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Home My WebLink About219-107ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 CD5-26 50103208060000 2191070 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com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eport is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter.The report will be submitted each quarter, even with zero volumes, until the application expires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anuary 8, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Fourth Quarter, 2020 To whom it may concern: Please find attached the fourth quarter 2020 annular disposal reports for the Colville River Unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2020. With no rig activity due to the COVID 19 pandemic until December 15, 2020, injectivity testing on current and expired annuli was the only activity to determine disposal options. Tests were on the wells closest to CD5-90. A test on CD5-98, with an active sundry failed. A test completed on CD5-92 to investigate a new sundry for disposal appeared promising but failed in the end. These injectivity tests conclusively determined that CD5-92 and CD5-98 are not suitable for disposal anymore. CD5-26 remains the only well that might be used in the future as the rig moves to CD5- 31 in March 2021. It was not tested recently as it is farthest from the current drilling operations on CD5-90. Successful results of a test on CD5-26 and a request for an extension of the AD sundry on this previously approved but since unused annulus will potentially follow. If the test proves the well will not take injectivity, the final correspondence for it will be a final 1Q report as the sundry expires in March 2021. Please call Greg Hobbs at 263-4749 should you have any questions. Sincerely, G. S. Hobbs Regulatory Engineer G. S. Hobbs Regulatory Engineer Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4749 Digitally signed by Greg Hobbs DN: OU=Compliance and Regulatory, O=Drilling and Wells, CN=Greg Hobbs, E=greg.s.hobbs@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021-01-08 12:41:27 Foxit PhantomPDF Version: 10.0.0 Greg Hobbs 219-1077. Well Name:50-5a. Sundry Number:319-14510(h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added.(h)(2) drill rig wash fluids and drill rig domestic waste water(h)(3) Other Commission approved substances (include descriptions in block 12)Volume (bbls):Number of days disposal occurred:Disposal Beginning Dates:Disposal Ending Dates:Source Wells:Previous totals (bbls):312713831 10/27/19 10/27/19n/a - Initial LOT/ Flush and Diesel Freeze Protect.2020/Q10000 n/a n/an/a n/a2020/Q20000 n/a n/an/a n/a2020/Q37007 n/a09/21/20 09/21/20 n/a - injectivity test2020/Q40000 n/a n/an/an/a - This well will have an injectivity test when the rig moves to CD5-31.Total Ending Volume (bbls):3190713901Other (Explain) Printed Name:Title:Phone Number:907-263-4749ConocoPhillips Alaska, Inc2. Address:4b. Well Status: Oil Gas WAG 103-20806-00-00CD5-26PO Box 100360, Anchorage, Alaska12. Remarks and Approved SubstancesDescription(s):Diesel Freeze Protection5b. Sundry approval date:3/23/2020Report is due on the 20thof the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter.11. Attach: Disposal Performance Data: Pressure vs. Time Step Rate Test 9. Field:Colville River Unit3. (Check one box only)I hereby certify that the foregoing is true and correct to the best of my knowledge.Regulatory EngineerSignature:Date:1/8/2021G. HobbsInitial Disposal Continuation Final4a. Well Class: Stratigraphic Service GINJWINJWDSPL STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONREPORT OF ANNULAR DISPOSALDevelopment Exploratory6. Permit to Drill Number:8. API Number:1. Operator:G StForm 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in DuplicateDigitally signed by Greg HobbsDN: OU=Compliance and Regulatory, O=Drilling and Wells, CN=Greg Hobbs, E=greg.s.hobbs@conocophillips.comReason: I am the author of this documentLocation: your signing location hereDate: 2021-01-08 13:21:07Foxit PhantomPDF Version: 10.0.0Greg HobbsRBDMS HEW 1/25/2021 October 13, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Third Quarter, 2020 To whom it may concern: Please find attached the third quarter 2020 annular disposal reports for the Colville River Unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the third quarter of 2020. With no rig activity due to the COVID 19 pandemic, the only activity on our three active Annular Disposal permits were injectivity tests. These injectivity tests determined that the only well that might be used in the future is CD5-26, a newly permitted well late in the first quarter, but not used to date. The first report is attached for this well noting this test. Please call Greg Hobbs at 263-4749 should you have any questions. Sincerely, G. S. Hobbs Compliance and Regulatory Engineer G. S. Hobbs Compliance and Regulatory Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4749 Digitally signed by Greg Hobbs DN: OU=Compliance and Regulatory, O=Drilling and Wells, CN=Greg Hobbs, E=greg.s.hobbs@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-10-13 15:07:12 Foxit PhantomPDF Version: 10.0.0 Greg Hobbs 219-1077. Well Name:50-5a. Sundry Number:319-14510(h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added.(h)(2) drill rig wash fluids and drill rig domestic waste water(h)(3) Other Commission approved substances (include descriptions in block 12)Volume (bbls):Number of days disposal occurred:Disposal Beginning Dates:Disposal Ending Dates:Source Wells:Previous totals (bbls):312713831 10/27/19 10/27/19n/a - Initial LOT/ Flush and Diesel Freeze Protect.2020/Q10000 n/a n/an/a n/a2020/Q20000 n/a n/an/a n/a2020/Q37007 n/a n/an/a n/a - injectivity testYYYY/Q#0Total Ending Volume (bbls):319071390Other (Explain) Printed Name:Title:Phone Number:907-263-4749Initial Disposal Continuation Final4a. Well Class: Stratigraphic Service GINJWINJWDSPL STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONREPORT OF ANNULAR DISPOSALDevelopment Exploratory6. Permit to Drill Number:8. API Number:1. Operator:I hereby certify that the foregoing is true and correct to the best of my knowledge.Compliance and Regulatory EngineerSignature:Date:10/13/2020G. Hobbs12. Remarks and Approved SubstancesDescription(s):Diesel Freeze Protection5b. Sundry approval date:3/23/2020Report is due on the 20thof the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter.11. Attach: Disposal Performance Data: Pressure vs. TimeStep Rate Test 9. Field:Colville River Unit3. (Check one box only)ConocoPhillips Alaska, Inc2. Address:4b. Well Status: Oil Gas WAG 103-20806-00-00CD5-26PO Box 100360, Anchorage, AlaskaG StForm 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in DuplicateDigitally signed by Greg HobbsDN: OU=Compliance and Regulatory, O=Drilling and Wells, CN=GregHobbs, E=greg.s.hobbs@conocophillips.comReason: I am the author of this documentLocation: your signing location hereDate: 2020-10-13 15:15:13Foxit PhantomPDF Version: 10.0.0Greg HobbsRBDMS HEW 12/7/2020 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, CD5-26 Permit to Drill Number: 219-107 Sundry Number: 320-102 Dear Mr. Alvord: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 IAain: 907.279.1433 Fax: 907.276.7542 www. a ogcc. a I a ska.g ov Enclosed is the approved application for the sundry approval relating to annular disposal of drilling wastes in the above -referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, <0/_05� Daniel T. Seamount, Jr. Commissioner 1 d DATED this— da of March, 2020. RBDMSL& APR 0 7 2020 !� 5L3 �2312e� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 RECEIVE® MAR 4 2020 DIS Zo AOGCC 1. Operator 3. Permit to Drill Name: 219-107 ' ConocoPhillips Alaska 4. API Number: 50-103-20806-00-00 ' 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD5-26 - 6. Field: Colville River Unit- Alpine Pool ' 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD5-03, CD5-04, CD5-05, CD5-06, CD5-07, CD5-08, CD5-09, CD5-10, CD5-11, CD5-12, CD5-17, CD5-18, CD5-19, CD5-20, Torok and Seabee formation, shale, siltstone and sandstone - CD5-21, CD5-22, CD5-23, CD5-24, CD5-25, CD5-92, 01315-96, CD5-98, CD5-313, CD5-314X, CD5-315, CD5-316 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation ` None - c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and daystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1,326' MD and 1,323' ND None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2,142 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 16. Estimated start date: 1 -Apr -20 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) ❑� Cement Bond Log (if required) ❑ FIT Records w/LOT Graph Surf. Casing Cementing Data FYI Other R] previous authorization for new product cleanup fluids for CD1 and CD2 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: �/'"��` Title: Drilling Manager Printed Phone Name: Chip Alvord Number: 265-6120 Date: 3(I2eZ" Commission Use Only Conditions of approval:/I// LOT review and approval: C� I-V Subsequent form required: - 4 2 3 �BDMS O` APR 0 7 Moval number: Pb1.001 APPROVED BY /7 Approved by: COMMISSIONER THE COMMISSION Date: 31z�/zv LV:2& ulna IV-YVOMU Kev. O/mVY / �/�/ate uvJiK 1. I I K v Submit In uupllc e Annulus Disposal Transmittal Form - Well CD5-26 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD5-26 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost= 1323' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stmtigraphic sections range from 15000 to 18000 mg/l. (Rei AOGCC Conservation Order No. 443, March 15- 1999) 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement -contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maxim YQlumc to be riumned is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipemem after producing drilling/completion fluid (see included note from CD I &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2,142 psi. See attached calculation calculations showing how this value was determined. pagge. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. I I Identification of the hydrocarbon zones, if any above the The top of cement is 12,510' MD in the intermediate casing depth to which the inner casing is cemented. which covers the uppermost hydrocarbon bearing zone. No hyrdrocarbou bearing zones have been identified above this de 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD5-90, CD5-28, CD5-27, CD5-93, CD5-31 will be generated, 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Vmia"3.o-Jonas Well CDS-26 Assumptions Date 3/3/2020 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the10 3/4" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi 79 TVD TOC Est. @ 0' 0' c a v N v a; TOC Est. @ 12,510' MD €ss 6,953' TVD Pbwst85% — PHydrostatic + PApplied - PFomlation 4,429 =( 2,179* 0.052 *MW,� )+ 1500 - ( 0.4337 * 2,179 ) MWmax = 34.2 ppg Surface Casing Strin Size 10.75 in Weight 45.5 ppf Grade L 80 rburstl00% 5,210 psi Pb,rrs035% 4,429 psi Depth of Shoe 2,179 It FIT/LOT @ Shoe 18.9 ppg FIT/LOT for Annulus 15.5 ppg Max Surf. Pressure 1,500 psi or 2,142 psi Maximum Fluid Density avoid Collapse of 2nd Casing String Pwllapse85 %— PHydrostatic + PApplied' PGasGradienl - PHeader 4,072 = ( 6,953 * 0.052 * M Wa,„ ) + 1,500 - ( 0.0700 * 6,953 ) - 1,000 Pmax allowable — Shoe TVD Depth * .052 * Shoe FIT/LOT Prau allowable — ( 2,179 * .052 * 18.9 ) Pmax allowable= 2,142 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". MWmax = 11.2 ppg 4.5 "Tubing 2nd Casing String Size 7.625 in 17 TVD Weight 29.7 ppf Grade L 80 rcollapsel00% 4,790 psi Pwllapse85% 4,072 psi Top of Cement 6,953 It Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Pmax allowable — Shoe TVD Depth * .052 * Shoe FIT/LOT Prau allowable — ( 2,179 * .052 * 18.9 ) Pmax allowable= 2,142 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". C D5-26 Dinn . Wells within quarter mile of the surface casigg, borehole displayed to 25OO7vd ` z 0 -600 -1200 Al -1800 -2400 -1800 -1200 -600 0 600 1200 1800 2400 W est( -)/East(+) 3 06 ------------ - 1200 � Oy,9a- Goy, �G0y.12 GOy�61 600 �e i LP oCan' Al 0 01 CD5-26 srf cs pY__ G I - --- 60526 -------- Gpy-3�6 `'J►. ALO 09 GD5-314X_�--_GD -g13 GO GD5-315 `Qc�31 G y3 � G0yg6 19 CD5-26, 1"4-, Surface Casin Well: CD5.26 10-3144 45.5# L-80 PXf- M Casino Date: tai1312019 Conoco -Phillips Alaska, Inc so Rig: Doyon 25 Depth Jt Number Joints Well Equipment Description and Comments Page 1 Length Tops RKB to Top Of String or RKB to Lock Down Screws Doyon 25 RKB to top of Landing Ring 39.75 FMC 10-3/4" Casing Hanger .13 39.75 10-3/4", 45.5#, L-80, Casing Pup Jt, H563 Pin X H563 Pin 2.40 39.88 Full length XO A 10-3W', 45.5#, L-80, BTCM Pin X H563 Box 39.89 42.28 Jts 3 to 56 54 Jts 10-314", 45.5#, L-80, TXP-M Casing 2080.65 82.17 10-3!4" Topco BTCM Float Collar 1.23 2162.82 Jts 1 to 2 2 As 10-314",45.5#, L-80, TXP-M Casing 73.39 2164.05 10-3!4" Topco BTCM Shoe 2.73 2237.44 2240.17 2240.17 2240.17 2240.17 2240.17 2240.17 10-314" Shoe at 2,240' MD 2,179' TVD 2240.17 13-1/2" TD at 2,252' MD, 2,190' TVD 12' rathole 2240.17 2240.17 2240.17 2240.17 2240.17 2240.17 1 Centek 10' up from shoe w/stop rings on Jt #1 2240.17 1 Centek 30' up from pin w/stop rings on Jt #2 2240.17 1 Centek 20' up from pin w/stop rings on Jt #3 2240.17 1 Centek centralizer every joint from #4 to #15 Floating 2240.17 1 Topco bowspring every Jt from #16 to #55 over coupling 2240.17 2240.17 2240.17 2240.17 2240.17 Total Centralizers 2240.17 15 Centek, SII, 10-314" x 13-112'. PN 1034-1312S 2240.17 (40) Top -Co PN 300-273413410.75' x 13-51W bowsprings 2240.17 2240.17 2240.17 Remarks Up WIt 130 K MU Tq with Volant -H563 Doped to 16,200 fUlbs w/ Seal Guard ECF, TXP-M to 27,160 fdlbs wl Run N Seal Dam wt 126 K Bakerlocked to pin end of jt #4 Bloch Wt 43K Drifted with 9.875" drift Rig Supervisors: K Harding/G. MadeH e I Cement Detail Report CD5-26 String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/9/2019 06:00 Cement Details Description Surface Casing Cement Cementing Start Date 10/13/2019 16:00 Cementing End Date 10/13/2019 19:00 Wellbore Name CD5-26 Comment Cement Stages Stage # 1 Description Lead - Surface Casing Cement ObjectiveTop Lead -Isolate surface I casing annulus to surface Depth (ftKB) 39.3 Bottom Depth (ftKB) 11740.0 Ful[ Return? Yes ' Vol Cement.. Top 113.0 No Plug? Btm Plug? Yes Q Pump Init (bbllm... 5 16 A Pump Final (bbl/... O Pump Avg (bbI1 6 P Pump Final (psi) 920.0 P Plug Bump (psi) Recip? Yes I Stroke (ft) Rotated? 10 00 No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKe) Drill Out Diameter (in) Comment Lead Cement -Pumped 288.8bbls, 11ppg, Deeperete, 0.5% D167, 0.06 gas D185, 0.lgps D047 1740' to 1328'MD 50% excess 1328'MD-surface 250% excess above permafrost depth Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description Estimated Top (RKB) D.0 Est etm (RKB) 0.0 Amount (sacks) Class Mudpush II Volume Pumped (bbi) 75.0 Yield (83Isack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ibigal) 11 050 Plastic Viscosity (CP) Thickening Time (hr) Cm prStrI (psi) 1 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Lead Cement Fluld Description Estimated Top (ftKB) 39.3 Est Bum IRKS) 1,740.0 Amount (sacks) 850 Class G Volume Pumped (bbl) 288.8 Yield (Mlsack) 1.91 Mix H2O Ratio (gai... 6.85 Free Water I%) Density jib/gal) 11.00 Plastic Viscosity (cP) 208-0 Thickening Tlme (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKS) 1,740.0 Est Bum (RKB) 1,740.0 Amount (sacks) Class Volume Pumped (bbl) Yield (tt'Isack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gaq Plasllc Viscosity (cP) Thickening Tlme (hr) CmprStr 1 (psi) Additives AddUWe Type Concentration Cone Unit label Stage # 2 Description Tail - Surface Casing Cement I Objective Top Depth (ffKB) Tail -Secure the shoe and 1,740.0 bottom 500ft of annulus Bottom Depth (ftKB) Full 2,240.2 Yes Return? Vol Cement... Top Yes Plug? Btm Plug? No d Pump Init (bbllm... O 5 13 Pump Final (bbll... 10 Pump Avg (bbg... 4 P Pump Final (psi) 445.0 P Plug Bump (psi) 1,000 0 Raclin? Yes Stroke (ft) Rotated? 10.00 INo Pipe RPM (rpm) Tagged Depth (RKB) Tag MMhod Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Tail -Pumped 59 5bbis, 15.8ppg Class G, with D-047 0.05gps, D-255 0.5%, D-065 0.3%, D-186 0.015°/ 2240'- 1740' 50% excess Cement Fluids & Additives Fluid Fluid Type Tail Cement 15.04 Fluid Description Estimated Top (RKB) 1,740.0 Est Bim (RKB) 2,240.0 Amount (sacks) 288 Class G Volume Pumped fti 59.5 Yield JW/sack) 1.16 Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) 15.80 Plastic Viscostty (cP) 138.8 Thickening Time (hry CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 3/4/20201 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD5-26 11 Rig::11 Doyon 25 Date: 10/15/2019 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: R. Reinhardt / G. Madell Pump used: ut Mud Pump V ------- -- ---- ------------ Strokes '♦ 0.1007. Bbls/Strk W 0.50 Bbl/min Type of Test: ICasing Shoe Test LOT/FIT W Pumping down I annulus and IDP. Casing Test I Pressure Integrity Test Hole Size: 9-7/8" w Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 39.1 rFtj 2240.0 Ft -MD 2179.0 Ft -TVD I 2272.0 Ft -MD 2207.0 Ft -TVD Strks--psi Min psi Strks psi Min psi Casing Size and Description: 10-3/4" 45.5#/Ft L-ao BTC w 0 0 0 3600 0 0 0.00 1050 Casing Test Pressure IntegritvTest 2 250 1 3600 1 75 0.25 1050 Mud Weight: 10.0 ppg Mud Weight: Mud 10 min Gel: 13.0 Lb/100 Ft2 Mud 10 min Gel: Test Pressure:3500.0 psi Rotating Weight: Rotating Weight: Lbs Blocks/Top Drive Weight: Blocks/Top Drive Weight 43000.17 Lbs Desired PIT EMW: Estimates for Test: 2.5 bbls Estimates for Test: E MW =Leak -off Pressure +Mud Weight = 1 050 0,052 x TVD 0.052 x 2179 + 9'6 EMW at 2240 Ft -MD (2179 Ft -TVD) = 18.9 pp 9.6 ppg 9.0 Lb/100 Ft2 Lbs 43000.0 Lbs 18.5 ppg 1008 psi 0.7 bbls PIT 15 Second Shut-in Pressure, psi 4 5017 -2-S5-5-0 -2-110 0.50 1050 6 750 3 3550 3 15D 1.00 1050 8 1050 4 3550 4 200 1.50 1050 10 1250 5 3550 -5-250 2.00 1050 12 1400 6 3550310 2.50 050 14 1500 7 3550 7 400 3.00 1025 16 1700 8 3550 -9-S-5-50- 8 475 3.50 1025 18 1900 9-550 4.00 10 5 20 2150 10 3500 10 625 4.50 1025 1050 22 2400 15 3500 11 700 5.00 1025 0000 3500 sono LU 2500 � y 2000 w y 1500 1000 500 0 0 0 Lost 100 psi during o, fr 24 2600 20 3500 12 800 5.50 1025 26 2900 25 3500 13 875 6.00 1025 28 3100 30 3500 141 9751 6.50 1025 30 3400 15 1050 7.00 1025 321 36001 7.50 1025 8.00 1025 8.50 1025 9.00 1010 9.50 1010 10.00 1010 1 2 3 4 Barrels .CASING TEST - LEAK -OFF TEST 5 10 15 20 25 3o Shut -In time, Minutes o PIT Point Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back S S S S Comments: Tested casing with 10.0 ppg DrilPIex mud, 10/15/19 Performed FIT to 18.5 ppg EMW with 9.6 ppg mud, 10/15/19 Summary ., Operations Summary (with Timelog Depths) C D5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log start l ime End Tone 0ur hr Phase O Code P AcUoit Cade Y Time P -T- % Ope24on epth Sart B) (WB) End D 10/12/2019 10H 272019 2.50 SURFAC CASING TRIP P Blow down jet line and line up hole -fill 1,887.0 5 8 0 568.0 18:00 20:30 POOH on elevators from 1887'- 1165'MD. Rack back 5" HWDP and jar stand. PU/SP=105k/94K at 1800'. Experienced 15K overpull POOH at 25fpm. Maintain constant hole fill over the top. Manual strap every 5 stands. 10/12/2019 10/12/2019 2.25 SURFAC CASING BHAH P LD Schlum BHA#1 as per CO. Broke 568.0 96.0 20:30 22:45 apart collar to remove stuck Gyro tool. Found tool lower than planned as it passed thru UBHO. Broke apart BHA subs to remove Gyrodata tool from UBHO sub. LD Gyrodata tool to ground. 10/12/2019 10/13/2019 1.25 SURFAC CASING SHAH P Conitnue lay down BHA and bit. 960 0.0 2245 00:00 10/13/2019 10/13/2019 2.00 SURFAC CASING RURD P Clean rig floor and remove BHA subs. 0.0 0.0 00:00 0200 Build DC stand from drilling configuration. PU Doyon and rig up Volant tool to run 10 3/4" rasing. 10/13/2019 10/13/2019 4.00 SURFAC CASING PUTB P Make-up 10.75", L-80 shoe trac assbly 0.0 845.0 02:00 06:00 as per Doyon Casing rep, Bakedoking all connections. MU torque=27k ft -lbs. Checked floats, OK. Continue running 10.75", L-80, TXPM, 45.5ppf casing from surface to 845'MD. installed centralizers as per detail. Using Volant CRT, MU torque=27k ft -lbs, PU/SO wt=71 k/73k at 800ftMD. Filled casing on the fly and topped off every 10 its. 10/13/2019 10/13/2019 1.25 SURFAC CASING PUTB P Continue running 10.75", L-80, 845.0 1,151.0 06:00 0715 TXPM, 45.5ppf casing from 845'- 1151'MD, installed centralizers as per detail. Using Valant CRT, MU torque=27k ft -lbs,. Filled casing on the fly and topped off every 10 Its. SO wt=80k 10/13/2019 10/13/2019 2.25 SURFAC CASING PUTB P Establish circulation and pump down 1,151.0 1,496.0 07:15 09:30 hole while running in from 1151' to 1496'MD. Using Volant CRT, pum rate=2 bpm, 150psi, FO=80%. Totap l strokes pumped=9389stks (939bbls). $O wt --80K 10/13/2019 10/13/2019 0.50 SURFAC CASING CIRC P CBU below permafrost and stage up 1,496.0 1,536.0 0930 10:00 pumps to 7bpm.from 1496' to 1596'MD. Pumped 1441stks, 7bpm, 197psi, 56% FO, SO wt=78K. 10/1372019 10/1312019 2.00 SURFAC CASING PUTB P Continue running 10.75", L-80, 1,536.0 2,085.0 1000 12:00 TXPM, 45.5ppf casing from 1536'- 2085'MD. installed centralizers as per detail. Using Volant CRT, MU torque=27k ft -lbs,. Filled casing on the fly and topped off every 10 Its. $O wt=80k. Losses for tour=18bbls. 10/13/2019 10/13/2019 1.00 SURFAC CASING PUTB P Continue running 10.75", L-80, 2,085.0 2,240.0 12:00 1300 TXPM, 45.5ppf rasing from 2085'- 2240'MD. installed centralizers as per detail. Using Volant CRT, MU torque=27k ft -lbs,. Filled rasing on the fly and topped off every 10 Its. SO wt=80k. PU and MU xover joint, hanger and landing joint per FMC/DDI reps. PU/SO wts=121 K/100K. Page 4/51 Report Printed: 3/412020 �. Operations Summary (with Timelag Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Lag 5[ad7me End Tme our inn ( 1 Phase O Code P Ac gCotle Time P -T- % Operation n De Stan Depth End Depth (flKB) 10113/2019 10/13/2019 1.75 SURFAC CEMENT CIRC P Establish circulation to condition mud 2,240.0 2,240-0 13:00 14:45 for surface casing cement job while reciprocating. Staging up pump rate upmaintaining 10ppg, YP=18-25, ICP=235psi, 1.5bpm, FCP=97psi, 7bpm, FO=44% 10/13/2019 10/13/2019 0.50 SURFAC CEMENT CMNT P SO, rig up cement line to Volant 2,240.0 2,2400 14.45 15.15 swivel. 10/13/2019 10/13/2019 0.50 SURFAC CEMENT CIRC P Re-establish circulation thru cement 2,240.0 2,240.0 15:15 15.45 line and continue to condition mud at 7bpm while recipmrating. Held PJSM, surfce cementjob, total strokes pumped 7116 (711 bbls). 10/13/2019 10/13/2019 2.25 SURFAC CEMENT CMNT P Pump surface cementjob as per 2,240.0 2,240.0 15:45 18:00 Schlum/CPAI detail. PU/SO wt--127K/120K, 10/13/2019 10/13/2019 1.00 SURFAC CEMENT CMNT P Continue to pump surface cement as 2,240.0 2,240.0 18:00 1900 per Schlum detail. PU/SO wt=1241</100K. Bumped plug @1849 strokes at 3bpm w/515psi over final displacement pressure to1000psi, held for 5 minutes. Total pumped 1854stks, rigged down cement hose and checked floats, Floats held.. 10/13/2019 10/13/2019 1.00 SURFAC CEMENT WWWH P Flushed surface lines, HP riser, cycled 2,240.0 2,240.0 19:00 2000. annular and fluided past with fluid. Pumped thru injection line on lower spool with black water @ 5bpm. Continued cleaning cement from pits, through cuttings tank, Eddy pump. Cycled annular preventer and rinsed clean. 10/13/2019 10/13/2019 1.00 SURFAC CEMENT RURD P Rigged down casing equipment. 2,240.0 2,240.0 20:00 21:00 Cleaned out and LD Volant tool. LD casing equipment and backed out landing joint as per FMC rep. 10/13/2019 10/13/2019 1.00 SURFAC CEMENT WWWH P Drained riser and cleaned out cement 2,240.0 2,2400 2100 2200 from annular preventer, 4" conductor valves and cellar box. 10/1312019 10/14/2019 2.00 SURFAC CEMENT NUND P Remove bell nipple, annular preventer 2,240.0 2,240.0 22:00 0000 and high pressure riser. 10/14/2019 10/14/2019 3.25 SURFAC CEMENT NUND P NO Tee and slip lok adapter flange as 2,240.0 2,240.0 00:00 03:15 per FMC. Cleaned flange and layed down. Performed Halliburton Epoxy Cement Cemlok cap job as per HES rep and procedure. SIMOPS-grease choke manifold, clean rig floor cemenmting valves,removed wellside side valves for installtion. 10/14/2019 10/14/2019 1.00 SURFAC WHDBOP NUND P Nipple up FMC Gen 5 Unihead starter 2,2400 2,240.0 03:15 04:15 and tubing head sections wellhead as per FMC rep. Tested lower wellhead seals to 1,000psi, witnessed by CPAI. 10/14/2019 10/14/2019 1.75 SURFAC WHDBOP NUND P NU high pressure riser and adapter 2,240.0 2,240 0 04.15 06:00 flange. 10/14/2019 10/14/2019 5.75 SURFAC WHDBOP NUND P Confine to NU riser and flange with 2,240.0 2,2400 06:00 1145 Sweeny wrench. NU BOPE, MU choke and kill lines, MU flowbox and flowline, RU MPD equipment. SIMOPS -gather elevations, RU to perform Wellwom bias testing and MPD test. Page 5151 ReportPrinted: 314/2020 CD5-26 7-58"Intermediate casing Well: C05-26 7 518" 23.7#39# L80 TXP Casin Date: 1012612019 ConocoPhillips Alaska, Inc - Rig: Doyon 25 Depth Jt Number Joints Hall Well Equipment Description and Comments Page 1 Length Tops Rpm RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 36.87 FMC 7.625" fluted hanger .72 36.87 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.33 37.59 7-5/8" 29.7#, L80, H563 box x TXP pin XO XON 40.53 39.92 its 318 to 374 57 its 7-5/8", 29.7#, L-80 TXP Casing 2269.62 80.45 XO Joint, 7-5/8", 29.7#, TXP Box x RYS110 Eagle Pin XO#2 19.85 2350.07 its 305 to 317 13 its 7-5/8", 29.7#, RYS110 Eagle Casing 539.36 2369.92 XO Joint, 7-5/8", 29.7#, RYS110 Eagle Box x TXP Pin XO#1 20.75 2909.28 its 121 to 304 184 its 7-5/8", 29-7#, L-80 TXP Casing 7359.48 2930.03 its 27 to 120 94 its 7-5/8", 39#, L-80 TXP Casing 3895.65 10289.51 its 26 to 26 1 its 7-5/8", 39#, L-80 TXP Casing with RA Tag in Coupling 41.35 14185.16 its 23 to 25 3 its its 21 to 22 2 its its 4 to 20 17 its 7-5/8", 39#, L-80 TXP Casing 7-5/8", 39#, L-80 TXP Casing 127.74 84.76 711.93 14226.51 14354.25 14439.01 its 3 to 3 1 its 7-5/8", 39#, L-80 TXP Casing, Bakerlock Jt 42.29 15150.94 7-518" HES Float Collar 1.20 15193.23 its 1 to 2 2 its 7-5/8", 39#, L80, TXP Casing, Bakerlock Jt 85.03 15194.43 7-5/8" HES Composite Concentric Phenolic Nose shoe 2.20 15279.46 15281.66 15281.66 15281.66 15281.66 11" Under reamed hole 15,173.57' MD 15281.66 Intermediate TD 9-7/8'1 15,294.5T MD 17,718.W TVD 15281.66 7-5/8" Shoe Q 15,281.66' MD 17,716-99' TVD 15281.66 15281.66 15281.66 15281.66 15281.66 15281.66 Total 87 Centeks 15281.66 Total 26 To co Bow springs 15281.66 15281.66 15281.66 15281.66 Remarks: Bakerlock to pin of it #4 Up Wt 425 K M/U Trq TXP 39#_26.1 k ft/lbs w/Run-N-Seal Pipe Dope Dn WI 152 K M/U Trq TXP 29.7#_21.3 k ft/lbs w/Run-N-Seal Pipe Dope BkK* VA 43K M/U Trq Hyd 563_ 10.3 k ft/Ibs w/Seal Guard Pipe ECF Dope, M/U Trq Eagle 20 k ft/Ibs w/Seal Guard Pipe Dope Rig Supervisors: R. Reinhardt/P. Castro r Cement Detail Report CD5-26 w ♦' String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 10/912019 06:00 Cement Details DescriptionCementIng Start Date Cementing End Dale Wellbore Name Intermediate Casing Cement 10/26/2019 05:19 10/26/2019 08:00 CD5-26 Comment No losses during cementing. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Elm Plug? Intermediate Casing The greater of 500'MD or 12,850.0 d 15,294.6 No 0.0 Yes Yes Cement 250'TVD of cement Q Pump Inst (bbllm... IQ Pump Final (bbl/... IQ Pump Avg (bbl/... P Pump Final (psi) VP lug Bump (ps0 Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 12 8 380.0 900.0Yes I 2000. No I Tagged Depth (ftKB) lag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment PJSM. Blowed down top drive. RlU cement and bleeder hose. Pressure tested lines to 4,000 psi. Pumped 64 We of 13 ppg mud push at 4 bpm ( Pressure = 100-280 psi, F/O = 17%). Batch mixed cement. Dropped bottom plug. Pumped 214 bible of 15.8 ppg tail cement ( Pressure = 320 psi, F/O = 16%). Dropped top plug. Pumped 20 bbls water. Displaced 663 bbls (6,580 strokes, FCP = 360 psi, F/0 = 8%) w/ rig pumps to bump the plug and pressure up to 900 psi (for 5 minutes). B/0 and checked floats. Cement was in place at 0810hr. Cement Fluids &Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB)Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 12,850.0 15,294.0 1,036 G 214.1 Yield (ft'/sack) Mix H2O Ratio (gal/se... Free Water (%) Density Qb/gaq Plastic Viscosity (eP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.06 15.80 160.3 6.16 Additives Additive Typo Concentration 11-00 Unit label Page 1/1 Report Printed: 3/4/2020 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD6-26 I Rig: Doyon 25 10/29/2019 Volume Input Volume/Stroke 0.100713bls/Strk Pump Rate: 0.50 Bbl/min _[Date: Drilling Supervisor: R. Reinhardt, P. Castro Pump used: #1MudPurnp . . . . .. . .. .... . ... .. Type of Test: Casing Shoe Test LOT/FIT 1W Pumping down 0- . annulus and DP. 'W strokes 'W Casing Test Pressure III tegrity Test Hole Size: USE PICK LIST IV RKB-CNF:j 36.7 1 Ft Casing Shoe Depth A Hole Depth 15310.0 Ft -MD 7719.0 Ft -TVD Pumping Strks p si Shut-in Min f psi Pumping Strks psi Shut-in Min psi Casing Size and Description: .7-5/8" 29.7#/Ft L-80 BTC -MOD IVT 0 0 013600 0 0 0.00 950 Casina est PressurelnteciritvTest 4 90 1 3600 2 75 025 940 Mud Weight: 10.6 ppg Mud Weight: 10.2 ppg 1110 : Mud in Gel� 6.0 Lb/100 Ft2 Mud 10 min Gel: 6.0 Lb/100 Ft2 Test Pressure: 3500.0 psi Rotating Weight: Lbs Rotating Weight: Lbs Blocks/Top Drive Weight: 43000.0 Lbs 43000.0 Blocks/Top Drive Weight: ALbs Desired PIT EMW: 12.5 ppg Estimates for Test: 8.4 bbis Estimates for Test: -923 psi 2.2 bbis EMW = Leak -off Pressure + Mud Weight = 950 PIT 15 Second 0.062 x TVD 0.052 x 7711 10.2 Shut-in Pressure, psi EMW at 15281.66 Ft -MD (7717 Ft -TVD) = 12.6 ppg 940 8 270 -2 _36_00_ -3 --55-751 4 160 0.50 925 12 510 6 250 1.00 925 16 750. 4 35751 8 320 1.50 925 20 975 5 35751 -10-400 2.00 925 24 1100 6 35751 121 4751 2.50 925 28 1300 32 1500 36 1650 7 35751 8 3550 9 35501 141 5601 16 6501 18 725 3.00 925 3.50 910 4.00 910 40 1800 10 3550 20 800 4.50 910 44 2000 16 3550 22 875 5.00 910 4000 Lost 50 psi during test, hplri CIA CO/ Af t.�t 48 2200 20 3550 24 950 5.50 9101 521 24001 25 3550 6.00 910 3500 56 26001 301 3550 6.50 910 or 60 28001 7.00 910 300064 3000 68 3200 7.50 910 1 8.00 910 _OS�u Lu 2500 72 3400 8.50 910 OPT 76 3600 - 9.00 910 9.50 910 10.00 2000 in W 910 - a 1500 1000 500 0 1 2 3 4 5 5 7 a Barrels r CASING TEST IIIIIIIIIIIIIII-EAK-OFF TEST s 0 5 10 15 20 25 30 Shut-in time, Minutes 0 PITPolnt Volume Pum Bled Back Volume Pum ed Volume Bled Back .7p;A IS 7.51 Bbis 2.4 A )Is s Comments: CD5-26 Intermediate Casina-FlT.xlsx Summary PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD5-26 Rig: Doyon 25 Date: 10/27/2019 Volume In ut Pump Rate: Drilling Supervisor: R. Reinhardt Pump used: i Other See Comments --_--------- ---- ---- - ._.. __ Type of Test: Annulus Leak Off Test for Disposal Adequacy 1WPumping down annulus. WCasing Barrels Bbls/Strk 'WW 0.50 Bbl/min � Test Pressure Integrity Test Hole Size: RKB-CHF: 11.' S+ 39.3 Ft CasingShoe Depth 2240.0 Ft-MD 2179.0 Ft-TVD Hole Depth 12850.0 Ft-MD 1.1111.0 Ft-TVD Pumping Bbls I psi Shut-in Min psi Pumping Bbls psi Shut-in Min psi Casing Size and Description: .10-3/41145.5#/Ft L-Bo BTC % 0 0 0 0.00 368 Chan es for Annular Adequacy Test Pressure Int earitvTest 1 0.5 31 0.25 340 Enter outer casing shoe test results in comments Casing description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. Mud Weight: 10.6 ppg Inner casing OD: 7.6 In. Desired PIT EMW: q18.9ppg Estimates for Test 940 psi 2.5 bbls - -- .. -- -._. _....... 2 1 60 0.50 331 3 1.5 75 1.00 324 4 2 100 1.50 318 5 2.5 135 2.00 315 6 1 3 169 2.50 310 7 3.5 200 3.00 305 8 4 231 3.50 302 EMW = Leak-off Pressure + Mud Weight = 552 + 10.6 0.052 x TVD 0.052 x 2179 EMW at 2240 Ft-MD (2179 Ft-TVD) = 15.5 PIT 15 Second Shut-in Pressure, psi 9 4.5 260 4.00 300 10 -5-286 4.50 298 340 15 5.5 315 5.00 292 1000 Lu t=n 500 Lu o. 0 0 5 Shut-In o 20 6 345 5.50 289 25 6.5 370 6.00 285 30 7 396 6.50 283 7.51 4251 7.00 282 81 4501 7.50 280 8.5 476 8.00 280 9 500 8.50 279 9.5 526 9.00 278 10 552 9.50 278 10.5 550 10.00 278 11 453 11.5 383 12 368 0 2 4 �CASINGTEST Barrels 6 B iD 12 BLEAK-OFF TEST 14 10 PITPointPUm 15 time, 2D Minutes 25 30 Volume ed Volume Bled Back Volume Pum ed Volume Bled Back 5 5 5 S Comments: Surface FIT 18.9 ppg EMW Used ball mill inj pump #1 Followed with 300 bbls water flush and 71 bbls diesel freeze protect D5-26 AD LOT 10-27-19.xlsx Summary Operations Summary (with Timelog Depths) CD5-26 Y Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Sian Depth StartTme End Tme Dur(hd Phase Op Coda Asivay Cod. Tme P -T -X Operation (ftKB) End Dart (WS) 10/23/2019 10/23/2019 1.00 INTRMI CASING BOPE P Slowed down top drive and hole Hill 0.0 0.0. 19.30 220:30 line. Pumped out BOP stack and retrieved 10" Wear ring, Built 7 5/8" test joint and installed upper test plug. 10/23/2018 10/23/2019 1.00 INTRMI CASING ROPE P Closed blind rams and bled down 00 0.0. 20:30 21:30 Koomey. C/O upper VBRs for 7.625" straight body rams. Energized Koomey. 1023/2019 10/23/2019 1.75 INTRMI CASING BOPE P Rigged up to test Annular and UPRon 00 0.0 21:30 23.15 7.625" test joint. Tested annular to 250 psi/2500 psi (Passed). Tested UPR to 250 psi/3500 psi (Passed). Rigged down testing equipmen. Blow down. Broke down 7.625" test joint. Cleaned and cleared rig floor. 1023/2019 10/24/2019 0.75 INTRMI CASING SLPC P Hung the block and rigged up to slip 00 0.0 23:15 0000 and cut drill line. 10/242019 1024/2019 1.25 INTRMI CASING SLPC P Slipped and cut 110' of drill line. 00 0.0 00:00 01:15 Unhung blocks. Calibrated AmphionTratco, Checked Crown-c- matic. Cleared and cleaned up tools. 10/24/2019 10/24/2019 1.25 INTRMI CASING RURD P R/U casing running equipment. 0.0 0.0 01:15 02:30 Torqued Volant to Top Drive to 37 kftibs. 10/24/2019 10/24/2019 3.50 INTRMI CASING PUTS P P/U 7 5/8" 39 ppf TXP from surface to 0.0 922.0 0230 0600 922' MD. M/U, Baker locked, and torqued shoe track to 26.1 klbs. Checked floats. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 67 klbs, and SID Wt = 72 klbs at 850' MD. 10/2412019 10/24/2019 6.00 INTRMI CASING PUTS P RIH w/ 7 5/8" 39 ppf TXP casing from 922.0 3,340.0 06:00 1200 922' MD to 3,340' MD. MUT = 26.1 kftibs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 134 klbs, and S/O Wt = 133 kibs. 1024/2019 10/24/2019 3.25 INTRMI CASING PUTS P RIH w/7 5/8" 39 ppf TXP casing from 3,340.0 4,992.0 1200 15:15 3,340' MD to 4,992' MD. MUT = 26.1 kftibs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 170 klbs, and SIO Wt = 140 klbs. 10/24/2019 1024/2019 0.50 INTRMI CASING RURD P PJSM. Changed out cup and stabbing 4,992.0 4,9920 15:15 15:45 head on CRT. 1024/2019 10242019 1.75 INTRMI CASING PUTS P RIH wl7 5/8" 39 ppf TXP casing from 4,992.0 5,7840 15:45 17:30 4,992' MD to 5,784' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. PIU Wt = 184 klbs, and SIO Wt = 136 klbs. 1024/2019 10/24/2019 0.50 INTRMI CASING CIRC P CBU. Staging up to 6 bpm. SPP =316 5,784.0 5,7840 17:30 18:00 psi. Initial loss rate was 40 bph. 1024/2019 j1012&2019 j 1.00 INTRMI CASING CIRC P Continued circulating at 6 bpm. w/ ICP 5,784.0 5,784.0 18.00 1900 = 385 psi and FCP = 320 psi. Pumped 5,800 strokes. Pumped until mud was 10.9 ppg in and out. P/U Wt = 176 klbs, and SIO Wt = 138 klbs. Page 16151 ReportPrinted: 3/4/2020 ,. Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) Phase Op Cade Ad9fty Cade Time P -T -X Operatcm Start Depth (ftKB) End Depth (MB) 10/24/2019 10!25/2019 5.00 INTRMI CASING PUTB P RIH w/ 7 5/8" 39 ppf TXP casing from 5,784.0' 8;300.0 i 9:00 0000 5,784'.MD to 8,300'MD. MUT =21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 246 klbs, and S/O Wt = 140 klbs @ 8,000' MD. 10/25/2019 10/25/2019 2.25 INTRMI CASING PUTS P RIH w/7518" 29.7 ppf TXP casing 8,300.0 9,100.0 0000 02.15 from 8,300' MD to 9,100' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. Initial Breakover Wt= 265 klbs, PIU Wt = 255 klbs, and S/O Wt = 138 klbs. 10/25/2019 10/25/2019 2.25 INTRMI CASING CIRC P Circulated at 9, 100'MD. Slowly 9,100.0 9,100.0 02.15 04.30 staging up to 6 bpm w/ICP =440 psi and FCP = 330 psi (11.3 ppg return mud). Total strokes = 6,200 psi. P/U Wt = 252 klbs, and S/O Wt = 142 klbs. 10/25/2019 10/25/2019 1.50 INTRMI CASING PUTS P RIH w/75/8" 29.7 ppf TXP casing 9,100.0 10,100.0 04:30 0600 from 9,100' MD to 10,100' MD. MUT= 21.3 kftlbs. Filled pipe on the fly using ' the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. S/O Wt = 138 klbs. 10/25/2019 10/25/2019 4.75 INTRMI CASING PUTB P RIH w/75/8" 29.7 ppf TXP rasing 10,100.0 12,351.0 06:00 10:45 from 10,100' MD to 12,351' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 310 klbs, and S/O Wt= 148 kilos. 10/25/2019 10125/2019 0.75 INTRMI CASING PUTB P RIH w/ 7 5/8" 29.7 ppf TXP casing 12,351.0 12,621.0 10:45 11:30 from 12,351' MD to 12,621' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. PIU Wt = 310 klbs, and S/O Wt= 148 klbs. 10/25/2019 10/25/2019 3.00 INTRMI CASING CIRC P CBU at 12,621' MD. Reciprocated 12,621.0 12,621.0 11:30 1430 pipe between 12,621' MD and 12,581' MD, Staged up to 6 bpm w/ ICP = 349 psi and FCP = 307 psi (11.0 ppg return mud). P/U Wt = 300 klbs, and S/O Wt= 168 klbs. 10/25/2019 10/25/2019 1.00 INTRMI CASING PUT@ P RIH w/ 7 5/8" 29.7 ppf Eagle casing 12,621.0 12,931.0 14:30 15.30 from 12,621' MD to 12,931' MD. MUT = 20.0 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 316 klbs, and SIO Wt = 160 klbs. 10/25/2019 10/25/2019 2.50 INTRMI CASING PUTB P RIHw/75/8" X -O to TXPcasing 12,931.0 14,135.0 15:30 18.00 from 12,931' MD to 14,135' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 425 klbs, and S/0 Wt = 152 klbs. Page 17/51 Report Printed: 3/4/2020 .. Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log stere Depth Start Time End Trne our (hr) Phase Op Cade Activity code Mme RT -X Operation (ftKB) End Depth(RKa) 10/25/2019 10/2512019 3,00 INTRMI CASING PUTB P RIH w/ 7 5/8" 29.7 ppf TXP casing 14,135. 15,161.0 18:00 21:00 from 14,135' MD to 15,161' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. S/O Wt = 117 klbs. 10/25/2019 10/25/2019 1.50 INTRMI CASING CIRC P Staged up pumps to 6 bpm. SPP - 15,161.0 15,161.0 21:00 22:30 430 psi, F/0 = 22%, and Total strokes = 3,300 10/25/2019 10/25/2019 0.50 INTRMI CASING HOSO P M/U hanger and landing joint. Landed 15,161.0 15,281.0 22:30 2300 hanger at 15,281' MD. 10/25/2019 10/26/2019 1.00 INTRMI CEMENT CIRC P Reciprocated pipe f/ 15,280' MD to 15,281.0 15,281.0 23:00 00:00 15,260' MD. Circulated to thin mud down to 10.6 ppg, 6 bpm, F/O = 22%, SPP = 430 psi, Attained PIU Wt = 370 klbs once hole cleaned up. S/0 Wt = 126 klbs. Total strokes = 7,800 psi. 10/26/2019 10/26/2019 4.50 INTRMI CEMENT CIRC P Reciprocated pipe from 15,281' MD to 15,281.0 15,281.0 00:00 04:30 15,260' MD while circulating and thing down the MW to 10.6 ppg. Staged pumps up to 8 bpm. F/0 = 23%, SPP = 595 psi, P/U Wt = 370 Mica, S/0 Wt = 126 kibs, Total strokes = 25,600. 10/26/2019 10/26/2019 4.00 INTRMI CEMENT CMNT P PJSM. Blowed down top drive. R/U 15,281.0 15.281.0 04:30 08:30 cement and bleeder hose. Pressure tested lines to 4,000 psi. Pumped 64 bbls of 13 ppg mud push at 4 bpm ( Pressure = 100-280 psi, FIC, = 17%). Batch mixed cement. Dropped bottom plug. Pumped 214 bbls of 15.8 ppg tail cement ( Pressure = 320 psi, F/0 = 16%). Dropped top plug. Pumped 20 bbls water. Displaced 663 bbls (6,580 strokes, FCP = 360 psi, F/0 = 8%) w/ dg pumps to bump the plug and pressure up to 900 psi (for 5 minutes). BIO and checked floats. Cement was in place at 0810hr. 10/26/2019 10/26/2019 2.00 INTRMI CEMENT W WSP P Set and tested 7 5/8" pack off to 5,000 15,281.0 15,281.0 08:30 10:30 psi. 10/26/2019 10/26/2019 1.50 INTRMI CEMENT GLEN P Cleaned and Geared rig floor of non- 15,281.0 15,281.0 10:30 12:00 essential tools. 10/26/2019 10/26/2019 2.75 INTRMI CEMENT BOPE P R/U to drill 6 1/2" production hole. C/O 0.0 0.0 12:00 14:45 saver sub, and pipe rams to 2 7/8" x 5 1/2" VBR's. 10/2612019 10/16/2019 2.00 INTRMI DRILLOUT BHAH P PJSM. P/U BHA#3 from surface to 0.0 350.0 14:45 1645 350' MD. P/U Wt = 47 klbs, and S/O Wt = 55 klbs. Monitored returns on pit #7. 10/26/2019 10/26/1019 2.75 INTRMI DRILLOUT PULD P RIH while picking up 4" XT39 drill pipe 350.0 2,2300 16.45 1930. from 350' MD to 2,230' MD. P/U Wt = 80 kips, and SIO Wt = 81 kilos. Monitored returns on pit V. 10/26/2019 10/26/2019 1.00 INTRMI DRILLOUT DHEO P Filled pipe. Performed MWD shallow 2,230.0 2,230.0 1930 2030 hole test GPM = 230 gpm and F/O = 15%. 10/26/2019 10/26/2019 3.00 INTRMI DRILLOUT PULD P Continued to RIH while picking up 4" 2,230.0 4,880.0 20:30 23:30 XT39 drill pipe from 2,230' MD to 4,880' MD. P/U Wt= 90 klbs, and SIO Wt = 91 klbs. Monitored returns on pit #7. Filled pipe every 20 stands. 10/26/2019 10/27/2019 0.50 INTRMI DRILLOUT SVRG P Serviced top drive, blocks, and crown. 4,880.0 4,880.0 23:30 10000 Page 18151 Report Printed: 3/4/2020 SURFACE CASING SHOE SEPARATION FROM CD5-26 CD5-26 x v Surface Casing Shoe ASP 4 Coordinates NAD 27: 349145.50 5965433.32 Details @ AOGCC Ann. Disp. Permit# Source Permit Date well Ann. Vol. ** Start Date End Date Distance from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Coord. Surface Surf LOT casing TVD (ppg) (ft) Annular LOT (ppg) Annular LOT Repeat (ppg) Comments "' j5-31 Y 429 349546.80 5965282.4D 14.8 Y 729 349856.86 5965593.81 14.8 2231 16.4 Y 411 349555.10 5965396.25 17.3 2155 19.2 16.0 Not a candidate- Surface Water Y 1055 349773.14 5966281.77 15.9 2165 16.3 Y 265 349296.66 5965215.35 17.7 2159 16.10 14.20 CD5-03 315-762 C05-10, C05-07, CD5-12, CD5-08, CD5-01, CD5-17, CD5-314X, CDS 10112/2017 316, CD5-22 54762.00 1/15/2016 12/15/2017 1304 349510.01 5966685.74 17.2 2156 14.80 Permit extension to 70,000 Date Extension to 10/12/18 CDSD9 1221 349249.13 5966650.27 18.0 2168 16.00 14.80 CD5-11 317-597 CDS02, CD5 06, -114/2018 C135-99 21859.70 4/1/2016 12/30/2017 839 349653.70 5966100.56 18.1 2169 16.30 Permit extension to 70,000 CD5-iD 797 349847.99 5965809,89 15.2 2147 14.30 CD5-07 NY 938 349846.29 5966056.85 18.0 2190 16.80 CDSD1 1350 350044.74 5966440.02 16.0 2178 17.70 Not a candidate CDS02 1341 349730.00 5966640.00 17.0 2189 16.60 Not a candidate CD&21 850 348681.27 5966144.79 18.0 2378 Not a candidate, No Int Casing CD5-08 848 349469.91 5966216.96 18.0 2187 14.10 CDS12 31 e-381 encs ivied] CD5-20 1201250 12/1/2016 12/3/2017 890 349560.D0 5966220.97 18.0 2187 14.80 Permitted CD5-06 1079 349534.51 5966440.23 18.0 2190 13.60 CD5-99 Y 824 349969,59 5965450.67 18.0 2182 15.10 CD5-18 Y 318-022 2/15/2018 In ectivity Test 5.25 2/21/2018 212112018 500 349542.44 5965128.75 18.0 2167 16.20 Permitted CD5-20 Y 1056 348934.93 5966467.80 17.5 2183 14.40 CD5-17 Y 406 349477.00 5965667.00 18.0 2181 15.70 Not a candidate(poor in' test) CD5-314X Y 199 349111.00 5965237.00 18.1 2183 16,70 CD5-316 Y 327 348858.83 5965276.22 16.0 2175 CDS-19 Y 165 349286.33 5965347.25 18.0 2187 15.20 Not a candidate IpW inj tail) CDS22 Y 645 349068.04 5966073.91 18.1 2184 16.40 CD5.23 Y 685 348993.55 5966101.39 15.3 2178 15.30 Not a candidate CDS-25 V 174 349091.35 5965598.79 18.3 2182 15.10 Not a candidate(poor in test CD524 Y 319-145 412212019 CD5-98 75 349220.83 5965438.04 18,0 2175 M00 Permitted but locked u CD5-9B Y 319-441 CD5-24, CD5-26, 10/1/2019 CD5-96 29129.75 6/24/2019 12/27/2D19 880 349262.87 5966305.01 18.5 2177 15.20 Permittetl CD5-92 Y 319-501 11122/2018 917 349529.38 5966266.07 18.6 2189 14.60 Permitted CD5-26 Y 01 349145.501 5965433.32 18.9 2179 15.50 CD596 , Y 862 349842.83 fdiw 6,54 15.8 2205 12.60 CD5-90wp06.1 N 1 11261 349933.211 5965183.66 ' Lateral distance in feet, between surface casing shoes, in the X -Y plane Note ihai this sheet is not the definitive record for annular disposal volumes Last lJpdata 3/4/2020 All wells highlighed In blue are within a quater mile 1320 CD5-26 Surface Injection Pressures with gauge at disposal wellhead and using annulus friction of 50 MW Injection Pressure (psi) MW Injection Pressure (psi) MW Injection Pressure (psi) 6.8 15421 8.8 19195 10.8 968 6.9 1,410 8.9 13183 10.9 957 7.0 15398 9.0 15172 11.0 945 7.1 13387 9.1 11161 11.1 934 7.2 13376 9.2 15149 11.2 923 7.3 11364 9.3 15138 11.3 911 7.4 15353 9.4 13127 11.4 900 7.5 1,342 9.5 1,115 11.5 889 7.6 1,330 9.6 19104 11.6 877 7.7 15319 9.7 19093 11.7 866 7.8 15308 9.8 15081 11.8 855 7.9 13297 9.9 1,070 11.9 843 8.0 11285 10.0 15059 12.0 832 8.1 19274 10.1 15047 12.1 821 8.2 15263 10.2 19036 12.2 809 8.3 19251 10.3 19025 12.3 798 8.4 1,240 10.4 19013 12.4 _ 787 8.5 1,229 10.5 15002 12.5 775 8.6 15217 10.6 991 12.6 764 8.7 1,206 10.7 979 12.7 753 Tom and Shannon, You have requested to dispose of "new -product" clean up fluids from the routine miring of mud and cement at Alpine as well as the clean up fluids resulting from cleaning out the tanks at the mud plant in preparation for using oil base mud, The Commission had previously approved disposing of the 'new product' clean up fluids via annular disposal at CD 1 pad. Due to the geological setting at Alpine, Class 1 and Class 2 disposal options are limited. Phillips' predecessor, ARCO, had established the limitation of disposal options to the Cotmnission's satisfaction and annular disposal was approved as the practicaland environmental alternative. In these requests the waste fluids are no diff.erert than previously approved and are the result of the ongoing development activities at Alpine. The Commissioners have authorized me to send you this message. By copy of this email, Phillips is authorized to dispose of clean up fluids as described in your email. Please call with any questions. ,rom Maunder, PE Sr. Petroleum Engineer AOGCC ALP Env Coord wrote: > Dear Mr. Maunder, > As noted in the attached email, -Com Manson previously requested > authorization to dispose of neer-product clean up fluids such as cement > rinsate, and mud and brine pit rinses from mixing operations via annular > injection in permitted wells at the Alpine CD2 Drill Site. As noted below, > AOGCC approved such disposal at the CD1 Drill Site in 1999,.based on the > integral relationship of the mud mixing facility andthe on-site drilling > operation. > > Phillips would like to continuing pursuing this request. Significant clean > out of tanks at the mud mixing facility must occur in preparation for the > temporary use of oil based mud products at Alpine in the coming months. > The availability of annular disposal as an option for tank rinse fluids and > similar wastes would greatly facilitate this process. (TYliically, routine > rinses are beneficially reused, however, there is a concern about the > potential quantity of fluid that could be generated during this large scale > clean up process.) > > Tanks ac. the mud mixing facility may contain either new and used mud > products. Though rinses in contact with used products may be injected in > the permitted class II disposal well (CD19A), rinses of new products would > potentially be routed to the class i disposal well (WD -02), where there is > a difficulty managing solids content. The class I well is a critical > lifeline for facility infrastructure, being the disposal. location for all > domestic effluent, and it is a priority to prevent any compromise to this > disposal facility. Annular disposal. presents a preferred waste management > alternative in this case. > Thank you very much for your consideration of this request. Please do not > hesitate to contact me or my alternate via email or phone at (907) 670-4200 > if you have questions or need additional. information. > Shannon Donnelly > Alpine Field Environmental Coordinator > (907) 570-4200 ---- Forwarded by ALP Env Coors./PPCO on 11/02/01 '_2:59 I'M ----- > ALP Env Coord > 08/31/01 12:45 PM > To: to;a_maundere.admin_state.ak.us > cc: Subject: Request to inject Cement Rinsato at CD2 > Dear tor. Maunder, > Injection of cement rinsate and clean-up fluids from mud and brine mixing > operations at the Alpine mud plant facility into approved annular disposal > operations was granted by the Alaska Oil And Gas Conservation Coillmission > (AOGCC) in the March 17, 1999 letter from AOGCC to Doug Chester of ARCO > Alaska, Inc., now Phillips Alaska, Inc. (PAI)- The approval was granted to > PAI speci-fi.cally for Alpine Drill Site CDl and authorized volumes up to > 35,000 barrels through the annular space. > PAT_ request that this approval be extended I..-, I!i.ng operaticol- n- 'Iri:� > Drill Site CD2. Cement mixing operations .'r;r :t- nq ;surface c.unductou, > will he taking place at. the Grind and Inject :.t;: i. l.'.'p ahllch is curs r ,i I; > attached to the drilling rig at CD2. Upon e:om:-)I,-.,.nr. of the cement.-:.ig -..r. > of the conductors, the Lines and mixing tank v:ill. 'iave to be rinsed and the > rinsate disposed of. PAI request approval to injcact this rinsate, and > other clean-up from the mud and brinemixing operations, into the annual > space of approved wells located at Drill Site CD2. > If you have any questions please contact me at 670-4200. > > Tom Manson > Al Field Environmental Compliance tom_maundermci ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 4, 2020 Alaska Oil and Gas Conservation Commission 333 West 76' Avenue, Suite 100 Anchorage, Alaska 99501-3539 ConocoPhillips Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD5-26 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD5-26 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD5-26 approximately April 1, 2020 or earlier depending on permit approval status. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Plan View of Adjacent Wells 4. Surface Casing Description 5. Surface Casing Cementing Report & Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 7. Intermediate Casing Description 8. