0.0 0.0 5/10/2023 12:00 5/10/2023 13:00 1.00 MIRU, MOVE MOB P Lay out rig mats & 3" X 12" wood around CD4-588 for BOP module & sub base. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 2/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/10/2023 13:00 5/10/2023 14:00 1.00 MIRU, MOVE MOB P Move pipe shed module & CPU near intersection of CD2 access road & CD4 road. 0.0 0.0 5/10/2023 14:00 5/10/2023 15:30 1.50 MIRU, MOVE MOB P Wait for aviation clearance. 0.0 0.0 5/10/2023 15:30 5/10/2023 18:00 2.50 MIRU, MOVE MOB P Move pipe shed module & CPU to CD4 and stage. 0.0 0.0 5/10/2023 18:00 5/11/2023 00:00 6.00 MIRU, MOVE MOB P Spot BOP module over CD4-588. Move sub base from staging area and begin to mate up with BOP module. 0.0 0.0 5/11/2023 00:00 5/11/2023 02:00 2.00 MIRU, MOVE MOB P Continue spotting mating up sub base with BOP module. Remove gravel from under off drillers side out rigger. 0.0 0.0 5/11/2023 02:00 5/11/2023 04:30 2.50 MIRU, MOVE MOB P Set out riggers into position and lower to ground. Pin out riggers in place and adjust setback rams to 500 psi. 0.0 0.0 5/11/2023 04:30 5/11/2023 06:00 1.50 MIRU, MOVE MOB P Skid rig floor into drill position. Install all hand rails. Adjust set back rams to 500 psi. 0.0 0.0 5/11/2023 06:00 5/11/2023 07:30 1.50 MIRU, MOVE MOB P Spot pit module next to sub base. Begin hooking up pit / sub base interconnects. 0.0 0.0 5/11/2023 07:30 5/11/2023 09:30 2.00 MIRU, MOVE MOB P Spot pump module & walk into place next to pit module. Begin hooking up pump module / pit module interconnects. 0.0 0.0 5/11/2023 09:30 5/11/2023 10:30 1.00 MIRU, MOVE MOB P Spot CPU & motor module. 0.0 0.0 5/11/2023 10:30 5/11/2023 13:00 2.50 MIRU, MOVE MOB P Spot pipe shed module and walk into place. Shim pipe shed to level. 0.0 0.0 5/11/2023 13:00 5/11/2023 14:00 1.00 MIRU, MOVE MOB P Continue hooking up interconnects throughout the rig. 0.0 0.0 5/11/2023 14:00 5/11/2023 15:00 1.00 MIRU, MOVE MOB P Walk CPU into place. 0.0 0.0 5/11/2023 15:00 5/11/2023 18:00 3.00 MIRU, MOVE RURD P Continue to hook up interconnects throughout the rig & begin rig acceptance checklist. Rig on highline power at 17:20 hrs. 0.0 0.0 5/11/2023 18:00 5/11/2023 21:30 3.50 MIRU, MOVE RURD P Continue working on rig acceptance checklist. Putting steam system on line for each module. Hooking up air to each module. Fill rig water tank & line up to each module. Continue with interconnects. 0.0 0.0 5/11/2023 21:30 5/12/2023 00:00 2.50 MIRU, MOVE RURD P Stage crane and liner hanger shuttle. Lift and set shuttle. Remove steam generator exhaust stack with crane. SIMOPS rig acceptance check list. 0.0 0.0 5/12/2023 00:00 5/12/2023 00:30 0.50 MIRU, MOVE RURD P Finish removing exhaust stack from steam generator with the crane. SIMOPS work on rig acceptance check list. 0.0 0.0 5/12/2023 00:30 5/12/2023 01:30 1.00 MIRU, MOVE SFTY P Conduct AAR with the crew reviewing rig move from CD2. 0.0 0.0 5/12/2023 01:30 5/12/2023 06:00 4.50 MIRU, MOVE RURD P Work on initiating steam, water & air to each module. Continue working on rig acceptance check list. Ensure all outside landings & handrails in place. Clean the rig modules from rig move. 0.0 0.0 5/12/2023 06:00 5/12/2023 07:00 1.00 MIRU, MOVE SFTY P Conduct AAR with the crew reviewing rig move from CD2. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 3/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/12/2023 07:00 5/12/2023 12:00 5.00 MIRU, MOVE RURD P Finish initiating steam, water & air to the drill module. Install new air boot to the chute in the CPU. Inventory shaker screens & install. Test run auger. Test cellar trash pump. Perform pre-spud derrick inspection. Clean up tools & equipment through out the rig from moving. Rig acceptance check list completed at 12:00 hrs. 0.0 0.0 5/12/2023 12:00 5/12/2023 18:00 6.00 MIRU, MOVE SVRG P Hang cement hose on the rig floor. Finish derrick inspection. Clean BOP deck. Continue cleaning through out the rig. Work on MP2s. Finish installing boot adapter for chute on CPU. Welder installing mud onboard bypass line in centrifical room. Prep to change oil & filters on top drive. RKB to ground level 54.02' RKB to landing ring load shoulder 54.40' 0.0 0.0 5/12/2023 18:00 5/13/2023 00:00 6.00 MIRU, MOVE SVRG P Change out beaver slide winch cable on the rig floor. Build portable scaffolding to work on the top drive. Continue cleaning up around the rig from move. Reposition boot adapter on chute to CPU and bolt up. Stage rig mat below BOP module. Stage 18-3/4" X 13-5/8" reducer flange. Start full inspection of all mud pump suction and discharge. Check all steam traps through entire steam system. 0.0 0.0 5/13/2023 00:00 5/13/2023 01:00 1.00 MIRU, MOVE SVRG P Pre-spud maintenance. Inspect valves & seats on #2 mud pump. Verify all steam traps installed in system. Turn on steam to pits & CPU. 0.0 0.0 5/13/2023 01:00 5/13/2023 03:00 2.00 MIRU, MOVE NUND P Mobilize surface adapter to the cellar. Install surface adapter per FMC Rep. Test seals to 600 psi for 10 minutes, good. Test witnessed by CPAI Rep. SIMOPS spot cement silos; mud pump #2 inspection; LO/TO top drive & change gear oil along with filters; paint MPD isolation valves on mud pump #4. 0.0 0.0 5/13/2023 03:00 5/13/2023 06:00 3.00 MIRU, MOVE SVRG P Pre-spud maintenance. Perform MP2 work orders on top drive. Drain gear oil in drillers side drawworks. Remove driller side lube pump to change out. Inspect mud pump #1 valves, seats & surge tank. Clean out rig vac suction lines. Clean & inspect RCD head as per MPD advisor. 0.0 0.0 5/13/2023 06:00 5/13/2023 09:00 3.00 MIRU, MOVE SVRG P Pre-spud maintenace. Inspect valves, seats & surge tanks on mud pumps #3 & #4. Continue to change out filters on top drive. Fill top drive with 220 gear oil & test. Work on MP2s. 0.0 0.0 5/13/2023 09:00 5/13/2023 12:00 3.00 MIRU, MOVE SVRG P Pre-spud maintenance. Install new gear oil lube pump on drillers side drawworks. Service blocks & top drive. Change valves & seats on mud pump #4. Clean auto dump valve & discharge line on rig vac. Tighten motor mount brackets on skate shuttle & inspect. Continue work on MP2s. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 4/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/13/2023 12:00 5/13/2023 18:00 6.00 MIRU, MOVE SVRG P Pre-spud maintenance. Finish installing gear lube pump on drillers side drawworks & change out filters. Fill both sides of drawworks with 150 gear oil. Remove rig vac dump line clear plug and clean out. Clean wind walls & skate chute. Clean surge tanks & discharge screens on mud pumps #3 & #4. 0.0 0.0 5/13/2023 18:00 5/14/2023 00:00 6.00 MIRU, MOVE SVRG P Remove 2nd section of vac line discharge. Clear, clean & install same. Remove charge pumps #1 & #3 for annual inspections. Pressure wash rig floor mud manifold & surrounding area. Inventory spare snub lines & store in wood box. Work on MP2s & annual work orders. Service rig floor tongs & balance. 0.0 0.0 5/14/2023 00:00 5/14/2023 06:00 6.00 MIRU, MOVE SVRG P Pre- spud maintenance. Finish installing rig vac discharge line & test run. Change out #3 charge pump snail. Change out #1 charge pump mechanical end. Paint MPD isolation valves on mud pump #4. Clean pits module. Install drill pipe stand building mouse holes. Adjust rig floor tong counter weights. Work on MP2 work orders. Housekeeping around the rig. Organize rig mats as delivered. 0.0 0.0 5/14/2023 06:00 5/14/2023 12:00 6.00 MIRU, MOVE SVRG P Clean wind walls & upper pipe shed area. Change out top drive hydraulic A- leg filter. Change out grease zerks on crown blocks. Complete items that were identified from pre-spud derrick inspection. Position and pin A-legs for pipe skate shuttle. Finish installing API 80 screens on the shakers. Dismantle & inspect charge pump #2. Continue to work on MP2 work orders. Begin loading 5-7/8" drill pipe in the shed. 0.0 0.0 5/14/2023 12:00 5/14/2023 18:00 6.00 MIRU, MOVE SVRG P Finish inspection of #2 charge pump. Change out snail & impeller on #4 charge pump. Finish cleaning out surge tanks #3 & #4. Finish loading and strapping 100 joints of 5-7/8" drill pipe & 8 joints of 5-7/8" HWDP. Continue cleaning wind walls on rig floor. Change oil in pit agitators. Open and service #1 centrifuge. Continue working on MP2 work orders. 0.0 0.0 5/14/2023 18:00 5/15/2023 00:00 6.00 MIRU, MOVE SVRG P Change out #4 charge pump snail & impeller to new 13" impeller & chrome snail. Pressure wash derrick board wind wall & the top drive rails. Install 4" valves on conductor outlets. Continue servicing agitators & jet pump. Work on MP2 work orders. Load BHA components into pipe shed. Begin between wells maintenance on 18-3/4" BOP stack. Test shipping line from CPU to MagTec cuttings tank with water. Continue work on bulk upright tanks plumbing. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 5/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/15/2023 00:00 5/15/2023 06:00 6.00 MIRU, MOVE SVRG P Pre-spud maintenance. Repair 2" vac line in the pipe shed. Continue between well maintenance on BOPE. Continue servicing pit agitators & #2 centrifuge. Pressure wash derrick wind walls & PS- 21. Change out HT-100 tong arm. Fabricate cellar box grating around conductor. Install insulation cushions on motor module. Continue MP2 work orders. 0.0 0.0 5/15/2023 06:00 5/15/2023 12:00 6.00 MIRU, MOVE SVRG P Finish servicing pit agitators. Check sheave alignment & belts on all charge pumps. Continue between wells maintenance, inspecting lower rams. Prepare to remove mud pump #4 center pod to remove broken bolts for discharge connector. Continue cleaning derrick wind walls. 0.0 0.0 5/15/2023 12:00 5/15/2023 18:00 6.00 MIRU, MOVE SVRG P Remove center pod from mud pump #4. Mobilize ST-120 to rig floor & begin installation. Continue between wells maintenance on lower pipe rams of BOPE. Begin changing ATF in degassers 1 & 2. Load BHA in the short side of the pipe shed. Housekeeping in BOP deck and throughout the rig. 0.0 0.0 5/15/2023 18:00 5/16/2023 00:00 6.00 MIRU, MOVE SVRG P Pin ST-120 into frame, tighten bolts, & wire tie. Finish changing ATF in the degassers. Attempt to remove sheared bolts from mud pump 4 center pod. Mobilize torque pro fluid end caps & fluid in pod from CD2. Trouble shoot ST- 120 die block & grabber dies. Continue between well maintenance inspection. Build slurry in pill pit 1 with old product left in bulk hopper & dispose of. Clean flow line room, charge pump room, & all sumps under pumps. Fluid pack MPD choke skid with water as per MPD Advisor. Stage BHA XOs & components at the bottom of beaver slide. Test transfer line from CPU to MagTec cuttings tank with water. Continue plumbing upright storage tanks. 0.0 0.0 5/16/2023 00:00 5/16/2023 03:00 3.00 MIRU, MOVE SVRG P Inspect lower 3-1/2" X 6-5/8" VBRs for between well maintenance. Build slurry with old mud product to send to disposal. Mobilize new mud pump fluid end into pump room for mud pump #4. Disassemble Torque Pro cap from old fluid end. Troubleshoot ST-120 die block. 0.0 0.0 5/16/2023 03:00 5/16/2023 06:00 3.00 MIRU, MOVE PULD P Pick up 5-7/8" drill pipe from the shed, racking back in the derrick, utilizing XY crane & ST-100. Drill pipe drifted to 3.75". SIMOPS continue removing Torque Pro cap & prep new fluid end for install on mud pump 4. 0.0 0.0 5/16/2023 06:00 5/16/2023 12:00 6.00 MIRU, MOVE PULD P Pick up 5-7/8" drill pipe from the shed, racking back in the derrick, utilizing XY crane & ST-100. Drill pipe drifted to 3.75". SIMOPS continue re-install on fluid end for mud pump 4; continue re- install of ST-120 on rig floor; change out lower 3-1/2" X 6-5/8" VBRs. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 6/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/16/2023 12:00 5/16/2023 18:00 6.00 MIRU, MOVE PULD P Pick up 5-7/8" drill pipe from the shed, racking back in the derrick, utilizing XY crane & ST-100. Drill pipe drifted to 3.75". SIMOPS continue re-install of fluid end for mud pump 4; prep old fluid end for storage; continue re-install of ST -120 & spinners on rig floor; finish changing out lower 3-1/2" X 6-5/8" VBRs; thaw ice plug in cement line; begin loading 13-3/8" casing in the pipe shed. 0.0 0.0 5/16/2023 18:00 5/16/2023 20:00 2.00 MIRU, MOVE PULD P Pick up 5-7/8" drill pipe from the shed, racking back in the derrick, utilizing XY crane & ST-100. Drill pipe drifted to 3.75". Total of 33 stands racked back. SIMOPS continue re-install of fluid end for mud pump 4; continue re-install of ST-120 & spinners on rig floor; run in and tag bottom of the conductor at 131' MD continue loading 13-3/8" casing in the pipe shed. 0.0 0.0 5/16/2023 20:00 5/17/2023 00:00 4.00 MIRU, MOVE SVRG P Pre-spud maintenance. Finish re-install of fluid end for mud pump 4. Continue re -install of ST-120 hydraulic lines on rig floor. Fabricate cover for mouse hole stump in lower cellar. Continue loading 13-3/8" casing in the pipe shed. Prep old VBRs for transport to rig shop on CD2. 0.0 0.0 5/17/2023 00:00 5/17/2023 04:00 4.00 MIRU, MOVE SVRG P Pre-spud maintenance. Remove blind / shear rams & install re-dressed set. Bump test charge pumps. Store mud pump fluid end parts. Continue MP2 work orders. Mobilize surface risers to outside cellar. 0.0 0.0 5/17/2023 04:00 5/17/2023 12:30 8.50 MIRU, MOVE NUND P Nipple up surface riser sections. SIMOPS check torque on shaker motor bolts. Welder installing valve in the onboard line to rig transfer line. Continue to reassemble ST-120. MP2 work orders. Process 13-3/8" casing. 0.0 0.0 5/17/2023 12:30 5/17/2023 13:30 1.00 MIRU, MOVE SFTY P Pre-spud meeting with rig crew. 0.0 0.0 5/17/2023 13:30 5/17/2023 18:00 4.50 MIRU, MOVE SVRG P Pre-spud maintenance. Continue MP2 work orders. Continue to reassemble ST -120. Welder finished installation of valve in rig transfer line. Welder install fitting for sensor on mud gas separator. Process 13-3/8" casing. Load landing joint in pipe shed & hanger to rig floor. Remove old fluid end from pump room. 0.0 0.0 5/17/2023 18:00 5/18/2023 00:00 6.00 MIRU, MOVE SVRG P Pre-spud maintenance. Weld extension on surface riser lip. Secure surface riser for spud. Install 90' mouse hole. Reroute hydraulic lines on ST-120. Flood mud pumps with water to find leak on mud pump #4. Housekeeping through out the rig. Mud pump liner inventory. 0.0 0.0 5/18/2023 00:00 5/18/2023 06:00 6.00 MIRU, MOVE SVRG P Pre-spud maintenance. Transfer 100 bbls of water to pill pits. Circulate water through all charge pumps and jet lines to look for leaks, good. Inspect top drive saver sub, grabber dies, & drilling line. Remove center fluid end pod from mud pump 4. Install new wear plates and seals. Continue working on MP2 work orders. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 7/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/18/2023 06:00 5/18/2023 12:00 6.00 MIRU, MOVE SVRG P Pre-spud maintenance. Install new wear plates and discharge seals on mud pump 4. Continue working on MP2 work orders. Assist mud logger rig up in the pits. Mobilize BHA components to the rig floor. Change die block on ST-120. 0.0 0.0 5/18/2023 12:00 5/18/2023 18:00 6.00 MIRU, MOVE SVRG P Pre-spud maintenance. re-assemble mud pump 4. Continue rigging up mud logging equipment in the pits. Continue changing out die block head on ST-120. Perform dummy run with 13-3/8" landing joint & FMC hanger. Land out at 54.40' MD. Work on MP2 work orders, 0.0 0.0 5/18/2023 18:00 5/18/2023 21:00 3.00 MIRU, MOVE SVRG P Pre-spud maintenance. re-install mud pump 4 fluid end. Fluid pack with water & check for leaks, good. Trouble shoot ST-120. Move water around in the pits checking valves & cross training. 0.0 0.0 5/18/2023 21:00 5/18/2023 22:00 1.00 MIRU, MOVE SEQP P Pressure test mud lines and mud pumps to 5000 psi, setting seats in mud pumps 3 & 4. Good test. 0.0 0.0 5/18/2023 22:00 5/18/2023 23:00 1.00 MIRU, MOVE SVRG P Pre-spud maintenance. Trouble shoot ST-120. Prep rig floor to pick up 5-7/8" HWDP. Continue working on MP2 work orders. Check handling equipment to pick up BHA. Transfer water from pits to MagTec cuttings box & blow down lines. 0.0 0.0 5/18/2023 23:00 5/19/2023 00:00 1.00 MIRU, MOVE SFTY P Perform rig evacuation drill & conduct head count. Conduct pre-spud meeting with all personnel. 0.0 0.0 5/19/2023 00:00 5/19/2023 00:30 0.50 MIRU, MOVE SFTY P Finish pre-spud meeting with all personnel. 0.0 0.0 5/19/2023 00:30 5/19/2023 01:30 1.00 MIRU, MOVE SVRG P Connect line to operate the spinners on the ST-120. Able to use most functions on ST-120 except for the jaws to torque connections. SIMOPS prep to pick up 5- 7/8" HWDP. 0.0 0.0 5/19/2023 01:30 5/19/2023 04:00 2.50 MIRU, MOVE PULD P Pick up 3 stands of 5-7/8" HWDP and rack back in derrick. Drifted to 3.75" & torque to 63K. 0.0 0.0 5/19/2023 04:00 5/19/2023 07:00 3.00 MIRU, MOVE BHAH P Pick up BHA 1 per Directional Driller; 16" bit, motor, stabilizer, NMXO, & GWD 68' hanging. SIMOPS bring on spud mud to pits. Rig Accepted at 04:00 hrs on 5-19-23 0.0 0.0 5/19/2023 07:00 5/19/2023 07:30 0.50 MIRU, MOVE SEQP P Fill surface riser with spud mud and check for leaks. Found leak on surface riser. 0.0 0.0 5/19/2023 07:30 5/19/2023 11:00 3.50 MIRU, MOVE RGRP T Pull top riser section. Weld crack at top of second riser section. Check air boots. Re-install top riser section. Fill riser with spud mud and see 4" conductor valve leaking. Install plug on valve. Surface riser & flow line good. 0.0 0.0 5/19/2023 11:00 5/19/2023 12:00 1.00 MIRU, MOVE BHAH P Continue making up BHA 1 per Directional Driller from 68'-127' MD. Make up arcVISION, TruLINK, NMXO,& UBHO sub. 0.0 127.0 5/19/2023 12:00 5/19/2023 13:15 1.25 MIRU, MOVE BHAH T UBHO screws were to long and stuck out preventing make up of next sub. Laid down sub from BHA & install spacer ring. 127.0 123.0 5/19/2023 13:15 5/19/2023 14:00 0.75 MIRU, MOVE BHAH P Change out elevators to 5-7/8". Make up stand of 5-7/8" DP. Prime pumps & fill lines. 123.0 123.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 8/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/19/2023 14:00 5/19/2023 18:45 4.75 SURFAC, DRILL DDRL P Drill surface section from 131'-383' MD, 383' TVD. 625 gpm 1030 psi 40 rpm Torque 3K on / 3K off WOB 5-10K PU 102K SO 97K ROT 95K ART 2.07 ADT 2.23 BIT 2.23 123.0 383.0 5/19/2023 18:45 5/19/2023 20:15 1.50 SURFAC, DRILL TRIP P Trip out of hole from 383'-123' MD. Rack back in derrick. PU 105K. 383.0 123.0 5/19/2023 20:15 5/19/2023 22:00 1.75 SURFAC, DRILL BHAH P Make up 2 non-mag drill collars & HWDP with jars, from 123'- 383' MD. 123.0 383.0 5/19/2023 22:00 5/19/2023 23:00 1.00 SURFAC, DRILL DDRL P Drill surface section from 383'-463' MD, 463' TVD. 610 gpm 1030 psi 40 rpm Torque 3K on / 2K off WOB 5-10K PU 105K SO 97K ROT 110K ART .89 ADT1.21 JAR hrs 1.21 BIT hrs 3.44 383.0 463.0 5/19/2023 23:00 5/20/2023 00:00 1.00 SURFAC, DRILL RGRP T Trouble shoot cuttings auger. Tighten belts on drive motor. Clear auger of cuttings with super sucker. Function test good. 463.0 463.0 5/20/2023 00:00 5/20/2023 06:00 6.00 SURFAC, DRILL DDRL P Drill surface section from 463'-721' MD, 721' TVD. Add 1 cup of SAPP & soap stick at every connection. Pump 30 bbl 10.5 ppg nut plug sweep. 640 gpm 1350 psi 40 rpm Torque 3K on / 2K off WOB 5-10K PU 115K SO 102K ROT 116K AST 1.85 ADT 3.64 JAR hrs 4.75 BIT hrs 6.98 463.0 721.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 9/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/20/2023 06:00 5/20/2023 12:00 6.00 SURFAC, DRILL DDRL P Drill surface section from 721'-1300' MD, 1285' TVD. Add 1 cup of SAPP & soap stick at every connection. Pump 20 bbl 10.5 ppg nut plug sweep every other connection. 650 gpm 1600 psi 40 rpm Torque 10K on / 3K off WOB 5-40K PU 124K SO 118K ROT 120K AST 2.52 ADT 3.61 JAR hrs 8.36 BIT hrs 10.59 721.0 1,300.0 5/20/2023 12:00 5/20/2023 18:00 6.00 SURFAC, DRILL DDRL P Drill surface section from 1300'-2025' MD, 1905' TVD. Add 1 cup of SAPP & soap stick at every connection. Pump 20 bbl 10.5 ppg nut plug sweep as needed. 1000 gpm 2680 psi 50 rpm Torque 8K on / 5K off WOB 20K PU 129K SO 125K ROT 127K AST 1.02 ADT 3.45 JAR hrs 11.81 BIT hrs 14.04 1,300.0 2,025.0 5/20/2023 18:00 5/21/2023 00:00 6.00 SURFAC, DRILL DDRL P Drill surface section from 1300'-2281' MD, 2089' TVD. Add 1 cup of SAPP & soap stick at every connection. Pump 20 bbl 10.5 ppg nut plug sweep as needed. SIMOPS Test MPD chokes to 300 / 1200 psi minutes each test, charted. Break studs on fast lock adapter on high pressure riser for upcoming nipple up. 1055 gpm 2933 psi 50 rpm Torque 8K on / 3K off WOB 20K PU 153K SO 131K ROT 136K AST 0 ADT 5.05 JAR hrs 16.86 BIT hrs 19.09 2,025.0 2,281.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 10/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/21/2023 00:00 5/21/2023 06:00 6.00 SURFAC, DRILL DDRL P Drill surface section from 2281'-2561' MD, 2287' TVD. Add 1 cup of SAPP & soap stick at every connection. Pump 40 bbl 10.5 ppg nut plug sweep as needed. 1055 gpm 2950 psi 50 rpm Torque 8K on / 3K off WOB 25K PU 153K SO 132K ROT 144K AST .41 ADT 5.61 JAR hrs 22.04 BIT hrs 24.09 2,281.0 2,561.0 5/21/2023 06:00 5/21/2023 08:00 2.00 SURFAC, DRILL DDRL P Drill surface section from 2561'-2769' MD, 2410' TVD. Add 1 cup of SAPP & soap stick at every connection. Pump 40 bbl 10.5 ppg nut plug sweep as needed. 1030 gpm 3000 psi 50 rpm Torque 12K on / 5K off WOB 30K PU 154K SO 132K ROT 141K AST 0 ADT 1.4 JAR hrs 23.44 BIT hrs 25.49 2,561.0 2,769.0 5/21/2023 08:00 5/21/2023 08:15 0.25 SURFAC, TRIPCAS SRVY P Obtain final survey. 2,769.0 2,769.0 5/21/2023 08:15 5/21/2023 09:15 1.00 SURFAC, TRIPCAS BKRM P Backream out of the hole pumping 2 bottoms up from 2769'-2598' MD. Dump & dilute 275 bbls of mud. 1000 gpm 2640 psi 50 rpm Torque 2-6K ROT 138K 2,769.0 2,598.0 5/21/2023 09:15 5/21/2023 09:45 0.50 SURFAC, TRIPCAS OWFF P Monitor well, static. SIMOPS grease wash pipe & change out grease zerk fitting. 2,598.0 2,598.0 5/21/2023 09:45 5/21/2023 16:15 6.50 SURFAC, TRIPCAS BKRM P Backream out of the hole from 2598'- 1483' MD. 1000 gpm 2500 psi 50 rpm Torque 2-8K ROT 125K 2,598.0 1,483.0 5/21/2023 16:15 5/21/2023 17:15 1.00 SURFAC, TRIPCAS BKRM P Backream out of the hole pumping 2 bottoms up from 1483'-1300' MD. 800 gpm 1800 psi 50 rpm Torque 2-8K ROT 124K 1,483.0 1,300.0 5/21/2023 17:15 5/21/2023 20:30 3.25 SURFAC, TRIPCAS PMPO P Pump out of the hole from 1300'-469' MD. 600 gpm 1200 psi PU 110K 1,300.0 469.0 5/21/2023 20:30 5/21/2023 20:45 0.25 SURFAC, TRIPCAS OWFF P Monitor well, static. Observe slight drop, 2-3" in fluid level. 469.0 469.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 11/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/21/2023 20:45 5/21/2023 22:30 1.75 SURFAC, TRIPCAS PMPO P Pump out of the hole from 469'-185' MD racking back HWDP and jars. 600 gpm 1040 psi PU 107K 469.0 185.0 5/21/2023 22:30 5/22/2023 00:00 1.50 SURFAC, TRIPCAS BHAH P Blow down top drive & change out elevators. PJSM to lay down BHA. Lay down from 185'-68' MD. Lay down 2 NMDC, NM Stab, TruLINK, & arcVISION. 185.0 68.0 5/22/2023 00:00 5/22/2023 01:30 1.50 SURFAC, TRIPCAS BHAH P Lay down BHA 1 from 67' to surface. Clear and clean rig floor. Stabilizer in gauge. Kymera 16" bit grade 6, 2, BT, C, E, JD, TD. 68.0 0.0 5/22/2023 01:30 5/22/2023 04:00 2.50 SURFAC, CASING RURD P Rig up to run casing. Mobilize casing equipment to the rig floor. Make up XO, cement swivel, & Volant CRT. Install bail extensions, spiders, & single joint elevators. 0.0 0.0 5/22/2023 04:00 5/22/2023 07:00 3.00 SURFAC, CASING PUTB P PJSM for running casing. Make up shoe track as per casing detail to 160' MD. BakerLok connections to the pin end of the first pup joint. Centralized as per program. Circulate through shoe track and check floats, good. 0.0 160.0 5/22/2023 07:00 5/22/2023 09:15 2.25 SURFAC, CASING PUTB P Run in the hole with 13-3/8", 68#, L80, Hydril 563 surface casing as per tally from 160'-568' MD. Centralize each joint. Connections made up to 25K ft/lbs. with Best O Life arctic grade 2000. Connection torque, double bumped. PU 118K, SO 96K. 160.0 568.0 5/22/2023 09:15 5/22/2023 09:45 0.50 SURFAC, CASING PUTB T Attempt to work past obstruction at 568' MD setting down weight each time at same depth. Stage up pumps to 7 bpm, 50 psi. Set weight down with no pressure increase observed. Pump & rotate at 5 rpm, Tq 2-3K setting down at same depth. 568.0 568.0 5/22/2023 09:45 5/22/2023 13:15 3.50 SURFAC, CASING PUTB T Lay down joint #13 & pick up to 465' MD inspecting centralizers. Confirm obstruction down hole and not centralizer in riser. Run back in the hole & make up joint #13. Run in and tag up at 568' MD attempting to work through. Drain stack and confirm centralizer was not hanging up in the riser. Pump at 3 bpm, 10 psi working casing setting full weight down repeatedly to get past obstruction. 568.0 568.0 5/22/2023 13:15 5/22/2023 14:00 0.75 SURFAC, CASING PUTB P Run in the hole with 13-3/8", 68#, L80, Hydril 563 surface casing as per tally from 568'-690' MD. Centralize each joint. Connections made up to 25K ft/lbs. with Best O Life arctic grade 2000. Connection torque, double bumped. PU 120K, SO 112K. 568.0 690.0 5/22/2023 14:00 5/22/2023 18:00 4.00 SURFAC, CASING PUTB P Run in the hole with 13-3/8", 68#, L80, Hydril 563 surface casing as per tally from 690'-860' MD. Centralize each joint. Connections made up to 25K ft/lbs. with Best O Life arctic grade 2000. Connection torque, double bumped. Wash down with 8 bpm, 45-80 psi, PU 124K, SO 100K. Work past obstruction at 690' MD and continue washing down. 690.0 860.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 12/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/22/2023 18:00 5/23/2023 00:00 6.00 SURFAC, CASING PUTB P Wash in the hole with 13-3/8", 68#, L80, Hydril 563 surface casing as per tally from 860'-1070' MD. Centralize each joint. Connections made up to 25K ft/lbs. with Best O Life arctic grade 2000. Connection torque, double bumped. Wash down with 8 bpm, 80-120 psi, PU 140K, SO 117K. Losses past 24hrs to the hole 22 bbls. 860.0 1,070.0 5/23/2023 00:00 5/23/2023 01:15 1.25 SURFAC, CASING PUTB P Run in the hole with 13-3/8", 68#, L80, Hydril 563 surface casing as per tally from 1070'-1285' MD. Centralize each joint. Connections made up to 25K ft/lbs, double bumped with Best O Life arctic grade 2000. PU 136K, SO 107K. 1,070.0 1,285.0 5/23/2023 01:15 5/23/2023 01:45 0.50 SURFAC, CASING CIRC P Circulate bottoms up staging up pump. 8 bpm 120 psi FO 21% PU 145K SO 120K 1,285.0 1,285.0 5/23/2023 01:45 5/23/2023 06:00 4.25 SURFAC, CASING PUTB P Run in the hole with 13-3/8", 68#, L80, Hydril 563 surface casing as per tally from 1285'-2707' MD. Centralize each joint. Connections made up to 25K ft/lbs, double bumped with Best O Life arctic grade 2000. SO 120K. SIMOPS load 275 bbls of black water in pits, rig up injection line to 2" outlet on surface adapter, stage 1502 equipment on the floor for hooking up cementing hose. 1,285.0 2,707.0 5/23/2023 06:00 5/23/2023 07:15 1.25 SURFAC, CASING PUTB P Make up 13-3/8" surface hanger, landing joint with 18' pup joint. Land hanger on depth 2707'-2764' MD. PU 214K, SO 180K. Ran a total of 62 joints of 13-3/8" casing, 2 13-3/8" space out pup joints, 62 bow spring centralizers, & 6 stop rings. 2,707.0 2,764.0 5/23/2023 07:15 5/23/2023 09:00 1.75 SURFAC, CEMENT CIRC P Fill casing and establish circulation reciprocating 10' strokes. Pump 1 bpm on down stroke & 2-3 bpm on the up stroke to see 120-140 psi. 2,764.0 2,764.0 5/23/2023 09:00 5/23/2023 12:30 3.50 SURFAC, CEMENT CIRC P Stage up pumps from 1 - 5 bpm, 140 psi with full returns circulating & conditioning for cement job. 2,764.0 2,764.0 5/23/2023 12:30 5/23/2023 13:15 0.75 SURFAC, CEMENT RURD P PJSM for cementing. Blow down the top drive. Rig up cement hose & equipment to Volant cementing swivel. Break circulation. 2,764.0 2,764.0 5/23/2023 13:15 5/23/2023 13:30 0.25 SURFAC, CEMENT SEQP P Line up on cement unit & SLB pump 10 bbls of water. Pressure test lines to 3000 psi, good. 2,764.0 2,764.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 13/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/23/2023 13:30 5/23/2023 17:30 4.00 SURFAC, CEMENT CMNT P SLB cementing unit pumped 100 bbls of 10.8 ppg MudPush II spacer at 5 bpm, 155 psi. Drop bottom plug. Pump 395 bbls of 11.0 ppg lead cement at 5.5 bpm, 155-359 psi. Pump 72.4 bbls of 15.8 ppg tail cement at 3.8 bpm, 177- 313 psi. Drop top plug and pump 20 bbls of water behind at 3-5 bpm, 67-215 psi. Swap to rig pumps and displace cement with 10.5 ppg mud at 7 bpm, 500-700 psi. Slow pumps to 3 bpm, 600 psi with 370 bbls pumped. Bump plug with 384.2 bbls, 3237 strokes pumped. Pressure up to 1200 psi & hold for 5 minutes. Bleed off pressure and check floats, good. CIP 17:26 hrs. Good Cement back to surface at 226bbls displaced. Returns were lost with 251.6 bbls of mud displacement pumped. Total losses to the hole 125 bbls. 25bbls of good cement back to surface. 2,764.0 0.0 5/23/2023 17:30 5/23/2023 20:30 3.00 SURFAC, CEMENT RURD P Drain and rinse riser. Install bail extensions & elevators. Lay down landing joint. Flush riser with black water and drain. Clean casing equipment. Rig down & send down bail extensions, elevators, strap tongs, Volant CRT, spiders & hand slips. Clear & clean rig floor. 0.0 0.0 5/23/2023 20:30 5/23/2023 22:30 2.00 SURFAC, CEMENT NUND P Nipple down surface riser and surface adapter. SIMOPS off load spud mud from the pits, clean shakers & flow return box in the pits from surface cement job. Cement top is 50" below hanger in conductor. 0.0 0.0 5/23/2023 22:30 5/24/2023 00:00 1.50 SURFAC, WHDBOP NUND P Mobilize FMC wellhead into cellar. Clean & prep surface hanger for nipple up. 0.0 0.0 5/24/2023 00:00 5/24/2023 04:00 4.00 SURFAC, WHDBOP NUND P NU FMC 13-5/8" wellhead, 13-5/8" x 18- 3/4" adapter, test wellhead seals T/1000 psi. Witnessed by CPAI Co rep. SIMOPS: Arrange low pressure surface riser and adapter in lower cellar. Test run MPD RCD head and RU 2" hard iron on RCD to balance weight 0.0 0.0 5/24/2023 04:00 5/24/2023 04:30 0.50 SURFAC, WHDBOP NUND P PJSM, PU 18-3/4" HP riser and set in place on adapter flange. Obtain wellhead RKB's. ULDS=49.20' LLDS=51.62' 0.0 0.0 5/24/2023 04:30 5/24/2023 06:00 1.50 SURFAC, WHDBOP NUND P PJSM, RU TD slings and PU RCD head over well center to set on stack. SIMOPS: clean mud pits and CPU tank. Flush all lines and clean cement valves on rig floor. 0.0 0.0 5/24/2023 06:00 5/24/2023 10:00 4.00 SURFAC, WHDBOP NUND P NU BOP stack and MPD head. 0.0 0.0 5/24/2023 10:00 5/24/2023 12:00 2.00 SURFAC, WHDBOP NUND P Torque nuts on MPD head to annular T/ 1750 ft/lbs W/Sweeny wrench. Install choke and kill lines. Repair auger packing in CPU, open hammer mill, clean and inspect. Install valve and line to take fluid from tank farm to gun line. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 14/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/24/2023 12:00 5/24/2023 14:00 2.00 SURFAC, WHDBOP NUND P Finish installing choke and kill lines. Torque wellhead adapter with sweeny wrench. RD lines from installing MPD. Mobilize test plug, wear ring and riser to rig floor. Take on 11.0 ppg FWP mud to pits. 0.0 0.0 5/24/2023 14:00 5/24/2023 16:30 2.50 SURFAC, WHDBOP NUND P Install MPD lines to RCD head. Remove flange and install second valve on lower annulus. Grease choke manifold. Install low pressure riser. Take RKB measurments to preventers. Repair dump line in pit #1. Test run riser. 0.0 0.0 5/24/2023 16:30 5/24/2023 18:00 1.50 SURFAC, WHDBOP NUND P Power up Koomey. Open blind ram doors and take pictures for BWM. Clean riser and send to shop to add 8" in length. MU pup Jts and 5-7/8" test Jt. Finish repairing pit #1 dump valve. Repair choke HCR 4 way valve. Finish taking on 11.0 ppg FWP mud to pits, 777 bbls total. 0.0 0.0 5/24/2023 18:00 5/24/2023 22:00 4.00 SURFAC, WHDBOP RURD P PJSM, set FMC test plug, conduct walk down with FMC rep on equip. RU BOP test equip, 5-7/8" TIW/Dart valves and test sub to TD. Grease upper and lower IBOPs, change out air boots on RT bell nipple, install pitcher nipple to RCD riser, inspect air boots. 0.0 0.0 5/24/2023 22:00 5/25/2023 00:00 2.00 SURFAC, WHDBOP RURD P Fluid pack BOPE's, flush lines with water, check for leaks on riser, shell test BOPs 0.0 0.0 5/25/2023 00:00 5/25/2023 04:45 4.75 SURFAC, WHDBOP BOPE P Perform Initial BOPE test 5-7/8” test jt, annular t/ 250 psi low 2500 psi high f/5 min charted, remaining tests t/ 250psi low f/5 min, 5,000psi high f/5 min charted, upper 4½”x 7-5/8" vbrs, lower 3½”x 6-5/8” vbrs, cmv #1-#16, manual & hcr choke/ kill & kill valve #3, upper/lower IBOPs, 5-7/8” TIW/dart valves, blind shears, conduct koomey drawdown, acc = 3050 psi, manifold = 1510 psi, acc = 1750 psi after all functions on bottles, 12 sec for 200 psi. build w/ 2 elec. pumps, 86 sec t/ full sys. pressure w/ 2 elec. & 6 air pumps, closing times: annular=16 sec. UPR=15 sec. blind/shears=15sec. LPR=16sec. choke HCR=2sec. kill HCR=2sec, test pvt gain/loss & flow out alarms, test LEL&H2S alarms, witness waived by AOGCC rep Sully Sullivan 0.0 0.0 5/25/2023 04:45 5/25/2023 06:30 1.75 SURFAC, WHDBOP MPDA P MU MPD test plug T/ 1stds 5-7/8 DP, set and test MPD manifiold and RCD head T/250 psi low, 1300 psi high F/5min on chart. 0.0 0.0 5/25/2023 06:30 5/25/2023 06:45 0.25 SURFAC, WHDBOP RURD P LD MPD test plug and rack std of DP 0.0 0.0 5/25/2023 06:45 5/25/2023 07:15 0.50 SURFAC, WHDBOP RURD P PU test Jt and pull FMC test plug 0.0 0.0 5/25/2023 07:15 5/25/2023 08:30 1.25 SURFAC, WHDBOP RURD P Drain stack and riser, MU wear ring running tool to test jt. Install long wear ring and run in 2 LDS's. Wear ring ID = 12.43" 0.0 0.0 5/25/2023 08:30 5/25/2023 08:45 0.25 SURFAC, WHDBOP RURD P Fill stack with water and RU for casing test 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 15/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/25/2023 08:45 5/25/2023 09:45 1.00 SURFAC, WHDBOP PRTS P Test 13-3/8" casing T/2600 psi for 30 min charted. Pumped 4.4 bbls at .5 bpm total. 4.4 bbls bled back. 0.0 0.0 5/25/2023 09:45 5/25/2023 10:45 1.00 SURFAC, WHDBOP RURD P Finish installing 2nd valve on lower annulus. Drain water from stack, Blow down choke and kill lines. Refill stack with 11.0 mud. 0.0 0.0 5/25/2023 10:45 5/25/2023 13:30 2.75 SURFAC, DRILLOUT SLPC P Hang blocks, slip and cut 47', 5 wraps, drilling line. 0.0 0.0 5/25/2023 13:30 5/25/2023 14:15 0.75 SURFAC, DRILLOUT RURD P Unhang blocks. Calibrate drawworks. Obtain empty block calibration for town. 0.0 0.0 5/25/2023 14:15 5/25/2023 14:45 0.50 SURFAC, DRILLOUT BHAH P Inspect saver sub, mobilze short BHA components to floor. 0.0 0.0 5/25/2023 14:45 5/25/2023 16:30 1.75 SURFAC, DRILLOUT BHAH P MU Int 1 BHA T/ 81'. PU, MU 12-1/4" bit T/48K torque. 0.0 81.0 5/25/2023 16:30 5/25/2023 18:00 1.50 SURFAC, DRILLOUT BHAH P Cont MU BHA #2 to 110'MD, MU NMDC, stab and mudgaurd. LD on skate to PU after source loaded. 81.0 110.0 5/25/2023 18:00 5/25/2023 18:30 0.50 SURFAC, DRILLOUT BHAH P PJSM, load source in SADN8 tool. 110.0 110.0 5/25/2023 18:30 5/25/2023 19:45 1.25 SURFAC, DRILLOUT BHAH P Cont MU all BHA #2 to 441' 110.0 441.0 5/25/2023 19:45 5/25/2023 22:00 2.25 SURFAC, DRILLOUT TRIP P RIH w/ 5-7/8" DP from derrick F/441' T/2,479' 441.0 2,479.0 5/25/2023 22:00 5/25/2023 23:00 1.00 SURFAC, DRILLOUT CIRC P Fill pipe, establish circulation, thick mud, stage up rate to 600 gpm, 685 psi, test MWD, Obtain PUW=160K, SOW= 133K, RTW= 147K 2,479.0 2,479.0 5/25/2023 23:00 5/26/2023 00:00 1.00 SURFAC, DRILLOUT REAM P Wash/Ream F/2,479' T/ 2,668'. 600 gpm, 685 psi, 27% flow out, PUW= 160K, SOW= 133K, RTW= 147K, 30 rpm, 2-7K tq 2,479.0 2,668.0 5/26/2023 00:00 5/26/2023 02:00 2.00 SURFAC, DRILLOUT DRLG P Ream down, tag FC on depth at 2,674'. Drill FC to 2,676'. 600 gpm, 680 psi, 27% flow out, 40 rpm, 5-8K tq, PUW= 160K, SOW= 133K, RTW= 147K. SPRs @ 2,670' w/ 10.5 MW. MP1, 20 spm = 67 psi. 30 spm = 74 psi. MP2, 20 spm = 69 psi, 30 spm = 83 psi. 2,668.0 2,676.0 5/26/2023 02:00 5/26/2023 04:15 2.25 SURFAC, DRILLOUT DRLG P Drill shoe track, cement, shoe and rathole F/ 2,676' T/2,769'. Ream shoe 3X, 600 gpm, 680 psi, 27% flow out, 80 rpm, 5-8K tq. PUW= 160K, SOW= 133K, RTW= 147K 2,676.0 2,769.0 5/26/2023 04:15 5/26/2023 05:30 1.25 SURFAC, DRILLOUT DDRL P Drill 20' new hole F/2,769' T/2,789'. 600 gpm, 680 psi, 27% flow out, 80 rpm, 5- 8K tq. PUW= 160K, SOW= 133K, RTW= 147K 2,769.0 2,789.0 5/26/2023 05:30 5/26/2023 06:30 1.00 SURFAC, DRILLOUT CIRC P LD working single, CBU and condition mud for FIT test. SIMOPS: RU/Prep for FIT test 2,789.0 2,769.0 5/26/2023 06:30 5/26/2023 08:00 1.50 SURFAC, DRILLOUT LOT P Perform FIT, leaked off at 17.7 ppg EMW. 2.4 bbls pumped, 1.8 bbls returned 2,769.0 2,769.0 5/26/2023 08:00 5/26/2023 10:00 2.00 INTRM1, DRILL DISP P PJSM, displace F/ 10.5 ppg DrillPlex T/11.0 ppg FWP. 550 gpm, 505 psi, 24% flow out, while rotate 30 rpm, 5K tq and reciprocate F/2,789' T/2,762'. 2,769.0 2,789.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 16/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/26/2023 10:00 5/26/2023 12:00 2.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/2,789' T/2,915'. 900 gpm, 1260 psi, 42% flow out, 100 rpm, 6 -12k tq on, 4-5k tq off. 6-12K wob, 11.64 ECD, Max gas 0 units. PUW= 160k, SOW= 132K, RTW= 147K. Bit hrs= 2.05. ADT= 2.05, Jar hrs= 25.49. SPRs, MP1, 20spm=101psi, 30spm=126. MP2, 20spm=104psi, 30spm= 131psi 2,789.0 2,915.0 5/26/2023 12:00 5/26/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/2,915' T/3,315'. 1000 gpm, 1560 psi, 44% flow out, 150 rpm, 5 -7k tq on, 3-4k tq off. 5-8K wob, 11.69 ECD, Max gas 39 ppm. PUW= 147k, SOW= 140K, RTW= 144K. Bit hrs= 5.28. ADT= 3.23, Jar hrs= 28.72. 2,915.0 3,315.0 5/26/2023 18:00 5/27/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/3,315' T/3,692'. 1000 gpm, 1560 psi, 44% flow out, 150 rpm, 5 -7k tq on, 3-4k tq off. 5-8K wob, 11.69 ECD, Max gas 102 ppm. PUW= 147k, SOW= 137K, RTW= 139K. Bit hrs= 10.60. ADT= 5.32, Jar hrs= 34.04 Pump NP/SAPP sweeps every other stand. SPRs MP1. 20 spm=68psi. 30spm=97psi MP2. 20spm=68psi, 30spm=98psi 3,315.0 3,692.0 5/27/2023 00:00 5/27/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/3,692' T/4,144'. 1000 gpm, 1741 psi, 41% flow out, 170 rpm, 6 -7k tq on, 5-6k tq off. 8K wob, 12.01 ECD, Max gas 22 ppm. PUW= 147k, SOW= 137K, RTW= 139K. Bit hrs= 14.88. ADT= 4.28, Jar hrs= 38.32 Pump NP/SAPP sweeps every other stand. 3,692.0 4,144.0 5/27/2023 06:00 5/27/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/4,144' T/4,564'. 1000 gpm, 1820 psi, 39% flow out, 180 rpm, 8 -10k tq on, 4-6k tq off. 6-11K wob, 11.92 ECD, Max gas 380 ppm. PUW= 141k, SOW= 133K, RTW= 136K. Bit hrs= 19.55. ADT= 4.67, Jar hrs= 42.99 Pump NP/SAPP sweeps every other stand. 4,144.0 4,564.0 5/27/2023 12:00 5/27/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/4,564' T/4,985'. 1000 gpm, 1890 psi, 39% flow out, 180 rpm, 8 -11k tq on, 6-8k tq off. 7-10K wob, 12.04 ECD, Max gas 360 ppm. PUW= 159k, SOW= 127K, RTW= 138K. Bit hrs= 24.07. ADT= 4.52, Jar hrs= 47.51 Pump NP/SAPP sweeps every other stand. 4,564.0 4,985.0 5/27/2023 18:00 5/28/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/4,985' T/5,375'. 1000 gpm, 2000 psi, 40% flow out, 180 rpm, 9 -10k tq on, 7-8k tq off. 6K wob, 12.18 ECD, Max gas 380 ppm. PUW= 151k, SOW= 130K, RTW= 137K. Bit hrs= 28.2. ADT= 4.13, Jar hrs= 51.64 Pump NP/SAPP sweeps every other stand. 4,985.0 5,375.0 5/28/2023 00:00 5/28/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/5,375' T/5,633'. 1000 gpm, 2100 psi, 42% flow out, 180 rpm, 10-12k tq on, 9-10k tq off. 9K wob, 12.25 ECD, Max gas 30 ppm. PUW= 155k, SOW= 129K, RTW= 138K. Bit hrs= 31.9. ADT= 3.7, Jar hrs= 55.34 Pump NP/SAPP sweeps every other stand. 5,375.0 5,633.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 17/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/28/2023 06:00 5/28/2023 09:45 3.75 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/5,633' T/5,786'. 1000 gpm, 1890 psi, 42% flow out, 180 rpm, 10k tq on, 8k tq off. 4K wob, 12.09 ECD, Max gas 30 ppm. PUW= 155k, SOW= 129K, RTW= 138K. Bit hrs= 34.66. ADT= 2.76, Jar hrs= 58.1 Pump NP/SAPP sweeps every other stand. Perform 550 bbl 11.0 mud dilution at 0730 hrs 5,633.0 5,786.0 5/28/2023 09:45 5/28/2023 10:15 0.50 INTRM1, DRILL CIRC P Rot and reciprocate, Pump 2ea 20 ppb NP/DZ sweeps to scour BHA. 950 gpm, 1870 psi, 39% FO, 12.01 ECD, 180 rpm, 8-10K tq 5,786.0 5,786.0 5/28/2023 10:15 5/28/2023 12:00 1.75 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/5,786' T/5,878'. 2,992' TVD. 950 gpm, 1860 psi, 38% flow out, 180 rpm, 10k tq on, 8k tq off. 5K wob, 12.01 ECD, Max gas 20 ppm. PUW= 155k, SOW= 129K, RTW= 138K. Bit hrs= 36.25 ADT= 1.59, Jar hrs= 59.69 Pump NP/SAPP sweeps every other stand. 5,786.0 5,878.0 5/28/2023 12:00 5/28/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/5,878' T/6,188' MD. 3,019' TVD. 1000 gpm, 2050 psi, 38% flow out, 180 rpm, 10k tq on, 8k tq off. 7K wob, 11.9 ECD, Max gas 34 ppm. PUW= 157k, SOW= 137K, RTW= 140K. Bit hrs= 40.55 ADT= 4.3, Jar hrs= 63.99 Pump NP/SAPP sweeps every other stand. 5,878.0 6,188.0 5/28/2023 18:00 5/29/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/6,188' T/6,590' MD. 3,061' TVD. 1000 gpm, 2226 psi, 42% flow out, 180 rpm, 10k tq on, 8k tq off. 6K wob, 12.03 ECD, Max gas 45 ppm. PUW= 163k, SOW= 137K, RTW= 142K. Bit hrs= 45.42 ADT= 3.73, Jar hrs= 68.86 Pump NP/SAPP sweeps every other stand. 6,188.0 6,590.0 5/29/2023 00:00 5/29/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/6,590' T/6,913' MD. 3,108' TVD. 1000 gpm, 2176 psi, 42% flow out, 180 rpm, 10k tq on, 8k tq off. 6K wob, 12.07 ECD, Max gas 35 ppm. PUW= 163k, SOW= 137K, RTW= 142K. Bit hrs= 50.04 ADT= 4.62, Jar hrs= 73.48 Pump NP/SAPP sweeps every other stand. 6,590.0 6,913.0 5/29/2023 06:00 5/29/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/6,913' T/7,225' MD. 3,148' TVD. 1000 gpm, 2230 psi, 42% flow out, 180 rpm, 12k tq on, 10k tq off. 5K wob, 12.10 ECD, Max gas 30 ppm. PUW= 168k, SOW= 134K, RTW= 143K. Bit hrs= 54.50 ADT= 4.46, Jar hrs= 77.94 Pump NP/SAPP sweeps every other stand. 6,913.0 7,225.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 18/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/29/2023 12:00 5/29/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/7,225' T/7,542' MD. 3,170' TVD. 1000 gpm, 2266 psi, 42% flow out, 190 rpm, 15k tq on, 10k tq off. 7K wob, 11.98 ECD, Max gas 34 ppm. PUW= 167k, SOW= 135K, RTW= 144K. Bit hrs= 59.12 ADT= 4.62, Jar hrs= 82.56 Pump NP/SAPP sweeps every other stand. Dump and Dilute 540 bbls of 10.8 FWP @ 1330 Hrs, 7300' MD 7,225.0 7,542.0 5/29/2023 18:00 5/30/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/7,542' T/7,833' MD. 3,219' TVD. 1000 gpm, 2320 psi, 40% flow out, 190 rpm, 15k tq on, 10k tq off. 8K wob, 11.94 ECD, Max gas 42 ppm. PUW= 167k, SOW= 135K, RTW= 144K. Bit hrs= 63.5 ADT= 4.38 Jar hrs= 86.94 Pump NP/SAPP sweeps every other stand. 7,542.0 7,833.0 5/30/2023 00:00 5/30/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/7,833' T/8,099' MD. 3,250' TVD. 1000 gpm, 2285 psi, 40% flow out, 190 rpm, 15k tq on, 10k tq off. 8K wob, 12.06 ECD, Max gas 25 ppm. PUW= 169k, SOW= 132K, RTW= 141K. Bit hrs= 68.09 ADT= 4.59 Jar hrs= 91.53 Pump NP/SAPP sweeps every other stand. Perform 550 bbl whole mud dilution at 7,985' 7,833.0 8,099.0 5/30/2023 06:00 5/30/2023 12:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/8,099' T/8,392' MD. 3,284' TVD. 1000 gpm, 2410 psi, 40% flow out, 170 rpm, 15k tq on, 10k tq off. 10K wob, 12.10 ECD, Max gas 41 ppm. PUW= 173k, SOW= 128K, RTW= 145K. Bit hrs= 72.34 ADT= 4.25 Jar hrs= 95.78 Pump NP/SAPP sweeps every other stand. Test run NOVOS update 8,099.0 8,392.0 5/30/2023 12:00 5/30/2023 18:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/8,392' T/8,763' MD. 3,310' TVD. 1000 gpm, 2365 psi, 40% flow out, 170 rpm, 17k tq on, 10k tq off. 5K wob, 12.02 ECD, Max gas 41 ppm. PUW= 173k, SOW= 128K, RTW= 145K. Bit hrs= 76.94 ADT= 4.60 Jar hrs= 100.38 Pump NP/SAPP sweeps every other stand. Perform 550 bbl whole mud dilution at 8,620' 8,392.0 8,763.0 5/30/2023 18:00 5/31/2023 00:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/8,763' T/9,226' MD. 3,362' TVD. 1000 gpm, 2451 psi, 39% flow out, 170 rpm, 16k tq on, 11k tq off. 7K wob, 12.10 ECD, Max gas 62 ppm. PUW= 171k, SOW= 132K, RTW= 137K. Bit hrs= 81.62 ADT= 4.68 Jar hrs= 105.06 Pump NP/SAPP sweeps every other stand. 8,763.0 9,226.0 5/31/2023 00:00 5/31/2023 06:00 6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/9,226' T/9,660' MD. 3,426' TVD. 1000 gpm, 2451 psi, 39% flow out, 170 rpm, 17k tq on, 14k tq off. 10K wob, 12.02 ECD, Max gas 109 ppm. PUW= 176k, SOW= 130K, RTW= 152K. Bit hrs= 85.89 ADT= 4.27 Jar hrs= 109.33 Pump NP/SAPP sweeps every other stand. 