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 9. Formation LOT on 10-3/4" x 7-5/8" casing annulus 10. List of wells on CD5 pad and the lateral distance from the surface casing shoe 11. Information regarding wells within '/4 mile radius at AOGCC: CD5-03, CD5-04, CD5-05, CDS-06, CD5-07, CD5-08, CD5-09, CD5-10, CDS-11, CD5-12, CD5-17, CD5-18, CD5-19, CD5-20, CD5-21, CD5-22, CD5- 23, CD5-24, CD5-25, CD5-92, CD5-96, CD5-98, CD5-313, CD5-314X, CD5-315, CD5-316 12. Copy of previous authorization (CDI and CD2) for disposal of new product clean-up fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The annular LOT (15.5 ppg) occurred at a lower equivalent mud weight than the casing shoe FIT (18.9 ppg). Therefore, we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be more than the shoe FIT. If you have any questions or require further information, please contact Tom Rawlins at 263-3787 or Chip Alvord can also be reached by calling 265-6120. Sincerely, Tom Rawlins Drilling Engineer cc: CD5-26 Well File Chip Alvord ATO -1570 Note to File CD5-26 (PTD 2191070, Sundry 320-102) Colville River Unit (Alpine Oil Pools) ConocoPhillips Alaska, Inc ConocoPhillips has made application to authorize annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD5-26). -- 10 3/4" Surface casing was cemented to surface successfully. No problems reported. No report of volume of cement circulated to surface but based on calculations this would be approximately 200 bbls. Full returns throughout. 2 stage cement job 50% excess 1740-1328 ft, 250% excess 1328 ft to surface, 50% excess 2240-1740 ft. -- On the initial Formation Integrity Test (FIT) for the surface casing shoe dated 10/15/2019, the pressure slope rises smoothly with test stopping at 1.5 bbl pumped and 1050 psi to yield the desired 18.9 ppg EMW (plan was for 18.5 ppg EMW). The pressure declined slightly from 1050 psi to 1010 psi (18.5 ppg EMW) during the 10 minute shut in period with the 1.2 bbl being bled back. The initial FIT indicates that the surface casing shoe is well cemented. -- The 7.625" casing was run and successfully cemented with a single stage with the shoe of 15310 ft. Cement is estimated at TOC 12510 ft (based on SonicScope run with a process date 11/19/2019) to TD. Cement job with full returns throughout. Annular disposal zone estimated from cemented 10.75" shoe at 2240 ft MD 2179 ft TVD to TOC estimated at 12510 ft MD. A post cement 10.75 x 7.625" annulus injectivity test LOT was performed 10/27/2019 with a calculated depth of the casing shoe of 2240 ft MD, 2179 ft TVD and an open hole to est 12510 ft MD yielding a 15.5 ppg EMW. The test showed pressure rising steadily with the sharp break over point at the 15.5 ppg EMW. --There are multiple wells currently drilled or planned to be drilled within '/ mile radius of CD5- 26 and the CPA[ application contains supporting cementing and LOT well information and mentions that well and cementing information is already on file with AOGCC. The surface shoe of CD5-24 is closest, about 75' distant. CD5-19 at 165 ft. AD is already prolific on CD5 and it is expected to continue with additional CD5 wells. CPAI is therefore constructing the CD5 wells to be compliant with AD regulations. Examination of the cementing information and LOT data did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Chris Wallace Sr. Petroleum Engineer AOGCC March 5, 2020 F:\cdwallace\Documents\Annular Disposal\200305_CD5-26 note to file.doc Note to File CRU CD5-26 (PTD 219-107) March 4, 2020 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD5-26 Request ConocoPhillips requests approval to dispose of 35,000 barrels of drilling waste in well CD5-26. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 10-3/4" surface casing shoe is set in this well at 2,240' measured depth (MD; -2,106' true vertical depth subsea]), near the base of a 700 -foot thick mudstone and siltstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of sandy siltstone and silty sandstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular injection activities will likely lie within a radius of about 100' from the wellbore. 8. Injected fluids may reach several nearby wells that have open annuli beneath their surface casing shoes. However, surface casing, good -quality surface casing cement, and thick overlying confining mudstone and siltstone layers will ensure injected waste fluids remain within the approved disposal interval. Discussion ConocoPhillips' application was reviewed along with records from CRU CD5-26 and 31 nearby wells.' The discussion that follows is based on well logs and mud logs from these wells. hidex maps are provided in Figures 1 and 2, below. The proposed annular disposal injection interval in these wells lies in the Torok and Seabee Formations within Section 18, T1 IN, R4E, Umiat Meridian, which is about 2-1/2 miles from the current exterior boundary of the Colville River Unit. The surface casing shoes of these wells mainly lie between about -2,068' (in CD5-10) and to -2,193' (in CD5-313), near the base of a 330 -foot thick interval that is dominated 1 Unless otherwise noted, all depths presented herein are expressed as negative integers, which represent feet, true vertical depth below mean sea level (mean low, low water). All thicknesses are expressed as positive integers, which represent true vertical feet. All horizontal distances are expressed as positive integers, which represent feet. ' CD5-01, CD5-02, CD5-03, CD5-04, CD5-05, C135-06, CD5-07, CD5-08, C135-09, C135-10, C135-1 1, CD5-12, CD5-17, CD548, CD5-19, C135-20, C135-21, CD5-22, C135-23, CD5-24, C135-25, C135-26, CD5-92, CD5-96, CD5-98, CD5-99, CD5-313, CD5-314, CD5-314X, CD5-315, and CD5-316. CD5-26 Annular Disposal Note to File March 4, 2020 Page 2 of 5 by mudstone and siltstone and is continuous throughout the area. This mudstone and siltstone interval will provide upper confinement for fluids disposed in the annulus of the well (see Figure 2, below). In CD5-26, the annulus open to the disposal interval extends downward from the surface casing shoe at -2,106' to the top of second -stage cement for the 7-5/8" casing string, which is estimated to be -6,880'. The portion of the open annulus that will most likely accept the injected waste is a 134 -foot thick interval containing several 1- to 10 -foot thick beds of sandy siltstone and silty sandstone that lie below the surface casing shoe between -2,236' and -2,370' (see Figure 2). The aggregate thickness of these thin, potential receptor beds is about 40'. The sandy siltstone and silty sandstone beds are separated by thin mudstone intervals. Beneath the disposal interval are several intervals of mudstone that are continuous throughout the area; they will provide lower confinement for any injected wastes. A Surface f,� Casing \ /� IL Surface Casing Shoe Locations 1 CD5-26 Open Annulus 0 NORTH 0 500 feet Figure 1. CD5-26 Index Map (The magenta -colored line depicts the path of the cross-section displayed in Figure 2.) The index map above displays trajectories for all wells drilled from the Colville River Unit CD5 Drill Site. The locations of the surface casing shoes for all well bores are illustrated using green -colored triangles. The calculated top of cement for CD5-26 production casing string lies beyond the southern border of the index map, above. Thirty one wells are currently open to these same strata within the'/ -mile radius area of review: CD5-01, CD5-02, CD5-03, CD5-04, CD5-05, CD5-06, CD5-07, CD5-08, CD5-09, CD5-10, CD5-11, CD5- 12, CD5-17, CD5-18, CD5-19, CD5-20, CD5-21, CD5-22, CD5-23, CD5-24, CD5-25, CD5-26, CD5-92, CD5-96, CD5-98, CD5-99, CD5-313, CD5-314, CD5-314X, CD5-315, and CD5-316. CD5-26 Annular Disposal Note to File March 4, 2020 Page 3 of 5 Figure 2, below, presents a west -to -east trending structural cross-section view of CD5-26 and nearby wells CD5-316 and CD5-17, which were logged to the ground surface. Resistivity measurements indicate that the base of permafrost occurs at about -1,250' in the CD5 Drill Site area, which is about 985' above the top of the top of the uncemented annulus that lies beneath the surface casing shoe. SW 2170400 354' CRU CD5-316 - 2191070 CRU CD5-26 412' 2170170 NE CRU CDS-17 [ _–o.— -2500 0–– .. L ..--' -3000 Surface £ _ -500„ . Casing AL `- `- ., Surface -500 - Cemented Surface — -"' Casing t_ to Surface Casing Cemented t� Cemented m. '- r- to Surface -1000 p f =F to Surface -1000 erma rost Base at ti -11250'--► -1500 TVDSS - "I Upper r Confining r 2000 Interval ��`.^, Surface Most Likely Casing Disposal r — Shoe 2500 Interval m - j Lower a Confining 4'1- - 3000 Intervals _ I– oon -3500 -4000 Annulus Cement top a -3,691' NDS' j \ -3500 f. 4000 Figure 2. CD5-26 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level; horizontal separation distance between wells is measured between the surface casing shoes) The shallow geologic section in the area surrounding the CD5 Drill Site contains predominantly methane gas, with minor amounts of ethane, propane, and butane. Mud logs were recorded in only two wells drilled near Drill Site CD5: CD5-313 and CD5-04. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.8 to 9.9 pounds per gallon). The shallowest -1500 -2000 [ -2500 L -3000 j \ -3500 f. 4000 Figure 2. CD5-26 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level; horizontal separation distance between wells is measured between the surface casing shoes) The shallow geologic section in the area surrounding the CD5 Drill Site contains predominantly methane gas, with minor amounts of ethane, propane, and butane. Mud logs were recorded in only two wells drilled near Drill Site CD5: CD5-313 and CD5-04. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.8 to 9.9 pounds per gallon). The shallowest CDS -26 Annular Disposal Note to File March 4, 2020 Page 4 of 5 occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mud log, equivalent to 4,000 ppm) were-1,850'and -2,000', respectively. So, the entire proposed annular disposal interval likely contains small, non-commercial amounts of methane gas. Unfortunately, oil shows are not recorded on the mud logs obtained in nearby wells CD5-313 and CD5-04, apparently due to the use of oil -base drilling mud. In ARCO's Nuiqsut 1 exploratory well, located about 1-1/2 miles to the northeast, the shallowest oil show was encountered at 3,990' MD (-3,930' TVDSS), with a second show encountered at 4,115' MD (-4,055' TVDSS). The mud logging geologists rated these shows as fair to poor in quality. These oil shows occur in thin sandstones that are encapsulated above and below by claystone and mudstone. These characteristics suggest the oil shows represent the presence of only trace to minor quantities of oil in the geologic strata that will be affected by annular disposal in CD5-26. These shows do not represent commercial quantities of oil. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Order No. 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Injected Fluid vs Affected Area Surrounding CRU CD5-26 Wellbore (Assumptlons: 30.0% porosity, 50% native fluid displacement., aggregate cylinder 40.0' high) 20D G� ' l ° 0 a 3 z V C 3 100 0 R 7 rc u U jt0 0 6,000 10,000 16,000 20,000 25,000 08000 00,000 Amount of Injected Fluid (barrels) Figure 3. CD5-26 Area Likely Affected by Annular Injection (Assuming uniform, piston -like, radial displacement of 50% of native formation fluids) The gamma ray well log curve recorded in CD5-26 indicates that an aggregate total of about 40 true vertical feet of sandy siltstone and silty sandstone are present within the likely disposal interval. Inspection of the density porosity log for correlative interv als in nearby wells suggests an average porosity of about 30% at this depth. Based on these values, the volume of rock that will receive 35,000 barrels of injected waste 102' affected radius assuming 40.0' of injealon interval aggegate thickness G� ' l Figure 3. CD5-26 Area Likely Affected by Annular Injection (Assuming uniform, piston -like, radial displacement of 50% of native formation fluids) The gamma ray well log curve recorded in CD5-26 indicates that an aggregate total of about 40 true vertical feet of sandy siltstone and silty sandstone are present within the likely disposal interval. Inspection of the density porosity log for correlative interv als in nearby wells suggests an average porosity of about 30% at this depth. Based on these values, the volume of rock that will receive 35,000 barrels of injected waste CD5-26 Annular Disposal Note to File March 4, 2020 Page 5 of 5 material lies within a radius of about 100' from the wellbore, assuming uniform, radial, piston -like displacement of half of the native formation fluids (Figure 3, above). Since the surface casing shoes of four wells (CD5-19, CD5-24, CD5-25, and CD5-314X) lies less than 200' away from the surface casing shoe of CD5-26, it is likely that injected fluids will the uncemented annuli of some of these wells. In CD5-19, surface casing was set at 2,237' MD (-2,118' TVDSS) and cemented with full returns to surface. In this instance, surface casing, surface casing cement, and thick overlying confining mudstone and siltstone layers will ensure the injected waste fluids remain within the approved disposal interval. Summary The limited volume of rock that will be affected by this proposed annular disposal program is situated beneath 1,250' of permafrost and is bounded above and below by laterally continuous confining layers of mudstone. This disposal interval lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. Although there are nearby wells with annuli that are open beneath their surface -casing shoes, surface casing, good -quality surface -casing cement, and thick overlying siltstone and mudstone confining layers will prevent injected fluids from migrating out of zone. I recommend approving the proposed annular disposal operations within CRU CD5-26 to the requested limit of 35,000 barrels. Steve Davies ySenior Petroleum Geologist DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20806-00-00Well Name/No. COLVILLE RIV UNIT CD5-26Completion Status1-OILCompletion Date12/4/2019Permit to Drill2191070Operator ConocoPhillips Alaska, Inc.MD33768TVD7943Current Status1-OIL4/16/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/Res/Sonic LogNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC12/10/201950 2252 Electronic Data Set, Filename: CPAI_CD5-26_Scope_GammaRay_RM_LWD001.las31624EDDigital DataC12/10/20192202 15294 Electronic Data Set, Filename: CPAI_CD5-26_Scope_Service_RM_LWD002.las31624EDDigital DataC12/10/201915229 26450 Electronic Data Set, Filename: CPAI_CD5-26_Scope_Service_RM_LWD003.las31624EDDigital DataC12/10/201926407 33738 Electronic Data Set, Filename: CPAI_CD5-26_Scope_Service_RM_LWD004.las31624EDDigital DataC12/10/201946 33738 Electronic Data Set, Filename: CPAI_CD5-26_Scope_Service_RM_Well Composite.las31624EDDigital DataC12/10/2019 Electronic File: CPAI_CD5-26_Scope_Gamma_Ray_LWD001_RM.dlis31624EDDigital DataC12/10/2019 Electronic File: CPAI_CD5-26_Scope_Service_LWD002_RM.dlis31624EDDigital DataC12/10/2019 Electronic File: CPAI_CD5-26_Scope_Service_LWD003_RM.dlis31624EDDigital DataC12/10/2019 Electronic File: CPAI_CD5-26_Scope_Service_LWD004_RM.dlis31624EDDigital DataC12/10/2019 Electronic File: CPAI_CD5-26_Scope_Service_Well Composite_RM.dlis31624EDDigital DataC12/10/2019 Electronic File: CPAI_CD5-26_Scope Service_RM_2MD.Pdf31624EDDigital DataC12/10/2019 Electronic File: CPAI_CD5-26_Scope Service_RM_2TVD.Pdf31624EDDigital DataC12/10/2019 Electronic File: CPAI_CD5-26_Scope Service_RM_5MD.Pdf31624EDDigital DataThursday, April 16, 2020AOGCCPage 1 of 3CPAI CD5-,_26_Scope_Service_RM_Well Composite.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20806-00-00Well Name/No. COLVILLE RIV UNIT CD5-26Completion Status1-OILCompletion Date12/4/2019Permit to Drill2191070Operator ConocoPhillips Alaska, Inc.MD33768TVD7943Current Status1-OIL4/16/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDC12/10/2019 Electronic File: CPAI_CD5-26_Scope Service_RM_5TVD.Pdf31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD27 EOW Compass Surveys [Canvas].txt31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD27 EOW Compass Surveys [Macro].txt31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD27 EOW Compass Surveys [Petrel].txt31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD27 EOW Compass Surveys [Survey].txt31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD27 EOW Compass Surveys.pdf31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD83 EOW Compass Surveys [Canvas].txt31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD83 EOW Compass Surveys [Macro].txt31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD83 EOW Compass Surveys [Petrel].txt31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD83 EOW Compass Surveys [Survey].txt31624EDDigital DataC12/10/2019 Electronic File: CD5-26 NAD83 EOW Compass Surveys.pdf31624EDDigital Data0 0 2191070 COLVILLE RIV UNIT CRU CD5-26 LOG HEADERS31624LogLog Header ScansC1/16/2020 Electronic File: CONOCOPHILLIPS NORTH SLOPE - EBUS_CD5_26_GWPC.pdf31930EDDigital Data0 0 2191070 COLVILLE RIV UNIT CRU CD5-26 LOG HEADERS31930LogLog Header ScansThursday, April 16, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20806-00-00Well Name/No. COLVILLE RIV UNIT CD5-26Completion Status1-OILCompletion Date12/4/2019Permit to Drill2191070Operator ConocoPhillips Alaska, Inc.MD33768TVD7943Current Status1-OIL4/16/2020UICNoCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date: 12/4/2019Release Date:8/15/2019Thursday, April 16, 2020AOGCCPage 3 of 3M. Guhl4/16/2020 THE srarx °'ALASIr.A GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, CD5-26 Permit to Drill Number: 219-107 Sundry Number: 320-102 Dear Mr. Alvord: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Enclosed is the approved application for the sundry approval relating to annular disposal of drilling wastes in the above -referenced well. Please�� note oral mustt any dlsposal complylnto the with the requirementssurface/production and casing annulus of a well approved forp limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, <V/-0�00- Daniel T. Seamount, Jr. Commissioners d DATED this_ day of March, 2020. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 RECEIVED MAR 4 2020 C -s 31z.31 Za AOGCC 1. Operator 3. Permit to Drill Name: 219-107 " ConocoPhillips Alaska 4, API Number: 50-103-20806-00-00 ` 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD5-26 - 6. Field: Colville River Unit- Alpine Pool ' 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD5-03, CD5-04, CD5-05, CD5-06, CD5-07, CD5-08, CD5-09, Torok and Seabee formation, shale, siltstone and sandstone - GD5-10, CD5-11, CD5-12, CD5-17, CD5-18, CD5-19, CD5-20, CD5-21, CD5-22, CD5-23, CD5-24, CD5-25, CD5-92, CD5-96, CD5-98, CD5-313, CD5-314X, C1315-315, C135-316 b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1,326' MD and 1,323' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Mabmum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2,142 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 16. Estimated start date: 1 -Apr -20 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ❑ FIT Records w/LOT Graph 0 Surf. Casing Cementing Data 0 Other ❑ previous authorization for new product cleaner fluids for CD and C132 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. e_ �� Signature: � "'� Title: Drilling Manager Printed Phone i�aTA Name: Chip Alvord Number: 265-6120 Date: 3� Commission Use Only Conditions of approval: LOT review and approval: C� G✓ form I Q r Approval Z Subsequent required: number. c-3A[J APPROVED BY Approved by: vl� COMMISSIONER THE COMMISSION Date: 3J2431/Za Form 10-403AD Rev. 612004 311plIrvs I R I T':V supmlt Ln uupimpte Annulus Disposal Transmittal Form - Well CD5-26 AOGCC Regulations, 20 AAC 25.080 1 I Designation of the well or wells to receive drilling wastes: CD5 26 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1323' TVD 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, 4 list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 114 mile. There are and all publicly recorded water wells within one mile of the JA no water wells within 1 mile. well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement -contaminated drilling mud, completion fluids, diesel, farmation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum e to be numprd is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CDl&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2,142 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated 13ressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LiJ'1IM report test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the The top of cement is 12,510' MD in the intermediate casing depth to which the inner casing is cemented. which coves the uppermost hydrocarbon bearing zone. No hyrdrocarbon bearing zones have been identified above this denth. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD5A0, CD5-28, CD527, CD5A3, CDS 31 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. Pbmtss% = PHydrostatic + PApplied - PFormation 4,429 =( 2,179 * 0.052 * MWS, )+ 1500 - ( 0.4337 * 2,179 } MW... — 34.2 ppg Pressure Calculations for Annular Disposal j I — 2,179 TVD TOC Est. cr 0' MD 0' TVI Surface Casing S tring Size 10.75 in Weight 45.5 ppf Grade L 80 (for submital with Annular Disposal Application) Vmim3.0-WIR Well CD5-26 Assumptions t burst100% 5,210 psi Date 3/3/2020 Maximum injection pressure of 1,500 psi ' Maximum density of the injection fluid is 12.0 ppg Depth of Shoe 2,179 ft Grade L 80 Pore pressure at thel0 314" casing shoe is 0.434 psi/ft psi Pcoliapsa5% FITILOT for Annulus 15.5 ppg Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft 6,953 Max Surf. Pressure 1,500 psi r' Gas Gradient Header Pressure (for wells on gas lift) 1,000 psi Pbmtss% = PHydrostatic + PApplied - PFormation 4,429 =( 2,179 * 0.052 * MWS, )+ 1500 - ( 0.4337 * 2,179 } MW... — 34.2 ppg Maximum Fluid Density avoid Collapse of 2nd Casing String PcollapseH% — Nydrostatic + Nppliea - PG.Gradieut - PHeBd. 4,072 =( 6,953 * 0.052 * MWS )+ 1,500 - ( 0.0700 * 6,953) - 1,000 y ev j I — 2,179 TVD TOC Est. cr 0' MD 0' TVI Surface Casing S tring Size 10.75 in Weight 45.5 ppf Grade L 80 2nd Casins t burst100% 5,210 psi Size 7.625 Pburst85% 4,429 psi ' Weight 29.7 ppf Depth of Shoe 2,179 ft Grade L 80 FIT/LOT rQ Shoe 18.9 ppg or 2,142 psi 4,790 psi Pcoliapsa5% FITILOT for Annulus 15.5 ppg psi Top of Cement 6,953 Max Surf. Pressure 1,500 psi r' Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi TOC Est. 9 12,510' MD 6,953' TVD Header Press 1,000 Maximum Fluid Density avoid Collapse of 2nd Casing String PcollapseH% — Nydrostatic + Nppliea - PG.Gradieut - PHeBd. 4,072 =( 6,953 * 0.052 * MWS )+ 1,500 - ( 0.0700 * 6,953) - 1,000 P. allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmex avowable = ( 2,179 *.052 * 18.9 ) P.. allowable = 2,142 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". MWmax 11.2 ppg 4.5 "Tubing 2nd Casins String Size 7.625 in 7,717 TVD Weight 29.7 ppf Grade L 80 Ycollapsel00% 4,790 psi Pcoliapsa5% 4,072 psi Top of Cement 6,953 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi P. allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT Pmex avowable = ( 2,179 *.052 * 18.9 ) P.. allowable = 2,142 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". a 0 N cel, N o D 00 .,. r 1 y O 0 N rIf 0 ,A a a � V LU �p 1 V �� y O o � a a � LO S Li co N 1 `3 V 5 ' a a N 0 a a 0 C) 0 ' C7 a a C) a N C0 CO N00 (+)gIJON/(-)ulnoS r I >� i f f I I � 6 0 I I /� 5 I / / •y c� o� o. �; D ao; • � � � ''jr sp oo I I �• 1 � 5 I I in D N sp �� t7 � U) s I '1I 'r �p N ,' Cp 5.21 v r'� o ; Y o� a 0 N cel, N o D 00 .,. r 1 y O 0 N rIf 0 ,A a a � V LU �p 1 V �� y O o � a a � LO S Li co N 1 `3 V 5 ' a a N 0 a a 0 C) 0 ' C7 a a C) a N C0 CO N00 (+)gIJON/(-)ulnoS r I >� i f f I I � 6 0 I I /� 5 I / / •y c� o� o. �; D ao; • � � � ''jr sp oo I I �• 1 � 5 I I in D N sp �� t7 � U) Onoc&hillips Alaska, lno COS -26, 1"4", Surface Casing 14-3d4°' ffi.5# L-_80 7XP-M COSin Well.' Date: Rig: C05-26 10/1312019 Doyon 25 Depth Jt Number Joints Well Equipment Description and Comments Length Tops RKB to Top Of String or RKB to Lock Down Screws 25 RKB 39.75 FMC 10-314" Casing Hanger .13 39.75 10,314', 45.511, L-80, Casing Pup ^ H563 Pin X H563 Pin 2.40 39.88 Full length XO A 10414", 46M, L -W, BTCM Pin X H563 Box 39.89 42.28 Jts 3 to 56 54 As 10-3W, 45.5#, L-80, TXP-M Casing 2080.65 82.17 10-W,V'Topeo BTCM Float Collar 1.23 2162.82 Jts 1 to 2 2 Jts 10-W, 45.5#, L-80, TXP-M CaWng 73.39 2164.05 10314" Topep ETCH Shoe 2.73 2237.44 2240.17 2240.17 2240.17 2240.17 2240.17 2240.17 10-314" Shoe at 2,2.40- MLI) ?,179''1 2240.17 13Ar2" TD .,# 2,257M, 2.190'TVD 12' redh€ to 2240.17 2240.17 2240.17 2240.17 2240.17 2240.17 1 Centek 10' up €rorty sh w/stop kings on A 81 2240.17 1 Controk 30" ijp fi''OM rin wiqop fin . s. on A 82 2240.17 1 Contck 0' up from pin wistap rings on .it Cl 2240.17 1 Confek wnWilizer ewe inR frnm 94 to 815 Fim-Aing 2240.17 1 To . � brow -,pdng evvry A $i om 116 to 0.65 over coupling 2240.17 2240.17 2240.17 2240.17 2240.17 Total Cenlraff m 2240.17 15 'entok, SH, 10--314"x 13-10'„ FIN 1034--13125 2240.17 (40) Top -Co FIN 300-213-� 10.75" x 13-.5M" bmmprtugs 2240.17 2240.17 2240.17 t�= lila M 130 K MU Tq with Volant -H563 Doped to 16,200 ftAbs wl Seal Guard ECF, TXP-M to 27,160 Nibs wl Run N Seal Lki VA 126 K Bakerlocked to pin end of jt #4 l 43 K Drifted with 9.875" drift Rig Supervisors: K Harding / G. Madell Cement Detail Report CDs-2s String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/9/2019 06.00 Cern ent Details Description Surface Casing Cement Cementing Start Date 10/13/2019 16:00 Cementing End Date 10/13/2019 19:00 Wellbore Name CD5-26 flow w' .0 Cement Stages Stage # 1 Description Lead - Surface Casing Cement Objective Lead-Isolate surface casing annulus to surface Top Depth (ftKB) 39.3 Bottom Depth (ftKB) 1,740.0 11t6NAtE2 S r l+Lfi 4we Yee � � R YfA INC, Pipe RPM (rpm) u0saip� oftofto d. T9 Drill Out Diameter (in) t t-F iled m4bw i1ma QGGPMUr ti-M 04117, Q ft we din, 4.40& MY 111174(riv fi Vie$ Cement Fluids & Additives Fluid •kith Fluid Description dqb 41-0 Atttb� h1aFdPu1►ad „ —to— Free Water (k) fifl� maft M CmprStr 1 (psi) Additives Fluid Fluid Description � 1 - TOj 1"96110 A A*pA*Xw0-*=§N Woegyp ,p .„ Free Water (°%) tNl MAI CmprStr 1 (psi) Additives f Fluid Fluid Description 11t4) Free Water {°�) FCmprStr 1 (psi) Additives Addlt:A Stage # 2 Description Objective Tap Depth (ftKB) Tail - Surface Casing Tail-Secure the shoe and 1,740.0 Cement bottom 500ft of annulus Bottom Depth (ftKB) 2,240.2 ifs ttf¢ 1.1 iiTtls hia Plpe RPM (rpm) fto .. taFm Mw Droml • .at Drill Out Diameter (in) 50 IfiaW MaG, *4M d; Z.=64%. W0.2'* 6-11M MOM Cement Fluids & Addith" F)uid Flrlid',yp-% Fluid Description Eaeirn:fitzd'fap frhtaj iF 31'r k.-t x1i?iAe..,J31 burs Rau* (gasa_.. Free Water (%) VL01Ei1y a"l TMck*y Tww R.4 —7t r 1 (psi) CmprStH2O Additives 4d':'itiv. fyPe I �,^,twctrint:la Icontilabel i � Page 111 Report Printed: 3/4/2020 E E co 00 O Ln Ln Lo to Lq w Ln Ln w) O O O U Lf# 0 O �(? In O N O 0 N 0 NN 0 0 NNNNNTTT 0 0 0 0 0 0 0 0 Y w w - Q_ T T T T !•' T T �"' T T T T T T T 40 M E mm W V) C ONLOf]O LQ CD L LqO C5 LLgqCD 0 O L44LLO]OLRgI CD gqqU�O ; m0�1 CL _� oOO s^NNM MV'� LID In La co I,-rNOD00maiOIM m E m � d . o O O LA O OLMwo r N � Q W 0 w O a Q OOD 0~D � _ � O7 a .... -._G tlH f O N I- 00 rco Vtto m a eT- Y cn e CoO LO �jW Y wLf y M Lw co w L MM w Lw co m0 nsMM to 01 v E LO m o T N v Ln cD l-- co rn on Ln o to o m 3 a C T r N N coCDP d F m O pl 5 +� 00 o Oo 000 0 aooOo w o C wLn �fn N Ln ti Lai CN w 0 r0 0 In o 0 0 NMcOef 0 0 0 E Q Ern O (O 00O V (0000 NN cOV MON MIL M � C14N N N ; 9 8 N co N ♦ a ~o O Ln a EL_ 3 N a o w O y LLn a C T iL+ O O� w w CM L O N Q a 66 T W rn a � �0 0. Q F J �+ .� o� c S v t M �% Oo o c a° Z CO C L r a O s 0 ac'i � ate', � T T TO V0 CL c LLI eO o N w E >- o Cr-a(A CL 0 Z W N a �:3 a Ca •t3 3 •� T O L) a 0 `` T � �`� a° rL � u �� '� �� o m o x !I F T _ m O ca �° T N �, LL a TCL ca CL i4 ON J 4 O `ateQ X00 W E04 07 I Ci O T. O Q C Oi 1 .. II .N... OC5 N w LSU r tq a c o00 otn m Q 0CM w M N F U N I �• T =d+C7ml .. rr i.+ tm Z i u -� wF-� ` x 0 w ;A N 0O [Loy' �� W dim o ter- c c �' 0.00 Ha E O O ns CL G. 0LU R N o o uj g o g a a E U) I... H U CD yah ["1 N N W w to Q I m 3HnSSaNd E d - 0 Y W U E E co 4� Operations Summary (with Timelog Depths) CDS-26 t i i Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time our (hr) Phase Op Code Actlyily Cade Tune RTX Operebon (ftm End Depth MM 1011212019 10112121719 2.50 SURFAC CASING TRIP P Blow down jet line and line up hole fill. Y. 18.00 2030 POOH on elevators from 1887'- 1165'MD. Rack back 5" HWDP and jar stand. PU1SP=105k194K at 1800'. Experienced 15K overpull POOH at 25fpm. Maintain constant hole fill over the lop. Manual strap every 5 stands. 1911212019 14/12/2019 2.25 SURFAC CASING BHAH P LD Schlum BHA#1 as per DD. Broke 2030 2245 apart collar to remove stuck Gyro tool. Found tool lower than planned as it passed thru UBHO. Broke apart BHA subs to remove Gyrodata tool from UBHO sub. LD Gyrodata tool to ground. 1011212019 1011312014 1.25 SURFAC CASING BHAH P Conitnue lay down BHA and bit. 2245 3000 10113120i9 1011312014 2.00 SURFAC CASING RURD P Clean rig floor and remove BHA subs. 0000 0200 Build DC stand from drilling configuration. PU Doyon and rig up Volant tool to run 10 314" casing. 1011312019 10!13.'2019 4.00 SURFAC CASING PUTB P Make-up 10.75", L-80 shoe trac assbly ISO 0200 0600 as per Doyon Casing rep, Bakedoking all connections. MU torque=27k ft -lbs. Checked floats, OK. Continue running 10.75", L-80, TXPM, 45.5ppf casing from surface to 845'MD. installed l centralizers as per detail. Using Volant CRT, MU torque=27k f# -lbs, PU1SO wr71 W73k at ROAftMI}, Fiilpd rasing on the fly and topped off every 10 jts. 10/13120/9 10/1312019 1.25 SURFAC CASING PUTB P Continue running 10.75", L-80, g, 06.00 0715 TXPM, 45.5ppf casing from 845- 115VIVID. installed centralizers as per detail. Using Volant CRT, MU torque=27k ft4bs,. Filled casing on the fly and tapped off every 10 jts. SO wt --80k 10113/2019 12019 2.25 SURFAC CASING PUTB P Establish circulation and pump down 0716 Gorso hole while running in from 1151' to 1496'MD. Using Volant CRT, pump rate=2 bpm, 150psi, FO=80%. Total strokes pumped=9389stks (939bbls). SO wt --80K 10/1312019 1011312019 0.50 SURFAC CASING CIRC P CHU below permafrost and stage up 0930 1000 pumps to 7bpm.from 1496' to 1596'MD. Pumped 1441stks, 7bpm, 197psi, 56% FO, SO wt --78K. 1011312419 10/1312019 2.00 SURFAC CASING PUTB P Continue running 10.75", L-80, 1000 1200 TXPM, 45.5ppf casing from 1536'- 2085'MD. installed centralizers as per detail. Using Volant CRT, MU torque=27k ft -lbs,. Filled rasing on the fly and topped off every 10 jts. SO wt --80k Losses for tour=18bbis. 10113/2019 10/13/2019 1.00 SURFAC CASING PUTB P Continue running 10.75", L-80, 1200 1300 TXPM, 45.5ppf casing from 2085- 2240'MD. installed centralizers as per detail. Using Volant CRT, MU torque=27k ft -lbs,. Filled rasing on the fly and topped off every 10 Its. SO wt --80k. PU and MU xover joint, hanger and landing joint per FMC1DD1 reps. PU1SO wts=121 K1100K. Page 4151 Report Printed: 3/412020 Operations Summary (with Timelog Depths) CD6-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Too our (hr) Phase Op Code Activity Code TlmeP-T--X Operation (RK9) EndDepth'M") 10/1312019 10!1312019 1.75 SURFAC CEMENT CiRC P Establish circulation to condition mud , 1300 1445 for surface casing cement job while reciprocating. Staging up pump rate upmaintaining 10ppg, YP=18-25, ICP=235psi, 1.5bpm, FCP=97psi, 7bpm, FO=44% 10/1312019 10/13/2019 0.50 SURFAC CEMENT CMNT P SD, rig up cement line to Volant 1445 1$ 15 swivel, 1071312619 10/13120!9 0.50 SURFAC CEMENT CIRC P Re-establish circulation thri cement 2 1615 1545 line and continue to condition mud at 7bpm while reciprocating. Held PJSM, t surfce cement job, total strokes d pumped 7116 (711 bbls). 10113/2019 V113=19 2.25 SURFAC CEMENT CMNT P Pump surface cement job as per 3 1545 loll" Schlum/CPAI detail. PU1SO wt--127K/120K 10/13/2019 10113/2019 1.00 SURFAC CEMENT CMNT P Continue to pump surface cement as 1830 19013 per Schlum detail. PU1SO wt=124K11OOK. Bumped plug [x)1849 strokes at 3bpm w/515psi over final displacement pressure to1000psi, held for 5 minutes. Total pumped 1854stks, rigged dawn cement hose and checked floats, Floats held.. 10/13/2019 10/1312019 1.00 SURFAC CEMENT WWWH P Flushed surface lines, HP riser, cycled 1900 20.00 annular and fluided past with fluid. Pumped thru injection line on lower spool with black water @ 5bpm. Continued Cleaning cement from pits, j through cuttings tank, Eddy pump. JI Cycled annular preventer and rinsed clean. 10/13/2019 1011312019 1.00 SURFAC CEMENT RURD P Rigged down casing equipment 2000 2100 Cleaned out and LD Volant tool. LD casing equipment and backed out landing joint as per FMC rep. /4113/2619 10113/2019 1.00 SURFAC CEMENT WWWH P Drained riser and cleaned out cement 2100 2200 from annular preventer, 4" conductor valves and Cellar box 10/1312019 1011412/319 2.00 SURFAC CEMENT NUND P Remove bell nipple, annular preventer , 22.00 0000 1 and high pressure riser. 10/14/2019 101-41201 q 3.25 SURFAC CEMENT NUND P ND Tee and slip lok adapter flange as 0000 0315 per FMC. Cleaned flange and layed down. Performed Halliburton Epoxy Cement Cemlok cap job as per HES j rep and procedure. SIMOPS-grease choke manifold, dean rig floor cemenmting valves,removed wellside side valves for installtion. 1 10114/2019 101141201$ 1.00 SURFAC WHDBOP NUND P Nipple up FMC Gen 5 Unihead starter Ac?a 03.15 0415 1 and tubing head sections wellhead as per FMC rep. Tested lcrwer waINead seals to 1,000psi, witnessed by CPA]. 10 9412019 10114/2019 1.75 SURFAC WHDBOP NUND P NU high pressure riser and adapter (W-15 06:00 flange. 1011412019 1011402019 5.75 SURFAC WHDBOP NUND P Contine to NU riser and flange with Zf,!0.4 --- --flCi 00 06-00 11.43 Sweeny wrench. NU ROPE, MU choke and kill lines, MU flowbox and flowline, RU MPD equipment. SIMOPS - gather elevations, RU to perform Wellworc bias testing and MPD test Page 5/51 Report Printed: 314/2020 Conm&hillsps 6,.6J 6,J6.6Jr A*1U' I!M CD5-26 7-518' kdermeaGate caain 7 +mow 2975 39# LBO TXP CWAU Well: Date: Rig: CD5-26 10126/2019 Dayan 25 Qepth Jt Number Joints Well Equipment Description and Comments Page 1 Ai Length Tops RKB to Top Of String or RKB to Lock Down Screws .. RICIN to LLDS 36.81 FMC 7.525" f" hander .72 36.87 7-5A8", 29.7#, 1-80 pup pin x pin below hanger H563 2.33 37.59 t-518"' 29.7#_. LBO, H563 box x UP pig XO XON 40.53 39.92 its 318 to 374 57 its 74V8", 2q.7#, t. -.80'1 -XP GmAnq 2269.62 80.45 XO Joint, 7-518", 29.7#, TXP Box x RYS110 Eagle Pin XO#2 19.85 2350.07 its 305 to 317 13 its 7-518", 29.7#, RYS110 Eagle Casing 539.36 2369.92 XO Joint, 7-518", 29.7#, RYS110 Eagle Box x TXP Pin XO#1 20.75 2909.28 its 121 to 304 184 its 7-51W, 29.7#, L-80 TXP Casing 7359.48 2930.03 its 27 to 120 94 its 7-5ffi", 39#, L-80 UP Casing 3895.65 10289.51 its 26 to 26 1 its 7-518", 39#, L-80 UP Casing RA Tag in Coupling 41.35 14185.16 its 23 to 25 3 .its its 21 to 22 2 its its 4 to 20 17 its 7-518", 39#, L-80 TXP Casing _ Lj- . _ y - , Ipalpo J WNa CenIra] Izefl A I a Ifft C T400 -14.376' 7-518", 39#, L-80 TXP Casing 127.74 84.76 711.93 14226.51 14354.25 14439.01 its 3 to 3 1 its 7-518", 39#, L-80 TXP Casing, Bakerlock Jt 42.29 15150.94 7-518" HES Float Collar 1.20 15193.23 its 1 to 2 2 its 7-6W, 39#, L80, TXP Casing, BalCat D& Jt 85.03 15194.43 7-518" HES Composite Concentric Phenolic Nose shoe 2.20 15279.46 15281.66 15281.66 15281.66 15281.66 11" Under reamed hole 15173.57' MD 15281.66 Intermediate TD 9-718 15,294.57 MD 17,718.35' TVD 15281.66 7-5J8" ShoeQ 15,281.66' MD 17,716.99' TVD 15281.66 15281.66 15281.66 15281.66 15281.66 15281.66 TMA 87 Contolss 15281.66 TOU1125 T ,o now s rin m 15281.66 15281.66 15281.66 15281.66 l3tic;_ Bakerlock to pin of it #4 lip Wk 42b K MIU Trq TXP 39q_26.1 k ftlibs w/Run-N-Seal Pipe Dope tin VA ilii K MIU Trq TXP 29.7# 21.3 k ftnbs wlRun-N-Seal Pipe Dope MO& Wt 4.3 K MIU Trq Hyd 563_ 10.3 k ftllbs wlSeal Guard Pipe ECF Dope, MIU Trq Eagle 20 k fUlbs wlSeal Guard Pipe Dope Rig Supervisors: R. Reinhardt / A Castro Cement Detail Report CD5-26 String; Intermediate Casing Cement Job: DRILLING ORIGINAL, 1019!2019 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 10/26/2019 05:19 10/26/2099 08:00 CAS-26 ccsnmefif Cement Stages Stage # 1 Description Objective Top Depth (rtKB) Bottom Depth (RKB) Intermediate Casing The greater of 500'MD or 12,850.0 a 1250'TVD 15,294.6 "v 0:4 Ilea Ville Cement of cement pRp p RPM (rpm) 144a4W 1061wkwifPipe itg si tp Drill Out Diameter (In) &O"d 4MM tW ftft RM 01W W#MCW h0" ftft&Xv t Was NMPW 8 tft Of 13 ppg MW PUM Rt A Wh ( PfOSSOO Cr "6-W 1W M : i"?"* ftft ftaxed MMU DPOpWbaftm g� � 244 t of 44.8' td :sa+rr * { � m . ft a 16'%6)- i %p i�20 WBili��' M3 it - fS, FM Z 41� W1 it gaps 10 ft rDW_yptanad 3. t1� N M I aft001 Cement Fluids & Additives Fluid FkKmwo Fluid Description nml 1.. . 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N w CN co to CD O f�B N '7 'o C, "D N :N rn CL 14 H tlD d C N 3 3 CD 7 Q. CD N 7 �1 C fD CD W N i ul Q N 0 oCno tio coao 1-41CA CT .PW Nio O � 0 m C7 cr ❑ w W m . C i�sOim CD V Cn P W N -� O crC = 0 NCJi iCnD!itwL"wCiti VcnCA in Cn6A 6 WCnN Cn-+CnO • {p 3 C cr Q- 0 W W ACn V+Cr�C7i AAAW W W W NNN Nii� fn A VI C100CACn[SfNO VC7�Nw VA i WOW OC)W O ]CAW N Cb W W CNCACSCAOCnQ� CCTV Cn CAO i OCoCAO Cn OiO O V............... � E 0 3 0 E m omcmwaovvrnrncn cn AAw wNN��oC3a = 3 v in o Ln 0 CA o m CD! CP o CA CD CA o in o cn O LY, Ia b : CA X CD o0000CDaC o 0 000 00000CDcno c im IM os 3 N N N N N N N N N N N N W W w W W w w W W W y V V V -4.W M M W W of cD COOO O-+�iN W AO , C7DODGDCDOON Iw (InO N GOON CnOEn co A-*OCo Operations Summary (with Timelog Depths) CDS-26 RIg: DOYON 25 Job: DRILLING ORIGINAL Time Log SUM Depth stmt T1me End Time our (ho Phase Op Code AcUvrty Code Time P -T -X operation (fIKB) End Depth (fIKB) 10/2312019 0123!2019 1.00 INTRMI CASING BOPE P Blowed down top drive and hole fill 19.30 2030 line. Pumped out HOP stack and retrieved 10" Wear ring, Built 7 518" test joint and installed upper test plug. 1012312019 1412312019 1.00 INTRMI CASING BOPE P Closed blind rams and bled down 13 2030 2130 Koomey. CIO upper VBRs for 7.625" straight body rams. Energized Koomey. 10,2312 19 10123/2019 1.75 INTRMI CASING BOPE P Rigged up to test Annular and UPR on 2130 2315 7.625" test joint Tested annular to 250 psi/2500 psi (Passed). Tested UPR to 250 psi13500 psi (Passed). Rigged down testing equipmen. Blow down. Broke down 7.625" test joint. Cleaned and Geared rig floor, i0f1312019 10124120019 0.751 INTRMI CASING SLPC P Hung the block and rigged up to slip 2315 10000 and cut drill line. 10,241 19 101-412019 1.25 INTRMI CASING SLPC P Slipped and cut 110' of drill line. 00.00 01 ' 5 Unhung blocks. Calibrated AmphionlTotco, Checked Crown -o - uratic. Cleared and Cleaned up tools. 10124/2019 10124=19 1.25 INTRMI CASING RURD P RAJ casing running equipment. 0t i5 02 30 Torqued Volant to Top Drive to 37 kftlbs. 101241201 fV24=10 3.50 INTRMI CASING PUTB P PIU 7 518" 39 ppf TXP from surface to 0230 06-10 922' MD. MN, Baker locked, and torqued shoe track to 26.1 klbs. Checked floats. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. PIU Wt = 67 klbs, and SIO Wt = 72 klbs at 850' MD. 1012412019 10/2412019 6.00 INTRMI CASING PUTB P RIH w17 518" 39 ppf TXP casing from 0600 12 Od 922' MD to 3,340' MD. MUT = 26.1 kftibs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. PIU Wt = 134 klbs, and 810 Wt = 133 klbs. 10/2412015 101241.2019 3.25 INTRMI CASING PUTB P RIH wI7 518" 39 ppf TXP casing from , 1200 1515 3,340' MD to 4,992' MD. MUT = 26.1 kftibs. Filled pipe on the fly using the Volant tool whilst topping off every 1 Oth joint. Manually strapped trip pit every 10 joints. PIU Wt = 170 klbs, and SIO Wt = 140 klbs. 1012412019 10124/2019 0.50 INTRMI CASING RURD P PJSM. Changed out cup and stabbing ,. 4, 15 15 '15.45 head on CRT. 10/24/20 t9 10/2412019 1.75 INTRMI 7EASING PUTB P RIH wl7 5181139 ppf TXP casing from 1545 1730 4,992' MD to 5,784' MD. MUT = 21,3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. PIU Wt = 184 klbs, and SIO Wt = 136 klbs. 1012412019 1(112412018 0.50 INTRMI CASING CIRC P CBU. Staging up to 6 bpm. SPP = 316 94.0. 5.781,4 17.30 18.00 psi. Initial loss rate was 49 bph. 101'2412019 10124/2019 1.00 INT'RMf— CASING CIRC P Continued Circulating at 6 bpm. w1 ICP }moi 18:00 '9 00 = 385 psi and FCP = 320 psi. Pumped 5,800 strokes. Pumped until mord was 10.9 ppg in and out PN Wt = 176 klbs, and SIO Wt = 138 lobs. Page 16151 Report Printed: 3/4/2020 Operations Summary (with Timeiog Depths) CD5-26 F Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth StartTims End Tkne Our (hrl Phase op Code Achvrty Code Time P -T -X Operation M01 End Depth (NCB} 1C12412014 1012512(119 5.00 INTRMI CASING PUTS P RIH wl 7 518" 39 ppf TXP casing from . . 1 g o0 00.00 5,784' MD to 8,300' MO. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P1U Wt = 246 klbs, and SIO Wt = 140 kibs @ 8,000' MD. 10/25120 9 1 1 2.25 INTRMI CASING PUTS P RIH w17 518" 29.7 ppf TXP casing 00-00 0211A from 8,300' MD to 9,100' MD. MUT = 21.3 kfflbs. Filled pipe on the fly using the Volant tool whilst topping off every 9 10th joint. Manually strapped trip pit every 10 joints. Initial Breakover Wt = 265 kibs, PIU Wt = 255 kibs, and SIO Wt = 138 kibs. 10125f2019 10/2512019 2.251 INTRMI CASING CIRC P17 at 9,100' MD, Slowly , 0215 0430 staging up to 6 bpm wl ICP = 440 psi and FCP = 330 psi (11.3 ppg return mud). Total strokes = 6,200 psi. PIU Wt = 252 kibs, and SIO Wt = 142 kibs. /012512019 #1i2Fi�0 1.50 1NTRM1 CASING PUTS P RIH wI 7 518" 29.7 ppf TXP casing B. GA 30 from 9,100' MD to 10,100' M D. MUT = 21.3 kfflbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. SIO Wt = 138 kibs. 10125120'19 IW&2019 4.75 INTRMI CASING PUTS P RIH w/7 518" 29.7 ppf TXP casing W ' 0600 1045 from 10,100' MD to 12,351' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every I Oth joint. Manually strapped trip pit every 10 joints. P1U Wt = 310 kibs, and S10 Wt = 148 kibs. 10/25/2019 10/2512019 0.75 INTRMI CASING PUTS P RIH w! 7 518" 29.7 ppf TXP casing TNT: r. 1045 91,30 from 12,351' MD to 12,621' MD. MUT = 21.3 kfdbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. PIU Wt = 310 kibs, and SIO Wt = 148 kibs. 1012W2019 1015 8 3.00 INTRMI P CBU at 12,621' MD. Reciprocated 1130 1430 pipe between 12,621' MD and 12,581' MD. Staged up to 6 bprn wl [CP = FCASINGCIRC 349 psi and FCP = 307 psi (11.0 ppg return mud). PfU Wt = 300 klbs, and SIO Wt = 168 kibs. 10125/2019 1012512;119 1.00 INTRMI PUTS P RIH wl 7 518" 29.7 ppf Eagle casing 14.30 1530 from 12,621' MD to 12,931' MD. MUT = 20.0 kftibs. Filled pipe on the fly using the Volant tool whilst topping off 1 every 10th joint. Manually strapped trip pit every 10 joints. PN Wt = 316 kibs, and VO Wt = 160 kibs. 10!_511- i 1[ o-Wni9 2.50 INTRMI CASING PUTS P RIH wl7 518" X -O to TXP casing 1530 18;00 from 12,931' MD to 14,135' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. PIU Wt = 425 kibs, and SIO Wt = 152 kibs. Page 171511 Report Printed: 314/2020 Operations Summary (with Timelog Depths) CD3-26 I'6-v Rig: DOYON 25 .fob: DRILLING ORIGINAL Time Log Start Depth Starffh End Time Dur(hr) Phase Op Cade AcWigr Code Time RT-X Operation (ftKB) End Depth (ftKB) I OQ512019 1012512019 3.00 INTRMI CASING PUTB P RIH w17 5029.7 ppf TXP casing WJ759.ff 11800 21.00 from 14,135' MD to 15,161' MD. MUT = 21.3 kfdbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. SIO Wt = 117 kips. 1 10/25/2019 49 1.50 INTRMI CASING CIRC P Staged up pumps to 6 bpm. SPP 2100 22'30 430 psi, FIO - 22%, and Total strokes = 3,300 owlr 10/25/2019 10/25/2019 0.50 INTRMI CASING HOSO P MIU hanger and landing joint. Landed 1W 0:1 22.30 2300 hanger at 15,281' MD. 101251201a 10126/2019 1.00 INTRMI CEMENT CIRC P Reciprocated pipe f115,280' MD to IMF 2300 00:00 15,264' MD. Circulated to thin mud down to 10.6 ppg, 6 bpm, F/O = 22%, SPP = 430 psi, Attained PIU Wt = 370 kibs once hole cleaned up. 810 Wt = 126 kibs. Total strokes = 7,800 psi. 10/26/2019 1012£12019 4.50 INTRMI CEMENT CIRC P Reciprocated pipe from 15,281' MD to 1111M 00.00 0430 15,260' MD while circulating and thing down the MW to 10.6 ppg. Staged pumps up to 8 bpm. F10 = 23%, SPP = 595 psi, PIU Wt = 370 kibs, SIO Wt = 126 kits, Total strokes = 25,600. ; a 10!2612019 T °19 4 00 INTRMI CEMENT CMNT P PJSM. Blowed down top drive. RIU 04,31 ®x:30 cement and bleeder hose. Pressure tested lines to 4,000 psi. Pumped 64 bbls of 13 ppg mud push at 4 bpm (Pressure = 100-280 psi, Flo = 17%). Batch mixed cement Dropped bottom plug. Pumped 214 bhis of 15.8 ppg tail cement (Pressure = 320 psi, F/O = 16%). Dropped fop plug. Pumped 20 bbls water. Displaced 663 bhis (6,580 strokes, FCP = 360 psi, F/0 = 8%) wl rig pumps to bump the plug and 3 pressure up to 900 psi (for 5 minutes). E110 and checked floats. } Cement was in place at 0810hr. 10f26&019 10126/2019 2.00 INTRMI CEMENT WWSP P Set and tested 7 518" pack off to 5,001 ,120161a- 08 30 1030 psi. 101'2612019 10126/2019 1.50 INTRMI CEMENT CLEN P on- Cleaned and cleared rig floor of non- 1i 1 1030 10 30 1200 essential tools. 1012612019 1012812019 2 75 INTRMI CEMENT BOPE P R1U to drill 6 112" production hole. CIO € . 12.00 14.45 saver sub, and pipe rams to 2 718" x 5 112" VBR's. 10/26/2019 1QQW019 2.00 INTRMI DRILLOUT BHAH P PJSM. P1U BHA *3 from surface to 1445 1-645 350' MD. P/U Wt = 47 klbs, and 510 Wt = 55 kibs. Monitored returns on pit #7. j 10126/2019 1012612019 2.75 INTRMI DRILLOUT PULD P RIH while picking up 4" XT39 drill pipe 1645 1930 from 350' MD to 2,230' MD. P1U Wt = 80 klbs, and S10 MR = 81 kits. Monitored returns on pit V. 1 1012612019 10126/2019 1.00 INTRMI DRILLOUT DHEQ P Filled pipe. Performed MWD shallow 1930 2030 hole test GPM = 230 gpm and FIO = 10/26/2019 10/2612019 3.00 INTRMI DRILLOUT PULD P Continued to RIH while picking up 4" 2 ZZc `-4,880 2030 23:30 XT39 drill pipe from 2,230' MD to 4,880' MD. P1U Wt = 90 k1bs, and S10 1 Wt = 91 kibs. Monitored returns on pit #7. Filled pipe every 20 stands. 10126/2019 1012712019 0.50 INTRMI DRILLOUT SVRG P Serviced top drive, blocks, and crown. 44ktQr 4.88 2330 0000 I Page 18161 Report Printed: 3/412020 rZq n n n n n nc�ooa n. n n n n g n n n .mom. Fo ud, c°l 5v" Y r�i Y' Y' Y' YO' 0 p�l' .o N W� G a V bi W m �aS -+. N V Ticel[ A . m 3 h sti � N tC 0" (� O C �n ID_rI v, a $a rr a y V N t* a Occ r A Tr a O i - C 4 a r yOj C e V Nn m x n vv 3 m no oa W n n n o �,avvv mN ID as n a a Y Y c 0 ID m A- CD N D A N o C n n T' 000 mrD m 13vo OF m a N f�h G O o O m m ao m m m N 0 0 0 � M W � J WAA p N 1 V AUg wQQf�im :a1-18ww�� W �wo.i --' �mm OA - SrV '. 666W111 66Tf>f W IUoo CO �D � �' ra W A A A '- W L n 7 c?p CD QSqW, rAp fT fAp '�, D. W W WA N - W v N $A 0N1 �W Ye ' O V tWDI po A w O s S - m O A W 6 C So N tr m (n W (h : rp N i cp tr [h m in Ln m fD bi m fD Vt m Cn O to N t0 N m N C {La Lm w ' [O1n CD �,, tmn rnm m - m m 0 w °o w w. w w N n �' W N fI) N O O m V O to . 1V W m t5 UI fT A V r m � fD VI L1 O .. O to O o O [7 G N m b n Rica V N .A fn m m W V �c O m V m w m O w w to W w W v a w to N S71 Q tUthn O O O AAm 4 0 AAA O d O O 0 . O o 0 41 A 0 = vTimZ CD 190 "- Z "0 Z - O v CID gmg a n a !k; a rp list - o o 14 g C, COI I I L I $ t CD5-26 Surface Injection Pressures with gauge at disposal wellhead and using annulus friction of 50 MW Injection Pressure (psi) MW Injection Pressure MW (psi) Injection Pressure (psi) 6.8 1,421 8.8 13195 10.8 968 6.9 1,410 8.9 11183 10.9 957 7.0 1,398 9.0 11172 11.0 945 7.1 13387 9.1 1,161 11.1 934 7.2 1,376 9.2 151149 11.2 923 7.3 11364 9.3 19138 11.3 911 7.4 1,353 9.4 15127 11.4 900 7.5 19342 9.5 1,115 11.5 889 7.6 1,330 9.6 13104 11.6 877 7.7 11319 9.7 1,093 11.7 866 7.8 1,308 9.8 1 1,081 11.8 855 7.9 15297 9.9 1,070 11.9 843 8.0 15285 10.0 19059 12.0 832 8.1 19274 10.1 19047 12.1 821 8.2 1,263 10.2 13036 12.2 809 8.3 19251 10.3 11025 12.3 798 8.4 1,240 10.4 15013 12.4 787 8.5 15229 10.5 15002 12.5 775 8,6 19217 10.6 991 12.6 764 8.7 1,206 1.0.7 979 12.7 753 ird '5!lcir"re'r . Vcn; rc-qt�crW to dlapauc Uf "nuw-pruduvL H " oar up flaidn from the yontina itt"ing of Aw.d. and war, v at mplrn am wool an the clean ap fluids rasai hinq AqM v1pasiDs nut Cho Louis at the inud y1wat in Prepowntion on Vainq oil babe iod. The cvonissLon had previciFTy opprovrd Aimponiag of Lhe "new piulur!" 01961 AP Quids ,)ria ann,ilar di.--Poc;al a-. (D I Pd --I Di.o t.) ',:htu ueLtli-,,l aL )+Ipjr-er CLLIMt; I and Claw 2 diupjjd-- up,.Iuns I i pn A:krrp, haJ e!,! t fae I ",M'I-ation of qKPOSVI k.kptiui: to tljR tz silri ior :n -H inn-olm-i dij�jat.] was appr, 1vPd 'A.S , by pracnina! an& nnvironmestal altezoaUve. Tr. thV4C- the WaSLO f WdS jrq nO Oil Vrnnt thM PreVIOUSlY WPPLuved and nri: An rcnult W thrz ongoing ar 'Alpinrz- The liikVfl )1IthV'T--7Qd rqi-.ri Sr lIC1 yo.1 tl�:.s luejtsclqe15y -..7vPy of Lo disposo VP Suidu au denctibed il. your cyxil ions- A�'P EL)II coq r'o wra?I �Lj nater in Me eUawheJ 11--rn Mai)v.nn pr-mvioasly re -quested 40 dinposo Cit naw -Product clown ap UUM e404 no calani- rinaatu, and nuj ant voice pit rLysins Croili lni)claq via annular p.r-, r,,rii t ran ur I I s a t the A' pi nc CD2 Di AL SiLe. As noted below, AOCM approlitzi nuch Haputal a7 tLe CCI DiM TiLm ;" 149Y hasRd nn the > integral relatio"SAP OL he mad MInInq JOCU17Y and the on-site dxMin.,ji - operation, Pi_ ILLib WOLJJd MY, to continvinq pursuing this requeot. AquifionnC CMOs. out o.! at thn- mud mixing facility mant scour in preparaUioi tot thc-- > torpnr4ry use of oil basel nud proWcon at Alpine 0 rho roming months. > Cho availabilit;y OL arnnLar dilposaj as an ontion for talk iihie fluids anc! >nITIlar wasteg won td qrvatly tocilita7a this prodeds. Mpleally, zouLJrf? hc,-rL-fjcj ally Icaced, tvwevej, LLmie ib " concern. abn%t fhn > porettid! quautAy cif Mid thaL could be qcnernrnd during thin large ocale > clean up rmores') > ?ankp an tha nad nixing fa,AiLy day COLLa-0L either new ard used mud > products. Thul-ig2h iinsus 13 wonnow waUh used pwaducts may bf-I i5jocted in > UL� 1j41xvdLL*d Qluss 11 disporl wsll (C519A), rKnah of how Pruducts WUUId poueutiaMy W-roix.c-I to fh,�, r.Iisr T.di: -pnna-I troll MD -02}, vhei:a Uxeve ig I djfNipjIty Minaginq rolida CQUtunw. Me Qla= 1"Vell is a COMM a lifulinq for facility InQuat=uctr=e, Wing the disposal lordtion tar all a domaptic eMuM, and IL is u p!hUX;ty LG prevenn any onmpromise to this x disposal facillLy. Annular dispospi presents a prefer cd waste managammuL in IMS lllhan.!