9,226.0 9,660.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 19/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 5/31/2023 06:00 5/31/2023 12:30 6.50 INTRM1, DRILL DDRL P Drill 12-1/4" Int1 F/9,660' T/10,136' MD. 3,478' TVD. 1000 gpm, 2520 psi, 39% flow out, 170 rpm, 19k tq on, 11k tq off. 12K wob, 12.06 ECD, Max gas 50 ppm. PUW= 183k, SOW= 127K, RTW= 148K. Bit hrs= 91.00 ADT= 5.11 Jar hrs= 114.44 Pump NP/SAPP sweeps every other stand. 9,660.0 10,136.0 5/31/2023 12:30 5/31/2023 13:00 0.50 INTRM1, TRIPCAS CIRC P Shoot final survey, collect T&D. PUW=188K, SOW=128K, RTW=148K, Tq=8K 10,136.0 10,136.0 5/31/2023 13:00 5/31/2023 14:00 1.00 INTRM1, TRIPCAS CIRC P CBU w/ rot and recip F/10,136 T/10,079', 1000gpm, 2300 psi, 39% FO, 150 rpm, 14K tq, 11.9 ECD. Pumped 12,500 stks, 50ppm max gas 10,136.0 10,136.0 5/31/2023 14:00 5/31/2023 18:00 4.00 INTRM1, TRIPCAS CIRC P BROOH F/10,136' T/9,640'. CBU x3 w/ perform 540 bbl whole mud dilution. Begin increase lube concentration to 3%. 1000gpm, 2350 psi, 160 rpm, 12K tq. PUW=128K, SOW=127K, RTW=139K 10,136.0 9,640.0 5/31/2023 18:00 6/1/2023 00:00 6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 9,640' T/ 8,437'. Increased lube concentration to 3%. 1000gpm, 2266 psi, 39% FO, 170rpm, 12K tq, PUW=141K, SOW=130K, RTW=140K 9,640.0 8,437.0 6/1/2023 00:00 6/1/2023 06:00 6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 8,437' T/ 7,300'. 1000gpm, 2103 psi, 41% FO, 170rpm, 12K tq, PUW=154K, SOW=130K, RTW=139K, 11.65 ECD 8,437.0 7,300.0 6/1/2023 06:00 6/1/2023 12:00 6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 7,300' T/ 6,186'. 1000gpm, 1960 psi, 42% FO, 170rpm, 11K tq, 11.70 ECD. Perform 275 bbl whole mud dilution at 6,200' for MBT. 7,300.0 6,186.0 6/1/2023 12:00 6/1/2023 18:00 6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 6,186' T/ 4,778'. 1000gpm, 1825 psi, 42% FO, 170rpm, 11K tq, 11.44 ECD. 6,186.0 4,778.0 6/1/2023 18:00 6/2/2023 00:00 6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 4,778' T/ 3,500'. 1000gpm, 1688 psi, 42% FO, 160rpm, 6K tq, 11.39 ECD. Perform 275 bbl whole mud dilution at 3,960' for MBT. 4,778.0 3,500.0 6/2/2023 00:00 6/2/2023 10:30 10.50 INTRM1, TRIPCAS BKRM P BROOH F/ 3,500' T/ 1,550'. 1000gpm, 1120 psi, 39% FO, 100rpm, 3K tq, 11.39 ECD. 3,500.0 1,550.0 6/2/2023 10:30 6/2/2023 11:15 0.75 INTRM1, TRIPCAS CIRC P Circ hole clean, 1000 gpm, 1100 psi, 41% FO, 100 rpm, 11.33 ECD, 7000 stks total. Blow down TD, line up on trip tank 1,550.0 1,550.0 6/2/2023 11:15 6/2/2023 11:30 0.25 INTRM1, TRIPCAS OWFF P Flow check, static 15 min. 1,550.0 1,550.0 6/2/2023 11:30 6/2/2023 12:00 0.50 INTRM1, TRIPCAS TRIP P POOH F/1,550' T/930' on trip tank. 118K PUW, 122K SOW 1,550.0 930.0 6/2/2023 12:00 6/2/2023 12:45 0.75 INTRM1, TRIPCAS TRIP P POOH F/930' T/441' on trip tank. 95K PUW 930.0 441.0 6/2/2023 12:45 6/2/2023 13:00 0.25 INTRM1, TRIPCAS OWFF P Flow check, static 15 min. 441.0 441.0 6/2/2023 13:00 6/2/2023 14:00 1.00 INTRM1, TRIPCAS BHAH P LD 3 Jts 5-7/8" HWDP to shed F/441' T/350' 441.0 350.0 6/2/2023 14:00 6/2/2023 15:00 1.00 INTRM1, TRIPCAS BHAH P Stand back 1 std 5-7/8" HWDP, 1 std 5- 7/8" HWDP w/ Jars F/350' T/158' 350.0 158.0 6/2/2023 15:00 6/2/2023 16:15 1.25 INTRM1, TRIPCAS BHAH P LD BHA to top of SADN8 F/158' T/110' 158.0 110.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 20/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/2/2023 16:15 6/2/2023 17:00 0.75 INTRM1, TRIPCAS BHAH P SLB remove sources 110.0 110.0 6/2/2023 17:00 6/2/2023 18:45 1.75 INTRM1, TRIPCAS BHAH P LD BHA. F/158' T/Surface 110.0 0.0 6/2/2023 18:45 6/2/2023 19:30 0.75 INTRM1, TRIPCAS BHAH P Break bit and LD Powerdrive. Bit Grading : 1-2-CT-A-X-I-BT-TD 0.0 0.0 6/2/2023 19:30 6/2/2023 20:00 0.50 INTRM1, TRIPCAS BHAH P Clear floor of BHA w/ drain stack and rinse 0.0 0.0 6/2/2023 20:00 6/2/2023 20:15 0.25 INTRM1, CASING RURD P PU 2 Jts 5" DP and MU wear ring puller. 0.0 0.0 6/2/2023 20:15 6/2/2023 20:30 0.25 INTRM1, CASING RURD P RIH w/ wear ring puller, stopped 5' high, pulled out, wear ring puller covered in clay. 0.0 0.0 6/2/2023 20:30 6/2/2023 20:45 0.25 INTRM1, CASING RURD P BO wear ring puller, put dbl 5" DP in mouse hole. 0.0 0.0 6/2/2023 20:45 6/2/2023 21:00 0.25 INTRM1, CASING WWWH P PU stand of 5-7/8" DP, MU stack washer 0.0 0.0 6/2/2023 21:00 6/2/2023 21:45 0.75 INTRM1, CASING WWWH P Wash stack F/60' to T/10'. 10 rpm, 900 gpm. 0.0 0.0 6/2/2023 21:45 6/2/2023 22:00 0.25 INTRM1, CASING WWWH P Blow down TD, break stack washer, Rack back std 5-7/8" DP 0.0 0.0 6/2/2023 22:00 6/2/2023 22:15 0.25 INTRM1, CASING RURD P PU 5" DP dbl, MU wear ring puller, Pull wear ring. 0.0 0.0 6/2/2023 22:15 6/2/2023 22:30 0.25 INTRM1, CASING RURD P MU test plug, observed large amount of clay in riser top 0.0 0.0 6/2/2023 22:30 6/3/2023 00:00 1.50 INTRM1, CASING WWWH P MU stack washer w/ std 5-7/8" DP, Wash stack F/5' to 40'. 10 rpm, 1300 gpm. 0.0 0.0 6/3/2023 00:00 6/3/2023 01:00 1.00 INTRM1, CASING WWWH P Wash stack F/5' to 40'. 10 rpm, 1300 gpm, 210 psi, 10 rpm, RD stack washer 0.0 0.0 6/3/2023 01:00 6/3/2023 01:30 0.50 INTRM1, CASING RURD P Set lower test plug per FMC w/ 2 Jts 5" DP 0.0 0.0 6/3/2023 01:30 6/3/2023 02:30 1.00 INTRM1, CASING RURD P Swap Upper pipe rams F/ 4-1/2 x 7-5/8 VBR to 9-5/8 solid body rams. SIMOPS: Mobilize casing equip to floor 0.0 0.0 6/3/2023 02:30 6/3/2023 03:00 0.50 INTRM1, CASING RURD P Pressure up Koomey system, adjust annular pressure for 9-5/8, check for leaks, set 9-5/8 test Jt, check spacing ok 0.0 0.0 6/3/2023 03:00 6/3/2023 03:30 0.50 INTRM1, CASING RURD P Flush and fluid pack stack/Test Jt with water, bleed air out of test system 0.0 0.0 6/3/2023 03:30 6/3/2023 04:00 0.50 INTRM1, CASING BOPE P Test upper 9-5/8 solid body rams to 250/3500 foir 5 min ea, charted. 0.0 0.0 6/3/2023 04:00 6/3/2023 04:15 0.25 INTRM1, CASING RURD P RD test equipment, blow down test lines 0.0 0.0 6/3/2023 04:15 6/3/2023 05:00 0.75 INTRM1, CASING RURD P Pull test plug per FMC, LD tyest plug, test JT, drain stack, blow down kill line. 0.0 0.0 6/3/2023 05:00 6/3/2023 06:00 1.00 INTRM1, CASING RURD P MU Volant, cement swivel and XO to TD and Tq per casing rep and SOP. RU casing equipment, prep shed for dummy run 0.0 0.0 6/3/2023 06:00 6/3/2023 06:15 0.25 INTRM1, CASING RURD P Remove Volant stand from floor, PU casing hanger to floor 0.0 0.0 6/3/2023 06:15 6/3/2023 07:45 1.50 INTRM1, CASING RURD P MU 9-5/8 casing hanger, landing Jt and pup Jt. Dummy run hanger and land at expected depth. Mark landing Jt. LD landing Jt , pup and hanger. 0.0 0.0 6/3/2023 07:45 6/3/2023 09:15 1.50 INTRM1, CASING RURD P Mobilize strap tongs, 350T slips and centralizers to floor. RU strap tongs and slips. Adjust chain on Volant swivel. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 21/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/3/2023 09:15 6/3/2023 11:15 2.00 INTRM1, CASING PUTB P MU 9-5/8", 47#, T95, H563 casing shoe track T/179'. Backerlok to pin of Jt #4. Torque to 16K. Circ through and check floats. 0.0 179.0 6/3/2023 11:15 6/3/2023 12:00 0.75 INTRM1, CASING PUTB P RIH W/ 9-5/8", 47#, T95, H563 casing F/179' T/351'. Fill pipe on the fly, top off every 10 Jts, Tq to 16K, monitor displacement on pit #5. 91K PUW, 91K SOW 179.0 351.0 6/3/2023 12:00 6/3/2023 18:00 6.00 INTRM1, CASING PUTB P RIH W/ 9-5/8", 47#, T95, H563 casing F/351' T/2,339'. Fill pipe on the fly, top off every 10 Jts, Tq to 16K, monitor displacement on pit #5. 156K PUW, 152K SOW 351.0 2,339.0 6/3/2023 18:00 6/4/2023 00:00 6.00 INTRM1, CASING PUTB P RIH W/ 9-5/8", 47#, T95, H563 casing F/2,339' T/4,756'. Fill pipe on the fly, top off every 10 Jts, Tq to 16K, monitor displacement on pit #5. 180K PUW, 166K SOW 2,339.0 4,756.0 6/4/2023 00:00 6/4/2023 03:00 3.00 INTRM1, CASING PUTB P RIH W/ 9-5/8", 47#, T95, H563 casing F/4,756' T/6,092'. Fill pipe on the fly, top off every 10 Jts, Tq to 16K, monitor displacement on pit #5. 156K PUW, 166K SOW 4,756.0 6,092.0 6/4/2023 03:00 6/4/2023 04:00 1.00 INTRM1, CASING CIRC P CBU, Reciprocate F/6,092' T/6,071'. Stage up pump rate to 8 bpm. 224 psi, 17% FO, 192K PUW, 164K SOW. Pumped 3500 stks 6,092.0 6,092.0 6/4/2023 04:00 6/4/2023 12:00 8.00 INTRM1, CASING PUTB P RIH W/ 9-5/8", 47#, T95, H563 casing F/6,092' T/9,597'. Fill pipe on the fly, top off every 10 Jts, Tq to 16K, monitor displacement on pit #5. 255K PUW, 162K SOW 6,092.0 9,597.0 6/4/2023 12:00 6/4/2023 13:30 1.50 INTRM1, CASING PUTB P RIH W/ 9-5/8", 47#, T95, H563 casing F/9,597' T/10,068'. Fill pipe on the fly, top off every 10 Jts, Tq to 16K, monitor displacement on pit #5. Calc disp=168 bbls, Actual disp=163 bbls 265K PUW, 162K SOW 9,597.0 10,068.0 6/4/2023 13:30 6/4/2023 14:15 0.75 INTRM1, CASING PUTB P MU Hanger, Landing Jt and LJ pup. Land casing on hanger at 10,125' 10,068.0 10,125.0 6/4/2023 14:15 6/4/2023 18:15 4.00 INTRM1, CEMENT CIRC P Circulate and condition mud for cement. No reciprocation. Stage up pump rate to 6 bpm, 360-220 psi. Swap to cement line. 10,125.0 10,125.0 6/4/2023 18:15 6/4/2023 19:00 0.75 INTRM1, CEMENT CIRC P Noticed bubbling from small pond off pad. Notified Security, ACS and Control room. Pad operators came out, determined to be gas and normal occurrence this time of year with thaw. Decision made to continue operations and monitor. Bubbling stopped soon after. 10,125.0 10,125.0 6/4/2023 19:00 6/4/2023 19:45 0.75 INTRM1, CEMENT CIRC P Continue prep for cement, circulate through cement line w/ PJSM. 10,125.0 10,125.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 22/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/4/2023 19:45 6/5/2023 00:00 4.25 INTRM1, CEMENT CMNT P Swap to cementers. Flood lines w/ water and PT to 3700 psi (good). Pump 73.7 bbls 12.0 ppg mud push @ 3.5 bpm, 227-114 psi. Drop Btm plug. Chase plug with 175.5 bbls of 15.8 ppg cement @ 4.4 bpm, 200-90 psi. Drop top plug. Chase plug w/ 20 bbls of water @ 5.5 bpm, 50 psi. Swap to rig pumps. Pump treated 10.8 FWP at 6 bpm, ICP – 50 psi. At 4600 stks observe bottom plug land, reduce rate to 3 bpm for the last 100 bbls per plan for ECD control. Bump plug at 6062 stks. pressure up t/ 900 psi. hold for 5 min. bleed off check floats (good). CIP @ 2354 hrs. Full returns throughout job. No losses. 10,125.0 10,125.0 6/5/2023 00:00 6/5/2023 02:00 2.00 INTRM1, CEMENT RURD P Blow down cement equip, line. RD 2" hard iron and hose. LD LJ and pup, wash casing equip, brk down Volant, elevators,, bail extensions. Clear floor. 0.0 0.0 6/5/2023 02:00 6/5/2023 04:00 2.00 INTRM1, CEMENT WWSP P Drain stack, MU FMC pack-off running tool on 2 Jts 5" DP. RIH w/ packoff, set and test to 5K for 10 min. LD running tool. Set upper test plug, LD 2 Jts 5" DP 0.0 0.0 6/5/2023 04:00 6/5/2023 06:00 2.00 INTRM1, CEMENT RURD P Close blinds, change UPR to new style 4-1/2" x 7-5/8" VBR's. SIMOPS: Prep for BOP test, MU floor valves, RU to test TD, MU 7-5/8 test Jt 0.0 0.0 6/5/2023 06:00 6/5/2023 07:15 1.25 INTRM1, CEMENT RURD P Install 7-5/8 test Jt. Function upper pipe rams 5 times to break in per break in procedure. Install 2nd valve on IA. Remove 7-5/8 test Jt. 0.0 0.0 6/5/2023 07:15 6/5/2023 08:00 0.75 INTRM1, CEMENT RURD P MU 4-1/2" test Jt and 3 pups. Install 4- 1/2" test Jt, function upper pipe rams 5 times per break in procedure. 0.0 0.0 6/5/2023 08:00 6/5/2023 09:00 1.00 INTRM1, WHDBOP BOPE P Perform BOPE test. Perform Koomey drawdown test, ACC = 3000 psi, Manifold = 1475 psi, ACC = 1700 psi after functions on bottles, 28 sec to build 200 psi w/ 2 elec pumps, 143 sec to full system pressure w/ 2 elec pumps and 6 air pumps. Nitrogen 10 bottle avg = 3900 psi. Closing times: Annular = 19 sec, UPR = 16 sec, Blind/Shear = 14 sec, LPR = 14 sec, Test PVT gain/loss and flow out alarms. Test LEL and H2S alarms. Witnessed by Brian Bixby AOGCC rep. SIMOPS: RU to test, fill stack w/ H2O and purge lines of air. 0.0 0.0 6/5/2023 09:00 6/5/2023 12:00 3.00 INTRM1, WHDBOP BOPE P Perform BOPE test w/ 4-1/2" test Jt. 250/3500 psi for 5 min each charted. Test #1 = Annular w/ 4-1/2" test Jt, kill #3, Upper IBOP, Choke valves #1, 14, 15, 16. Test #2 = 4-1/2" x 7-5/8" Upper pipe rams w/ 4-1/2" test Jt, HCR kill, lower IBOP, choke valves #10, 13 and needle valve on #1. Test #3 = Choke valves #4, 9, 12 and 5-7/8" Dart valve. Test #4 = Choke valves #6, 8, 11 and 5- 7/8" TIW valve. Test #5= Choke valves #5 and 7. Test #6 = Choke valve #2. Test #7 = HCR choke and 4-1/2" Dart valve. Witnessed by Brian Bixby AOGCC rep. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 23/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/5/2023 12:00 6/5/2023 16:45 4.75 INTRM1, WHDBOP BOPE P Perform BOPE test w/ 4-1/2", 5-7/8" and 7-5/8" test Jts. 250/3500 psi for 5 min each charted. Test #8 = Manual choke, manual kill and 4-1/2" test Jt. Test #9 = 3-1/2" x 6-5/8" lower pipe rams w/ 4-1/2" test Jt. Test #10 = 3-1/2" x 6-5/8" lower pipe rams w/ 5-7/8" test Jt. Test #11 = 4- 1/2" x 7-5/8" upper pipe rams w/ 7-5/8" test Jt. Test #12 = Blind rams and choke #3. Test #13 = Manual and Super choke. Witnessed by Brian Bixby AOGCC rep. 0.0 0.0 6/5/2023 16:45 6/5/2023 18:00 1.25 INTRM1, DRILLOUT RURD P Pull test plug, drain stack, blow down choke and kill lines. Install wear ring w/ 8.6251" ID, LD running tool, 7-5/8 test Jt and pups. 0.0 0.0 6/5/2023 18:00 6/5/2023 20:00 2.00 INTRM1, DRILLOUT RURD P Cont RD test equip. Mobilize BHA to floor. SIMOPS: Service TD, grease wash pipe and IBOPs. 0.0 0.0 6/5/2023 20:00 6/6/2023 00:00 4.00 INTRM1, DRILLOUT BHAH P PJSM, MU BHA T/ 386' 0.0 386.0 6/6/2023 00:00 6/6/2023 04:00 4.00 INTRM1, DRILLOUT PULD P Single in BHA on 4-1/2" DP from shed F/ 386' T/ 2,297'. 108K PUW, 100K SOW. Monitor displacement on TT, fill pipe every 20 stds. 386.0 2,297.0 6/6/2023 04:00 6/6/2023 04:30 0.50 INTRM1, DRILLOUT DHEQ P Fill pipe, test MWD tools. 550 gpm, 1319 psi, 37% FO 2,297.0 2,297.0 6/6/2023 04:30 6/6/2023 06:00 1.50 INTRM1, DRILLOUT PULD P Single in BHA on 4-1/2" DP from shed F/ 2,297' T/ 3,264'. 120K PUW, 109K SOW. Monitor displacement on TT, fill pipe every 20 stds. 2,297.0 3,264.0 6/6/2023 06:00 6/6/2023 08:45 2.75 INTRM1, DRILLOUT PULD P Single in BHA on 4-1/2" DP from shed F/ 3,264' T/ 5,097'. 124K PUW, 99K SOW. Monitor displacement on TT, fill pipe every 20 stds. 3,264.0 5,097.0 6/6/2023 08:45 6/6/2023 12:00 3.25 INTRM1, DRILLOUT TRIP P Install XO, RIH with 5-7/8" DP from derrick. F/ 5,097' T/ 8,164'. 143K PUW, 106K SOW. Monitor displacement on TT, fill pipe every 20 stds. 5,097.0 8,164.0 6/6/2023 12:00 6/6/2023 13:15 1.25 INTRM1, DRILLOUT TRIP P RIH with 5-7/8" DP from derrick. F/ 8,164' T/ 9,743'. 162K PUW, 90K SOW. Monitor displacement on TT, fill pipe every 20 stds. 8,164.0 9,743.0 6/6/2023 13:15 6/6/2023 14:30 1.25 INTRM1, DRILLOUT CIRC P Circ and condition mud for casing test. 600 gpm, 2700 psi 9,743.0 9,743.0 6/6/2023 14:30 6/6/2023 15:45 1.25 INTRM1, DRILLOUT RURD P RU for casing test, purge air from lines 9,743.0 9,743.0 6/6/2023 15:45 6/6/2023 16:45 1.00 INTRM1, DRILLOUT PRTS P Test 9-5/8", 47#, T95, Int 1 casing. 3850 psi for 30 min charted. Pump .5 bpm, 9.5 bbls. Bled back 9.4 bbls. 9,743.0 9,743.0 6/6/2023 16:45 6/6/2023 17:15 0.50 INTRM1, DRILLOUT RURD P RD casing test equip, LD working single not in string. 9,743.0 9,743.0 6/6/2023 17:15 6/6/2023 22:00 4.75 INTRM1, DRILLOUT MPDA P Test MPD system with new software successfully. Remove MPD element/bearing. SIMOPS: Freeze protect OA with 90 bbls diesel. Break over occurred at 10.75 bbls pumped at 17.5 EMW below FIT of 17.7 EMW. 9,743.0 9,743.0 6/6/2023 22:00 6/6/2023 23:30 1.50 INTRM1, DRILLOUT REAM P Wash and Ream to plugs F/9,743' T/ 10,031'. Tag on depth. 550 gpm, 2331 psi. 40 rpm, 11K tq. 23% FO, 180K PUW, 120K SOW. 155K RTW 9,743.0 10,031.0 6/6/2023 23:30 6/7/2023 00:00 0.50 INTRM1, DRILLOUT DRLG P Drill plugs on FC F/ 10,031' T/ 10,032'. 550 gpm, 2391 psi. 40 rpm, 18K tq. 12K WOB, 23% FO, 135K RTW. 10,031.0 10,032.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 24/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/7/2023 00:00 6/7/2023 02:00 2.00 INTRM1, DRILLOUT DRLG P Drill plugs on FC F/ 10,032' T/ 10,035' MD. 550 gpm 2391 psi 40 rpm Tq 18K WOB 12K FO 23% ROT 135K 10,032.0 10,035.0 6/7/2023 02:00 6/7/2023 05:30 3.50 INTRM1, DRILLOUT DRLG P Drill cement in shoe track from 10,035'- 10,122' MD. Tag 9-5/8" shoe on depth at 10,122' MD. 500 gpm 1988 psi 60 rpm Tq 20K WOB 15K FO 25% ROT 139K 10,035.0 10,122.0 6/7/2023 05:30 6/7/2023 06:00 0.50 INTRM1, DRILLOUT DRLG P Drill shoe from 10,122'-10,125' MD. 500 gpm 1956 psi 60 rpm Tq 19K WOB 5-6K FO 25% ROT 140K 10,122.0 10,125.0 6/7/2023 06:00 6/7/2023 06:30 0.50 INTRM1, DRILLOUT CIRC P Pull inside shoe and obtain slow circulating rates. 10,125.0 10,125.0 6/7/2023 06:30 6/7/2023 07:00 0.50 INTRM1, DRILLOUT DRLG P Drill out cement in rat hole from 10,125'- 10,136' MD. 550 gpm 2250 psi 60 rpm Tq 17K FO 25% PU 177K SO 80K ROT 140K 10,125.0 10,136.0 6/7/2023 07:00 6/7/2023 07:30 0.50 INTRM1, DRILLOUT REAM P Dress shoe from 10,136'-10,120' MD. 500 gpm 1975 psi 40 rpm Tq 15K FO 25% 10,136.0 10,136.0 6/7/2023 07:30 6/7/2023 08:15 0.75 INTRM1, DRILLOUT DDRL P Drill 20' of new hole from 10,136'- 10,156' MD. 550 gpm 2250 psi 60 rpm Tq 17K WOB 7-8K PU 177K SO 80K ROT 131K 10,136.0 10,156.0 6/7/2023 08:15 6/7/2023 10:00 1.75 INTRM1, DRILLOUT CIRC P Circulate 2 bottoms up racking back a stand from 10,156'-10,051' MD. 550 gpm 2300 psi 40 rpm Tq 15K ROT 126K 10,156.0 10,051.0 6/7/2023 10:00 6/7/2023 10:30 0.50 INTRM1, DRILLOUT RURD P Rig up test equipment & fluid pack lines. 10,051.0 10,051.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 25/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/7/2023 10:30 6/7/2023 11:30 1.00 INTRM1, DRILLOUT FIT P Perform FIT to an EMW of 14.0 ppg with a 10.4 ppg mud at 10,125' MD, 3478' TVD. Pump 1.6 bbls pressuring up to 653 psi. Shut in and observe pressure for 10 minutes, with a final pressure of 602 psi. Bled back 1.4 bbls. 10,051.0 10,051.0 6/7/2023 11:30 6/7/2023 12:30 1.00 INTRM2, DRILL RURD P Rig down test equipment and blow down lines. Retrieve FIT data from MWD. 10,051.0 10,051.0 6/7/2023 12:30 6/7/2023 13:00 0.50 INTRM2, DRILL MPDA P Install MPD bearing as per MPD Advisor. 10,051.0 10,051.0 6/7/2023 13:00 6/7/2023 13:30 0.50 INTRM2, DRILL SFTY P PJSM for displacement with all personnel. 10,051.0 10,051.0 6/7/2023 13:30 6/7/2023 14:30 1.00 INTRM2, DRILL CLEN P Prep pits for displacement, offloading mud & moving mud in pit system. 10,051.0 10,051.0 6/7/2023 14:30 6/7/2023 16:00 1.50 INTRM2, DRILL DISP P Displace mud system from a 10.4 ppg FWP to an 9.5 FWP. Pump 50 bbls of 11.5 ppg hi-vis spacer. Displace with 650 bbls of 9.5 ppg FWP. Observed 100 bbls of interface at surface. 650 gpm 2290 psi 40 rpm Tq 9-11K 10,051.0 10,051.0 6/7/2023 16:00 6/7/2023 16:15 0.25 INTRM2, DRILL CIRC P Obtain slow circulating rates with new mud system & MPD. 10,051.0 10,051.0 6/7/2023 16:15 6/7/2023 17:15 1.00 INTRM2, DRILL WASH P Wash down from 10,051'-10,156' MD. 600 gpm 2010 psi 40 rpm Tq 4-7K 12.37 ECD ROT 127K 10,051.0 10,156.0 6/7/2023 17:15 6/7/2023 19:30 2.25 INTRM2, DRILL DDRL P Directional drill intermediate 2 section from 10,156'-10,296' MD, 3500' TVD. Hold 550 psi on connections with MPD. 600 gpm 2030 psi 80 rpm Tq 12K WOB 5-10K ECD 12.58 PU 175K SO 90K ROT 127K ADT 2.75, Bit hrs 2.75, Jars 117.19 10,156.0 10,296.0 6/7/2023 19:30 6/7/2023 20:00 0.50 INTRM2, DRILL CIRC P Record baseline parameters for activating reamer. 700 gpm 2460 psi 80 rpm Tq 7K TRPM 4350 PU 146K SO 110K ROT 126K 10,296.0 10,260.0 6/7/2023 20:00 6/7/2023 22:30 2.50 INTRM2, DRILL MPDA T Noticed RCD element material on a tool joint. Investigated to find new bearing with less than 6 hours on it had seized up. Change out RCD per Advisor maintaining 550 psi down hole. 10,260.0 10,260.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 26/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/7/2023 22:30 6/7/2023 23:30 1.00 INTRM2, DRILL CIRC P Open 9-1/2" reamer per SLB DD. Drop 1.25" activation ball. Pump at 250 gpm, 875 psi for 500 strokes. Reduce rate to 100 gpm, 710 psi to see ball on seat at 1080 strokes total. Pressure up to 1557 psi to see reamer activation. Increase flow rate up to 700 gpm, 2200 psi, 60 rpm, Tq 10K, TRPM 4000. 10,260.0 10,260.0 6/7/2023 23:30 6/8/2023 00:00 0.50 INTRM2, DRILL REAM P Ream from 10,260'-10,265' MD. Confirm reamer open with 10K over slack off & pick up weights on ledges. 700 gpm 2200 psi 60 rpm Tq 10K PU 146K SO 110K 10,260.0 10,265.0 6/8/2023 00:00 6/8/2023 00:30 0.50 INTRM2, DRILL REAM P Ream from 10,265'-10,296' MD. 700 gpm 2212 psi 80 rpm WOB 3K Tq 10K PU 146K SO 110K ROT 147K 10,265.0 10,296.0 6/8/2023 00:30 6/8/2023 06:00 5.50 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 10,269'-10,675' MD, 3540' TVD. Holding 12.5 ppg EMWon connections with MPD. 700 gpm 2256 psi 140 rpm Tq on 14K. off 10K WOB 9K ECD 12.69 PU 160K SO 105K ROT 136K ADT 4.43, Bit hrs 7.18, Jars 121.62 Total Gas 6 10,296.0 10,675.0 6/8/2023 06:00 6/8/2023 12:00 6.00 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 10,675'-10,909' MD, 3564' TVD. Holding 12.5 ppg EMW on connections with MPD. 650-750 gpm 2051-2256 psi 140-160 rpm Tq on 12K. off 0K WOB 17K ECD 12.56 PU 160K SO 105K ROT 136K ADT 4.45, Bit hrs 11.63, Jars 126.07 Total Gas 6 10,675.0 10,909.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 27/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/8/2023 12:00 6/8/2023 14:00 2.00 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 10,909'-10,952' MD, 3571' TVD. Holding 12.5 ppg EMW on connections with MPD. 730 gpm 2430 psi 160 rpm Tq on 11K. off 10K WOB 9-14K ECD 12.76 PU 160K SO 105K ROT 136K ADT 1.61, Bit hrs 13.24, Jars 127.68 Total Gas 6 10,909.0 10,952.0 6/8/2023 14:00 6/8/2023 15:45 1.75 INTRM2, DRILL CIRC T Observed losses around 60 bph. Racked back stand and pumped 45 bbls of LCM at 35 ppb reciprocating. Pick up last stand to return to drilling. 550 gpm 1550 psi 150 rpm Tq 9-11K ECD 12.5 ppg 10,952.0 10,952.0 6/8/2023 15:45 6/8/2023 16:30 0.75 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 10,952'-10,979' MD, 3573' TVD. Holding 12.5 ppg EMW on connections with MPD. Losses at ~40 bph were observed at 10,957' MD. 730 gpm 2430 psi 160 rpm Tq on 11K. off 10K WOB 9-14K ECD 12.76 PU 160K SO 105K ROT 136K ADT .26, Bit hrs 13.5, Jars 127.94 Total Gas 6 10,952.0 10,979.0 6/8/2023 16:30 6/8/2023 17:00 0.50 INTRM2, DRILL CIRC T Pump 45 bbls of 35 ppb LCM pill at 700 gpm, 116 rpm, Tq 8-13K. Slow pumps to 300 gpm, 960 psi as pill passed through the BHA. 10,979.0 10,979.0 6/8/2023 17:00 6/8/2023 18:00 1.00 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 10,979'-11,036' MD, 3581' TVD. Holding 12.5 ppg EMW on connections with MPD. Losses at ~40 bph were observed decreasing. 