� erns ve'--y mim-h ff.r YOUr XCT.V_qt. Mcase do not Q Q,,,, , Q , jt,,,atw via nuaij or phone cAt (50'7) G.'/U-.4200 h,,, jungtio7s Or naer,. r.adi-,-.ronal infuruk-ition. !dham-,rn -jonaell.y > Alpine ?it --d 675"UN tv > AL? Env > TO: Lai rr SzMcct: ReqUdSt C.V, M -dr Mr. Ma-AildeL, fluirls f-eirn j%tij aml b:., itie Mix iox� > r,.:v��i,,La. and c.[ir 'IT, nprLrat-.nns P.L Cie AlpifayljLty jjm.Lo � zi#� rMUCI pldUt jijprnvcm-j annular 4i%pomal > operallom wop uIlmed by hm AKKo Oil Xnd qan Cunaewvhtion Cumminuion > MOGM '-,i tU.---, Harch 11, 1999 jnttcr "rpm A01CC to VM9 MOtcy Q AM > 1,1zijka, :::V-4, I'-.klW 1'1113-"Upk; Alctsk:-- rm,�. wAJ) - Thom aMrc-al was 90anted t" f J,(- L1 y :-O-r Alpiap Dri -- I 5,irf% r-E)l al.0 Volume -h Lip > 3�,nOU homInK Moig4 zhe emullar -bpaun. j%Z rcquent thaL zhit approval Le exzmajed Lo W1109 oyn-ationq n; Alpint, Di=11Site (:-)7 I . Coal -CL 11114..0q OPOW !OCS !Or n0tving nulfa" "W"Of V > wi;l be raking place at the Srind and InjeCt WUMLY 6410n W UU0YOM3 w a=tached Lu 1. he diAlIng rip at CD2. UP01 of com-n-i,nq ir Of Ule ckj�, the Lines W mininq tank will hdvO Wbe Unsela 0114 danpumed of. TAI reqaego apOluval to LUMT VhiWrTnWR, =d Vzn: Qe mjd and MAnn Mining n;mr-ation." "-1t.0 U-'tg annual a wpmcc of approved w&ll.j located at Di-Ul a=te CU) n. ajjy q.11f, Lqj q contct 7e aL L70— 200 > Upinc Field Envilonmental ConplianCe , I .t7z i &n-! IvaunaondmW ConocoPhillips Alaska, Inc. Post Office Pox 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 4, 2020 Alaska Oil and Gas Conservation Commission 333 West V, Avenue, Suite 100 Anchorage, Alaska 99501-3539 ConocoPhillips Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD5-26 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD5-26 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CDS-26 approximately April 1, 2020 or earlier depending on permit approval status. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Plan View of Adjacent Wells 4. Surface Casing Description 5. Surface Casing Cementing Report & Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 7. Intermediate Casing Description 8. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 9. Formation LOT on 10-314" x 7-518" casing annulus 10. List of wells on CD5 pad and the lateral distance from the surface casing shoe 11. Information regarding wells within 'A mile radius at AOGCC: CD5-03, CD5-04, CD5-05, CD5-06, CD5-07, CD5-08, CD5-09, CD5-10, CD5-11, CD5-12, CD5.17, CD5-18, CD5-19, CD5-20, CD5-21, CD5-22, CD5- 23, CD5-24, CD5-25, C135-92, CD5-96, CD5-98, CD5-313, CD5-314X, CD5-315, CD5-316 12. Copy of previous authorization (CD1 and CD2) for disposal of new product clean-up fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The annular LOT (15.5 ppg) occurred at a lower equivalent mud weight than the casing shoe FIT (18.9 ppg). Therefore, we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be more than the shoe FIT. If you have any questions or require further information, please contact Tom Rawlins at 263-3787 or Chip Alvord can also be reached by calling 265-6120. Sincerely, Tom Rawlins Drilling Engineer cc: CD5-26 Well File Chip Alvord ATO -1570 Note to File CD5-26 (PTD 2191070, Sundry 320-102) Colville River Unit (Alpine Oil Pools) ConocoPhillips Alaska, Inc ConocoPhillips has made application to authorize annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. -- No unusual events were reported while drilling the surface hole of the well (CD5-26). 10 314" Surface casing was cemented to surrace successfully. No problems reported. No report of volume of cement circulated to surface but based on calculations this would be approximately 200 bbls. Full returns throughout. 2 stage cement job 50% excess 1740-1328 ft, 250% excess 1328 ft to surface, 50% excess 2240-1740 ft. -- On the initial Formation Integrity Test (FIT) for the surface casing shoe dated 10/15/2019, the pressure slope rises smoothly with test stopping at 1.5 bbl pumped and 1050 psi to yield the desired 18.9 ppg EMW (plan was for 18.5 ppg EMW). The pressure declined slightly from 1050 psi to 1010 psi (18.5 ppg EMW) during the 10 minute shut in period with the 1.2 bbl being bled back. The initial FIT indicates that the surface casing shoe is well cemented. -- The 7.625" casing was run and successfully cemented with a single stage with the shoe of 15310 ft. Cement is estimated at TOC 12510 ft (based on SonicScope run with a process date 11119/2019) to TD. Cement job with full returns throughout. Annular disposal zone estimated from cemented 10.75" shoe at 2240 ft MD 2179 ft TVD to TOC estimated at 12510 ft MD. A post cement 10.75 x 7.625" annulus injectivity test LOT was performed 10/27/2019 with a calculated depth of the casing shoe of 2240 ft MD, 2179 ft TVD and an open hole to est 12510 ft MD yielding a 15.5 ppg EMW. The test showed pressure rising steadily with the sharp break over point at the 15.5 ppg EMW. --There are multiple wells currently drilled or planned to be drilled within Y4 mile radius of CD5- 26 and the CPAI application contains supporting cementing and LOT well information and mentions that well and cementing information is already on file with AOGCC. The surface shoe of CD5-24 is closest, about 75' distant. CD5-19 at 165 ft. AD is already prolific on CD5 and it is expected to continue with additional CD5 wells. CPAI is therefore constructing the CD5 wells to be compliant with AD regulations. Examination of the cementing information and LOT data did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. Chris Wallace Sr. Petroleum Engineer AOGCC March 5, 2020 F:lcdwallace\Documents\Amular Disposa11200305_CD5-26 note to file.doc Note to File CRU CD5-26 (PTI) 219-107) March 4, 2020 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CDS-26 Request ConocoPhillips requests approval to dispose of 35,000 barrels of drilling waste in well CD5-26. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 10-314" surface casing shoe is set in this well at 2,240' measured depth (MD; -2,106' true vertical depth subsea'), near the base of a 700 -foot thick mudstone and siltstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of sandy siltstone and silty sandstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed additional annular injection activities will likely lie within a radius of about 100' from the wellbore. 8. Injected fluids may reach several nearby wells that have open annuli beneath their surface casing shoes. However, surface casing, good -quality surface casing cement, and thick overlying confining mudstone and siltstone layers will ensure injected waste fluids remain within the approved disposal interval. Discussion ConocoPhillips' application was reviewed along with records from CRU CD5-26 and 31 nearby wells? The discussion that follows is based on well logs and mud logs from these wells. Index maps are provided in Figures 1 and 2, below. The proposed annular disposal injection interval in these wells lies in the Torok and Seabee Formations within Section 18, TI IN, R4E, Umiat Meridian, which is about 2-1/2 miles from the current exterior boundary of the Colville River Unit. The surface casing shoes of these wells mainly lie between about -2,068' (in C135-10) and to -2,193' (in CD5-313), near the base of a 330 -foot thick interval that is dominated I Unless otherwise noted, all depths presented herein are expressed as negative integers, which represent feet, true vertical depth below mean sea level (mean low, low water). All thicknesses are expressed as positive integers, which represent true vertical feet. All horizontal distances are expressed as positive integers, which represent feet. 2 CD5-01, CD5-02, CD5-03, CD5-04, CD5-05, CD5-06, CD5-07, CD5-08, CD5-09, CD5-10, CD5-11, CD5-12, CD5-17, CD5-18, CD5-19, CD5-20, CDS-21, CDS-22, CD5-23, CD5-24, CD5-25, CD5-26, CD5-92, CD5-96, CD5-98, CD5-99, CD5-313, CD5-314, C05 -314X, CD5-315, and CD5-316. CD5-26 Annular Disposal Note to File March 4, 2020 Page 2 of 5 by mudstone and siltstone and is continuous throughout the area. This mudstone and siltstone interval will provide upper confinement for fluids disposed in the annulus of the well (see Figure 2, below). In CD5-26, the annulus open to the disposal interval extends downward from the surface casing shoe at -2,106' to the top of second -stage cement for the 7-518" casing string, which is estimated to be -6,880'. The portion of the open annulus that will most likely accept the injected waste is a 134 -foot thick interval containing several 1- to 10 -foot thick beds of sandy siltstone and silty sandstone that lie below the surface casing shoe between -2,236' and -2,370' (see Figure 2). The aggregate thickness of these thin, potential receptor beds is about 40'. The sandy siltstone and silty sandstone beds are separated by thin mudstone intervals. Beneath the disposal interval are several intervals of mudstone that are continuous throughout the area; they will provide lower confinement for any injected wastes. &, _• Surface Casing Shoe for _ CDS-26�i , NORTH Soo feet A-LSurface Casing AShoe Locations Z CD5-26 n Open Annulus 4u~ o+ Figure 1. CD5-26 Index Map (The magenta -colored line depicts the path of the cross-section displayed in Figure 2.) The index map above displays trajectories for all wells drilled from the Colville River Unit CD5 Drill Site. The locations of the surface casing shoes for all well bores are illustrated using green -colored triangles. The calculated top of cement for CD5-26 production casing string lies beyond the southern border of the index map, above. Thirty one wells are currently open to these same strata within the V4 -mile radius area of review: CD5-01, CD5-02, CD5-03, CD5-04, C135-05, CD5-06, CD5-07, CD5-08, CD5-09, CD5-10, C135-1 1, CD5- 12, CD5-17, CD5-18, CD5-19, CD5-20, CD5-21, CD5-22, CD5-23, CD5-24, CD5-25, CD5-26, CD5-92, CD5-96, CD5-98, CD5-99, C135-313, CD5-314, CD5-314X, CD5-315, and CD5-316. CD5-26 Annular Disposal Note to File March 4, 2020 Page 3 of 5 Figure 2, below, presents a west -to -east trending structural cross-section view of CD5-26 and nearby wells CD5-316 and CD5-17, which were logged to the ground surface. Resistivity measurements indicate that the base of permafrost occurs at about -1,250' in the CD5 Drill Site area, which is about 985' above the top of the top of the uncemented annulus that lies beneath the surface casing shoe. SW iiiii oo 354' 2SB1070 412' 2170170 NE CRU Cb5-316 CRU C05-28 CRU COB -17 0 _5DO -1000 -1500 -2000 -2500 -3000 -8600 -4000 a 1A Surface _ Casing M a Cemented �r to Surface Permafrost Base at TVDSS Upper Confining interval Most Likely Disposal -{ Interval w r ,• p Surface I sew Casing -3500. Cemented u n to Surface Icy - .• Surface -50e Casing Cemented • 4' to Surface Surface ..+' ma Casing - - Shoe „ -1500 Lower Confining Intervals t�" y -3500. - .• Surface -50e Casing Cemented • 4' to Surface ;,.� ..+' ma „ -1500 -2500 i - Open Annulus gip: -3000 Cement top at .- . _ # -4000 = -3,691' TVDSS iw " J4 yu 1 Figure 2. CD5-26 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level; horizontal separation distance between wells is measured between the surface casing shoes) The shallow geologic section in the area surrounding the CD5 Drill Site contains predominantly methane gas, with minor amounts of ethane, propane, and butane. Mud logs were recorded in only two wells drilled near Drill Site CD5: CD5-313 and CD5-04. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.8 to 9.9 pounds per gallon). The shallowest -3500. Cement top at .- . _ # -4000 = -3,691' TVDSS iw " J4 yu 1 Figure 2. CD5-26 Area: Structural Cross-section (Depth scale represents true vertical feet below sea level; horizontal separation distance between wells is measured between the surface casing shoes) The shallow geologic section in the area surrounding the CD5 Drill Site contains predominantly methane gas, with minor amounts of ethane, propane, and butane. Mud logs were recorded in only two wells drilled near Drill Site CD5: CD5-313 and CD5-04. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.8 to 9.9 pounds per gallon). The shallowest CD5-26 Annular Disposal Note to File March 4, 2020 Page 4 of 5 occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mud log, equivalent to 4,000 ppm) were -1,850'and -2,000', respectively. So, the entire proposed annular disposal interval likely contains small, non-commercial amounts of methane gas. Unfortunately, oil shows are not recorded on the mud logs obtained in nearby wells CD5-313 and CD5-04, apparently due to the use of oil -base drilling mud. In ARCO's Nuiqsut 1 exploratory well, located about 1-112 miles to the northeast, the shallowest oil show was encountered at 3,990' MD (-3,930' TVDSS), with a second show encountered at 4,115' MD (4,055' TVDSS). The mud logging geologists rated these shows as fair to poor in quality. These oil shows occur in thin sandstones that are encapsulated above and below by claystone and mudstone. These characteristics suggest the oil shows represent the presence of only trace to minor quantities of oil in the geologic strata that will be affected by annular disposal in CD5-26. These shows do not represent commercial quantities of oil. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Order No. 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Injected Fluid vs Affected Area Surrounding CRUS135-26 Wellbore (Asrmptlon& 30.0% porosity, 50% naWs fluid displacement, aggregate cylinder 40.0' high) 200 102' affected radius assuming 40.0' of Injection Intervala99e9alelhlckneas s 100 0 a 0 0 5,000 10,00D 11x000 20,000 26,000 30,000 36,000 Amount of lnjeabed Fluid (barrels) (Assuming uniform, piston -like, radial displacement of 50% of nati 102' affected radius assuming 40.0' of Injection Intervala99e9alelhlckneas r Figure 3. CD5-26 Area Likely Affected by Annular Injection ve formation fluids) The gamma ray well log curve recorded inCD5-26 indicates that an aggregate total of about 40 true vertical feet of sandy siltstone and silty sandstone are present within the likely disposal interval. Inspection of the density porosity log for correlative intervals in nearby wells suggests an average poro sity of about 30% at this depth. Based on these values, the volume of rock that will receive 35,000 barrels of injected waste CD5-26 Annular Disposal Note to File March 4, 2020 Page 5 of 5 material lies within a radius of about 100' from the wellbore, assuming uniform, radial, piston -like displacement of half of the native formation fluids (Figure 3, above). Since the surface casing shoes of four wells (CD5-19, CD5-24, CD5-25, and CD5-314X) lies less than 200' away from the surface casing shoe of CD5-26, it is likely that injected fluids will the uncemented annuli of some of these wells. In CD5-19, surface casing was set at 2,237' MD (-2,118' TVDSS) and cemented with full returns to surface. In this instance, surface casing, surface casing cement, and thick overlying confining mudstone and siltstone layers will ensure the injected waste fluids remain within the approved disposal interval. Summary The limited volume of rock that will be affected by this proposed annular disposal program is situated beneath 1,250' of permafrost and is bounded above and below by laterally continuous confining layers of mudstone. This disposal interval lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. Although there are nearby wells with annuli that are open beneath their surface -casing shoes, surface casing, good -quality surface -casing cement, and thick overlying siltstone and mudstone confining layers will prevent injected fluids from migrating out of zone. I recommend approving the proposed annular disposal operations within CRU CD5-26 to the requested limit of 35,000 barrels. Steve Davies y �` Senior Petroleum Geologist COICV poi STATE OF ALASKA ALAS. JILAND GAS CONSERVATION COMM ISSIG, _ REPORT OF SUNDRY WELL OPERATIONS JAN 16 2020 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shut own"d Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development E] Exploratory ❑ Stratigraphic❑ Service ❑ 219-107-0 3. Address: P. O. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-103-20806-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: CRU CC15-26 ASRC-NPR4, ASRC-AA082344, ASRC-NPR2, ASRC-NPR5 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): POST FRAC REPORT Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 33,768 feet Plugs measured None feet true vertical 7,943 feet Junk measured None feet Effective Depth measured 33,768 feet Packer measured 14086,14549,14593 feet true vertical 7,943 feet true vertical 7572, 7634, 7639 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 20 115' MD 11 5'TVD SURFACE 2,201 feet 10 3/4 " 2,240' MD 2179' TVD INTERMEDIATE 15,203 feet 7 5/8 " 15,282' MD 7717' TVD ASAND LINER 19,142 feet 4 1/2 " 33,735' MD 7940' TVD Perforation depth: Measured depth: 15893-33689 feet FRAC SLEEVES True Vertical depth: 7755-7938 feet Tubing (size, grade, measured and true vertical depth) 4.5x3.5 L-80 14,610' MD 7,641' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - HALL]BURTON TNT PACKER 14,086' MD 7,572' TVD PACKER - HALLIBURTON TNT PACKER 14,549' MD 7,634' TVD PACKER - HRD-E ZXP LINER TOP PKR 14,593' MD 7,639' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 15893-33689 Treatment descriptions including volumes used and final pressure: Total Well - 19 stages, 1,494,400lbs of proppant placed ..... see attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: e a e e 0 Subsequent to operation: 1758 529 816 1705 436 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations D Exploratory ❑ Development I] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ �° II 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-544 Contact Name: Adam Klem Authorized Name: Adam Klem Contact Email: adam.klem@conocophillips.com Authorized Title: Completions Engineer ✓/"�--_� Contact Phone: (907) 263-4529 authorized � �S " Signature: Date: `,xC� ;�, J C J)N 112 91.20.20 V7-4- 31-f /2 ° Form 10-404 Revised 4/2017 p �/� J� RBDMS ^ �qN 16 2020 Submit Original Only CD5-26 FRAC STIMULATE DTTM JOBTYP SUMMARYOPS START 12/15/19 DRILLING RAN 3" DD BAILER (FLAPPER/ ID = 2.09") TO 14084' RKB. DRIFT TBG TO 14568' SUPPORT- RKB WITH 2.77" BAR BELL CENT. TESTED TBG @ 14568' RKB WITH 2.81" CAT CAPITAL STANDING VLV TO 2500 psi. "HELD SOLID". READY FOR FRAC. 12/16/19 DRILLING Hydraulic fracture stimulation on zones seven through fourteen. Pumped SUPPORT- approximately 10.1k -bbl fluid, 30-40 BPM, placing 568,000+ ponuds 20/40 Wank CAPITAL proppant. All balls launched as expected and pobserved good sleeve shift signature with approximately 3000 -psi differential each port. Freeze protected well with 24 -bbl LVT and proceeded with water and proppant reload for final stages. 12/18/19 DRILLING Hydraulic fracture stimulation on zones fifteen through twenty-two. Pumped SUPPORT- approximately 10.1k -bbl fluid, 37-47 BPM, placing 621,000+ pounds 20/40 Wanli CAPITAL proppant. All balls launched as expected and positive sleeve -shift signatures were observed with approximately 3300 -psi differential each port (one was high at 3900 -psi). Freeze protected well with 24 -bbl LVT and proceeded with remnant seawater disposal. Plan to complete rig -down tomorrow. 12/19/19 DRILLING MIT -IA TO 2500 PSI PASS, SEE WSR TIME LOG FOR DETAILS, LRS PORTION SUPPORT- COMPLETE CAPITAL CD6 - 26 Alpine AIC Dual Lateral Producer Final Schematic 2(" 94# H-40 Welded Conductorto 116 MD i i i 10-314" 45.5# L-80 HYD 563 x i 8TC Surface Casing at 2,249 MD 4-1/2'x 1" GLM 4-112" 1260 L-80 Hyd 563 4 -Ys' x 1- GLM 7 548" 29.711 L-80 TXP Intermediate Casing at 15,281' MD 39111 at heel TUC 12510' MD/ 6.953' TVD 4-1/.' x 1' GL.M 1 5' 1, Upper Completion: — - - 1) 4 %'-126# Hyd 553 tubing 2) Shallow nipple profile 3.813"X profile 3) 3x 4-K' x V Camco ICBM G GLM w/ Def 4) SL8 DHG 5) TNT Packer 6) High Pressure 2.813" X sliding sleeve -up to open 7) High Burst X Nipple profile, 2.813- 8) TNT Packer 9) XN Nipple profile. 2.813" Lomer Completion: 10)ZXP liter top packer & Flexlock liner Hanger XO 6' Hydril 521 Box X 4-Y.* H563 pin 11) 4 S' Hydril56312.6# L-80 W Frac Ports C sand Lateral 61/2` Hole TD 14.369 17.932° MD 4-'1:" 12.69 L-80 Hyd563 Liner W frac ports A sand Lateral 6 112' Hole TO 15,282'— 33, 768' M D wNs P`7D WELLNAME CD5-26 WELLBORE CD5-26 ConocoPhillips Alaska, Inc. ••• HORIZONTAL, CD5-26, 1116120208:01:01) AM Completion Details Vertical schematic (actual) Top (TV Top Incl Nominal Top (ftKB) (ftKB) (') Item Des Com ID (in) HANGER; 34:4 ..:............. 14,591.5 7,639.2 83.44 1 MULE SHOE I Baker WLEG 2.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (TVD) Top Incl Top (ftKB) (ftKB) C) Des Com Run Date ID (in) 14,185.2 7,589.5 80.93 RADIOACTIVE RA Tag placed into top coupling of 7 5/8" casing above 10/ 5/201 MARKER the C Sand Depth for window milling depth confirmation. 9 CONDUCTOR; 35.0-115.0 RA tag confirmed with Gamma Log on drill pipe at 14178'MD slacking off, not rotating Nov 10, 2019. Frac Summary SURFACE; 39.8-2,240.2 Start Date Proppant Designed (b)Proppamin Formation (lb) 12/14/2019 70,000.0 64,099.0 Stg # Start Date Top Depth (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbq NIPPLE; 2,484.8 1 12/14/2019 33,686.0 33,688.0 Gelled Salt Water, Hybor 1,642.00 1,709.00 Start Date Proppant Designed (lb) Proppant In Formation (lb) 12/14/2019 70,000.0 4,617.0 Stg* StartDate Top Depth (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) GAS LIFT; 4,449.3 2 12/14/2019 32,837.0 32,839.0 Gelled Salt Water, Hybor G 716.00 721.00 Start Date I Proppant Designed (Ib) Proppant In Formation (b) 12/14/2019 70,000.0 68,097.0 GAS LIFT; 9,479.9 D P ( I ( I Y (bbl)Slurry (bbl) Stg # Start Date To Depth ftKB Btm ftKB Link to Fluid System Vol Clean hbl VolVOI Slur bbl 3 12/14/2019 31,987.0 131,989.0 1 Gelled Salt Water, HyborG 1,515.00 1,587.00 Start Date Proppant Designed (Ib) Proppant In Formation (lb) 12/14/2019 70,000.0 67,576.0 GAS LIFT; 13,998.1 Stg 11 Start Date Top Depth (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 4 12/142019 31,138.0 31,140.0 Gelled Salt Water, Hybor G 1,514.00 1,585.00 GAUGE/ PUMP SENSOR; Start DateProppant Designed (Ib) Proppant In Formation (lb) 14,068.0 12/14/2019 70,000.0 72,250.0 PACKER; 14,085.8 Stg # Start Date Top Depth (ftKB) St. (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbp 5 12/14/2019 30,295.0 30,297.0 Gelled Salt Water, Hybor G 1,304.00 1,379.00 Start Date Proppant Designed (lb) Proppanl In Formation (lb) SLIDING SLEEVE; 14,140.9 12/14/2019 70,000.0 10,951.0 5ta # Start Date Top Depth (ftKB) St. (ftKB) Link ro Fluid System Vol Clean (bbl) Vol Slurry(bbl) 6 12/14/2019 29,449.0 29,451.0 Gelled Salt Water, Hybor G 2,517.00 2,5Start Data I Proppant 28.00 NIPPLE; 14,257.4 12/16/2020 70.0 p ODestgned (Ib) P70,8pi.0In Formation (Ib) Stg # StartDateTop DePth (ftKB) Btm (ftK8) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl)7 12/16/2019 28,602.0 28,604.0 Gelled Salt Water, Hybor G 1,229.00 1,303.00 Start DateProppant Designed (lb) Proppant In Formation (lb) PACKER; 14,549.0 12/16/2020 70,000.0 68,126.0 NIPPLE; 14,568.5 Stg # I Start Date Top Depth (ftKB) Son IftKB) Link to Fluid System Vol Clean (bbq Vol Slurry (bbl) LOCATOR; 14,590.6 8 12/162019 27,754.0 27,756.0 Gelled Salt Water, Hybor G 1,185.00 1,257.00 Start Data I Proppam Designed (Ib) Proppant In Formation (lb) MULE SHOE; 14,591.6 12/16/2020 70,000.0 70,569.0 S19# Start Date Top Depth (ftKB) 2B6',(ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 9 12/16/2019 26,905.0 26,907.0 Gelled Salt Water, Hybor G 1,208.00 1,281.00 I ' Start Date I Proppant Designed (b) Proppant In Formation (lb) 9qv-.Pp 12/16/2020 70,000.0 70,743.0 Stg# Start Date Top Depth (ftKB) Btm ITB) Link to Fluitl System Vol Clean (bbl) Vol Slurry (bbl) 10 12/16/2019 26,056.0 26,058.0 Gelled Salt Water, HyborG 1,229.00 1,303.00 INTERMEDIATE; 78.4-15,281.7 12/162020 70,0 O ODesignetl (Ib) 7 as2°o In Formation (Ib) Stg # Start Date Top Dep- (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Hydradi Fncture; 15,8930 I I 11 12/16/2019 25,205.0 25,207.0 Gelled Salt Water, HyborG 1,202.00 1,277.00 Start Data Proppant Designed (Ib) Proppant In Formation (Ib) 12/16/2020 70,000.0 72,597.0 Hydraulic Fmetum; 16,745.0 Stg #Start Date Top Depth (ftKB) Btm (ftKB) Link to Fluitl System Vol Clean (bbl) Vol Slurry (bbl) 12 12/16/2019 24,361.0 24,363.0 Gelled Salt Water, Hybor G 1,261.00 1,337.00 Hydraulic Fracture; 17,584.0 I 1 Start DateProppant Designed (lb) Proppant In Formation (Ib) 12/16/2020 70,000.0 72,021.0 Hydraulic Fracture; 18,417.0I I Stg # Start Date Top Dep- (ftKB) Bb" (ftKB) Link to Fluitl System Vol Clean (bbq Vol Slurry (bbl) 13 12/16/2019 23,514.0 23,516.0 Gelled Salt Water, Hybor G 1,197.00 1,272.00 Start Date Proppant Designed fib) Proppant In Formation (lb) Hydraulic Fracture; 19,268.0 1 12/16/2020 70,000.0 72,328.0 Stg # Start Date Tap Depth (ftKB) Btm (ftK8) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Hydraulic Fracture; 20,124.0 I I 14 12/16/2019 22,670.0 22,672.0 Gelled Salt Water, HyborG 1,578.00 1,654.00 Hydraulic Fracture; 20,975.0 I 1 Start DateProDpant Designed (b) Proppam In Formation (Ib) 12/182020 70,000.0 66,434.0 S- # Start Data Top Dep- (ftKB) Btm (ftKB) Link to Fluitl System Vol Clean (bbl) Vol Slurry (bbl) Hydraulic Fmcum; 21,819.0 I 15 12/18/2019 21,819.0 21,821.0 Gelled Salt Water, Hybor G 1,241.00 1,310.00 Start Date I Proppant Designed (Ib) Pmppant In Formation gb) Hydraulic Fracture; 22,670.0 12/18/2020 70,000.0 63,220.0 Stg IN I Start Date Top Dep-(ftKB) Btm (ftKB) Link Fluid System Vol Clean (bbp VOI Slurry (bbl)Hydraulic Fracture; 23,514.0 I 1 16 12/18/2019 20,975.0 20,977.0 Gelled Salt Water, Hybor G 1,200.00 1,266.00 Start Date I Proppant Designed (Ib) Proppant In Formation (Ib) Hydraulic Fracture; 24,361.0 I 12/18/2020 70,000.0 67,222.0 Stg # StartDateTop Depth (ftKB) 13"' (ft(B) Link to Fluid System Vol Clean (bbp Vol Slurry (bbl)TO12/182019 20,124.0 20,126.0 Gelled Salt Water, Hybor G 1,193.00 1,263.00 Hydraulic Fracture; 25,205.0 ( 1 Start Data I Proppant Designed (lb) Proppant In Formation (ib) 12/1812020 70,000.0 61,811.0 Hydraulic Fracture; 28,058.0 I I Stg # StartDate Top Dep- (ftKB) Btm (ftKB) Link ro Fluid System Vol Clean (bbl) Vol Slurry (bbl) 18 12118/2019 19,268.0 19,270.0 Gelled Salt Water, HyborG 1,276.00 1,341.00 Start DateProppant Designed (lb) Proppant In Formation (b) 12/18/2020 70,000.0 88,089.0 Hydraulic Fracture; 26,9050 Stg # StartDate To Da th ftKB Btm ftKB Link ro Fluid System Vol Clean bbl Vol Slur bbl P P I 1 (ftKB) Y ( 1 ryl ) Hydraulic Fracture; 27,754.0 I ' 19 12/18/2019 18,417.0 18,419.0 Gelled Salt Water, Hybor G 929.00 1,021.00 Start Date Proppant Designed (lb) Proppant In Formation (b) Hydraulic Fracture; 26,602.0' 12/18/2020 70,000.0 85,700.0 S. # Start Date Top Depth (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Hydraulic Fracture; 29,449.0 I ' 20 12/18/2019 17,584.0 17,586.0 Gelled Salt Water, Hybor G 919.00 1,009.00 Start Date Proppant Designed (lb) Proppant In Formation (lb) 12/18/2020 70,000.0 85,125.0 Hydraulic Fracture; 30,295.0 Stg # I Start Data Top Dep- (ftKB) Btm (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 21 12/18/2019 16,745.0 16,747.0 Gelled Salt Water, Hybor G 918.00 1,007.00 Hydraulic Fracture; 31,138.0 I I Start Data Proppant Designed (b) Proppant In Formation (lb) 12/182020 70,000.0 103,896.0 Hydraulic Fracture; 31,967.0 Stil# Start Date Top Depth (ftKB)7B1 - (ftKB) Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl)1 22 12/18/2019 15,893.0 15,895.0 Gelled Salt Water, Hybor G 1,215.00 1,324.00 Hydraulic Fracture; 32,637.0 I 1 Hydraulic Fracture; 33,686.0 A SAND LINER; 14,593,3- 33,735.4 4,593333,735.4 WN$ POOD WELLNAME CD5-26 WELLBORE CD5-26 Hydraulic Fracturing Fluid Product Component Information L .ure Fraclue Date 12/15r1019 stale: Alaska County: Harnso API Number: 5010320806 CONOCOMU11-IR NORTH SLOPE - Opemtor Name: ESUS Wall Name and Number. CDs 26 Longitude: -151.22336 Latftuda: 70.313594 Lorga.at Proieathn: NAD27 lndlardFederal: Production oil True Venl al Depth(TVD): 7,943 Total Water Volume 1,179,223 Hydraulic Fracturing Fluid Composhlon: Chemical Maximum Abstract Maximum Ingredient I Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration I Ingredient Mass In Comments Company First Name Last Name Email Phone Number (CAS (%by. masa)" lbs HE Fluid (h by mass Fresh Water _Operator Base Fluid Wales 7732-155 1oC. 002 85.735112 10046947 Donuty=8520 MHaliturdit Bbdde Listed Bested MICROBIOCIDE Bel IC li Below 0 NA CL-22 UC Halibunon Cmaslinker Listed Bekrw Listed Bekxv 0 NA CL -31 ria Hahlun Cmasuker Listed Below CROSSLINKER Listed Ba 0 NA LOSURF-300D Haliburtm Nm -ion. Surf.-[ Lister Below Listed Below 0 NA MO -67 Haliburton PH Call Additive Listed Below Lsted Below D NA OPTIFLO-III DELAYED Halliburton Break. Listed Below RELEASE Listed Below 0 NA BREAKER SP BREAKER Husborton Brinker Listed Below Listed Belau 0 NA WG GELLING Haliburton G AGENT ellkg Agent Listed Sam Listed Below 0 NA LVr-200 Perri Reece Protect Listed Below luted Salm 0 NA War W anti 20/40 Pmppam Adult- Listed Below Listed Below 0 NA Com Ingredients Lsted Above Listed Above 1,2,4 Tnrre ben7ena eS63-6 i.00e 0.00074% m 2.Bmmo-24-1,3 r anseiel 52-51-7 100.00% 0.00150% 176 Dense Tuck, HaII@urton, 3000 Dense.Tuck,g Acrylate polymer Proprietary 1.009 o.cr0 116 N. Sam Houston Pkwy E., Houston, Halliburton Denise Tuck Hal4bumin.co 281671-6226 TX 77032, 281- in 8716226 Am -k,. eersu8ats 7727-$4-0 100.008 0.020<e9 2401 Denise.Tuck@ Boralesa85 Proprietary 60.008 0.05896% 6909 Haeibunon Dense Tuck Haltiburton.co 281671-6226 in Corundum 1302-74-5 65.00% 8.28905% 971361 C telIv fl_, quarte 14808-60-7 30.001 0.00624% 732 Omse.Tuck@ Cured acrylic min Proprietary 30.006 0.006148 720 Halliburton Dense Tuck HalGburtwr.co 281671-6226 in ENmnd 6417-5 60.00% 0.04466% 5234 Guar u 9000-3D-0 100.009 0.260229 30494 %mat. nes lithe 64742-945 30.00% 0.022339 2617 rabmted Matters, light 6474247-8 100.008 0.95460% 111876 MuIIOe 1302-936 45.001 5.735579 672480 Na hlhdana 91-20.3 s.0o% 0.003729 437 Denise.Tuck@ Oxysted phenci. resin Proprietary 30.00% 0.02978% 3480 Halla enon Dense Tuck He lhurton.co 281671-6226 in Pdy(ox -1,2ethanedy), Apha{4 narylpharryl)amegahydmxy-, 127087-876 5.00% 0.00372% 437 branched Potassium formate 590-294 60.009 0.058969 6909 Potassium hydroxide 1310-58-3 5.00% 0.00235% 276 Potassium -.borate 13709-94-9 60.00% 0.02821% 3306 Sedum meth ceONose 9004-327 1.00% 0.00098% 116 Sodium Chloride 7647-14-5 1.00% 0.00154% 182 Sodium glycolude 2836-32-0 1.009 0.00098% lie Sodium hydroxide 1310-73-2 30.00% 0.016729 1960 Sodom ersu8ale 7775274 100.00% 0.000176 20 Sodium SUiFate 7757-82-6 0.10% 0.000009 1 Wet. 7732-18.5 100.00% 0.11342% 13293 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. Al component imormation listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inamurate and/or incomplete information. Any quartons regarding the content of the MSDS should be directed to the supplier who provided it. The Occupa9onal Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary', 'trade sewer', and "confidential business information' and the criteria for how this information is re ned on an MSDS is sub'ect m 29 CFR ist0.t200 and Appendix D. Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: Job End Date: State: County: API Number: Operator Name: Well Name and Number: Latitude: Longitude: Datum: Federal Well: Indian Well: True Vertical Depth: Total Base Water Volume (gal): Total Base Non Water Volume: 12/14/2019 12/18/2019 Alaska Harrison Bay 50-103-20806-00-00 ConocoPhillips Company/Burlington Resources CD5-26 70.31325900 -151.22648300 NAD83 NO NO 7,943 1,179,223 0 Hydraulic Fracturing Fluid Composition: 1'rdC F; c ) Lw m Chemical Disclosure Registry GROUNDWATER roil&Gas Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS #) (% by mass)** (% by mass)** Fresh Water Operator Base Fluid Water 7732-18-5 100.00000 85.73511 Density = 8.520 Ingredients Listed Above Listed Above Water 7732-18-5 100.00000 0.11342 SP BREAKER Halliburton Breaker Listed Below MO-67 Halliburton pH Control Additive Listed Below BE-6 MICROBIOCIDE Halliburton Biocide Listed Below LVT-200 Penreco Freeze Protect Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below WG-36 GELLING AGENT Halliburton Gelling Agent Listed Below CL-31 CROSSLINKER Halliburton Crosslinker Listed Below OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Listed Below Wank 20/40 Wanli Proppant Company Additive Listed Below CL -22 LIC Halliburton Crosslinker Listed Below Items above are Trade Names with the exception of Base Water. Items below are the individual Corundum ti 1302-74-5 65.00000 8.28905 Mullite 1302-93-8 45.00000 5.73857 Hydrotreated Distillate, light 64742-47-8 100.00000 0.95468 Guar gum 9000-30-0 100.00000 0.26022 Borate salts Proprietary 60.00000 0.05896 Potassium formate 590-29-4 60.00000 0.05896 Ethanol 64-17-5 60.00000 0.04466 Oxylated phenolic resin Proprietary 30.00000 0.02978 Potassium metaborate 13709-94-9 60.00000 0.02821 Heavy aromatic petroleum naphtha 64742-94-5 30.00000 0.02233 Ammonium persulfate 7727-54-0 100.00000 0.02048 Sodium hydroxide 1310-73-2 30.00000 0.01672 Crystalline silica, quartz 14808-60-7 30.00000 0.00624 Cured acrylic resin Proprietary 30.00000 0.00614 Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)- omega-hydroxy-, branched 127087-87-0 5.00000 0.00372 Naphthalene 91-20-3 5.00000 0.00372 Potassium hydroxide 1310-58-3 5.00000 0.00235 Sodium chloride 7647-14-5 1.00000 0.00154 2-Bromo-2-nitro-1,3- propanediol 52-51-7 100.00000 0.00150 Sodium carboxymethyl cellulose 9004-32-4 1.00000 0.00098 Sodium glycollate 2836-32-0 1.00000 0.00098 Acrylate polymer Proprietary 1.00000 0.00098 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226 1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00074 Sodium persulfate 7775-27-1 100.00000 0.00017 Sodium sulfate 7757-82-6 1 0.10000 0.00000 ' Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water lInformation is based on the maximum potential for concentration and thus the total may be over 100 If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) HALLISURTON l r c-6.160385 Conoco Phillips Alaska CD5-26 Intervals 1-22 A -Sand Formation Harrison Bay County, AK API: 50-103-20806 Prepared,for: Adam Klem December 18. 2019 Stimulation Treatment Post Job Report 25# Hybor G Prepared By: Keegan Lambe Chad Burkett Nanook Crew Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user's own risk. Table of Contents Section Page(s) Executive Summary 3 _ Wellbore Information Actual Design 4 5-7 Interval Summary _ 8-30 Fluid System-Proppant Summary _ _ 31 Interval 1 Plots _ 32-39 _ Interval 2 Plots__40-42 _ _ _ Interval 3 Plots 43-45 Interval 4 Plots Interval 5 Plots 46-48 49-51 Interval 6 Plots 52-56 Interval 7 Plots 57-62 Interval 8 Plots _ _ 63-65 Interval 9 Plots _ 66-68 Interval 10 Plots 69-71 Interval 11 Plots 72-74 Interval 12 Plots 75-77 Interval 13 Plots 78-80 Interval 14 Plots 81-83 Interval 15 Plots _ _ _ 84-90 Interval 16 Plots _ _ 91-93 Interval 17 Plots 94-96 Interval 18 Plots 97-99 Interval 19 Plots 100-102 Interval 20 Plots 103-105 Interval 21 Plots 106-108 _ _ Interval 22 Plots _ _ 109-111 Appendix 112 Well Summary 113 Chemical Summary _ _ _ _ 114 Planned Design 115-117 Water Straps Day 1 118 Water Straps Day 2 119 Water Straps Day 3 120 Water Analysis Day 1 121 Water Analysis Day 2 122 _ _ Water Analysis Day 3 _ 123 Real -Time QC 124 Fann 15 Prejob Break Test Day 1 125 Fann 15 Prejob Break Test Day 2 126 Fann 15 Prejob Break Test Day 3 _ _ 127 Fann 15 Zone 1 128 Fann 15 Zone 2 129 Fann 15 Zone 3 130 Fann 15 Zone 4 131 fann 15 Zone 5 132 Fann 15 Zone 6 133 Fann 15 Zone 7 134 Fann 15 Zone 8 135 Fann 15 Zone 9 136 _ _ _ Fann 15 Zone 10 _ 137 Fann 15 Zone 11 .138 Fann 15 Zone 12 139 Fann 15 Zone 13 140 Fann 15 Zone 14 141 Fann 15 Zone 15 142. Fann 15 Zone 16 143 Fann 15 Zone 17 144 Fann 15 Zone 18 145 - Fann 15 Zone 19 146 Fann 15 Zone 20 _ 147 Fann 15 Zone 21 148 Fann 15 Zone 22 149 _ Event Log Day 1 150 _ Event Log. Day 2 151 Event Log Day 3 152 Lab Testing 153-154 Conoco Phillips Alaska - CD5-26 TOC Engineering Executive Summary On December 14, 2019 a stimulation treatment was performed in the A -Sand formation on the CD5-26 well in Harrison Bay County, AK. The CD5-26 was a 22 stage Horizontal Sleeve Design. The proposed treatment consisted of: 0 gallons of Seawater 1,040,600 gallons of 25# Hybor G 24,361 gallons of 25# Waterfrac G 1,848 gallons of Freeze Protect 1,620,000 pounds of Wanli 20/40 The actual treatment fully completed 19 of 22 stages. 0 stages were skipped, and 3 stages were otherwise cut short of design. The actual treatment consisted of: 9,475 gallons of Seawater 1,086,510 gallons of 25# Hybor G 83,238 gallons of 25# Waterfrac G 4,602 gallons of Freeze Protect 1,494,400 pounds of Wanli 20/40 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: Due to the ball not hitting on interval 2, the interval was cut short and the ball for interval 3 was dropped. Interval 6 was also cut short of proppant after there was no ball hit signature for both the primary ball and the backup ball. Interval 18 was cut short of design due to loosing the tub on the Blender and ADP. Due to water constraints on the day the 3ppg stage was cut short, the 4ppg stage was extended. The extra proppant cut from interval 18 was pumped in interval 22. The Minifrac was cut from design per customer request. The pump schedule was altered based upon the issues that occurred during the job. One of the castles had a load cell go bad resulting in inconsistent weight readings. A second castle had a motor burn out and the arm bent. This meant that the Castle had to be operated manually. There were also issues with proppant ice chunks leading to the blender struggling to get to full concentration. On 12/10 the pressure test on the double isolation ground valves was started. The initial tests failed, leading to different ground valves being sent out to Alpine. On 12112 the second set of ground valves was tested and they failed as well. On 12113 the third set of 4"ground valves was tested and failed. A failed test was indicated by fluid flowing through the closed valve with visual conformation at the pit. 3" ground valves were supplied by a 3rd party and had a positive test on the evening of 12/13. The 3" valves were drifted with a 2.49" ball. 4" Valves were shipped back out after the first day of pumping and pressure tested. After initial pressure bleed through the valves held at higher pressure. Intervals 7-22 were pumped using the 4" valves. 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 Concentration was adjusted as needed. 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. Thank you, Keegan Lambe Technical Professional Halliburton Energy Services Conoco Phillips Alaska - CD5-26 Executive Summary pmoe 1 21ta 2— F—SwevlPoElOpgX I vYWuun T- A, I """IZ elwo 1A Conoco Phillips Alaska - CD5-26 Wellbore Information F—SwevlPoElOpgX I T- A, """IZ elwo 1A 1,— 1 2� �Z� 151 to se0 oats x9T5t ].999 6 <-Sane 1659 a.3l:oo aM na s,o]E east NP HA nn nn nn rva rvn nn nP Ao 4 211 M 4334 17. 1.1 I 1,114 17 1A1111 Ill TTZ z 4,yL5 SA31 SA51 14,8 33D0 4.8W Ja30 L403 9.39} 1.069 328.31 ]g268 1— Conoco Phillips Alaska - CD5-26 Wellbore Information BFD Conoco Phillips Alaska-CD5-26 Actual Design 911119ml R., . �'+LR:..L� now Im Conoco Phillips Alaska-CD5-26 Actual Design =MEa nu�niMw r�wwauwro i.�a_. eeo lro/¢oil sT!'FI Conoco Phillips Alaska-CD5-26 Actual Design OWN��•�am•��m�� o �st�r,�..��a��®�ar��m��e�� mvlllll��^��®��sae - ��®®�m��®®gym•®�m��®�� :�m��®®mom®��®lllllwm�illillliiim� - no En IMM -11M -- - - jjj&�— amm NONE Conoco Phillips Alaska-CD5-26 Actual Design worms uIT wsTM M.non aaa aaaa � � � �mom�mo�m eee m��aoa�a Conoco Phillips Alaska - CD5-26 Actual Design ®�.�vr•�m.��®®®ms�m•mm,m�m•mmtm m. ®��cam•� �.��•r�mo�m.� ��m•��I�m'•a�� m.��®®®gym•®mtm�m.®m,m m.mm,m�m•®mtm - m•��®�©�®®��®m®mom®®®m loom �rs��*e�m•m�r.��®®��s�mmtm��•smmm - ®�r�r��mm�®��s��®®��m•m®mom®®®m m• ®�a��.-��mo�m��®�m.mm��mmmt®�m•mmtm �r��v� m•��m�m•�®��®�m•mm,m�®m®m m.��•�mm�m•��®®mm,� mmmtm�m.mm,m m•m��!mmm�mme�m• m•�.��mm��m. m©�©®m�ll��m�m��mmm m�©m.��®�m.mmtm�®mmtm m•�a.•xx��m�ve�m• m•�cr.��v�m•��©®mom®��m•mmtm�m•mmtm m�mmt®�®®�®�m•mm,m�m•mmtm ®�.a�.�v�m•®©m�m�©�®m®®m,®gym•®®m m•�rsr��±�v©m®��®®®i��®®mtm�m•m®�� ®tea . ��v��®®��®®®®�®®mt®�m•m®m m•slum ®��'• �.»�I��m��ee�s� ice.'•., m�11111IM1111111��m ® rte• �'s •" m '��Ef.� ��mlt�� aaa aaaa � � � �mom�mo�m eee m��aoa�a Conoco Phillips Alaska - CD5-26 Actual Design Interval Summary CD5-26 - A -Sand - Interval 1 Interval Summary Start Date/Time: 12/14/19 9:06 25# Hybor G Volume: End Date/Time: 12/14/19 10:53 25# Waterfrac G Volume: Pump Time: 107 min Initial Rate (Breakdown): 12,5 bpm Initial Surface Pressure (Breakdown): 5,611 psi Initial BH Pressure (Breakdown): 8,614 psi Max Rate: 30.6 bpm Max Surface Pressure: 6,791 psi Max BH Pressure: 9,373 psi Average Rate: 21.1 bpm Average Missile Pressure: 4,976 psi Average Surface Pressure: 4,790 psi Average BH Pressure: 7,478 psi Average Missile HHP: 2,576 hhp Initial OA Pressure: 310 psi Max OA Pressure: 370 psi Max Proppant Concentration: 3.85 ppg Average Visc: 24 cP Average Temp: 86 F Average pH: 9.46 Wanli 20/40 Pumped: Total Proppant Pumped* : Proppant in Formation: Proppant Summary 64,099 lbs 64,099 lbs 64,099 lbs Fluid Summary (by fluid description) Seawater Volume: 9,475 gal 25# Hybor G Volume: 59,483 gal 25# Waterfrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 17,153 gal Proppant Laden Fluid Volume: 33,959 gal Spacer Volume: 9,475 gal Spacer and Ball drop Volume: 2,553 gal Interval Status: Completed ;omments: linifrac was skipped per customer request. After establishing the X -link the ball was dropped. No udio was heard. Pumped 10bbl through the ball drop line. Slowed down 301bbl early based off the alve opening as a precaution. During the 2ppg stage the mixing bowl on the ADP stopped getting ,ater. Dropped rate and pumped a seawater spacer while the problem was resolved. Restarted roppant in 15bbl steps up to 2ppg. During the second 2ppg stage the dirty mag meter acted up. witched to truck rate with efficiency to account for the fluid. .m:,. ,�,_� , _ W 0., „ri._�! .,.,.. a i. 1> hil od i,!i Oi J!N ..,:42 ,tT es 'IrA, M') ,s ,t 1 !h, 226 bbls 1,416 bbls 0 bbls 0 bbls 408 bbls 809 bbls 226 bbls 61 bbls Engineer: Keegan Lambe Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer: Adam Klem Customer Rep: Mark Adams Conoco Phillips Alaska - CD5-26 Interval Summary 8 CD5-26 - A -Sand - Interval 2 Interval Summary Start Date/Time: 12/14/19 10:53 End Date/Time: 12/14/19 11:36 4,617 Pump Time: 43 min Initial Rate (Breakdown): NA bpm Initial Surface Pressure (Breakdown): NA psi Initial BH Pressure (Breakdown): NA psi Max Rate: 31.0 bpm Max Surface Pressure: 5,666 psi Max BH Pressure: 7,996 psi Average Rate: 16.3 bpm Average Missile Pressure: 4,234 psi Average Surface Pressure: 4,052 psi Average BH Pressure: 6,861 psi Average Missile HHP: 1,686 hhp Initial OA Pressure: 355 psi Max OA Pressure: 360 psi Max Proppant Concentration: 1.10 PP9 Average Visc: 23 cp Average Temp: 88 F Average pH: 9.4 gal Comments No ball hit was observed. Dropped rate multiple times and no hit was seen. Skipped the stage per Engineer: Keegan Lambe customer request. Treater: Josh Caprio Supervisor: Josh Caprio _- .a.an u t �<�=r, f ,., j <.� ., ��i<, �::,,�d „r ,.i� .. . I Customer Engineer: Adam Klem �rnp,oa-,[ i5 . ,ed cff of !i<K , ,,,.iumes, and iiae var fro-, Customer Rep: Mark Adams Conoco Phillips Alaska - CD5-26 Interval Summary 9 Proppant Summary Wanli 20/40 Pumped: 4,617 lbs Total Proppant Pumped' : 4,617 lbs Proppant in Formation: 4,617 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 30,061 gal 716 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 16,754 gal 399 bbls Proppant Laden Fluid Volume: 12,236 gal 291 bb/s Spacer and Ball drop Volume: 1,071 gal 26 bbls Interval Status: Cut Short Comments No ball hit was observed. Dropped rate multiple times and no hit was seen. Skipped the stage per Engineer: Keegan Lambe customer request. Treater: Josh Caprio Supervisor: Josh Caprio _- .a.an u t �<�=r, f ,., j <.� ., ��i<, �::,,�d „r ,.i� .. . I Customer Engineer: Adam Klem �rnp,oa-,[ i5 . ,ed cff of !i<K , ,,,.iumes, and iiae var fro-, Customer Rep: Mark Adams Conoco Phillips Alaska - CD5-26 Interval Summary 9 CD5-26 - A -Sand - Interval 3 Interval Summary Start Date/Time: 12/14/19 11:36 End Date/Time: 12/14/19 12:29 Pump Time: 53 min Initial Rate (Breakdown): 12.0 bpm Initial Surface Pressure (Breakdown): 5,853 psi Initial BH Pressure (Breakdown): 8,728 psi Max Rate: 35.3 bpm Max Surface Pressure: 6,330 psi Max BH Pressure: 8,664 psi Average Rate: 28.4 bpm Average Missile Pressure: 5,296 psi Average Surface Pressure: 5,132 psi Average BH Pressure: 7,707 psi Average Missile HHP: 3,684 hhp Initial OA Pressure: 346 psi Max OA Pressure: 387 psi Max Proppant Concentration: 4.07 ppg Average Visc: 17 cp Average Temp: 90 F Average pH: 9.55 Proppant Summary Wanli 20/40 Pumped: 68,097 lbs Total Proppant Pumped" : 68,097 lbs Proppant in Formation: 68,097 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 25# Hybor G Volume: 63,650 gal 25# Waterfrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 16,764 gal Proppant Laden Fluid Volume: 34,876 gal Flush Volume: 12,010 gal Interval Status: Completed Comments: During 4ppg the top cap on the front pump started to leak. Brought the pump offline and shut it in. Due to the placement of the pump the well was flushed using linear. Shut the well in and bled off to swap the hose. In order to minimize the over flush of the previous stage, the ball was dropped during the linear stage. (s 7a➢ 3[li: . , I k P ) ,(N le i 4....H1 tIn �).i n m 1 oio J 0 bbls 1,515 bbls 0 bbls 0 bbls 399 bbls 830 bbls 286 bbls tngineer: Keegan Lambe Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer: Adam Klem Customer Rep: Mark Adams Conoco Phillips Alaska - CDS-26 Interval Summary 10 CD5-26 - A -Sand - Interval 4 Interval Summary Start Date/Time: 12/14/19 12:29 End Date/Time: 12/14/19 13:49 Pump Time: 80 min Initial Rate (Breakdown): 11.6 bpm Initial Surface Pressure (Breakdown): 5,708 psi Initial BH Pressure (Breakdown): 8,802 psi Max Rate: 31.1 bpm Max Surface Pressure: 5,800 psi Max BH Pressure: 8,054 psi Average Rate: 20.9 bpm Average Missile Pressure: 3,878 psi Average Surface Pressure: 3,749 psi Average BH Pressure: 6,836 psi Average Missile HHP: 1,982 hhp Initial OA Pressure: 372 psi Max OA Pressure: 381 psi Max Proppant Concentration: 3.73 Ppg Average Visc: 19 cp Average Temp: 90 F Average pH: 9.52 Proppant Summary Wanli 20/40 Pumped: 67,576 lbs Total Proppant Pumped` : 67,576 lbs Proppant in Formation: 67,576 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 42,211 gal 1,005 bbls 25# Waterfrac G Volume: 21,382 gal 509 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 29,804 gal 710 bbls Proppant Laden Fluid Volume: 32,714 gal 779 bbls Spacer and Ball drop Volume: 1,075 gal 26 bbls Interval Status: Completed Seat was shitted and 15bbl was pumped past the wellhead. Shut down until the line was swapped. Engineer: Keegan Lambe Also moved the LVT to Little Red to refill. Treater: Josh Caprio Supervisor: Josh Caprio �.:'cn ,mpp, n, :a`.na <,! sea or <,;e es- Customer Engineer: Adam Klem r .aat is sd ;r` cr, pit a , nav vary -hi n r,er. Customer Rep: Mark Adams Conoco Phillips Alaska - CD5-26 Interval Summary 11 CD5-26 - A -Sand - Interval 5 Interval Summary Start Date/Time: 12/14/19 13:49 End Date/Time: 12/14/19 14:34 Pump Time: 45 min Initial Rate (Breakdown): NA bpm Initial Surface Pressure (Breakdown): NA psi Initial BH Pressure (Breakdown): NA psi Max Rate: 33.8 bpm Max Surface Pressure: 6,249 psi Max BH Pressure: 7,628 psi Average Rate: 29.3 bpm Average Missile Pressure: 5,342 psi Average Surface Pressure: 5,188 psi Average BH Pressure: 8,326 psi Average Missile HHP: 3,840 hhp Initial OA Pressure: 346 psi Max OA Pressure: 372 psi Max Proppant Concentration: 3.63 Ppg Average Visc: 19 cp Average Temp: 90 F Average pH: 9.6 Proppant Summary Wanli 20/40 Pumped: 72,250 lbs Total Proppant Pumped` : 72,250 lbs Proppant in Formation: 72,250 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 254 Hybor G Volume: 54,755 gal 25# Waterfrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 16,776 gal Proppant Laden Fluid Volume: 37,496 gal Spacer and Ball drop Volume: 483 gal Interval Status: Completed Comments 0 bbls 1,304 bbls 0 bbls 0 bbls 399 bbls 893 bbls 12 bbls No initial ball hit observed. Dropped rate to 0 and back to 20bpm. No Ball hit observed again. Engineer: Keegan Lambe Relaunched the ball line, continued the stage after not hearing any audio cue per customer request. Treater: Josh Caprio Continued back in 1ppg. Supervisor: Josh Caprio Customer Engineer: 9 Adam Klem lrc . pa'. ii . d P"! ";if of , q rah, t(Ae, Customer Rep: Mark Adams Conoco Phillips Alaska - CD5-26 Interval Summary 12 CD5-26 - A -Sand - Interval 6 Interval Summary Start DatefTime: 12/14/19 14:34 End Date/Time: 12/14/19 18:03 Pump Time: 126 min Initial Rate (Breakdown): NA bpm Initial Surface Pressure (Breakdown): NA psi Initial BH Pressure (Breakdown): NA psi Max Rate: 32.0 bpm Max Surface Pressure: 6,384 psi Max BH Pressure: 7,947 psi Average Rate: 12.1 bpm Average Missile Pressure: 3,356 psi Average Surface Pressure: 3,204 psi Average BH Pressure: 5,825 psi Average Missile HHP: 994 hhp Initial OA Pressure: 309 psi Max OA Pressure: 374 psi Max Proppant Concentration: 1.15 PP9 Average Visc: 19 cp Average Temp: 86 F Average pH: 9.63 bbls Proppant Summary Wanli 20/40 Pumped: 10,951 lbs Total Proppant Pumped` : 10,951 lbs Proppant in Formation: 10,951 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 66,327 gal 1,579 bbls 25# Waterfrac G Volume: 37,468 gal 892 bbls Freeze Protect Volume: 1,904 gal 45 bbls Fluid Summary (by stage description) Pad Volume: 39,465 gal 940 bbls Proppant Laden Fluid Volume: 26,862 gal 640 bbls Flush Volume: 37,468 gal 892 bbls Freeze Protect Volume: 1,904 gal 45 bbls Interval Status: Cut Short Conoco Phillips Alaska - CD5-26 Interval Summary 13 Comments: No ball hit was observed. Cut proppant and flushed the well. Broke the ball drop line apart to visually inspect the line. No balls were found in the line. After getting the ball line back together, warm fluid was circulated down the well as a precaution while waiting for the pressure test of the ball launch line. The back up ball was dropped, with zero rate on the main treating line. The rate was slowly increased so that the audio of the ball passed through the iron. The ball was pumped down using the frac fleet. After pumping 211 bbl with the frac fleet (10bbl Little Red pump) there was a 200psi increase/decrease. There was no indication of a ball hit at the displacement volume. A viscus pill was pumped to see if there was a pressure response through the wellbore. The pressure response indicated a pressure decrease before the goal depth. The well was flushed with linear gel and seawater. 