700 gpm 2250 psi 160 rpm Tq on 14K. off 10K WOB 5-13K ECD 12.58 PU 167K SO 104K ROT 142K ADT .46, Bit hrs 14.44, Jars 128.88 Total Gas 6 10,979.0 11,036.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 28/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/8/2023 18:00 6/8/2023 23:15 5.25 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 11,036'-11,201' MD, 3599' TVD. Holding 12.5 ppg EMW on connections with MPD. Observed indications that debris might be around the BHA. 650 gpm 2112 psi 150 rpm Tq on 14K. off 10K WOB 12K ECD 12.85 PU 167K SO 104K ROT 142K ADT 3.83, Bit hrs 18.27, Jars 132.71 Total Gas 6 11,036.0 11,201.0 6/8/2023 23:15 6/9/2023 00:00 0.75 INTRM2, DRILL BKRM T Observe ECD fluctuations, higher weight on bit at surface with little to no down hole weight on bit, erratic torque & decrease ROP. Discuss with town and try varying parameters to work past debris. 11,201.0 11,201.0 6/9/2023 00:00 6/9/2023 06:00 6.00 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 11,201'-11,562' MD, 3641' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2138 psi 160 rpm Tq on 15K. off 10K WOB 10K ECD 12.54 PU 170K SO 102K ROT 145K ADT 4.05, Bit hrs 22.32, Jars 136.76 Total Gas 21 11,201.0 11,562.0 6/9/2023 06:00 6/9/2023 08:30 2.50 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 11,562'-11,688' MD, 3655' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2180 psi 160 rpm Tq on 14K. off 10K WOB 14K ECD 12.7 PU 171K SO 103K ROT 142K ADT 2.2, Bit hrs 23.13, Jars 137.57 Total Gas 0 11,562.0 11,688.0 6/9/2023 08:30 6/9/2023 09:15 0.75 INTRM2, DRILL CIRC T Observe ECD fluctuations, higher weight on bit at surface with little to no down hole weight on bit, erratic torque & decrease ROP. Backream full stand to clear debris from BHA. 650 gpm 2070 psi 160 rpm Tq 10K ECD 12.07 11,688.0 11,688.0 6/9/2023 09:15 6/9/2023 09:45 0.50 INTRM2, DRILL SVRG P Service top drive. SIMOPS change out grabber dies on top drive. 11,688.0 11,688.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 29/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/9/2023 09:45 6/9/2023 10:45 1.00 INTRM2, DRILL RGRP T Finish changing out torque wrench dies on top drive. 11,688.0 11,688.0 6/9/2023 10:45 6/9/2023 12:00 1.25 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 11,688'-11,781' MD, 3664' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2130 psi 160 rpm Tq on 12-14K. off 10K WOB 15K ECD 12.4 PU 175K SO 103K ROT 139K ADT .81, Bit hrs 25.33, Jars 139.77 Total Gas 17 11,688.0 11,781.0 6/9/2023 12:00 6/9/2023 18:00 6.00 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 11,781'-12,190' MD, 3717' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2167 psi 160 rpm Tq on 15-17K. off 14K WOB 11-12K ECD 12.37 PU 177K SO 103K ROT 138K ADT 4.17, Bit hrs 29.50, Jars 143.94 Total Gas 100 11,781.0 12,190.0 6/9/2023 18:00 6/10/2023 00:00 6.00 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 12,190'-12,574' MD, 3771' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2300 psi 160 rpm Tq on 16K. off 14K WOB 12K ECD 12.45 PU 178K SO 104K ROT 136K ADT 4.75, Bit hrs 34.25, Jars 148.69 Total Gas 70 12,190.0 12,574.0 6/10/2023 00:00 6/10/2023 06:00 6.00 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 12,574'-12,892' MD, 3811' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2260 psi 160 rpm Tq on 19K. off 17K WOB 9-14K ECD 12.58 PU 189K SO 97K ROT 139K ADT 4.31, Bit hrs 38.56, Jars 153.0 Total Gas 80 12,574.0 12,892.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 30/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/10/2023 06:00 6/10/2023 07:30 1.50 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 12,892'-12,985' MD, 3828' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2310 psi 160 rpm Tq on 22K. off 20K WOB 9-11K ECD 12.73 PU 189K SO 97K ROT 139K ADT 1.25, Bit hrs 39.81, Jars 154.25 Total Gas 65 12,892.0 12,985.0 6/10/2023 07:30 6/10/2023 08:00 0.50 INTRM2, DRILL BKRM P Ream stand #135 for high torque & ECD from 12,985' - 12,890' MD. 650 gpm 2230 psi 100 rpm Tq 20K PU ROT 138K SO ROT 130K 12,985.0 12,985.0 6/10/2023 08:00 6/10/2023 12:00 4.00 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 12,985'-13264' MD, 3887' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2258 psi 160 rpm Tq on 24-26K, off 13K WOB 11-13K ECD 12.43 PU 220K SO N/A ROT 152K ADT 3.18, Bit hrs 42.99, Jars 157.43 Total Gas 341 12,985.0 13,264.0 6/10/2023 12:00 6/10/2023 13:30 1.50 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 13,264'-13,357' MD, 3904' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2240 psi 160 rpm Tq on 26K, off 22K WOB 14K ECD 12.41 PU 220K SO N/A ROT 152K ADT 1.33, Bit hrs 44.32, Jars 158.76 Total Gas 323 13,264.0 13,357.0 6/10/2023 13:30 6/10/2023 14:15 0.75 INTRM2, DRILL BKRM P Ream stand #139 for high torque & ECD from 13,357' - 13,262' MD. 700 gpm 2400 psi 100 rpm Tq 24K PU ROT 139K SO ROT 132K 13,357.0 13,357.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 31/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/10/2023 14:15 6/10/2023 18:00 3.75 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 13,357'-13,665' MD, 3959' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2227 psi 160 rpm Tq on 25K, off 22K WOB 15K ECD 12.42 PU 220K SO N/A ROT 137K ADT 2.51, Bit hrs 46.38, Jars 161.27 Total Gas 159 13,357.0 13,665.0 6/10/2023 18:00 6/11/2023 00:00 6.00 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 13,665'-14,041' MD, 4027' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2220 psi 160 rpm Tq on 28K, off 25K WOB 10K ECD 12.36 PU 254K SO N/A ROT 147K ADT 4.32, Bit hrs 51.15, Jars 165.59 Total Gas 157 13,665.0 14,041.0 6/11/2023 00:00 6/11/2023 04:30 4.50 INTRM2, DRILL DDRL P Directional drill 8.5" X 9.5" intermediate 2 section from 14,041'-14,230' MD, 4060' TVD. Holding 12.5 ppg EMW on connections with MPD. Pump 40 bbl nut plug sweeps every other stand. 650 gpm 2090 psi 160 rpm Tq on 27K, off 23K WOB 7K ECD 12.14 PU 254K SO N/A ROT 147K ADT 4.32, Bit hrs 51.15, Jars 165.59 Total Gas 69 14,041.0 14,230.0 6/11/2023 04:30 6/11/2023 05:45 1.25 INTRM2, TRIPCAS CIRC P Drop 1.625" steel deactivation ball & pump down to cycle the reamer closed. Pump down at 250 gpm & 100 gpm; 945 psi & 739 psi. Ball on seat with 158.7 bbls pumped, pressuring up and shearing at 2222 psi. Good indication that reamer closed with increases observed at 2080 psi to 2180 psi; MWD trpm 2460 to 2656; RSS trpm3720 to 4070. 14,230.0 14,230.0 6/11/2023 05:45 6/11/2023 06:15 0.50 INTRM2, TRIPCAS CIRC P Send final down links to MWD. Collect slow circulating rates & final torque / drag. 100 gpm = 780 psi 30 rpm = Tq 12K PU 182K SO 113K ROT 146K 14,230.0 14,230.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 32/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/11/2023 06:15 6/11/2023 08:00 1.75 INTRM2, TRIPCAS CIRC P Circulate 2 bottoms up from 14,230'- 14,108' MD. Rack back a stand on each bottoms up. 650 gpm = 2180 psi 140 rpm = Tq 11K ECD 12.15 PU ROT 139K SO ROT 137K 14,230.0 14,108.0 6/11/2023 08:00 6/11/2023 12:00 4.00 INTRM2, TRIPCAS BKRM P Back ream out of the hole from 14,108'- 13,170' MD, maintaining an EMW of 12.2 ppg on connection with MPD. 650 gpm = 2140 psi 140 rpm = Tq 9-11K ECD 12.11 PU ROT 139K 14,108.0 13,170.0 6/11/2023 12:00 6/11/2023 18:00 6.00 INTRM2, TRIPCAS BKRM P Back ream out of the hole from 13,170'- 11,313' MD, maintaining an EMW of 12.2 ppg with MPD on connections. 650 gpm = 2100 psi 140 rpm = Tq 10-12K ECD 12.10 PU ROT 135K 13,170.0 11,313.0 6/11/2023 18:00 6/11/2023 21:45 3.75 INTRM2, TRIPCAS BKRM P Back ream out of the hole from 11,313'- 10,300' MD, maintaining an EMW of 12.2 ppg with MPD on connections. 650 gpm = 2050 psi 140 rpm = Tq 10-12K ECD 12.10 PU ROT 135K 11,313.0 10,300.0 6/11/2023 21:45 6/11/2023 23:15 1.50 INTRM2, TRIPCAS PMPO P Pump out of the hole, pulling BHA through the shoe from 10,300'-10,115' MD. 650 gpm = 2150 psi PU 152K 10,300.0 10,115.0 6/11/2023 23:15 6/12/2023 00:00 0.75 INTRM2, TRIPCAS CIRC P Drop 2.115" steel ball to cycle the Well Commander open. Pump down at 250 gpm = 860 psi & 100 gpm = 685 psi; ball on seat with 94 bbls pumped. Pressure up to 2018 psi to observe cycle open. 10,115.0 10,115.0 6/12/2023 00:00 6/12/2023 01:45 1.75 INTRM2, TRIPCAS CIRC P Circulate and reciprocate from 10,115' MD to 10,026' MD with the well commander open. 1,000 gpm, 1,980 psi, 120 rpm and 9,000 ft-lbs torque. 129k RTW / 148k PUW. 10,115.0 10,115.0 6/12/2023 01:45 6/12/2023 02:45 1.00 INTRM2, TRIPCAS CIRC P Drop 2.11" ball to cycle well commander closed as per SLB DD representative. 250 gpm, 582 psi. At 350 strokes away reduced rate to 100 gpm, 540 psi. Ball on seat at 799 strokes away 1,212 psi. Shear at 1,922 psi and 806 strokes. 10,115.0 10,115.0 6/12/2023 02:45 6/12/2023 04:30 1.75 INTRM2, TRIPCAS CIRC P At 10,072' MD observed 80 bbls of losses at 12.9 ppg ECD. Shut down and trapped 12.5 ppg EMW. Began step down to 11.9 ppg EMW. 10,115.0 10,072.0 6/12/2023 04:30 6/12/2023 05:30 1.00 INTRM2, TRIPCAS CIRC T Spot 50 bbls 40 ppb pill at 450 gpm / 1,540 psi. Shut down and trap 12.0 ppg EMW at the intermediate 1 shoe. Increase ECD increased from 12.0 ppg to 12.9 ppg while circulating out HiVis spacer. 10,072.0 10,072.0 6/12/2023 05:30 6/12/2023 06:00 0.50 INTRM2, TRIPCAS CIRC T Stage flow rate up to 450 gpm / 1,225 psi. Maintain 12.5 ppg EMW at the intermediate 1 shoe. 10,072.0 10,072.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 33/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/12/2023 06:00 6/12/2023 08:30 2.50 INTRM2, TRIPCAS CIRC T Circulate and condition mud system. Continue preppring the pits for exhale test and displacement. 450 gpm / 1,400 psi. 10,072.0 10,072.0 6/12/2023 08:30 6/12/2023 15:15 6.75 INTRM2, TRIPCAS OWFF P Perform exhale test with 9.2 ppg. Slowly staging down the MPD backpressure on the well from 540 psi to achieve 11.0 ppg EMW at TD. 10,072.0 10,072.0 6/12/2023 15:15 6/12/2023 16:15 1.00 INTRM2, TRIPCAS CIRC P Stage up flow rate to 450 gpm, 1,225 psi maintaining 11.3 ppg EMW. Establish parameters, obtain SPR's and stripping schedule. Drop 2.88" OD hollow drift. 10,072.0 10,110.0 6/12/2023 16:15 6/12/2023 18:00 1.75 INTRM2, TRIPCAS TRIP P Strip out of the hole with 5-7/8" DP from 10,110' MD to 8,553' MD maintaining 11.3 ppg EMW with MPD. 10,110.0 8,553.0 6/12/2023 18:00 6/12/2023 20:30 2.50 INTRM2, TRIPCAS TRIP P Strip out of the hole with 5-7/8" DP from 8,553' MD to 6,028' MD maintaining 11.3 ppg EMW with MPD. 8,553.0 6,028.0 6/12/2023 20:30 6/13/2023 00:00 3.50 INTRM2, TRIPCAS CIRC P PJSM. Spot 50 bbls high viscosity 10.3 ppg spacer and strip out of the hole from 6,028' MD to 5,348' MD. 6,028.0 5,348.0 6/13/2023 00:00 6/13/2023 02:30 2.50 INTRM2, TRIPCAS OWFF P Observed the well for flow. 5,348.0 5,348.0 6/13/2023 02:30 6/13/2023 06:00 3.50 INTRM2, TRIPCAS RURD P RD 5-7/8" MPD bearing and RU 4-1/2" bearing. 5,348.0 5,348.0 6/13/2023 06:00 6/13/2023 09:00 3.00 INTRM2, TRIPCAS TRIP P Continue SOOH to 856' MD. 5,348.0 856.0 6/13/2023 09:00 6/13/2023 13:00 4.00 INTRM2, TRIPCAS OWFF P Observed the well for flow. 856.0 856.0 6/13/2023 13:00 6/13/2023 13:45 0.75 INTRM2, TRIPCAS RURD P RD the 4-1/2" MPD bearing. Observed the well for flow. 856.0 856.0 6/13/2023 13:45 6/13/2023 14:30 0.75 INTRM2, TRIPCAS TRIP P POOH with 4-1/2" DP from 856' MD to 386' MD. Recover 2.88" hollow drift. Monitor displacement via trip tank. 856.0 386.0 6/13/2023 14:30 6/13/2023 19:00 4.50 INTRM2, TRIPCAS BHAH P LD BHA #3. LD jars, MU single to 5-7/8" DP and rack back in the derrick. Continue LD BHA. Inspect all BHA components and gauge stabilizers. 386.0 0.0 6/13/2023 19:00 6/13/2023 20:45 1.75 INTRM2, CASING BHAH P PU 1 stand of 5-7/8" DP out of the derrick and MU stack washer. Perform weekly BOP cycle on annular, UPR's, LPR's and flush at 450 gpm / 75 psi. Rack back stand and blow down top drive and kill line. 0.0 0.0 6/13/2023 20:45 6/13/2023 22:00 1.25 INTRM2, CASING RURD P RU 7-5/8" casing running equipment, power tongs, elevators etc. SIMOPS - Prep mud pits for liner run. 0.0 0.0 6/13/2023 22:00 6/14/2023 00:00 2.00 INTRM2, CASING PUTB P PJSM, PU and MU 7-5/8" L-80 29.7# H523 shoetrack, MU torque = 12k ft-lbs using best of life 2000. Baker-lok shoe track assembly. 0.0 40.0 6/14/2023 00:00 6/14/2023 02:30 2.50 INTRM2, CASING PUTB P PU and RIH with 7-5/8" 29.7# and 39# shoe track and liner per running order. Follow trip speeds filling every joint and topping off every 10th joint. 0.0 294.0 6/14/2023 02:30 6/14/2023 06:00 3.50 INTRM2, CASING PUTB P RIH with 7-5/8" 29.7# and 39# from 294' MD to 1,801' MD. Follow trip schedule per section plan filling every joint and topping off every 10 joints. 294.0 1,801.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 34/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/14/2023 06:00 6/14/2023 12:00 6.00 INTRM2, CASING PUTB P RIH with 7-5/8" 29.7# Hydril 523 liner from 1,801' MD to 3,752' MD slackoff weight = 109k lbs. Follow trip schedule filling every joint and topping off every 10 joints. Monitoring displacement in pit #1. 1,801.0 3,752.0 6/14/2023 12:00 6/14/2023 15:00 3.00 INTRM2, CASING PUTB P RIH with 7-5/8" Hydril 523 liner from 3,752' MD to 4,293' MD following trip schedule. Filling every joint and topping off every 10 joints. 3,752.0 4,293.0 6/14/2023 15:00 6/14/2023 16:00 1.00 INTRM2, CASING RURD P PJSM, rig down casing equipment. Prepare for picking up 7-5/8" liner hanger. 4,293.0 4,293.0 6/14/2023 16:00 6/14/2023 17:30 1.50 INTRM2, CASING OTHR P PU 7-5/8" liner hanger assembly, MU liner wiper plugs, torque hanger to 7- 5/8" string. RIH on 5-7/8" DP to 4,372' MD. 4,293.0 4,372.0 6/14/2023 17:30 6/14/2023 18:45 1.25 INTRM2, CASING RURD P PJSM for RCD bearing installation. Install 5-7/8" RCD bearing. 4,372.0 4,372.0 6/14/2023 18:45 6/15/2023 00:00 5.25 INTRM2, CASING RUNL P RIH from 4,372' MD to 5,826' MD with 7- 5/8" 29.7# Hydril 523 liner on 5-7/8" DP out of the derrick. PU = 159k lbs., SO = 93k lbs. at 15 fpm. Following trip schedule filling every stand and topping off every 5 stands. 4,372.0 5,826.0 6/15/2023 00:00 6/15/2023 06:00 6.00 INTRM2, CASING RUNL P RIH from 4,430' MD to 9.062' MD with 7- 5/8" 29.7# H523 liner on 5-7/8" DP. PU = 159K SOW = 84K at 30 fpm. 4,430.0 9,062.0 6/15/2023 06:00 6/15/2023 09:00 3.00 INTRM2, CASING RUNL P RIH from 9,062' MD to 9,409' MD. Lost slackoff, worked pipe and continued RIH from 9,409' MD to 9,803' MD with 7-5/8" 29.7# H523 liner on 5-7/8" DP. 9,062.0 9,803.0 6/15/2023 09:00 6/15/2023 10:00 1.00 INTRM2, CASING RURD P OWFF 30 min. Pulled MPD bearing to reduce friction running in the hole and increase slackoff. 9,803.0 9,803.0 6/15/2023 10:00 6/15/2023 12:00 2.00 INTRM2, CASING RUNL P RIH from 9,803' MD to 10,891' MD with 7-5/8" 29.7# H523 liner on 5-7/8" DP. PUW / SOW 170k / 90k at 9-5/8" intermediate 1 shoe. 9,803.0 10,891.0 6/15/2023 12:00 6/15/2023 17:15 5.25 INTRM2, CASING RUNL P RIH from 10,891' MD to 13,341' MD with 7-5/8" 29.7# H523 liner on 5-7/8" DP / HWDP. 10,891.0 13,341.0 6/15/2023 17:15 6/15/2023 18:00 0.75 INTRM2, CASING RUNL P RIH from 13,341' MD to 13,957' MD with H523 7-5/8" liner on 5-7/8" HWDP. 13,341.0 13,957.0 6/15/2023 18:00 6/16/2023 00:00 6.00 INTRM2, CASING RUNL P Washed and rotated from 13,957' MD to 14,230' MD with 7-5/8" 29.7# H523 liner on 5-7/8" DP / HWDP. Tag depth at 14,230' MD and mark for space out of hanger. Set down with 5k lbs. with good indication. 0.5 BPM / 480 psi. RTW = 163k lbs / 20 rpm / 12k ft-lbs 13,957.0 14,230.0 6/16/2023 00:00 6/16/2023 06:00 6.00 INTRM2, CEMENT CIRC P Circulate and reciprocate from 14,208' MD to 14,190' MD. Establish parameters from 0.5 BPM to 5.6 BPM 530 psi / 2% return flow. 9.4 ppg FWP in and 9.8 - 11.3 ppg FWP out. RTW = 165K lbs / TQ = 12K ft-lbs. / RPM = 20 SIMOPS: Remove 3" cement hose from derrick and blow down for upcoming cement job. Mobilize two 5-7/8" pup joints to the rig floor (5.1' and 6.02') 14,230.0 14,230.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 35/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/16/2023 06:00 6/16/2023 08:00 2.00 INTRM2, CEMENT CIRC P Continue circulating and reciprocating from 14,208' MD to 14,190' MD. 5.6 BPM 520 psi / 2% return flow. 9.5 ppg FWP in and 9.5 ppg FWP out. RTW = 167K fbs / TQ = 11ft-lbs / RPM = 20 14,230.0 14,230.0 6/16/2023 08:00 6/16/2023 08:30 0.50 INTRM2, CEMENT RURD P Lay down 5-7/8" DP working single. Make up 6.02' 5-7/8" DP pup (drifted to 3.75") and blow down the top drive. 14,230.0 14,230.0 6/16/2023 08:30 6/16/2023 10:30 2.00 INTRM2, CEMENT RURD P PJSM. Pick up citadel cement head and make up hydril valve to verify function. Make up citadel cement head to string. Make up cement hose. Attempt to move pipe, overpull 50k lbs. Slack off neutral, rotate 20 rpm and breakover at 26k ft- lbs torque. 14,230.0 14,230.0 6/16/2023 10:30 6/16/2023 11:00 0.50 INTRM2, CEMENT CIRC P Establish circulation and stage up flow rate to 5.5 bpm / 570 psi. 14,230.0 14,230.0 6/16/2023 11:00 6/16/2023 12:00 1.00 INTRM2, CEMENT CMNT P PJSM with SLB cementers. Pressure test cement line to 6,500 psi. Pump cement with SLB cement unit. 42.4 bbls of 12.0 ppg mud push, 123.4 bbls 15.8# cement / 20 bbls H2O. 14,230.0 14,230.0 6/16/2023 12:00 6/16/2023 14:15 2.25 INTRM2, CEMENT CMNT P Continue pumping cement with SLB cement unit. Swap over to rig and displace with 9.5 ppg FWP at 5 BPM / 600 psi. Good indication plugs bumped on calculated strokes. Hold 500 psi over final circulating pressure for 5 min. Bleed off and verify floats holding (good). No losses during cement job. 14,230.0 14,230.0 6/16/2023 14:15 6/16/2023 15:00 0.75 INTRM2, CEMENT CMNT P Set DrilQuip liner hanger per DrilQuip rep. Slack off on string, pick up to 190k lbs. at 14,225' MD to place string in tension. 7-5/8" liner TOL at 9,912.92' MD. Pressure up on string at 1 BPM. Shear out with 3,799 psi, continue pressuring up to 5,000 psi to expand hanger and hold for 10 minutes. Bleed off pressure. Pick up 310k lbs. (70k lbs over) to verify dogs set. Slack off to 110k lbs. to auto release. 14,230.0 14,230.0 6/16/2023 15:00 6/16/2023 15:15 0.25 INTRM2, CEMENT PRTS P Close annular, open up to the kill line. Pressure up on the back side at 1 BPM to 2,000 psi to test the liner top for 10 mintues. Monitor the drillstring for communication. (Good test) 14,230.0 14,230.0 6/16/2023 15:15 6/16/2023 16:30 1.25 INTRM2, CEMENT OTHR P Blow down and rig down the cement hose. Rig down the citadel cement head. Flush cement head with water and lay down in the pipe shed. Lay down 6.02' 5-7/8" drill pipe pup. 14,230.0 14,230.0 6/16/2023 16:30 6/16/2023 17:15 0.75 INTRM2, CEMENT TRIP P POOH from 9,937' MD to 9,748' MD. Rack back 5-7/8" DP in the derrick and lay down the 5-7/8" HWDP. 9,937.0 9,748.0 6/16/2023 17:15 6/16/2023 18:00 0.75 INTRM2, CEMENT OTHR P Kelly up and pressure up on the drillstring to shear DrilQuip ball seat and shear with 6,557 psi. 9,748.0 9,748.0 6/16/2023 18:00 6/16/2023 19:30 1.50 INTRM2, CEMENT CIRC P Pump foam ball down the drillstring. Rotate and reciprocate 2x bottoms up from 9,748' MD to 9,653' MD at 630 gpm / 1,238 psi. 9,748.0 9,653.0 6/16/2023 19:30 6/17/2023 00:00 4.50 INTRM2, CEMENT TRIP P POOH racking back 5-7/8" DP from 9,653' MD to 4,545' MD. 9,653.0 4,545.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 36/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/17/2023 00:00 6/17/2023 03:30 3.50 INTRM2, CEMENT TRIP P POOH from 4,505' MD to 52.5' MD racking back 5-7/8" DP in the derrick. Lay down 5-7/8" HWDP. 4,545.0 52.5 6/17/2023 03:30 6/17/2023 05:00 1.50 INTRM2, CEMENT BHAH P Inspect TIW 7-5/8" running tool assembly and lay down in pipe shed. 52.5 0.0 6/17/2023 05:00 6/17/2023 06:45 1.75 INTRM2, WHDBOP OTHR P PU and MU stack washer with 1 stand of 5-7/8" DP and drain the BOP. Perform weekly cycle on the annular / UPR / LPR. Flush BOP stack / wear ring profile and kill with H2O at 235 GPM. MU 5- 7/8" and 4-1/2" TIW / dart valves. 0.0 0.0 6/17/2023 06:45 6/17/2023 08:00 1.25 INTRM2, WHDBOP NUND P Pull wear ring and set test plug per FMC rep. RU test fittings and hoses. Flood lines, choke manifold and BOP stack with H2O. 0.0 0.0 6/17/2023 08:00 6/17/2023 12:00 4.00 INTRM2, WHDBOP BOPE P Perform BOP test with 5-7/8" test joint. All tests 250 psi low / 3,500 psi high - annular, upper 4-1/2" x 7-5/8" VBR's, lower 3-1/2" x 6-5/8" VBR's, CM #1-16, manual choke and kill, HCR choke and kill, kill valve #3, upper / lower IBOPS, 5 -7/8" TIW and dart valve, 4-1/2" TIW and dart valve. Witness waived by AOGCC rep (Adam Earl) 0.0 0.0 6/17/2023 12:00 6/17/2023 15:00 3.00 INTRM2, WHDBOP BOPE P Continue BOP test with 4-1/2" test joint. All tests 250 psi / 3,500 psi high - annular, upper 4-1/2" x 7-5/8" VBR's, lower 3-1/2" x 6-5/8" VBR's, blind / shears. Test man and super choke to 1,500 psi, bleed to 1,000 psi and hold. Conduct koomey drawdown, accumulator = 3,050 psi, manifold = 1,500 psi, accumulator = 1,700 psi after all functions, 12 seconds for 200 psi. Build with 2 electric pumps, 89 seconds to full system pressure with 2 electric and 6 air pumps, closing times: annular = 16 seconds. UPR = 14 seconds. Blind / shears = 14 seconds LPR = 13 seconds. Choke HCR = 1 second. Kill HCR = 1 second - Average nitrogen back up = 3,950 psi from 10 bottles. Test LEL and H2S alarms. Witness wavied by AOGCC rep (Adam Earl) 0.0 0.0 6/17/2023 15:00 6/17/2023 15:30 0.50 INTRM2, WHDBOP NUND P Pull FMC test plug, set wear ring and run in lock down screws. 0.0 0.0 6/17/2023 15:30 6/17/2023 16:00 0.50 INTRM2, WHDBOP RURD P Drain stack of water, blow down lines and manifolds. Rig down testing equipment. Clear floor. 0.0 0.0 6/17/2023 16:00 6/17/2023 17:00 1.00 INTRM2, DRILLOUT BHAH P Mobilize BHA components to rig floor. Prep floor and handling equipment for making up the BHA. 0.0 0.0 6/17/2023 17:00 6/17/2023 22:00 5.00 INTRM2, DRILLOUT BHAH P PJSM. PU and MU 6-1/2" production BHA per DD / MWD from 0' to 305' MD. SIMOPS - load pits with 8.6 ppg OBM for upcoming displacement. 