20bbl of Freeze protect was pumped down the well. vaUs fur proppant are taken From software Calculations based on multiple variables. 'roppant is billed orf of weight ticket voluines and may vary slightly from this number. Engineer. Keegan Lambe Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer: Adam Klem Customer Rep: Mark Adams Conoco Phillips Alaska - CD5-26 Interval Summary 14 CD5-26 - A -Sand - Interval 7 Interval Summary Start Date/Time: 12/16/19 11:38 End Date/Time: 12/16/19 12:45 Pump Time. 67 min Initial Rate (Breakdown): 12.5 bpm Initial Surface Pressure (Breakdown): 6,248 psi Initial BH Pressure (Breakdown): 8,806 psi Max Rate: 34.8 bpm Max Surface Pressure: 6,271 psi Max BH Pressure: 7,806 psi Average Rate: 26.2 bpm Average Missile Pressure: 4,550 psi Average Surface Pressure: 4,399 psi Average BH Pressure: 6,548 psi Average Missile HHP: 2,918 hhp Initial OA Pressure: 249 psi Max OA Pressure: 372 psi Max Proppant Concentration: 4.02 Ppg Average Visc: 22 cP Average Temp: 88 F Average pH: 9.68 Proppant Summary Wanli 20/40 Pumped: 70,851 lbs Total Proppant Pumped` : 70,851 lbs Proppant in Formation: 70,851 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 25# Hybor G Volume: 51,613 gal 25# Waterfrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 16,861 gal Proppant Laden Fluid Volume: 31,843 gal Spacer and Ball drop Volume: 2,295 gal Interval Status: Completed Comments 0 bbls 1,229 bbls 0 bbls 0 bbls 401 bbls 758 bbls 55 bbls Opened the well and after establishing injection, the audio of the ball was heard passing through Engineer: Keegan Lambe the iron. Slowed down for the ball to pass through the 3.5" tubing. Saw a ball hit. Treater: Josh Caprio Supervisor: Josh Caprio � ,-:Mrl .. e t . , 'r , .< t�v�a afar 5 base_ � �«�r �;� v <.F =.., Customer Engineer: Adam Klem nr.-C-Garai i� !, i'e.l c"' , m-1 gnt Bcke", vckj're5 and .nap vary sI ch a fm-tl-o i , :_. Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 15 CD5-26 - A -Sand - Interval 8 Interval Summary Start Date/Time: 12/16/19 12:45 End Date/Time: 12/16/19 13:25 Pump Time: 40 min Initial Rate (Breakdown): 12.5 bpm Initial Surface Pressure (Breakdown): 6,231 psi Initial BH Pressure (Breakdown): 8,740 psi Max Rate: 39.0 bpm Max Surface Pressure: 6,384 psi Max BH Pressure: 8,288 psi Average Rate: 32.2 bpm Average Missile Pressure: 5,126 psi Average Surface Pressure: 4,974 psi Average BH Pressure: 7,414 psi Average Missile HHP: 4,040 hhp Initial OA Pressure: 332 psi Max OA Pressure: 358 psi Max Proppant Concentration: 4.00 ppg Average Visc: 18 cp Average Temp: 92 F Average pH: 9.46 Proppant Summary Wanli 20/40 Pumped: 68,126 lbs Total Proppant Pumped' : 68,126 lbs Proppant in Formation: 68,126 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 49,786 gal 1,185 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 16,751 gal 399 bbls Proppant Laden Fluid Volume: 32,334 gal 770 bbls Spacer and Ball drop Volume: 701 gal 17 bbls Interval Status: Completed Comments Heard the Audio of the ball on the mic. Slowed down before the ball passed through the 3.5'. Engineer: Keegan Lambe Treater., Josh Caprio Supervisor: Josh Caprio Customer Engineer: Adam Klem �'r.ppant is r r„ T orf of v',-gjht tfrlke. chIfrr; in., �,,I, vary .(:city Irurr Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 16 CD5-26 - A -Sand - Interval 9 Interval Summary Start Date/Time: 12/16/19 13:25 End Date/Time: 12/16/19 14:02 Pump Time: 37 min Initial Rate (Breakdown): 12.6 bpm Initial Surface Pressure (Breakdown): 5,967 psi Initial BH Pressure (Breakdown): 8,801 psi Max Rate: 39.3 bpm Max Surface Pressure: 6,479 psi Max BH Pressure: 8,302 psi Average Rate: 33.9 bpm Average Missile Pressure: 5,209 psi Average Surface Pressure: 5,046 psi Average BH Pressure: 7,337 psi Average Missile HHP: 4,333 hhp Initial OA Pressure: 349 psi Max OA Pressure: 392 psi Max Proppant Concentration: 3.95 ppg Average Visc: 18 cp Average Temp: 91 F Average pH: 9.52 Proppant Summary Wanli 20/40 Pumped: 70,569 lbs Total Proppant Pumped` : 70,569 lbs Proppant in Formation: 70,569 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 50,715 gal 1,208 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 16,737 gal 399 bbls Proppant Laden Fluid Volume: 33,076 gal 788 bbls Spacer and Ball drop Volume: 902 gal 21 bbls Interval Status: Completed Comments Ball Audio passing through the iron was heard. Zone pumped to design. Engineer: Keegan Lambe Treater., Josh Caprio Supervisor: Josh Caprio Customer Engineer: Adam Klem is "ei. [hi Customer Rep: Mike Hazen Conoco Phillips Alaska - CDS-26 Interval Summary 17 ----------- CD5-26 - A -Sand - Interval 10 Interval Summary Start Date/Time: 12/16/19 14:02 Wanli 20/40 Pumped: End Date/Time: 12/16/19 14:40 Total Proppant Pumped` : Pump Time: 38 min Initial Rate (Breakdown): 12.9 bpm Initial Surface Pressure (Breakdown): 5,867 psi Initial BH Pressure (Breakdown): 8,567 psi Max Rate: 41.0 bpm Max Surface Pressure: 6,514 psi Max BH Pressure: 8,213 psi Average Rate: 34.8 bpm Average Missile Pressure: 5,328 psi Average Surface Pressure: 5,159 psi Average BH Pressure: 7,392 psi Average Missile HHP: 4,547 hhp Initial OA Pressure: 359 psi Max OA Pressure: 380 psi Max Proppant Concentration: 3.71 ppg Average Visc: 20 cp Average Temp: 89 F Average pH. 9.4 Interval Status: Completed Comments 0 bbls 1,229 bbls 0 bbls 0 bb/s 400 bbls 818 bbls 11 bbls Ball Audio passing through the iron was heard. Shut in the castle during the 4ppg stage, in order to Engineer: Keegan Lambe clear out the hopper. Had a pump derate during the 4ppg stage. Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer- Adam Klem rcppa t is hilled cfi of grt Ca,rc ,� Va . shgh: 11 r .;n. ih. n.r"er. Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 18 Proppant Summary Wanli 20/40 Pumped: 70,743 lbs Total Proppant Pumped` : 70,743 lbs Proppant in Formation: 70,743 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 25# Hybor G Volume: 51,609 gal 25# Waterfrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 16,780 gal Proppant Laden Fluid Volume: 34,357 gal Spacer and Ball drop Volume: 472 gal Interval Status: Completed Comments 0 bbls 1,229 bbls 0 bbls 0 bb/s 400 bbls 818 bbls 11 bbls Ball Audio passing through the iron was heard. Shut in the castle during the 4ppg stage, in order to Engineer: Keegan Lambe clear out the hopper. Had a pump derate during the 4ppg stage. Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer- Adam Klem rcppa t is hilled cfi of grt Ca,rc ,� Va . shgh: 11 r .;n. ih. n.r"er. Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 18 CD5-26 - A -Sand - Interval 11 Interval Summary Start Date/Time: 12/16/19 14:40 End Date/Time: 12/16/19 15:17 Pump Time: 37 min Initial Rate (Breakdown): 12.6 bpm Initial Surface Pressure (Breakdown): 6,074 psi Initial BH Pressure (Breakdown): 8,537 psi Max Rate: 41.3 bpm Max Surface Pressure: 6,516 psi Max BH Pressure: 8,254 psi Average Rate: 34.3 bpm Average Missile Pressure: 5,084 psi Average Surface Pressure: 4,907 psi Average BH Pressure: 7,168 psi Average Missile HHP: 4,279 hhp Initial OA Pressure: 370 psi Max OA Pressure: 409 psi Max Proppant Concentration: 4.40 PP9 Average Visc: 19 cp Average Temp: 88 F Average pH: 9.62 Proppant Summary Wanli 20/40 Pumped: 71,612 lbs Total Proppant Pumped' : 71,612 lbs Proppant in Formation: 71,612 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 50,471 gal 1,202 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 16,761 gal 399 bbls Proppant Laden Fluid Volume: 32,969 gal 785 bbls Spacer and Ball drop Volume: 741 gal 18 bbls Interval Status: Completed Comments: Ball Audio passing through the iron was heard. During the 4ppg stage, a suction side hose on one Engineer: Keegan Lambe of the pumps had a hole. The blender had a small bobble in suction causing proppant concentration Treater: Josh Caprio to spike. Supervisor: Josh Caprio Customer Engineer: Adam Klem r,.arf is r i. ,j .;' M€ 'nnd ms r r „ "q'-:'yti ere ihis un,t -,r_ Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 19 CD5-26 - A -Sand - Interval 12 Interval Summary Start Date/Time: 12/16/19 15:17 End Date/Time: 12/16/19 15:53 Pump Time: 36 min Initial Rate (Breakdown): 12.4 bpm Initial Surface Pressure (Breakdown): 6,041 psi Initial BH Pressure (Breakdown): 8,552 psi Max Rate: 42.2 bpm Max Surface Pressure: 6,475 psi Max BH Pressure: 8,045 psi Average Rate: 38.8 bpm Average Missile Pressure: 5,271 psi Average Surface Pressure: 5,089 psi Average BH Pressure: 7,218 psi Average Missile HHP: 5,016 hhp Initial OA Pressure: 365 psi Max OA Pressure: 391 psi Max Proppant Concentration: 4.30 PP9 Average Visc: 18 cp Average Temp: 89 F Average pH: 9.6 Proppant Summary Wanli 20/40 Pumped: 72,597 lbs Total Proppant Pumped* : 72,597 lbs Proppant in Formation: 72,597 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 52,978 gal 1,261 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bb/s Fluid Summary (by stage description) Pad Volume: 16,839 gal 401 bbls Proppant Laden Fluid Volume: 33,871 gal 806 bbls Spacer and Ball drop Volume: 2,268 gal 54 bbls Interval Status: Completed Comments Ball Audio passing through the iron was heard. Interval pumped to design Engineer: Keegan Lambe Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer: Adam Klem Customer Rep: Mike Hazen Conoco Phillips Alaska - CDS-26 Interval Summary 20 CD5-26 - A -Sand - Interval 13 Interval Summary Start Date/Time: 12/16/19 15:53 End Date/Time: 12/16/19 16:32 72,021 Pump Time: 39 min Initial Rate (Breakdown): 12.4 bpm Initial Surface Pressure (Breakdown): 6,130 psi Initial BH Pressure (Breakdown): 8,501 psi Max Rate: 43.7 bpm Max Surface Pressure: 6,146 psi Max BH Pressure: 7,281 psi Average Rate: 32.8 bpm Average Missile Pressure: 4,226 psi Average Surface Pressure: 4,034 psi Average BH Pressure: 6,585 psi Average Missile HHP: 3,395 hhp Initial OA Pressure: 377 psi Max OA Pressure: 398 psi Max Proppant Concentration: 4.38 ppg Average Visc: 17 cp Average Temp: 93 F Average pH: 9.5 23 Interval Status: Completed was heard. Lost a pump due to a hose leak stage at 35bpm. (ya t it „pled Of of "e ght 'cv wi e r , na. Thi wit; r. ppg. Engineer: Keegan Lambe Treater' Josh Caprio Supervisor: Josh Caprio Customer Engineer. Adam Klem Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 21 Proppant Summary Wanli 20/40 Pumped: 72,021 lbs Total Proppant Pumped* : 72,021 lbs Proppant in Formation: 72,021 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 50,254 gal 1,197 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 16,808 gal 400 bbls Proppant Laden Fluid Volume: 32,485 gal 773 bbls Spacer and Ball drop Volume: 961 gal 23 bb/s Interval Status: Completed was heard. Lost a pump due to a hose leak stage at 35bpm. (ya t it „pled Of of "e ght 'cv wi e r , na. Thi wit; r. ppg. Engineer: Keegan Lambe Treater' Josh Caprio Supervisor: Josh Caprio Customer Engineer. Adam Klem Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 21 CD5-26 - A -Sand - Interval 14 Interval Summary Start Date/Time: 12/16/19 16:32 End Date/Time: 12/16/19 17:11 Pump Time: 39 min Initial Rate (Breakdown): 12.4 bpm Initial Surface Pressure (Breakdown): 5,857 psi Initial BH Pressure (Breakdown): 8,504 psi Max Rate: 35.0 bpm Max Surface Pressure: 4,461 psi Max BH Pressure: 6,639 psi Average Rate: 33.2 bpm Average Missile Pressure: 4,080 psi Average Surface Pressure: 3,888 psi Average BH Pressure: 6,363 psi Average Missile HHP: 3,316 hhp Initial OA Pressure: 377 psi Max OA Pressure: 405 psi Max Proppant Concentration: 4.17 PP9 Average Visc: 16 cp Average Temp: 91 F Average pH: 9.46 ISDP: 5090 psi Final Fracture Gradient: 0.650 psi/ft Final 5 min: 5064 psi Final 10 min: 5047 psi Final 15 min: 5013 psi Proppant Summary Wanli 20/40 Pumped: 72,328 lbs Total Proppant Pumped' : 72,328 lbs Proppant in Formation: 72,328 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 50,219 gal 1,196 bbls 25# Waterfrac G Volume: 14,407 gal 343 bbls Freeze Protect Volume: 1,648 gal 39 bbls Fluid Summary (by stage description) Pad Volume: 16,769 gal 399 bbls Proppant Laden Fluid Volume: 33,450 gal 796 bbls Flush Volume: 14,407 gal 343 bbls Freeze Protect Volume: 1,648 gal 39 bbls Interval Status: Completed Ball Audio passing through the iron was heard. During 4ppg one of the pumps had an internal Engineer: Keegan Lambe issue. Continued to pump until the well was flushed. Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer: Adam Klem Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 22 CD5-26 - A -Sand - Interval 15 Interval Summary Start Date/Time: 12/18/19 12:40 End Date/Time: 12/18/19 13:32 Pump Time: 52 min Initial Rate (Breakdown): 12.8 bpm Initial Surface Pressure (Breakdown): 5,816 psi Initial BH Pressure (Breakdown): 8,069 psi Max Rate: 42.4 bpm Max Surface Pressure: 5,837 psi Max BH Pressure: 7,676 psi Average Rate: 32.6 bpm Average Missile Pressure: 4,379 psi Average Surface Pressure: 4,386 psi Average BH Pressure: 6,441 psi Average Missile HHP: 3,497 hhp Initial OA Pressure: 259 psi Max OA Pressure: 347 psi Max Proppant Concentration: 3.72 PP9 Average Visc: 19 cp Average Temp: 88 F Average pH: 9.54 Proppant Summary Wanli 20/40 Pumped: 66,434 lbs Total Proppant Pumped' : 66,434 lbs Proppant in Formation: 66,434 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 52,110 gal 1,241 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 16,767 gal 399 bbls Proppant Laden Fluid Volume: 32,779 gal 780 bb/s Spacer and Ball drop Volume: 1,307 gal 31 bbls Interval Status: Completed II Audio was heard. Noticed in 3ppg and 4ppg proppant that the proppant concentration was not ;ponding. Ice chunks were noted by the hopper operator. Attempted to close the Castle but due a broken weld the bin could not be closed until emptied. , < ,n f ( , c .v,:) < ca c., i,lo, s o" ,,ObpIE. . '. ss k, a orf di 7Fl ?i,. clttt� and nilly ry shy t i, i^ ". ,, .•mbar. Engineer: Keegan Lambe Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer: Adam Klem Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 23 CD5-26 - A -Sand - Interval 16 Interval Summary Start Date/Time: 12/18/19 13:32 End Date/Time: 12/18/19 14:05 Pump Time: 33 min Initial Rate (Breakdown): 12.5 bpm Initial Surface Pressure (Breakdown): 6,134 psi Initial BH Pressure (Breakdown): 8,446 psi Max Rate: 47.3 bpm Max Surface Pressure: 6,647 psi Max BH Pressure: 7,181 psi Average Rate: 39.2 bpm Average Missile Pressure: 5,304 psi Average Surface Pressure: 5,288 psi Average BH Pressure: 6,855 psi Average Missile HHP: 5,091 hhp Initial OA Pressure: 342 psi Max OA Pressure: 349 psi Max Proppant Concentration: 3.59 PP9 Average Visc: 22 cp Average Temp: 89 F Average pH: 9.52 Proppant Summary Wanli 20/40 Pumped: 63,220 lbs Total Proppant Pumped' : 63,220 lbs Proppant in Formation: 63,220 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 50,402 gal 1,200 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 16,818 gal 400 bbls Proppant Laden Fluid Volume: 32,715 gal 779 bbls Spacer and Ball drop Volume: 869 gal 21 bbls Interval Status: Completed Comments Ball Audio was heard. Proppant struggled to get to full concentration due to blockages in the Engineer' Keegan Lambe hopper. Treater: Josh Caprio Supervisor: Josh Caprio .lit; l ",;i ! n Customer Engineer: Adam Klem ara,:i_-i r�,7 Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 24 CD5-26 - A -Sand - Interval 17 Interval Summary Start Date/Time: 12/18/19 14:05 End Date/Time: 12/18/19 14:40 Pump Time: 35 min Initial Rate (Breakdown): 12.6 bpm Initial Surface Pressure (Breakdown): 6,216 psi Initial BH Pressure (Breakdown): 8,598 psi Max Rate: 47.4 bpm Max Surface Pressure: 5,852 psi Max BH Pressure: 6,956 psi Average Rate: 36.5 bpm Average Missile Pressure: 4,672 psi Average Surface Pressure: 4,634 psi Average BH Pressure: 6,412 psi Average Missile HHP: 4,176 hhp Initial OA Pressure: 342 psi Max OA Pressure: 359 psi Max Proppant Concentration: 3.74 PP9 Average Visc: 24 cp Average Temp: 89 F Average pH: 9,3 Proppant Summary Wanli 20/40 Pumped: 67,222 lbs Total Proppant Pumped* : 67,222 lbs Proppant in Formation: 67,222 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 25# Hybor G Volume: 50,100 gal 25# Waterfrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 16,750 gal Proppant Laden Fluid Volume: 32,460 gal Spacer and Ball drop Volume: 890 gal Interval Status: Completed mments: I Audio was heard. Proppant struggled to get to full concentration due to blockages in the iper. The castle was light enough that the castle was shut in and the hopper cleaned up. One of pumps kicked during 2ppg proppant due to a preload. The pump did not come back to full rate. pped rate off the pump and let it clean up. 0 bbls 1,193 bbls 0 bbls 0 bbls 399 bbls 773 bbls 21 bbls Engineer: Keegan Lambe Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer: Adam Klem Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 25 CD5-26 - A -Sand - Interval 18 Interval Summary Start Date/Time: 12/18/19 14:40 End Date/Time: 12/18/19 15:20 Pump Time: 40 min Initial Rate (Breakdown): 12,2 bpm Initial Surface Pressure (Breakdown): 5,857 psi Initial BH Pressure (Breakdown): 8,348 psi Max Rate: 46.1 bpm Max Surface Pressure: 5,510 psi Max BH Pressure: 6,759 psi Average Rate: 33.6 bpm Average Missile Pressure: 4,065 psi Average Surface Pressure: 4,011 psi Average BH Pressure: 6,087 psi Average Missile HHP: 3,351 hhp Initial OA Pressure: 351 psi Max OA Pressure: 372 psi Max Proppant Concentration. 3.95 Ppg Average Visc: 17 cp Average Temp: 87 F Average pH: 9.42 Proppant Summary Wanli 20/40 Pumped: 61,811 lbs Total Proppant Pumped' : 61,811 lbs Proppant in Formation: 61,811 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 25# Hybor G Volume: 53,593 gal 25# Waterfrac G Volume: 0 gal Freeze Protect Volume: 0 gal Fluid Summary (by stage description) Pad Volume: 16,767 gal Proppant Laden Fluid Volume: 36,063 gal Spacer and Ball drop Volume: 763 gal Interval Status: Cut Short Comments: Ball Audio was heard. Lost the blender tub after grabbing rate from the ball drop due to suction, Lost it again during 3ppg due to tanks equalizing and multiple tanks emptying at the same time. Cut screws to prevent slugging proppant. Stepped back into 4ppg proppant in 15bbl steps up to 4ppg . Extended 4ppg out to make up some of the proppant cut from the 3ppg. _3l .0 fo ,,�d.nt _ t �� r'i ° �r ;,_..ter . 3t ,_:.'.i , ,�i4,--.�; c ri_i t arras Pti,4 rear i�gr , ��u� J1 unib, 0 bbls 1,276 bbls 0 bbls 0 bbls 399 bbls 859 bbls 18 bb/s Engineer: Keegan Lambe Treater., Josh Caprio Supervisor: Josh Caprin Customer Engineer: Adam Klem Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 26 CD5-26 - A -Sand - Interval 19 Interval Summary Start Date/Time: 12/18/19 15:20 End Date/Time: 12/18/19 15:47 Pump Time: 27 min Initial Rate (Breakdown): 12.6 bpm Initial Surface Pressure (Breakdown): 5,800 psi Initial BH Pressure (Breakdown): 8,391 psi Max Rate: 42.3 bpm Max Surface Pressure: 6,131 psi Max BH Pressure: 7,194 psi Average Rate: 36.6 bpm Average Missile Pressure: 4,571 psi Average Surface Pressure: 4,503 psi Average BH Pressure: 6,267 psi Average Missile HHP: 4,099 hhp Initial OA Pressure: 356 psi Max OA Pressure: 367 psi Max Proppant Concentration: 5.82 Ppg Average Visc: 18 cP Average Temp: 88 F Average pH: 9.33 Proppant Summary Wanli 20/40 Pumped: 88,089 lbs Total Proppant Pumped* : 88,089 lbs Proppant in Formation: 88,089 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 39,015 gal 929 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,631 gal 301 bbls Proppant Laden Fluid Volume: 25,562 gal 609 bbls Spacer and Ball drop Volume: 822 gal 20 bbls Interval Status: Completed Comments Ball Audio was heard. Proppant pumped to design Engineer: Keegan Lambe Treater: Josh Caprio Supervisor: Josh Caprio Customer Engineer g Adam Klem Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 27 CD5-26 - A -Sand - Interval 20 Interval Summary Start Date/Time: 12/18/19 15:47 End Date/Time. 12/18/19 16:16 Pump Time: 29 min Initial Rate (Breakdown): 12.6 bpm Initial Surface Pressure (Breakdown): 6,108 psi Initial BH Pressure (Breakdown): 8,806 psi Max Rate: 41.3 bpm Max Surface Pressure: 4,921 psi Max BH Pressure: 6,524 psi Average Rate: 35.3 bpm Average Missile Pressure: 4,138 psi Average Surface Pressure: 4,056 psi Average BH Pressure: 5,965 psi Average Missile HHP: 3,582 hhp Initial OA Pressure: 342 psi Max OA Pressure: 358 psi Max Proppant Concentration: 5.81 pp9 Average Visc: 18 cP Average Temp: 86 F Average pH: 9.4 Proppant Summary Wanli 20/40 Pumped: 85,700 lbs Total Proppant Pumped` : 85,700 lbs Proppant in Formation: 85,700 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 38,613 gal 919 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,623 gal 301 bbls Proppant Laden Fluid Volume: 25,290 gal 602 bbls Spacer and Ball drop Volume: 700 gal 17 bbls Freeze Protect Volume: 0 gal 0 bbls Interval Status: Completed Comments Ball Audio heard. Lost suction on the ADP and the blender during 5ppg due to tank swaps. Engineer: Keegan Lambe Treater: Josh Caprio Supervisor: Josh Caprio i s�c pam a ,tom'. n from , , ,.. _ _ _�+. n �) ts: u n n, , ! r: Customer Engineer: Adam Klem ,,,t., &,. ;, t, ed cff, Oi v, ht C= kc . 1j,I' OS "Md "'I'TY V,PY S . , 'N , t.rr.bei Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 28 CD5-26 - A -Sand - Interval 21 Interval Summary Start Date/Time: 12/18/19 16:16 End Date/Time: 12/18/19 16:46 Pump Time: 30 min Initial Rate (Breakdown): 12.6 bpm Initial Surface Pressure (Breakdown): 5,775 psi Initial BH Pressure (Breakdown): 8,315 psi Max Rate: 37.2 bpm Max Surface Pressure: 4,122 psi Max BH Pressure: 6,099 psi Average Rate: 33.2 bpm Average Missile Pressure: 3,433 psi Average Surface Pressure: 3,342 psi Average BH Pressure: 5,621 psi Average Missile HHP: 2,795 hhp Initial OA Pressure: 348 psi Max OA Pressure: 370 psi Max Proppant Concentration: 5.49 pP9 Average Visc: 18 cp Average Temp: 88 F Average pH: 9.38 Proppant Summary Wanli 20/40 Pumped: 85,125 lbs Total Proppant Pumped* : 85,125 lbs Proppant in Formation: 85,125 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 0 bbls 25# Hybor G Volume: 38,539 gal 918 bbls 25# Waterfrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 12,601 gal 300 bbls Proppant Laden Fluid Volume: 25,184 gal 600 bbls Spacer Volume: 0 gal 0 bbls Flush Volume: 0 gal 0 bbls Shut -In Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Spacer and Ball drop Volume: 754 gal 18 bbls Freeze Protect Volume: 0 gal 0 bbls Interval Status: Completed Ball audio was heard. Proppant struggled to get to full concentration due to blockages in the Engineer: Keegan Lambe hopper. Treater: Josh Caprio Supervisor: Josh Caprio 'Values `:or proppant are taken from softWara calculations based on multiple variables. Customer Engineer. Adam Klem Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 29 CD5-26 - A -Sand - Interval 22 Interval Summary Start Date[Time: 12/18/19 16:46 End Date/Time: 12/18/19 17:17 Pump Time: 31 min Initial Rate (Breakdown): 12.8 bpm Initial Surface Pressure (Breakdown): 5,843 psi Initial BH Pressure (Breakdown): 8,260 psi Max Rate: 40.3 bpm Max Surface Pressure: 4,749 psi Max BH Pressure: 6,165 psi Average Rate: 35.2 bpm Average Missile Pressure: 3,426 psi Average Surface Pressure: 3,335 psi Average BH Pressure: 5,564 psi Average Missile HHP: 2,953 hhp Initial OA Pressure: 363 psi Max OA Pressure: 383 psi Max Proppant Concentration: 6.57 ppg Average Visc: 21 cp Average Temp: 88 F Average pH: 9.4 ISDP: 5095 psi Final Fracture Gradient: 0.657 Psi/ft Final 5 min: 5039 psi Final 10 min: 5024 psi Proppant Summary Wanli 20/40 Pumped: 103,896 lbs Total Proppant Pumped* : 103,896 lbs Proppant in Formation: 103,896 lbs Fluid Summary (by fluid description) Seawater Volume: 0 gal 25# Hybor G Volume: 40,006 gal 25# Waterfrac G Volume: 9,981 gal Freeze Protect Volume: 1,050 gal Fluid Summary (by stage description) Pad Volume: 11,960 gal Proppant Laden Fluid Volume. 28,046 gal Flush Volume: 9,981 gal Freeze Protect Volume: 1,050 gal Interval Status: Completed Comments 0 bbls 953 bbls 238 bbls 25 bbls 285 bbls 668 bbls 238 bbls 25 bbls Ball audio was heard. Proppant struggled to get to full concentration due to blockages in the Engineer: Keegan Lambe hopper. Adjusted screws to compensate. Pumped the extra proppant cut from interval 18 in the Treater: Josh Caprio 6ppg stage. Little Red pumped the freeze protect down the well. Supervisor: Josh Caprin ✓, :,r„ <�.; ,..��. r., .z. r ,. wedcn dtplr. Customer Engineer: Adam Kern r.,pp, l,t i_ b .. -;' w;,Ium rqr t-_> i, ribHr. Customer Rep: Mike Hazen Conoco Phillips Alaska - CD5-26 Interval Summary 30 Curtomer Conoco Phillips Alaska Formation A -Sand lease CDS-26 All 50-103-20806 Date December 14, 2019 Well Summary ISeawater HALLIBURTON erhn�znmw _ IN Fluids Proppants Interval Average Max ISeawater 25# Hybar G 25# Waterfrac G Freeze Protect Total Fluid Wanli 20/40 Total Proppant Missile Pressure Rate Visc Temp pH PPG Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs 1 4976 21.1 24 86 9.5 #N/A 30.6 9,475 226 59,483 1,416 68,958 1,642 64,099 64,099 2 4234 16.3 23 88 9.4 #N/A 31.0 30,061 716 30,061 716 4,617 4,617 3 5296 28.4 17 90 9.6 #N/A 35.3 63,650 1,515 63,650 1,515 68,097 68,097 4 3878 20.9 19 90 9.5 #N/A 31.1 42,211 1,005 21,382 509 63,593 1,514 67,576 67,576 5 5342 29.3 19 90 9.6 #N/A 33.8 54,755 1,304 54,755 1,304 72,250 72,250 6 3356 12.1 19 86 9.6 #N/A 32.0 66,327 1,579 37,468 892 1,904 45 105,699 2,517 10,951 10,951 7 4550 26.2 22 88 9.7 #N/A 34.8 51,613 1,229 51,613 1,229 70,851 70,851 8 5126 32.2 18 92 9.5 #N/A 39.0 49,786 1,185 49,786 1,195 686126 68,126 9 5209 33.9 18 91 9.5 #N/A 39.3 50,715 1,208 50,715 1,208 70,569 70,569 10 5328 3" 20 89 9.4 #N/A 41.0 51,609 1,229 51,609 1,229 70,743 70,743 11 5084 34.3 19 88 9.6 #N/A 41.3 50,471 1,202 50,471 1,202 71,612 71,612 12 5271 US 18 89 9.6 #N/A 42.2 52,978 1,261 52,973 1,261 72,597 72,597 13 4226 32.8 17 93 9.5 #N/A 43.7 50,254 1,197 50,254 1,197 72,021 72,021 14 4080 33.2 16 91 9.5 #N/A 35.0 90,219 1,196 14,407 343 1,648 39 66,274 1,578 72,328 72,328 15 4379 32.6 19 88 9.5 #N/A 42.4 52,110 1,241 52,110 1,241 66,434 66,434 16 5304 39.2 22 89 9.5 #N/A 47.3 $0,402 1,200 50,402 1,200 63,220 _63,220 17 4672 36.5 24 89 9.3 #N/A47.4 50,100 1,193 50,100 1,193 67,222 67,222 18 4065 33.6 37 87 9.4 #N/A 46.1 53,593 1,276 53,593 1,276 61,811 61,311 19 4571 36.6 18 88 9.3 #N/A 42.3 39,015 929 39,015 929 88,089 88,089 20 4138 35.3 I8 86 9.4 #N/A 41.3 38,613 919 38,613 919 85,700 $5,700 21 3433 33.2 18 88 9.4 #N/A 37.2 38,539 918 38,539 918 85,125 85,125 22 3426 35.2 21 88 9,4 #N/A 40.3 40,006 953 9,981 238 1,050 25 51,037 1,215 103,896 103,896 Minimum 9475 226 30061 716 9961 238 1050 25 30061 716 4617 4617 Average 9475 226 49387 1176 20810 495 1534 37 53810 1281 67179 67179 Maximum 9475 226 66327 1579 37468 892 1904 45 105699 2517 103896 103896 IN WE numbers for proppant are taken from software Proppant is billed from Weight Ticket volumes Conoco Phillips Alaska - CD5-26 Fluid System-Proppant Summary Weight Tml WE numbers for proppant are taken from software Proppant is billed from Weight Ticket volumes Conoco Phillips Alaska - CD5-26 Fluid System-Proppant Summary Pressure Test - 12-13-2019 Treating Pressure (psi) Treating Pressure @Pump (psi) 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 10000 9000 8000 7000 6000 5000 4000 3000 2000 1000 0 17:00 17:10 17:20 17:30 17:40 12/13/2019 Time 12/13/2019 Global Event Log 34 PressureTest- Globals 16:56:00 135 PressureTest- Locals 16:56:26 36 Pressure Test- Ground Valve 16:57:20 37 Bleed down to check pumps 17:07:45 38 Test Second Ground Valve 17:10:56 '39 reprime pumps 17:18:30 40, Pressure Test -Max Pressure 17:37:09 4 Pressure Test- Good Test 17:40:27 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS I Job Date: 10 -Dec -2019 Sales Order* 0906160385 Well Description: CD5 26 LIM 50-103-20806 Conoco Phillips Alaska-CD5-26 Interval l Plots 32 Pressure Test - 12-14-2019 Treating Pressure (psi) Treating Pressure @Pump (psi) - 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 10000 9000 8000 7000 6000 5000 4000 3000 2000 1000 0 08:20 08:25 08:30 08:35 12/14/2019 Time 12/14/2019 1 Global Event Log 41 Pressure Test- Globals 08:19:03 5 Pressure Test- Locals 08:20:43 -6-5 Pressure Test- Max 08:25:06 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska-CD5-26 Interval 1 Plots 33 Nitrogen Pop -Off Test - Initial Test Treating Pressure (psi) Treating Pressure @Pump (psi) i 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 10000 ----- - ---- -- - 9000 8000 7000 6000 5000 4000 3000 2000 1000 0 17:55 18:00 18:05 18:10 18:15 12/13/2019 Time 12/13/2019 Global Event Log Intersection TPP Intersection TPP 42, N2 Pop Off -14F 17:51:34 54.22 '43 N2 Test Pap @ 7221 psi 17:53:55 7221 44 N2 Test Pop @ 7212psi 17:59:23 7212 46,, N2 Test Pop @ 7137psi 18:03:19 7137 40 N2 Test Pop @ 7532psi 18:07:16 7534 47 N2 Test Pop @ 7620psi 18:10:38 7628 4&, N2 Test Pop @ 7764psi 18:13:37 7764 49 N2 Test Pop @ 7781 psi 18:16:14 7781 50 Good Tests Bleed Down. 18:17:28 41.20 Customer: CONOCORIILLIPS NORTH SLOPE - EBUS Job Date: 10 -Dec -2019 f Sales Order #: 0906160385 Well Description: C05 26 LWI: 50-103-20806 Conoco Phillips Alaska-CD5-26 Interval 1 Plots 34 Blender Chemical Plot - Bucket Tests Day 1 131 CL -31 Conc -LA1 (gal/Mgal) — A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B 111 B 2.5- 2.0 1.5 0.5 onus 05:56 05:58 06:00 06:02 06:04 06:06 06:08 06:10 12/14/2019 Time 12/14/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 """'� Well Description: CD5 26 UWI: 50-103-20806 61 4 3 2 1 U Conoco Phill ips Alaska-CD5-26 Interval 1 Plots 35 ADP Chemical Plot - Bucket Tests Day 1 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B 2.0 — --- ----- 1.8 �,00 90 1.6 80 1.4 70 1.2 60 1.0 50 0.8 40 0.6 30 0.4 20 0.2 10 0.0 0 06:44:30 06:45:00 06:45:30 06:46:00 06:46:30 06:47:00 12/14/2019 Time 12/14/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBIJS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 —..-, a Conoco Phillips Alaska - CDS-26 Interval 1 Plots 36 Treatment Plot - Treatment 01 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conc (Ib/gal) C BH Proppant Conic (Ib/gal) A B Gauge BH Pres (psi) A Actual BH Temp (°F) - 10000 100-J - - 9000 90 8000 80 7000 70- 6000 60 5000 50 4000 40 3000- 30 2000 20- 1000- 10- 0 0 t� C D C D ,0 500 400 300 -200 L100 09:20 09:40 10:00 10:20 10:40 12/14/2019 12/14/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD526 UWI: 50-103-20806 J Conoco Phillips Alaska - CD5-26 Interval 1 Plots 37 Blender Chemical Plot - Interval 01 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Cone -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B 09:20 09:40 10:00 10:20 10:40 11:00 12/14/2019 12/14/2019 Time Custorner: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 _ _ UWI: 50-103-20806 B 6 W 4 3 2 1 I Conoco Phillips Alaska - CD5-26 Int—al 1 Plots 38 ADP Chemical Plot - Interval 01 A B2 2.0 Losurf-300D Conc -LA2 (gal/Mgal) A --- B2 WG -36 Conc -DA1 (ib/Mgal) B B - — 100 - 1.8- 90 1.6 80 1.4 70 1.2 60 1.0 w 04&1m50 0.8 40 0.6 30 0.4 20 0.2- ` 10 0.0 L 0 09:20 09:40 10:00 10:20 10:40 12/14/2019 Time 12/14/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS i Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UNI: 50-103-20806 Conoco Phillips Alaska-CD5-26 Interval 1 Plots 39 Treatment Plot - Treatment 02 10:40 10:50 11:00 11:10 11:20 11:30 12/14/2019 12/14/2019 Time Customer. CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14-Dec-2019Sales Order #: 09061603851 Well Description: CD5 26 UWI: 50-103-20806 1- Conoco Phillips Alaska -CD5-26 Interval 2 Plots 40 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp (°F) D C D 10000 100 - 10 500 9000 90 9 8000 1 80 8 400 7000 70 7 6000 60 6 300 5000 50- 5 4000 40 4 200 3000- 30 3 2000 20 2 100 1000 10 1 0 0 --- 0 -0 10:40 10:50 11:00 11:10 11:20 11:30 12/14/2019 12/14/2019 Time Customer. CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14-Dec-2019Sales Order #: 09061603851 Well Description: CD5 26 UWI: 50-103-20806 1- Conoco Phillips Alaska -CD5-26 Interval 2 Plots 40 Blender Chemical Plot - Interval 02 81 CL -31 Conc -LA1 (gal/Mgal) --- t, B1 CL -22 UC Conc -LA2 (gal/Mgal) A A I B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 3.0 1 IN 11 1 ■ 1 - -- -7 6 2 2 F 10:40 10:50 11:00 11:10 11:20 11:30 12/14/2019 Time 12/14/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 t Sales Order #: 0906160385 Well Description: CD5 26 LIM 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 2 Plots 41 ADP Chemical Plot - Interval 02 A "` Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B 2.0 - — - - -----1 11111 In r Vrrri rr — r 100 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0. 90 80 70 60 50 40 30 20 10 0 � I I s—I I ",-M rr 1 0 10:30 10:40 10:50 11:00 11:10 11:20 11:30 12/14/2019 Time 12/14/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - ESUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 LIM 50-103-20806 Conoco Phillips Alaska-CD5-26 Interval Plots 42 Treatment Plot - Treatment 03 Conoco Phillips Alaska - CD5-26 Interval 3 Plots 43 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (ib/gal) C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp (°F) D C D 10000 100 - ---- — 10 500 9000 90 9 8000 80 8 400 7000 70 7 I 6000 60 6 300 5000 50 5 4000 40 4 200 3000 30- 3 2000 20 --2 100 1000 10 1 0 0 - 0 0 11:20 1 1:40 12:00 12:20 12/14/2019 12/14/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 j Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 3 Plots 43 Blender Chemical Plot - Interval 03 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 3.0 2.5 2.0 1.5 1.0 0.5 0.0 1120 12/14/2019 11:30 11:40 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Well Description: CD5 26 11:50 12:00 Time Job Date: 14 -Dec -2019 UWI: 50-103-20806 12:10 12:20 12:30 12/14/2019 Sales Order#: 0906160385 Conoco Phillips Alaska-CD5-26 Interval 3 Plots 44 i ADP Chemical Plot - Interval 03 AB2 Losurf--300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (ib/Mgal) B 2.0 - - -- - - ,-- 100 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 02 0.0 11:20 11:30 11:40 11:50 12:00 12:10 12:20 12:30 12/14/2019 Time 12/14/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 l Sales Order #: 0906160385 Well Description: CD5 26 LW: 50-103-20806 f Conoco Phillips Alaska - CD5-26 Interval 3 Plots 45 Treatment Plot - Treatment 04 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conc (lb/gal) C BH Proppant Conc (Ib/gal) A B Gauge BH Pres (psi) A Actual BH Temp (°F) 10000 100 9000 90 8000 80 7000 70 6000- 60 5000 � 50 4000 � 40 3000 30 2000 20 1000 10 0 0 C D C D "0 500 12:20 12:40 13:00 13:20 13:40 12/14/2019 12/14/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 1 Sales Order #: 0906160385 w..., Well Description: CD5 26 UWI: 50-103-20806 1 400 300 200 100 M Conoco Phillips Alaska - CD5-26 Interval Plots 46 Blender Chemical Plot - Interval 04 A �B1 CL -31 Conc -LA1 (gal/Mgal) – — A B1 CL -22 UC Conc -LA2 (gal/Mgal) 1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) 3.0 - 2.5 2.0 1.5 1Ni7 0.5 w A B B 6 12:20 12:40 13:00 13:20 13:40 12/14/2019 Time 12/14/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 5 4 3 2 1 7 Conoco Phillips Alaska -CDS-26 Interval 4 Plats 47 ADP Chemical Plot - Interval 04 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) 2.0 -- -- — — 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 12:20 12:40 13:00 13:20 13:40 12/14/2019 12/14/2019 Time Customer: CONOOOPHILLIPS NORTH SLOPE- EBUS Jab Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska -CDS-26 Inte—I4 Plots 48 Treatment Plot - Treatment 05 Conoco Phillips Alaska -CDS-26 Interval Plots 49 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Ackal BH Tema (`F) ---- - F C D 10000 100 _ - -- --- 10 500 9000 90 9 8000 80 8 400 7000 70 7 6000 60 6 300 5000 50 5 4000 40 4 200 3000 30 1 3 2000 20 __._._...___.___ _ __.____ ....____-- .- ------_.-___.__ __. 2 100 1000 10 0 -1 13:40 14:00 14:20 14:40 12/14/2019 12/14/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD526 UWI: 50-103-20806 Conoco Phillips Alaska -CDS-26 Interval Plots 49 Blender Chemical Plot - Interval 05 9 CL 31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 3.0 2.5 2.0 1.5 1.0 0.5 1M 13:40 13:50 14:00 14:10 14:20 14:30 v 12/14/2019 Time 12/14/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UVA 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 5 Plots 50 ADP Chemical Plot - Interval 05 A LB2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) 2.0 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 13:30 13:40 13:50 14:00 14:10 12/14/2019 Time Oustorner: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska-CD5-26 Intervals Plots 14:20 14:30 12/14/2019 Sales Order #: 0906160385 """' Treatment Plot - Treatment 06 Conoco Phillips Alaska - CD5-26 Interval 6 Plots 52 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp ("F) D C D 10000 100 -- - — --- -- _ - - — 10 500 - 9000 90 9 8000 80 8 400 7000 70 7 6000 60 6 300 5000 50 5 4000 40 4 -200 3000 30 ,' 3 2000 20 2 100 1000 10 • -1 0 0 0 -0 14:30 15:00 15:30 16:00 16:30 17:00 17:30 18:00 12/14/2019 12/14/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 Sales Order#: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 6 Plots 52 A 3. 2. 2. im lei M Blender Chemical Plot - Interval 06 B1 CL -31 Conc -LA1 (gaUMgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A B1 MO -67 Conc -LA5 (gaUMgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 14:20 14:30 14:40 14:50 15:00 15:10 12/14/2019 12/14/2019 Time Customer CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: C05 26 UWI: 50-103-20806 Conoco Phillips Alaska-CD5-26 Int—al6 Plots 53 A 3.0- 2.5 - MI 1.5- 1.0 0.5 M Blender Chemical Plot - Interval 06.1 (91 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC ConcLA2 (gal/Mgal) A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B I 16:40 16:50 17:00 17:10 17:20 17:30 17:40 17:50 12/14/2019 Time 12/14/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 -- Well Description: CD5 26 LANE 50-103-20806 B -6 R 4 -3 2 1 Conoco Phillips Alaska - CD5-26 Interval 6 Plots 54 ADP Chemical Plot - Interval 06 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B ' B 100 14:25 14:30 14:35 14:40 14:45 14:50 14:55 15:00 12/14/2019 Time 12/14/2019 -- - Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 14 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 M11. 50-103-20806 90 80 70 60 50 40 30 20 10 0 Conoco Phillips Alaska - CD5-26 Interval 6 Plots 55 ADP Chemical Plot - Interval 06.1 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B 2.0- -100 - 1.8 -90 1.6 -80 1.4 -70 1.2 60 1.0 50 0.8 40 0.6 30 0.4 20 0.2 10 0.0 - 0 17:40 18:00 15:40 16:00 16:20 16:40 17:00 17:20 12/14/2019 Time 0906160385 12/14/2019 Qistomer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 14 -Dec -2019 Sales Order* Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 6 Plots 56 Pressure Test - 12-16-2019 Treating Pressure (psi) Treating Pressure @Pump (psi) 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 10:05 12/16/2019 10:10 10:15 Time Global Event Log 10:20 12/16/2019 01 Pressure Test- Globals 10:03:01 Little Red Bleed through 10:03:36 0 Pressure Test- Locals Ground Vale Equaliang 10:04:53 Checking Iron 10:06:25 Bleed -Off Little Red Pressure Test- Max 10:12:29 Pressure Test- Good Test 10:22:34 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Well Description: CD5 26 Job Date: 16 -Dec -2019- Sales Order #: 0906160385 - UWI: 50-103-20806 10:03:53 10:07:46 Conoco Phillips Alaska - CD5-26 Interval 7 Plots 57 Blender Chemical Plot - Bucket Tests Day 2 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 2.5 -5 l 2.0 1.5 1.0 0.5 11 06:20 06:22 06:24 06:26 06:28 06:30 12/16@019 Time 12/16/2019 Oustomer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 1:Sales Order #: 0906160385 Well Description: CD5 26 LIWI: 50-103-20806 rd -3 2 1 0 Conoco Phillips Alaska - CDS-26 Interval 7 Plots 58 ADP Chemical Plot - Bucket Tests Day 2 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DAA (Ib/Mgal)— 2.0 --- - - 1.8- 1.6 1.4 1.2 B i B 100 -90 -80 -70 1.050 0.8 /1 ,I - �v,(�� 50 40 0.6 30 0.4 20 0.2 10 0.0 0 06:24:20 06:24:40 06:25:00 06:25:20 06:25:40 06:26:00 06:26:20 06:26:40 12/16/2019 Time 12/16/2019 Customer. CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD.5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 7 Plots 59 B C [� C D ^0 500 400 300 200 100 11:40 12:00 12:20 12:40 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 - U 50-103-20806 Conoco Phillips Alaska -CD5-26 Interval Plots 60. Treatment Plot - Treatment 07 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) A B Gauge BH Pres (psi) A Actual BH Temp ('F) 10000 100 - - - - 9000 90 8000 80 7000 70 6000 60 5000 50 4000 40 3000 30 2000 20 — -- 1000 10 • • 0 0 — —� B C [� C D ^0 500 400 300 200 100 11:40 12:00 12:20 12:40 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 - U 50-103-20806 Conoco Phillips Alaska -CD5-26 Interval Plots 60. Blender Chemical Plot - Interval 07 B1 CSL -31 Conc--LA i(gaUMg,l) -- — A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A 81 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 3.0 - 2.5 2.0 1.5 1.0 0.5 0.0 11:40 12/16/2019 11:50 12:00 12:10 12:20 12:30 12:40 Time 12/16/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Well Description: CD5 26 Job Date: 16 -Dec -2019 FSales Order #: 0906160385 UWI: 50-103-20806 Conoco Ph ill ips Alaska - CDS-26 Int -17 Plots 61 ADP Chemical Plot - Interval 07 A 82 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgai) — 2.0 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 11:40 11:50 12:00 12:10 12:20 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 16 -Dec -2019 Well Description: CD526 LWI: 50-103-20806 B B 100 90 80 70 60 50 40 30 20 10 0 12:30 12:40 12/16/2019 Sales Order #: 0906160385 Conoco Phillips Alaska - CD5-26 Interval 7 Plots 62 Treatment Plot - Treatment 08 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) A B Gauge BH Pres (psi) 10000 100 9000 90 !, 8000 80 7000 70 6000 60 5000 50 { 4000 40 3000 30- 2000- 20- 1000- 10 0 0, — -- rs C D C D 0 F500 12:30 12:40 12:50 13:00 13:10 13:20 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 ' Sales Order#: 090616038 -� Well Description: CD526 UWI: 50-103-20806 400 me 200 100 Conoco Phillips Alaska - CD5-26 Interval 8 Plots 63 A 2. 2. 3 M am 0.1 12:30 12:40 12:50 13:00 13:10 13:20 12/16/2019 12/16/2019 Time Blender Chemical Plot - Interval 08 131 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 LIC Conc -LA2 (gal/Mgal) A 61 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS I Job Date 16 -Dec -2019 I Sales Order #: 0906160385 Well Description: CD5 26 LIM 50-103-20806 Conoco Phillips Alaska - CDS-26 Interval 8 Plots 64 ADP Chemical Plot - Interval 08 A LB2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) 13] B 7 n 4" 1 1 1 1 1 0 0 0 0 0 12:30 12:40 12:50 13:00 13:10 13:20 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UNI: 50-103-20806 Conoco Phillips Alaska -CDS-26 Interval Plots 6S Treatment Plot - Treatment 09 Treating Pressure (psi) A Slurry Rate (bpm) E Slurry Proppant Conc (lb/gal) C BH Proppant Conc (Ib/gal) A B Gauge BH Pres (psi) A Actual BH Temp (°F) [ 10000 100 9000 90 8000 80 7000 70 6000 60 5000 50 4000 40 3000 30- 2000- 20- 1000- 10- 0 0 1!- C D '0 500 13:10 13:20 13:30 13:40 13:50 14:00 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 09061603851 Well Description: CD5 26 UWI: 50-103-20806 400 300 -200 100 0 Conoco Phillips Alaska -CD5-26 Interval Plots 66 Blender Chemical Plot - Interval 09 131 CL -31 Conc -LA1 (gal/Mgal)— — A B1 CL -22 UC Conc -LA2 (gal/Mgal)— A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) — 2.5 2.0 1.5 w7 0.5 0.0 13:10 13:20 13:30 13:40 12/16/2019 Time F&stomer: CONOCOPHILL IPS NORTH SLOPE- EB US Job Date: 16 -Dec -2019 Well Description: CD5 26 LIM 50-103-20806 A B B 13:50 14:00 12/1612019 Sales Order #: 0906160385 5 4 3 2 1 0 Conoco Phillips Alaska - CD5-26 Interval 9 Plots 67 ADP Chemical Plot - Interval 09 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) 2n 1. 1. 1. 1. 1. 0. 0. 0. 0.. 0. 13:10 13:20 13:30 13:40 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Well Description_ CD5 26 Lim: 50-103-20806 —81 B w00 0 0 0 0 0 0 0 0 0 13:50 14:00 12/16/2019 Sales Order #: 0906160385] """"'""' Conoco Phillips Alaska-CD5-26 Interval Plots 68 C D C D "0 500 13:50 14:00 14:10 14:20 14:30 14:40 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 I Sales Order#: 0906160385 w" Well Description: CD526 UWI: 50-103-20806 400 300 200 100 10 Conoco Phillips Alaska - CDS-26 I nterval 10 Plots 69 Treatment Plot -Treatment 10 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) A B Gauge BH Pres (psi) A Actual BH Temp (°F) - 10000 100 - 9000 90 8000 80 1 7000- 70 6000 60 5000 50 4000 40 3000 30- 2000 20_ 1000 10- 40 0 0 0 0 T- C D C D "0 500 13:50 14:00 14:10 14:20 14:30 14:40 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 I Sales Order#: 0906160385 w" Well Description: CD526 UWI: 50-103-20806 400 300 200 100 10 Conoco Phillips Alaska - CDS-26 I nterval 10 Plots 69 Blender Chemical Plot - Interval 10 B1 CL -31 Conic -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 3.0 2.5 2.0 1.5 ON 0.5 0.0 13:50 14:00 14:10 14:20 14:30 14:40 12/16/2019 12/16/2019 Time Customer: CONOCOR-illLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 LAM: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 10 Plots 70 ADP Chemical Plot - Interval 10 A I B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B 100 90 80 70 60 50 40 30 20 10 13:50 14:00 14:10 14:20 12/16/2019 Time Customer. CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Well Description: CD5 26 MI: 50-103-20806 14:30 14:40 12/16/2019 Sales Order* 0906160385 Conoco Phillips Alaska -CDS-26 Interval 10 Plots 71 Treatment Plot - Treatment 11 A B Treating Pressure (psi) [Slurry Proppant Conc (lb/gal) Gauge BH Pres (psi) A Slurry Rate (bpm) B C BH Proppant Conc (Ib/gal) C A Actual BH Temp ('F) — -- — D C D 10000 100 -- 10 500 9000 90 9 8000 80 8 400 7000 70 7 6000 60 6 300 5000 50 -5 4000 40 4 200 3000 30 3 2000 20 _ 2 100 1000 - 10 • • 1 0 0 .>.� __r..�__ ..�— --------- 0 0 14:30 14:40 14:50 15:00 15:10 15:20 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 k Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 11 Plots 72 Blender Chemical Plot - Interval 11 B1 CL -31 Conc -LA1 (gal/Mgal) -- A B 1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B 14:30 14:40 14:50 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 16 -Dec -2019 Well Description: CD5 26 LIM 50-103-20806 15:00 15:10 12/16/2019 Sales Order #: 0906160385 B 6 5 4 3 K 1 M Conoco Phillips Alaska-CD5-26 Interval 11 Plats 73 ADP Chemical Plot - Interval 11 A I B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B � n ------- ---- -- - - inn 0.0T I I —I 0 14:30 14:40 14:50 15:00 15:10 15:20 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD526 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 11 Plots 74 ` If B C D C D "0 1500 15:10 15:20 15:30 15:40 15:50 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD526 UWI: 50-103-20806 400 300 200 100 0 Conoco Phillips Alaska - CD5-26 Interval 12 Plots 75 Treatment Plot - Treatment 12 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (lb/gal) A B Gauge BH Pres (psi) A Actual BH Temp (°F) --- 10000 100 -- ----- -- 9000 90 8000 80 7000 70 6000 60 5000 50 4000 40 3000- 30- L14 2000- 20 1000 10 B C D C D "0 1500 15:10 15:20 15:30 15:40 15:50 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD526 UWI: 50-103-20806 400 300 200 100 0 Conoco Phillips Alaska - CD5-26 Interval 12 Plots 75 Blender Chemical Plot - Interval 12 B1 CL -31 Conc -LA1 (gaUMgal) --- — ------ A Bl CL -22 LIC Conc -LA2 (gal/Mgal) A A - B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 3.0 ,. 6 2.5 2.0 1.5 HE 0.5 We 15:10 15:20 15:30 15:40 15:50 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 LW: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 12 Plots 76 ADP Chemical Plot - Interval 12 A I B2 Losurf 300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (ib/Mgal) AB 15:10 15:20 15:30 15:40 15:50 12/16/2019 12/16/2019 Time Customer. CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 " Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska -CDS -26 Interval 12 Plots 77 Treatment Plot - Treatment 13 Conoco Phillips Alaska - CD5-26 Interval 13 Plots 78 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp (°F) D C D 10000 100 — ---- — - --- 10 500 — --- 9000 90 9 8000 80 8 400 7000 70 7 6000 60 6 300 5000 50 5 4000 40 4 200 3000 30- 3 2000 20 2 100 1000 10 • • 1 I 0 0 -- 0 10 15:50 16:00 16:10 16:20 16:30 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 LIM: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 13 Plots 78 Blender Chemical Plot - Interval 13 B1 CL -31 Conc -LA1 (gal/Mgal) _._ A 81 CL -22 UC Conc -LA2 (gal/Mgal) A A 131 MO -67 Conc -LA5 (gal/Mgaf) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 3.0- 2.5- EEO 0.5 MUG 15:50 16:00 16:10 16:20 16:30 12/16/2019 Time 12/16/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 "'"" Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 13 Plots 79 ADP Chemical Plot - Interval 13 A I B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) 1)n B B 100 90 80 70 60 50 40 30 20 -10 - 0 15:50 16:00 16:10 16:20 16:30 12116/2019 Time 12/16/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 13 Plots so Treatment Plot - Treatment 14 A B Treating Pressure (psi) Slurry Proppant Conc (lb/gal) Gauge BH Pres (psi) A Slurry Rate (bpm) B C BH Proppant Conc (Ib/gal) C A Actual BH Temp (°F) D C D 10000 100 -- -- -- -- 10 500 9000 90 9 8000 80 8 400 7000 70 7 6000 60 6 300 5000 50 5 4000, 40 4 200 3000 30 3 2000 20 p 2 100 1000 101 0 • • 0 0 0 16:20 16:40 17:00 17:20 17:40 12/16/2019 12/16/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 16-Dec-2019ISales Order #: 090616038-p Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 I me nva 114 Plots 81 Blender Chemical Plot - Interval 14 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) V B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B A ! B1 SP Breaker Conc -DA1 (Ib/Mgal) B B 16:20 16:30 16:40 16:50 17:00 17:10 12/16/2019 12/16/2019 Time Customer GONOOOPHILLIPS NORTH SLOPE- ESUS I Job Date: 16 -Dec -2019 Sales Order #: 0906160385 Well Description: C05 26 UWI: 50-103-20806 Conoco Phillips Alaska -CDS-26 Interval 14 Plots 82 ADP Chemical Plot - Interval 14 A B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgai) B B 1 1 1 1 1 0 0 0 0 0 16:20 16:30 16:40 16:50 17:00 17:10 12/16/2019 Time 12/16/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 16 -Dec -2019 Sales Order #: 0906160385 -- Well Description: CD5 26 LIM 50-103-20806 Conoco Phillips Alaska - CDS-26 Interval 14 Plots 83 �f Pressure Test - 12-18-2019 Treating Pressure (psi) Treating Pressure @Pump (psi) ---� 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 10000 9000 8000 7000 6000 5000 4000 3000 2000 1000 0 10:56 10:58 11:00 11:02 11:04 11:06 12/18/2019 Time 12/18/2019 Global Event Log i $1 Pressure Test- Local 10:56:01 Pressure Test- Globals 10:56:08 71 Pressure Test- Max 10:57 942 Customer: CONOCOPHILLIPS NORTH SLOPE - EBLIS Job Date: 18 -Dec -2019 I Sales Order #: 0906160385 Well Description: CD5 26 LIWI: 50-103-20806 Conoco Phillips Alaska - CDS-26 Interval 15 Plats 84 1 Nitrogen Pop -Off Test - 12-18-2019 Treating Pressure (psi) Treating Pressure @Pump (psi) 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 11:43 11:44 11:45 11:46 11:47 11:48 12/18/2019 12/18/2019 Time Global Event Log I N2 Pop @ 7807psi 11:44:47 ,`_1.6, N2 Pop @ 7939psi 11:47:38 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 15 Plots 85 Blender Chemical Plot - Bucket Tests Day 3 B1 CL -31 Conc -LAI (gei'i lgalj- — --- — B1 CL -22 UC Conc -LA2 (gal/Mgal) A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) 3.0 - 2.5 2.0 1.5 in 0.5 w A B -6 06:22 06:24 06:26 06:28 06:30 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Well Description: CD5 26 UWI: 50-103-20806 -5 4 3 K I 0 06:32 06:34 06:36 12/18/2019 Sales Order #: 0906160385 Conoco Phillips Alaska - CD5-26 Interval 15 Plots 86 ADP Chemical Plot - Bucket Tests Day 3 A 32 Losurf-300D Conc -LA2 (gal/Mgal) A 82 WG -36 Conc -DA1 (Ib/Mgal) B 2.0 : --- - - -- - ---- - 100 1.8 -90 1.6 80 1.4 70 1.2 60 1.0 50 0.8 0.6 0.4 0.2 0.0 -r-- 10: 08:20 10:08:40 10:09:00 10:09:20 12/18/2019 Time Customer: CONOOOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Well Description: CD5 26 UWI: 50-103-20806 10:09:40 12/18/2019 Sales Order #: 0906160385 40 30 20 10 0 Conoco Phillips Alaska - CD5-26 Interval 15 Plots 87 Treatment Plot - Treatment 15 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (lb/gal) C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp (°F) D , C D 10000 100 - -- — 10 X500 9000 90 9 8000 80 8 7000 70_. -7 6000 60 6 5000 50 5 4000 40 � 4 3000 30 3 2000 202 1000 10 1 0 0 0 12:40 12:50 13:00 13:10 13:20 13:30 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 300 200 100 Conoco Phillips Alaska -CD5-26 Interval 15 Plots 88 Blender Chemical Plot - Interval 15 B1 CL -31 Conc -LA 1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) — A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 12:50 13:00 13:10 13:20 13:30 12/18/2019 Time 12/18/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order M 0906160385 Well Description: CD5 26 UWI: 50-103-20806 2.5 2.0 1.5 1.0 0.5 Conoco Phillips Alaska-CD5-26 Interval 15 Plots 89 ADP Chemical Plot - Interval 15 A DB2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conic -DA1 (lb/Mgai) 1 B 2.0 IF _F_ — -ter .-ter 100 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 12:50 13:00 13:10 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Well Description: CD5 26 LIWI: 50-103-20806 13:20 13:30 12/18/2019 Sales Order #: 0906160385 Conoco Phillips Alaska-CD5-26 Interval 15 Plots 90 Treatment Plot - Treatment 16 13:30 13:40 13:50 14:00 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 I Sales Order#: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 16 Plots 91 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal; - C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp ('F) — D C D 10000, 100 - -10 500 9000 90 F -9 8000 80 8 400 7000 70 7 6000 60 6 300 5000 50 5 4000 40 4 200 3000 30 3 2000 20 2100 I 1000 101 13:30 13:40 13:50 14:00 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 I Sales Order#: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 16 Plots 91 Blender Chemical Plot - Interval 16 1231 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) BJ B 3.0 11 1 ----T-6 2.5 2.0 1.5 we 0.5 M 13:25 13:30 13:35 13:40 13:45 13:50 13:55 14:00 14:05 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Well Description: CD5 26 Job Date: 18 -Dec -2019 LW: 50-103-20806 Sales Order #: 0906160385 Conoco Phillips Alaska - CD5-26 Interval 16 Plots 92 ADP Chemical Plot - Interval 16 A I B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgai) 2.0 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 B I B 13:30 13:40 12/18/2019 Customer. CONOCOPHILLIPS NORTH SLOPE - EBUS Well Description: CD5 26 13:50 Time Job Date: 18 -Dec -2019 LIM 50-103-20806 14:00 12/16/2019 Sales Order* 0906160385 Conoco Phillips Alaska - CD5-26 Interval 16 Plots 93 Treatment Plot - Treatment 17 14:00 14:10 14:20 14:30 14:40 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 I Sales Order#: 0906160385 1 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CDS-26 Interval 17 Plots 94 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp (°F) D C D 10000 100 - ---- — -- 10 500 9000- 90- -9 8000 80 8 400 7000 70 7 6000 60 6 300 5000 50 5 4000- 40 4 200 3000 30 - 3 2000 20 2 -100 1000 0 10- 0 0 0- - - 0 0 14:00 14:10 14:20 14:30 14:40 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 I Sales Order#: 0906160385 1 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CDS-26 Interval 17 Plots 94 Blender Chemical Plot - Interval 17 13 (1 3 1 LA (gt1 Mq i1)- ----- -- A B1 CL -22 UC Conc -LA2 (gal/Mgal) A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal)— 3.0 - - 2.5 2.0 1.5 1.0 0.5 0.0 14:00 12/18/2019 A B B 6 5 4 3 -2 1 14:10 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Well Description: CD5 26 0 14120 14:30 14:40 Time 12/18/2019 Job Date: 18 -Dec -2019 Sales Order #: 0906160385 "" ......`. L1WI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 17 Plots 95 ADP Chemical Plot - Interval 17 AI L rr 3uso 00D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B - - - - 2.0-r 100 te � T _ _ _ _---,-r-TT 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 14:00 14:10 14:20 14:30 14:40 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS r Job Date: 18 -Dec -2019 Sales Order k 0906160385 Well Description: CD5 26 - IJWI: 50-103-20806 - Conoco Phillips Alaska - CD5-26 Interval 17 Plots 96 Treatment Plot - Treatment 18 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conc (Ib/gal) C BH Proppant Conic (Ib/gal) A B Gauge BH Pres (psi) A Actual BH Temp (°F) - 100001 100 9000 90 8000 80 7000 70 6000 60 5000 50 4000 40 3000 30- 2000 20 1000 10 0 0 B C D C D I U 1500 9 8 400 7 6 300 5 4 200 3 2 100 1 0 0 14:30 14:40 14:50 15:00 15:10 15:20 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order#: 0906160385 1m Well Description: CD5 26 UWL 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 18 Plots 97 Blender Chemical Plot - Interval 18 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conic -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 3.0 —6 2.5 2.0 1.5 HE 0.5 0.0 14:30 14:40 14:50 15:00 15:10 15:20 12/18/2019 12/18/2019 Time Oistomer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 18 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CDS-26 Interval 18 Plots 98 ADP Chemical Plot - Interval 18 A B2 Losurf-300D Conc -LA2 (gal/Mgai) A B2 WG -36 Conc -DA1 (Ib/Mgal) B—] B 2.0 i i, --T- r - - T — 100 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 14:30 14:40 14:50 15:00 15:10 15:20 12/18/2019 Time 12/18/2019 Customer. CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 T—Sa�der #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska-CD5-26 Interval 18 Plots 99 Treatment Plot - Treatment 19 Conoco Phillips Alaska - CD5-26 Interval 19 Plots 100 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp ('F) — --- D' C D 10000 100 -- - 10 500 - -- -- 9000 90 9 8000 80 8 400 7000 70 7 6000 1 60 6 300 5000 50 5 4000 40 1200 4 3000 30 3 2000 20 — -- ------ -- 2 100 -_ ----------- - - 1000 10 •• • • 1 0 0 t 0 0 15:10 15:20 15:30 15:40 15:50 12/18/2019 Time 12/18/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order #: 0906160385 ' Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 19 Plots 100 Blender Chemical Plot - Interval 19 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Cone -DA2 (Ib/Mgal) B B FA 2 0 15:10 12/18/2019 15:15 15:20 15:25 15:30 15:35 15:40 15:45 15:50 Time 12/18/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date 18 -Dec -2019 Sales Order #: 0906160385 Well Description: C05 26 LIM 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 19 Plots 101 ADP Chemical Plot - Interval 19 A B2 Losurf--300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B 2.0 - 1 AF— r T1 - - >r � 100 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 _ 15:10 15:15 15:20 15:25 15:30 15:35 15:40 15:45 15:50 12/18/2019 Time 12/18/2019 Customer. CONOCOPHILLIPS NORTH SLOPE- EBUS - Job Date: 18 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 19 Plots 102 F•7 400 300 200 100 Conoco Phillips Alaska-CD5-26 Interval 20 Plots .103 Treatment Plot - Treatment 20 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conic (Ib/gal) C A B Gauge BH Pres (psi) A Actual BH Temp (°F) D C 10000 100 - 10 9000 90 9 8000 7 I 80 8 7000 70 -7 6000 60 r .1wlr 6 5000 50 i 5 4000- 40 4 3000 i i 30 3 -----2 2000 20 1000 , 10- 1 0 0-1I • ••e • - 0 15:40 15:50 16:00 16:10 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order#: 0906160385` Well Description: CD526 UWI: 50-103-20806 F•7 400 300 200 100 Conoco Phillips Alaska-CD5-26 Interval 20 Plots .103 Blender Chemical Plot - Interval 20 131 CL-31 Cane -LA 1 (gah'Mgal) — -- A B1 CL-22 UC Conc -LA2 (gal/Mgal) A 61 MO-67 Conc -LA5 (gal/Mgal) B 131 Optiflo-III Conc -DA2 (Ib/Mgal) 2.5 2.0 1.5 EEO 0.5 0.0 A B B 6 15:40 15:45 15:50 15:55 16:00 16:05 16:10 16:15 12/18/2019 Time 12/18/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 18 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 UWI: 50-103-20806 5 4 3 2 1 L Conoco Phillips Alaska-CD5-26 Interval 20 Plots 104 ADP Chemical Plot - Interval 20 A [ B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) _I B 2.0 — �irrr� --_- �rr�r 100 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 1 Conoco Phillips Alaska - CD5-26 Interval 20 Plots 105 15:40 15:45 15:50 15:55 16:00 16:05 16:10 16:15 2/18/2019 Time 12/18/2019 Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 18 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 LIM 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 21 Plots 106 Treatment Plot - Treatment 21 Treating Pressure (psi) A Slurry Rate (bpm) 8 Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C A B Gauge BH Pres (psi) A Actual BFi Temp ('F) — — F) C D 10000 100 - - 10 500 9000 90 9 8000 80 8 400 7000 70 7 6000 60 -6 300 5000 50 5 4000 40 4 200 3000 30 3 2000 20 2 100 ' �` 1000 10 40• • 0 • 1 0 0- I , 1-- - 0 0 16:10 16:20 16:30 16:40 16:50 12/18/2019 Time 12/18/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS f Job Date: 18 -Dec -2019 Sales Order#: 0906160385 ""`�" Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 21 Plots 106 Blender Chemical Plot - Interval 21 B1 CL -31 Conc -LAI (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B B 3.0-,-- — 6 2.5 2.0 1.5 UM 0.5 wa, 16:10 16:15 16:20 16:25 16:30 16:35 16:40 16:45 12/18/2019 12/18/2019 Time Oistomer. CONOOOPHILLIPS NORTH SLOPE - EBUS Job Date. 18 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 LW: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 21 Plots 107 ADP Chemical Plot - Interval 21 A B2 Losurf-300D Conc -LA-2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B 2.0 -F'— r _ -- — - 7 - R 100 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 16:10 16:15 16:20 16:25 16:30 16:35 16:40 16:45 12/18/2019 Time 12/18/2019 Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order* 0906160385 Well Description: CD5 26 UWI: 50-103-20806 Conoco Phillips Alaska-CD5-26 Interval 21 Plots 108 C D C D "0 500 400 16:40 16:50 17:00 17:10 17:20 17:30 17:40 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order#: 0906160385 �� Well Description: CD526 UWI: 50-103-20806 300 200 100 M Conoco Phillips Alaska - CDS-26 Interval 22 Plots 109 Treatment Plot - Treatment 22 Treating Pressure (psi) A Slurry Rate (bpm) Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) A B Gauge BH Pres (psi) A Actual BH Temp ("F) 10000 100 9000 90 8000 80 7000 70- 6000 60!� 5000 50• 4 4000 40 3000 30 2000 20- 1000 10 o• o • 0 0 -r C D C D "0 500 400 16:40 16:50 17:00 17:10 17:20 17:30 17:40 12/18/2019 12/18/2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order#: 0906160385 �� Well Description: CD526 UWI: 50-103-20806 300 200 100 M Conoco Phillips Alaska - CDS-26 Interval 22 Plots 109 Blender Chemical Plot - Interval 22 B1 CL -31 Conc -LA1 (gal/Mgal) -- A B1 CL -22 UC Conc -LA2 (gal/Mgal) A B1 MO -67 Conc -LA5 (gal/Mgal) B B1 Optiflo-III Conc -DA2 (Ib/Mgal) B A SP Breaker Conc (Ib/Mgal) B B 6 2.5 2.0 1.5 1.0 0.5 0.0 16:40 16:45 16:50 16:55 17:00 17:05 17:10 17:15 12/18/2019 12/18/2019 Time Customer. CONOCOPHILLIPS NORTH SLOPE - EBUS Job Date: 18 -Dec -2019 Sales Order* 0906160385 Well Description: CD5 26 LNVI: 50-103-20806 Conoco Phillips Alaska - CD5-26 Interval 22 P lots 110 ADP Chemical Plot - Interval 22 A I B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (ib/Mgal)- 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 B 16:40 16:45 16:50 16:55 17:00 17:05 17:10 17:15 12/18/2019 Time 12118/2019 Customer: CONOOOPHILLIPS NORTH SLOPE- EBUS 1 Job Date: 18 -Dec -2019 Sales Order #: 0906160385 Well Description: CD5 26 _ LAN[: 50-103-20806 Conoco Phillips Alaska-CD5-26 Interval 22 Plots 111 HALLIBURTON , Order#-1 60-48,5 Conoco Phillips Alaska - CD5-26 Conoco Phillips Alaska CD5-26 Intervals 1-22 A -Sand Formation Harrison Bay County, AK API: 50-103-20806 Prepared.for: Adam Klem Stimulation Treatment Appendix - Well Summary - Chemical Summary - Planned Design - Water Straps - Water Analysis - Real -Time QC - Wellbore Information - Event Log - Field Break Test - Fann 15 Minute - Lab Testing Appendix 112 Conoco Phillips Alaska - CD5-26 Well Summary 113 CDS -26 Interval Highlights Interval Date Designed Proppant (Ibs) Proppant in Formation (lbs) Vol Clean (bbl) Vol Slurry (bbl) Top Perf (ft) Bottom Perf (ft) Fluid System 1 12/14/2019 70000 64,099 1642 1,709 33,686 33,688 HyborG 2 12/14/2019 70000 4,617 716 721 32,837 32,839 HyborG 3 12/14/2019 70000 68,097 1515 1587 31,987 31,989 HyborG 4 12/14/2019 70000 67,576 1514 1585 31,138 31,140 HyborG 5 12/14/2019 70000 72,250 1304 1379 30,295 30,297 HyborG 6 12/14/2019 70000 10,951 2517 2528 29,449 29,451 HyborG 7 12/16/2019 70000 70,851 1229 1303 28,602 28,604 HyborG 8 12/16/2019 70000 68,126 1185 1257 27,754 27,756 HyborG 9 12/16/2019 70000 70,569 1208 1281 26,905 26,907 HyborG 10 12/16/2019 70000 70,743 1229 1303 26,056 26,058 HyborG 11 12/16/2019 70000 71,612 1202 1277 25,205 25,207 HyborG 12 12/16/2019 70000 72,597 1261 1337 24,361 24,363 HyborG 13 12/16/2019 70000 72,021 1197 1272 23,514 23,516 HyborG 14 12/16/2019 70000 72,328 1578 1654 22,670 22,672 HyborG 15 12/18/2019 70000 66,434 1241 1310 21,819 21,821 HyborG 16 12/18/2019 70000 63,220 1200 1266 20,975 20,977 HyborG 17 12/18/2019 70000 67,222 1193 1263 20,124 20,126 HyborG 18 12/18/2019 70000 61,811 1276 1341 19,268 19,270 HyborG 19 12/18/2019 90000 88,089 929 1021 18,417 18,419 HyborG 20 12/18/2019 90000 85,700 919 1009 17,584 17,586 HyborG 21 12/18/2019 90000 85,125 918 1007 16,745 16,747 HyborG 22 12/18/2019 90000 1 103,896 1215 1324 15,893 1 15,895 1 HyborG Conoco Phillips Alaska - CD5-26 Well Summary 113 Customer Conoco Phillips Alaska Formation A -Sand HALLIBURTON Production Enhancement Lease CD5-26 API 50-103-20806 Date 12/14/2019 Interval Summary - Chemicals Conoco Phillips Alaska -CD5-26 Chemical Summary 114 Liquid Additives Dry Additives LoSurf-3001) MO -67 CL -22 UC CL -31 LVT-200 WG -36 BE -6 Opti Flo -III SP Interval (gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) Prime Up 0 0 0 0 0 0 0 0 0 1 59 33 54 27 0 1924 10 119 0 2 30 17 27 14 0 749 5 60 0 3 64 35 57 29 0 1409 10 127 0 4 64 23 38 19 0 1596 10 127 0 5 55 30 49 25 0 1383 8 110 0 6 108 57 50 22 7140 2843 16 207 0 7 52 28 46 23 0 1636 8 103 0 8 50 27 45 22 0 1258 7 100 0 9 51 28 46 23 0 1254 8 101 0 10 52 28 46 23 0 1238 8 103 0 it 50 28 45 23 0 1212 8 101 0 12 53 29 48 24 0 1248 8 106 0 13 50 28 45 23 0 1201 8 101 0 14 53 23 53 39 4200 1682 10 135 10 15 52 29 47 23 0 1702 8 104 0 16 50 28 45 23 0 1462 8 101 0 17 50 28 45 23 0 1373 8 100 0 18 54 29 48 24 0 1329 8 107 0 19 39 21 35 18 0 959 6 78 0 20 39 21 35 17 0 993 6 77 0 21 39 21 35 17 0 938 6 77 0 22 48 23 40 25 5040 1105 7 155 10 Total 1160 615 980 505 16380 30494 176 2400 20 w/o Prime Up 1160 615 980 505 16380 30494 176 2400 20 Conoco Phillips Alaska -CD5-26 Chemical Summary 114 F nnis.n Conoco Phillips Alaska - CDS-26 Planned Design 115 m��»v�m®m•��®��m®m®�®®mom � ��rW-s �+ea� � ten, m• ®®� � � �� ®� � EszSa� m � Conoco Phillips Alaska - CDS-26 Planned Design 115 Conoco Phillips Alaska-CD5-26 Planned Design 116 - ®iM1i�'Rffi�im�i•®��i•��mimi�mimi ' i•�5i�}��m®ice®®��0imi�iimi �� ®lllllm• 00 mi m ®� 11111®im OEM= �-©E+Vi�oi•��i♦i®iiiimi m�� i• ©� ®®� �®��i®�� iimi 0 E.� � ®E� ®0 ®��i•imi�iimi ®'i®� �®®0� � ��0®®®Mimi ■� 0 ii�� i•®� �®� ��i•imi�iimi - Vii"'••' ��m©0®®��i♦i®i�i�lEi7i ®�.RT� �}�� i• ®moi ®®ice � � milt®Mimi - � ®�'i�S��i• ��i��im�i•®�i��il��i•ilti�iimi ®moi ®©�� ®i♦imi�iimi ®�®T�im�i•®moi®®��i•imi�iimi i .: i•.7.'F.Et��""_iD�i•��C��®�31C•'��i�ii♦miiti ®m��®��imi�iimi ®�'6i�}��i• ®i'� �®i• �©i•i®ice iimi ®i��i♦i®i�iimi on ♦ iceiimi Imp ��®lllllm•�0 i♦i®i�iimi lllm•imNKEM l• imm^r!r.�i�f"�lD�m � �*.:.� ®®E}-�� Iff-Im lL�t��i�E3:f Conoco Phillips Alaska-CD5-26 Planned Design 116 eusrom. >e��,. w.a. �� _ So-- I.— - �� as �� sa Conoco Phillips Alaska-CD5-26 Planned Design 117 Customer: Conoco Phillips Alaska Well: CD5-26 Date: 12/14/2019 Formation: A -Sand SOM 0906160385 Conoco Phillips Alaska - CD5-26 Water Straps Day 1 General Beginning Strap Ending Strap Tank Type Water Source inches Gallons Barrels Temperature ('F) Inches Gallons Barrels 1 Atigan CDS 108 20,529 489 101 9 1,444 34 2 Atigan CDS 95 18,014 429 97 9 1,444 34 3 Atigan CDS 107 20,336 484 99 9 1,444 34 4 Atigan CDS 105 19,949 475 99 9 1,444 34 5 Atigan CDS 98 18,595 443 97 9 1,444 34 6 Atigan CD5 105 19,949 475 105 9 1,444 34 7 Atigan CD5 103 19,562 466 99 39 6,920 165 8 Atigan CD5 81 15,306 364 103 81 15,306 364 9 Atigan CDS 105 19,949 475 102 105 19,949 475 10 Atigan CDS 104 19,755 470 97 61 11,408 272 11 Atigan CDS 81 15,306 364 98 56 10,367 247 12 Atigan CDS 89 16,854 401 92 9 1,444 34 13 Atigan CD5 100 18,981 452 96 9 1,444 34 14 Atigan CDS 105 19,949 475 96 9 1,444 34 15 Atigan CDS 105 19,949 475 104 9 1,444 34 16 Atigan CDS 103 19,562 466 94 9 1,444 34 17 Atigan CDS 105 19,949 475 103 9 1,444 34 18 Atigan CD5 105 19,949 475 96 9 1,444 34 19 Atigan CDS 105 19,949 475 102 9 1,444 34 20 Atigan CD5 99 18,788 447 105 9 1,444 34 21 Wichita CD5 98 19,740 470 98 11 2,100 50 22 Wichita CD5 92 18,480 440 90 9 1,722 41 23 Wichita CDS 96 19,320 460 105 9 1,722 41 24 Wichita CDS 102 20,580 490 101 10 1,890 45 25 Wichita CDS 100 20,160 480 97 9 1,722 41 Location Summary Starting VolumeEnding Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 479,456 11,416 94,772 1 2,256 384,685 9,159 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 0 457 0 457 0 457 0 457 Conoco Phillips Alaska - CD5-26 Water Straps Day 1 Customer: Conoco Phillips Alaska Well: CDS-26 Date: 12/16/2019 Formation: A -Sand SO#: 0906160385 Conoco Phillips Alaska - CD5-26 Water Straps Day 2 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature ("F) Inches Gallons Barrels 1 Atigan CD5 99 18,788 447 105 9 1,444 34 2 Atigan CD5 101 19,175 457 101 9 1,444 34 3 Atigan CD5 102 19,368 461 103 9 1,444 34 4 Atigan CD5 99 18,788 447 109 9 1,444 34 5 Atigan CD5 100 18,981 452 108 9 1,444 34 6 Atigan CD5 104 19,755 470 107 9 1,444 34 7 Atigan CD5 103 19,562 466 107 23 4,182 100 8 Atigan CD5 79 14,919 355 110 63 11,824 282 9 Atigan CD5 100 18,981 452 135 82 15,500 369 10 Atigan CD5 98 18,595 443 110 9 1,444 34 11 Atigan CD5 103 19,562 466 108 9 1,444 34 12 Atigan CDS 102 19,368 461 105 9 1,444 34 13 Atigan CD5 104 19,755 470 107 9 1,444 34 14 Atigan CD5 103 19,562 466 105 9 1,444 34 15 Atigan CD5 103 19,562 466 103 9 1,444 34 16 Atigan CD5 104 19,755 470 103 9 1,444 34 17 Atigan CD5 104 19,755 470 102 10 1,627 39 18 Atigan CD5 105 19,949 475 102 9 1,444 34 19 Atigan CD5 107 20,336 484 103 9 1,444 34 20 Atigan CD5 99 18,788 447 105 9 1,444 34 21 Wichita CD5 99 19,950 475 101 9 1,722 41 22 Wichita CD5 98 19,740 470 102 9 1,722 41 23 Wichita CD5 100 20,160 480 105 9 1,722 41 24 Wichita CDS 100 20,160 480 103 9 1,722 41 25 Wichita CD5 105 21,000 500 103 9 1,722 41 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 484,313 11,531 64,853 1,544 419,459 9,987 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 0 461 0 461 0 461 0 461 Conoco Phillips Alaska - CD5-26 Water Straps Day 2 Customer: Conoco Phillips Alaska Well: CD5-26 Date: 12/18/2019 Formation: A -Sand SO#: 0906160385 Conoco Phillips Alaska - CD5-26 Water Straps Day 3 120 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels 1 Atigan CD5 100 18,981 452 106 9 1,444 34 2 Atigan CD5 96 18,208 434 102 9 1,444 34 3 Atigan CD5 97 18,401 438 100 9 1,444 34 4 Atigan CD5 96 18,208 434 101 9 1,444 34 5 Atigan CD5 98 18,595 443 105 9 1,444 34 6 Atigan CD5 101 1 19,175 457 1 101 9 1,444 34 7 Atigan CD5 100 18,981 452 103 28 4,912 117 8 Atigan CD5 99 18,788 447 103 68 12,792 305 9 Atigan CD5 98 18,595 443 108 52 9,535 227 10 Atigan CD5 99 18,788 447 104 25 4,365 104 11 Atigan CD5 100 18,981 452 103 9 1,444 34 12 Atigan CD5 98 18,595 443 103 9 1,444 34 13 Atigan CDS 105 1 19,949 475 104 9 1,444 34 14 Atigan CD5 84 15,887 378 95 9 1,444 34 15 Atigan CD5 100 18,981 452 95 9 1,444 34 16 Atigan CD5 100 18,981 452 96 9 1,444 34 17 Atigan CD5 93 17,627 420 95 9 1,444 34 18 Atigan CD5 102 19,368 461 100 15 2,540 60 19 Atigan CD5 101 19,175 457 100 15 2,540 60 20 Atigan CD5 99 18,788 447 97 9 1,444 34 21 Wichita CDS 969,320 460 97 9 1,722 41 22 Wichita CD5 99 19,950 475 98 9 1,722 41 25 Wichita CD5 100 20,160 480 95 9 1,722 41 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 432,482 10,297 62,071 1,478 370,411 8,819 Pre -Joh Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 0 448 0 448 0 448 0 448 Conoco Phillips Alaska - CD5-26 Water Straps Day 3 120 Coro. Phillly-ka- CES 26 Company: HALLISURTO-N Alaska District Field QC Prejob Water Analysis on Location Conoco Phillips Well Name: CD5-261nt-als 1-6 Water Source: CDS SpecificTesting Gravity Temperature Dissolved Iron Fe2i Chloride CI Sulfate Sot Calcium Magnesium Total Cat` (MR,) Hardness Linear Viscosity Water H Gel pH Post-Crosslink PH Crosslink Bacteria -F mg/L mg/L mg/L mg/L mg/L mg/L cP (Y/N) Bq Value Tank# Hydrometer Digital The Strip Strip Strip Titration Total Hardness Titration Minus Calcium FANN-35 Probe Probe Probe - Mycometer 1 1.021 63.0 0 16,400 800 1,200 800 2,000 20 7.26 7.60 9.78 Y 1,174 2 1.021 61.0 0 22,250 800 1,200 800 2,000 20 7.31 7.70 9.85 Y 570 3 1.022 59.0 0 24,070 800 1,200 1,200 2,400 20 7.48 7.70 9.77 Y 489 4 1.022 59.0 5 19,080 1,200 800 2,000 2,800 la 7.46 7.90 9.80 Y 633 5 1.022 59.0 0 17,690 800 1,200 800 2,000 18 7.50 7.90 9.86 Y 197 6 1.022 59.0 0 19,080 800 1,200 1,600 2,800 19 7.60 7.80 9.83 Y 9,385 7 1.022 59.0 5 17,690 800 1,000 1,600 2,600 19 7.60 7.80 9.92 Y 66 8 1.022 60.0 0 171690 800 1,000 1,400 2,400 19 7.50 7.90 9.91 Y 227 9 1.022 60.0 0 17,690 800 1,200 1,400 2,600 19 7.70 7.80 9.87 Y 904 10 1.022 6005 16,400 1 800 1,000 1,800 2,800 18 7.70 7.80 1 9.88 Y 262 31 1.022 60.0 0 17,690 800 1,000 11000 2,000 19 7.70 7.90 9.82 Y 498 12 1.022 60.0 0 19,080 800 1,200 1,600 2,800 20 7.70 7.80 9.97 Y 517 13 1.022 60.0 0 17,690 1,200 800 1,600 2,400 20 7.70 7.90 9.91 Y 126 14 1.022 69.9 0 17,690 800 1,200 800 2,000 19 7.45 7.70 9.77 y 1,123 15 1.022 68.7 0 15,210 800 1,200 800 2,000 18 7.46 7.80 9.87 Y 482 16 1.021 78.6 0 17,690 800 1,200 1,400 2,600 19 7.51 7.64 9.84 Y 645 17 1.022 78.0 5 19,080 1,200 1,200 1,200 2,400 19 7.52 7.68 9.85 Y 569 18 1.022 74.9 0 17,690 800 1,000 1,000 2,000 18 7.53 7.72 9.75 Y 1,128 19 1.020 90.1 0 20,600 1,200 1,200 1,400 2,600 17 7.42 7.63 9.80 Y 1,308 20 1.022 75.8 5 20,600 800 1,200 1,200 2,400 19 7.52 1 7.84 9.78 Y 1,709 21 1.022 75.9 0 19,080 1,200 1,200 1,600 2,800 18 7.44 7.64 9.72 Y 1,113 22 1.020 91.4 5 19,080 800 1,000 1,400 2,400 17 1 7.51 7.72 9.72 Y 2,430 23 1.020 90.1 0 24,070 800 1,600 600 2,200 20 7.14 7.33 9.80 Y 1,520 24 1.020 81.8 5 15,210 800 1,600 200 1,800 19 7.05 7.54 9.74 Y 1,512 25 1.021 77.1 0 22,250 800 1,400 1,200 2,600 20 7.03 7.60 9.88 Y 31926 Average 1.022 69.3 1 18830 880 1160 1216 2376 19 7.47 7.73 9.83 1300.5 Maximum 1.022 91.4 5 24,070 1,200 1,600 2,000 2,800 20 7.70 7.90 9.97 9,385 Minimum 1.020 59.0 0 15,210 800 800 200 1,800 17 T,03+7,5373 9.72 66 Range 0.002 32.4 5 8,860 400 800 1,800 1,000 3 0.60.1 0.25 9,319 Coro. Phillly-ka- CES 26 Company: HALLIBURTON Alaska District Field CIC Prejob Water Analysis on Location Conoco Phillips Well Name: CDS-26 Intervals 7-14 Water Source: CDS Specific Gravity Testing Temperature Dissolved Iron Fe" Chloride Cf Sulfate Calcium Magnesium So Ca" (MR,*) Total Hardness Linear Viscosity Water pH Gel PH Post-Crosslink PH Crosslink Bacteria -F mg/L mg/L mg/L mg/L mg/L mg/L cP (Y/N) BQValue Tank# Hydrometer Y Digital Thermometer StripStrip P Strip Titration Total Hardness P Minus Calcium Titration FANN-35 Probe Probe Probe - M ycometer 1 1.024 65.6 0 19,080 800 17520 1,280 2,800 19 1 7.15 7.31 9.86 1 Y 474 2 1.022 67.0 0 1 19,080 800 1,560 1,320 2,880 20 7.08 7.28 9.67 Y 283 3 1.021 66.2 0 16,400 800 1,640 1,480 3,120 18 7.05 7.31 9.79 y 203 4 1.022 68.0 0 22,250 800 1,400 11"403,240 20 7.04 7.35 9.75 y 291 5 1.024 67.5 0 20,600 800 1,240 1,880 3,120 19 7.04 7.37 9.73 y 273 6 1.022 66.2 0 17,690 800 1,360 11840 3,200 19 7.02 7.27 9.72 Y 1,204 7 1.021 66.1 0 17,690 1,200 1,200 1,680 2,880 18 7.03 7.35 9.81 Y 968 8 1.022 60.0 0 17,690 800 1,000 1,400 21400 19 7.50 7.90 9.91 Y 227 9 1.022 60.0 0 17,690 800 1,200 1,400 2,600 19 7.70 7.80 9.87 Y 904 10 1.024 64.3 1 0 22,250 1,200 1,280 1,640 2,920 19 7.01 7.41 1 9.71 Y 9,934 11 1.023 67.3 5 22,250 800 1,280 1,840 3,120 20 7.03 7.35 9.78 Y 23,819 12 1.022 63.3 5 23,510 1,200 1,400 1,840 1 3,240 19 7.06 7.34 9.71 Y 3,305 13 1.021 64.7 0 21,770 800 1,360 1,480 1 2,840 18 7.08 7.37 9.67 Y 526 14 1.022 78.0 0 21,770 800 1,680 1,000 1 2,680 19 7.04 7.28 9.81 Y 256 15 1.021 78.6 0 20,170 800 1,800 1,360 3,160 20 7.03 7.34 9.71 y 121 16 1.021 80.9 5 21,770 1,200 1,720 1,160 2,880 18 7.01 7.27 9.68 Y 69 17 1.021 66.4 0 16,400 800 1,400 1,320 2,720 19 7.06 7.21 9.74 Y 434 18 1.023 68.1 0 32,390 800 1,600 1,600 3,200 19 7.28 7.34 9.67 Y 427 19 1 1.021 69.4 0 29,800 800 1,680 1,560 3,240 19 7.12 7.28 1 9.72 Y 855 20 1.022 70.1 0 18,690 800 1,280 11440 2,720 19 7.09 7.34 9.71 Y 541 21 1.025 68.7 0 21,770 1,200 1,640 11200 2,840 20 7.08 7.29 9.68 Y 1,088 22 1.023 68.7 0 25,400 800 1,680 1,240 2,920 20 7.09 7.69 9.68 Y 1,279 23 1.022 70.8 0 29,800 1,200 1,600 1,280 2,880 18 7.08 7.56 9.88 Y 1,144 24 1.023 1 67.8 I 0 42,820 1,200 1,680 1,080 2,760 20 7.08 7.60 9.90 y 1,585 25 1.023 66.5 0 29,800 800 1,640 1,360 3,000 18 7.08 7.65 9.65 Y 1,638 Average 1.022 68.0 1 22741 912 1474 1461 2934 19 7.11 7.41 9.75 2073.9 Maximum 1.025 80.9 5 42,820 1,200 1,800 1,880 3,240 20 7.70 7.90 9.91 23,819 Minimum 1.021 60.0 0 16,400 800 1,000 1,000 2,400 18 7.01 7.21 9.65 69 Range 0.004 20.9 5 26,420 400 800 880 840 2 0.69 1 0.69 0.26 23,751 Company: HALLISUATON Alaska District Field OC Prejob Water Analysis on Location Conoco Phillips Well Name: CD5-981nte-Is 15-22 Water Source: CD5 Specific GravityTemperature Testing Dissolved Iron Fe" Chloride CI SulfateCalcium Magnesium Total Linear SO'- Ca" (MR,) Hardness Viscosi Water PH Gel PH Post-Crasslink PH Crosslink Bacteria 'F mg/L mg/L mg/L mg/L mg/L mg/L cP (Y/N) BOValue Tank p Hydrometer Digital Thermometer Strip Strip Strip Titration Total Hardness Titration FANN-35 Minus Calcium Probe Probe Probe - Mycometer 1 1.023 61.7 0 21,960 800 1,640 880 2,520 20 7.05 7.35 9.68 Y 1,293 2 1.024 63.4 0 21,960 800 1,640 1,040 2,680 19 7.01 7.34 9.65 Y 96 3 1.023 68.1 0 17,580 800 1,720 880 2,600 19 7.03 7.31 9.82 Y 166 4 1.022 62.4 0 23,680 1,200 1,880 960 2,840 20 7.01 7.23 9.75 Y 341 5 1.023 63.5 5 18,930 800 1,680 800 20480 19 6.98 7.35 9.84 Y 210 6 1.024 60.5 0 17,580 800 1,600 1,000 2,600 20 7.17 7.38 9.67 Y 2,488 7 1.022 63.7 0 17,580 800 1,480 1,400 2,880 20 7.06 7.29 9.72 Y 1,635 8 1.023 62.1 0 18,930 800 1,640 1,120 2,760 20 7.04 7.32 9.71 Y 864 9 1 1.022 60 0 17,690 800 1,200 1,400 2,600 19 1 7.70 7.80 9.87 1 Y 904 10 1.023 63.8 0 23,680 800 1,720 1,240 2,960 21 7.06 7.30 9.67 Y 899 11 1.022 64.7 0 18,930 800 1,920 640 2,560 20 7.08 7.36 9.70 Y 11118 12 1.024 67.3 0 17,580 800 1,680 800 2,480 197.07 7.28 9.69 Y 633 13 1.024 70.1 0 20,380 800 1,840 1,120 2,960 19 7.04 7.29 9.67 Y 332 14 1.021 61.3 0 17,580 1,200 1,760 760 2,520 19 7.06 7.28 9.70 Y 271 15 1.023 59.8 5 17,580 800 1,840 600 2,440 20 7.04 7.32 9.72 Y 227 16 1.022 60.2 5 18,930 1,200 1,680 720 2,400 21 7.06 7.45 9.83 Y 293 17 1.023 63.1 0 17,580 800 1,840 720 2,560 19 7.22 7.41 9.71 y290 18 1 1.023 61.7 0 17,580 800 1,920 760 2,680 20 7.11 7.39 9.67 Y 1,092 19 1.024 64.3 0 18,930 800 1,760 840 2,600 20 7.07 7.33 9.73 Y 1,175 20 1.023 61.3 0 20,380 800 2,040 760 2,800 20 1 7.07 1 7.35 9.72 Y 4,385 21 1.024 60.2 0 18,930 1,200 1,840 880 2,720 19 7.09 7.41 9.80 Y 3,633 22 1.025 67.3 0 17,580 800 1,960 600 2,560 21 7.05 7.43 9.68 Y 1,638 25 1.024 65.4 0 23,680 1,200 2,160 1,440 3,600 19 7.03 7.35 9.71 Y 2,066 Average 1.023 63.3 1 17,808 887 1618 854 2,472 20 7.09 7.36 9.73 1,132 Maximum 1.025 70.1 5 23,680 1,200 2,160 1,440 3,600 21 7.70 7.80 9.87 4,385 Minimum 1.021 59.8 0 0 800 0 0 0 19 6.98 7.23 9.65 96 Range 0.004 10.3 5 23,680 400 2,160 1,440 3,600 2 0.72 0.57 0.22 4,288 - Customer: ConocoPhillips Alaska, Inc. wellname & #: CD5-26 Date: I December 14, 2019 Interval Stage Visc Linear H Tem °F XL H Comments Interyal Sta eTem °F XL H Comments 1 Muni -Frac ski ed II Pad 82 9.7 Pad 24 6.8 68 9.3 1# 88 9.6 1# 26 6.9 92 9.5 2# MLfiiearLineu 90 9.6 2# 24 6.9 92 9.5 3# 91 9.6 3# 23 6.9 90 9.5 4# 90 9.6 4# 21 6.9 86 9.5 2 Pad 24 6.9 90 9.3 12 Pad 88 9.4 1# 21 6.9 86 9.5 19 19 6.8 90 9.5 2# didn't see ball hit 2# 18 6.8 92 9.7 39 skipping to zone 3 34 17 6.9 88 9.7 4# 49 17 6.8 90 9.7 3 Pad 17 7 88 9.7 13 Pad 18 6.7 96 9.4 1# 17 6.9 90 9.5 1# 17 6.8 90 9.5 2# 17 6.9 88 9.5 29 17 6.8 92 9.5 3# 17 6.8 92 1 9.5 3# 17 6.8 96 9.5 44 a pump top cap caking went to flush 4# 17 6.8 92 9.6 4 Pad 21 6.9 96 9.8 14 Pad 17 6.8 90 9.5 14 19 6.9 96 9.5 1# 16 6.7 88 9.5 2# 19 6.9 88 9.4 2# 16 6.8 88 9.4 3# 19 6.9 86 9.5 39 16 6.8 90 9.5 4# 19 6.9 82 9.4 4# 16 6.9 100 9.4 5 Pad 19 6.8 88 9.5 15 Pad 19 6.9 82 12/18/2019 9.5 l# 18 6.9 92 9.8 1# 19 6.9 88 9.5 24 19 6.9 91 9.5 2# 19 6.8 88 9.5 3# 19 6.9 90 9.5 39 IS 6.9 90 9.6 49 19 6.9 90 9.7 4# 18 6.8 92 9.6 6 Pad 19 6.8 88 9.5 16 Pad 22 7 90 9.6 t# 19 6.9 82 9.5 went to flush cause couldn't see I# 22 6.9 88 9.6 29 20 6.8 88 9.9 ball hit 2# 21 6.9 90 9.6 3# started backup, using secondary ball 3# 21 7 91 9.5 4# 4# 23 7 88 9.3 7 Pad 29 7 68 10 12/16/2019 lowered LAI on ADP 17 Pad 22 7 88 9.3 1# 21 7 92 9.6 l# 23 7 90 9.3 2# 21 6.9 90 9.6 2# 24 6.9 88 9.3 3# 20 6.9 96 9.6 30 28 6.9 90 9.3 4# 20 6.9 92 9.6 4# 24 6.9 90 93 8 Pad 18 6.9 92 9.4 18 Pad 18 6.9 88 9.4 1# 18 6.9 94 9.5 14 18 6.9 90 9.3 2# 18 6.8 95 9.6 2# 17 6.9 88 9.4 3# 19 6.9 92 9.4 34 16 6.9 86 9.5 49 19 6.9 88 9.4 49 17 6.9 85 9.5 9 Pad 19 6.9 92 9.5 19 Pad 17 6.9 88 9.4 1# 19 6.9 90 9.5 19 17 6.9 90 9.4 2# 18 6.9 92 9.5 24 17 6.9 89 9.4 39 18 6.9 92 9.5 34 18 6.9 88 9.3 49 18 6.9 88 9.6 44 18 6.9 84 9.3 5# 18 6.9 86 9.3 6# 18 6.9 88 9.3 10 Pad 18 6.9 86 9.6 20 Pad 18 6.9 86 9.4 19 19 6.9 88 9.5 1# 18 6.9 90 9.4 2# 19 6.5 90 9.5 29 18 6.9 86 9.4 39 23 6.5 90 9.2 offloaded gel 3# 18 6.9 84 9.4 44 23 6.5 92 9.2 4# 186.9 85 9.4 59 17 6.9 86 9.4 64 17 6.9 84 9.4 C-Phmp A-.-cos-ab n..rn-a HALLIBURTON Fluid is broken at200cp Prejob Crosslink Break Tests ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report —Break Test 1 —Break Test 2 —Break Test 3 2000 Fluid System: 1800 Date: 12/10/2019 1600 Company: ConocoPhillips Project No: 1400 Well Name: CD5-26 Stage(s): Break Test 1200 BHST (eF): 156 Water Source: CD5 1000 m Depth: Water pH: 7.43 m eoo 600 Formation: Hydration pH: 7.80 400 Analyst: XLambe Hydration Visc: 20 Cp @ 72 200 0 00:00 All chemical concentrations below are In gallons per thousand / pounds per thousand TempaF PH LOSURF-300D CL -22 UC CL -31 MO -67 OptiOo-III 02:00 04:00 10:00 2000 30:00 1:00 3000 00:00 30:00 Time (m n:sec) Break Test 80 9.85 1.00 0.90 0.45 0.40 2.00 Conoco Phillips Alaska - CD5-26 Fann 15 Prelob Break Test Day 1 125 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 12/15/2019 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): Break Test BHST (eF): 156 Water Source: CD5 Depth: Water pH: 7.04 Formation: Hydration pH: 7.31 Analyst: XLambe Hydration Vise: 18 cp @ 74 Fluid is broken at 200cp Prejob Crosslink Break Tests -Break Test 1 2500 2000 0 0000 02:00 04:00 1000 2000 30:00 1:00 30:00 00:00 30:00 0000 Time (min:sec) All chemical concentrations below are in gallons per thousand I pounds per thousand Temp OF PH LOSURF-300D CL -22 UC CL -31 MO -67 Optigo-III Break Test 72 9.76 1.00 0.90 0.45 0.50 2.00 Conoco Phillips Alaska - C05-26 Fann 15 Prejob Break Test Day 2 Fluid is broken at 200cp Prejob Crosslink Break Tests [ _ -Break Testi 2500 2000 v 1500 _T N 0. 1000 500 0 0000 02:00 0400 10:00 2000 30:00 1:00 30:00 00:00 3000 00:00 Time (min:sec) All Chemical concentrations below are in gallons per thousand I pounds per thousand Temp°F PH LOSURF-300D CL -22 UC CL -31 MO -67 OptiRo-lll Break Test 71 9.72 1.00 0.90 0.45 0.50 2.00 Conoco Phillips Alaska - CD5-26 Fann 15 Prq.b Break Test Day 3 127 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/17/2019 Company: ConocoPhillips Project No: Well Name: CDS-98 Stage(s): Break Test BHST (eF): 156 Water Source: CD5 Depth: Water pH: 7.04 Formation: Hydration pH: 7.34 Analyst: XLambe Hydration Visc: 22 cp @ 74.3 Fluid is broken at 200cp Prejob Crosslink Break Tests [ _ -Break Testi 2500 2000 v 1500 _T N 0. 1000 500 0 0000 02:00 0400 10:00 2000 30:00 1:00 30:00 00:00 3000 00:00 Time (min:sec) All Chemical concentrations below are in gallons per thousand I pounds per thousand Temp°F PH LOSURF-300D CL -22 UC CL -31 MO -67 OptiRo-lll Break Test 71 9.72 1.00 0.90 0.45 0.50 2.00 Conoco Phillips Alaska - CD5-26 Fann 15 Prq.b Break Test Day 3 127 Fluid is broken of 200cp Zone 1 Crosslink TestE —P.d —1 ppg —2 Ppg — 3 PP9 3500 3000 2500 a 2000 T p 1500 m > 1000 Soo 4 PP9 —5 PP9 o -I i I B i l l I I I I I I 1 1�� 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 1 12:00 i 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - CD5-26 F.- 15 Zone 1 128 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 1211412019 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 1 BHST (eF): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott (Rios Hydration Visc: cp @ Fluid is broken of 200cp Zone 1 Crosslink TestE —P.d —1 ppg —2 Ppg — 3 PP9 3500 3000 2500 a 2000 T p 1500 m > 1000 Soo 4 PP9 —5 PP9 o -I i I B i l l I I I I I I 1 1�� 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 1 12:00 i 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - CD5-26 F.- 15 Zone 1 128 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/14/2019 Company: ConocoPhillips Project No: Well Name: CD -5 26 Stage(s): 2 BHST (°F): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scutt Rios Hydration Visc: cp @ Fluid is broken at 100cp Zone 2 Crosslink Tests LPad - - 1 PP9 —2 PPg —3 PP9 —4 Pp9 _5 PP9 3500 3000 - - — -- 2500 - - - a 2000 - — T p 1500 U N > 1000 — 500 -- — - -- -.y-- — - --, 0 0000 01:00 02:00 0300 0400 0500 06:00 0700 0800 0900 1000 11:00 12:00 1300 1400 15:00 Time (min:sec) Conoco Phillips Alaska - CD5-26 F.- 15 Zone 2 129 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 12/14/2019 Company: ConocoPhillips Project No: Well Name: CD -5 26 Stage(s): 3 BHST (eF): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott 9ejos Hydration Visc: cp @ Fluid is broken of 200cp Zone 3 Crosslink Tests rPad -1 PP9 -2 pp9 -3 ppg -4 pp9 -5 pp9 3500 —_ - TTFI3000 — - - --- 2500 - - - - - - a 2000 T p 1500 U - I m > 1000 — 500 — 0 00:00 0100 0200 03:00 04:00 05:00 06:00 07:00 0800 09:00 1000 11:00 12:00 13:00 14:00 1500 Time (min:sec) Conoco Phillips Alaska-CO5-26 Fann 15 Zone 130 HALLIBURTGN ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/14/2019 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 4 BHST (°F): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott 9jbs Hydration Visc: cp @ Fluid is broken at 200cp Zone 4 Crosslink Tests —Pal —1 pPg —2... —3 PP9 —4 ppg —5 PP9 2500 — 2000 - - _ -- - --.--- - - - — _ Z 1500 T 'a u 1000-- w 500 0 0000 01:00 0200 0300 04:00 05:00 0600 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - CD5-26 Fann 15 Zone 4 131 Fluid i5 broken of 200cp Zone 5 Crosslink Tests —Pad —1 PP9 —2 ppg _ _-3 ppg —4 PPg —5 PP9 2500 12/14/2019 2000 5 0 1500 _T N 0. 1000 _N 500 00:00 01:00 1 02'00 1 03:00 1 04:00 05:00 1 06:00 1 07:00 0800 09:00 10:00 11:00 1 12:00 1 1300 14:00 1500 Time (min:sec) Conoco Phillips Alaska- CD5-26 Fann 15 Zone 5 132 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Repor Fluid System: Date: Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): BHST (eF): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Rios Hydration Visc: cp Fluid i5 broken of 200cp Zone 5 Crosslink Tests —Pad —1 PP9 —2 ppg _ _-3 ppg —4 PPg —5 PP9 2500 12/14/2019 2000 5 0 1500 _T N 0. 1000 _N 500 00:00 01:00 1 02'00 1 03:00 1 04:00 05:00 1 06:00 1 07:00 0800 09:00 10:00 11:00 1 12:00 1 1300 14:00 1500 Time (min:sec) Conoco Phillips Alaska- CD5-26 Fann 15 Zone 5 132 Fluid is broken of 200cp Zone 6 Crosslink Tests f- —Pad —1 ppg —2 PPg —3 pp9 —4 PPg —5 PP9 1200 1/2019 100o 800 — -- — 6 u T 600 - - - - - - .N _ 0 U 400 -- — -- — — 200 - — - 0 00:00 01:00 02:00 03:00 04:00 05:00 06:00 0700 08:00 09:00 10:00 11:00 12:00 1300 1400 15:00 Time (min:sec) Conoco Phillips Alaska - CD5-26 Fenn 15 Zone 6 133 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 1 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): BHST (eF): 155 Water Source: Depth: Water pH: Formation: Hydration pH: _ Analyst: Scott Pi0s Hydration Visc: 0p Fluid is broken of 200cp Zone 6 Crosslink Tests f- —Pad —1 ppg —2 PPg —3 pp9 —4 PPg —5 PP9 1200 1/2019 100o 800 — -- — 6 u T 600 - - - - - - .N _ 0 U 400 -- — -- — — 200 - — - 0 00:00 01:00 02:00 03:00 04:00 05:00 06:00 0700 08:00 09:00 10:00 11:00 12:00 1300 1400 15:00 Time (min:sec) Conoco Phillips Alaska - CD5-26 Fenn 15 Zone 6 133 Fluid is broken of 200cp Zone , Crossllnk Tests Pad —1 ppg —2 ppg —3 PP9 —4 pp9 —5 pp9 7000 :000000 0000: - — n 4000 p 3000 — U u, > 2000 - 1000 - - - - - 0 0000 01:00 0200 0300 0400 05:00 06:00 0700 08:00 09:00 10:00 11:00 1200 1300 1400 15:00 Time (min:sec) Conoco Phillips Alaska - CDS-26 Fann 15 Zone 7 134 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 12/16/201 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 7 BHST (eF): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Rios Hydration Visc: cp @ Fluid is broken of 200cp Zone , Crossllnk Tests Pad —1 ppg —2 ppg —3 PP9 —4 pp9 —5 pp9 7000 :000000 0000: - — n 4000 p 3000 — U u, > 2000 - 1000 - - - - - 0 0000 01:00 0200 0300 0400 05:00 06:00 0700 08:00 09:00 10:00 11:00 1200 1300 1400 15:00 Time (min:sec) Conoco Phillips Alaska - CDS-26 Fann 15 Zone 7 134 Fluid is broken at 200cp Zone 8 Crosslink Tests �Paid —t ppg —Z PP9 —3 pp9 —4 PP9 —5 PP9 11111111111100 . ■■ 00 ■. 101 ■ L■■■■■■■■ ..■.go■ _■ ■■■■�■.aa�J■ ■ NINON■■■ ■■■■■� .....=.■■■.... _____ No ■q■MiM■■■■ FEEMENs . Conoco Phillips Alaska - CD5-26 Fann 15 Zone 8 135 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/16/ Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 8 BHST (oF): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Tjos Hydration Visc: cp @ Fluid is broken at 200cp Zone 8 Crosslink Tests �Paid —t ppg —Z PP9 —3 pp9 —4 PP9 —5 PP9 11111111111100 . ■■ 00 ■. 101 ■ L■■■■■■■■ ..■.go■ _■ ■■■■�■.aa�J■ ■ NINON■■■ ■■■■■� .....=.■■■.... _____ No ■q■MiM■■■■ FEEMENs . Conoco Phillips Alaska - CD5-26 Fann 15 Zone 8 135 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Fluid is broken at 200cp Z 6000 12/16/2019 1 5000 n 4000 9 u 0 3000 0 u '^ 2000 1000 one 9 Crossllnk Tests LPad —1 PP9 —2 PP9 _-3 PP9 —4 PP9 �5 PP9 r 0 00:00 01:00 0200 03:00 04:00 05:00 0600 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska- CD5-26 Fann 15 Zone 9 136 Date: Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): BHST (eF): 156 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Rjos Hydration Visc: Fluid is broken at 200cp Z 6000 12/16/2019 1 5000 n 4000 9 u 0 3000 0 u '^ 2000 1000 one 9 Crossllnk Tests LPad —1 PP9 —2 PP9 _-3 PP9 —4 PP9 �5 PP9 r 0 00:00 01:00 0200 03:00 04:00 05:00 0600 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska- CD5-26 Fann 15 Zone 9 136 HALLIBURTON ping -2 ping -3 ppg -4 ppg -1PP9 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report 6000 Fluid System: Date: 12/16/2019 5000 Company: ConocoPhillips Project No: 4000 Well Name: CD5-26 Stage(s): 10 BHST (°F): 155 Water Source: 3000 N O Depth: Water pH: = 2000 Formation: Hydration pH: Analyst: Scott Rios Hydration Visc: cin @ 1000 0 00:00 0100 0200 0300 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - CD5-26 Fann 15 Zone 10 137 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: FWid is broken at 200cp Z 4 U C 1' k Te 6000 12/16/2019 1 5000 t ss [ -Pad -1 PP9 -2 pp9 -3 ppg -4 pp9 -5 pp9 00 30 y 20 00000:00 I01:00I 02:00 I03:00 04:00 I05:00I 06I00 I07:00I 08I00I 09:00I 10:I00 11:00 12:00 13!004"14:00 15,00 Time 00 Time (min:sec) Conoco Phillips Alaska - CD5-26 Fann 15 Zone 11 138 Date: Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): BHST (°F): 156 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Pjos Hydration Visc: FWid is broken at 200cp Z 4 U C 1' k Te 6000 12/16/2019 1 5000 t ss [ -Pad -1 PP9 -2 pp9 -3 ppg -4 pp9 -5 pp9 00 30 y 20 00000:00 I01:00I 02:00 I03:00 04:00 I05:00I 06I00 I07:00I 08I00I 09:00I 10:I00 11:00 12:00 13!004"14:00 15,00 Time 00 Time (min:sec) Conoco Phillips Alaska - CD5-26 Fann 15 Zone 11 138 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 1 Company: ConocoPhillips Project No: _ Well Name: CD5-26 Stage(s): BHST (°F): 155 Water Source: Depth: Water pH: Formation: Hydration pH: _ Analyst: Scott Itjos Hydration Visc: CP 12 ,Fria is 6rdlarloo� 1 PP9 -2 PP9 —3 PP9 —4 PP9 —5 pp9 a000 - as0o — - - - 3000 2500 2000 - 0 U 1500 N_ i loon- _ _ - - - — - _ - - _ 500 0 00:00 01:00 02:00 0300 04:00 05:00 06:00 0700 0800 0900 1000 1100 12:00 1300 1400 1500 Time (mi—ec) Conoco Phillips Alaska - CD5-26 Fann 15 Zone 12 139 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/16/2019 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 13 BHST (°F): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Pios Hydration Visc: cp @ w ism a�f ZOUc�1 PP9 -2 PP9 3 PP9 -4 PP9 _5 PP9 3500 3000 a 2500 N 2000 - m1500 —} – 1000 -- - 500 0- 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - CD5-26 Fann 15 Zone 13 Iso HALLISURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 12/16/: Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 14 BHST (eF): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott 4Ubs Hydration Visc: cp @ �Tdis bm - t 20 cp a� -1 PP9 _2 PP9 _3 PP9 -4 PP9 -5 PP9 3500 3000 2500 a 2000 T •p 1500 N_ > 1000 500 0 0000 01:00 02:00 0300 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 1400 15.00 Time (nnin:sec) Conoco Phillips Alaska - C135-26 Fann 15 Zone 14 141 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 121181: Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 15 BHST (eF): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Rios Hydration Visc: CP @ Fridi�-bm racri2)cj�1 PP9 �2 PP9 -3 PPg -4 PP9 -5 PP9 4000 -- 3500 3000 2500 N 2000 0 N 1500 - - -- — - 1000 — - - — - 500 - a 00:00 01:00 0200 03:00 0400 0500 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska- CD5-26 Fan, 15 Zone 15 142 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 12118/2019 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 16 BHST (°F): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Rios Hydration Visc: cp @ w ism ad —2-1 2 P.— — —2 PP -9— --- —3 PP9 —4 PP9 Prig - 60 0 P9 6000 — — s000 a 4000 N 3000 u '^ 2000 - - - - -- — 1000 - - - - — 0 00:00 01:00 02:00 03:00 04:00 05:00 06:00 0700 08.00 09:00 10:00 11:00 1200 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - CD5-26 Fann 15 Zone 16 143 HALLiBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Id �s= za c,� 1 pp —2 ppy —s Pa9 —4 PP9 —5 PP9 6000 0:00 07: :00 �^ 00:00 01:00 02:00 03:00 04:00 05:00 0600 0800 09 10:00 11:00 1 12:00 13:00 14:00 0000 Time (min:sec) Conoco Phillips Alaska - CD5-26 F.- 15 Zone 17 144 Date: 12/18/2019 5000 Company: ConocoPhillips Project No: Well Name: C135-26 Stage(s): 17 a a000 BHST (eF): 155 Water Source: A 3000 N Depth: Water pH: 0 = 2000 Formation: Hydration pH: Analyst: Scott 160S Hydration Vise: CP @ 1000 0:00 07: :00 �^ 00:00 01:00 02:00 03:00 04:00 05:00 0600 0800 09 10:00 11:00 1 12:00 13:00 14:00 0000 Time (min:sec) Conoco Phillips Alaska - CD5-26 F.- 15 Zone 17 144 HALLIBURTONFlu37s� anat700c�1PP9 -2 PP9 -3 PP9 -4 PP9 ..._.-5 PP9 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: 2500 12/18/2019 2000 18 a 1500 T N u 1000 m 500 01 00:00 01:00 02:00 1 03:00 1 04:00 1 05:00 1 06:00 07:00 1 08:00 1 09:00 10:00 11:00 1 12:00 1 13:00 1400 1500 Time (mimsec) Conoco Phillips Alaska - CD5-26 Fann 15 Zone 18 145 Date: Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): BHST (°F): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott 4jjos Hydration Visc: 2500 12/18/2019 2000 18 a 1500 T N u 1000 m 500 01 00:00 01:00 02:00 1 03:00 1 04:00 1 05:00 1 06:00 07:00 1 08:00 1 09:00 10:00 11:00 1 12:00 1 13:00 1400 1500 Time (mimsec) Conoco Phillips Alaska - CD5-26 Fann 15 Zone 18 145 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 12/18/2019 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 19 BHST (°F): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Tjjos Hydration Visc: cp @ �—is broken-I200cp_1 - — - 1 PP9 2 PP9 —3 PP9 —4 PP9 5 PP9 2500 2000 O i I I I I I I I I I I I '1 hI :00 00 15I --I 0000 01:00 02:00 03:00 04:00 05:00 06:00 0700 0800 09:00 10:00 11'.00 12:00 13 14::00 Time (min:sec) Conoco Phillips Alaska- CD5-26 Fann 15 Zone 19 146 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: 12/18/2019 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 20 BHST (°F): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Tjos Hydration Visc: CP @ w 1st 2 1 F� P9 2 ping -3 FP9 -4 PP9 _ _._-5 PP9 3500 3000 2500 a 2000 T 0 1500 > 1000 500 0 00:00 01:00 02:00 03:00 04:00 0500 0600 0700 08.00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - CDS-26 Fann 15 Zone 20 147 HALLIBURTON IpP9 -2ppg -3pp9 -4ppg— —5pp9 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: 2500 -7—TIT - -- — - - J7 TT 1211812019 2000 — 21 U lsoa T .N g 1000 - — — N I 500 @ 0 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - CDS-26 Fano 15 Zone 21 148 Date: Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): BHST (°F): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott ROS Hydration Visc: 2500 -7—TIT - -- — - - J7 TT 1211812019 2000 — 21 U lsoa T .N g 1000 - — — N I 500 @ 0 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska - CDS-26 Fano 15 Zone 21 148 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/18/2019 Company: ConocoPhillips Project No: Well Name: CD5-26 Stage(s): 22 BHST (OF): 155 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst: Scott Rios Hydration Visc: cp @ Frais tirdlueagt 200cp1 ppg -2 Ppg -3 PP9 -4 PPg -5 PPg 3000 2500 a 2000 T p 1500 > 1000 500 0 0000 0100 02:00 0300 0400 0500 06:00 0700 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 Time (min:sec) Conoco Phillips Alaska- CD5-26 Fann 15 Zone 22 149 Conoco Phillips Alaska - CD5-26 Event Log Day 1 150 Conoco Phillips Alaska - CD5-26 Event Log Day 2 151 Conoco Phillips Alaska - CD5-26 Event Log Day 3 152 HAL.LIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2070484 Customer: ConocoPhillips Well Name & Number: CD5-26 Fluid System: Hybor G Date: December 5, 2019 10 minutes at 511 1/sec 10 minutes the shear rate was decreased to 100 I /sec SeaWater SL#1331 Technician(s) Performing Testing: Jason Doyle Reviewed & Approved By: O' INFORMATION AND TESTING CONDITIONS Customer: ConocoPhillips Fluid System: Hybor G Bob Type: B5X Well Name: CD5-26 Water Source: Seawater Shear Rate (1/sec): 511 / 100 Date: December 5, 2019 BHST ("F): 155 Lab Project ID: 2070484 FLUID DESIGN Test No: 1 1 z Water Analysis Lot # Chemical Units Chemical Concentrations Sample ID: SL#1331 BE -6 ppt 0.15 0.15 0.15 0.15 Total Hardness (ppm) LOSurf 300D opt 1.00 1.00 1.00 1.00 Alkalinity (ppm as WG -36 ppt 25.00 25.00 25.00 25.00 CaCO3 Chloride( m) MO -67 opt 0.25 0.25 0.25 0.25 Iron m /L CLr22 ppt 0.90 0.90 0.90 0.90 Sulfate (m /L CL31 ppt 0.45 1 0.45 1 0.45 0.45 Ions tested using Strip s in Lab H 7.01 Optiflo III ppt 2.00 2.00 2.00 Specific Gravity SP Breaker ppt 0.25 0.50 Temperature (°F) *calculated values FLUID PROPERTIES Test No: t 2 3 A 5 6 Gel Hydration (511/s) Water pH 7.01 7.01 7.01 7.01 Min. Viscosity (0) Temp. (oF): Base Gel (#) 25.00 25.00 25.00 25.00 1 10.0 76 Base Gel Vise (cP) 21.0 21.0 21.0 21.0 2 19.0 76 Base Gel pH 7.34 7.34 7.32 7.32 3 20.0 76 Base Gel Temp. (°F) 76 76 76 76 4 20.0 76 Buffered pH 9.43 9.43 1 9.38 9.40 1 1 1 1 5 20.0 1 76 Crosslink pH 9.73 9.73 9.70 9.64 10 21.0 76 Final pH 9.20 8.85 8.75 78Test Temp. (°F) 155 155 155 E55 Break Time (hr:min) NA 2:51 L45 057 Test Notes: BREAK TEST CHART i ......... \k* ......... tette - \hl4' ......... saw - \4' 9wIRP Vm* ......... 