0.0 305.0 6/17/2023 22:00 6/18/2023 00:00 2.00 INTRM2, DRILLOUT PULD P RIH with 4-1/2" DP singles out of the pipe shed from 305' to 1,247' MD. 305.0 1,247.0 6/18/2023 00:00 6/18/2023 02:30 2.50 INTRM2, DRILLOUT TRIP P Continue to RIH with 4-1/2" DP singles out of the pipe shed from 1,247' MD to 2,190'. Fill pipe every 20 stds 1,247.0 2,190.0 6/18/2023 02:30 6/18/2023 03:30 1.00 INTRM2, DRILLOUT TRIP P Fill pipe @ 2,190', Test Directional and MWD tools @ 24gpm, 1450psi,40 rpm, 11k torque 2,190.0 2,190.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 37/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/18/2023 03:30 6/18/2023 06:30 3.00 INTRM2, DRILLOUT TRIP P Continue to RIH with 4-1/2" DP singles out of the pipe shed from 2,190' to 4,210'. Fill pipe every 20 stds 2,190.0 4,210.0 6/18/2023 06:30 6/18/2023 07:00 0.50 INTRM2, DRILLOUT TRIP P Fill pipe @ 4,210', Test Directional and MWD tools @ 24gpm, 1450psi,40 rpm, 11k torque 4,210.0 4,210.0 6/18/2023 07:00 6/18/2023 09:00 2.00 INTRM2, DRILLOUT TRIP P Continue to RIH with 4-1/2" DP singles out of the pipe shed from 4,210' to 6,624'. Fill pipe every 20 stds 4,210.0 6,624.0 6/18/2023 09:00 6/18/2023 11:00 2.00 INTRM2, DRILLOUT TRIP P Continue to RIH with 4-1/2" DP from derrick from 6,624' to 9,922'. Fill pipe every 20 stds 6,624.0 9,922.0 6/18/2023 11:00 6/18/2023 13:30 2.50 INTRM2, DRILLOUT DRLG P Wash and ream down to 9,935'. Tag up on DPOB @ 9,935' GPM=230, PSI=1660, RPM=60, TQ=8K. Drill through DPOB, Circulate bottoms up, minimal debris back to surface. Note: Wash and ream through DOPB several times and work through without rotary as well. 9,922.0 10,015.0 6/18/2023 13:30 6/18/2023 18:00 4.50 INTRM2, DRILLOUT QEVL P RIH from 10,015' to 13,415' MD. Begin logging down with SonicScope as per DD/ MWD with 4-1/2" & 5-7/8" DP at 1800 fph. Wash / ream through tigth spots seen at 13,130' MD, 13,338' MD and 13,420' MD. 240 GPM / 2075 psi. PUW = 177k lbs / SOW = 119k lbs. / RTW = 140k lbs. 10,015.0 13,415.0 6/18/2023 18:00 6/18/2023 20:30 2.50 INTRM2, DRILLOUT DLOG P RIH to 13,929' MD at 1,800 fph logging with SonicScope. Ream through cement stringers. Tag plugs at 13,929' MD. Set down 9k lbs. twice to confirm. 240 GPM / 2,100 psi / 20 rpm / 3k ft-lbs torque. 13,415.0 13,929.0 6/18/2023 20:30 6/18/2023 23:00 2.50 INTRM2, DRILLOUT CIRC P Circulate bottoms up with reciprocation and rotation from 13,928' to 13,855' MD. Rig up and prepare for casing pressure test. 13,929.0 13,929.0 6/18/2023 23:00 6/19/2023 00:00 1.00 INTRM2, DRILLOUT PRTS P Begin pressure testing 9-5/8" x 7-5/8" casing and liner. 13,929.0 13,929.0 6/19/2023 00:00 6/19/2023 03:30 3.50 INTRM2, DRILLOUT PRTS T Pressure testing 7-5/8" x 9-5/8" casing and liner to 3600psi for 30min, Charted. Note: did not pressure up to the target 3850psi due to the pipe being light at surface. Consult Town/Engineering 13,929.0 13,929.0 6/19/2023 03:30 6/19/2023 04:00 0.50 INTRM2, DRILLOUT PRTS T Rig down test equipment / blow down top drive 13,929.0 13,929.0 6/19/2023 04:00 6/19/2023 07:30 3.50 INTRM2, DRILLOUT SLPC P PJSM and cut and slip drilling line, Service topdrive, drawworks, brakes, traveling blocks. Inspect all rig equipment per sop 13,929.0 13,929.0 6/19/2023 07:30 6/19/2023 08:30 1.00 INTRM2, DRILLOUT PRTS P Consult town/engineering for testing to 3850psi, PJSM and pick up 4 1/2" dp, Make up XO's to Top Drive. Space out in BOP stack, fill lines. 13,929.0 13,929.0 6/19/2023 08:30 6/19/2023 10:00 1.50 INTRM2, DRILLOUT PRTS P Perform pressure test of 7-5/8" x 9-5/8" casing and liner to 3896psi for 30min, Charted test, Good test, Pumped and bled back ~12.7bbls 13,929.0 13,929.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 38/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/19/2023 10:00 6/19/2023 11:00 1.00 INTRM2, DRILLOUT RURD P Rig down casing and liner testing equipment, clean and clear floor. LD 4- 1/2" DP single, RIH from 13,486' MD and tag plugs at 13,929' MD. PUW = 175k lbs. / SOW = 109k lbs. / RTW = 138k lbs. 13,929.0 13,929.0 6/19/2023 11:00 6/19/2023 12:00 1.00 INTRM2, DRILLOUT DRLG P Drill out first plug / landing collar from 13,929' MD to 13,930' MD with 200 GPM / 1700 psi / 50 rpm / 17k ft-lbs. / 6 -10 k lbs. WOB 13,929.0 13,930.0 6/19/2023 12:00 6/19/2023 14:30 2.50 INTRM2, DRILLOUT DRLG P Continue drilling out the plugs / landing collar from 13,930' MD to 13,933' MD. 240 GPM / 2175 psi / 50 rpm / 19-24k ft- lbs. / 9-13k lbs WOB. Make three passes through with rotary and three passes through without rotary. 13,930.0 13,933.0 6/19/2023 14:30 6/19/2023 18:00 3.50 INTRM2, DRILLOUT DRLG P Drilling cement from 13,933' MD to 14,030' MD. 230 GPM / 2437 psi / 90 rpm / 20k ft-lbs / 15-20k lbs WOB 13,933.0 14,030.0 6/19/2023 18:00 6/19/2023 19:15 1.25 INTRM2, DRILLOUT DRLG P Ream cement from 14,030' MD to 14,099' MD. Tag plugs / float collar 230 gpm / 2437 psi / 80 rpm / 20k ft-lbs. / 2- 12k lbs. WOB. Prep mud pits for upcoming displacement and install 5- 7/8" MPD bearing. 14,030.0 14,099.0 6/19/2023 19:15 6/19/2023 22:00 2.75 INTRM2, DRILLOUT DRLG P Ream plugs / float collar from 14,099' to 14,103' MD. 14,099.0 14,103.0 6/19/2023 22:00 6/20/2023 00:00 2.00 INTRM2, DRILLOUT RURD P PJSM. Install 5-7/8" bearing. Begin displacing to OBM. 14,103.0 14,103.0 6/20/2023 00:00 6/20/2023 01:30 1.50 INTRM2, DRILLOUT MPDA P OWFF & PJSM on install 5 7/8 RCD bearing per the MPD Rep, Obtain SPR's 14,103.0 14,130.0 6/20/2023 01:30 6/20/2023 04:30 3.00 INTRM2, DRILLOUT DISP P PJSM and displace well from 9.5ppg mw WBM to 8.6ppg mw @ 240gpm w/2650. Observed 76bbls interface 14,130.0 14,130.0 6/20/2023 04:30 6/20/2023 07:30 3.00 INTRM2, DRILLOUT DRLG P Establish circulation through MPD and obtain new SPR's. Drill Cement and Shoe track f/14,130' to 14,230'. Ream through shoe 5 x, Tag shoe @ 14,222' 14,130.0 14,230.0 6/20/2023 07:30 6/20/2023 08:30 1.00 INTRM2, DRILLOUT DDRL P Drill 20' new hole for FIT from 14,230' to 14,250', Gpm=225, Psi=2200, Rpm=80, Tq=13k, Wob=6-8k, Mpd-dynamic-psi=300psi, Mpd-static- psi=20psi 14,230.0 14,250.0 6/20/2023 08:30 6/20/2023 10:30 2.00 INTRM2, DRILLOUT CIRC P Circulate and condition mud for FIT Mw- in=8.7, Mw-out=8.7, Gpm=250, Psi=2500, Rpm=50, Tq=13k, Stand back one stand to 14,125' 14,250.0 14,125.0 6/20/2023 10:30 6/20/2023 12:00 1.50 INTRM2, DRILLOUT FIT P PJSM - Line up to perform FIT test. Dynamically trap 305 psi with MPD, Mud weight = 8.7ppg, Perform FIT to 13.0ppg emw with 910psi. FIT charted. Pumped 1.8bbls and Bleed off 1.8bbls. RD line & Equipment 14,125.0 14,125.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 39/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/20/2023 12:00 6/20/2023 18:00 6.00 PROD1, DRILL DDRL P Operating under a dispensation to drill with statically underbalanced mud weight, while maintaining overbalance with MPD. Meeting dispensation criteria by holding 10.0 ppg EMW at 7-5/8" shoe at all times.Obtain SPR's, wash and ream down from 14,125' - 14,250' MD. Drill 6-1/2" production hole from 14,250 - 14,599' MD / 4,124' TVD. 100 RPM / 17k ft-lbs. on bottom / 14k ft-lbs. off bottom / 4k lbs. WOB. PUW / SOW / RTW = 231k lbs. / NA / 149k lbs. 387 units max gas. 14,125.0 14,599.0 6/20/2023 18:00 6/21/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 14,599' to 14,936' MD / 4,185' TVD. Maintaining 10.0 ppg EMW at the shoe per dispensation. 260 GPM / 2,630 psi / 100 RPM / 17k ft-lbs. on bottom / 14k ft- lbs off bottom / 2-9k lbs WOB. PUW / SOW / RTW = 231k lbs. / NA / 149k lbs. 140 units max. gas. 14,599.0 14,936.0 6/21/2023 00:00 6/21/2023 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 14,936' to 15,264' MD. Maintaining 10.0 ppg EMW at the shoe per dispensation. 260 GPM / 2,650 psi / 120 RPM / 16k ft- lbs. on bottom / 14k ft-lbs off bottom / 2- 7k lbs WOB. PUW / SOW / RTW = 231k lbs. / NA / 151k lbs. 165 units max. gas. ADT=4.5 / Bit Hrs=14.17 14,936.0 15,264.0 6/21/2023 06:00 6/21/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 15,264' to 15,623' MD. Maintaining 10.0 ppg EMW at the shoe per dispensation. 260 GPM / 2,630 psi / 110 RPM / 16k ft- lbs. on bottom / 11k ft-lbs off bottom / 2- 5k lbs WOB. PUW / SOW / RTW = 239k lbs. / NA / 153k lbs. 160 units max. gas. ADT=4.89 / Bit Hrs=19.06 15,264.0 15,623.0 6/21/2023 12:00 6/21/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 15,623' to 16,008' MD, 4,225' TVD. Maintaining 10.0 ppg EMW at the shoe per dispensation. 260 GPM / 2,532 psi / 100 RPM / 16k ft-lbs. on bottom / 17k ft- lbs off bottom / 3k lbs WOB. PUW / SOW / RTW = 239k lbs. / NA / 153k lbs. 158 units max. gas. ADT=4.93 / Bit Hrs=23.99 15,623.0 16,007.0 6/21/2023 18:00 6/22/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 16,008' to 16,350' MD, 4,231' TVD. Maintaining 10.0 ppg EMW at the shoe per dispensation. 260 GPM / 2,501 psi / 100 RPM / 18k ft-lbs. on bottom / 17k ft- lbs off bottom / 3k lbs WOB. 10.17 ECD / PUW / SOW / RTW = 234k / NA / 159k. 882 ppm max. gas. ADT=4.34 / Bit Hrs=28.33 16,007.0 16,350.0 6/22/2023 00:00 6/22/2023 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 16,350' to 16,723' MD, 4,251' TVD. Maintaining 10.0 ppg EMW at the shoe per dispensation. 260 GPM / 2,550 psi / 100 RPM / 17k ft-lbs. on bottom / 14k ft- lbs off bottom / 2-6k lbs WOB. 10.36 ECD / PUW / SOW / RTW = 249k / NA / 162k. 172 ppm max. gas. ADT=4.72 / Bit Hrs=33.05 16,350.0 16,723.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 40/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/22/2023 06:00 6/22/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 16,723' to 17,170' MD, 4,258' TVD. Maintaining 10.0 ppg EMW at the shoe per dispensation. 260 GPM / 2,605 psi / 100 RPM / 19k ft-lbs. on bottom / 19k ft- lbs off bottom / 2-4k lbs WOB. 10.34 ECD / PUW / SOW / RTW = 253k / NA / 164k. 117 ppm max. gas. ADT=4.70 / Bit Hrs=37.75 16,723.0 17,170.0 6/22/2023 12:00 6/22/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 17,170' to 17,595' MD, 4,261' TVD. Maintaining 10.0 ppg EMW at the shoe per dispensation. 260 GPM / 2,610 psi / 100 RPM / 19k ft-lbs. on bottom / 15k ft- lbs off bottom / 2-5k lbs WOB. 10.37 ECD / PUW / SOW / RTW = 262k / NA / 157k. 116 ppm max. gas. ADT=4.45 / Bit Hrs=42.20 17,170.0 17,595.0 6/22/2023 18:00 6/22/2023 21:00 3.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section from 17,595' to 17,815' MD, 4,261' TVD. Maintaining 10.0 ppg EMW at the shoe per dispensation. 260 GPM / 2,575 psi / 100 RPM / 20k ft-lbs. on bottom / 18k ft- lbs off bottom / 2-5k lbs WOB. 10.32 ECD / PUW / SOW / RTW = 261k / NA / 154k. 116 ppm max. gas. ADT=2.44 / Bit Hrs=44.64 17,595.0 17,815.0 6/22/2023 21:00 6/22/2023 22:00 1.00 PROD1, DRILL BKRM T Observed ECD spikes to 11.38. PU, BR to attempt to clear 17,815.0 17,741.0 6/22/2023 22:00 6/22/2023 22:30 0.50 PROD1, DRILL SVRG P Perform rig service, Top Drive, Blocks, Washpipe, ST-120 17,741.0 17,741.0 6/22/2023 22:30 6/22/2023 23:00 0.50 PROD1, DRILL BKRM T Troubleshoot Top Drive fault. Could not rotate. Call out electrician and reset SBC (Single Board Computer) 17,741.0 17,741.0 6/22/2023 23:00 6/23/2023 00:00 1.00 PROD1, DRILL BKRM T Work flow restriction, ECD spikes to 10.9-11.3. 17,741.0 17,741.0 6/23/2023 00:00 6/23/2023 06:00 6.00 PROD1, DRILL BKRM T Work BHA uphole. F/17,741' T/17,627' MD attempt clear partial restriction. Maintain 10.0 ppg EMW at shoe. High ECD,11.2-12.2 and losses with 215 gpm. Lost ~110 bbls mud. Move BHA uphole with low flow/RPM F/17,725' T/ 17,627'. 100 GPM, 890 PSI, 60 RPM, 22-30K TQ. PU ROT= 165K, SO ROT= 145K 17,741.0 17,627.0 6/23/2023 06:00 6/23/2023 12:00 6.00 PROD1, DRILL CIRC T Circ and reciprocate w/ stage up flow rate as hole would allow. Maintain 10.0 ppg EMW at shoe. 163 GPM, 1399 PSI, 55 RPM, 22-30K TQ, PU ROT= 165K, SO ROT= 149K 17,627.0 17,609.0 6/23/2023 12:00 6/23/2023 18:00 6.00 PROD1, DRILL CIRC T Circ and reciprocate w/ stage up flow rate as hole would allow. Maintain 10.0 ppg EMW at shoe. 240 GPM, 2344 PSI, 50-60 RPM, 22-30K TQ. PU ROT= 160K, SO ROT= 143K 17,609.0 17,620.0 6/23/2023 18:00 6/24/2023 00:00 6.00 PROD1, DRILL CIRC T Circ and reciprocate.Work to full flow and RPM, work stand to clean up wellbore. Maintain 10.0 ppg EMW at shoe. 260 GPM, 2610 PSI, 100 RPM, 17-22K TQ. PU ROT= 168K, SO ROT= 141K, ROT WT= 152K 17,620.0 17,547.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 41/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/24/2023 00:00 6/24/2023 02:30 2.50 PROD1, DRILL CIRC T Circ and reciprocate. Work stand to clean up wellbore of ECD and Torque spikes with full flow and RPM. Maintain 10.0 ppg EMW at shoe. 260 GPM, 2610 PSI, 100 RPM, 17-22K TQ. PU ROT= 168K, SO ROT= 141K, ROT WT= 152K. Max gas 18 ppm. 17,547.0 17,645.0 6/24/2023 02:30 6/24/2023 06:00 3.50 PROD1, DRILL REAM T Ream to bottom F/17,645' T/17,815' MD working ECD and TQ spikes till clean with full flow and RPM . 260 GPM, 2700 PSI. 100 RPM, 17K TQ, PU ROT= 163K, SO ROT= 135K, ROT WT= 143K. Max gas 45 ppm. 17,645.0 17,815.0 6/24/2023 06:00 6/24/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section with NOVOS from 17,815' to 18,121' MD, 4,274' TVD. Maintaining 10.2 ppg EMW at the shoe per dispensation. 260 GPM / 2,740 psi / 120 RPM / 20k ft-lbs on bottom / 18k ft-lbs off bottom / 3k lbs WOB. 10.32 ECD / PUW / SOW / RTW = 235k / NA / 161k. 76 ppm max. gas. ADT=3.61 / Bit Hrs=48.37. 17,815.0 18,121.0 6/24/2023 12:00 6/24/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section with NOVOS from 18,121' to 18,573' MD, 4,291' TVD. Maintaining 10.2 ppg EMW at the shoe per dispensation. 260 GPM / 2,871 psi / 110 RPM / 21k ft-lbs. on bottom / 20k ft-lbs off bottom / 7k lbs WOB. 10.7 ECD / PUW / SOW / RTW = 235k / NA / 161k. 147 ppm max. gas. ADT=5.01 / Bit Hrs=53.38 18,121.0 18,573.0 6/24/2023 18:00 6/25/2023 00:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section with NOVOS from 18,573' to 18,970' MD, 4,322' TVD. Maintaining 10.2 ppg EMW at the shoe per dispensation. 260 GPM / 2,775 psi / 120 RPM / 22k ft-lbs. on bottom / 21k ft-lbs off bottom / 7k lbs WOB. 10.79 ECD / PUW / SOW / RTW = 253k / NA / 158k. 203 ppm max. gas. Utilizing NOVOS for drilling and MPD ramp. ADT=4.17 / Bit Hrs=57.55 18,573.0 18,970.0 6/25/2023 00:00 6/25/2023 06:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section with NOVOS from 18,970' to 19,410' MD, 4,322' TVD. Maintaining 10.2 ppg EMW at the shoe per dispensation. 260 GPM / 2,795 psi / 120 RPM / 22k ft-lbs. on bottom / 21k ft-lbs off bottom / 8k lbs WOB. 10.78 ECD / PUW / SOW / RTW = 256k / NA / 161k. 120 ppm max. gas. Utilizing NOVOS for drilling. ADT=4.72 / Bit Hrs=62.27 18,970.0 19,410.0 6/25/2023 06:00 6/25/2023 12:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section with NOVOS from 19,410' to 19,783' MD, 4,368' TVD. Maintaining 10.2 ppg EMW at the shoe per dispensation. 260 GPM / 2,790 psi / 120 RPM / 22k ft-lbs. on bottom / 21k ft-lbs off bottom / 3k lbs WOB. 11.01 ECD / PUW / SOW / RTW = 266k / NA / 164k. 90 ppm max. gas. Utilizing NOVOS for drilling. ADT=4.41 / Bit Hrs=66.68 19,410.0 19,783.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 42/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/25/2023 12:00 6/25/2023 18:00 6.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section with NOVOS from 19,783' to 20,182' MD, 4,370' TVD. Maintaining 10.2 ppg EMW at the shoe per dispensation. 260 GPM / 2,838 psi / 120 RPM / 21k ft-lbs. on bottom / 19k ft-lbs off bottom / 9k lbs WOB. 11.04 ECD / PUW / SOW / RTW = 274k / NA / 163k. 125 ppm max. gas. Utilizing NOVOS for drilling. ADT=4.56 / Bit Hrs=71.24 19,783.0 20,182.0 6/25/2023 18:00 6/25/2023 22:00 4.00 PROD1, DRILL DDRL P Drill 6-1/2" production hole section with NOVOS from 20,182' to 20,427' MD, 4,375' TVD. Maintaining 10.2 ppg EMW at the shoe per dispensation. 260 GPM / 2,945 psi / 120 RPM / 24k ft-lbs. on bottom / 22k ft-lbs off bottom / 6k lbs WOB. 11.12 ECD / PUW / SOW / RTW = 278k / NA / 165k. 160 ppm max. gas. Utilizing NOVOS for drilling. Obtain final survey, T&D and SPR's ADT=2.73 / Bit Hrs=73.96 20,182.0 20,427.0 6/25/2023 22:00 6/26/2023 00:00 2.00 PROD1, TRIPCAS CIRC P Circulate and Reciprocate stand. 260 GPM, 2922 PSI, 120 RPM, 22K TQ, 11.1 ECD, PUW / SOW / RTW = 278k / NA / 165k. 119 ppm max. gas. 20,427.0 20,427.0 6/26/2023 00:00 6/26/2023 00:30 0.50 PROD1, TRIPCAS CIRC P Circulate and Reciprocate stand. 260 GPM, 2878 PSI, 120 RPM, 22K TQ, 11.08 ECD, PUW / SOW / RTW = 278k / NA / 165k. 119 ppm max. gas. Total Stks pumped=7000 20,427.0 20,427.0 6/26/2023 00:30 6/26/2023 01:00 0.50 PROD1, TRIPCAS FIT P Perform OH FIT test to 12.0 ppg EMW with 8.0 ppg MW. Isolated on pit #5. Rotate 10 rpm. Shut down MP, ramping MPD to 11.0 EMW, stage up MPD back pressure to 844 psi, 12.0 ppg EMW ok. 20,427.0 20,427.0 6/26/2023 01:00 6/26/2023 06:00 5.00 PROD1, TRIPCAS BKRM P BROOH F/20,427' T/19,499' MD, 260 GPM, 2750 PSI, 120 RPM, 21K TQ, 10.81 ECD, 276K PUW, 165K ROT WT 20,427.0 19,499.0 6/26/2023 06:00 6/26/2023 12:00 6.00 PROD1, TRIPCAS BKRM P BROOH F/19,499' T/17,883' MD, 260 GPM, 2455 PSI, 120 RPM, 16K TQ, 10.55 ECD, 165K ROT WT 19,499.0 17,833.0 6/26/2023 12:00 6/26/2023 12:45 0.75 PROD1, TRIPCAS BKRM P BROOH F/17,833' T/17,767' MD, 260 GPM, 2455 PSI, 120 RPM, 16K TQ, 10.55 ECD, 165K ROT WT. Experienced pressure spikes. 17,833.0 17,767.0 6/26/2023 12:45 6/26/2023 18:00 5.25 PROD1, TRIPCAS BKRM P Stage up flow rate/RPM. Attempt to clean up pressure spikes with full flow and RPM. No success. 17,767.0 17,736.0 6/26/2023 18:00 6/27/2023 00:00 6.00 PROD1, TRIPCAS BKRM P Reduce flow rate to 150 gpm, RPM to 50. Work area and stand till clean of pressure spikes. Low energy BROOH ok to 17,127' MD. Slowly staging up pump rate. 190 GPM, 1680 PSI, 75 RPM, 21K TQ, Holding 10.2 ppg EMW at shoe. 17,736.0 17,127.0 6/27/2023 00:00 6/27/2023 06:00 6.00 PROD1, TRIPCAS BKRM P BROOH F/17,127' T/15,697' MD, 260 GPM, 2556 PSI, 100 RPM, 19K TQ, 10.15 ECD, 149K ROT WT. Slowly staged up flow rate from 190-260 gpm. Holding 10.2 EMW at shoe. 17,127.0 15,697.0 6/27/2023 06:00 6/27/2023 12:00 6.00 PROD1, TRIPCAS BKRM P BROOH F/15,697' T/14,216' MD, 260 GPM, 2530 PSI, 100 RPM, 12K TQ, 10.16 ECD, 149K ROT WT. Holding 10.2 EMW at shoe. 15,697.0 14,216.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 43/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/27/2023 12:00 6/27/2023 14:15 2.25 PROD1, TRIPCAS BKRM P Rot & Recip W/ Circ at shoe. 260 gpm, 2540 psi, 80 RPM, 13K TQ, 10.29 ECD, 154K Rot WT up, 14K Rot Wt dwn. Holding 10.2 EMW at shoe. 14,216.0 14,216.0 6/27/2023 14:15 6/27/2023 14:30 0.25 PROD1, TRIPCAS SMPD P Obtain T&D at 14,216' MD. W/ 100 GPM, 800 PSI, 310 PSI MPD, 196K PUW, 104K SOW, 150K RTW, 8-10K TQ at 30 RPM 14,216.0 14,216.0 6/27/2023 14:30 6/27/2023 14:45 0.25 PROD1, TRIPCAS SMPD P Attempt to SIH, w/ MPD holding 450 PSI, lost SO wt w/ tool jt at MPD element 14,216.0 14,235.0 6/27/2023 14:45 6/27/2023 18:00 3.25 PROD1, TRIPCAS SMPD P Rotate in hole w/o pump F/14,235' T/15,232' MD, 20 RPM, 6-8K TQ, 500'/Hr, 127K Dwn Wt. MPD holding 10.2 EMW at shoe, Monitor displacement on pit #5, Fill pipe every 10 stds. 14,235.0 15,232.0 6/27/2023 18:00 6/28/2023 00:00 6.00 PROD1, TRIPCAS SMPD P Rotate in hole w/o pump F/15,232' T/16,535' MD, 20 RPM, 6-8K TQ, 500'/Hr, 127K Dwn Wt. MPD holding 10.2 EMW at shoe, Monitor displacement on pit #5, Fill pipe every 10 stds. 15,232.0 16,535.0 6/28/2023 00:00 6/28/2023 06:00 6.00 PROD1, TRIPCAS SMPD P Rotate in hole w/o pump F/16,535' T/18,300' MD, 20 RPM, 6-8K TQ, 500'/Hr, 122K Dwn Wt. MPD holding 10.2 EMW at shoe, Monitor displacement on pit #5, Fill pipe every 10 stds. 16,535.0 18,300.0 6/28/2023 06:00 6/28/2023 12:30 6.50 PROD1, TRIPCAS SMPD P Rotate in hole w/o pump F/18,300' T/20,243' MD, 20 RPM, 15-18K TQ, 500'/Hr, 125-130K Dwn Wt. MPD holding 10.2 EMW at shoe, Monitor displacement on pit #5, Fill pipe every 10 stds. 18,300.0 20,243.0 6/28/2023 12:30 6/28/2023 13:30 1.00 PROD1, TRIPCAS SMPD P Rotate in hole F/20,243' T/20,336'. Begin pumping slowly while rotate in. 50 GPM, 1500 PSI, 20 RPM, 18-20K TQ, 125-130K Dwn Wt. MPD holding 10.2 EMW at shoe, Monitor displacement on pit #5 20,243.0 20,336.0 6/28/2023 13:30 6/28/2023 15:30 2.00 PROD1, TRIPCAS SMPD P Rotate in hole F/20,336' T/20,426'. Stage up pump rate and rotary slowly while rotate in. 260 GPM, 2880 PSI, 50 RPM, 28-32K TQ, 145K Rot Dwn Wt. MPD holding 10.2 EMW at shoe, Monitor displacement on pit #5 20,336.0 20,426.0 6/28/2023 15:30 6/28/2023 18:00 2.50 PROD1, TRIPCAS CIRC P CBU, Rot & Recip, 260 GPM, 2830 PSI, 100 RPM, 28K TQ, 145K ROT Dwn, 159K ROT Up, MPD Holding 10.2 EMW at shoe. SIMOPS: Prep tank farm and pits for displacement. 20,426.0 20,426.0 6/28/2023 18:00 6/28/2023 20:30 2.50 PROD1, TRIPCAS DISP P Displace open volume and drill string w/ 650 bbls 10.1 ppg NAF w/ Rot & Recip. 260 GPM, 2780 PSI, 11.1 ECD. 20,426.0 20,345.0 6/28/2023 20:30 6/29/2023 00:00 3.50 PROD1, TRIPCAS SMPD P SOOH F/20,345' T/19,096' MD per stripping schedule. Racking 5-7/8 DP. 255K PUW, Monitor hole fill on pit #5 holding 10.2 ppg at shoe. 20,345.0 19,096.0 6/29/2023 00:00 6/29/2023 06:00 6.00 PROD1, TRIPCAS SMPD P SOOH F/19,096' T/15,405' MD per stripping schedule. Racking 5-7/8 DP. 235K PUW, Monitor hole fill on pit #4 holding 10.2 ppg at shoe. Dropped 2.5" OD hollow drift on stand #184 19,096.0 15,405.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 44/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/29/2023 06:00 6/29/2023 08:00 2.00 PROD1, TRIPCAS SMPD P SOOH F/15,405' T/14,215' MD per stripping schedule. Racking 5-7/8 DP. 220K PUW, Monitor hole fill on pit #4 holding 10.2 ppg at shoe. 15,405.0 14,215.0 6/29/2023 08:00 6/29/2023 08:30 0.50 PROD1, TRIPCAS DISP P PJSM, prep pits for displacement 14,215.0 14,215.0 6/29/2023 08:30 6/29/2023 10:45 2.25 PROD1, TRIPCAS DISP P Displace to 10.1 ppg NAF at 260 GPM, 2823 PSI, 100 RPM, 16K TQ. 10.54 ECD. MW out light at end of displacement. 14,215.0 14,215.0 6/29/2023 10:45 6/29/2023 14:30 3.75 PROD1, TRIPCAS DISP P Shut down, move fluids in/out of pits. Complete weight up to 10.1 ppg 14,215.0 14,215.0 6/29/2023 14:30 6/29/2023 16:45 2.25 PROD1, TRIPCAS CIRC P Circulate and weight up system to 10.1. Rot & Recip. 