3WRk- \b* ......... 5 -ft _\h* - - - Tffpal-- T9PAR-.._ _. TffPa3e- - - ire- - - T9 ;. ID T ' i i M _Lim i 5b /i i X v i 2) o� o 01D aE 119 1z is 221 22 321 35D 49 49 Tnt m STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED JAN 10 2020 A f-Nt"%i-%n WELL COMPLETION OR RECOMPLETION REPORT AND LOG`' 1a. Well Status: Oil El • Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: �y. { 1b. Well Class: Development 2 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 12/4/2019 14. Permit to Drill Number/ Sundry: 219-107 - 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/11/2019 15. API Number: 50-103-20806-00-00 ` 4a. Location of Well (Governmental Section): Surface: 438' FNL, 2919' FEL, Sec 18, T11N, R4E, UM Top of Productive Interval: 1431' FNL, 3952' FEL, Sec 29, T11 N, R4E, UM Total Depth: 1512' FNL, 658' FEL, Sec 9, T1 ON, R4E, UM 8. Date TD Reached: 11/15/2019 16. Well Name and Number: CRU CD5-26 - 9. Ref Elevations: KB:73 - GL:33.7 - BF: 17. Field / Pool(s): Coleville River Unit /Alpine Oil Pool 10. Plug Back Depth MD/TVD: 33735/7,941 18. Property Designation: ASRC-NPR4, ASRC-AA092344, 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 349057 y- 5965780 Zone- 4 - TPI: x- 353117 y- 5954145 Zone- 4 Total Depth: x- 361431 y- 5938065 Zone- 4 11. Total Depth MD/TVD: • 33768/7943 • 19. DNR Approval Number: 932669, 340757, 932128, 342658 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1325/1320 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, 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 if necessary GR/Res/Sonic Log 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 H-40 35 115 35 115 42 10 yds 103/4 45.5 L-80 40 2240 40 2179 13.5 850sx 11.Oppg Class G a60 s X6%7 75/8 29.7 L-80 78.4 15282 78.4 7717 9.875 1 sx 15.8ppg Class G a 41/2 12.6 L-80 14593 33735 7639 7941 6.5"/'LINER / 6 V 24. Open to production or injection? Yes E] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): FRAC PORTS @: COMPLETION 15893-33686 MD and 7755-7938 TVD A iE VE -�(i �/ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 14610 14086/7572 14549/7634 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 12/28/2019 Method of Operation (Flowing, gas lift, etc.): bas { + " Date of Test: 1/6/2020 Hours Tested: 22 Production for Test Period Oil -Bbl: 1611 Gas -MCF: 484 Water -Bbl: 748 Choke Size: 128 beans Gas -Oil Ratio: 301 Flow Tubing Press. 436 Casinq Press: 1705 Calculated 24 -Hour Rate Oil -Bbl: 1758 Gas -MCF: 529 Water -Bbl: 1 816 Oil Gravitv - API (corr): Form 10-407 Revised 5/2017 e'��L _f l 1+/�gTINUED ON PAGE 2 RBDMS` 6w JAN 10 2020Subm'4v t ORIGINIALonl / l 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No 2 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1325 1320 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 15626 7747 information, including reports, per 20 AAC 25.071. Formation @ TPI -Alpine A C-30 2391 2310 C-10 3157 2847 K-3 5249 3771 K2 5813 4015 Albian 97 6760 4429 Albian 96 9636 5689 H RZ 12977 7159 Kalubik 13195 7255 Kuparuik C 13434 7359 LCU/Miluveach 13458 7369 TD 33768 7943 Formation at total depth: Alpine A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, aleon olo ical rei)ort, oroduction or well test results, 1)er 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Matt Smith 14 Authorized Title: Alaska Drilling Manager Contact Email: Matt. Smith2 co .com Authorizedj Contact Phone: 263-4324 c t ( Signature: c: '• Date: ( 202 - INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only CD5 - 26 Alpine A/C Dual Lateral Producer Final Schematic 4-'/7' x 1" GLM 20" 94# H-40 Welded Conductor to 115' MD 10-3/4" 45.5# L-80 HYD 563 x BTC Surface Casing at 2,240' MD 4-'/2"x1"GLM 4-1/2" 12.6# L-80 Hyd 563 4-'/2" x 1" GLM 7 518" 29.7# L-80 TXP Intermediate Casing at 15,281' MD 39# at heel TOC: 12,510' MD/ 6,953' TVD --------- - --------- Upper TNT Packer at 14,086 HP Sliding sleeve for Selectivity 3-112" 9.3# TN11OSS TNT Production Packer at 14,548' MD Upper Completion: 1)41/2"-12.6# Hyd 563 tubing 2) Shallow nipple profile 3.813" X profile 3) 3x 4-'/2' x 1" Camco KBMG GLM w/ DV 4) SLB DHG 5) TNT Packer 6) High Pressure 2.813" X sliding sleeve -up to open 7) High Burst X Nipple profile, 2.813" 8) TNT Packer 9) XN Nipple profile, 2.813" Lower Completion: 10)ZXP liner top packer & Flexlock Liner Hanger XO 5" Hydril 521 Box X 4-'/2" H563 pin 11) 4.5" Hydri1563 12.6# L-80 w/ Frac Ports ZXP liner top packer at 14,593' MD C sand Lateral 6 1/2" Hole TD 14,369- 17,932' MD - -------- I --------- 4'/2" 12.6# L-80 Hyd563 Liner w/ frac ports A sand Lateral 6 1/2" Hole TD 15,282'— 33,768' MD wNs PROD WELLNAME CD5-26 f(1� � h Well Attributes Conoc(3I hii6ps Field Name Wellbore APVUWI Wellbc Alaska, 1110. -.-vM, 6DD PROr NIPPLE WELLBORE CD5-26 Max Angle & MD jTD re Status I cl (°) MD (ftKB) Act Btm (ftKB) 0.79 25,590.07 Act 131 .0 nnotation End Date KB-Grd (ft) Rig Release Date AST WO: 39.28 1/4/2020 HORIZONTAL, CD5.26, 1(92020 2:13:03 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG' CD5-26 jennalt HANGER; .4 ......................... ...... 34 ................................. ... Last Rev Reason Annotation End Date Wellbore 1 Last Mod By REV REASON: Prep for Flowback 12/24/2019 CD5-26 1jennalt Casing Strings Casing Description OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I... Grade Top Thread CONDUCTOR 20 19.25 35.0 115.0 115.0 94.00 H40 Casing Description OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR; 35.0-115.0 SURFACE 103/4 9.95 39.7 2,240.2 2,179.4 45.50 L-80 TXP-M Casing Description OD (in) "Nin)Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (1... Grade Top Thread INTERMEDIATE 7111 6.88 78.4 15,281.7 7,717.0 29.70 L80 TXPM Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread A SAND LINER 41/2 3.96 14,593.3 33,735.4 7,940.9 12.60 L-80 Hyd563 SURFACE; 39.8-2,240.2 Liner Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Co. (in) NIPPLE; 2,484.8 14,593.3 7,639.4 83.44 PACKER "HRD-E" ZXP Liner Top Packer 5.740 14,613.2 7,641.6 83.45 PACKOFF "RS" Packoff Seal Nipple 4.250 14,615.5 7,641.9 83.45 HANGER "DG" Flex -Lock Liner Hanger- pinned 2500 psi 4.800 14,624.8 7,643.0 83.45 XO - Reducing XO, 5.5" H563 x 4.5" H563, BxP 4.390 GAS LIFT; 4,449.3 14,636.1 7,644.2 83.45 SBE SBE, 5" H521 x 4.5" H521, 80-40 4.000 14,654.4 7,646.3 83.46 XO - Reducing XO Pup, 4.5" H521 x 4.5" H563 3.958 15,893.3 7,755.5 89.51 FRAC Baker frac sleeve #22, Hyd563 2.335 GAS LIFT: 9,4799 Sleeve/Port 2.695" OD Ball 16,744.8 7,760.8 89.61 FRAC Baker frac sleeve #21, Hyd563 2.295 Sleeve/Port 2.645" OD Ball 17,583.7 7,771.0 89.24 FRAC Baker frac sleeve #20, Hyd563 2.255 GAS LIFT; 13,998.1 Sleeve/Port 2.595" OD Ball 18,417.3 7,776.8 89.52 FRAC Baker frac sleeve #19, Hyd563 2.215 GAUGE/ PUMP SENSOR; Sleeve/Port 2.545" OD Ball 14,0680 19,267.7 7,785.4 89.40 FRAC Baker frac sleeve #18, Hyd563 2.175 Sleeve/Port 2.495" OD Ball PACKER; 14,085.6 20,123.5 7,794.6 89.40 FRAC Baker frac sleeve #17, Hyd563 2.135 Sleeve/Port 2.455" OD Ball SLIDING SLEEVE; 14,140.9 20,975.2 7,804.6 89.20 FRAC Baker rac sleeve #16, Hyd563 2.095 Sleeve/Port 2.415" OD Ball 21,819.4 7,816.3 89.14 FRAC Baker frac sleeve #15, Hyd563 2.055 Sleeve/Port 2.375" OD Ball NIPPLE; 14,257.4 22,670.1 7,829.9 89.95 FRAC-Baker frac sleeve #14, Hyc1563 2.015 Sleeve/Port 2.335" OD Ball 23,514.0 7,833.5 89.61 FRAC Baker frac sleeve #13, Hyd563 1.975 Sleeve/Port 2.295" OD Ball PACKER; 14,5490 24,360.9 7,840.6 89.66 FRAC Baker frac sleeve #12, Hyd563 1.935 Sleeve/Port 2.255" OD Ball NIPPLE; 14,568.5 25,204.9 7,848.6 89.28 FRAC Baker frac sleeve #11. Hyd563 1.895 LOCATOR; 14,590.8 Sleeve/Port 2.215" OD Ball MULE SHOE; 14,591.5 26,055.5 7,855.6 89.17 FRAC Baker frac sleeve #10, Hyd563 1.855 Sleeve/Port 2.175" OD Ball 26,903.9 7,864.0 89.43 FRAC Baker frac sleeve , Hyd563 2.175 Sleeve/Port 2.135" OD Ball I 27,754.0 7,877.2 89.44 FRAC Baker frac sleeve #8, Hyd563 2.135 Sleeve/Port 2.095" OD Ball 28,602.0 7,880.1 89.43 FRAC Baker frac sleeve #7, Hyd563 2.095 Sleeve/Port 2.055" OD Ball INTERMEDIATE; 78.4-15,281.7 29,449.3 7,888.7 89.39 FRAC Baker frac sleeve #6, Hyd563 2.055 Sleeve/Port 2.015" OD Ball 30,294.8 7,897.4 89.29 FRAC Baker frac sleeve #5, Hyd563 2.015 Sleeve/Port 1.975" OD Ball 31,138.3 7,905.0 89.60 FRAC Baker frac sleeve #4, Hyd563 1.975 Sleeve/Port 1.935" OD Ball 31,987.0 7,917.5 89.36 FRAC-Baker frac sleeve #3, Hyc1563 1.935 Sleeve/Port 1.895" OD Ball 32,836.9 7,924.8 89.78 FRAC Baker frac sleeve #2, Hyd563 1.895 Sleeve/Port 1.855" OD Ball 33,686.2 7,938.0 87.04 FRAC Baker frac sleeve #1, Hyd563 1.855 Sleeve/Port 1 1.815" OD Ball Tubing Strings Tubing Description Strtng Ma... ID (in) Top (ftKB) Set Depth (k.. Set Depth (TVD) (... Wt (Ib/ft) Grade Top Connection TUBING 41/2 3.96 34.5 14,610.0 7,641.3 12.60 L-80 Hyd563 PRODUCTION 11 Completion Details Top (TVD) Top Incl Nominal Top (ftKa) (ftKB) V) Item Des Com ID (in) 34.5 34.5 0.00 HANGER FMC 4-12" Tubing Hanger Hydril HYD 563 3.958 2,484.8 2,388.9 34.65 NIPPLE NIPPLE,LANDING,4 1/2";'X",3.813", H563 3.813 14,068.0 7,568.5 78.40 AU E/ PUMP SLB Solid Gauge Mandrel w/ 11 mm encapsulated I wire, H563 3.884 SENSOR 14,084.2 7,571.7 78.78 XO - Reducing X0, 4-1/2" 12.6# H563 Box x 3-1/2" 9.2# H563 Pin 2.992 14,085.6 7,572.0 78.82 PACKER Halliburton TNT Packer, 3-1/2" H563 2.900 14,140.9 7,582.2 80.00 SLIDING SLEEVE,SLIDING, 3-1/ "APCV-II, .813", SLB, X Profile, Up to 2.813 SLEEVE open 14,257.4 7,600.2 81.99 NIPPLE NIPPLE,LANDING,3-1/2",X,2.813",Hydril 563 -High Burst 2.813 14,549.0 7,634.3 83.42 PACKER Halliburton TNT Packer, 3-1/2" H563 2.900 14,568.5 7,636.5 83.43 NIPPLE NIPPLE,LANDING,3-1/2",XN, 2.813",EUE 8rd 2.750 14,590.6 7,639.0 83.44 LOCATOR Baker Mechanical locator, EUE 8rd (Shear screws 1.04' below 3.000 locator) A SAND LINER; 14,593.3- 33,735A WNS PROD WELLNAME CD5-26 WELLBORE CD5-26 Cement Detail Report CD5-26 In. )m String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/9/2019 06:00 Cement Details Description Surface Casing Cement Cementing Start Date 10/13/2019 16:00 Cementing End Date 10/13/2019 19:00 Wellbore Name CD5-26 Comment Cement Stages Stage # 1 Description Lead - Surface Casing Cement Objective Lead-Isolate surface casing annulus to surface Top Depth (ftKB) 39.3 Bottom Depth (ftKB) 1,740.0 Full Return? Yes Vol Cement... 113.0 Top Plug? No Btm Plug? Yes Q Pump Init (bbl/m... 5 6 Q Pump Final (bbl/... Q Pump Avg (bbl/... 6 P Pump Final (psi) 920.0 P Plug Bump (psi) Recip? Yes Stroke (ft) 10.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Lead Cement-Pumped 288.8bbls, 11ppg, Deeperete, 0.5% D167, 0.06 gps D185, 0.1gps D047 1740' to 1328'MD 50% excess 1328'MD-surface 250% excess above permafrost depth Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description Estimated Top (ftKB) 0.0 Est Btm (ftKB) 0.0 Amount (sacks) Class Mudpush II Volume Pumped (bbl) 75.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (°/) Density (Ib/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 39.3 Est Btm (ftKB) 1,740.0 Amount (sacks) 850 Class Volume G 288.8 Pumped (bbl) Yield (ft'/sack) 1.91 Mix H2O Ratio (gal/sa... 6.65 Free Water (%) Density (Ib/gal) 11.00 Plastic Viscosity (cP) 208.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) 1,740.0 Est Btm (ftKB) Amount 1,740.0 (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Stage # 2 Description Tail - Surface Casing Cement Objective Tail-Secure the shoe and bottom 500ft of annulus Top Depth (ftKB) 1,740.0 Bottom Depth (ftKB) 2,240.2 Full Return? Vol Yes Cement... Top Plug? Yes Btm Plug? No Q Pump Init (bbl/m... Q 5 3 Pump Final (bbl/... Q Pump Avg (bbl/... 4 P Pump Final (psi) 445.0 P Plug Bump (psi) 1,000.0 Recip? I Yes 110.00 Stroke (ft) Rotated? I No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Tail-Pumped 59.5bbls, 15.8ppg Class G, with D-047 0.05gps, D-255 0.5%, D-065 0.3%, D-186 0.015% 2240'-1740'50% excess Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,740.0 Est Btm (ftKB) Amount 2,240.0 288 (sacks) Class Volume G 59.5 Pumped (bbl) Yield (ft'/sack) 1.16 Mix H2O Ratio (gal/sa... 5.04 Free Water (%) Density (Ib/gal) Plastic 15.80 138.8 Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 1/1 Report Printed: 12/31/2019 a. Cement Detail Report CD5-26 y String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 10/9/2019 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 10/26/2019 05:19 10/26/2019 08:00 CD5-26 Comment No losses during cementing. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing The greater of 500'MD or �2507VD 12,850.0 15,294.6 No 0.0 Yes Yes Cement of cement Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 2 8 380.0 900.0 Yes 120.00 No I Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment PJSM. Blowed down top drive. R/U cement and bleeder hose. Pressure tested lines to 4,000 psi. Pumped 64 bbls of 13 ppg mud push at 4 bpm ( Pressure = 100-280 psi, F/O = 17%). Batch mixed cement. Dropped bottom plug. Pumped 214 bbls of 15.8 ppg tail cement ( Pressure = 320 psi, F/O = 16%). Dropped top plug. Pumped 20 bbls water. Displaced 663 bbls (6,580 strokes, FCP = 360 psi, F/O = 8%) w/ rig pumps to bump the plug and pressure up to 900 psi (for 5 minutes). B/O and checked floats. Cement was in place at 0810hr. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 12,850.0 15,294.0 1,036 G 214.1 Yield (fe/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.06 15.80 160.3 6.18 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/31/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/9/2019 10/9/2019 1.50 MIRU MOVE MOB P Clean and secure cellar, raise up 0.0 0.0 06:00 07:30 outside stairs and landings. 10/9/2019 10/9/2019 2.00 MIRU MOVE MOB P Scope derrick in and secure/pin top 0.0 0.0 07:30 09:30 drive and prepare to layover. 10/9/2019 10/9/2019 0.75 MIRU MOVE MOB P Raise C-section and pin. SIMOPS- 0.0 0.0 09:30 10:15 unplug modules. 10/9/2019 10/9/2019 1.50 MIRU MOVE MOB P Prepare and skid rig floor. 0.0 0.0 10:15 11:45 10/9/2019 10/9/2019 0.25 MIRU MOVE MOB P Lower derrick. SIMOPS-Stomp motor 0.0 0.0 11:45 12:00 complex. 10/9/2019 10/9/2019 0.50 MIRU MOVE MOB P Continue to lower derrick SIMOPS- 0.0 0.0 12:00 12:30 stomp motor complex. 10/9/2019 10/9/2019 2.50 MIRU MOVE MOB P Move pump, pits and casing modules, 0.0 0.0 12:30 15:00 get onto suspension and ready to hook-up to Peak trucks. Place modules to staging area 10/9/2019 10/9/2019 3.00 MIRU MOVE MOB P Lay rig mats, raise cellar, unpin 0.0 0.0 15:00 18:00 pipeshed and move into place for truck. 10/9/2019 10/9/2019 1.50 MIRU MOVE MOB P Continue to move pipeshed into place 0.0 0.0 18:00 19:30 for truck hook-up. Move out of way of sub. 10/9/2019 10/9/2019 1.50 MIRU MOVE MOB P Stomp forward, turn stompers for 50ft 0.0 0.0 19:30 21:00 turn with sub off of well CD5-92 location for truck, install jeep. 10/9/2019 10/9/2019 0.50 MIRU MOVE MOB P Pull sub off mats at CD5-92 position 0.0 0.0 21:00 21:30 land position out of way.. 10/9/2019 10/9/2019 1.00 MIRU MOVE MOB P Move rig mats from CD5-92 to CD5- 0.0 0.0 21:30 22:30 26- 10/9/2019 10/10/2019 1.50 MIRU MOVE MOB P Move sub onto mats at CD5-26. 0.0 0.0 22:30 00:00 position with sow, remove jeep. 10/10/2019 10/10/2019 2.00 MIRU MOVE MOB P Stomp sub complex over well CD5- 0.0 0.0 00:00 02:00 26., square and level sub over well SIMOPS-lay mats for pipeshed with two loaders. 10/10/2019 10/10/2019 1.00 MIRU MOVE MOB P Hook-up and position pipeshed with 0.0 0.0 02:00 03:00 truck. 10/10/2019 10/10/2019 1.00 MIRU MOVE MOB P Stomp pipeshed into position under 0.0 0.0 03:00 04:00 sub complex. SIMOPS - change valves in pits. 10/10/2019 10/10/2019 1.00 MIRU MOVE MOB P Continue stomp and changing 0.0 0.0 04:00 05:00 valves.Move pits with truck into position. Take -off truck and stomp into place with sub. 10/10/2019 10/10/2019 1.00 MIRU MOVE MOB P P/U pump module on truck and stage, 0.0 0.0 05:00 06:00 10/10/2019 10/10/2019 4.00 MIRU MOVE MOB P Continue to stomp and shim pipeshed 0.0 0.0 06:00 10:00 and pin to sub. 10/10/2019 10/10/2019 1.00 MIRU MOVE MOB P Square up, shim and spot pits to sub. 0.0 0.0 10:00 11:00 SIMOPS-move and shim casing module into place. 10/10/2019 10/10/2019 1.00 MIRU MOVE MOB P Square up and spot pump module to 0.0 0.0 11:00 12:00 pits. Simops-plug in pipeshed, pits to sub. 10/10/2019 10/10/2019 1.50 MIRU MOVE MOB P Square up and spot power module to 0.0 0.0 12:00 13:30 pump module. Simops-plug in pump to pits. Lower stairs around rig and address landings. 10/10/2019 10/10/2019 0.50 MIRU MOVE MOB ---JP Raise derrick. SIMOPS-plug in power 0.0 0.0 13:30 14:00 module, start to make-up pit interconnect Page 1/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/10/2019 10/10/2019 0.50 MIRU MOVE MOB P Skid rig floor over well. 0.0 0.0 14:00 14:30 10/10/2019 10/10/2019 0.75 MIRU MOVE MOB P Raise upper and lower cattle chute. 0.0 0.0 14:30 15:15 SIMOPS-Plug in sub, turn on steam to sub. 10/10/2019 10/10/2019 0.75 MIRU MOVE MOB P Lower C-section. SIMOPS-plug in 0.0 0.0 15:15 16:00 derrick. 10/10/2019 10/10/2019 1.00 MIRU MOVE MOB P Lower cellar house and prepare to 0.0 0.0 16:00 17:00 scope up. Swap from moving gens to main Cat power per DDI electrician. 10/10/2019 10/10/2019 1.00 MIRU MOVE MOB P Scope derrick up and spot power 0.0 0.0 17:00 18:00 module. Hook up geronimo and derrick climber lines, M/U mud pits and pump room inter -connect lines, post permit to drill. 10/10/2019 10/10/2019 4.00 MIRU MOVE MOB P Remove bridle line and yokes, 0.0 0.0 18:00 22:00 connect derrick lights, hoop up Kelly hose, install C.O.M., lower upper derrick ladder, hook up SRL's, SIMOPS-Load BHA, HWDP, DP into shed and strap 10/10/2019 10/11/2019 2.00 MIRU MOVE NUND P PU High pressure surface riser, make 0.0 0.0 22:00 00:00 up surface bag, install flow box, hook up hole fill and jet lines, load shed with 10 3/4" surface casing. 10/11/2019 10/11/2019 3.00 MIRU MOVE NUND P Tq up riser, set 90' MH, MU bell 0.0 0.0 00:00 03:00 nipple. SIMOPS, PU elevators, slips, BHA 10/11/2019 10/11/2019 3.00 MIRU MOVE BHAH P PJSM, RIH and rack back HWDP/Jars 0.0 0.0 03:00 06:00 and DC's 10/11/2019 10/11/2019 2.00 MIRU MOVE BHAH P MU 13 1/2" Surface BHA#1 per DD, 0.0 115.0 06:00 08:00 scribe/orient MWD/UBHO 10/11/2019 10/11/2019 1.00 MIRU MOVE BHAH P MU 13 1/2" surface BHA#1 as per 115.0 115.0 08:00 09:00 Schlum DD. Conduct scribe/orient procedure. Verify offset put in correctly 10/11/2019 10/11/2019 1.00 MIRU MOVE BHAH P Move drillcollar stand, jars and HWDP 115.0 115.0 09:00 10:00 stand from Drillers side to off drillers slide to accomodate wireline gyro rig - in. PU and RU Pollard witreline for gyro. 10/11/2019 10/11/2019 0.50 MIRU MOVE BHAH P Hold prespud meeting and AAR for rig 115.0 115.0 10:00 10:30 move 10/11/2019 10/11/2019 0.25 MIRU MOVE SFTY P Fill conductor and riser, pressure test 115.0 115.0 10:30 10:45 mud lines to 3500psi. 10/11/2019 10/11/2019 0.25 MIRU MOVE CIRC P Establish circulation, tag base on 115.0 115.0 10:45 11:00 conductor, 350gpm, 280psi, 29%FO, 40rpm, 1-21K TQ. PU/SO=58K/66K, RTG=60K 10/11/2019 10/11/2019 1.00 SURFAC DRILL DDRL P Spud and drill 13 1/2" surface hole 115.0 184.0 11:00 12:00 from 115'-184'MD. 450gpm, 574psi, 76% FO, 40rpm, 2-4K TQ, 5K WOB, PU/SO=58K/66K, RTG=60K, AST=O, ART=0.55, ADT=0.55. Total Bit Hrs=0.55, Total Jars=64.21, no losses for tour. 10/11/2019 10/11/2019 3.25 SURFAC DRILL DDRL P Continue drill 13 1/2" surface hole 184.0 370.0 12:00 15:15 from 184'-370'MD. 550gpm, 903psi, 79% FO, 40rpm, 2-4K TQ, 5K WOB, PU/SO=70K/66K, RTG=62K, AST=O, ART=1.3, ADT=1.3, Total Bit Hrs=1.85, Total Jars=65.51, no losses fortour. Page 2/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/11/2019 10/11/2019 0.25 SURFAC DRILL DDRL P Swap rig to Hi -line power 184.0 370.0 15:15 15:30 10/11/2019 10/11/2019 2.50 SURFAC DRILL DDRL P Continue drilling 13 1/2" surface hole 370.0 595.0 15:30 18:00 from 370-595ft MD. 550gpm, 574psi, 78% FO, 40rpm, 2-4K TQ, 5K WOB, PU/SO=71 K/681K, RTG=62K, AST=O, ART=1.3, ADT=1.3, Total Bit Hrs=1.85, Total Jars=65.51, Gyro confirmation survey at 468.34'MD 10/11/2019 10/12/2019 6.00 SURFAC DRILL DDRL P Continue drilling 13 1/2" surface hole 595.0 1,039.0 18:00 00:00 from 595-1039ft MD. 550gpm, 550psi, 78% FO, 50rpm, 2-4K TQ, 5-7K WOB. PU/SO=74K/82K, RTG=74K, AST=1.07, ART=2.32, ADT=3.39, Total Bit Hrs=7.94, Total Jars=71.60, Gyro confirmation survey at 751ft, 940ft. 10/12/2019 10/12/2019 6.00 SURFAC DRILL DRLG P Continue drilling 13 1/2" surface hole 1,039.0 1,507.0 00:00 06:00 from 1039'-1507' MD. 600gpm, 1196psi, 80% FO. 50rpm, 3K TQ, 5-8K WOB, PU/SO=87K/94K, RTG=88K, AST=1.33, ART=2.13, ADT=3.46, Total Bit Hrs=11.40, Total Jars=75.06. Gyro survey at 1319'MD. 10/12/2019 10/12/2019 6.00 SURFAC DRILL DRLG P Continue drilling 13 1/2" surface hole 1,507.0 2,000.0 06:00 12:00 from 1507'-2000' MD. 800gpm, 1830psi, 24% FO. 50rpm, 5K TQ, 8K WOB, PU/SO=100K/103K, RTG=104K, pump 2 x 20bbl nutplug sweeps. AST=1.42, ART=2.75, ADT=4.17, Total Bit Hrs=15.57, Total Jars=79.23, 10/12/2019 10/12/2019 3.25 SURFAC DRILL DRLG P Continue drilling 13 1/2" surface hole 2,000.0 2,252.0 12:00 15:15 from 2000'-2252'MD, 2190'TVD- 800gpm, 1895psi, 24% FO, 50rpm, 5K TQ, 13K WOB, PU/SO= 101 K/1 03K, RTG=104K, AST=0.70, ART=1.61, ADT=2.31, Total Bit Hrs=17.88, Total Jars=81.54, Dump and dilute @2100' MD. 40bbl NP sweep at 2194'MD, shoot final survey as per Schlum DD. 10/12/2019 10/12/2019 0.50 SURFAC CASING CIRC P Circulate BUx1 while standing back 1 2,152.0 2,167.0 15:15 15:45 std from 2152' to 2167'MD at 800gpm, 2175psi, 24%FO, 40rpm, 5K tq, RTG WT=100k, total strokes pumped =3419 Stks 10/12/2019 10/12/2019 0.25 SURFAC CASING SRVY P Drop battery Gyro 2,167.0 2,167.0 15:45 16:00 as per Gyrodata. Let fall for 5 min and perform quadrant check as per Gyrodata.. 10/12/2019 10/12/2019 1.50 SURFAC CASING CIRC P Continue to circ BUx3 while standing 2,167.0 1,887.0 16:00 17:30 back std for each BU. from 2167" to 1887'MD. at 800gpm, 2300psi, 42% FO, 40rpm, 5K tq, RTG wt=100k 10/12/2019 10/12/2019 0.50 SURFAC CASING OWFF P OWFF for 30min, dropping. 1,887.0 1,887.0 17:30 18:00 Page 3/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/12/2019 10/12/2019 2.50 SURFAC CASING TRIP P Blow down jet line and line up hole fill 1,887.0 568.0 18:00 20:30 POOH on elevators from 1887'- 1165'MD. Rack back 5" HWDP and jar stand. PU/SP= 1 05k/94K at 1800'- Experienced 15K overpull POOH at 25fpm. Maintain constant hole fill over the top. Manual strap every 5 stands. 10/12/2019 10/12/2019 2.25 SURFAC CASING BHAH P LD Schlum BHA #1 as per DD. Broke 568.0 96.0 20:30 22:45 apart collar to remove stuck Gyro tool. Found tool lower than planned as it passed thru UBHO. Broke apart BHA subs to remove Gyrodata tool from UBHO sub. LD Gyrodata tool to ground. 10/12/2019 10/13/2019 1.25 SURFAC CASING BHAH P Conitnue lay down BHA and bit. 96.0 0.0 22:45 00:00 10/13/2019 10/13/2019 2.00 SURFAC CASING BHAH P Clean rig floor and remove BHA subs. 0.0 0.0 00:00 02:00 Build DC stand from drilling configuration. PU Doyon and rig up Volant tool to run 10 3/4" casing. 10/13/2019 10/13/2019 4.00 SURFAC CASING PUTB P Make-up 10.75", L-80 shoe trac assbly 0.0 845.0 02:00 06:00 as per Doyon Casing rep. Bakerloking all connections. MU torque=27k ft-lbs. Checked floats, OK. Continue running 10.75", L-80, TXPM, 45.5ppf casing from surface to 845'MD. installed centralizers as per detail. Using Volant CRT, MU torque=27k ft-lbs, PU/SO wt=71 k/73k at 800ftMD. Filled casing on the fly and topped off every 10 jts. 10/13/2019 10/13/2019 1.25 SURFAC CASING PUTB P Continue running 10.75", L-80, 845.0 1.151.0 06:00 07:15 TXPM, 45.5ppf casing from 845'- 1151'MD. installed centralizers as per detail. Using Volant CRT, MU torque=27k ft-lbs,. Filled casing on the fly and topped off every 10 jts. SO wt=80k 10/13/2019 10/13/2019 2.25 SURFAC CASING PUTB P Establish circulation and pump down 1,151.0 1,496.0 07:15 09:30 hole while running in from 1151' to 1496'MD. Using Volant CRT, pump rate=2 bpm. 150psi, FO=80% Total strokes pumped=9389stks (939bbis). SO wt=80K 10/13/2019 10/13/2019 0.50 SURFAC CASING CIRC P CBU below permafrost and stage up 1,496.0 1,536.0 09:30 10:00 pumps to 7bpm.from 1496' to 1596'MD. Pumped 1441stks, 7bpm. 197psi, 56% FO. SO wt=78K. 10/13/2019 10/13/2019 2.00 SURFAC CASING PUTB P Continue running 10.75", L-80, 1,536.0 2,085.0 10:00 12:00 TXPM, 45.5ppf casing from 1536'- 2085'MD. installed centralizers as per detail. Using Volant CRT, MU torque=27k ft-lbs,. Filled casing on the fly and topped off every 10 jts. SO wt=80k. Losses for tour=18bbls. 10/13/2019 10/13/2019 1.00 SURFAC CASING PUTB P Continue running 10.75". L-80, 2,085.0 2,240.0 12:00 13:00 TXPM, 45.5ppf casing from 2085'- 2240'MD. installed centralizers as per detail. Using Volant CRT. MU torque=27k ft-lbs.. Filled casing on the fly and topped off every 10 jts. SO wt=80k. PU and MU xoverjoint, hanger and landing joint per FMC/DDI reps. PU/SO wts=121 K/1 00K Page 4/51 ReportPrinted: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 t- M Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 10/13/2019 10/13/2019 1.75 SURFAC CEMENT COND P Establish circulation to condition mud 2,240.0 2,240.0 13:00 14:45 for surface casing cement job while reciprocating. Staging up pump rate upmaintaming 10ppg, YP=18-25, ICP=235psi, 1.5bpm, FCP=97psi, 7bpm, FO=44% 10/13/2019 10/13/2019 0.50 SURFAC CEMENT CMNT P SD, rig up cement line to Volant 2,240.0 2,240.0 14:45 15:15 swivel. 10/13/2019 10/13/2019 0.50 SURFAC CEMENT COND P Re-establish circulation thru cement 2,240.0 2,240.0 15:15 15:45 line and continue to condition mud at 7bpm while reciprocating. Held PJSM, surfce cement job, total strokes pumped 7116 (711 bbls). 10/13/2019 10/13/2019 2.25 SURFAC CEMENT CMNT P Pump surface cement job as per 2,240.0 2,240.0 15:45 18:00 Schlum/CPAI detail. PU/SO wt=127K/120K, 10/13/2019 10/13/2019 1.00 SURFAC CEMENT CMNT P Continue to pump surface cement as 2,240.0 2,240.0 18:00 19:00 per Schlum detail. PU/SO wt=124K/100K. Bumped plug @1849 strokes at 3bpm w/515psi over final displacement pressure tol000psi, held for 5 minutes. Total pumped 1854stks, rigged down cement hose and checked floats. Floats held.. 10/13/2019 10/13/2019 1.00 SURFAC CEMENT CMNT P Flushed surface lines. HP riser, cycled 2,240.0 2,240.0 19:00 20:00 annular and fluided past with fluid. Pumped thru injection line on lower spool with black water @ 5bpm- Continued cleaning cement from pits, through cuttings tank, Eddy pump. Cycled annular preventer and rinsed clean. 10/13/2019 10/13/2019 1.00 SURFAC CEMENT CMNT P Rigged down casing equipment. 2,240.0 2,240.0 20:00 21:00 Cleaned out and LD Volant tool. LD casing equipment and backed out landing joint as per FMC rep. 10/13/2019 10/13/2019 1.00 SURFAC CEMENT CLEN P Drained riser and cleaned out cement 2,240.0 2,240.0 21:00 22:00 from annular preventer. 4" conductor valves and cellar box. 10/13/2019 10/14/2019 2.00 SURFAC CEMENT CLEN P Remove bell nipple, annular preventer 2,240.0 2,240.0 22:00 00:00 and high pressure riser. 10/14/2019 10/14/2019 3.25 SURFAC CEMENT NUND P ND Tee and slip lok adapter flange as 2,240.0 2,240.0 00:00 03:15 per FMC. Cleaned flange and layed down. Performed Halliburton Epoxy Cement Cemlok cap job as per HES rep and procedure. SIMOPS-grease choke manifold, clean rig floor cemenmting valves,removed wellside side valves for installtion. 10/14/2019 10/14/2019 1.00 SURFAC WHDBOP NUND P Nipple up FMC Gen 5 Unihead starter 2,240.0 2,240.0 03:15 04:15 and tubing head sections wellhead as per FMC rep. Tested lower wellhead seals to 1,000psi, witnessed by CPAI. 10/14/2019 10/14/2019 1.75 SURFAC WHDBOP NUND P NU high pressure riser and adapter 2,240.0 2,240.0 04:15 06:00 flange. 10/14/2019 10/14/2019 5.75 SURFAC WHDBOP NUND P Contine to NU riser and flange with 2,240.0 2,240.0 06:00 11:45 Sweeny wrench. NU BOPE, MU choke and kill lines. MU flowbox and flowline, RU MPD equipment. SI MOPS - gather elevations, RU to perform Wellworc bias testing and MPD test. Page 5/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (W) 10/14/2019 10/14/2019 0.25 SURFAC WHDBOP NUND P Flood line, BOP, MPD skid with water 2,240.0 2,240.0 11:45 12:00 and purge. 10/14/2019 10/14/2019 1.50 SURFAC WHDBOP MPDA P Perform Wellworc Bias testsing thru 2,240.0 2,240.0 12:00 13:30 MPD sustem as per MPD rep. 10/14/2019 10/14/2019 1.00 SURFAC WHDBOP NUND P Pull MPD test cap, install trip nipple, 2,240.0 2,240.0 13:30 14:30 RU to test BOPE. BOP test waived by AGOCC, Lou Laubenstein, 06:14 10/14/2019. All test charts are to be submitted with test reports. AOGCC has a must catch for the next test cycle (60days max allowable). 10/14/2019 10/14/2019 5.50 SURFAC WHDBOP PRTS P Test BOPE. All tests 250psi 2,240.0 2,240.0 14:30 20:00 low/3500psi high for 5 charted minutes with exception of manual operated and super chokes tested to 250/2000psi for 5 charted minutes. Using 5" test jt, test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR. Test choke valves 1-15, manual operated and super choke, choke and kill manuals and HCR's, 4" valve on kill line, Blind/shear rams, 5" TIW #1 and #2, 5" dart, upper and lower IBOP Perform Koomey drawdown. ACC=2950psi, Manifold=1500psi, ACCU=1600psi after all functions on just bottles. 15 secs to 200psi build with 1 electric pump, 101 secs to build to full system pressure with 2 electric and 2 air pumps. Closing times, annular=23secs, UPR=18secs, blind/shears=16secs, LPR=16sec, Choke HCR=2 sec, kill HCR=2sec 10/14/2019 10/14/2019 0.50 SURFAC WHDBOP SEQP P Rig down test equipment, blow down 2,240.0 2,240.0 20:00 20:30 choke line, kill line, top drive 10/14/2019 10/14/2019 0.50 SURFAC WHDBOP OTHR P Pull test plug and install 10" long wear 2,240.0 2,240.0 20:30 21:00 ring. Run in LDS. 10/14/2019 10/14/2019 1.00 SURFAC DRILLOUT BHAH P PU Schlum tools for BHA#2. 2,240.0 2,240.0 21:00 22:00 10/14/2019 10/15/2019 2.00 SURFAC DRILLOUT BHAH P PU BHA#2 as per Schlum DD Gauge 2,240.0 2,240.0 22:00 00:00 all stabs and install floats as per DD Maintain constant hole fill over the top and strap pits at start and end of BHA. SIMOPS-pressure test MPD equipment in BOP deck. 10/15/2019 10/15/2019 1.50 SURFAC DRILLOUT BHAH P Continue to PU BHA#2 from 127' to 2,240.0 2,240.0 00:00 01:30 605'MD as per SChlum DD. Gauge all stabsand install floats as per DD. Maintain constant hole fill over the top and strap trip pit at drill collars and HWDP. PU/S0=65K/65K at 700'MD. 10/15/2019 10/15/2019 1.00 SURFAC DRILLOUT TRIP P Trip in hole with 5" drillpipe from 2,240.0 2,240.0 01:30 02:30 derrick @ 100 fpm from 605' to 2017' Maintained constant hole fill and manual strapped every 5 stands. 10/15/2019 10/15/2019 1.00 SURFAC DRILLOUT CIRC P Perform Schlum shallow test as per 2,240.0 2.240.0 02:30 03:30 DD at 2015'MD. Pumped at 650gpm, 1425psi. Circulated 1 bottoms up at 600gpm. PU/S0=99K/97K. 10/15/2019 10/15/2019 0.50 SURFAC DRILLOUT PRTS P Blow down top drive and hole fill line. 2,240.0 2,240.0 03:30 04:00 Rigged up to test casing. Flush lines and rig up sensator to OA flange. Test surface lines. Bleed air out of system Page 6/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/15/2019 10/15/2019 1.00 SURFAC DRILLOUT PRTS P Perform casing test to 3500psi/30 2,240.0 2,240.0 04:00 05:00 minutes@2015' @ 2015'MD as per CPAI rep. Charted and witnessed. Bled off volume to closed pit. Record volumes and open up wellbore. Blow down kill line and rig down casing test equipment. 10/15/2019 10/15/2019 1.00 SURFAC DRILLOUT COCF P Wash and ream down to plugs/float 2,240.0 2,240.0 05:00 06:00 collar. Found cement at 2163'MD. Establish drilling rate as per Schlum DD. 600gpm/1445psi. TQ off=3-4K. TQ on=3.5K, PU/SO=108K/103K- 10/15/2019 10/15/2019 6.00 SURFAC DRILLOUT COCF P Drill out wiper plugs and float 2,240.0 2,240.0 06:00 12:00 collar/shoe tack and rathole as per DD from 2163'MD to 2240' MD (shoe), 650gpm. 1445psi, 30-40rpm, 3-4K tq. 10k WOB, RTG wt=105K, 10/15/2019 10/15/2019 0.50 SURFAC DRILLOUT COCF P Cleaned rathole to 2252' and drilled 2,252.0 2,272.0 12:00 12:30 20 ft of new hole to 2272'MD, 650 gpm, 1445psi, 30-40rpm, 3-4K TQ, 10 -20K WOB, RTG WT=105K displacing to 9.6ppg LSND on the fly 10/15/2019 10/15/2019 0.50 SURFAC DRILLOUT DISP P Continue to displace to 9.6 ppg LSND 2,272.0 2,272.0 12:30 13:00 mud until even in/out while rotating and reciprocating from 2271'MD to 2239'MD with 650gpm, 1073psi, FO=32%, RPM=80, TO off=3K, PU/SO=108K/103K, RTG wt=105K, rtg tq=3K, total pumped=4559 strokes (456bbls) 10/15/2019 10/15/2019 0.50 SURFAC DRILLOUT FIT P Pull back into casing racking back one 2,272.0 2,272.0 13:00 13:30 stand PU Wt=108k, OWFF, Static 10/15/2019 10/15/2019 0.25 SURFAC DRILLOUT FIT P Rig up to conduct F.I.T test. 2,272.0 2,272.0 13:30 13:45 10/15/2019 10/15/2019 1.00 SURFAC DRILLOUT FIT P Perform F.I.T. test to 1050psi charted. 2,272.0 2,272.0 13:45 14:45 Rig out test equipment and lines. Calculated F.I.T.=18.9 ppg with 9.6ppg mud. 10/15/2019 10/15/2019 1.50 INTRM1 DRILL DDRL P RIH one stand to bottom and drill 9 2,272.0 2,390.0 14:45 16:15 7/8" hole from 2272' to 2390'MD, (2179'TVD). 700 gpm. 1275psi, 34% FO, 100 rpm. 6K WOB, off bottom 1257psi, PU/SO110k?109K. RTG=104K, 2K TQ. 10/15/2019 10/15/2019 0.75 INTRMI DRILL DDRL P Obtain baseline parameters and drop 2,390.0 2,390.0 16:15 17:00 underreamer opening ball as per Schlum DD, 50rpm, 2.5K tq, 1248psi, 700gpm, PU/SO=110k/109K. RTG wt= 104K, pump down ball at 50spm, 56psi, 30rpm, 2K tq. Ball on seat at 167 strokes, inc pump rate as per Schlum DD to open reamer at 1252psi. Verified open against baseline parameters and pull/ledge test. 10/15/2019 10/15/2019 0.50 INTRMI DRILL DDRL P Ream down rest of std with reamer 2,390.0 2,390.0 17:00 17:30 open from 2269-2390'MD, 850gpm, 1297psi, 100RPM, 4K TQ Page 7/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/15/2019 10/15/2019 0.50 INTRM1 DRILL DDRL P Drlg 9 7/8"x11' intermediate hole with 2,390.0 2,452.0 17:30 18:00 underreamer from 2390'-2452'MD, 2366'TVD, 850gpm, 1074psi, 65% FO. 120rpm, 6K TO, 10K WOB, PU/SO=110K/109K, RTG w1=1 04K, 3K TO ADT=1.45, total bit hours=1.45, total jars=82.99 SPR's at 2994md (2227'TVD), MW=9.6ppg MP#1 - 30/40spm, 120/150psi MP#2 - 30/40spm, 120/150psi 10/15/2019 10/16/2019 6.00 INTRM1 DRILL DDRL P Drlg 9 7/8"x11' intermediate hole with 2,452.0 3,883.0 18:00 00:00 underreamer from 2455'-3308'MD. 3308'MD, 850gpm, 1740psi, 72% FO. 120rpm, 6K TO, 1 OK WOB, PU/SO=119K/106K, RTG wt=116K, 4K TO ADT=1.45, total bit hours=1.45, total jars=82.99SPR's@5963'M D, 4078'TVD, 9.7ppg, 10/16/2019 10/16/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 3,308.0 3,883.0 00:00 06:00 underreamer from 3308'-3900'MD, 3183'TVD, 850gpm, 1900psi, 74% FO, 140rpm, 8K TO, 10-12K WOB, off bttm=1897psi, PU/SO=120K/106K, RTG wt=117K, 4.5K TO ADT=4.21, total bit hours=10.20, total jars=91.74 10/16/2019 10/16/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 3,900.0 4,763.0 06:00 12:00 underreamer from 3900'-4763'MD, 3563'TVD, 850gpm, 2417psi, 79% FO, 150rpm, 9K TO, 26K WOB, off bttm=2390psi, PU/SO=135K/113K, RTG wt=125K, 4.5K TO ADT=3.95, total bit hours=14.15, total jars=95.69 10/16/2019 10/16/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 4,763.0 5,594.0 12:00 18:00 underreamer from 4763'-5594'MD, 3915'TVD, 850gpm, 2297psi, 79% FO, 180rpm, 9K TO, 26K WOB, ECD=11.01 ppg, Off Bttm=2100psi, PU/SO=139K/124K, RTG wt= 126K. 5K TO ADT=3.97, total bit hours=18.12, total jars=96.66 Page 8/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 AM Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/16/2019 10/17/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 5,597.0 6,720.0 18:00 00:00 underreamer from 5594'-6720'MD, 44107VD, 850gpm, 2475psi, 80% FO, 180rpm. 12K TO, 15K WOB, ECD=11.01 ppg, Off Bttm=2460psi, PU/SO=141 K/1 22K, RTG wt=127K. 4.5K TO ADT=3.82, total bit hours=21.94, total jars=103.48hrs Pumped to/hi jamming sweep @6346'MD Dump and dilute @ 6600'MD w/ 9.2ppg LSND mud SPR's@5963'MD, 4078'TVD, 9.7ppg, 19:35hrs #1 MP - 20/30spm, 230/270psi MP#2 - 20/30spm - 225/265psi Tour Losses=0 10/17/2019 10/17/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 6,720.0 7,739.0 00:00 06:00 underreamer from 6720'-7750MD, 4864'TVD, 850gpm, 2471 psi, 78% FO, 180rpm, 14K TQ. 15K WOB, ECD=10.95ppg, Off Bttm=2450psi, PU/SO=165K/135K, RTG w4=144K. 10K TO ADT=3.86, total bit hours=25.80, total jars=107.34hrs Pumped to/hi jamming sweep @6346'MD SPR's@7000'MD, 4582'TVD, 9.7+ppg, 19:35hrs #1 MP - 20/30spm, 230/270psi MP#2 - 20/30spm - 225/265psi Tour Losses=0 10/17/2019 10/17/2019 6.00 INTRMI DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 7,739.0 8,761.0 06:00 12:00 underreamer from 7739'-8761'MD, 5304'TVD. 850gpm, 2172psi, 78%, FO, 180rpm, 17.5K TO, 22K WOB. ECD=11.03ppg, Off Bttm=2100psi, PU/SO=1 77K/1 34K, RTG wt=147K, 10K TO ADT=3.5, total bit hours=29.3, total jars=110.84hrs Pumped Io/hi jamming sweep @6346'MD Dump and dilute 280bbls@ 7945'MD Pump LO/HIGH sweeps at 8229' and 8508' Page 9/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/17/2019 10/17/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 8,761.0 10,017.0 12:00 18:00 underreamer from 8761'-10017'MD, 58507VD, 850gpm, 2572psi, 78% FO, 180rpm, 20K TO, 24K WOB, ECD=11.07ppg, Off Bttm=2500psi, PU/SO=178K/162K, RTG wt=147K, 14K TO ADT=3.72, total bit hours=33.02, Total jars=1 1 4.56hrs Dump and dilute 280bbls@ 9630'MD SPR's@7000'MD, 4582'TVD, 9.7+ppg, 19:35hrs #1 MP - 20/30spm, 230/270psi MP#2 - 20/30spm - 225/265psi Tour Losses=0 10/17/2019 10/18/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 10,017.0 11,230.0 18:00 00:00 underreamer from 10017'-11230'MD. 6390 'TVD, 850gpm, 2675psi, 74% FO.. 180rpm, 24K TQ, 23K WOB, ECD=11.01 ppg, Off Bttm=2500psi, PU/SO=202K/160K, RTG wt= 172K, 15K TO ADT=4.24, total bit hours=37.26, total jars=1 1 8.80hrs Dump and dilute 280bbls@ 10580'MD SPR's@7000'MD. 45827VD. 9.7+ppg, 19:35hrs #1 MP - 20/30spm, 230/270psi MP#2 - 20/30spm - 225/265psi Tour Losses=0 10/18/2019 10/18/2019 6.00 INTRMI DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 11230.0 11,970.0 00:00 06:00 underreamer from 11230'-11970'MD, 6712'TVD, 850gpm, 2610psi, 74% FO, 180rpm. 25K TQ, 23K WOB, ECD=10.73ppg, Off Bttm=1225psi at 550gpm, PU/SO=238K/148K, RTG wt=182K. 17K TO ADT=4.11, total bit hours=41.37, total jars=122.91 hrs Pumped 20/20 to/hi vis anti -jamming sweep at 11335'MD Dump and dilute 550bbls@ 115200'MD Page 10151 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/18/2019 10/18/2019 4.25 INTRMI DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 11,970.0 12,563.0 06:00 10:15 underreamer from 11970'-12563'MD. 6938'TVD, 850gpm, 2760psi, 74% FO, 180rpm, 26K TO, 19K WOB, ECD=10.85ppg, Off Bttm=1278psi at 550gpm. PU/SO=244K/146K, RTG wt=186K, 19K TO ADT=2.83, total bit hours=44.20, total jars=125.741 hrs 10/18/2019 10/18/2019 0.75 INTRM1 DRILL CIRC P Rotate and reciprocate bottoms up 12,563.0 12,563.0 10:15 11:00 @55spm @1200psi, RPM=160. 17K TQ. SIMOPS - PJSM on pulling trip nipple and installing RCD bearing 10/18/2019 10/18/2019 0.50 INTRM1 DRILL OWFF P Blow down Top Drive and prepare to 12,563.0 12,563.0 11:00 11:30 install RCD bearing as per MPD rep. OWFF=static. 10/18/2019 10/18/2019 0.50 INTRM1 DRILL MPDA P Pull trip nipple and install RCD as per 12,563.0 12,563.0 11:30 12:00 MPD rep. Rotate pip@5rpm. Broke in RCD bearing for 5 mins @50rpm. Follow with 100rpm for 5 mins. Tour losses=0. 10/18/2019 10/18/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 12,563.0 12,875.0 12:00 18:00 underreamer from 12563'-12875'MD. 7110'TVD, 850gpm, 3270psi, 65% FO. 160rpm, 26K TQ, 19K WOB, ECD=11.48ppg, Off Bttm=1675psi at 550gpm, PU/SO=266K/144K, RTG wt=182K, 21KTO ADT=3.95, total bit hours=48.15, total jars=129.69hrs 10/18/2019 10/19/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 12,875.0 13,346.0 18:00 00:00 underreamer from 12875'-13346'MD, 73157VD, 850gpm, 3407psi, 48% FO, 160rpm, 27K TQ, 16K WOB, ECD=11.64ppg, Off Bttm=1775psi at 550gpm, PU/SO=270K/150K, RTG wt=185K, 21 K TO ADT=4.55, total bit hours=52.70, total jars=134.241 hrs SPR's@12938'MD, 7138'TVD, 10.2ppg, 19:30hrs MP#1 - 20spm, 540/250psi(MPD), 30spm. 560/210psi(MPD) MP#2 - 20spm, 540/250psi(MPD). 30spm, 560/210psi(MPD) Tour Losses=0 Page 11151 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/19/2019 10/19/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 13,346.0 13,693.0 00:00 06:00 Rhino underreamer from 13346'- 13693'MD, 7463'TVD, holding 375psi back pressure MPD with injection pump on connections, (11.5ppg MWE). 850gpm, 3637psi, 57% FO, 160rpm, 28K TQ, 18K WOB, ECD=11.67ppg, ADT=5.16, total bit hours=57.86, total jars=139.401 hrs Lubes and glass bead additions working well to keep torques manageable. 10/19/2019 10/19/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 13,693.0 14,072.0 06:00 12:00 Rhino underreamer from 13693'- 14072'MD. 7570'TVD, holding 375psi back pressure MPD with injection pump on connections, (11.5ppg MWE), 850gpm, 3387psi, 57% FO, 160rpm, 28K TQ, 28K WOB. ECD=11.67ppg, ADT=4.76, total bit hours=62.62, total jars=144.16hrs S P R's @ 14070' M D. 75707V D, 10.4+ppg, 11:500hrs MP#1 - 30spm, 680/265psi(MPD), 40spm, 680/245psi(MPD) MP#2 - 30spm, 270/270psi(MPD)- 40spm, 680/250psi(MPD) 10/19/2019 10/19/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 14,072.0 14,380.0 12:00 18:00 Rhino underreamer from 14072'- 14380'MD, 7612'TVD, holding 375psi back pressure MPD with injection pump on connections, (11.5ppg MWE), 850gpm. 3703psi, 57% FO, 160rpm, 23K TQ, 25K WOB, ECD=11.57ppg, ADT=4.65, total bit hours=67.27, total jars= 148.81 hrs 10/19/2019 10/20/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 14,380.0 14,683.0 18:00 00:00 Rhino underreamer from 14380'- 14683'MD, 76487VD, holding 375psi back pressure MPD with injection pump on connections. (11.5ppg MWE), 850gpm, 3560psi, 58% FO, 120-160rpm (some torque shocks observed in alternating lithology), 26K TQ, 25K WOB, ECD=11.54ppg, ADT=5.32, total bit hours=72.59, total jars=154.13hrs No losses last 24 hours No PU and SO weights recorded through the shale sections. Page 12/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 . , it Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/20/2019 10/20/2019 6.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 14,463.0 15,145.0 00:00 06:00 Rhino underreamer from 14683'- 15145' MD, 7698'TVD, holding 375psi back pressure MPD with injection pump on connections, (11.5ppg MWE), 850gpm, 3820psi, 51% FO, 120rpm, 27K TQ, 24K WOB, ECD=11.56ppg, ADT=4.82, total bit hours=77.41, total jars=158.95hrs No PU and SO weights recorded through the shale sections. 10/20/2019 10/20/2019 2.00 INTRM1 DRILL DDRL P RWD 9 7/8"x11" intermediate hole with 15.145.0 15,294.0 06:00 08:00 Rhino underreamer from 15145'- 15294' MD, 7714'TVD, FINAL INT TD, holding 375psi back pressure MPD with injection pump on connections. (11.5ppg MWE), 850gpm, 3940psi, 51 % FO, 120rpm, 27K TQ, 24K WOB, TQ=20K off bttm, ECD=11.57ppg, ADT=1.86. total bit hours=79.27, total jars=160.81 hrs No PU and SO weights recorded through the shale sections. 10/20/2019 10/20/2019 4.00 INTRM1 CASING CIRC P CBU x 4, rack back stand after 1 BU 15,294.0 15,110.0 08:00 12:00 after reciprocating 15294'- 15,110'MD weight up to 10.8ppg, rpm=160, tq=23k, gpm=850, psi=3940 10/20/2019 10/20/2019 2.00 INTRM1 CASING CIRC P Continue to circ 4xBU, R/B stand after 15,110.0 15,110.0 12:00 14:00 reciprocating 15191' to 15110' MW=10.8ppg, rpm=160. TQ=23K, GPM=850, psi=3940 10/20/2019 10/20/2019 4.00 INTRM1 CASING BKRM P BROOH from 15110'-14067"MD, 15,110.0 14,067.0 14:00 18:00 gpm=800, psi=3560, rpm=150, tq=19- 20K, FP=61%, ECD=11.89ppg, RTG WT=186K 10/20/2019 10/21/2019 6.00 INTRM1 CASING BKRM P BROOH from 14067'-13594'MD, 14,067.0 13,594.0 18:00 00:00 gpm=775, psi=3420, rpm=125, tq=19- 22K, pulling at 225fph„ FO=61 %, ECD=11.92ppg, RTG WT=178K Encountered tight spot/pack-off @ 14073'MD. Tour Losses = 205bbls (123 bbls est. loss at 14073'MD) 10/21/2019 10/21/2019 6.00 INTRM1 CASING BKRM P BROOH F/ 13,594' MD - T/ 13,121' 13,594.0 13,121.0 00:00 06:00 MD, W/ GPM = 775, PSI = 3375, RPM = 160TQ = 22K. F/O = 60%, ECD = 12.0 PPG, RT WT = 180K 10/21/2019 10/21/2019 6.00 INTRM1 CASING BKRM P BROOH F/ 13,121' MD - T/ 12,648' 13,121.0 12,648.0 06:00 12:00 MD, W/ GPM = 800. PSI = 3102. RPM = 160, TO = 19-20K. F/O = 50%, ECD = 11.91 PPG, RT WT = 176K Page 13151 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/21/2019 10/21/2019 4.75 INTRM1 CASING CIRC P CBU X 4 Racking back a stand each 2 12,648.0 12,552.0 12:00 16:45 B/U, Pump High Vis Nut Plug & High Vis High Density sweeps, F/ 12,648'MD T/ 12,552'MD. GPM = 800, PSI = 3120, RPM = 160, TO = 16.5K. F/O = 65%, ECD = 11.98PPG. 10/21/2019 10/21/2019 1.00 INTRM1 CASING CIRC P Drop ball (DIA.1.65) to close Rhino 12,552.0 12,552.0 16:45 17:45 reamer as per SLB rep. Parameters before, 700 gpm @ 2525, 50 rpm @ 16.5k Tq. P/U=178K. S/O=170K, ROT=175K, TRPM=2343, After ball seat @1772 STKS, 360 PSI increase sheared @235 GPM, PSI=2100. 700 GPM, TRPM=2890, 10/21/2019 10/21/2019 0.25 INTRM1 CASING SMPD P B/D Top drive, attempt to SOOH on 12,552.0 12,552.0 17:45 18:00 elevators @ 12,552' MD. Observed 45k overpull repeated. 10/21/2019 10/21/2019 0.50 INTRM1 CASING SMPD P Continue attempt to SOOH from 12,552.0 12,525.0 18:00 18:30 12,552' MD to 12,525' MD with 50k OP, unsuccessful. 10/21/2019 10/22/2019 5.50 INTRM1 CASING BKRM P M/U to top drive and backream out @ 12,525.0 11,910.0 18:30 00:00 130 fph from 12,525' MD to 11,910' MD. 650 gpm @ 2424 psi. 160 rpm 18 -22k Tq. Maintagin ECD below 11.9 ppg, ROT wt=165k. Tour Losses=0 bbls 10/22/2019 10/22/2019 6.00 INTRM1 CASING BKRM P BROOH from 11.910' MD to 11,465' 11,910.0 11,465.0 00:00 06:00 MD w/ GPM = 650 gpm. SPP = 2440 psi, Rotary = 160 rpm, TO = 17-24 kftlbs, F/O = 32%, ECD =11.86 ppg. and RT Wt = 160 klbs. 10/22/2019 10/22/2019 0.75 INTRM1 CASING BKRM P BROOH from 11,465' MD to 11,420' 11,465.0 11,420.0 06:00 06:45 MD w/ GPM = 650 gpm, SPP = 2440 psi, Rotary = 160 rpm, TO = 17-24 kftlbs, F/O = 32%, ECD =11.86 ppg, and RT Wt = 160 klbs. 10/22/2019 10/22/2019 2.25 INTRM1 CASING CIRC P CBU 2X. Pumped 80 bbls HVNP 11,420.0 11,420.0 06:45 09:00 sweep and diution. Rotated and reciprocated. GPM - 640 gpm, SPP = 2,264 psi. Rotary = 160 gpm, and TO = 13-15 kftlbs 10/22/2019 10/22/2019 1.00 INTRM1 CASING SMPD P Attempted to SOOH on elevators 11.420.0 11,420.0 09:00 10:00 Observed 50 klbs OP. Attempted to work through 5 X. Observed 50 klbs OP each time. 10/22/2019 10/22/2019 2.00 INTRM1 CASING PMPO P Pumped out of hole from 11,420' MD 11,420.0 10,852.0 10:00 12:00 to 10,852' MD w/ 5" DP/ Racked back in derrick. GPM = 645 gpm, SPP = 2,320 psi, P/U Wt = 228 klbs, S/O Wt = 118 klbs, Monitored displacement on pits 2-4. B/D T/D. 10/22/2019 10/22/2019 6.00 INTRM1 CASING SMPD P SOOH on elevators w/ MPD from 10,852.0 7,363.0 12:00 18:00 10,852' MD to 7,363' MD. B/P in slips = 190 psi, B/P out of slips = 340 psi. P/U Wt = 171 klbs. S/O Wt = 116 klbs, Monitored displacement on pits 2-4. 10/22/2019 10/22/2019 1.00 INTRM1 CASING SMPD P SOOH on elevators w/ MPD from 7,363.0 6,970.0 18:00 19:00 7,363' MD to 6,970' MD. B/P in slips = 185 psi, B/P out of slips = 330 psi. Monitored displacement on pits 1-4. Page 14/51 Report Printed: 1 2/912 01 9 Operations Summary (with Timelog Depths) CD5-26 CEO 0 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (V[3) 10/22/2019 10/22/2019 1.00 INTRM1 CASING CIRC P Circulated, rotated and reciprocated 6,970.0 6,970.0 19:00 20:00 from 7,041' MD to 6,970' MD w/ GPM = 675 gpm, SPP = 2,065 ps, F/0 = 40%, Rotary = 160 rpm, and TO = 10 - 27 kftlbs to breakover. ECD = 11.7 ppg, RT Wt = 130 kibs, Total Strokes = 8000. 10/22/2019 10/23/2019 4.00 INTRM1 CASING BKRM P BROOH from 6970' MD to 6,303' MD 6,970.0 6,303.0 20:00 00:00 w/ GPM = 675 gpm, SPP = 1,950 psi, Rotary = 160 rpm, TO = 8-12 kftlbs, F/0 = 51%, ECD = 11.76 ppg, and Rot Wt = 126 kibs. 10/23/2019 10/23/2019 3.00 INTRM1 CASING BKRM P BROOH from 6,303' MD to 5,691' MD 6,303.0 5,691.0 00:00 03:00 w/ GPM = 675 gpm, SPP = 1,900 psi. Rotary = 160 rpm, TO = 8-12 kftlbs, F/0 = 51 %, ECD = 11.76 ppg, and Rot Wt = 122 kibs. 10/23/2019 10/23/2019 1.75 INTRM1 CASING CIRC P Circulated, rotated and reciprocated 5,691.0 5,691.0 03:00 04:45 from 5,691' MD to 5,740' MD w/ GPM = 675 gpm, SPP = 1,670 ps, F/0 = 52%, Rotary = 160 rpm. and TO = 8 kftlbs. ECD = 11.68 ppg, and RT Wt = 120 klbs. Pumped 40 bbls H.V. Nut plug sweep and 40 bbls weighted nut plug sweeps w/ no observed increase in cuttings returned. Total pumped strokes = 13,000. SIMOPS: L/D 16 stands of 5" DP off line. 10/23/2019 10/23/2019 1.25 INTRM1 CASING SMPD P Blowed down top drive. SOOH from 5.691.0 5,105.0 04:45 06:00 5,691' MD to 5,105' MD w/ 5" DP and racked back in derrick. P/U Wt = 99 klbs, S/0 Wt = 94 kibs, Monitored displacement on pits 3-4 10/23/2019 10/23/2019 4.00 INTRM1 CASING SMPD P SOOH on elevators w/ MPD from 5,105.0 2,162.0 06:00 10:00 5,105' MD to 2,162' MD. B/P to slips = 175 psi, B/P out of slips = 340 psi. P/U Wt = 99 kibs, S/0 Wt = 94 klbs- Monitored displacement on pits 3-4. 10/23/2019 10/23/2019 1.50 INTRM1 CASING CIRC P CBU 2X. Pumped 40 bbls HVNP and 2,162.0 2,162.0 10:00 11:30 70 bbls HVNP sweeps. GPM = 580 gpm, SPP = 1,295 ps. Rotary = 60 rpm, and TO = 3 kftlbs 10/23/2019 10/23/2019 0.50 INTRM1 CASING OWFF P OWFF (Static). 2,162.0 2,162.0 11:30 12:00 10/23/2019 10/23/2019 0.75 INTRM1 CASING SMPD P SOOH on elevators w/ MPD from 2,162.0 1,000.0 12:00 12:45 2,162' MD to 1,000' MD. B/P in slips = 175 psi, B/P out of slips = 340 psi. P/U Wt = 86 klbs, S/0 Wt = 91 klbs Monitored displacement on pits 3-4 10/23/2019 10/23/2019 1.00 INTRM1 CASING MPDA P PJSM. Pulled MPD bearing and 1.000.0 1,000.0 12:45 13:45 installed trip nipple. 10/23/2019 10/23/2019 0.25 INTRM1 CASING TRIP P POOH on elevators from 1,000' MD to 1,000.0 605.0 13:45 14:00 605' MD w/ 5" DP racked back in derrick. P/U Wt = 71 klbs, S/0 Wt = 81 klbs. Monitored displacement on pit 3. 10/23/2019 10/23/2019 4.00 INTRMI CASING BHAH P PJSM. L/D BHA from 605' MD to 605.0 0.0 14:00 18:00 surface. Monitored displacement on pit 3. 10/23/2019 10/23/2019 1.00 INTRM1 CASING BHAH P Cleaned and cleared rig floor. Laid 0.0 0.0 18:00 19:00 down remaining BHA components. 10/23/2019 10/23/2019 0.50 INTRM1 CASING WWWH P Flushed BOP stack at 7 bpm w/ 85 psi 0.0 0.0 19:00 19:30 from ground level to annular preventers. Page 15151 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) 1.1,0 CD5-26 . .. .-M) Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/23/2019 10/23/2019 1.00 INTRM1 CASING SEQP P Blowed down top drive and hole fill 0.0 0.0 19:30 20:30 line. Pumped out BOP stack and retrieved 10" Wear ring. Built 7 5/8" test joint and installed upper test plug. 10/23/2019 10/23/2019 1.00 INTRM1 CASING SEQP P Closed blind rams and bled down 0.0 0.0 20:30 21:30 Koomey. C/O upper VBRs for 7.625" straight body rams. Energized Koomey. 10/23/2019 10/23/2019 1.75 INTRM1 CASING BOPE P Rigged up to test Annular and UPR on 0.0 0.0 21:30 23:15 7.625" test joint. Tested annular to 250 psi/2500 psi (Passed). Tested UPR to 250 psi/3500 psi (Passed). Rigged down testing equipmen. Blow down. Broke down 7.625" test joint. Cleaned and cleared rig floor. 10/23/2019 10/24/2019 0.75 INTRM1 CASING SLPC P Hung the block and rigged up to slip 0.0 0.0 23:15 00:00 and cut drill line 10/24/2019 10/24/2019 1.25 INTRM1 CASING SLPC P Slipped and cut 110' of drill line. 0.0 0.0 00:00 01:15 Unhung blocks. Calibrated Amphion/Totco, Checked Crown-o- matic. Cleared and cleaned up tools. 10/24/2019 10/24/2019 1.25 INTRM1 CASING RURD P R/U casing running equipment. 0.0 0.0 01:15 02:30 Torqued Volant to Top Drive to 37 kftlbS. 10/24/2019 10/24/2019 3.50 INTRM1 CASING PUTB P P/U 7 5/8" 39 ppf TXP from surface to 0.0 922.0 02:30 06:00 922' MD. M/U, Baker locked, and torqued shoe track to 26.1 klbs. Checked floats. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 67 klbs, and S/O Wt = 72 klbs at 850' MID, 10/24/2019 10/24/2019 6.00 INTRM1 CASING PUTB P RIH w/ 7 5/8" 39 ppf TXP casing from 922.0 3,340.0 06:00 12:00 922' MD to 3,340' MD. MUT = 26.1 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 134 klbs. and S/O Wt = 133 klbs 10/24/2019 10/24/2019 3.25 INTRM1 CASING PUTB P RIH w/ 7 5/8" 39 ppf TXP casing from 3,340.0 4,992.0 12:00 15:15 3,340' MD to 4.992' MD. MUT = 26.1 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 170 klbs, and S/O Wt = 140 klbs. 10/24/2019 10/24/2019 0.50 INTRM1 CASING OTHR P PJSM. Changed out cup and stabbing 4,992.0 4,992.0 15:15 15:45 head on CRT. 10/24/2019 10/24/2019 1.75 INTRM1 CASING PUTB P RIH w/ 7 5/8" 39 ppf TXP casing from 4,992.0 5,784-0- 15:45 17:30 4,992' MD to 5,784' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 184 klbs, and S/O Wt = 136 klbs. 10/24/2019 10/24/2019 0.50 INTRM1 CASING CIRC P CBU Staging up to 6 bpm. SPP = 316 5,784.0 5,784.0 17:30 18:00 psi. Initial loss rate was 40 bph. 10/24/2019 10/24/2019 1.00 INTRM1 CASING CIRC P Continued circulating at 6 bpm. w/ ICP 5,784.0 5,784.0 18:00 19:00 = 385 psi and FCP = 320 psi. Pumped 5,800 strokes Pumped until mud was 10.9 ppg in and out. P/U Wt = 176 klbs, and S/O Wt = 138 klbs. Page 16/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/24/2019 10/25/2019 5.00 INTRM1 CASING PUTB P RIH w/ 7 5/8" 39 ppf TXP casing from 5.784.0 8,300.0 19:00 00:00 5,784' MD to 8,300' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 246 klbs. and S/O Wt = 140 klbs @ 8,000' MD 10/25/2019 10/25/2019 2.25 INTRM1 CASING PUTB P RIH w/ 7 5/8" 29.7 ppf TXP casing 8300.0 9,100.0 00:00 02:15 from 8,300' MD to 9,100' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. Initial Breakover Wt = 265 klbs, P/U Wt = 255 klbs, and S/O Wt = 138 klbs. 10/25/2019 10/25/2019 2.25 INTRM1 CASING CIRC P Circulated at 9,100' MD. Slowly 9,100.0 9,100.0 02:15 04:30 staging up to 6 bpm w/ ICP = 440 psi and FCP = 330 psi (11.3 ppg return mud). Total strokes = 6,200 psi. P/U Wt = 252 klbs, and S/O Wt = 142 klbs. 10/25/2019 10/25/2019 1.50 INTRM1 CASING PUTB P RIH w/ 7 5/8" 29.7 ppf TXP casing 9,100.0 10,100.0 04:30 06:00 from 9,100' MD to 10,100' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. S/O Wt = 138 klbs. 10/25/2019 10/25/2019 4.75 INTRM1 CASING PUTB P RIH w/ 7 5/8" 29.7 ppf TXP casing 10,100.0 12,351.0 06:00 10:45 from 10,100' MD to 12,351' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 310 klbs, and S/O Wt = 148 klbs. 10/25/2019 10/25/2019 0.75 INTRM1 CASING PUTB P RIH w/ 7 5/8" 29.7 ppf TXP casing 12,351.0 12,621.0 10:45 11:30 from 12,351' MD to 12,621' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 1 Oth joint. Manually strapped trip pit every 10 joints. P/U Wt = 310 klbs, and S/O Wt = 148 klbs. 10/25/2019 10/25/2019 3.00 INTRM1 CASING CIRC P CBU at 12,621' MD. Reciprocated 12,621.0 12,621.0 11:30 14:30 pipe between 12,621' MD and 12,581' MD. Staged up to 6 bpm w/ ICP = 349 psi and FCP = 307 psi (11.0 ppg return mud). P/U Wt = 300 klbs, and S/O Wt = 168 klbs. 10/25/2019 10/25/2019 1.00 INTRM1 CASING PUTB P RIH w/ 7 5/8" 29.7 ppf Eagle casing 12,621.0 12,931.0 14:30 15:30 from 12,621' MD to 12,931' MD. MUT = 20.0 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 316 klbs, and S/O Wt = 160 klbs. 10/25/2019 10/25/2019 2.50 INTRM1 CASING PUTB P RIH w/ 7 5/8" X-O to TXP casing 12,931.0 14,135.0 15:30 18:00 from 12,931' MD to 14,135' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. P/U Wt = 425 klbs, and S/O Wt = 152 klbs. Page 17/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/25/2019 10/25/2019 3.00 INTRM1 CASING PUTB P RIH w/ 7 5/8" 29.7 ppf TXP casing 14,135.0 15.161.0 18:00 21:00 from 14,135' MD to 15.161' MD. MUT = 21.3 kftlbs. Filled pipe on the fly using the Volant tool whilst topping off every 10th joint. Manually strapped trip pit every 10 joints. S/O Wt = 117 klbs. 10/25/2019 10/25/2019 1.50 INTRM1 CASING CIRC P Staged up pumps to 6 bpm. SPP = 15,161.0 15,161.0 21:00 22:30 430 psi, F/O = 22%, and Total strokes = 3,300 10/25/2019 10/25/2019 0.50 INTRM1 CASING PUTB P M/U hanger and landing joint. Landed 15,161.0 15.281.0 22:30 23:00 hanger at 15,281' MD. 10/25/2019 10/26/2019 1.00 INTRM1 CEMENT CIRC P Reciprocated pipe f/ 15,280' MD to 15,281.0 15,281.0 23:00 00:00 15,260' MD. Circulated to thin mud down to 10.6 ppg, 6 bpm, F/O = 22%. SPP = 430 psi, Attained P/U Wt = 370 klbs once hole cleaned up. S/O Wt = 126 klbs. Total strokes = 7,800 psi. 10/26/2019 10/26/2019 4.50 INTRM1 CEMENT CIRC P Reciprocated pipe from 15,281' MD to 15,281.0 15.281.0 00:00 04:30 15,260' MD while circulating and thing down the MW to 10.6 ppg. Staged pumps up to 8 bpm. F/O = 23%, SPP = 595 psi, P/U Wt = 370 klbs, S/O Wt = 126 klbs, Total strokes = 25,600 10/26/2019 10/26/2019 4.00 INTRM1 CEMENT CMNT P PJSM. Blowed down top drive. R/U 15,281.0 15,281.0 04:30 08:30 cement and bleeder hose. Pressure tested lines to 4,000 psi. Pumped 64 bbls of 13 ppg mud push at 4 bpm ( Pressure = 100-280 psi, F/O = 17%). Batch mixed cement. Dropped bottom plug. Pumped 214 bbls of 15.8 ppg tail cement ( Pressure = 320 psi, F/O = 16%). Dropped top plug. Pumped 20 bbls water. Displaced 663 bbls (6,580 strokes, FCP = 360 psi. F/O = 8%) w/ rig pumps to bump the plug and pressure up to 900 psi (for 5 minutes). B/O and checked floats Cement was in place at 0810hr. 10/26/2019 10/26/2019 2.00 INTRM1 WHDBOP WWSP P Set and tested 7 5/8" pack off to 5,000 15,281.0 15,281.0 08:30 10:30 psi. 10/26/2019 10/26/2019 1.50 INTRM1 WHDBOP CLEN P Cleaned and cleared rig floor of non- 15,281.0 15,281.0 10:30 12:00 essential tools. 10/26/2019 10/26/2019 2.75 INTRM1 WHDBOP SEQP P R/U to drill 6 1/2" production hole. C/O 0.0 0.0 12:00 14:45 saver sub, and pipe rams to 2 7/8" x 5 1/2" VBR's. 10/26/2019 10/26/2019 2.00 INTRM1 WHDBOP BHAH P PJSM. P/U BHA#3 from surface to 0.0 350.0 14:45 16:45 350' MD. P/U Wt = 47 klbs, and S/O Wt = 55 klbs. Monitored returns on pit #7. 10/26/2019 10/26/2019 2.75 INTRM1 WHDBOP TRIP P RIH while picking up 4" XT39 drill pipe 350.0 2,230.0 16:45 19:30 from 350' MD to 2,230' MD. P/U Wt = 80 klbs, and S/O Wt = 81 klbs. Monitored returns on pit #7. 10/26/2019 10/26/2019 1.00 INTRM1 WHDBOP DHEQ P Filled pipe. Performed MWD shallow 2,230.0 2,230.0 19:30 20:30 hole test. GPM = 230 gpm and F/O = 15%. 10/26/2019 10/26/2019 3.00 INTRM1 WHDBOP TRIP P Continued to RIH while picking up 4" 2,230.0 4,880.0 20:30 23:30 XT39 drill pipe from 2,230' MD to 4,880' MD. P/U Wt = 90 klbs, and S/O Wt = 91 klbs. Monitored returns on pit #7. Filled pipe every 20 stands. 10/26/2019 10/27/2019 0.50 INTRM1 WHDBOP SVRG P Serviced top drive, blocks, and crown 4,880.0 4,880.0 23:30 00:00 1 1 I I I Page 18/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/27/2019 10/27/2019 5.00 INTRM1 WHDBOP TRIP P Continued to RIH while picking up 4" 4,880.0 7,114.0 00:00 05:00 XT39 drill pipe from 4,880' MD to 7,114' MD. P/U Wt = 96 klbs, and S/0 Wt = 95 klbs. Monitored returns on pit #2. Filled pipe every 20 stands. 10/27/2019 10/27/2019 1.00 INTRM1 WHDBOP SVRG P Inspected and maintained Top Drive. 7,114.0 71114.0 05:00 06:00 10/27/2019 10/27/2019 3.00 INTRM1 WHDBOP RGRP T Changed out upper I -BOP 7,114.0 7,114.0 06:00 09:00 10/27/2019 10/27/2019 2.00 INTRM1 WHDBOP PACK P PJSM. P/U storm packer. P/U Wt = 7,114.0 7,174.0 09:00 11:00 111 klbs. and S/0 Wt = 98 klbs. RIH 60' and set packer in place. 10/27/2019 10/27/2019 1.00 INTRM1 WHDBOP RURD P PJSM. Rig up to test BOPE w/ 4" test 7,174.0 7,174.0 11:00 12:00 joint. 10/27/2019 10/27/2019 3.00 INTRM1 WHDBOP BOPE P Tested BOPE. All tests 250psi 7,174.0 7,174.0 12:00 15:00 low/3500psi high for 5 charted minutes with exception of manual operated and super chokes tested to 250/2000psi for 5 charted minutes. Using 4" test jt, test annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR. Test choke valves 1-15, manual operated and super choke, choke and kill manuals and HCR's, 4" valve on kill line. 4" FOSV, 4" dart valve, upper and lower IBOP, and Blind/Shear Rams. Perform Koomey drawdown. ACC=2900psi, Manifold= 1500psi, ACCU=1650psi after all functions on just bottles. 14 secs to 200psi build with 2 electric pumps, 97 secs to build to full system pressure with 2 electric and 2 air pumps. Closing times, annular=23 secs. UPR= 18 secs. blind/shears= 16 secs, LPR= 16 sec, Choke HCR= 2 sec, kill HCR = 2 sec Tested PVT gain/loss and flow alarms. Tested LEL and 1-12S alarms. Witnessed by AOGCC Rep. Jeff Jones. 10/27/2019 10/27/2019 2.00 INTRM1 WHDBOP RURD P Rigged down BOPE testing equipment 7,174.0 7,174.0 15:00 17:00 and set 6 7/8" wear ring. 10/27/2019 10/27/2019 1.50 INTRM1 DRILLOUT PACK P PJSM. RIH to 60' with overshot 7,174.0 7,114.0 17:00 18:30 retrieval tool. Engaged overshot and pulled storm packer. L/D storm packer. 10/27/2019 10/27/2019 0.75 INTRM1 DRILLOUT SEQP P Blowed down choke manifold and 7,114.0 7,114.0 18:30 19:15 choke line. Removed PS -21's. Installed master bushing. 10/27/2019 10/27/2019 0.75 INTRM1 DRILLOUT SEQP P Freeze protect OA w/ 71 bbls diesel. 7,114.0 7,114.0 19:15 20:00 Final Shut in pressure = 625 psi. SIMOPS: Adjust upper I -BOP actuator 10/27/2019 10/28/2019 4.00 INTRM1 DRILLOUT TRIP P Continued to RIH while picking up 4" 7,114.0 9,884.0 20:00 00:00 XT39 drill pipe from 7,114' MD to 9,884' MD. P/U Wt = 125 klbs, and S/0 Wt = 114 klbs. Monitored returns on pit #2. Filled pipe every 20 stands. 10/28/2019 10/28/2019 1.00 INTRM1 DRILLOUT TRIP P Continued to RIH while picking up 4" 9,884.0 10.300.0 00:00 01:00 XT39 drill pipe from 9,884' MD to 10,300' MD. P/U Wt = 126 klbs, and S/O Wt = 115 klbs. Monitored returns on pit #2. Page 19/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/28/2019 10/28/2019 7.00 INTRMI DRILLOUT DLOG P Filled pipe and downlinked to LWD to 10,300.0 14,175.0 01:00 08:00 turn on SonicScope for logging cement. Continued to RIH while picking up 4" XT39 drill pipe from 10,300' MD to 14,175' MD at 1750 fph. P/U Wt = 178 klbs, and S/O Wt = 123 klbs. Monitored returns on pit #2. 10/28/2019 10/28/2019 0.75 INTRM1 DRILLOUT DLOG P Log R/Atag w/ GPM = 230 gpm, SPP 14,175.0 14,175.0 08:00 08:45 = 2,145 psi, Rotary = 60 rpm. Located tag at 14,178' MD. Relocated it with no rotation. GPM = 230 gpm, SPP = 2.144 psi, Relocated tag at 14,178' MID 10/28/2019 10/28/2019 1.75 INTRM1 DRILLOUT DLOG P Continued to RIH while picking up 4" 14,175.0 15,022.0 08:45 10:30 XT39 drill pipe from 14,175' MD to 15,022' MD at 1750 fph (Logging cement). P/U Wt = 178 klbs, and S/O Wt = 124 klbs. Monitored returns on pit #2. 10/28/2019 10/28/2019 1.00 INTRMI DRILLOUT CIRC P Circulated and conditioned mud at 240 15,022.0 15,022.0 10:30 11:30 gpm. SSP = 2,220 psi, Rotary = 50 rpm, and TQ = 7-8 kftlbs. Reciprocated pipe 90'. 10/28/2019 10/28/2019 0.50 INTRM1 DRILLOUT RURD P PJSM. Rigged up to test 7 5/8" Casing 15,022.0 15,022.0 11:30 12:00 10/28/2019 10/28/2019 0.75 INTRMI DRILLOUT PRTS P PJSM Tested 7 5/8" casing to 3,500 15,022.0 15.022.0 12:00 12:45 psi for 30 minutes (Charted). Closed UPR and pumped down DP and kill line at 1 bpm. Pumped 80 strokes (8.05 bbls) to full pressure. Bled back 7.8 bbls. 10/28/2019 10/28/2019 0.50 INTRMI DRILLOUT CLEN P Cleaned and cleared rig floor of non- 15,022.0 15,022.0 12:45 13:15 essential tools. 10/28/2019 10/28/2019 2.00 INTRM1 DRILLOUT SLPC P Slipped and cut drill line (57 wraps). 15,022.0 15,022.0 13:15 15:15 448' 10/28/2019 10/28/2019 1.75 INTRM1 DRILLOUT REAM P Washed and reamed down to float 15,022.0 15,187.0 15:15 17:00 collar. From 15,022' MD to 15,187' MD. GPM = 150 gpm, SPP = 978 psi. Rotary = 50 rpm, TO = 11.5 kftlbs, F/O = 14%. P/U Wt = 182 klbs, and S/O Wt = 126 klbs. 10/28/2019 10/28/2019 3.50 INTRM1 DRILLOUT DRLG P Drilled shoe track and rat hole from 15,187.0 15.294.0 17:00 20:30 15,187' MD to 15,294' MD. GPM = 150 gpm. SPP = 978 psi, Rotary = 50 rpm, TQ = 11.5 kftlbs, F/O = 14%, P/U Wt = 182 klbs, and S/O Wt = 126 klbs. 10/28/2019 10/28/2019 1.50 INTRM1 DRILLOUT DRLG P Drilled 6 1/2" Production from 15,294' 15,294.0 15,314.0 20:30 22:00 MD to 15,314' MD (7,718' TVD). WOB = 10 klbs, GPM = 200 gpm, SPP = 1,780 psi, Rotary = 60 rpm, TO On = 13 kftlbs, TQ Off = 8 klbs, F/O = 19 %, ECD = 11.03 ppg, P/U Wt = 173 klbs, S/O Wt = 123 klbs, and Rot Wt = 139 klbs. ADT = 0.66 hrs, Total Bit Hours = 0.66 hrs, and Total Jar Hours = 84.62 hrs. 10/28/2019 10/29/2019 2.00 INTRM1 DRILLOUT CIRC P L/D double. Circulated and 15,314.0 15,269.0 22:00 00:00 conditioned mud to 10.05 ppg in and out. Rotated and reciprocated whilst conditiong mud from 15,269' MD to 15,194' MD. GPM = 215 gpm, SPP = 1975 psi, Rotary = 50 rpm, TO = 8 kftlbs, F/O = 19%, and total strokes = 5891. Page 20/51 Report Printed: 12/9/2019 - Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/29/2019 10/29/2019 0.75 INTRM1 DRILLOUT OWFF P SPR's. OWFF (Static). B/D top drive 15,269.0 15,269.0 00:00 00:45 and R/U for F.I.T. 10/29/2019 10/29/2019 0.75 INTRM1 DRILLOUT FIT P Performed FIT to 1,000 psi w/ 10.05 15,269.0 15,314.0 00:45 01:30 ppg LSND. EMW for FIT was 12.5 ppg. R/D tested equipment. Blowed down lines. 10/29/2019 10/29/2019 0.50 INTRM1 DRILL MPDA P Pulled trip nipple and installed MPD- 15,314.0 15.314.0 01:30 02:00 10/29/2019 10/29/2019 4.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 15,314' 15,314.0 15,405.0 02:00 06:00 MD to 15,405' MD (7,729' TVD). WOB = 7 klbs, GPM = 240 gpm, SPP = 1,840 psi, Rotary = 100 rpm. TO On = 9 kftlbs, F/O = 15 %, ECD = 9.93 ppg. P/U Wt = 193 klbs, S/O Wt = 120 klbs, and Rot Wt = 143 klbs. ADT = 2.77 hrs, Total Bit Hours = 3.43 hrs. and Total Jar Hours = 87.39 hrs. MPD connection back pressure = 0 psi. Displaced to 9.0 ppg FloPro while drilling. SIMOPS: L/D 5" DP from derrick, and attempted to initialize Novos but was unable to initialize. 10/29/2019 10/29/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 15,405' 15,405.0 16,070.0 06:00 12:00 MD to 16,070' MD (7,756' TVD). WOB = 14 klbs, GPM = 240 gpm. SPP on = 1,970 psi, SPP off = 1,935 psi. Rotary = 140 rpm, TQ On = 10 kftlbs, TQ Off = 7 kftlbs, F/O = 15 %, ECD = 10.19 ppg, P/U Wt = 183 klbs. S/O Wt = 112 klbs, and Rot Wt = 142 kibs. ADT = 4.34 hrs, Total Bit Hours = 7.77 hrs, and Total Jar Hours = 91.73 hrs. MPD connection back pressure = 0 psi. SIMOPS: L/D 5" DP from derrick and used Novos as autodriller. 10/29/2019 10/29/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 16,070' 16,070.0 16,830.0 12:00 18:00 MD to 16,830' MD (7,762' TVD). WOB = 12.5 klbs, GPM = 250 gpm, SPP on = 2,093 psi, SPP off = 2,025 psi, Rotary = 160 rpm, TO On = 11-12 kftlbs. TQ Off = 7 kftlbs, F/O = 15 ECD = 10.43 ppg, P/U Wt = 178 klbs, S/O Wt = 109 klbs, and Rot Wt = 148 klbs. ADT = 4.01 hrs, Total Bit Hours = 11.78 hrs. and Total Jar Hours = 95.74 hrs. MPD connection back pressure = 0 psi. Drilled with Novos slips to slips. No soft speed as per SLB rep. Page 21/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/29/2019 10/30/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 16,830' 16,830.0 17,590.0 18:00 00:00 MD to 17,590' MD (7,772' TVD). WOB = 15 klbs, GPM = 260 gpm, SPP on = 2,648 psi. SPP off = 2,568 psi, Rotary = 150 rpm, TQ On = 15 kftlbs, TO Off = 8 kftlbs, F/O = 16 %, ECD = 10.75 ppg, P/U Wt = 178 klbs, S/O Wt = 144 klbs, and Rot Wt = 144 klbs. ADT = 3.49 hrs, Total Bit Hours = 15.27 hrs, and Total Jar Hours = 99.23 hrs. MPD connection back pressure = 0 psi. Drilled w/ Novos slips to slips. Two stands Novos stopped drilling w/ 6' left on stand and would not initialize again. Novos was rebooted a second time. No soft speed as per SLB rep. Power Drive short hop transmission stopped communicating wl LWD at 17,010' MD. Decision was made to resume drilling and monitor directional responses moving forward. Power Drive GR and Directional data are not being transmitted, but the tool still seems to be responding to directional commands. LWD data is still transmitting in real time. 10/30/2019 10/30/2019 2.50 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 17,590' 17,590.0 17,870.0 00:00 02:30 MD to 17.870' MD (7,777' TVD). WOB = 13 klbs, GPM = 260 gpm, SPP on = 2,700 psi, Rotary = 150 rpm, TQ On = 14 kftlbs. TQ Off = 5 kftlbs, F/O = 17 %, ECD = 10.76 ppg, P/U Wt = 178 klbs, S/O Wt = 112 klbs, and Rot Wt = 144 klbs. MPD connection back pressure = 0 psi 10/30/2019 10/30/2019 1.00 PROD1 DRILL OTHR T Troubleshooted Power Drive w/ anti- 17,870.0 17,870.0 02:30 03:30 jamming sweep. Attempted to send 60 second downlink w/ Novos (Incorrect timing sequence format). Reverted to Amphion to send the downlink. 10/30/2019 10/30/2019 2.50 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 17,870' 17,870.0 18,255.0 03:30 06:00 MD to 18,255' MD (7,777' TVD). WOB = 14 klbs, GPM = 240 gpm, SPP on = 2,495 psi, SPP off = 2,415 psi, Rotary = 150 rpm, TQ On = 14 kftlbs, TO Off = 5 kftlbs. F/O = 17 %, ECD = 10.8 ppg, P/U Wt = 181 klbs, S/O Wt = 113 klbs, and Rot Wt = 145 klbs. ADT = 3.13 hrs (0:00 - 06:00hr), Total Bit Hours = 18.40 hrs, and Total Jar Hours = 102.36 hrs. MPD connection back pressure = 0 psi. 10/30/2019 10/30/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 18,255' 18,255.0 19.199.0 06:00 12:00 MD to 19,199' MD (7,785' TVD). WOB = 19 klbs, GPM = 250 gpm, SPP on = 2,758 psi, SPP off = 2,485 psi, Rotary = 150 rpm, TO On = 16 kftlbs, TO Off = 8 kftlbs, F/O = 16 %. ECD = 11.1 ppg, P/U Wt = 177 klbs, S/O Wt = 108 klbs, and Rot Wt = 143 klbs. ADT = 3.52 hrs. Total Bit Hours = 21.92 hrs, and Total Jar Hours = 105.88 hrs MPD connection back pressure = 0 psi. Drilling w/ Novos slips to slips. SIMOPS: L/D 5" DP w/ 90' mouse hole Page 22/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) )� CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 10/30/2019 10/30/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 19,199' 19,199.0 20,051.0 12:00 18:00 MD to 20,051' MD (7,794' TVD). WOB = 17 klbs. GPM = 255 gpm. SPP on = 2,970 psi. SPP off = 2,844 psi. Rotary = 150 rpm, TQ On = 16 kftlbs, TQ Off = 6 kftlbs, F/O = 16 %, ECD = 11.26 ppg, P/U Wt = 180 klbs, S/O Wt = 103 klbs, and Rot Wt = 143 klbs. ADT = 3.29 hrs, Total Bit Hours = 25.21 hrs, and Total Jar Hours = 109.17 hrs. MPD connection back pressure = 0 psi. Drilling w/ Novos slips to slips. 10/30/2019 10/30/2019 1.00 PROD1 DRILL OTHR T Installed Novos and Stick Slip 20,051.0 20,051.0 18:00 19:00 Channel on Totco. Troubleshooted installation and rebooted Totco. 10/30/2019 10/31/2019 5.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 20,051' 20,051.0 20,812.0 19:00 00:00 MD to 20,812' MD (7,802' TVD). WOB = 18 klbs, GPM = 255 gpm, SPP on = 3,026 psi, SPP off = 2,850 psi, Rotary = 150 rpm. TQ On = 15 kftlbs, TO Off = 8 kftlbs, F/O = 16 %. ECD = 11.19 ppg, P/U Wt = 179 klbs, S/O Wt = 101 klbs, and Rot Wt = 143 klbs. ADT = 3.26 hrs, Total Bit Hours = 28.47 hrs, and Total Jar Hours = 112.43 hrs. MPD connection back pressure = 0 psi. 10/31/2019 10/31/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 20,812' 20,812.0 21,580.0 00:00 06:00 MD to 21,580' MD (7,814' TVD). WOB = 18 klbs, GPM = 260 gpm. SPP on = 3,320 psi, SPP off = 3,215 psi, Rotary = 150 rpm, TO On = 14 kftlbs, TQ Off = 9 kftlbs, F/O = 16 %, ECD = 11.39 ppg. P/U Wt = 178 klbs, S/O Wt = 98 klbs, and Rot Wt = 139 klbs. ADT = 4.05 hrs, Total Bit Hours = 32.52 hrs, and Total Jar Hours = 116.48 hrs. MPD connection back pressure = 8 psi. Novos not in use due to update 03:00 - 12:00hr. 10/31/2019 10/31/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 20,580' 21,580.0 22,352.0 06:00 12:00 MD to 22,352' MD (7,827' TVD). WOB = 15 klbs, GPM = 261 gpm. SPP on = 3,333 psi. SPP off = 3,261 psi, Rotary = 160 rpm, TQ On = 16 kftlbs, TO Off = 9 kftlbs. F/O = 19 %, ECD = 11.67 ppg, P/U Wt = 178 klbs, S/O Wt = 92 klbs, and Rot Wt = 139 klbs. ADT = 4.20 hrs, Total Bit Hours = 36.72 hrs. and Total Jar Hours = 120.68 hrs. MPD connection back pressure = 12 psi. Novos riot in use. Waiting on update confirmation 10/31/2019 10/31/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 22,352' 22,352.0 23,187.0 12:00 18:00 MD to 23,187' MD (7,832' TVD). WOB = 18 klbs, GPM = 261 gpm, SPP on = 3,450 psi, SPP off = 3,393 psi, Rotary = 160 rpm, TO On = 15 kftlbs, TO Off = 9 kftlbs, F/O = 19 %, ECD = 11.73 ppg, P/U Wt = 184 klbs, S/O Wt = 86 klbs, and Rot Wt = 134 klbs. ADT = 4.13 hrs, Total Bit Hours = 40.85 hrs. and Total Jar Hours = 124.81 hrs. MPD connection back pressure = 14 psi. Troubleshooting new update on Novos. Drilling w/ Amphion. Page 23/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 CEO Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 10/31/2019 10/31/2019 2.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 23,187' 23,187.0 23,375.0 18:00 20:00 MD to 23,375' MD (7,835' TVD). WOB = 12 klbs, GPM = 255 gpm, SPP on = 3,182 psi, SPP off = 3,100 psi, Rotary = 130 rpm, TO On = 14 kftlbs, TQ Off = 10 kftlbs, F/O = 19 %, ECD = 12.01 ppg, P/U Wt = 181 klbs, S/O Wt = 84 klbs, and Rot Wt = 135 klbs. MPD connection back pressure = 10 psi. Continued to troubleshoot new Novos update. Drilled w/ Amphion. 10/31/2019 10/31/2019 1.50 PROD1 DRILL CIRC T Circulated while rotating and 23,375.0 23,375.0 20:00 21:30 reciprocating from 23.375' MD to 23,288' MD w/ GPM = 256 gpm, SPP = 3,056 psi, F/O = 19%, Rotary = 130 rpm, TO = 10 kftlbs, ECD = 12,1 - 10.9 ppg. Total pumped strokes = 3,687 due to high ECD's 10/31/2019 11/1/2019 2.50 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 23,375' 23,375.0 23.722.0 21:30 00:00 MD to 23,772' MD (7,835' TVD). WOB = 13 klbs. GPM = 260 gpm, SPP on = 3.430 psi, SPP off = 3,284 psi. Rotary = 150 rpm, TQ On = 14 kftlbs, TQ Off = 10 kftlbs, F/O = 19 %. ECD = 11.99 ppg, P/U Wt = 176 klbs, S/O Wt = 80 klbs, and Rot Wt = 134 klbs. ADT = 3.45 hrs. Total Bit Hours = 44.3 hrs, and Total Jar Hours = 128.26 hrs. MPD connection back pressure = 10 psi. Continued to troubleshoot new Novos update. Drilled w/ Amphion. 11/1/2019 11/1/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 23,772' 23,722.0 24,323.0 00:00 06:00 MD to 24,323' MD (7,842' TVD) WOB = 9 klbs. GPM = 257 gpm, SPP on = 3,345 psi, SPP off= 3,240 psi, Rotary = 150 rpm, TO On = 15 kftlbs. TQ Off = 10 kftlbs, F/O = 19 %, ECD = 11.3 ppg, P/U Wt = 179 klbs, S/O Wt = 85 klbs, and Rot Wt = 140 klbs. ADT = 4.57 hrs, Total Bit Hours = 48.87 hrs, and Total Jar Hours = 132.83 hrs. MPD connection back pressure = 15 psi. Continued to drill wl Amphion. Waiting on Novos update. 11/1/2019 11/1/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 24,323' 24,323.0 24,988.0 06:00 12:00 MD to 24,988' MD (7,849' TVD). WOB = 11 klbs, GPM = 257 gpm, SPP on = 3,360 psi, SPP off = 3,200 psi, Rotary = 150 rpm, TQ On = 16 kftlbs, TQ Off = 10 kftlbs. F/O = 19 %, ECD = 11.68 ppg, P/U Wt = 179 klbs, S/O Wt = 64 klbs, and Rot Wt = 137 klbs. ADT = 4.42 hrs, Total Bit Hours = 53.29 hrs, and Total Jar Hours = 137.25 hrs. MPD connection back pressure = 12 psi. Continued to drill w/ Amphion. Waiting on Novos update. Page 24/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (WB) End Depth (ftKB) 11/1/2019 11/1/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 24,988' 24,988.0 25,736.0 12:00 18:00 MD to 25,736' MD (7,849' TVD). WOB = 11 klbs. GPM = 250 gpm. SPP on = 3,230 psi, SPP off = 3,110 psi, Rotary = 130 rpm. TQ On = 15 kftlbs, TQ Off = 10 kftlbs, F/O = 20 %. ECD = 11.28 ppg, P/U Wt = 186 klbs, S/O Wt = 53 klbs, and Rot Wt = 138 klbs. ADT = 3.67 hrs, Total Bit Hours = 56.96 hrs. and Total Jar Hours = 140.92 hrs MPD connection back pressure = 12 psi. Drilled w/ Novos. 11/1/2019 11/2/2019 6.00 PROD1 DRILL DDRL P Drilled 6 1/2" Production from 25,736' 25,736.0 26.480.0 18:00 00:00 MD to 26,480' MD (7,861' TVD). WOB = 15 klbs, GPM = 250 gpm. SPP on = 3,320 psi, SPP off = 3,204 psi, Rotary = 140 rpm, TQ On = 17 kftlbs. TQ Off = 9.5 kftlbs, F/O = 18 %, ECD = 11.49 ppg, P/U Wt = 183 klbs, S/O Wt = 72 klbs, and Rot Wt = 160 klbs. ADT = 3.94 hrs, Total Bit Hours = 60.90 hrs, and Total Jar Hours = 144.86 hrs MPD connection back pressure = 12 psi. Drilled w/ Novos. 11/2/2019 11/2/2019 1.50 PROD1 DRILL DRLG T Drilled w/ Novos WOB limit = 18 klbs 26,480.0 26,480.0 00:00 01:30 and actual drilling was on 8 klbs. WOB exceed the Novos limit at 21 klbs thus resulting in loss of ROP and a sharp increase in torque from 17 kftlbs to 22 kftlbs. Attempted to reset and continue drilling a total of 4 times. Observed some buckling. No ROP or footage was made. 11/2/2019 11/2/2019 4.00 PROD1 DRILL CIRC T Circulated and reciprocated from 26. 26,480.0 26,473.0 01:30 05:30 473' MD to 26,410' MD w/ GPM = 250 gpm, SPP = 3,200 psi, F/O = 17%, Rotary = 50-100 rpm, TQ = 10 kftlbs. ECD = 11.1 ppg, P/U Wt = 185 klbs, S/O Wt = 77 klbs. Rot Wt = 143 klbs, Total Pumped Strokes = 14,900. Racked back one stand 4" DP in Derrick after each bottoms up 11/2/2019 11/2/2019 1.25 PROD1 DRILL TRIP T P/U stand from Derrick and RIH from 26,473.0 26.476.0 05:30 06:45 to 26,476' MD. Rotary = 100 rpm, GPM = 250 gpm, SPP = 3,150 psi, F/O = 18%, TQ = 10-12 kftlbs, Set WOB 25 klbs (no ROP). Downlinked and set RSS to neutral. Racked back stand. 11/2/2019 11/2/2019 0.25 PROD1 DRILL OWFF T Fingerprinted well. Well was not 26,476.0 26,413.0 06:45 07:00 underbalance. Mud weight 9.0+ shut on well with 108psi, open 15sec, shut in for 5mn build up to 18psi. Open choke 15sec. shut in for 5 min. Opsi build up. Plan kill fluid 9.4ppg brine for trip margin. 11/2/2019 11/2/2019 5.00 PROD1 DRILL BKRM T BROOH from 26,413' MD to 24,575' 26,413.0 24,575.0 07:00 12:00 MD w/ GPM = 250 gpm, SPP =2,963 psi, Rotary = 80-120 rpm, TQ = 8-10 kftlbs, F/O = 15%. ECD = 10.55 ppg, P/U Wt = 180 klbs, S/O Wt = 90 klbs, and Rot Wt = 141 klbs. Page 25/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/2/2019 11/2/2019 6.00 PROD1 DRILL SMPD T Blowed down top drive and SOOH 24,575.0 19,200.0 12:00 18:00 from 24,575' MD to 19,200' MD w/ 4" DP racked back in derrick. P/U Wt = 185 klbs. Monitored displacement on pit #3. 11/2/2019 11/2/2019 3.50 PROD1 DRILL SMPD T Continued to SOOH per schedule 19,200.0 15,180.0 18:00 21:30 from 19,200' MD to 15,180' MD w/ 4" DP, racking back in the derrick. P/U Wt = 185 klbs Monitored displacement on pit #3. 11/2/2019 11/3/2019 2.50 PROD1 DRILL CIRC T PJSM. Displaced well to 9.4 ppg KW 15,180.0 15,095.0 21:30 00:00 brine. Reciprocated from 15,194' MD to 15,097' MD w/ GPM =250 gpm. SPP = 865 psi, F/O = 14%, P/U Wt = 206 klbs, S/O Wt = 107 klbs, Total Strokes = XXXX. 11/3/2019 11/3/2019 0.50 PROD1 DRILL OWFF T OWFF (Static) 15,095.0 15,095.0 00:00 00:30 11/3/2019 11/3/2019 1.00 PROD1 DRILL SLPC T PJSM. Slipped and cut 120' of drill fine 15,095.0 15,095.0 00:30 01:30 (15 wraps) 11/3/2019 11/3/2019 0.50 PROD1 DRILL SVRG T Lubricated top drive/blocks, and 15,095.0 15,095.0 01:30 02:00 calibrated blocks. 11/3/2019 11/3/2019 0.50 PROD1 DRILL SMPD T SOOH from 15,180' MD to 14,610' MD 15,095.0 14.610.0 02:00 02:30 w/ 4" DP racking back in the derrick PU/Wt = 170 klbs and Monitored displacement on pit #3. 11/3/2019 11/3/2019 1.50 PROD1 DRILL DLOG T Reciprocated up and pumped in hole 14,610.0 14,230.0 02:30 04:00 whiiie logging from 14,440' MD to 14,490' MD, and 14,185' MD (R/A pip tag) 11/3/2019 11/3/2019 2.00 PROD1 DRILL SMPD T SOOH from 14,230' MD to 11,180' MD 14,230.0 11,180.0 04:00 06:00 w/ 4" DP racking back in the derrick PU/Wt = 168 klbs and Monitored displacement on pit #3. 11/3/2019 11/3/2019 6.00 PROD1 DRILL SMPD T SOOH from 11,180' MD to 2,300' MD 11,180.0 2,300.0 06:00 12:00 w/ 4" DP racking back in the derrick. PU/Wt = 82 klbs and Monitored displacement on pit #3 11/3/2019 11/3/2019 0.75 PROD1 DRILL SMPD T SOOH from 2,300' MD to 980' MD w/ 2,300.0 980.0 12:00 12:45 4" DP racking back in the derrick. PU/Wt = 64 klbs and Monitored displacement on pit #3. 11/3/2019 11/3/2019 0.50 PROD1 DRILL BHAH T Found washout in the bottom ofjoint 7 980.0 980.0 12:45 13:15 and on the top of joint 6. L/D and replaced both joints. P/U Wt = 64 klbs and S/O Wt = 55 klbs. 11/3/2019 11/3/2019 0.75 PROD1 DRILL SMPD T SOOH from 980' MD to 350' MD w/ 4" 980.0 350.0 13:15 14:00 DP racking back in the derrick. PU/Wt = 64 klbs and Monitored displacement on pit #3. 11/3/2019 11/3/2019 1.00 PROD1 DRILL MPDA T Removed MPD bearing and installed 350.0 350.0 14:00 15:00 trip nipple. 11/3/2019 11/3/2019 2.50 PROD1 DRILL BHAH T L/D #3 BHA from 350' MD to surface. 350.0 0.0 15:00 17:30 PU/Wt = 54 klbs and S/O Wt = 53 klbs. Monitored displacement on pit #3. 11/3/2019 11/3/2019 1.00 PROD1 DRILL CLEN T Cleaned and cleared rig floor of all 0.0 0.0 17:30 18:30 non-essential tools and equipment. 11/3/2019 11/3/2019 1.00 PROD1 DRILL RURD T Drained stack, pulled wear ring, and 0.0 0.0 18:30 19:30 installed test plug as per FMC 11/3/2019 11/3/2019 1.50 PROD1 WHDBOP RURD T Rigged up to test BOPs. 0.0 0.0 19:30 21:00 Page 26/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (WEI) End Depth (VB) 11/3/2019 11/3/2019 2.50 PROD1 WHDBOP BOPE T Tested BOPE. All tests 250psi 0.0 0.0 21:00 23:30 low/3500psi high for 5 charted minutes with 4 112" test joint 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR. Test choke valves 1-3, and 5-15, manual operated and super choke, choke and kill manuals and HCR's, 4" valve on kill line, 4" FOSV, 4" dart valve, upper and lower IBOP, and Blind/Shear Rams. AOGCC Rep Matthew Herrera waived witness on 11/2/2019 at 0836hr. 11/3/2019 11/4/2019 1.00 PROD1 WHDBOP OTHR T [DST] Adjustment 0.0 23:30 00:30 11/4/2019 11/4/2019 0.50 PROD1 DRILL OWFF T OWFF (Static). 350.0 350.0 00:30 01:00 11/4/2019 11/4/2019 2.50 PROD1 WHDBOP BOPE T Tested BOPE. All tests 250psi 0.0 0.0 00:00 02:30 low/3,500psi high for 5 charted minutes with w/ the exception of manual operated and super choke (2,000 psi/2minutes). 4" Test joint. Tested annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR. Test choke valve 4. manual operated and super choke, choke and kill manuals and HCR's. Performed Koomey drawdown. ACC = 2,950 psi, Manifold = 1,550 psi„ ACC = 1,575 psi after all functions on bottles, 17 seconds for 200 psi. Built pressure w/ 2 electric pumps, 103 seconds to build full system pressure w/ 2 electric and 2 air pumps. Closing time Annulars =23 sec. UPR = 18 sec. Blind/shear rams = 16 sec. LPR = 16 sec. Choke HCR = 2 sec. Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms, Tested LEL and H2S alarms. AOGCC rep Matthew Herrera waived witness on 11/02/2019 at 0836hr. 11/4/2019 11/4/2019 1.00 PROD1 WHDBOP RURD T Pulled test plug and L/D test joint. 0.0 0.0 02:30 03:30 Blowed down choke/kill lines, choke manifold, top drive, and cleaned and cleared rig floor. Installed wear ring. 11/4/2019 11/4/2019 0.50 PROD1 DRILL SVRG T Serviced top drive, blocks, and crown. 0.0 0.0 03:30 04:00 11/4/2019 11/4/2019 2.00 PROD1 DRILL SVRG T PM's rig floor, mud pumps, P/U and 0.0 0.0 04:00 06:00 ifunction tested PS-21 slips, 11/4/2019 11/4/2019 4.25 PROD1 DRILL SVRG T Continued with PM's and worked on 0.0 0.0 06:00 10:15 #1 mud pump. Installed PS-21's. Inspected/serviced iron roughneck and service skate. 11/4/2019 11/4/2019 1.00 PROD1 DRILL BHAH T M/U milling BHA. Monitored 0.0 0.0 10:15 11:15 displacement on bit #3. P/U Wt = 50 klbs, S/O Wt = 50 klbs. Waited on junk mill. 11/4/2019 11/4/2019 0.75 PROD1 DRILL SVRG T Continued with PM's. C/O pressure 0.0 0.0 11:15 12:00 washer pump in BOP deck.. 11/4/2019 11/4/2019 2.50 PROD1 DRILL SVRG T Continued with PM's. C/O batteries on 0.0 0.0 12:00 14:30 MCW. Cleaned and maintained rig. 11/4/2019 11/4/2019 0.50 PROD1 DRILL BHAH T Finished making up milling BHA from 0.0 295.0 14:30 15:00 87' MD to 295' MD. P/U Wt = 54 klbs, and S/O Wt =55 klbs. Page 27/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 ., , Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/4/2019 11/4/2019 3.00 PROD1 DRILL TRIP T TIH w/ milling BHA from 295' MD to 295.0 4,041.0 15:00 18:00 4,041' MD w/ 4" DP from the derrick. P/U Wt = 83 kibs, and S/O Wt =80 kibs. Monitored displacement on pit #3. Filled pipe every 20 stands. 11/4/2019 11/5/2019 6.00 PROD1 DRILL TRIP T TIH w/ milling BHA from 4,041' MD to 4,041.0 15,220.0 18:00 00:00 15,220' MD w/ 4" DP from the derrick. P/U Wt = 173 klbs, and S/O Wt = 116 klbs. Monitored displacement on pit #3. Filled pipe every 20 stands. 11/5/2019 11/5/2019 0.50 PROD1 DRILL OWFF T OWFF at 15,220' MD (Static) 15,220.0 15,220.0 00:00 00:30 11/5/2019 11/5/2019 2.50 PROD1 DRILL CIRC T Circulate and displace 9.4ppg brine to 15,220.0 15,220.0 00:30 03:00 9.Oppg Flo-Pro. (75bbls interfase) work string from 15,220' MD to 15,145' MD 280gpm, Orpm, 1250psi, Flow 14%, P/U Wt = 194 kibs and S/O Wt = 97 klbs. 11/5/2019 11/5/2019 1.00 PROD1 DRILL CIRC T Attempt to TIH from 15,220' MD, 15,220.0 15,290.0 03:00 04:00 tagged with 13k at 15,290' MD Circulate at 15,244' MD, 200gpm, 980psi, Flow 13%. 11/5/2019 11/5/2019 1.00 PROD1 DRILL REAM T Attempt to TIH from 15,244' MD, 15,290.0 15,397.0 04:00 05:00 Tagged at 15,297' MD 30 kibs, Wash and ream from through ledges at 15,297' MD and 15,397' MD with 20rpm 8klbs torque 80gpm 130psi Rot Wt = 140 kibs. 11/5/2019 11/5/2019 1.00 PROD1 DRILL TRIP T TIH w/ milling BHA on elevators from 15,397.0 16.297.0 05:00 06:00 15,397' MD to 16,297' MD w/ 4" DP from the derrick. S/O Wt = 91 to 101 klbs. Monitored displacement on pit #3. Filled pipe every 20 stands. 11/5/2019 11/5/2019 6.00 PROD1 DRILL TRIP T TIH w/ milling BHA on elevators from 16,297.0 23,857.0 06:00 12:00 16,297' MD to 23,857' MD w/ 4" DP from the derrick. S/O Wt =80 kibs Monitored displacement on pit #3. Filled pipe every 20 stands. Losses per tour=39bbls 11/5/2019 11/5/2019 2.25 PROD1 DRILL TRIP T Cont. RIH w/ milling BHA from 23,857' 23,857.0 26,455.0 12:00 14:15 MD to 26,455' MD w/ 4" DP from the derrick. S/O Wt = 67-74 klbs. Monitored displacement on pit #3. Filled pipe every 20 stands. 11/5/2019 11/5/2019 0.25 PROD1 DRILL WASH T Wash and ream down with milling BHA 26,455.0 26,477.0 14:15 14:30 from 26,455'MD to 26.477' MDwith 6k down, PU/SO wt 213/73k, RTG wt=140k 11/5/2019 11/5/2019 3.50 PROD1 DRILL MILL T Mill as per Baker rep from 26,477'MD 26,477.0 26,480.0 14:30 18:00 to 26.480.24 (Liklely pipe squat), 4- 6bpm, 1345-1616psi, 13%FO, 60- 80rpm, 10-12k TQ, 10-15k WOB, work pipe as directed. 11/5/2019 11/5/2019 2.50 PROD1 DRILL MILL T Continue to mill as per Baker rep from 26,480.0 26,480.0 18:00 20:30 26,480.24' MD to 26,480.35' MD, gpm=42-175, psi=725-1240, FO=7- 15%, RPM=80, TQ=12-14k, WOB=15- 20k working pipe as directed. Page 28/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/5/2019 11/6/2019 3.50 PROD1 DRILL MILL T Continue to work mill as per Baker rep 26,480.0 26,480.0 20:30 00:00 from 26,480.35' MD-26,450MD. gpm=252, psi=1700-2000 RPM=100- 130, TQ=12-14k, WOB=20k, work pipe as directed. Observe increase in torque at 25k WOB, TQ 15-16K. suspected bucklint of pipe at 25k WOB. Continue milling at 20k WOB, tq=12-13k ft -lbs. Resestablish initial parameters, no depth change observed. OA@23:30=170psi Losses for tour=45bbls Cummulative hole section losses=1046bbls 11/6/2019 11/6/2019 1.00 PROD1 DRILL OWFF T Observe Well for Flow. (STATIC) 26,480.0 26,480.0 00:00 01:00 11/6/2019 11/6/2019 5.00 PROD1 DRILL SMPD T SOOH from 26,480' MD to 22,036' MD 26,480.0 22,036.0 01:00 06:00 with 4" Drill Pipe. PU Wt: 211 klbs. SO Wt = 79klbs, holding back pressure via MPD, 85 psi in slips, 415 psi out of slips. 11/6/2019 11/6/2019 6.00 PROD1 DRILL SMPD T SOOH from 22,036' MD to 15,699' MD 22,036.0 15,699.0 06:00 12:00 with 4" Drill Pipe. PU Wt: 210klbs, SO Wt = 87klbs, holding back pressure via MPD, 85 psi in slips, 400 psi out of slips. Tour losses = 47 bbls 11/6/2019 11/6/2019 1.00 PROD1 DRILL SMPD T SOOH from 15,699' MD to 15.194' MD 15,699.0 15,194.0 12:00 13:00 with 4" Drill Pipe. PU Wt: 206klbs, SO Wt = 107klbs: holding back pressure via MPD, 85 psi in slips, 400 psi out of slips. 11/6/2019 11/6/2019 2.50 PROD1 DRILL CIRC T Displace 9.0 ppg FloPro with 9.4 ppg 15,194.0 15,194.0 13:00 15:30 Brine. Circulate @ 215 gpm, 1565 psi, 10% Flow. 11/6/2019 11/6/2019 1.00 PROD1 DRILL SLPC T Slip and cut drill line . 15 wraps (118'), 15,194.0 15,194.0 15:30 16:30 calibrate and service blocks, SIMOPS- 30min OWFF, monitor hole fill on Pit 3 11/6/2019 11/6/2019 1.50 PROD1 DRILL SMPD T Continue SOOH from 15,097'- 15,194.0 13.125.0 16:30 18:00 13,125'MD, MPD holding 82psi in slips, 360psi out of slips, FO= 12%, PU/SO Wt=204K/107k, monitor displacement on pits 4 and 5 11/6/2019 11/7/2019 6.00 PROD1 DRILL SMPD T Continue SOOH from 13,125'MD to 13,125.0 3,215.0 18:00 00:00 3,215'MD, MPD 82psi in slips, 140psi out of slips, FO=12%, PU/SO=93K/75K, OA pressure=150psi Tour losses=63bbls Cumulative losses=1 1 56bbls 11/7/2019 11/7/2019 1.50 PROD1 DRILL SMPD T Continue SOOH from 3,215' MD to 3,215.0 1,929.0 00:00 01:30 1,929' MD, L/D 4" drill pipe with bad hard band. MPD 82psi in slips, FO=12%, PU/SO=71 K/77K, Floats not holding. 11/7/2019 11/7/2019 0.50 PROD1 DRILL OWFF T OWFF (Static). 1,929.0 1,929.0 01:30 02:00 11/7/2019 11/7/2019 1.00 PROD1 DRILL MPDA T Removed MPD bearing and installed 1,929.0 1,929.0 02:00 03:00 I trip nipple. Page 29151 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) )— CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/7/2019 11/7/2019 2.50 PROD1 DRILL TRIP T POOH from 1,929' MD to 300' MD. 1,929.0 300.0 03:00 05:30 L/D 4" drill pipe with bad hard band. PU/S0=70K/77K. 11/7/2019 11/7/2019 2.00 PROD1 DRILL BHAH T LD BHA as per Baker rep. Clean and 300.0 0.0 05:30 07:30 inspect boot baskets and magnets and mill/ PU/S0=60K/55K. 1 Olbs+ metal on magnets, boot baskets clear, chunk missing on boot basket shroud. Hard metal wear on mill face. 11/7/2019 11/7/2019 0.50 PROD1 DRILL BHAH T Clean and clear floor - Service PS -21 0.0 0.0 07:30 08:00 slips 11/7/2019 11/7/2019 1.50 PROD1 DRILL PULD T Pipe Management - RIH w/ 14 stds of 0.0 1,400.0 08:00 09:30 4" DP fir surface to 1400'. PU/S0=54k/55K. SIMOPS-Prep doubles and strap and tally new 4" Its 11/7/2019 11/7/2019 2.50 PROD1 DRILL PULD T POOH L/D total 73 culled singles to 1,400.0 0.0 09:30 12:00 pipe shed due to bad hardbanding. Losses per tour=38bbls OA annulus=140psi @ 8:00 11/7/2019 11/7/2019 1.50 PROD1 DRILL BHAH T MU Milling Assembly BHA#5 as per 0.0 300.0 12:00 13:30 Baker Rep fir surface to 300'MD, PU/SP=54K/53K 11/7/2019 11/7/2019 4.50 PROD1 DRILL TRIP T TIH from 300' to 3200'w/ 14 doubles 300.0 3,200.0 13:30 18:00 and 66 singles from pipeshed. PU/S0=79K/66K, monitor holefill and fill every 20 stads 11/7/2019 11/7/2019 5.50 PROD1 DRILL TRIP T Continue TIH fr 3200' to 15,202'MD, 3,200.0 15,202.0 18:00 23:30 w/ 4" DP from derrick. PU/S0=174K/77K, monitor hole fill and fill every 20 stds 11/7/2019 11/8/2019 0.50 PROD1 DRILL OWFF T OWFF - Simops - PJSM for pulling trip 15,202.0 15,202.0 23:30 00:00 nipple and running RCD bearing, pull PS -21's Tour Losses=26bbls Acc. Losses for hole section1221 bbls 11/8/2019 11/8/2019 0.50 PROD1 DRILL MPDA T PJSM for pulling trip nipple and 15,202.0 15,202.0 00:00 00:30 running RCD bearing, pull PS -21's 11/8/2019 11/8/2019 2.00 PROD1 DRILL CIRC T Displace well 9.4ppg brine to 9.Oppg 15,202.0 15,202.0 00:30 02:30 FloPro, at 271 gpm 1250psi 14% flow PU/S0= 180klbs/103klbs. 6,783 stks. Blow down top drive 11/8/2019 11/8/2019 3.50 PROD1 DRILL SMPD T Strip in hole from 15,202' MD to 15,202.0 19,400.0 02:30 06:00 19,400' MD, w/ 4" DP from derrick, PU/S0=198klbs/90klbs, monitor hole fill and fill every 20 stds 11/8/2019 11/8/2019 6.00 PROD1 DRILL SMPD T Continue Strip in hole from 19,400' 19,400.0 26,470.0 06:00 12:00 MD to 26,470' MD, w/ 4" DP from derrick, PU/S0=212klbs/72klbs, monitor hole fill and fill every 20 stds 11/8/2019 11/8/2019 0.25 PROD1 DRILL WASH T Wash and ream from 26,470'MD- 26.470.0 26,477.0 12:00 12:15 26,477'MD, 4-6bpm, 1395-2150psi, 80rpm, 12k TQ, 15% FO. Break in new bearing at 40rpm, prior to washing down, tag bottom at 26,477'MD with 5K weight down. 11/8/2019 11/8/2019 5.75 PROD1 DRILL MILL T Mill as per Baker rep Clint, 26,481'MD, 26.477.0 26,481.0 12:15 18:00 4-6bpm. 1395-2150psi, 80-140rpm, 12 -17k TQ, 15% FO, work pipe as directed. No depth progress. Page 30/51 Report Printed: 1 2/912 01 9 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/8/2019 11/8/2019 1.50 PROD1 DRILL MILL T Mill as per Baker rep Clint, 26,481'MD. 26,481.0 26,481.0 18:00 19.30 2-6bpm, 895-1410psi, 80-140rpm, 16K -18K TQ, 15% FO, WOB=16-18K, work pipe as directed. No depth progress. 11/8/2019 11/8/2019 0.50 PROD1 DRILL RGRP T Serviced rig, changed out leaking 26,481.0 26,481.0 19:30 20:00 1 washpipe. 11/8/2019 11/9/2019 4.00 PROD1 DRILL MILL T Mill as per Baker rep Clint, 26,481'MD, 26,481.0 26,481.0 20:00 00:00 6bpm, 1410psi,140rpm, 16K -18K TQ, 15% FO, WOB=18K, work pipe as directed. Worked and hit bottom hard over 40 times, pumped two 25bbl hi - vis nut plug sweeps. No depth progress. 11/9/2019 11/9/2019 1.50 PROD1 DRILL MILL T Mill as per Baker rep Clint, 26,481'MD, 26.481.0 26.481.0 00:00 01:30 6bpm, 1410psi,140rpm, 18klbs-20klbs TQ, 15% FO, WOB= 1 8-20klbs, work pipe as directed. No depth progress 11/9/2019 11/9/2019 0.50 PROD1 DRILL CIRC T Slow pump rates at 26,400' MD 26.481.0 26.481.0 01:30 02:00 7,860'TVD 9.2ppg mud #1 pump 20spm 700psi 30spm 900psi #2 pump 20spm 705psi 30spm 910psi Flow check (static), Blow down top drive 11/9/2019 11/9/2019 4.00 PROD1 DRILL SMPD T SOOH from 26,481'MD to 23,180' MD 26,481.0 23,180.0 02:00 06:00 with 4" Drill Pipe. PU Wt: 215klbs; holding back pressure via MPD. 50 psi in slips, 320 psi out of slips. 11/9/2019 11/9/2019 6.00 PROD1 DRILL SMPD T Continue SOOH from 23,180' MD to 23,180.0 17,955.0 06:00 12:00 17,955' MD with 4" Drill Pipe. PU Wt=210klbs,holding back pressure via MPD, 50 psi in slips, 320 psi out of slips. 11/9/2019 11/9/2019 2.50 PROW DRILL SMPD T Continue SOOH from 17,955' MD to 17,955.0 15,265.0 12:00 14:30 15,265' MD with 4" Drill Pipe. PU Wt=196klbs, holding back pressure via MPD, 50 psi in slips, 320 psi out of slips. 11/9/2019 11/9/2019 2.25 PROD1 DRILL CIRC T Displace 9.0 ppg FloPro with 9.4 ppg 15,265.0 15,265.0 14:30 16:45 Brine @ 15,265' MD. Circulate @ 252 gpm, 935 psi, 15% Flow, 11/9/2019 11/9/2019 1.00 PROD1 DRILL SLPC T Slip and cut 15 wraps (120'), calibrate 15,265.0 15,265.0 16:45 17:45 blocks-Simops OWFF (very little vac) 11/9/2019 11/9/2019 0.25 PROD1 DRILL SMPD T Continue SOOH from 15,265' MD- 15,265.0 15,169.0 17:45 18:00 15,169'MD with 4" Drill Pipe. PU Wt: 196k1bs. holding back pressure via MPD, 50 psi in slips, 320 psi out of slips. 11/9/2019 11/10/2019 6.00 PROD1 DRILL SMPD T Continue, SOON, from 15,169'MD to 15,169.0 5,637.0 18:00 00:00 5,637'MD on MPD pressures 40psi in slips/160psi out of slips, PU wt=120K 11/10/2019 11/10/2019 4.00 PROD1 DRILL TRIP T Continue to SOOH 5,675'MD- 5,675.0 420.0 00:00 04:00 420'MD, MPD prtessures 50/420psi, PU Wt= 120k 11/10/2019 11/10/2019 0.25 PROD1 DRILL OWFF T OWFF. SIMOPS=PJSM on pulling 420.0 420.0 04:00 04:15 RCD bearing and running trip nipple. 11/10/2019 11/10/2019 0.75 PROD1 DRILL MPDA T Pull RCD bearing, install trip nipple 420.0 420.0 04:15 05:00 and fill line - 11/10/2019 11/10/2019 1.00 PROD1 DRILL BHAH T Lay down milling BHA assembly from 420.0 200.0 05:00 06:00 420'-200' Page 31/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/10/2019 11/10/2019 0.75 PROD1 DRILL BHAH T Continue laying down BHA. Some 200.0 0.0 06:00 06:45 metal recovered on magnets including 2 oz+junk sub piece. Mill tip good, sand formation abrasion observed on remaining surface and sides. 11/10/2019 11/10/2019 0.75 PROD1 DRILL BHAH T Clean and clear rig floor. Prepare to 0.0 0.0 06:45 07:30 PU new RSS drilling BHA. 11/10/2019 11/10/2019 0.50 PROD1 DRILL SVRG T Service top -drive, blocks. ST -80 iron 0.0 0.0 07:30 08:00 roughneck, and PS -21 slips. 11/10/2019 11/10/2019 2.00 PROD1 DRILL BHAH T MU new RSS drilling BHA as per DD 0.0 350.0 08:00 10:00 from surface to 350'MD. 11/10/2019 11/10/2019 2.00 PROD1 DRILL TRIP T TIH from 350' to 2,201'MD w/ 4" 350.0 2,201.0 10:00 12:00 shallow test Schlum tools, 250gpm, 1034psi. 15% FO. PU/S0=76K/63K, Losses for tour -41 bbis 11/10/2019 11/10/2019 6.00 PROD1 DRILL TRIP T Continue RIH from 2201' to 7811'. 2,201.0 7,811.0 12:00 18:00 PU/S0=113K/97K. Fill pipe every 20 stds, LD and swap in any bad hard banded joits 11/10/2019 11/10/2019 1.75 PROD1 DRILL TRIP T Continue RIH from 7,811'to10,300'. 7.811.0 10,300.0 18:00 19:45 PU/S0=113K/97K. Fill pipe every 20 stds, LD and swap in any bad hard banded joints. 11/10/2019 11/11/2019 4.25 PROD1 DRILL TRIP T Pump to Downlink turn on and begin 10,300.0 13,050.0 19:45 00:00 Sonic logging down at 1,OOOfph from 10,300'MD to 13.050'MD. Monitor hole displacement. fill every 20 stands, lay down bad hard banded joints and swap in good joints. SO wt= 112k at 11.950'MD. Losses for tour=80bbls Accumulated losses for hole section= 1 527bbls OA Pressure = 140psi at 22:30 hrs Culled Total of 13 joints. 4", 14ppf. bad hardbanded joints 11/11/2019 11/11/2019 5.75 PROD1 DRILL DLOG T Continue RIH while sonic scope 13,050.0 15,237.0 00:00 05:45 logging (memory) from 13,050'MD to 15,237'MD. GR circulating, slacking off and rotating passes completed for PIP tag confirmation, A sand depth confirmation and sonic cement evaluation. PIP at 14,178'MD slacking off, 14,176'MD rotating. (Good correlation to initial logged depth.) 11/11/2019 11/11/2019 1.00 PROD1 DRILL SLPC T Slip and cut drill line, 5 wraps (44ft). 