260 GPM, 3000 PSI, 80 RPM, 11K TQ. 150K RTW. 14,215.0 14,215.0 6/29/2023 16:45 6/29/2023 18:15 1.50 PROD1, TRIPCAS OWFF P Bleed off MPD pressure in stages, 155 psi to 0. Open to cellar. Observe well static 30 min. 14,215.0 14,215.0 6/29/2023 18:15 6/29/2023 21:15 3.00 PROD1, TRIPCAS SMPD P SOOH F/14,215' T/11,436' MD per stripping schedule. Racking 5-7/8 DP. 165K PUW, Monitor hole fill on pit #4 holding 10.2 ppg at shoe. 14,215.0 11,436.0 6/29/2023 21:15 6/29/2023 23:30 2.25 PROD1, TRIPCAS MPDA P OWFF, PJSM, Remove 5-7/8" MPD element, rack 5-7/8" std. Install 4-1/2" MPD element. Push/Pull test to verify set. 11,436.0 11,436.0 6/29/2023 23:30 6/30/2023 00:00 0.50 PROD1, TRIPCAS SMPD P SOOH F/11,436' T/11,141' MD per stripping schedule. Racking 4-1/2" DP. 165K PUW, Monitor hole fill on pit #4 holding 10.2 ppg at shoe. 11,436.0 11,141.0 6/30/2023 00:00 6/30/2023 06:00 6.00 PROD1, TRIPCAS SMPD P SOOH F/11,141' T/4,840' MD per stripping schedule. Racking 4-1/2" DP. 128K PUW, Monitor hole fill on pit #4 holding MPD back pressure to mitigate swab. 11,141.0 4,840.0 6/30/2023 06:00 6/30/2023 10:30 4.50 PROD1, TRIPCAS SMPD P SOOH F/4,840' T/500' MD per stripping schedule. Racking 4-1/2" DP. 88K PUW, Monitor hole fill on pit #4 holding MPD back pressure to mitigate swab. 4,840.0 500.0 6/30/2023 10:30 6/30/2023 11:00 0.50 PROD1, TRIPCAS MPDA P Shut down backside pump, open 2" bleed line off MPD, observe well static 10 min 500.0 500.0 6/30/2023 11:00 6/30/2023 11:30 0.50 PROD1, TRIPCAS MPDA P PJSM, pull 4.5" MPD element per MPD advisor 500.0 500.0 6/30/2023 11:30 6/30/2023 12:00 0.50 PROD1, TRIPCAS TRIP P POOH on elevators, Rack last 2 stds DP 500.0 310.0 6/30/2023 12:00 6/30/2023 12:30 0.50 PROD1, TRIPCAS BHAH P PJSM, clean/clear floor for BHA 310.0 310.0 6/30/2023 12:30 6/30/2023 14:30 2.00 PROD1, TRIPCAS BHAH P LD BHA F/310' T/245' 310.0 245.0 6/30/2023 14:30 6/30/2023 15:00 0.50 PROD1, TRIPCAS BHAH P PJSM, remove and LD sources 245.0 245.0 6/30/2023 15:00 6/30/2023 18:00 3.00 PROD1, TRIPCAS BHAH P LD BHA F/245' T/65' 245.0 65.0 6/30/2023 18:00 6/30/2023 19:00 1.00 PROD1, TRIPCAS BHAH P Break bit, LD BHA. BHA looked good, stabs and bit in gauge. Some chipped teeth on bit. No excessive wear on BHA. 65.0 0.0 6/30/2023 19:00 6/30/2023 21:30 2.50 PROD1, TRIPCAS BHAH P Clear and clean floor. Kick out all BHA components from floor. Scrub floor of OBM from trip, replace saturated felt. 0.0 0.0 6/30/2023 21:30 6/30/2023 22:45 1.25 COMPZN, CASING RURD P PU casing equipment, RU to run 4.5" Liner 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 45/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 6/30/2023 22:45 7/1/2023 00:00 1.25 COMPZN, CASING PUTB P PJSM, PU Jt #1, MU MOAS shoe. RU and circ through shoe to verify functionality. 0.0 44.0 7/1/2023 00:00 7/1/2023 06:00 6.00 COMPZN, CASING PUTB P MU 4-1/2" 12.6# P110S H563 liner per tally F/44' T/2,630' w/ frac sleeves and swell packers Installing 5.63" hydroform centralizers 1/jt, installing 6.13" hydroform centralizer above and below swell packers. Tq liner to 5.6K. Monitor displacement on TT. 44.0 2,630.0 7/1/2023 06:00 7/1/2023 12:15 6.25 COMPZN, CASING PUTB P MU 4-1/2" 12.6# P110S H563 liner per tally F/2,630' T/6,538' w/ frac sleeves and swell packers Installing 5.63" hydroform centralizers 1/jt, installing 6.13" hydroform centralizer above and below swell packers. MU 6K psi floatation sub.Tq liner to 5.6K. Monitor displacement on TT. 2,630.0 6,538.0 7/1/2023 12:15 7/1/2023 13:30 1.25 COMPZN, CASING PUTB P PJSM, RU to pull in liner hanger skate, PU liner Hgr/Pkr assy, pull out liner hanger skate and RD skate equip. 6,538.0 6,538.0 7/1/2023 13:30 7/1/2023 14:30 1.00 COMPZN, CASING PUTB P MU liner RT setting tools, MU liner Hgr/Pkr assy to 4-1/2" liner. Inspect and prep, fill SLZXP extension w/ Zanplex. RIH F/6,538' T/6,597'. 6,538.0 6,597.0 7/1/2023 14:30 7/1/2023 15:15 0.75 COMPZN, CASING RURD P RD liner running tools, bail extensions, tongs, etc 6,597.0 6,597.0 7/1/2023 15:15 7/1/2023 16:30 1.25 COMPZN, CASING RUNL P MU XO to running tool and 1 std 4-1/2" DP. RIH to 6,678'. Top fill string on top of floatation sub. Test against RS pack-off to 500 psi for 3 min. 6,597.0 6,678.0 7/1/2023 16:30 7/1/2023 16:45 0.25 COMPZN, CASING RUNL P Obtain T&D numbers. 93K PUW, 88K SOW, 88K RTW, 2K Tq 6,678.0 6,678.0 7/1/2023 16:45 7/1/2023 18:00 1.25 COMPZN, CASING RUNL P RIH w/ 4-1/2" Liner on 4-1/2" DP F/6,678' T/7,626'. Fill pipe via fill up line every stand, top off every 10 stds. Monitor displacement on TT. 6,678.0 7,626.0 7/1/2023 18:00 7/2/2023 00:00 6.00 COMPZN, CASING RUNL P RIH w/ 4-1/2" Liner on 4-1/2" DP F/7,626' T/14,331'. Fill pipe via fill up line every stand, top off every 10 stds. Monitor displacement on TT. 7,626.0 14,331.0 7/2/2023 00:00 7/2/2023 06:00 6.00 COMPZN, CASING RUNL P RIH w/ 4-1/2" Liner on 4-1/2" DP F/14,331' T/18,962'. Fill pipe via fill up line every stand, top off every 10 stds. Monitor displacement on TT. 14,331.0 18,962.0 7/2/2023 06:00 7/2/2023 07:45 1.75 COMPZN, CASING RUNL P RIH w/ 4-1/2" Liner on 4-1/2" DP F/18,962' T/19,683'. 90-110K SOW. Fill pipe via fill up line every stand, top off every 10 stds. Monitor displacement on TT. 18,962.0 19,683.0 7/2/2023 07:45 7/2/2023 08:00 0.25 COMPZN, CASING RUNL T Lost SOW, down to 85K hookload at 19,683'. Work pipe 3 times, tag same place at 19,683' w/ 25K. 19,683.0 19,683.0 7/2/2023 08:00 7/2/2023 08:15 0.25 COMPZN, CASING RUNL T Pull up to 19,613' MD, 210K PUW. Put 10 wraps in pipe, hold 7K Tq. RBIH at 25'/min. Tag at 19683' MD w/ 25K 19,683.0 19,683.0 7/2/2023 08:15 7/2/2023 08:45 0.50 COMPZN, CASING RUNL T Pull up to 19,670' MD. w/ 330K, Slack off to neutral wt, 170K, Rot 20 RPM, stalled at 15K Tq. Appears stuck. 19,683.0 19,683.0 7/2/2023 08:45 7/2/2023 09:15 0.50 COMPZN, CASING RUNL T Work pipe F/85K T/450K at 19,683' 19,683.0 19,683.0 7/2/2023 09:15 7/2/2023 09:30 0.25 COMPZN, CASING RUNL T Pull to 475K and hold 19,683.0 19,683.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 46/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/2/2023 09:30 7/2/2023 10:00 0.50 COMPZN, CASING RUNL T Slack off the neutral wt, 170K, Put 8K Tq in string w/ 3.5 wraps and hold. Work pipe 80K to 450K 19,683.0 19,683.0 7/2/2023 10:00 7/2/2023 10:15 0.25 COMPZN, CASING RUNL T Increase Tq to 10K. PU to 450K and hold position. 19,683.0 19,683.0 7/2/2023 10:15 7/2/2023 10:30 0.25 COMPZN, CASING RUNL T Work pipe, 450K to 80K w/ hold 10K Tq 19,683.0 19,683.0 7/2/2023 10:30 7/2/2023 11:00 0.50 COMPZN, CASING RUNL T Work pipe, 160-250K to 80K w/ hold 10K Tq 19,683.0 19,683.0 7/2/2023 11:00 7/2/2023 12:30 1.50 COMPZN, CASING RUNL T Stop working pipe. Consult w/ town. Liner Hgr/Pkr is just below top of 39# 19,683.0 19,683.0 7/2/2023 12:30 7/2/2023 14:00 1.50 COMPZN, CASING RUNL T PU to 216K, Close annular. Pressure up on annulus thru kill line at .5 bpm, 36 stks total to 425 psi, hold for 15 min, bled down to 288 PSI. Pump another 9 stks to 420 PSI, bled down to 293 PSI. Bleed pressure to 0, open annular. 19,683.0 19,683.0 7/2/2023 14:00 7/2/2023 16:30 2.50 COMPZN, CASING RUNL T Consult with town. Clean rig of OBM. Service blocks, ST-120, work on MP2's. 19,683.0 19,683.0 7/2/2023 16:30 7/2/2023 17:15 0.75 COMPZN, CASING RUNL T LD top single of Std #140. MU shear/vent assy with 10' DP pup, TIW, SES, TIW, 15' DP pup. 19,683.0 19,683.0 7/2/2023 17:15 7/2/2023 18:00 0.75 COMPZN, CASING RUNL T Consult with town, PU thread protectors and prep shed to LD DP. Approval obtained from AOGCC to set packer here. 19,683.0 19,683.0 7/2/2023 18:00 7/2/2023 20:30 2.50 COMPZN, CASING RUNL P Set hanger per Baker rep. Pump down string, pressure up to 2500 PSI for 5 min, bleed off pressure to 500 psi, SO to 80K, bleed of pressure to 0 PSI. Test packer pumping down annulus through kill line to 3850 PSI, .5 BPM, 88 total stks. Chart 10 min ok, bleed off pressure to 0 PSI. Line up and pump down string. Pressure up to 3000 PSI for 3 min, increase pressure to 3500 PSI, hold 5 min. Bleed off pressure. PU verify running tool released. 193K PUW, 126K SOW. 19,683.0 19,683.0 7/2/2023 20:30 7/2/2023 21:00 0.50 COMPZN, CASING RUNL P Pump down string to burst floatation sub with 4192 PSI, continue pump down string through TD with vent line on side entry sub open to bleeder/flowline. Pumping 3 bpm, charge pump outrunning pump, filled liner with 94 bbls of mud. Slowed pump to 1 bpm once returns seen and let last of air vent. 19,683.0 19,683.0 7/2/2023 21:00 7/2/2023 21:30 0.50 COMPZN, CASING RUNL P PU to dogs out. Perform mechanical rotating packer setting procedure per Baker rep as an added precaution. 196K PUW, 150K RTW, 20 RPM, 7-9K Tq. Rotate down and set 35K weight on LT. Rotate 5 min.. PU, stop rotation, SO to light tag TOL. Verify depth, DPM shows TOL at 13,109.33' and shoe at 19,680.44' MD. Packer center at 13,126' MD 19,683.0 13,146.0 7/2/2023 21:30 7/2/2023 22:30 1.00 COMPZN, WELLPR RURD P RD pumping equipment, DP pups, TIW's, SES. LD 2 jts to get running tool above TOL 13,146.0 13,086.0 7/2/2023 22:30 7/3/2023 00:00 1.50 COMPZN, WELLPR DISP P PJSM, displace well over to 10.1 CI Brine. Pump 20 Bbls LVT, 50 Bbls 12.1 ppg spacer, 100 bbls DC spacer at 122 GPM, 370 PSI 13,086.0 13,086.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 47/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/3/2023 00:00 7/3/2023 03:30 3.50 COMPZN, WELLPR DISP P Continue displace out 10.1 Versaclean mud to 10.1 CI Brine. Reciprocate pipe. 250 GPM, 600-425 PSI, 9015 Stks good brine to surface. 50 bbls interface 13,086.0 13,086.0 7/3/2023 03:30 7/3/2023 04:00 0.50 COMPZN, WELLPR OWFF P Observe well static no flow 30 min. 13,086.0 13,086.0 7/3/2023 04:00 7/3/2023 05:15 1.25 COMPZN, WELLPR DISP P Clean/clear floor, clean trip tanks, clean floor drains, disp all OBM from jet line, hole fill lines, kill line, choke line, MGS, Install PS-21 Hyd slips, prep to LD DP 13,086.0 13,086.0 7/3/2023 05:15 7/3/2023 06:45 1.50 COMPZN, WELLPR PULD P POOH Laying down 5-7/8" DP F/13,086' T/12,754'. Monitor hole fill on TT. 13,086.0 12,754.0 7/3/2023 06:45 7/3/2023 07:15 0.50 COMPZN, WELLPR SVRG P Service ST-120, Top Drive and skate. Clean surface equip & pits of OBM. 12,754.0 12,754.0 7/3/2023 07:15 7/3/2023 13:15 6.00 COMPZN, WELLPR PULD P POOH Laying down 5-7/8" DP F/12,754' T/7,795'. Monitor hole fill on TT. 12,754.0 7,795.0 7/3/2023 13:15 7/3/2023 14:15 1.00 COMPZN, WELLPR RURD P Clean and remove PS-21 slips. C/O elevators, Remove 5-7/8 and PU 4-1/2 thread protectors. C/O stripping rubber under bushings, clean surface equip and pits of OBM 7,795.0 7,795.0 7/3/2023 14:15 7/3/2023 22:00 7.75 COMPZN, WELLPR PULD P POOH Laying down 4-1/2" DP F/7,795' T/60'. Monitor hole fill on TT. Clean surface equip and pits of OBM 7,795.0 60.0 7/3/2023 22:00 7/3/2023 22:45 0.75 COMPZN, WELLPR PULD P PJSM, LD liner running tool and inspect 60.0 0.0 7/3/2023 22:45 7/4/2023 00:00 1.25 COMPZN, WELLPR TRIP P PJSM, RIH w/ 4.5" DP from derrick to LD, monitor disp on TT. 101K PUW, 109K SOW 0.0 1,880.0 7/4/2023 00:00 7/4/2023 00:45 0.75 COMPZN, WELLPR TRIP P RIH w/ all excess 4-1/2" DP from derrick T/3,300'. Monitor displacement on TT 1,880.0 3,300.0 7/4/2023 00:45 7/4/2023 05:00 4.25 COMPZN, WELLPR PULD P POOH laying down 4-1/2" DP to shed. Monitor hole fill on TT 3,300.0 0.0 7/4/2023 05:00 7/4/2023 05:15 0.25 COMPZN, WELLPR RURD P Swap handling equip to 5-7/8" 0.0 0.0 7/4/2023 05:15 7/4/2023 05:30 0.25 COMPZN, WELLPR TRIP P RIH w/ 5-7/8" DP to 90'. POOH f/ 90' 0.0 0.0 7/4/2023 05:30 7/4/2023 06:00 0.50 COMPZN, WELLPR CLEN P Prep to clean surface lines of OBM SIMOPS: LOTO ST-120, remove bad hose 0.0 0.0 7/4/2023 06:00 7/4/2023 08:15 2.25 COMPZN, WELLPR CLEN P Flush mud pumps, #1,2 and 4 F/ pit #7 through bleeder line with Deep Cleen and H2O. Flush mud pump #3 through MPD line with Deep Clean and H2O. Reflush all pumps with H2O. Blow down mud pump #3 and MPD lines. Prep liner hanger skate/stand for removal. SIMOPS: repair ST-120 0.0 0.0 7/4/2023 08:15 7/4/2023 09:30 1.25 COMPZN, WELLPR TRIP P RIH w/ 19 stds excess 5-7/8" DP. Monitor displacement on TT 0.0 1,770.0 7/4/2023 09:30 7/4/2023 12:00 2.50 COMPZN, WELLPR RURD P Remove liner hanger skate/stand F/ roof with crane. SIMOPS: Continue flush equip with Deep Clean and H2O 1,770.0 1,770.0 7/4/2023 12:00 7/4/2023 13:30 1.50 COMPZN, WELLPR TRIP P RIH w/ all excess 5-7/8" DP, 48 stds total. Monitor displacement on TT. SIMOPS: Cont cleaning pits, Blow down, clean and inspect MP #3 1,770.0 4,452.0 7/4/2023 13:30 7/4/2023 13:45 0.25 COMPZN, WELLPR RURD P Pull bushings and install stripping rubber and stand below rotary table. 4,452.0 4,452.0 7/4/2023 13:45 7/4/2023 18:30 4.75 COMPZN, WELLPR PULD P POOH laying down 5-7/8" DP to shed. Monitor hole fill on TT. SIMOPS: Cont cleaning pits, blow down, clean, inspect and change out all valves on MP#4. 4,452.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 48/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/4/2023 18:30 7/4/2023 19:30 1.00 COMPZN, WELLPR RURD P MU FMC wear ring running tool. Pull wear ring per SOP, RD wear ring running tool 0.0 0.0 7/4/2023 19:30 7/4/2023 20:45 1.25 COMPZN, WELLPR WWWH P MU stack washing tool on 2 Jts 5-7/8" DP. Jet/Wash hanger profile, BOP stack, ram cavities, RCD head w/ Deep Clean soap, function upper and lower VBR's, annular and blind rams. Wash BOP stack final pass. 10 RPM, 800 gpm. RD stack washer and LD 2 Jts 5-7/8" DP 0.0 0.0 7/4/2023 20:45 7/5/2023 00:00 3.25 COMPZN, RPCOMP RURD P Clean clear floor, PU spooler unit, SLB Tec wire tools and equipment. PU casing equip, RU to run tubing 0.0 0.0 7/5/2023 00:00 7/5/2023 00:30 0.50 COMPZN, RPCOMP PUTB P Make up 4.5", 12.6#, L80, H563 upper completion as per tally to 230' MD. 0.0 230.0 7/5/2023 00:30 7/5/2023 02:00 1.50 COMPZN, RPCOMP PUTB P Make up TEC wire to Down Hole Gauge & test connection to 5000 psi for 5 minutes, good test. 230.0 230.0 7/5/2023 02:00 7/5/2023 06:00 4.00 COMPZN, RPCOMP PUTB P Make up 4.5", 12.6#, L80, H563 upper completion as per tally from 230'-2214' MD. Install TEC wire clamps every joint per SLB & fill tubing every 10 joints. SO 94K. 230.0 2,214.0 7/5/2023 06:00 7/5/2023 12:00 6.00 COMPZN, RPCOMP PUTB P Make up 4.5", 12.6#, L80, H563 upper completion as per tally from 2214'-6381' MD. Install TEC wire clamps every joint per SLB & fill tubing every 10 joints. SO 100K. 2,214.0 6,381.0 7/5/2023 12:00 7/5/2023 18:00 6.00 COMPZN, RPCOMP PUTB P Make up 4.5", 12.6#, L80, H563 upper completion as per tally from 6381'-9897' MD. Install TEC wire clamps every joint per SLB & fill tubing every 10 joints. SO 100K. 6,381.0 9,897.0 7/5/2023 18:00 7/5/2023 23:00 5.00 COMPZN, RPCOMP PUTB P Make up 4.5", 12.6#, L80, H563 upper completion as per tally from 9897'- 13,045 MD. Install TEC wire clamps every joint per SLB & fill tubing every 10 joints. PU 134K, SO 94K. 9,897.0 13,045.0 7/5/2023 23:00 7/6/2023 00:00 1.00 COMPZN, RPCOMP HOSO P Run in the hole from 13,045'-13,120' MD. Set down 14K to shear at 79K. Continue down and set down 20K to confirm nogo & located. Lay down 3 joints from 13,120'-13,003' MD. Make up 2 space out pups 3.78' & 9.72'. Pick up joint #312, hanger, & landing joint. Total full clamps 316 & 2 half clamps. 13,045.0 13,060.0 7/6/2023 00:00 7/6/2023 01:15 1.25 COMPZN, RPCOMP THGR P TEC wire penetration through hanger per SLB & FMC. Test to 5000 psi for 5 minutes, good. SIMOPS OWFF, rig up lines for pumping & test equipment. 13,060.0 13,060.0 7/6/2023 01:15 7/6/2023 02:30 1.25 COMPZN, RPCOMP THGR P Drain stack. run in the hole and land hanger 13,060'-13,115.46'. Locator spaced 1.03' from fully located. Run in lock down screws as per FMC. 13,060.0 13,115.5 7/6/2023 02:30 7/6/2023 04:00 1.50 COMPZN, RPCOMP PRTS P Rig up and test hanger seals from above to 250 psi for 5 minutes & 4000 psi for 10 minutes, good tests. 13,115.5 13,115.5 7/6/2023 04:00 7/6/2023 06:15 2.25 COMPZN, RPCOMP PRTS P Flood lines & pressure test to 4000 psi. Pump down the tubing to 3600 psi, with 2.2 bbls and shut in for 30 minutes to set packer and test tubing. Bleed down tubing to 2500 psi and shut in. Pressure up IA to 3850 psi, with 7.3 bbls and shut in for 30 minutes. Both tests charted & good. 13,115.5 13,115.5 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 49/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/6/2023 06:15 7/6/2023 06:45 0.50 COMPZN, RPCOMP CIRC P Bleed off IA to 3500 psi. Quickly bleed off tubing pressure to shear SOV. Circulate down IA with returns through the tubing to confirm shear at 2 bpm, 950 psi. 13,115.5 13,115.5 7/6/2023 06:45 7/6/2023 07:15 0.50 COMPZN, RPCOMP OWFF P Monitor well for 30 minutes, static. SIMOPS rig down test equipment. 13,115.5 13,115.5 7/6/2023 07:15 7/6/2023 09:45 2.50 COMPZN, RPCOMP RURD P Remove crossover, pump in sub, & landing joint. Rig down casing handling equipment & SLB TEC line equipment. Remove from rig floor. Drain stack via IA. 13,115.5 13,115.5 7/6/2023 09:45 7/6/2023 10:45 1.00 COMPZN, RPCOMP MPSP P Install H-BPV with T-bar. Rig up and test to 2500 psi, in the direction of flow. Chart for 15 minutes. Bleed off pressure. 13,115.5 0.0 7/6/2023 10:45 7/6/2023 12:00 1.25 COMPZN, WHDBOP RURD P Rig down test equipment. Blow down top drive, choke line / choke manifold, & kill line / mud line to mud pump 2. SIMOPS continue to empty & clean pits. 0.0 0.0 7/6/2023 12:00 7/6/2023 14:00 2.00 COMPZN, WHDBOP NUND P Remove choke and kill line from BOP stack. Remove master bushings & riser. SIMOPS suck out stack down to high pressure riser with super sucker; pull & disconnect and lay down mouse hole; bleed down accumulator & de-energize; empty & top rinse pits. Rig off high line at 14:00 hrs. 0.0 0.0 7/6/2023 14:00 7/6/2023 15:00 1.00 COMPZN, WHDBOP NUND P Remove BOP stack from high pressure adapter & install / secure on moving stump. Mobilize frac tree to the BOP deck landing. SIMOPS lay down mouse hole, service accumulator, continue cleaning pits. 0.0 0.0 7/6/2023 15:00 7/6/2023 16:15 1.25 COMPZN, WHDBOP NUND P Remove high pressure adapter riser & adapter flange from the wellhead. SIMOPS remove 2nd mouse hole & lay down in the pipeshed; continue cleaning pits; perform maintenance on accumulator. 0.0 0.0 7/6/2023 16:15 7/6/2023 19:00 2.75 COMPZN, WHDBOP NUND P Clean tubing hanger & terminate TEC wire through wellhead per FMC & SLB. SIMOPS mobilize equipment from rig floor; pull drip pan plug; clean pits; perform maintenance on accumulator. 0.0 0.0 7/6/2023 19:00 7/6/2023 21:30 2.50 COMPZN, WHDBOP NUND P Nipple up adapter flange & 10K frac tree per FMC. 0.0 0.0 7/6/2023 21:30 7/6/2023 23:15 1.75 COMPZN, WHDBOP PRTS P Rig up test equipment. Fluid pack tree with diesel. Pressure test tree to 250 psi for 5 minutes & 10,000 psi for 15 minutes. Test witness by CPAI Drilling Supervisor. Pull test dart & BPV. 0.0 0.0 7/6/2023 23:15 7/7/2023 00:00 0.75 COMPZN, WHDBOP FRZP P Rig up high pressure lines for freeze protect & u-tube. Pressure test lines to 2500 psi. 0.0 0.0 7/7/2023 00:00 7/7/2023 01:30 1.50 COMPZN, WHDBOP FRZP P Freeze protect well with 80 bbls of diesel. Stage up rate to 1.25 bpm. Initial pump pressure 335 psi, final pumping pressure 604 psi. Shut in pressure after pumping 574 psi. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 Page 50/50 CD4-588 Report Printed: 7/25/2023 Operations Summary (with Timelog Depths) Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/7/2023 01:30 7/7/2023 02:15 0.75 COMPZN, WHDBOP FRZP P Line up to allow tubing & IA to u-tube. SIMOPS blow down rig pump lines; unhook interconnects in pump room. Final pressures after u-tube: Tubing 0 psi IA 179 psi OA 415 psi 0.0 0.0 7/7/2023 02:15 7/7/2023 02:45 0.50 COMPZN, WHDBOP MPSP P Verify tubing pressure 0 psi. Install H- BPV per FMC. 0.0 0.0 7/7/2023 02:45 7/7/2023 06:00 3.25 COMPZN, WHDBOP NUND P Clean tree & cellar box. Install flanges & gauges on IA & OA outlets. SIMOPS lay down surface riser; unhook interconnects in the flow line room; blow down steam / water system; install drip pan plug; remove MPD hard line; prep rig to move. Rig release at 06:00 hrs. 0.0 0.0 Rig: DOYON 26 RIG RELEASE DATE 7/7/2023 ! "#$$ Digitally signed by Vincent Osara DN: C=US, OU=Schlumberger, O=Schlumberger, CN=Vincent Osara, E=vosara@slb.com Reason: I am the author of this document Location: your signing location here Date: 2023.06.30 19:39:40-08'00' Foxit PhantomPDF Version: 10.1.4 Vincent Osara %& ' & ("! & )* & & & +& ,!& !"#$%# &' ()* -&+ &)+," - , &!"#$%# &' ()* & + , '& .'& % , /& ''&. ,%#"&)/0 * ,%#"&''.* 1 -1. -23 4 . ( 0 . 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& )* & & & +& ,!& !"#$%# &' ()* -&+ &)+," - , &!"#$%# &' ()* & + , 4 6 9 456 : 456 102" 4 6 12" 4 6 )* 4 6 )* 4 6 , - 4 6 , 0 - 4 6 * 4 6 ( 452;<6 )' ,%135,$" 5$" ,,$ 15#"$# 1#%$"# ,1,,$3,1#$3 1%513$#" 5%#13$#% 3$35 ,1"#$3 ?<@#?:?&"* ,%1,#$, $% ,3$,, 1556$, 15"6$,6 ,1,%$%#1#65$% 1%#1%""$,# 5%#1%5$% ,$6 ,1"%$,, ?<@#?:?&"* ,%1#,"$66 $5 ,3$35 15$%3 16$"% ,1#36$51#"#$% 1%#1%$"6 5%#15%$33 3$," ,16%$66 ?<@#?:?&"* ,%15,3$# $# ,%$"5 15$#" 156$" ,1##$651#,$5 1%#1,$# 5%#15$%% ,$3 ,1%3$3 ?<@#?:?&"* ,%135$3 "$, ,$ 1563$5 16,6$5 ,1533$5#1#"$, 1%#1"5$65 5%#1653$5" #$5 ,13,5$#" ?<@#?:?&"* ,%1%$3 $" ,"$"5 1565$6% 16%$, ,15$%1#%3$"" 1%#166$, 5%#16""$5 #$3# ,13$ ?<@#?:?&"* ,%1$3% %$" ,$#% 156$35 1""5$3 ,15%"$"1#%#$,, 1%#1"6$" 5%#1"#$5 ,$3 ,1,%$, ?<@#?:?&"* ,%163$6 %$", ,$%5 156$6, 1#$#5 ,16$,%1#%#$6% 1%#1%6$# 5%#1""#$3 3$", ,1#5#$3, ?<@#?:?&"* ,%1""5$3 %3$3 ,$33 156$, 1%5,$ ,1%$31#%#$% 1%#1,6$5 5%#1,%$"# ,$3" ,153$,# ?<@#?:?&"* ,%166$# %$6 ,%$3, 1566$36 13,3$53 ,15$,#1#%5$, 1%#1556$%, 5%#166$" ,$, ,15""$5 ?<@#?:?&"* ,%1%$5 $% ,$" 156"$," 13%$5 ,1%3$%1#%$# 1%#1#6$%5 5%#1%,5$#% 3$"" ,13$## ?<@#?:?&"* #313,$6 %$3 ,%$5 156$"" 1,6%$, ,165$"31#%$ 1%#1,"6$6 5%#1%%$" 3$6 ,1##$6" ?<@#?:?&"* #31,$#5 %$3 ,%$3 15"3$53 1#$6# ,166$3%1#%"$5 1%#13%6$5 5%5133$ 3$5# ,1%$"5 ?<@#?:?&"* #31#56$6 %$,# ,3$% 15",$" 15#$65 ,1"5#$531#%$6 1%#13,$63 5%5133$" #$3" ,166$" ?<@#?:?&"* #315#6$#% $" ,,$" 15"5$ 13"$55 ,1""$,%1533$# 1%,1%56$#, 5%513%#$5 ,$,, ,1"55$ ?<@#?:?&"* #31#"$33 $" ,,$" 15"$6 1%6$,5 ,1##$66153#$"# 1%,16$6" 5%51,5$5 3$33 ,13$# 'C)+) + Page 1/1 CD4-588 Report Printed: 7/25/2023 Cement Cement Details Description Conductor String Cement Cementing Start Date 3/25/2014 12:00 Cementing End Date 3/25/2014 14:00 Wellbore Name CD4-588 Comment Cement Stages Stage # 1 Description Conductor String Cement Objective Top Depth (ftKB) 57.9 Bottom Depth (ftKB) 134.0 Full Return? Yes Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Primary Cement Fluid Description Estimated Top (ftKB) 57.9 Est Btm (ftKB) 134.0 Amount (sacks) Class Volume Pumped (bbl) 50.4 Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Conductor String Cement Page 1/1 CD4-588 Report Printed: 7/25/2023 Cement Cement Details Description Surface String Cement Cementing Start Date 5/23/2023 13:30 Cementing End Date 5/23/2023 17:30 Wellbore Name CD4-588 Comment SLB cementing unit pumped 100 bbls of 10.8 ppg MudPush II spacer at 5 bpm, 155 psi. Drop bottom plug. Pump 395 bbls of 11.0 ppg lead cement at 5.5 bpm, 155-359 psi. Pump 72.4 bbls of 15.8 ppg tail cement at 3.8 bpm, 177-313 psi. Drop top plug and pump 20 bbls of water behind at 3-5 bpm, 67-215 psi. Swap to rig pumps and displace cement with 10.5 ppg mud at 7 bpm, 500-700 psi. Slow pumps to 3 bpm, 600 psi with 370 bbls pumped. Bump plug with 384.2 bbls, 3237 strokes pumped. Pressure up to 1200 psi & hold for 5 minutes. Bleed off pressure and check floats, good. CIP 17:26 hrs. Returns were lost with 251.6 bbls of mud displacement pumped. Total losses to the hole 125 bbls. Cement Stages Stage # 1 Description Surface String Cement Objective Top Depth (ftKB) 58.0 Bottom Depth (ftKB) 2,769.0 Full Return? No Vol Cement … 50.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 6 P Pump Final (psi) 700.0 P Plug Bump (psi) 1,200.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Surface Cement Fluid Description Estimated Top (ftKB) 58.0 Est Btm (ftKB) 2,269.0 Amount (sacks) 1,161 Class Blend Volume Pumped (bbl) 395.0 Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sack) 6.68 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 213.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 2,269.0 Est Btm (ftKB) 2,769.0 Amount (sacks) 346 Class G Volume Pumped (bbl) 72.0 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 5.03 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 177.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Surface String Cement Page 1/1 CD4-588 Report Printed: 7/25/2023 Cement Cement Details Description Intermediate String 1 Cement Cementing Start Date 6/4/2023 19:45 Cementing End Date 6/4/2023 23:56 Wellbore Name CD4-588 Comment SLB cementing unit pumped 73.7 bbls of 12.0 ppg MudPush II spacer at 3.5 bpm, 227-114 psi. Drop bottom plug. Pump 175.5 bbls of 15.8 ppg G cement at 4.5 bpm, 203-90 psi. Drop top plug and pump 20 bbls of water behind at 5 bpm, 109-39 psi. Swap to rig pumps and displace cement with 10.8 ppg mud at 6 bpm, 100 -340 psi. Slow pumps to 3 bpm, 170-200 psi, observed bottom plug land on FC at 4600 stks, increase rate to 6 bpm, 350-450 psi, Slow pump to 3 bpm with 100 bbls remaining per cement program for ECD. Bump plug with 719.6 bbls, 6062 strokes pumped. Pressure up to 950 psi & hold for 5 minutes. Bleed off pressure and check floats, good. CIP 23:54 hrs. No reciprocation per section plan. Full returns throughout job. No losses. Cement Stages Stage # 1 Description Intermediate String 1 Cement Objective Top Depth (ftKB) 7,908.0 Bottom Depth (ftKB) 10,125.7 Full Return? Yes Vol Cement … 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 3 Q Pump Avg (bbl/… 6 P Pump Final (psi) 450.0 P Plug Bump (psi) 950.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top (ftKB) 7,908.0 Est Btm (ftKB) 10,125.7 Amount (sacks) 843 Class G Volume Pumped (bbl) 175.5 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 4.75 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 1 Cement Page 1/1 CD4-588 Report Printed: 7/25/2023 Cement Cement Details Description Intermediate String 2 Cement Cementing Start Date 6/16/2023 11:00 Cementing End Date 6/16/2023 14:12 Wellbore Name CD4-588 Comment SLB cementing unit pumped 42.75 bbls of 12.0 ppg Mud Push II spacer at 4 BPM, 100-680 psi. Drop bottom dart. Pump 124.53 bbls of 15.8ppg G liquid adds cement at 4.1 BPM, 113-686 psi. Drop top dart and pump 20 bbls of water behind at 5 BPM, 110-428 psi. Swap to rig pumps and displace cement with 9.5 ppg FWP mud at 5.5 BPM. Observed plug bump at 3,360 strokes at final circulation pressure of 607 psi. Pressured up to 1064 psi and held for five minutes. Bled off pressure and floats held. No losses during cement job. Cement Stages Stage # 1 Description Intermediate String 2 Cement Objective Top Depth (ftKB) 11,549.2 Bottom Depth (ftKB) 14,230.0 Full Return? Yes Vol Cement … 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 6 Q Pump Final (bbl/… 5 Q Pump Avg (bbl/… 5 P Pump Final (psi) 580.0 P Plug Bump (psi) 604.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top (ftKB) 11,549.2 Est Btm (ftKB) 14,230.0 Amount (sacks) 1,005 Class G Volume Pumped (bbl) 124.5 Yield (ft³/sack) 1.17 Mix H20 Ratio (gal/sack) 4.71 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Intermediate String 2 Cement 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?CD4-588 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): Colville Delta - Narwhal Undefined Oil 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 20427 None None Casing Collapse Structural Conductor Surface 2260 Intermediate I 5090 Intermediate II 4790, 11080 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: Contact Email: Contact Phone: 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 204274375 4375 1550 None 4313 4-1/2" None 10125 2764 14226 10125 20" x 34" 13-3/8" 135 3479 135 2764 40597-5/8" 9-5/8" Length Size L-80 TVD Burst 13115 6890, 12620 MD 8150 5020 135 2405 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL380077, ADL384211, ADL380081 223-029 P.O. Box 100360 Anchorage, AK 99510-0360 50-103-20853-00-00 ConocoPhillips Alaska Inc. 11590 Tubing Grade:Tubing MD (ft): LTP @ 13126' MD / 3862' TVD, Production Packer @ 12951' MD / 3832' TVD Perforation Depth TVD (ft):Tubing Size: 6/13/2022 196806554 4.5" 4365 Halliburton TNT Production Packer, Baker SLZXP Liner Top Packer, no SSSV Perforation Depth MD (ft): 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: AOGCC USE ONLY Baskoro Tejo baskoro.tejo@cop.com 907-265-6462 Completion Engineer P 2 6 5 6 t _ Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. July 20, 2023 By Grace Christianson at 10:45 am, Jul 21, 2023 323-415 SFD SFD 10-404 SFD 7/31/2023 CDW 08/01/2023 X Fracture Stimulate DSR-7/24/23 8/5/2023 X VTL 8/02/2023GCW 08/02/2023JLC 8/2/2023 08/02/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.02 13:56:35 -08'00' RBDMS JSB 080323 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). 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) Well Name API Well Type Status Field Name Fluid Type Well in Frac Port 1/2 mi Buffer Open Interval in Frac Port 1/2 mi Buffer CD4-298 501032062300 PROD ACTIVE NANUQ OIL YES YES CD4-301 501032055700 PROD PA NANUQ KUPARUK <Null> YES CD4-301A 501032055701 PROD PA NANUQ KUPARUK <Null> YES CD4-301B 501032055702 PROD ACTIVE NANUQ KUPARUK OIL YES CD4-594 501032080700 INJ ACTIVE NARWHAL SW CD4-594PH1 501032080770 EXPEND PA NARWHAL <Null> CD4-595 501032077800 PROD ACTIVE NARWHAL OIL CD4-595PH 501032077870 EXPEND PA NARWHAL <Null> CD4-597 501032083900 INJ ACTIVE NARWHAL <Null> CD2-77 501032062900 PROD ACTIVE ALPINE OIL CD4-03 501032064100 INJ ACTIVE ALPINE MWAG CD4-05 501032055800 PROD ACTIVE ALPINE OIL CD4-07 501032055300 PROD ACTIVE ALPINE OIL CD4-12 501032041401 INJ ACTIVE ALPINE MWAG CD4-12PB1 501032041470 EXPEND PA ALPINE <Null> CD4-16 501032053500 PROD ACTIVE ALPINE OIL CD4-17 501032053400 INJ ACTIVE ALPINE MWAG CD4-208 501032051700 INJ PA NANUQ MWAG CD4-208A 501032051701 PROD ACTIVE ALPINE OIL CD4-208AL1 501032051760 PROD ACTIVE ALPINE OIL CD4-208APB1 501032051771 EXPEND PA ALPINE <Null> CD4-208PB1 501032051770 EXPEND PA NANUQ <Null> CD4-209 501032053200 INJ ACTIVE NANUQ MWAG CD4-210 501032053300 PROD PA NANUQ OIL CD4-210A 501032053301 PROD PA ALPINE <Null> CD4-210APB1 501032053370 EXPEND PA ALPINE <Null> CD4-210B 501032053302 PROD ACTIVE ALPINE OIL CD4-211 501032053800 PROD ACTIVE NANUQ OIL CD4-211L1 501032053860 PROD ACTIVE NANUQ OIL CD4-211L1-01 501032053861 PROD ACTIVE NANUQ OIL CD4-213 501032054000 INJ PA NANUQ <Null> CD4-213A 501032054001 INJ PA ALPINE <Null> CD4-213B 501032054002 INJ ACTIVE ALPINE MWAG CD4-213BPB1 501032054070 EXPEND PA ALPINE <Null> CD4-213BPB2 501032054071 EXPEND PA ALPINE <Null> CD4-214 501032053700 INJ ACTIVE NANUQ MWAG CD4-214L1 501032053760 INJ ACTIVE NANUQ MWAG CD4-215 501032053900 PROD ACTIVE NANUQ OIL CD4-215L1 501032053960 PROD ACTIVE NANUQ OIL CD4-23 501032062100 PROD ACTIVE ALPINE OIL CD4-23PB1 501032062170 EXPEND PA ALPINE <Null> CD4-23PB2 501032062171 EXPEND PA ALPINE <Null> CD4-24 501032060200 INJ ACTIVE ALPINE MWAG CD4-24PB1 501032060270 EXPEND PA ALPINE <Null> CD4-24PB2 501032060271 EXPEND PA ALPINE <Null> CD4-25 501032060800 PROD ACTIVE ALPINE OIL CD4-25L1 501032060860 PROD ACTIVE ALPINE OIL CD4-25PB1 501032060870 EXPEND PA ALPINE <Null> CD4-26 501032060000 INJ ACTIVE ALPINE MWAG CD4-27 501032064400 INJ ACTIVE ALPINE MWAG CD4-27PB1 501032064470 EXPEND PA ALPINE <Null> CD4-27PB2 501032064471 EXPEND PA ALPINE <Null> CD4-27PB3 501032064472 EXPEND PA ALPINE <Null> CD4-289 501032069700 INJ ACTIVE NANUQ PW CD4-290 501032067400 PROD ACTIVE NANUQ OIL CD4-291 501032067200 INJ ACTIVE NANUQ MWAG CD4-291PB1 501032067270 EXPEND PA NANUQ <Null> CD4-292 501032066900 PROD ACTIVE NANUQ OIL CD4-298PB1 501032062370 EXPEND PA NANUQ <Null> CD4-302 501032054500 INJ ACTIVE NANUQ KUPARUK MWAG CD4-304 501032055500 PROD ACTIVE NANUQ KUPARUK OIL CD4-304PB1 501032055570 EXPEND PA NANUQ KUPARUK <Null> CD4-306 501032055000 INJ ACTIVE NANUQ KUPARUK MWAG CD4-318 501032051900 PROD PA NANUQ KUPARUK OIL CD4-318A 501032051901 PROD ACTIVE NANUQ KUPARUK OIL CD4-318PB1 501032051970 EXPEND PA NANUQ KUPARUK <Null> CD4-319 501032051600 INJ ACTIVE NANUQ KUPARUK MWAG CD4-320 501032053100 PROD ACTIVE NANUQ KUPARUK OIL CD4-320PB1 501032053170 EXPEND PA NANUQ KUPARUK <Null> CD4-321 501032053600 INJ ACTIVE NANUQ KUPARUK MWAG CD4-322 501032055100 INJ ACTIVE NANUQ KUPARUK MWAG CD4-499 501032081000 PROD ACTIVE QANNIK OIL CD4-93 501032069000 PROD PA ALPINE <Null> CD4-93A 501032069001 PROD ACTIVE ALPINE OIL CD4-96 501032067300 PROD PA ALPINE OIL CD4-96A 501032067301 PROD ACTIVE ALPINE OIL CD4-96APB1 501032067370 EXPEND PA ALPINE <Null> NANUQ 3 501032036500 EXPLOR PA NANUQ <Null> NANUQ 5 501032041400 EXPLOR PA ALPINE <Null> Wells within 1/2 mile buffer of well track * Data from SDE layer: AK_WELL_BOTTOM_TD_ATDB_DD83 SECTION 3 – FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states “No underground sources of drinking water (“USDWs”) exist beneath the permafrost in the Colville River Unit area.” 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) All casing is cemented and tested in accordance with 20 AAC 25.030. See Wellbore schematic for casing details. 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: 13 & 3/8” casing cement pump report on 05/23/2023 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11ppg DeepCRETE cement lead, followed by 15.8 ppg class G cement displaced with 8.33 ppg water. Full returns were seen throughout the job. The plug bumped at 1276 psi and the floats were checked and they held. 9 & 5/8” casing cement pump report on 06/04/2023 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 13.0 ppg Lead cement, 15.8 ppg class G cement, displaced with 8.33 ppg water. The plug bumped at 970 psi and the floats were checked and they held. The 7 & 5/8” casing cement report on 06/16/2023 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug bumped at 1013 psi and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 05/25/2023 the 13-3/8” casing was pressure tested to 2,600 psi for 30 minutes On 06/06/2023 the 9-5/8” casing was pressure tested to 3,850 psi for 30 minutes. On 06/19/2023 the 7-5/8” casing was pressure tested to 3,850 psi for 30 minutes. On 07/06/2023 the 4-1/2” tubing was pressure tested to 3,500 psi for 30 minutes. On 07/06/2023 the 7-5/8” casing by 9-5/8” by 4.5 tubing annulus was pressure tested to 3,850 psi for 30 minutes. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 5,175 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 3,500 Electronic PRV 6,175 Highest pump trip 5,675 SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Table 2: Wellbore pressure ratings Size Weight, ppf Grade API Burst, psi API Collapse, psi 13 & 3/8” 68 L-80 5,050 2,260 9 & 5/8” 47 L-80 5,750 3,090 7 & 5/8” 29.7 L-80 6,890 4,790 7 & 5/8” 39 P-110S 12,620 11,700 4.5” 12.6 L-80 8,430 7,500 4.5” 12.6 P-110S 11,590 9,210 Stimulation Surface Rig-Up Alpine 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 consists of Cretaceous Brookian “Narwhal” Topset Sands. The Narwhal interval is approximately 275’ TVD thick at the heel of the lateral, thickening to >800’ TVD at the toe. The Narwhal reservoir is a very fine-grained quartz and lithic rich sand, interbedded with mudstone and siltstone, with a coarsening upward log profile. Top Narwhal was intersected at 14314.5’ MD, -4001.6’ TVDSS. The estimated fracture gradient for the Narwhal reservoir is 10.9 ppg. The overlying confining zone consists of greater than 1500’ TVD of Seabee Formation (dominantly mudstones beginning at top of C-30, 2834.5’ MD, -2761.6’ TVDSS) and approximately 200’ TVD of Albian K3 (dominantly siltstones). The estimated fracture gradient for the Seabee is 16-17 ppg and for the Albian K3 14.2 ppg. The underlying confining zone consists of approximately 250’ TVD of Albian mudstones and siltstones, based on nearby well control (CD4-595PH) and was not penetrated in the CD4-588 wellbore. The estimated fracture gradient for this interval is 16-17 ppg. SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, 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: None of any well transect K3 and Narwhal confining zone within ½ mile radius of the proposed wellbore trajectory. CD2-289 is targeting Qannik which is deeper than the confining zone of K3 for Narwhal. The top narwhal and K3 on CD4-298 is shallower before the fault encounters on CD4-588 at 6527’ MD.Agree. SFD 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 or fracture system transected the confining zone within one half mile radius of the wellbore trajectory for CD4-588. The fault intersected the CD4-588 well path at 6527’ MD and was interpreted from seismic data prior to drilling. The fault was encountered far above the reservoir interval in the overlying Seabee Formation and interpreted as a single plane with 60-90’ of throw. Within one half mile radius of the wellbore trajectory for CD4-588, the fault was also encountered in the CD4-594 at 6297’ MD. A second fault is seismically mapped within the one half mile radius of the CD4-588 wellbore trajectory but did not intersect the wellbore or any other wellbores within the half mile radius. This fault is seismically interpreted to be confined within the Narwhal reservoir and does not intersect the confining zones. The fault is shown on the Fault Plat map. Fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that the apparent faults will not interfere with containment. We do not expect any of our hydraulic fractures to intersect the faults within the half mile radius of this wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Wellbore fault intersections that may transect the confining zones within a half mile radius of the CD4-588 wellbore. Well Name Fault Depth MD (ft) Fault Depth TVDSS (ft) Fault Vertical Displacement (ft) Fluid Losses (bbls/hr) CD4-588 6527 -2994 60-90 0 CD4-594 6297 -2888 60-90 0 g fault intersected the CD4-588 well path at 6527’ MD y interpreted to be confined within the Narwhal reservoir and does not intersect they confining zones. p, one fault pg in the overlying Seabee Formation jy second fault is SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD4-588 was completed in 2023 as a horizontal injector in the Narwhal formation. The well was completed with a 4.5” tubing upper completion and a 4.5” liner with 9ea ball actuated and 5ea dart actuated sliding sleeves lower completion. The upper most 2 sleeves will not be opened. The 1st stage will be pumped with initially dropping ball to shift sleeve opened, sequentially continue to remaining ball actuated sleeves until stage 9 (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow fracturing from the toe of the well towards the heel. Stage 10-12 will be activated with dart drop system with the same mechanism as ball drop. Proposed Procedure: Halliburton Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any preexisting conditions. 2. 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. 3. Pressure test the rig installed frac tree to 10,000 psi. 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 100º F seawater (approx. 2,200 barrels are required for each stage with breakdown, maximum pad and pumping down the next ball. (450 bbls usable volume per tank). 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 from 2,500 psi to 3,850 psi as the tubing pressures up. 10. Pump the 300 bbl breakdown stage (30# Delta) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 25 BPM as quickly as possible, pressure permitting. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 11. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 12. Pump the 12 stage Frac job by following attached HES schedule @ ~25 bpm with a maximum expected treating pressure of 6,125 psi. 13. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep/production tree installation and flowback (Slickline and possibly CTU). 5175 psi CDW 3500 psi CDW SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will be turned over to production for initial clean up production before conversion to injection TO: AOGCC 333 WEST 7T" SUITE 100 ANCH. AK. 99501 279-1433 OPERATOR: CPAI SAMPLE TYPE: Dry Cuttings SAMPLES SENT: CD4-588 12200 - 20127 3 Boxes SENT BY: M. McCRACKEN RECEIVED JUL 13 2023 SAMPLE T5401GCflN DATE: 07/13/2023 AIR BILL: N/A CPAI: CPA12023071303 CHARGE CODE: N/A NAME: CD4-588 �a3- b211 5z-- NUMBER OF BOXES: 3 Boxes UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY CONOCOPHILLIPS, ALASKA 700 G ST ATO-380 ANCHORAGE, AK. 99510 ATTN: MIKE McCRACKEN Mike.mccracken@conocophillips.com RECEIVED STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________COLVILLE RIV UNIT CD4-588 JBR 07/26/2023 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 Tested with 4 1/2", 5 7/8" and 7 5/8" test joints, Tested all gas alarms and PVT's. Precharge Bottles 36 each all at 1000psi each. Good Test! Test Results TEST DATA Rig Rep:J. Newman / E. FleagleOperator:ConocoPhillips Alaska, Inc.Operator Rep:K. Hinrichs / K. Harding Rig Owner/Rig No.:Doyon 26 PTD#:2230290 DATE:6/5/2023 Type Operation:DRILL Annular: 250/3500Type Test:OTH Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB230607070626 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8 MASP: 1522 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 2 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 18 3/4 P #1 Rams 1 4 1/2x7 5/8 P #2 Rams 1 Blind/Shear P #3 Rams 1 3 1/2x6 5/8 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 1/16,3 1/8 P Kill Line Valves 2 3, 3 1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1700 200 PSI Attained P28 Full Pressure Attained P143 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P10@3900 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P19 #1 Rams P16 #2 Rams P14 #3 Rams P14 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2      Test Type "OTH" = 21 day interval; jbr Doyon 26 CD4-588 6-5-23 Test Sequence 4-1/2 Test Joint #1. Annular/ Valves 1,14,15,16/ kill valve 3/ upper IBOP #2. UPR/ Valves 10,13/ HCR kill/ Lower IBOP #3. Valves 4,9,12/ 5-7/8 Dart #4. Valves 6,8,11/ 5-7/8 FOSV #5. Valves 5,7 #6. Valve 2 #7. HCR choke/ 4-1/2 Dart #8. Manual choke/ Manual Kill/ 4-1/2 FOSV #9. LPR w/ 4-1/2 Test Joint #10. LPR w/ 5-7/8 Test Joint #11. UPR w/ 7-5/8 Test Joint #12 Blind rams/ Valve #3 #13 Choke A & B 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.govChris Brillon Engineering Manager ConocoPhillips P.O. Box 100360 Anchorage, AK, 99510 Re: Narwhal, Undefined Oil, CD4-588 ConocoPhillips Permit to Drill Number: 223-029 Surface Location: 2456 FSL, 4799 FEL, Sec 19, Twn 11 N, Rg 5 E Bottomhole Location:2213 FSL, 558 FEL, Sec 28, Twn 11 N, Rg 5 E Dear Mr. Brillon: Enclosed is the approved application for the permit to drill the above referenced well. Proposed logging program is described in the attached email from Justin Cremer (CPAI) to Steve Davies (AOGCC) dated May 2, 2023. Minimum logging suite required for this well is gamma ray and resistivity recorded from base of conductor to TD. 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 AOGCC reserves 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 AOGCC specifically 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 AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair, Commissioner DATED this ___ day of April, 2023. 5 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.04 13:28:22 -08'00' May 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: 20,470 TVD: 4326 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 5/24/2023 Total Depth:9. Acres in Property:14. Distance to Nearest Property: 557.5' to ADL392961 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 73.5 15. Distance to Nearest Well Open Surface: x-378408 y- 5957581 Zone- 4 18.9 to Same Pool: 3634' to CD4-594 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94.0 H-40 Welded 120 0 0 135 135 16" 13.375" 68.0 L-80 Hyd563 2750 0 0 2750 2428 12.25" 9.625" 47.0 T-95 Hyd563 10220 0 0 10220 3486 8.5" x 9.5" 7.625" 29.7 / 39.0 L-80 / P-110S Hyd523 4158 10070 3469 14228 4053 6.5" 4.5" 12.6 P-110S Hyd563 6392 14078 4027 20470 4326 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: Justin Cremer Chris Brillon Contact Email:Justin.cremer@conocophillips.com Engineering Manager Contact Phone:907-231-7426 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: 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 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 270sx 13ppg ext. lead, 123sx 15.8 ppg C Uncemented liner w/ frac sleeves Effect. Depth MD (ft): Effect. Depth TVD (ft): Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Conductor/Structural LengthCasing Cement Volume MDSize Plugs (measured): (including stage data) 10 yds 1263sx 11 ppg & 334sx 15.8 ppg 2485, 640 18. Casing Program: Top - Setting Depth - BottomSpecifications 2170 Total Depth MD (ft): Total Depth TVD (ft): 59-52-180 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 871sx 15.8 ppg Class G 1763 1744 FSL, 3312 FEL, Sec 21, Twn 11 N, Rg 5 E 2213 FSL, 558 FEL, Sec 28, Twn 11 N, Rg 5 E LONS 97-007 P.O. Box 100360 Anchorage, Alaska, 99510-0360 ConocoPhillips 2456 FSL, 4799 FEL, Sec 19, Twn 11 N, Rg 5 E ADL384211, ADL380081 CD4-588 Narwhal Undefined Oil Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 50-103-20853-00-00 Yes DSR-3/31/23SFD 5/2/2023 223-029 ? VTL 5/4/2023 Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig Annular preventer test to 2500 psig Diverter variance granted per 20 AAC 25.035(h)(2) Waiver for CPAI Rotary Rig BOPE Test Frequency applies according to order OTH-21-018 extension attached Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval Surface casing LOT and annular LOT to the AOGCC as soon as available. VTL 5/4/23 X 1955 1522 JLC 5/4/2023 5/4/2023Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.05.04 13:28:49 -08'00' 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov March 2, 2023 Mr. Luke Lawrence Wells Manager ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Re: Docket Number: OTH-21-018 CPAI Rotary Rig BOPE Test Frequency Dear Mr. Lawrence: By letter dated January 12, 2023, ConocoPhillips Alaska, Inc. (CPAI) requested a continuance of the waiver granted under Docket OTH-21-018 allowing certain CPAI rotary drilling rigs to test blowout prevention equipment (BOPE) on a 21-day test schedule. The Alaska Oil and Gas Conservation Commission (AOGCC) grants CPAI’s request for a limited duration and scope. OTH-21-018 approved the 21-day test interval for a 1-year period which expired on January 25, 2023. The AOGCC approved an extension to the pilot program by electronic mail on February 6, 2023, to accommodate review of the July-December 2022 BOPE Between Wells Maintenance Report (received January 27, 2023, and revised February 3, 2023). AOGCC met with CPAI on February 22, 2023 to discuss the Between Wells Maintenance Report and BOPE performance of the CPAI-operated rigs during 2022 in considering the requested continuance.1 During the past year, CPAI-operated rigs Doyon 25 and Doyon 26 were authorized to participate in the pilot – the other rigs working for CPAI failed to meet the conditions for testing BOPE at 21- day intervals.2 CPAI’s request to continue the pilot project allowing BOPE testing on a 21-day interval is approved for drilling rigs Doyon 25 and Doyon 26, with the following conditions: - The pilot test duration is for ONE year from the approval date of this letter, subject to potential extension and expansion to include other CPAI operated rigs with at least 3 months of continuous rig work and AOGCC review of a rig’s BOPE system reliability. 1 AOGCC approval of the Between Wells Maintenance program has enabled CPAI workover rigs to extend the interval between BOPE tests from every 7 days to not exceeding 14 days and was also part of the justification for allowing certain rigs to test BOPE on a 21-day interval. CPAI data shows the BWM has reduced the number of component failures during BOPE testing by replacing components that indicate suspect integrity before those components fail during testing. 2 Doyon 26 has additionally been approved (Permit-to-Drill) to test BOPE on an event-basis instead of at pre- determined time intervals while drilling specific sections in an ultra-extended reach well. Docket Number: OTH-21-018 March 2, 2023 Page 2 of 2 - CPAI must continue to implement the BWM program as approved by AOGCC. - Development drilling wells only are included in this approval. - 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. - 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. - 48-hour advance notice for a BOPE test shall be provided to AOGCC for opportunity to witness. If you have questions regarding this, please contact Jim Regg at (907) 793-1236. Sincerely, Brett W. Huber, Sr. Chair, Commissioner cc: Greg Hobbs (CPAI) Mike Kneale (CPAI) Victoria Loepp (AOGCC) AOGCC Inspectors (email) Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.02 11:09:23 -09'00' ϰͲϱϴϴ 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. * Recommend approval of requested diverter variance: CD4-588 will be the 43rd well drilled from the CD4 Pad, and it will be the 4th well drilled to the Narwhal sand from this pad. Surface casing shoes of Nanuk 1, CD4-302, and CD4-298 all lie between 270' and 520' from planned surface casing shoe of CD4-588. The daily drilling operations summaries for these three wells do not report encountering shallow gas or gas hydrates. SFD 5/2/2023 * ??? CD4-588 Drilling Hazards Summary 16" Hole / 13- Hazard Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Gas Hydrates Low Monitor well at base of permafrost, controlled drilling rates, low mud temperatures. Additions of Lecithin. Lost Circulation Low Monitor real time equivalent circulating density (ECD) to below expected formation fracture gradient. Prepare enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of hole if necessary. Anti-Collision Low Monitor real time surveys closely, run gyro survey to eliminate magnetic interference from nearby wells when needed. Washouts / Hole Sloughing Moderate Keep mud temperatures as low as possible, minimize circulating time when possible. 12-/ 9-Casing Interval Hazard Risk Level Mitigation Strategy Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and torque/drag real time. Abnormal Reservoir Pressure Low Monitor pit volumes while drilling and tripping, flow check on connections. Shallow hazard analysis performed and suggests low risk of abnormal pressure. Lost Circulation Low Monitor ECD to below expected formation fracture gradient. Prepare enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of hole if necessary. 8-1/2 x 9-1/2 Hole / 7-5/8 Interval Hazard Risk Level Mitigation Strategy Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and torque/drag real time. Abnormal Reservoir Pressure Low Monitor pit volumes while drilling and tripping, flow check on connections. Shallow hazard analysis performed and suggests low risk of abnormal pressure. Narwhal Central Sand PP expected to be ~8.9 ppg. Lost Circulation Moderate Monitor real time equivalent circulating density (ECD) to below expected formation fracture gradient. Prepare enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of hole if necessary. 6-1/2" Open Hole / 4-val Hazard Risk Level Mitigation Strategy Abnormal Reservoir Pressure Low Monitor pit volumes while drilling and tripping, flow check on connections. Narwhal Central Sand PP expected to be ~8.9 ppg. Narwhal Lefty Sand PP expected to be ~9.6 ppg. Central Sand and Lefty Sand may communicate prior to drilling. Stuck Pipe Low Keep good hole cleaning practices, use PWD tools monitoring and analysis, stabilized BHA. Lost Circulation Moderate Reduced pump rates, mud rheology, use LCM program, control ECD below expected fracture gradient. Differential Sticking Low Follow mud program, keep pipe moving when able. Getting Liner to bottom Moderate Monitor T&D real time for early signs of issues, properly clean hole prior to pulling out of hole to run liner. Hole swabbing on trips Moderate Use proper tripping speed, monitor proper hole fill (use of trip sheets), pumping backreaming out if necessary. CD4-588 Narwhal Lefty Sand Injector with 7-5/8 INT2 (RKBD26 = 73.5') Surface Casing: 13-3/8" 68# L80 H563 MD / 2,428' TVD 56° Inc Conductor Installed: 20" set @ 135' MD / TVD Production Liner: 4-1/2" 12.6# TN110S H563 14,078'-20,470' MD Intermediate 1: 9-5/8" 47# T95 H563 @ 10,220' MD / 3,486' TVD 83° Inc Tubing: 14,078' 4-½L80 H563 12-1/4" Intermediate 1 Hole 6-1/2" Production Hole 16" Surface Hole Narwhal LOL/Lefty Sand Top: 14,917' MD / 4,172' TVD Intermediate 2: 7-5/8" 29.7# L80 H523 7-5/8" 39# P110S H523 (680' heavy heel) w/ 29.7# Shoetrack @ 14,228' MD / 4,053' TVD 80° Inc 7-5/8" x 9-5/8" Liner hanger: MD' / 3,469' TVD TOC @ 8,027' MD / 3,236' TVD (250' TVD above shoe) FMC Big Bore Well Head Last Update: 3/14/23 TGP DHG TOC @ 11,400' MD / 3,621' TVD (1500' MD above K3) K-3 Top: Possible Sand Stringers 12,900' MD / 3,821' TVD Narwhal Central Sand Top: 14,315' MD / 4,068' TVD 4-½Citadel MOAS Shoe 3.75" DB 3.813" X CMU 3.813" X Nipple -x -Under-Reamed Intermediate 2 Hole Production TD: @ ± 20,470' MD / 4,326' TVD -x 7-5/8" ZXP Liner Top Packer 14,078' MD -x 7-5/8" Baker Flex Lock Liner hanger DrilPlex WBM 10.5 ppg FWP WBM 11.3ppg FWP WBM 9.5ppg VersaPro OBM 8.3ppg Diesel 6.8ppg ~2000' TVD GLMGLM GLM Brine 9.2ppg CD4-588wp04.1 Production Packer Oil swell packers and frac sleeves 55 600 600 900 900 1200 1200 1700 1700 2100 2100 2300 2300 2500 2500 3500 3500 6300 6300 8000 8000 10000 10000 15000 15000 21000 CD4-588 wp04.1 Plan Summary 0 3 0 3000 6000 9000 12000 15000 18000 Measured Depth 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 30.0 30.0 60.0 60.0 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 55 118218318 4185176167158139101008CD4-289 55 118218 318 417516 614 712 CD4-290 55118218318417516CD4-29155118218318417516CD4-291PB1 551002003004015016037048069071009111112121312141415171620 1722CD4-586 wp05 55100200300400500601702 802 903 1003 1103 13778 13872 CD4-587 wp06 2250 0 2250 4500 6750 9000 11250 13500 15750 Vertical Section at 110.38° 13-3/8" Surface Casing 9-5/8" Intermediate Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 13 25 38 0 400 800 1200 1600 2000 2400 2800 Measured Depth Equivalent Magnetic Distance DDI 7.228 SURVEY PROGRAM Date: 2019-09-27T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 54.60 1400.00 CD4-588 wp04.1 (CD4-588) SDI_URSA1_I4 1400.00 2740.00 CD4-588 wp04.1 (CD4-588)MWD OWSG 1400.00 2740.00 CD4-588 wp04.1 (CD4-588) MWD+IFR2+SAG+MS 2740.00 3740.00 CD4-588 wp04.1 (CD4-588) MWD OWSG 2740.00 10210.00 CD4-588 wp04.1 (CD4-588) MWD+IFR2+SAG+MS 10210.00 11220.00 CD4-588 wp04.1 (CD4-588) MWD OWSG 10210.00 14220.00 CD4-588 wp04.1 (CD4-588) MWD+IFR2+SAG+MS 14220.00 15220.00 CD4-588 wp04.1 (CD4-588) MWD OWSG 14220.00 20469.55 CD4-588 wp04.1 (CD4-588) MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2428.24 2749.98 13-3/8" Surface Casing 3486.00 10220.00 9-5/8" Intermediate Casing 4053.32 14228.01 7-5/8" Intermediate Casing 4326.00 20469.55 4-1/2" Production Liner Mag Model & Date: BGGM2022 20-Oct-23 Magnetic North is 14.99° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.61° 57238.17nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 54.60 0.00 0.00 54.60 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 1.00 3 500.00 2.00 70.00 499.96 1.19 3.28 1.00 70.00 2.66 Start Build 1.75 4 700.00 5.50 70.00 699.50 5.67 15.57 1.75 0.00 12.62 Start Build 2.25 5 1225.29 17.32 70.00 1213.50 41.14 113.04 2.25 0.00 91.64 Start 104.75 hold at 1225.29 MD 6 1330.04 17.32 70.00 1313.50 51.81 142.35 0.00 0.00 115.40 Start Build 2.75 7 2706.46 55.17 70.00 2403.50 325.11 893.23 2.75 0.00 724.11 Start 20.00 hold at 2706.46 MD 8 2726.46 55.17 70.00 2414.92 330.72 908.65 0.00 0.00 736.62 Start DLS 3.50 TFO 31.37 9 3638.84 83.45 86.09 2735.82 493.95 1734.18 3.50 31.37 1453.63 Start 8335.10 hold at 3638.84 MD 1011973.93 83.45 86.09 3685.93 1058.68 9995.67 0.00 0.00 9001.40 Start DLS 3.50 TFO 97.93 11 13781.14 80.00 150.00 3975.91 267.18 11491.30 3.50 97.93 10679.04 Start 300.00 hold at 13781.14 MD 1214081.14 80.00 150.00 4028.00 11.32 11639.02 0.00 0.00 10906.62 CD4-NE4A (LL) T1 110822 Start 20.00 hold at 14081.14 MD 1314101.14 80.00 150.00 4031.47 -5.74 11648.87 0.00 0.00 10921.79 Start DLS 0.25 TFO -2.48 1414141.45 80.10 150.00 4038.44 -40.12 11668.73 0.25 -2.48 10952.38 Start 776.63 hold at 14141.45 MD 1514918.08 80.10 150.00 4171.95 -702.66 12051.31 0.00 0.00 11541.73 Start DLS 2.00 TFO 0.04 1615250.55 86.75 150.00 4210.00 -988.53 12216.37 2.00 0.04 11796.00 CD4-NE4A (LL) T2 110822 Start DLS 2.50 TFO -0.01 1715330.21 88.74 150.00 4213.13 -1057.46 12256.17 2.50 -0.01 11857.31 Start 5139.34 hold at 15330.21 MD 18 20469.55 88.74 150.00 4326.00 -5507.17 14825.25 0.00 0.00 15815.08 CD4-NE4A (LL) T3 110822 TD at 20469.55 FORMATION TOP DETAILS TVDPath Formation 1261.91 Base Perm 2217.59 C-40 2448.09 C-30 2748.98 C-20 3035.82 C-10 3820.81 K-3 3903.93 K-3 FS1 3948.43 K-3 FS2 3981.70 K-3 FS3 4005.33 K-3 FS4 4068.25 Central Top 4171.81 LOL Top By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by 18.9+54.6 @ 73.50usft NAD 83 Attachment 6 CD4-588 Area of Review (AOR) An Area of Review plot is show below of the CD4-588 Injector planned well path and offset wells. There are no offset wells within ¼ mile from CD4-588. CD4-587 (shown on plot) is a planned well that will not be drilled prior to CD4-588 Well Name Status Top of Pool (MD/TVD) TOC (MD/TVD) TOC Determined By Reservoir Status Zonal Isolation Cement Operations Summary CD4-587 Not Drilled Certificate Of Completion Envelope Id: 3C4CC5CEE1B04F0FADA3DD663E9137E5 Status: Completed Subject: Complete with DocuSign: 01_CD4-588 AOGCC PTD Final.pdf Source Envelope: Document Pages: 62 Signatures: 1 Envelope Originator: Certificate Pages: 4 Initials: 0 Justin Cremer AutoNav: Enabled EnvelopeId Stamping: Disabled Time Zone: (UTC-06:00) Central Time (US & Canada) 600 N Dairy Ashford Rd Houston, TX 77079-1100 Justin.Cremer@conocophillips.com IP Address: 138.32.8.5 Record Tracking Status: Original 3/30/2023 5:07:31 PM Holder: Justin Cremer Justin.Cremer@conocophillips.com Location: DocuSign Signer Events Signature Timestamp Chris Brillon chris.l.brillon@conocophillips.com Wells Engineering Manager Security Level: Email, Account Authentication (None)Signature Adoption: Uploaded Signature Image Using IP Address: 138.32.8.5 Sent: 3/30/2023 5:08:29 PM Viewed: 3/31/2023 9:54:17 AM Signed: 3/31/2023 10:02:46 AM Electronic Record and Signature Disclosure: Accepted: 3/31/2023 9:54:17 AM ID: ddb28a91-ec4f-4ef2-8d64-4106b9a16e6f In Person Signer Events Signature Timestamp Editor Delivery Events Status Timestamp Agent Delivery Events Status Timestamp Intermediary Delivery Events Status Timestamp Certified Delivery Events Status Timestamp Carbon Copy Events Status Timestamp Witness Events Signature Timestamp Notary Events Signature Timestamp Envelope Summary Events Status Timestamps Envelope Sent Hashed/Encrypted 3/30/2023 5:08:29 PM Certified Delivered Security Checked 3/31/2023 9:54:17 AM Signing Complete Security Checked 3/31/2023 10:02:46 AM Completed Security Checked 3/31/2023 10:02:46 AM Payment Events Status Timestamps Electronic Record and Signature Disclosure ELECTRONIC RECORD AND SIGNATURE DISCLOSURE From time to time, ConocoPhillips (we, us or Company) may be required by law to provide to you certain written notices or disclosures. 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Acknowledging your access and consent to receive and sign documents electronically To confirm to us that you can access this information electronically, which will be similar to other electronic notices and disclosures that we will provide to you, please confirm that you have read this ERSD, and (i) that you are able to print on paper or electronically save this ERSD for your future reference and access; or (ii) that you are able to email this ERSD to an email address where you will be able to print on paper or save it for your future reference and access. Further, if you consent to receiving notices and disclosures exclusively in electronic format as described herein, then select the check- By selecting the check- that: You can access and read this Electronic Record and Signature Disclosure; and You can print on paper this Electronic Record and Signature Disclosure, or save or send this Electronic Record and Disclosure to a location where you can print it, for future reference and access; and Until or unless you notify ConocoPhillips as described above, you consent to receive exclusively through electronic means all notices, disclosures, authorizations, acknowledgements, and other documents that are required to be provided or made available to you by ConocoPhillips during the course of your relationship with ConocoPhillips. 1 Davies, Stephen F (OGC) From:Cremer, Justin <Justin.Cremer@conocophillips.com> Sent:Tuesday, May 2, 2023 3:46 PM To:Davies, Stephen F (OGC) Cc:Guhl, Meredith D (OGC); Crews, Jennifer R Subject:RE: [EXTERNAL]CRU_CD4-588 (PTD 223-029) - Question Steve, NothereisnoplantopreͲproducefor30daysorlonger.Itwillbeflowedbacktocleanup.Thankyouforthenoteon injection.Wewillnotinjectuntiltheareainjectionorder. Justin From:Davies,StephenF(OGC)<steve.davies@alaska.gov> Sent:Tuesday,May2,20233:18PM To:Cremer,Justin<Justin.Cremer@conocophillips.com> Cc:Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:RE:[EXTERNAL]CRU_CD4Ͳ588(PTD223Ͳ029)ͲQuestion Justin, Afterfracturing,willCD4Ͳ588bepreͲproducedfor30daysorlonger,orwillitbeflowedbackforcleanup?Notethat thiswellcannotoperateasaNarwhalinjectoruntilanAreaInjectionOrderhasbeenapprovedandissuedbythe AOGCC. Thanksandstaysafe, SteveDavies AOGCC CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:Cremer,Justin<Justin.Cremer@conocophillips.com> Sent:Tuesday,May2,20233:09PM To:Davies,StephenF(OGC)<steve.davies@alaska.gov> Subject:RE:[EXTERNAL]CRU_CD4Ͳ588(PTD223Ͳ029)ͲQuestion Steve, HereiswhatourplanisforMWD/LWD: MWDLWD SurfaceD&I,GWDGR/ResPWD Intermediate1D&IGR/Res,Den/Neu,PWD Intermediate2D&IGR/ResAzmDen,PWD 2 ProductionD&IGR/Res,AzmDen,Sonic,UltrasonicPWD Thesearesubjecttochangebaseduponavailabilityandsubsurfaceneeds. Thanks, Justin From:Davies,StephenF(OGC)<steve.davies@alaska.gov> Sent:Tuesday,May2,20232:44PM To:Cremer,Justin<Justin.Cremer@conocophillips.com> Subject:[EXTERNAL]CRU_CD4Ͳ588(PTD223Ͳ029)ͲQuestion Justin., Thankyouforthedirectionalsurveydata. Quickquestion:Idon’trecallreadingaloggingprogramwithinCPAI’sapplicationbeyondafewoccurrencesof“Run MWD/LWDloggingtoolsindrillstringasrequiredfordirectionalmonitoringandformationdatagathering”andthe mentionofasoniclogatTDtoevaluatecement.WhatLWDtool(s)doesCPAIplantorecordacrosseachsectionofthe well? Thanksagainandstaysafe, SteveDavies AOGCC CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:Cremer,Justin<Justin.Cremer@conocophillips.com> Sent:Tuesday,May2,202312:34PM To:Davies,StephenF(OGC)<steve.davies@alaska.gov> Subject:RE:[EXTERNAL]CRU_CD4Ͳ588(PTD223Ͳ029)ͲRequest Steve, Pleasefindtherequesteddirectionalattached.Columnsareintheorderasmentionedbelow,MD,Inc,Azm. Thankyou, JustinCremer From:Davies,StephenF(OGC)<steve.davies@alaska.gov> Sent:Tuesday,May2,202312:24PM 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. 3 To:Cremer,Justin<Justin.Cremer@conocophillips.com> Subject:[EXTERNAL]CRU_CD4Ͳ588(PTD223Ͳ029)ͲRequest 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. Justin, CouldCPAIpleaseprovideadigitalcopyoftheplanneddirectionalsurveyforCD4Ͳ588?Idon’tseeone,andhavingthat datadigitallyinspreadsheetorcommaͲdelimitedtextfilespeedsmyportionofthereview.IonlyneedMD,inclination, andazimuthdatatoloadintomyworkstationsoftware. Thanksandstaysafe, SteveDavies AOGCC CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. 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:Cremer, Justin To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]CD4-588 Date:Thursday, May 4, 2023 8:37:48 AM Attachments:CD4-588 AOGCC PTD 10-401_Rev1.pdf Good Morning Victoria, Thank you for the note. Form 10-401 is incorrect. The estimated pore pressure is 1955 psig, which corresponds with the calculations and a ASP of 1,522 psi. Please advise if you would like me to resend the entire pdf’ed permit. Justin From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Thursday, May 4, 2023 8:29 AM To: Cremer, Justin <Justin.Cremer@conocophillips.com> Subject: [EXTERNAL]CD4-588 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. Justin, Please check/verify max downhole pressure, MPSP on 10-401 form vs calcs. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov 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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this 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. COLVILLE RIVER NARWHAL UNDEFINED OIL 223-029 CRU CD4-588 Proposed logging program is described in the attached email from Justin Cremer (CPAI) to Steve Davies (AOGCC) dated May 2, 2023. Minimum logging suite required for this well is gamma ray and resistivity recorded from base of conductor to TD. WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:COLVILLE RIV UNIT CD4-588Initial Class/TypeSER / PENDGeoArea890Unit50360On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2230290COLVILLE RIVER, NARWHL UND OIL - 120176NA1Permit fee attachedYesSurf Loc & Top Prod Int lie in ADL0384211; TD lies in ADL0380081.2Lease number appropriateYes3Unique well name and numberNoCOLVILLE RIVER, NARWHL UND OIL4Well 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 waitNoAIO needed. Well will not be operated as an injector until the approved AIO is issued.14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servYesNone currently.15All wells within 1/4 mile area of review identified (For service well only)No16Pre-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)Yes120'18Conductor string providedYesSC set at 2750' MD19Surface casing protects all known USDWsYes144% excess20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoUncemented liner with frac sleeves22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYesDiverter waiver approved per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax res pressure is 1955 psig( 8.7 ppg EMW); will drill w/ 8.3-11.0 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1522 psig; will test BOPs to 5000 psig initially and 3500 psig subsuquently30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNo33Is presence of H2S gas probableYesNo wells in AOR currently34Mechanical condition of wells within AOR verified (For service well only)YesNone anticipated based on nearby wells to the Narwhal sand.35Permit can be issued w/o hydrogen sulfide measuresYesNarwhal Central and Lefty sands are expected to be overpressured to36Data presented on potential overpressure zonesNA8.9 and 9.6 ppg EMW, respectively. MPD will be used in combination with 8.3 ppg mud to mitigate37Seismic analysis of shallow gas zonesNAany overpressured intervals encountered and to maintain wellbore stability.38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate5/2/2023ApprVTLDate5/4/2023ApprSFDDate5/2/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 5/4/2023