15,237.0 15,237.0 05:45 06:45 Calibrate Schlum Hookload and block height. SIMOPS - OWFF 11/11/2019 11/11/2019 1.00 PROD1 DRILL MPDA T Pull trip nipple and install RCD bearing 15,237.0 15,237.0 06:45 07:45 as per MPD. Function test MPD chokes. Conduct Weekly BOP Function test. 11/11/2019 11/11/2019 2.25 PROD1 DRILL CIRC T Displace well from 9.4ppg brine to 15,237.0 15,237.0 07:45 10:00 9.Oppg Flo Pro at 15,237'MD. 6bpm. 1760psi. 13% FO, PU/S0=113K/96K Gather SPR's Page 32151 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/11/2019 11/11/2019 0.50 PROD1 DRILL DLOG T Continue sonic logging at 1,OOOfph, 15,237.0 15.423.0 10:00 10:30 from 15,237'MD to 15,423'MD. PU/SO= 11 3K/96K, Downlink to turn off Schlum tools 11/11/2019 11/11/2019 1.50 PROD1 DRILL TRIP T RIH from 15,423'MD-16,913'MD, with 15,423.0 16,913.0 10:30 12:00 4" DP from derrick, PU/SO= 11 3K/97K, monitor displacement on trip tank. 11/11/2019 11/11/2019 6.00 PROD1 DRILL TRfP T Continue RIH from 16,913'MD to 16,913.0 25,303.0 12:00 18:00 25,303'MD, PU/SO=212K/85K, monitor displacement, fill pipe every 20 stds Tour Losses=51 bbls 11/11/2019 11/11/2019 1.50 PROD1 DRILL TRIP T Continue RIH from 25,203'MD- 25,303.0 26,439.0 18:00 19:30 26,439'MD, PU/SO=214K/92K, monitor displacement, fill pipe every 20 stds 11/11/2019 11/11/2019 1.25 PROD1 DRILL DDRL T Perform Schlum Downlinks. Establish 26,439.0 26,480.0 19:30 20:45 drilling parameters and wash to bottom. Observed tag up at 26,480' with torque to 15K on bottom, 12K off bottom 26,477'MD. Pump pressure 2920/2900psi on/off bottom. PU/SO/RTG=214K/92K/139K lbs 11/11/2019 11/12/2019 3.25 PROD1 DRILL DDRL P Drill 6 1/2" production hole from 26,480.0 26,721.0 20:45 00:00 26,480'MD-26,721'MD (7,862'TVD), PSI=2930psi, RPM=100-140, On/Off TQ=19K/12K, FO=16%, ECD=10.65ppg, PU/SO/RTG=214 K/93K/139K. ADT=2.18hrs. Total bit HRS=2.18 Tour Losses=66bbls 11/12/2019 11/12/2019 6.00 PROD1 DRILL DDRL P Drill 6 1/2" production hole from 26,721.0 27,387.0 00:00 06:00 26,721' MD-27,387' MD (7,872'TVD), WOB=17K, 260 gpm. PSI=3270psi, RPM=100-140, On/Off TQ=21 K/1 8K, FO=16%, ECD=11.32ppg, P U/S O/RTG=200 K/87 K/ 140 K. ADT=4.54hrs, Total bit HRS=6.72, Jars=151.58hrs 11/12/2019 11/12/2019 6.00 PROD1 DRILL DDRL P Drill 6 1/2" production hole from 27,387.0 27,958.0 06:00 12:00 27,387' MD-27,958' MD (7,879'TVD), WOB=17K, 270gpm PSI=3,430psi, RPM= 80-100, On/Off TQ=20K/14K, FO=16%, ECD=11.Oppg, PU/SO/RTG=210K/76K/141 K, ADT=4.26hrs, Total bit HRS=10.98, Jars = 155.84hrs Tour Losses=55bbls 11/12/2019 11/12/2019 6.00 PROD1 DRILL DDRL P Drill 6 1/2" production hole from 27,958.0 28,420.0 12:00 18:00 27,958' MD-28,420' MD (7,879'TVD), WOB=17K, 270gpm, PSI=3,494psi, RPM= 80-100, On/Off TQ=20K/14K, FO=16%, ECD=11.16ppg, PU/SO/RTG=201 K/NA/141 K, Pumped 30/30bbls, to/hi vis sweeps at 28,240'MD ADT=3.92hrs, Total bit HRS=14.90. Jars = 159.76 MPD@28,339'MD=5psi drilling, closing chokes on connections build to 12psi, Max Peak Gas=80units Page 33/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/12/2019 11/12/2019 5.00 PROD1 DRILL DDRL P Drill 6 1/2" production hole from 28,420.0 28,815.0 18:00 23:00 28,420' MD, 28,815MD (7,882'TVD). WOB=17K. 260gpm, PSI=3,275psi, RPM= 100, On/Off TQ=21 K/1 4K, FO=16%, ECD=10.95pp9, PU/SO/RTG=200K/NA/144K, ADT=3.12hrs, Total bit HRS=18.02, Jars = 162.88 Tour Losses=86bbls 11/12/2019 11/13/2019 1.00 PROD1 DRILL DDRL T Trouble shoot SLB tools. Lost signal to 28.815.0 28,815.0 23:00 00:00 tools. change mud pumps, add mud dilution, cycle pumps 11/13/2019 11/13/2019 0.50 PROD1 DRILL DDRL T Continue dilution, trouble shoot MWD 28,815.0 28,815.0 00:00 00:30 signal transmission 11/13/2019 11/13/2019 5.50 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 28,815.0 29,291.0 00:30 06:00 28,815'MD-29,291'MD (7,887'TVD), WOB=17K, 270gpm, 3580psi, 100rpm, TQ on/off=21 k/14k, 16% FO, ECD=11.19ppg, PU/SO/RTG=198K/NA/143K MPD closing chokes on connections. pumped 20/20bbls to-hi vis sweeps at 29,195'MD. Dump and Dilute 275bbls at 28,816'MD. ADT=3.54hrs, Total Bit=21.56hrs, Total Jar=166.42hrs 11/13/2019 11/13/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 29,291.0 29,789.0 06:00 12:00 29,291'MD-29,789'MD (7,891'TVD), WOB=17K, 270gpm, 3482psi, 80rpm, TQ on/off=21.5k/15k, 15% FO, ECD=10.91 ppg, P U/S O/RTG=197 K/ N A/ 143 K. Pumped 30/30 to/hi vis sweeps at 29,673'MD. MPD closing chokes on connections. ADT=3.62hrs, Total Bit=25.18hrs, Total Jar=170.04hrs Mud Losses for 12 tour=73bbls 11/13/2019 11/13/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 29,789.0 30,340.0 12:00 18:00 29,789'MD-30,340'MD (7,897'TVD), WOB=17K, 270gpm, 3482psi, 80rpm, TQ on/off=21.5k/15k, 15% FO, ECD=10.91ppg, PU/SO/RTG=197K/NA/143K. MPD closing chokes on connections ADT=3.70hrs, Total Bit=28.88hrs, Total Jar=173.74hrs Mud Losses for 12 tour=73bbls 11/13/2019 11/14/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 30,340.0 30,721.0 18:00 00:00 30,340'MD-30,721'MD (7,900'TVD), WOB=17K, 270gpm, 3760psi, 100rpm, TO on/off=22K/15K, 15% FO, ECD=11.18ppg, P U/SO/RTG=205 K/NA/ 144 K. MPD closing chokes on connections. Pumped 30/30 to/hi vis sweeps at 30,721'MD. ADT=3.34hrs, Total Bit=25.18hrs, Total Jar=177.08hrs Mud Losses for 12 tour=100bbls Page 34/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/14/2019 11/14/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 30,721.0 31,006.0 00:00 06:00 From 30,721' MD To 31,006'MD (7,903'TVD), W013=17K, 270gpm, 3910psi, 100rpm, TQ on/off=22K/15K. 15% FO, ECD=11.22ppg, P U/SO/RTG=205 K/NA/ 144K MPD closing chokes on connections. Pumped 20/20 to/hi vis sweeps at 30,721'MD. ADT=1.93hrs, Total Bit=34.15hrs, Total Jar=179.01 hrs 11/14/2019 11/14/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 31,006.0 31,483.0 06:00 12:00 From 31,006' MD To 31,483'MD (7,907'TVD), W013=16K, 270gpm, 3835psi, 100rpm. TQ on/off=22K/15K, 15% FO, ECD=11.29ppg, P U/S O/ RTG=2 05 K/ NA/ 144 K. MPD closing chokes on connections. ADT=3.38hrs. Total Bit=37.53hrs, Total Jar=182.39hrs Mud Losses for 12 tour=140bbls 11/14/2019 11/14/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 31,483.0 31,803.0 12:00 18:00 From 31,483' MD To 31,803'MD (7.914'TVD), W013=16K, 270gpm, 3850psi, 100rpm, TQ on/off=22K/15K.. 15% FO, ECD=11.22ppg, P U/SO/RTG=205 K/NA/ 144K. MPD closing chokes on connections ADT=2.47hrs. Total Bit=40.00hrs, Jars=184.56hrs 11/14/2019 11/15/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 31,803.0 32,246.0 18:00 00:00 From 31,803'MD-32,246'MD (7,920'TVD), W013=18K, 270gpm, 4055psi, 90rpm, TQ on/off=23K/15K. 15% FO, ECD=11.44ppg, P U/S O/ RTG=2 06 K/N A/ 142 K MPD closing chokes on connections. ADT=3.40hrs, Total Bit=43.40hrs, Jars= 1 88.26hrs Mud Losses for 12 tour=123bbls 11/15/2019 11/15/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 32,246.0 32,627.0 00:00 06:00 From 32,246' MD-32,627'MD (7,924'TVD), W06=18K, 270gpm. 3760psi, 90rpm, TQ on/off=23K/15K, 15% FO, ECD=11.34ppg, P U/SO/RTG=204K/NA/144K. MPD closing chokes on connections ADT=3.03hrs, Total Bit=46.43hrs, Jars=191.29hrs Page 35151 Report Printed: 1 21912 01 9 Operations Summary (with Timelog Depths) CD5-26 w • w' Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/15/2019 11/15/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 32,627.0 33,007.0 06:00 12:00 From 32,627' MD-33,007'MD (7,925'TVD), WOB=18K. 270gpm, 3960psi, 90rpm, TO on/off=23K/15K, 15% FO, ECD=11.36ppg, PU/SO/RTG=209K/NA/144 K. MPD closing chokes on connections. ADT=2.81 hrs, Total Bit=49.24hrs, Jars=194.10hrs Mud Losses for 12 tour -181 bbls 11/15/2019 11/15/2019 6.00 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 33,007.0 33,420.0 12:00 18:00 From 33,007' MD-33.420'MD (7931'TVD), WOB=13K, 270gpm. 4053psi, 90rpm, TO on/off=23K/16K, 14% FO, ECD=11.26ppg, P U/SO/RTG=224 K/NA/ 148 K. MPD closing chokes on connections. ADT=3.63hrs, Total Bit=52.87hrs, Jars= 1 97.73hrs. 275bbls dump and dilute 9.Oppg at 33,102'MD 11/15/2019 11/15/2019 5.50 PROD1 DRILL DDRL P Continue to drill 6 1/2" production hole 33,420.0 33,768.0 18:00 23:30 From 33,420'MD-33,768"MD (7943 -TVD), WOB=14K, 270gpm, 4032psi, 90rpm, TO on/off=22K/16K, 14% FO, ECD=11.16ppg. P U/SO/RTG=224 K/NA/ 148 K. MPD closing chokes on connections ADT=2.92hrs, Total Bit=55.79hrs, Jars=200.65hrs. FINAL TD REACHED 33,768'MD (7943 -TVD) 11/15/2019 11/16/2019 0.50 PROD1 CASING CIRC P Pump 30bbIsHV sweep, power down 33,768.0 33,768.0 23:30 00:00 Schlumberger tools as per DD. Circulate and condition mud at 270gpm, 4000psi. 80rpm, FO=14%, ECD=11.25.prior to Fingerprint Drawdown, final bottoms up and BROOK 11/16/2019 11/16/2019 4.25 PROD1 CASING CIRC P Continue C&C, rotate and reciprocate, 33,767.0 33,677.0 00:00 04:15 33,767@270gpm, 4020psi, 80rpm. 148K rtg wt, 14%FO. 11.25ppg ECD. 13,030 total strokes Rack back stand, fingerprint MPD Build ups at 33.677'MD. Initial capture 220psi, BU's 80, 37, 15, 6 psi, formation balanced or less. 11/16/2019 11/16/2019 2.75 PROD1 CASING CIRC P Circ BU, rtg and circ. 33.677'MD- 33.677.0 33.580.0 04:15 07:00 33,580' MD, 270gpm, 4025psi, 14% FO, 120rpm (for better hole cleaning), 19.5k TO, 11.16ppg ECD, 148k rtg wt BROOH @ 33,360'= 500'/hr. Page 36151 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/16/2019 11/16/2019 5.00 PROD1 CASING BKRM P BROOH 33580'MD - 32341'MD, 33,580.0 32,341.0 07:00 12:00 270gprn. 3870psi, 80rpm, 17K TO, 14%FO. 11.1ppg ECD. PU/SO/RTG wt's 212K/NA/149K Dropped 2.30" Hollow drift with 120' wire tail. BROOH @ 32,900'= 750'/hr Tour Losses=136bbl 11/16/2019 11/16/2019 6.00 PROD1 CASING BKRM P BROOH from 32,341'MD-30,437'MD, 32,341.0 30,437.0 12:00 18:00 270gpm, 3630psi, 80rpm, 17K TO, 14% FO. 10.89ppg ECD, PU/RTG=206K/143K. BROOH @ 31,780'= 1000'/hr BROOH @ 31,200'= 1250'/hr BROOH @ 30,800'= 1500'/hr 11/16/2019 11/17/2019 6.00 PROD1 CASING BKRM P BROOH from 30,437'MD-27,770'MD 30,437.0 27,770.0 18:00 00:00 270gpm, 3425psi, 80rpm, 16K TO, 14% FO, 10.82ppg ECD, PU/RTG=204K/142K, Attempt to Strip in the hole at 28,000MD, still no down weight available 116bbls-Losses this tour 11/17/2019 11/17/2019 4.00 PROD1 CASING BKRM P BROOH from 27.770'MD-26,445'MD, 27,770.0 26,445.0 00:00 04:00 270gpm, 3325psi, 80rpm. 15.5K TO, 14%FO, 10.80ppg ECD, At 26,445'MD, blow down top-drive, grease washpipe ready to SOOH. 1st attempt to Strip in the hole at 27,000'MD, no go with 68K down weight, 142K rtg wt PU wt=224k lbs at 25,600'MD. 11/17/2019 11/17/2019 2.00 PROD1 CASING SMPD P SOOH from 26,445' MD-24,924'MD 26,445.0 24,924.0 04:00 06:00 with 4" Drill Pipe. PU Wt: 224klbs: holding back pressure via MPD, 80 psi in slips, 211 psi out of slips @ 1500'/hr Max overpull 5klbs. 11/17/2019 11/17/2019 6.00 PROD1 CASING SMPD P SOOH from 24,924' MD-18,617'MD 24,924.0 18,6170 06:00 12:00 with 4" Drill Pipe. PU Wt: 207klbs, SO Wt: 95klbs. holding back pressure via MPD, 80 psi in slips. 260 psi out of slips@ 25007hr. Tour losses=71 bbls 11/17/2019 11/17/2019 1.50 PROD1 CASING SMPD P SOOH from 18,617'MD-17,446'MD 18,617.0 17.446.0 12:00 13:30 with 4" Drill Pipe. PU Wt: 206klbs: SO Wt: 94klbs. holding back pressure via MPD, 80 psi in slips, 260 psi out of slips 11/17/2019 11/17/2019 2.50 PROD1 CASING CIRC P Hold PJSM, displace 9.0ppg Flo Pro 17,446.0 17,446.0 13:30 16:00 mud to 9.5ppg brine, 250gpm, 1643psi, 50rpm, 9K TO, 10% FO, PU/SO=199K/88K, total 7945stks 11/17/2019 11/17/2019 0.50 PROD1 CASING OWFF P OWFF (static) 17,446.0 17,446.0 16:00 16:30 11/17/2019 11/17/2019 1.50 PROD1 CASING SMPD P SOOH from 17,446'MD-16,119'MD 17,446.0 16,119.0 16:30 18:00 with 4" Drill Pipe. PU Wt: 208klbs: SO Wt: 101 klbs. holding back pressure via MPD, 80 psi in slips, 260 psi out of slips Page 37/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) C D5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 11/17/2019 11/17/2019 1.75 PROM CASING SMPD P SOOH from 16,119'MD-15,150'MD 16,119.0 15.150.0 18:00 19:45 with 4" Drill Pipe. PU Wt: 208k1bs' SO Wt: 101klbs. holding back pressure via MPD, 80 psi in slips, 260 psi out of slips 11/17/2019 11/17/2019 1.25 PROD1 CASING SLPC P Inside 7 5/8" int. casing shoe, Slip and 15,150.0 15,150.0 19:45 21:00 Cut Drill Line (164'), SIMOPS - OWFF for 10 min. calibrated Amphion/Totco, 11/17/2019 11/18/2019 3.00 PROM CASING SMPD P SOOH from 15,150'MD-11,450'MD 15,150.0 11,450.0 21:00 00:00 with 4" Drill Pipe. PU Wt: 170klbs; SO Wt: 100k1bs. holding back pressure via MPD, 170gpm going thru MPD choke, 80 psi in slips, 260 psi out of slips, FO=10% 11/18/2019 11/18/2019 6.00 PROD1 CASING SMPD P SOOH 15,150'MD-4,844'MD, MPD at 11,450.0 4,844.0 00:00 06:00 170gpm, out of slips 260psi, in slips=80psi, FO=10%. PU/SP=115K/98K, laying down culled bad hard banded DP as identified. Total jts laid down=31 so far. 11/18/2019 11/18/2019 6.00 PROD1 CASING SMPD P SOOH 4,844'MD-445'MD, under MPD 4,844.0 445.0 06:00 12:00 at 170gpm, out of slips 260psi, in slips=80psi, FO=10%, PU/SP=52K/56K, laying down culled bad hard banded DP as identified. Laid out total of 102jts, 56 culled for hardbanding (total 88 outside) and 28 jts left in pipe shed magazines. 11/18/2019 11/18/2019 0.50 PROM CASING OWFF P OWFF before pulling RCD bearing. 445.0 445.0 12:00 12:30 11/18/2019 11/18/2019 1.00 PROM CASING MPDA P PJSM. pull RCD bearing. 445.0 445.0 12:30 13:30 11/18/2019 11/18/2019 3.00 PROM CASING BHAH P PJSM, LD BHA from 445' -surface. 445.0 0.0 13:30 16:30 11/18/2019 11/18/2019 0.75 PROM CASING BHAH P Clear and clean rig floor on non- 0.0 0.0 16:30 17:15 essential BHA equipment and tools. 11/18/2019 11/18/2019 1.75 PROM WHDBOP RURD P R/U to Test BOP'S 0.0 0.0 17:15 19:00 Page 38/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 i • • 1 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/18/2019 11/19/2019 5.00 PROD1 WHDBOP BOPE P Test BOP'S. 250 low/3500psi high for 0.0 0.0 19:00 00:00 all charted with exception of manual operated and super choke tested to 250/2000psi for charted 5 minutes. Using 4" test joint, tested annular, 2 7/8" x 5 1/2" UPR, with 4 1/2" test joint, tested 2 7/8" x 5 1/2" UPR, and 2 7/8" x 5 1/2" LPR, tested choke valves 1-15, manual operated and super choke. choke and kill manuals and HCR's, 4" valve on kill line, 4" FOSV, 4" dart valve, upper and lower IBOP, blind shear rams, perform Koomey drawdown, ACC=3000psi. manifold=1550psi. Acc=1600psi after all functions on bottles only,Average pressure remaining on 6 bottles=1908psi. 14 sec's to build 200psi, with 2 electric pumps, 102secs to full system pressure with 2 electric and 2 air pumps. Closing times, annular=23secs. UPR=18secs, blind/shear rams=16secs. LPR=16secs, choke HCR=2 sec's, kill HCR=2sec, tested PVT gain/loss and flow out alarms, LEL and H2S alarms. AOGCC witness waived by Jeff Jones 06:47 11-16-2019 - BOP Testing operations completed 01:00, 11-19- 2019 11/19/2019 11/19/2019 1.00 PROD1 WHDBOP BOPE P Completed BOP testing, All primary 0.0 0.0 00:00 01:00 and secondary BOPE controls. Koomey and driller's station were tested. All tests passed initial inspection. 11/19/2019 11/19/2019 0.50 PROD1 WHDBOP RURD P Rig down testing equipment and blow 0.0 0.0 01:00 01:30 down top drive, test pump, kill line, choke line, choke manifold and gas buster. 11/19/2019 11/19/2019 0.75 PROD1 WHDBOP MPSP P Pull test plug, install wear ring as per 0.0 0.0 01:30 02:15 FMC rep, RILDS on 6.875" wear ring. Line up hole fill and fill BOP stack. 14 bbls to fill. 11/19/2019 11/19/2019 3.75 COMPZ1 CASING PULD P Make up ported bull nose to avoid 0.0 3,115.0 02:15 06:00 damage to HWDP pin end, pick up and makeup 96 singles of 4" HWDP from shed and rack in derrick for liner running string weight. Drift all on the skate with 2.3" drift and manually strap displacement every 9 joints. PU/SO=104k/84K at 3125'. 11/19/2019 11/19/2019 2.00 COMPZ1 CASING PULD P POOH on elevators, from 3,115' to 3,115.0 0.0 06:00 08:00 surface. 11/19/2019 11/19/2019 0.50 COMPZ1 CASING RURD P R/U to run 4.5", 12.6 ppf, L80. Hyd 0.0 0.0 08:00 08:30 563 Frac liner as per detail. 11/19/2019 11/19/2019 3.50 COMPZ1 CASING PUTB P Conduct team PJSM in the office , run 0.0 2,032.0 08:30 12:00 4 1/2". 12.6 ppf, L-80, Hyd 563 A lateral liner, from surface to 2,032', PU/SP wts= 59K/66K Losses for tour=58bbis, OA pressure=160psi. Page 39/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/19/2019 11/19/2019 6.00 COMPZ1 CASING PUTB P Pick-up and run 4 1/2" 12.6 ppf, L-80, 2,032.0 7,516.0 12:00 18:00 Hyd 563 A lateral liner, from 2,032'MD- 7,516'MD, PU/SO wts= 101 K/87K. Monitor hole displacement. 11/19/2019 11/20/2019 6.00 COMPZI CASING PUTB P Pick-up and run 4 1/2", 12.6 ppf. L-80, 7,516.0 13,155.0 18:00 00:00 Hyd 563 A lateral liner, from 7,516'MD- 13,155'MD, PU/SO Ms= 118K/101K. Monitor hole displacement. Losses=20bbls for tour 11/20/2019 11/20/2019 6.00 COMPZ1 CASING PUTB P Continued to TIH w/ "A" Lateral 4.5" 13,155.0 18.128.0 00:00 06:00 12.6ppf L-80 H563 trac liner from 13.155' MD to 18,128' MD. P/U Wt = 171 kibs, and S/O Wt = 98 klbs. Monitored displacement on pit #4. Gathered circulating parameters while at the shoe at 15,220' MD. 1 bpm = 124 psi. 1.5 bpm = 145 pis, and 2 bpm = 170 psi. A total of 6.5 bbls of volume was pumped. Attempted to rotate at 5 k (Not successful). P/U Wt = 162 kibs, S/O Wt = 99 kibs. 11/20/2019 11/20/2019 1.00 COMPZ1 CASING PUTB P Continued to TIH w/ "A" Lateral 4.5" 18,128.0 19,102.0 06:00 07:00 12.6ppf L-80 H563 frac liner from 18,128' MD to 19,102' MD. P/U Wt = 172 kibs, and S/O Wt = 97 klbs. Monitored displacement on pit #4 11/20/2019 11/20/2019 1.50 COMPZ1 CASING PUTB P PJSM. M/U Hanger and Seal Bore 19,102.0 19,188.0 07:00 08:30 Extension (X/0 to DP) from 19,102' MD to 19,188' MD. P/U Wt = 172 kibs, S/O Wt = 97 kibs. Rot Wt = 156 kibs. Rotary= 10 rpm,. Monitored displacement on pit #4. 11/20/2019 11/20/2019 3.50 COMPZ1 CASING RUNL P Continued to TIH on DP wl "A" Lateral 19,188.0 22,577.0 08:30 12:00 4.5" 12.6ppf L-80 H563 frac liner from 19,188' MD to 22,577' MD. P/U Wt = 183 kibs, and S/O Wt = 93 klbs. Monitored displacement on pit #4- 11/20/2019 11/20/2019 3.00 COMPZ1 CASING RUNL P Continued to TIH on 14 ppf 4" DP from 22,577.0 26,276.0 12:00 15:00 the derrick from 22,577' MD to 26,276' MD. Monitored displacement on pit #4. 11/20/2019 11/20/2019 3.00 COMPZ1 CASING RUNL P Continued to TIH on 15.7 ppf 4" DP 26,276.0 28,380.0 15:00 18:00 from the derrick from 26,276' MD to 28,380' MD. P/U Wt = 210 klbs. Monitored displacement on pit #4. Encountered tight spot at 28.380' MD Attempted to work through at GPM = 84 gpm. SPP = 700 psi, Rotary = 10 rpm, and TQ = 13 kftlbs. 11/20/2019 11/20/2019 2.00 COMPZ1 CASING RUNL T Worked through tight spot at 28,380' 28,380.0 28,380.0 18:00 20:00 MD. Pumped 84-126 gpm w/ SPP = 710-968 psi, Rotary 2-0-30 rpm. Broke through tight spot and attempted to TIH on elevators wl no success. Attempted to pump in hole with no success. P/U Wt = 214 kibs, S/O Wt = 42 kibs, and Rot = 143 kibs. Page 40/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 • • ww ' a Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/20/2019 11/21/2019 4.00 COMPZ1 CASING RUNL P Rotated 4 1/2" liner in hole from 28,380.0 29,775.0 20:00 00:00 28,380' MD to 29,775' MD w/ 5 stands of 4" HWDP from the derrick followed by 15.7 ppf 4" DP. Rotary = 20 rpm, GPM = 84 gpm, SPP = 675 psi, and TQ = 12-15kftlbs. Worked pipe through tight spots. Note` filled active w/ 9.0 ppg FloPro and displaced drillstring on the fly while rotating pipe down. 11/21/2019 11/21/2019 6.00 COMPZ1 CASING RUNL P Rotated 4 1/2" liner in hole from 29,775.0 32,035.0 00:00 06:00 28,775' MD to 32,035' MD w/ stands of 15.7 ppf 4" DP and 4" HWDP. Rotary = 20 rpm. GPM = 84 gpm. SPP = 775 psi, and TQ = 12-15kftlbs. Rot Wt = 149 klbs. 26 bph loss rate at 2 bpm while rotating string in hole. Note` filled active w/ 9.0 ppg FloPro and displaced drillstring on the fly while rotating pipe down. 11/21/2019 11/21/2019 5.00 COMPZ1 CASING RUNL P Rotated 4 1/2" liner in hole from 32,035.0 33,725.0 06:00 11:00 32,035' MD to 33.725' MD w/ stands of 15.7 ppf 4" DP and 4" HWDP Rotary = 20 rpm, GPM = 84 gpm, SPP = 775 psi, and TQ = 16 kftlbs. Rot Wt = 131 klbs Note' filled active w/ 9.0 ppg FloPro and displaced drillstring on the fly while rotating pipe down. 11/21/2019 11/21/2019 1.50 COMPZ1 CASING HOSO P Dropped 1.5" setting ball. Pumped 33,725.0 33,735.0 11:00 12:30 down at 84 gpm w/ 900 psi. Ball set at 1,085 strokes. Pressured up to 2,500 psi to set hanger. Sat down 50 klbs to confirm that the hanger was set. Pressured up to 4,000 psi to release. P/U to string weight 204 klbs + 5'. Set down 50 klbs to set packer in place. P/U to string weight 204 klbs + 5'. Rotated at 15 rpm (TQ = 7.5 kftlbs) and sat down 50 klbs to ensure weight transfer. Liner set in place at 33,735' MD. Top of Liner is at 14,593' MD. 11/21/2019 11/21/2019 1.00 COMPZ1 CASING PRTS P Tested liner top packer to 2,500 psi 33,735.0 33,735.0 12:30 13:30 (Charted). Total strokes = 38. 11/21/2019 11/21/2019 0.75 COMPZ1 WELLPR OWFF P OWFF (Static) 33,735.0 33,735.0 13:30 14:15 11/21/2019 11/21/2019 3.75 COMPZ1 WELLPR TRIP P POOH from 14,394' MD to 10,877' MD 14,394.0 10,877.0 14:15 18:00 w/ 4" DP (Racking back in the derrick). P/U Wt = 159 klbs. Monitored displacement on trip tanks. 11/21/2019 11/21/2019 5.75 COMPZ1 WELLPR TRIP P POOH from 10,877' MD to 154' MD w/ 10,877.0 154.0 18:00 23:45 4" DP (Racking back in the derrick). P/U Wt = 145 klbs @ 8,000' MD. Monitored displacement on trip tanks. 11/21/2019 11/22/2019 0.25 COMPZ1 WELLPR BHAH P PJSM. L/D liner running tool. 154.0 0.0 23:45 00:00 Maintained constant hole fill over the top and monitored trip pit before and after BHA. 11/22/2019 11/22/2019 1.50 COMPZ1 WELLPR BHAH P L/D liner hanger running tools. 0.0 0.0 00:00 01:30 1 I I I Cleaned and cleared the rig floor. Page 41/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/22/2019 11/22/2019 1.25 PROD2 WHPST SLPC P PJSM. Slipped and cut drill line 0.0 0.0 01:30 02:45 (133717 wraps). Calibrated Amphion and Totco. Unspooled additional line from spooler for new spool install. 11/22/2019 11/22/2019 3.25 PROD2 WHPST BHAH P PJSM. P/U Whipstock BHA 0.0 0.0 02:45 06:00 Maintained constant hole fill over the top using the jet pump and monitored returns on Pit #4. 11/22/2019 11/22/2019 1.00 PROD2 WHPST WPST P PJSM. Continued picking up 0.0 328.0 06:00 07:00 Whipstock/Milling BHA from surface to 328' MD. P/U Wt = 57 kibs, S/O Wt = 62 klbs. Monitored displacement w/ pit #4. 11/22/2019 11/22/2019 5.00 PROD2 WHPST WPST P PJSM.TIH w/ Whipstock/Milling BHA 328.0 6,594.0 07:00 12:00 from 328' MD to 6,594' MD. P/U Wt = 111 kibs, S/O Wt = 93 kibs. Monitored displacement w/ pit #4. 11/22/2019 11/22/2019 4.00 PROD2 WHPST WPST P PJSM.TIH w/ Whipstock/Milling BHA 6,594.0 11,535.0 12:00 16:00 from 6,594' MD to 11,535' MD. P/U Wt = 159 klbs, S/O Wt = 121 kibs Monitored displacement w/ pit #4. 11/22/2019 11/22/2019 1.00 PROD2 WHPST SEQP P C/O Saver Sub 11,535.0 11,535.0 16:00 17:00 11/22/2019 11/22/2019 1.00 PROD2 WHPST WPST P PJSM.TIH w/ Whipstock/Milling BHA 11,535.0 12,542.0 17:00 18:00 from 11,535' MD to 12,542' MD. P/U Wt = 171 kibs, S/O Wt = 127 kibs. Monitored displacement w/ pit #4 11/22/2019 11/22/2019 1.50 PROD2 WHPST WPST P TIH w/ Whipstock/Milling BHA from 12,542.0 14,392.0 18:00 19:30 12,542' MD to 14,392' MD w/ 4" from derrick. P/U Wt = 200 kibs, S/O Wt = 154 kibs. Monitored displacement w/ pit #4. Logged R/A tag at 14,180' MD. 11/22/2019 11/22/2019 1.50 PROD2 WHPST WPST P Filled pipe. Oriented whipstock to 44° 14,392.0 14,593.0 19:30 21:00 R GTF. Tagged no go at 14,593' MD. Set 15 kibs downwards. P/U 15 kibs over (X2). Set 30 klbs down to shear the bolt on milling assembly. Top of Whipstock = 14369' Bottom of Whipstock = 14383' 11/22/2019 11/22/2019 0.50 PROD2 WHPST PRTS P Tested packer to 1,000 psi for 10 14,593.0 14,593.0 21:00 21:30 minutes. B/D kill line and shut manuals for milling. 11/22/2019 11/23/2019 2.50 PROD2 WHPST WPST P Mill 6 1/2" window out of 7 5/8" casing 14,369.0 14,373.0 21:30 00:00 from 14369' MD to 14,373' MD. WOB = 3-5 kibs, GPM = 300 gpm, PSI on = 2,550 psi, Rotary = 80 rpm, TQ On = 6 -13 kftlbs, Flow Out= 11 %, 11/23/2019 11/23/2019 4.00 PROD2 WHPST WPST P Mill 6 1/2" window out of 7 5/8" casing 14,373.0 14,394.0 00:00 04:00 from 14,373' MD to 14,394' MD (7,614' TVD). WOB = 3-5 kibs, GPM = 300 gpm, PSI on = 2,550 psi, Rotary = 80- 100 rpm, TQ On = 6-13 kftlbs, Flow Out = 11 %, P/U Wt = 201 kibs, S/O Wt = 155 kibs, and Rot Wt = 201 kibs. Pumped 30 bbls Super Sweep. 11/23/2019 11/23/2019 1.50 PROD2 WHPST WPST P Worked milling BHA through window 14,394.0 14,394.0 04:00 05:30 w/ 100 rpm (X4), No rotation (X2), No Pump and Rotation (X2). Blown down top drive. 11/23/2019 11/23/2019 0.50 PROD2 WHPST OWFF P Pulled into casing and OWFF (Static). 14,394.0 14,351.0 05:30 06:00 Page 42/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/23/2019 11/23/2019 0.75 PROD2 WHPST TRIP P PJSM. POOH from 14,351' MD to 14,351.0 14,069.0 06:00 06:45 14,069' MD w/ 4" DP (Racking back in the derrick). P/U Wt = 204 klbs, and S/O Wt = 156 klbs. Monitored displacement on pit #4. 11/23/2019 11/23/2019 3.75 PROD2 WHPST TRIP P PJSM. POOH while L/D 4" HWDP 14,069.0 11,514.0 06:45 10:30 singles to pipe shed from 14,069' MD to 11,514' MD. P/U Wt = 160 klbs, and S/O Wt = 123 klbs. Monitored displacement on pit #4 11/23/2019 11/23/2019 1.50 PROD2 WHPST TRIP P PJSM. POOH from 11,514' MD to 11,514.0 8,465.0 10:30 12:00 8,465' MD w/ 4" DP (Racking back in the derrick). P/U Wt = 128 klbs, and S/O Wt = 104 klbs. Monitored displacement on trip tank. 11/23/2019 11/23/2019 3.50 PROD2 WHPST TRIP P PJSM. POOH from 8,465' MD to 198' 8,465.0 198.0 12:00 15:30 MD w/ 4" DP (Racking back in the derrick). P/U Wt = 56 klbs, and S/O Wt = 59 klbs. Monitored displacement on trip tank. 11/23/2019 11/23/2019 1.00 PROD2 WHPST BHAH P PJSM. L/D Milling BHA from 198' MD 198.0 0.0 15:30 16:30 to surface. Monitored displacement on trip tank. 11/23/2019 11/23/2019 1.50 PROD2 WHPST OTHR P M/U Stack washer w/ magnets and 0.0 0.0 16:30 18:00 flushed stack. 11/23/2019 11/23/2019 2.00 PROD2 WHPST BHAH P M/U 6 1/2" Kick Off BHA#8 from 0.0 557.0 18:00 20:00 surface to 557' 11/23/2019 11/23/2019 2.50 PROD2 WHPST TRIP P Single in 4" DP the hole (From pipe 557.0 1,970.0 20:00 22:30 shed) from 557' MD to 1,970' MD, 11/23/2019 11/23/2019 0.50 PROD2 WHPST DHEQ P Shallow tested MWD (Good). GPM = 1,970.0 1,970.0 22:30 23:00 220-270 gpm, SPP = 720-900 psi, and F/O = 7-13% 11/23/2019 11/24/2019 1.00 PROD2 WHPST TRIP P TIH from 1,970' MD to 4,602' MD w/ 4" 1,970.0 4,602.0 23:00 00:00 DP from the derrick. Filled pipe every 20 stands. P/U Wt = 91 klbs, and S/O Wt = 89 klbs. Monitored displacement on pit #4. 11/24/2019 11/24/2019 5.50 PROD2 WHPST TRIP P TIH from 4,602' MD to 14.299' MD w/ 4,602.0 14,299.0 00:00 05:30 4" DP from the derrick. Filled pipe every 20 stands. P/U Wt = 168 klbs, and S/O Wt = 120 klbs. Monitored displacement on pit #4. 11/24/2019 11/24/2019 0.50 PROD2 WHPST TRIP P Oriented BHA 40 degrees to the right 14,299.0 14,392.0 05:30 06:00 Shut pumps and tripped through the window. Tagged up at 14,392' MD. 11/24/2019 11/24/2019 4.00 PROD2 WHPST DRLG P Drilled to Kick Off and land in zone 14,392.0 14,450.0 06:00 10:00 from 14,392' MD to 14,450' MD. WOB = 7 klbs, GPM = 250 gpm, SPP On = 1700 psi, Rotary = 40 rpm. TO On = 7.5 kftlbs, F/O = 13%, P/U Wt = 179 klbs, S/O Wt = 122 klbs, RT Wt = 144 klbs. ADT = 3.68 hrs. AST = 1.44 hrs. and ART = 2.24 hrs 11/24/2019 11/24/2019 2.00 PROD2 WHPST CIRC P CBU. Pumped 40 bbl sweep TOtal 14.450.0 14,450.0 10:00 12:00 strokes 6,200. 11/24/2019 11/24/2019 0.50 PROD2 WHPST OWFF P OWFF (Static). 14,450.0 14,450.0 12:00 12:30 11/24/2019 11/24/2019 5.50 PROD2 WHPST TRIP P PJSM. POOH from 14,450' MD to 14,450.0 2,001.0 12:30 18:00 2,001 MD w/ 4" DP racked back in the derrick. P/U Wt = 74 klbs, S/O Wt = 80 klbs, Monitored displacement on trip tank Page 43/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/24/2019 11/24/2019 1.00 PROD2 WHPST TRIP P POOH from 2,001' MD to 557' MD w/ 2,001.0 557.0 18:00 19:00 4" DP racked back in the derrick. Monitored displacement on trip tank. 11/24/2019 11/24/2019 0.50 PROD2 WHPST OWFF P OWFF (Static) 557.0 557.0 19:00 19:30 11/24/2019 11/24/2019 1.50 PROD2 WHPST BHAH P L/D BHA #8. 557.0 0.0 19:30 21:00 11/24/2019 11/24/2019 0.50 PROD2 WHPST CLEN P Clean and clear rig floor 0.0 0.0 21:00 21:30 11/24/2019 11/24/2019 0.50 PROD2 WHPST SFTY P PJSM for slip and cut 0.0 0.0 21:30 22:00 11/24/2019 11/25/2019 2.00 PROD2 WHPST SLPC P Slip and cut 1,995' of drill line (New 0.0 0.0 22:00 00:00 Spool), 11/25/2019 11/25/2019 1.00 PROD2 WHPST SLPC P Slipped and cut drill line. 0.0 0.0 00:00 01:00 11/25/2019 11/25/2019 0.50 PROD2 WHPST SVRG P Serviced top drive. blocks, crown, and 0.0 0.0 01:00 01:30 calibrated blocks. SIMOPS: P/U BHA components to rig floor. 11/25/2019 11/25/2019 0.50 PROD2 WHPST BHAH P P/U BHA to rig floor. 0.0 0.0 01:30 02:00 11/25/2019 11/25/2019 2.00 PROD2 WHPST BHAH P M/U RSS BHA#9 from surface to 337' 0.0 337.0 02:00 04:00 MD 11/25/2019 11/25/2019 2.00 PROD2 WHPST TRIP P TIH from 337' MD to 2,213' MD w/ 4" 337.0 2,213.0 04:00 06:00 DP from derrick. Monitored displacement on pit #4. P/U Wt = 76 klbs, and S/O Wt = 82 klbs. 11/25/2019 11/25/2019 6.00 PROD2 WHPST TRIP P TIH from 2,213' MD to 11,688' MD w/ 2,213.0 11,668.0 06:00 12:00 4" DP from derrick. Monitored displacement on pit #4. P/U Wt = 157 klbs, and S/O Wt = 117 klbs. Filled pipe every 20 stands. 11/25/2019 11/25/2019 2.50 PROD2 WHPST TRIP P TIH from 11,688' MD to 14,172' MD w/ 11,668.0 14,172.0 12:00 14:30 4" DP from derrick. Monitored displacement on pit #4. P/U Wt = 173 klbs, and S/O Wt = 121 kilos. Filled pipe every 20 stands. 11/25/2019 11/25/2019 0.75 PROD2 WHPST DLOG P Washed down and logged R/Atag 14,172.0 14,267.0 14:30 15:15 from 14,172' MD to 14,267' MD. GPM = 240 gpm, and SPP = 1,779 psi. R/A tag observed at 14,180' MD. 11/25/2019 11/25/2019 0.75 PROD2 WHPST MPDA P PJSM. Removed trip nipple and 14,267.0 14,267.0 15:15 16:00 installed RCD bearing. 11/25/2019 11/25/2019 1.00 PROD2 WHPST TRIP P TIH from 14,267' MD to 14,450' MD w/ 14,267.0 14,450.0 16:00 17:00 4" DP from derrick. Monitored displacement on pit #4. P/U Wt = 178 klbs, and S/O Wt = 120 klbs. 11/25/2019 11/25/2019 1.00 PROD2 DRILL DRLG P Drilled 6 1/2" production hole from 14,450.0 14,512.0 17:00 18:00 14,450' MD to 14,512' MD (7.633' TVD), WOB = 15 klbs, GPM = 255 gpm, SPP on = 1,933 psi, Rotary = 100 rpm, TQ on = 10 kftlbs, F/O = 6%, ECD = 9.91 ppg, P/U Wt = 178 klbs, S/O Wt = 120 klbs, and Rot Wt = 146 klbs. MPD connection back pressure = 0 psi. ADT = 0.59 hrs, and Jar Time = 4.27 hrs. Page 44/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 • • F Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/25/2019 11/26/2019 6.00 PROD2 DRILL DRLG P Drilled 6 1/2" production hole from 14,512.0 15.091.0 18:00 00:00 14,512' MD to 15.091' MD (7,631' TVD), WOB = 15 klbs, GPM = 260 gpm, SPP on = 2,112 psi, Rotary = 100 rpm, TO on = 10 kftlbs, F/O = 6%, ECD = 10.09 ppg, P/U Wt = 165 klbs, S/O Wt = 108 klbs, and Rot Wt = 150 klbs. MPD connection back pressure = 0 psi. ADT = 4.46 hrs, and Jar Time = 8.14 hrs 11/26/2019 11/26/2019 6.00 PROD2 DRILL DRLG P Drilled 6 1/2" production hole from 15.091.0 15,690.0 00:00 06:00 15,091' MD to 15,690' MD (7,624' TVD), WOB = 14 klbs. GPM = 259 gpm, SPP on = 2,296 psi, Rotary = 80 rpm, TO on = 10-12 kftlbs, F/O = 12%. ECD = 10.31 ppg, P/U Wt = 170 klbs. S/O Wt = 114 klbs, and Rot Wt = 146 klbs. ADT = 4.03 hrs. Bit Hours = 8.49 and Jar Time = 12.17 hrs. MPD connection back pressure = 0 psi Pumped Anti -Jamming sweep. 11/26/2019 11/26/2019 6.00 PROD2 DRILL DRLG P Drilled 6 1/2" production hole from 15,690.0 16,408.0 06:00 12:00 15,690' MD to 16,408' MD (7,629' TVD), WOB = 15 klbs, GPM = 260 gpm, SPP on = 2,352 psi, Rotary = 80 rpm, TO on = 10-11 kftlbs, F/O = 14%, ECD = 10.29 ppg, P/U Wt = 175 klbs, S/O Wt = 114 klbs, and Rot Wt = 142 klbs. ADT = 4.34 hrs, Bit Hours = 12.83 and Jar Time = 16.59 hrs. MPD connection back pressure = 0 psi. Pumped Anti -Jamming sweep. 11/26/2019 11/26/2019 6.00 PROD2 DRILL DRLG P Drilled 6 1/2" production hole from 16,408.0 17.155.0 12:00 18:00 16,408' MD to 17,155' MD (7,630' TVD), WOB = 19 klbs, GPM = 270 gpm, SPP on = 2,595 psi, Rotary = 90 rpm, TO on = 12 kftlbs, F/O = 14%, ECD = 10.38 ppg, P/U Wt = 175 klbs, S/O Wt = 112 klbs, and Rot Wt = 144 klbs. ADT = 3.98 hrs, Bit Hours = 16.81 and Jar Time = 20.49 hrs. MPD connection back pressure = 0 psi. Pumped Anti -Jamming sweep. 11/26/2019 11/27/2019 6.00 PROD2 DRILL DRLG P Drilled 6 1/2" production hole from 17,155.0 17,635.0 18:00 00:00 17,155' MD to 17,635' MD (7,632' TVD), WOB = 11 klbs, GPM = 270 gpm, SPP on = 2,630 psi, Rotary = 90 rpm, TO on = 11 kftlbs, TO off = 7 kftlbs, F/O = 13%. ECD = 10.3 ppg, P/U Wt = 170 klbs, S/O Wt = 111 klbs, and Rot Wt = 145 klbs. ADT = 2.71 hrs, Bit Hours = 19.52 and Jar Time = 23.2 hrs. MPD connection back pressure = 0 psi. Pumped Anti - Jamming sweep. 11/27/2019 11/27/2019 3.50 PROD2 DRILL DRLG P Drilled 6 1/2" production hole from 17,635.0 17,932.0 00:00 03:30 17,635' MD to 17,932' MD (7,634' TVD), WOB = 18 klbs, GPM = 270 gpm, SPP on = 2,650 psi, Rotary = 80 rpm, TO on = 10-12 kftlbs. TO off= 8 kftlbs, F/O = 14%, ECD = 10.25 ppg. P/U Wt = 175 klbs, S/O Wt = 109 klbs, and Rot Wt = 146 klbs. ADT = 3.2 hrs. Bit Hours = 23.36 and Jar Time = 27.04 hrs. MPD connection back pressure = 0 psi. Page 45/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/27/2019 11/27/2019 1.50 PROD2 CASING CIRC P Obtained survey. Circulated, rotated 17,932.0 17,930.0 03:30 05:00 and reciprocated pipe from 17,930' MD to 17,870' MD w/ GPM = 270 gpm. SPP = 2.630 psi. F/O = 13%, ROM 70 rpm, TO = 8 kftlbs, and ECD = 10.21 ppg, P/U Wt = 175 klbs, S/O Wt = 109 klbs, and Rot Wt = 146 klbs. 11/27/2019 11/27/2019 0.50 PROD2 CASING OWFF P Fingerprinting (Static). 17,930.0 17,930.0 05:00 05:30 11/27/2019 11/27/2019 4.50 PROD2 CASING CIRC P CBU while racking back stands after 17,930.0 17,582.0 05:30 10:00 each bottoms up from 17,930' MD to 17,582' MD w/ GPM = 270 gpm, SPP = 2,630 psi, F/O = 13%, ROM 70 rpm, TQ = 8 kftlbs, and ECD = 10.23 ppg. P/U Wt = 181 klbs, S/O Wt = 108 klbs, and Rot Wt = 142 klbs. 11/27/2019 11/27/2019 2.00 PROD2 CASING CIRC P PJSM. Displaced well at 17,582' MD 17,582.0 17,582.0 10:00 12:00 to 9.5 ppg KW Brine. Rotated and reciprocated 90'w/ GPM = 268 gpm, ICP = 2,449 psi, FCP = 1,994 psi. Rotary = 60 rpm, and TQ = 7.5 kftlbs. P/U Wt = 184 klbs, S/O Wt = 110 klbs. and Rot Wt = 140 klbs. 11/27/2019 11/27/2019 0.50 PROD2 CASING OWFF P OWFF (Static). 17,582.0 17,582.0 12:00 12:30 11/27/2019 11/27/2019 3.50 PROD2 CASING SMPD P SOOH f/ 17.582' MD to 14,207' MD w/ 17,582.0 14,207.0 12:30 16:00 4" DP L/D doubles in the pipe shed. P/U Wt = 183 klbs, S/O Wt = 119 klbs, In Slips = 50 psi, Out of Slips = 80 psi. Monitored displacement on pit #4. 11/27/2019 11/27/2019 0.50 PROD2 CASING MPDA P PJSM. OWFF. Pulled RCD bearing 14,207.0 14,207.0 16:00 16:30 and installed trip nipple. 11/27/2019 11/27/2019 1.50 PROD2 CASING TRIP P PJSM. POOH f/ 14,207' MD to 13,090' 14,207.0 13,090.0 16:30 18:00 MD w/ 4" DP L/D doubles in the pipe shed. P/U Wt = 179 klbs, and S/O Wt = 11 klbs, Monitored displacement on pit #4. 11/27/2019 11/27/2019 4.00 PROD2 CASING TRIP P PJSM. POOH f/ 13,090' MD to 9,751' 13,090.0 9,751.0 18:00 22:00 MD w/ 4" DP L/D doubles in the pipe shed. P/U Wt = 150 klbs, and S/O Wt = 115 klbs, Monitored displacement on pit #4. 11/27/2019 11/28/2019 2.00 PROD2 CASING TRIP P PJSM. POOH f/ 9,751' MD to 8,592' 9,751.0 8,592.0 22:00 00:00 MD w/ 4" DP L/D singles in the pipe shed. P/U Wt = 135 klbs, and S/O Wt = 105 klbs, Monitored displacement on pit #4. 11/28/2019 11/28/2019 6.00 PROD2 CASING TRIP P POOH f/ 8,592' MD to 3.996' MD w/ 8,592.0 3,996.0 00:00 06:00 4" DP L/D singles in the pipe shed P/U Wt = 87 klbs, and S/O Wt = 83 klbs, Monitored displacement on pit #4. 11/28/2019 11/28/2019 3.50 PROD2 CASING TRIP P POOH f/ 3,996' MD to 430' MD w/ 4" 3,996.0 430.0 06:00 09:30 DP L/D singles in the pipe shed. P/U Wt = 48 klbs, and S/O Wt = 55 klbs. Monitored displacement on pit #4 11/28/2019 11/28/2019 0.25 PROD2 CASING OWFF P OWFF (Static). 430.0 430.0 09:30 09:45 11/28/2019 11/28/2019 1.75 PROD2 CASING BHAH P PJSM. L/D BHA#9. from 430' MD to 430.0 0.0 09:45 11:30 surface. Monitored displacement on pit #4. 11/28/2019 11/28/2019 1.00 PROD2 CASING CLEN P Cleaned and cleared rig floor. 0.0 0.0 11:30 12:30 Page 46/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/28/2019 11/28/2019 1.50 COMPZ2 FISH BHAH P PJSM P/U Whipstock retrieval BHA 0.0 127.0 12:30 14:00 #10 from surface to 127' MD. P/U Wt = 48 kibs, and S/O Wt = 50 klbs, Monitored displacement on pit #4. 11/28/2019 11/28/2019 1.00 COMPZ2 FISH TRIP P TIH from 127' MD to 2,491' MD w/ 4" 1270 2,491.0 14:00 15:00 DP from the derrick. P/U Wt = 66 kibs, and S/O Wt = 69 kibs, Monitored displacement on pit #4. 11/28/2019 11/28/2019 0.50 COMPZ2 FISH SVRG P Lubricate rig 2,491.0 2,491.0 15:00 15:30 11/28/2019 11/28/2019 2.50 COMPZ2 FISH TRIP P TIH from 2,491' MD to 6,277' MD w/ 4" 2,491.0 6,2770 15:30 18:00 DP from the derrick. P/U Wt = 101 kibs, and S/O Wt = 92 kibs, Monitored displacement on pit #4. 11/28/2019 11/29/2019 6.00 COMPZ2 FISH TRIP P TIH from 6,277' MD to 14,292' MD w/ 6,277.0 14,292.0 18:00 00:00 4" DP from the derrick. P/U Wt = 180 kibs, and S/O Wt = 128 klbs, Monitored displacement on pit #4. Logged R/Atag at 14,178' MD. 11/29/2019 11/29/2019 1.50 COMPZ2 FISH WASH P Oriented 135 degrees Left GTF. 14,292.0 14,286.0 00:00 01:30 Washed slot 5 X. Oriented 45 degrees right GTF. Set 10 kibs down weight @ 14,374' MD. P/U to 225 klbs, 40 k over (bleed of jars). P/U 255 klbs to release anchor. Racked back one stand of DP at 14,286' MD 11/29/2019 11/29/2019 1.50 COMPZ2 FISH CIRC P CBU at 14,286' MD w/ 255 gpm, SPP 14,286.0 14,286.0 01:30 03:00 1,320 psi, and F/O = 13%. Total strokes pumped 4,921. 11/29/2019 11/29/2019 0.50 COMPZ2 FISH OWFF P OWFF (Static) 14,286.0 14,286.0 03:00 03:30 11/29/2019 11/29/2019 2.50 COMPZ2 FISH TRIP P POOH from 14,286' MD to 7,550' MD 14,286.0 7,550.0 03:30 06:00 w/ 4" DP racked back in the derrick P/U 143 kibs. Monitored displacement on pit #4. 11/29/2019 11/29/2019 5.00 COMPZ2 FISH TRIP P POOH from 7,550' MD to 352' MD w/ 7,550.0 352.0 06:00 11:00 4" DP racked back in the derrick. Monitored displacement on pit #4. 11/29/2019 11/29/2019 2.50 COMPZ2 FISH BHAH P PJSM. L/D Whipstock and 352.0 0.0 11:00 13:30 Whipstock/retrieval BHA #10, 11/29/2019 11/29/2019 0.50 COMPZ2 CLNOUT CLEN P Cleaned and cleared rig floor. 0.0 0.0 13:30 14:00 11/29/2019 11/29/2019 0.75 COMPZ2 CLNOUT BHAH P M/U Clean Out BHA#11 0.0 82.0 14:00 14.45 11/29/2019 11/29/2019 3.25 COMPZ2 CLNOUT TRIP P RIH w/ BHA#11 from 82' MD to 5,008' 82.0 5,008.0 14:45 18:00 MD w/ 4" DP. P/U Wt = 90 kibs, S/O Wt = 88, klbs. Monitored displacement on pit #4. Filled every 20 stands. 11/29/2019 11/30/2019 6.00 COMPZ2 CLNOUT TRIP P RIH w/ BHA#11 from 5,008' MD to 5,008.0 13,556.0 18:00 00:00 13,556' MD w/ 4" DP. P/U Wt = 178 kibs, S/O Wt = 128, kibs. Monitored displacement on pit #4. Filled every 20 stands. 11/30/2019 11/30/2019 0.50 COMPZ2 CLNOUT TRIP P RIH w/ BHA#11 from 13,556' MD to 13,556.0 14,337.0 00:00 00:30 14,337' MD w/ 4" DP. P/U Wt = 180 kibs, S/O Wt = 129, klbs. Monitored displacement on pit #4. Filled every 20 stands. 11/30/2019 11/30/2019 0.50 COMPZ2 CLNOUT TRIP P Worked clean out assembly w/ mill by 14,337.0 14,383.0 00:30 01:00 window at 14,369' MD to 14383' MD. (Good) Page 47/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 0. 1AA W. ) Rig: DOYON 25 Job: DRILLING ORIGINAL Time. Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/30/2019 11/30/2019 0.50 COMPZ2 UNCUT TRIP P RIH to 14,602' MD. Stung into TOL w/ 14,383.0 14,602.0 01:00 01:30 GPM = 125 gpm, and SPP = 300 psi. No pressure increase was observed. P/U to 14,580' MD. Increased GPM = 210 gpm, and SPP = 680 psi (X2). Observed the TOL at 14,590' MD. 11/30/2019 11/30/2019 1.00 COMPZ2 CLNOUT CIRC P CBU at 14,588' MD w/ GPM = 251 14,602.0 14,588.0 01:30 02:30 gpm. SPP = 880 psi. F/O = 13%. Total Stokes pumped = 6,129. 11/30/2019 11/30/2019 2.50 COMPZ2 CLNOUT CIRC P Displaced well to 9.5 ppg clear brine 14,588.0 14,588.0 02:30 05:00 at 14,588' MD w/ GPM = 210 - 251 gpm, SPP = 880-1,100 psi, F/O = 13%. Total Stokes pumped = 8,515. 11/30/2019 11/30/2019 2.00 COMPZ2 CLNOUT CIRC P Pumped Corrosion Inhibited brine 14,588.0 14,588.0 05:00 07:00 directtly from truck at 14,588' MD w/ GPM = 210 - 251 gpm, SPP = 880- 1,100 psi, F/O = 13%. Total Stokes pumped = 5,150. 11/30/2019 11/30/2019 0.50 COMPZ2 CLNOUT OWFF P OWFF (Static). 14,588.0 14,588.0 07:00 07:30 11/30/2019 11/30/2019 4.50 COMPZ2 CLNOUT TRIP P POOH w/ clean out BHA whilst LID 4" 14,588.0 12,500.0 07:30 12:00 DP singles from 14,588' MD to 12,500' MD. P/U Wt= 160 klbs, SIC, Wt = 125 klbs. Monitored hole fill on pit #2. 11/30/2019 11/30/2019 6.00 COMPZ2 CLNOUT TRIP P POOH w/ clean out BHA whilst LID 4" 12,500.0 8,800.0 12:00 18:00 DP singles from 12,500' MD to 8,800' MD. P/U Wt= 120 klbs, SIC, Wt = 109 klbs. Monitored hole fill on pit #2. 11/30/2019 12/1/2019 6.00 COMPZ2 CLNOUT TRIP P POOH w/ clean out BHA whilst LID 4" 8,800.0 4,200.0 18:00 00:00 DP singles from 8,800' MD to 4,200' MD. P/U Wt= 80 klbs, S/O Wt = 80 klbs. Monitored hole fill on pit #2. 12/1/2019 12/1/2019 5.00 COMPZ2 CLNOUT TRIP P POOH while LID 4" DP from 4,200' 4,200.0 0.0 00:00 05:00 MD to surface. Monitored hole fill on pit #2 12/1/2019 12/1/2019 1.50 COMPZ2 CLNOUT BHAH P LID Clean Out BHA #11. 0.0 0.0 05:00 06:30 12/1/2019 12/1/2019 0.50 COMPZ2 RPCOMP CLEN P Cleaned and cleared rig floor. 0.0 0.0 06:30 07:00 12/1/2019 12/1/2019 1.50 COMPZ2 RPCOMP SLPC P Slipped and cut 135' of drill line (17 0.0 0.0 07:00 08:30 wraps) and calibrated blocks. 12/1/2019 12/1/2019 0.50 COMPZ2 RPCOMP OTHR P Pulled wear ring. 0.0 0.0 08:30 09:00 12/1/2019 12/1/2019 1.00 COMPZ2 RPCOMP WWWH P LID Single DP and magnets. Flushed 0.0 0.0 09:00 10:00 BOP stack. Rotary = 50 rpm, GPM = 675 GPM. SPP = 256 psi, and F/O = 33%. 12/1/2019 12/1/2019 1.00 COMPZ2 RPCOMP BHAH P LID Magnet and Double of 4" DP. 0.0 0.0 10:00 11:00 12/1/2019 12/1/2019 1.00 COMPZ2 WHDBOP RURD P Set test plug and rigged up to test 0.0 0.0 11:00 12:00 BOPs. Rigged up to pump down the IA w/ injection line to keep hole full. 12/1/2019 12/1/2019 0.50 COMPZ2 WHDBOP BOPE P Performed shell test and fill hole down 0.0 0.0 12:00 12:30 IA. 3 bbls to fill. Page 48/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/1/2019 12/1/2019 4.00 COMPZ2 WHDBOP BOPE P Tested BOPE's. All tests 250psi 0.0 0.0 12:30 16:30 low/3500psi high for 5 charted minutes with exception of manual operated and super chokes which were tested to 250/2000psi for 5 charted minutes. Used 3 1/2" and 4 1/2" testjts,to test the annular, 2 7/8"" x 5 1/2"" UPR, and 27/8 x 5 1/2"" LPR. Tested choke valves 1-15, manual operated and super chokes, choke and kill manuals and NCR's, 4" valve on kill line, Blind/Shear Rams, 4" FOSV. 4" dart valve, upper and lower IBOP. Perform Koomey drawdown, Accumulator = 3000 psi, Manifold =1500 psi. Accumulator =1600 psi after all functions on just bottles. 15 secs to 200 psi build with 2 electric pumps, 85 secs to build to full system pressure with 2 electric and 2 air pumps. N2 x 6 bottles Ave = 1860 psi. Closing times, annular=24 secs, UPR=21 secs, blind/shears=17 secs, LPR=16 sec. Choke HCR=2 sec, kill HCR=2sec. Tested PVT gain/loss and flow alarms. Tested LEL and 1-12S alarms. AOGCC Rep Austin McLeod waived witness on 11/29/2019 at 17:50 hr. 12/1/2019 12/1/2019 0.50 COMPZ2 WHDBOP RURD P R/D and blowed down test equipment. 0.0 0.0 16:30 17:00 Cleaned and cleared rig floor. Pull test plug 12/1/2019 12/1/2019 2.50 COMPZ2 RPCOMP RURD P Brought up tools to the rig floor and 0.0 0.0 17:00 19:30 rigged up to run upper completions. 12/1/2019 12/1/2019 2.50 COMPZ2 RPCOMP RCST P PJSM. RIH w/ 3 1/2" x 4 1/2" Upper 0.0 594.0 19:30 22:00 completions as per detail from 0 to 594' MD. 12/1/2019 12/1/2019 0.50 COMPZ2 RPCOMP RCST P Changed handling equipment. M/U 1- 594.0 594.0 22:00 22:30 Wire to SLB Gauge Mandrel. 12/1/2019 12/2/2019 1.50 COMPZ2 RPCOMP RCST P Continued RIH w/ 4 1/2" Upper 594.0 1.788.0 22:30 00:00 completions as per detail from 594' MD to 1,788' MD. P/U Wt = 58 klbs, and S/O St = 66 klbs. 12/2/2019 12/2/2019 6.00 COMPZ2 RPCOMP RCST P Continued RIH w/ 4 1/2" Upper 1,788.0 6,780.0 00:00 06:00 completions as per detail from 1,788' MD to 6.780' MD. P/U Wt = 92 klbs, and S/O St = 91 klbs. Monitored displacement on Pit #3. 12/2/2019 12/2/2019 6.00 COMPZ2 RPCOMP RCST P Continued RIH w/ 4 1/2" Upper 6,780.0 11,350.0 06:00 12:00 completions as per detail from 6,780' MD to 11,350' MD. S/O St = 108 klbs. Monitored displacement on Pit #3. 12/2/2019 12/2/2019 4.25 COMPZ2 RPCOMP RCST P Continued RIH w/ 4 1/2" Upper 11,350.0 14,583.0 12:00 16:15 completions as per detail from 11,350' MD to 14,583' MD. P/U Wt = 146 klbs, and S/O St = 113 klbs. Monitored displacement on Pit #3. 12/2/2019 12/2/2019 1.25 COMPZ2 RPCOMP RCST T RIH and attempted to locate TOL 14,583.0 14,593.0 16:15 17:30 Tagged up at 14,593' MD w/ 15 klbs down weight. No indication of shear was observed. Put in 3/4 turn and worked pipe. Attempted to locate on the down stroke. P/U Wt = 146 klbs, and S/O Wt = 113 klbs. Page 49/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 12/2/2019 12/2/2019 0.50 COMPZ2 RPCOMP RCST T L/D joint #346 and P/U 9' pup joint. 14,593.0 14,593.0 17:30 18:00 R/U to pump down tubing w/ top drive. Established circualtion at 2 bpm, SPP = 90 psi. Total strokes pumped = 86. Re -attempted to locate w/ pumps on and one full turn. 12/2/2019 12/2/2019 1.00 COMPZ2 RPCOMP RCST T Worked completions and sting into the 14.593.0 14,593.0 18:00 19:00 TOL .f/ 14,520' MD to 14,593' MD four times to no avail. GPM 168 gpm, and SPP = 158 psi. Total strokes purred = 84. Attempted to sting in liner top (Unsuccessful). Rotated string and applied a half a turn. Worked the completions down into the liner top and set 14 klbs down weight. Pins sheared at 14,613' MD. Fully located on Joint 346 @ 14,614' MD. 12/2/2019 12/2/2019 1.00 COMPZ2 RPCOMP CIRC P L/D joint #346. B/D top drive. Pumped 14,593.0 14,555.0 19:00 20:00 30 bbls of 10 ppg clear brine. SPP = 158 psi and Total Strokes = 282. 12/2/2019 12/2/2019 1.00 COMPZ2 RPCOMP RCST P L/D joints 344-346 and 9' pup. M/U 14,555.0 14,560.0 20:00 21:00 spaceout pups as follows: 5.82'5.83'. 3.77', 3.78', Joint #344, hanger, and landing joint. 12/2/2019 12/2/2019 1.00 COMPZ2 RPCOMP PRTS P Terminated I -Wire and tested to 5,000 14,560.0 14,560.0 21:00 22:00 psi/5 minutes. P/U Wt = 143 klbs, and S/O Wt = 103 klbs. 12/2/2019 12/3/2019 2.00 COMPZ2 RPCOMP RCST T Worked 4 1/2" completions string from 14,560.0 14,593.0 22:00 00:00 14,505' MD to 14,593' MD a total of 25 times to no avail. M/U crossover to top drive and rotated one full turn to try and sting into top of liner. Located liner top. 12/3/2019 12/3/2019 1.50 COMPZ2 RPCOMP THGR P Land Hanger and RILDS. R/U test 14,593.0 14,593.0 00:00 01:30 hanger seals to 3.000 psi for 30 minutes (Charted). Monitored IA while testing (No flow). 12/3/2019 12/3/2019 1.00 COMPZ2 RPCOMP CLEN P Cleaned and cleared rig floor. Blowed 14,593.0 0.0 01:30 02:30 down surface lines. L/D landing joint. 12/3/2019 12/3/2019 3.50 DEMOB MOVE NUND P Sucked out stack. Removed hole fill, 0.0 0.0 02:30 06:00 trip nipple, shrue hole & mouse hole, R/D choke & kill lines, broke bols on the stack and riser, P/U BOPs. and skidded out of the way. Picked up BOP riser and staged in BOP deck. SIMOPS: P/U frac tree to rig floor. 12/3/2019 12/3/2019 1.75 DEMOB MOVE NUND P Terminated and tested I -Wire. 0.0 0.0 06:00 07:45 12/3/2019 12/3/2019 0.25 DEMOB MOVE NUND P Prepped wellhead for adaptor flange 0.0 0.0 07:45 08:00 and frac tree. 12/3/2019 12/3/2019 3.00 DEMOB MOVE NUND P Reassembled and oriented FMC 10k 0.0 0.0 08:00 11:00 frac tree/adaptor. SIMOPS: C/O saver sub on top drive. 12/3/2019 12/3/2019 0.50 DEMOB MOVE PRTS P Test adaptor flange SBM seals to 0.0 0.0 11:00 11:30 5,000 psi for 5 minutes. 12/3/2019 12/3/2019 0.50 DEMOB MOVE OTHR P Filled tree w/ diesel and function 0.0 0.0 11:30 12:00 valves to purge. R/U to test. 12/3/2019 12/3/2019 2.00 DEMOB MOVE RURD P R/U lines for freeze protect. Heat and 0.0 0.0 12:00 14:00 ship diesel to ball mill for freeze protect. 12/3/2019 12/3/2019 1.75 DEMOB MOVE PRTS P Pressure tested tree from 250 psi 0.0 0.0 14:00 15:45 low/10,000 psi high, CPAI witnessed. Bled off and checked IA (On Vaccum). Page 50/51 Report Printed: 12/9/2019 Operations Summary (with Timelog Depths) CD5-26 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/3/2019 12/3/2019 0.50 DEMOB MOVE RURD P Rigged down test equipment. 0.0 0.0 15:45 16:15 12/3/2019 12/3/2019 0.75 DEMOB MOVE RURD P Pulled test dart and HP-BPV. 0.0 0.0 16:15 17:00 12/3/2019 12/3/2019 1.00 DEMOB MOVE PRTS P M/U hoses and hardlines to tree and 0.0 0.0 17:00 18:00 tested to 2,250 psi. 12/3/2019 12/3/2019 1.00 DEMOB MOVE FRZP P Pumped 73 bbls diesel freeze protect 0.0 0.0 18:00 19:00 down IA (Charted). 12/3/2019 12/3/2019 1.00 DEMOB MOVE FRZP P IA pressure before U-tubing equalized 0.0 0.0 19:00 20:00 was 450 psi. Upon equalization the pressures read 220 psi. SIMOPS: R/U bridle lines and prepped derrick for scope. 12/3/2019 12/3/2019 0.50 DEMOB MOVE RURD P Blowed down and rigged down freeze 0.0 0.0 20:00 20:30 protect lines in the cellar. 12/3/2019 12/4/2019 3.50 DEMOB MOVE SEQP T R/U lubricator and tested to 2,000 psi 0.0 0.0 20:30 00:00 (Good). Ran in w/ H-BPV via lubricator and resistance was felt while lowering into the tree. Shut in master valve and attempted to free BPV w/ no success No upwared/downward movement was achieved once the H-BPV was stuck in the tree. Continued trying to extract the H-BPV and lubricator. 12/4/2019 12/4/2019 5.00 DEMOB MOVE WAIT T Sent FMC rep for bedrest while 14,593.0 0.0 00:00 05:00 evaluating lubricator issue. Monitor IA and tubing pressures every half hour. slowly dropped to 0/0 psi. SIMOPS- Complete rig work orders, change out worn valves in pit complex. 12/4/2019 12/4/2019 1.00 DEMOB MOVE WAIT T Continue waiting for FMC rep. Fully 0.0 0.0 05:00 06:00 opened master valve, pulled lubricator and inspected BPV, re-installed lubricator. SIMOPS- Lower cattle chute, R/U bridle lines on top drive. 12/4/2019 12/4/2019 0.50 DEMOB MOVE WAIT T Continue waiting for FMC rep. 0.0 0.0 06:00 06:30 Continue R/U bridle lines on top drive and set in sheaves. Continue changing out valves in pit module. work on welding projects in pit module. 12/4/2019 12/4/2019 2.00 DEMOB MOVE WAIT T Continue waiting for FMC rep. 0.0 0.0 06:30 08:30 SIMOPS- Blow down water and steam in pits 12/4/2019 12/4/2019 1.00 DEMOB MOVE MPSP P Pull lubricator and BPV, inspect and re 0.0 0.0 08:30 09:30 -install. FMC set Type H BPV with lubricator. 12/4/2019 12/4/2019 0.50 DEMOB MOVE RURD P Secure well, install gauges, wipe 0.0 0.0 09:30 10:00 down. Install valve handles. Clean cellar box. 12/4/2019 12/4/2019 1.25 DEMOB MOVE RURD P Scope derrick down and pin to derrick. 0.0 0.0 10:00 11:15 Secure energy track. 12/4/2019 12/4/2019 0.75 DEMOB MOVE RURD P Un-Spool line off drum, secure derrick 0.0 0.0 11:15 12:00 to lay over. SIMOPS- Unplugging complexes, begin pulling Ball Mill away Rig Release @ 12:00 hrs 12/4/19 Page 51/51 Report Printed: 12/9/2019 NADConversion Western North Slope CD5 Alpine West Pad CD5-26 CD5-26 ConocoPhillips Definitive Survey Report 06 December, 2019 ConocoPhilli s p ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well CD5-26 Project: Western North Slope TVD Reference: CD5-26 Actual @ 73.0usft (D25) Site: CD5 Alpine West Pad MD Reference: CD5-26 Actual @ 73.0usft (D25) Well: CD5-26 North Reference: True Wellbore: CD5-26 Survey Calculation Method: Minimum Curvature Design: CD5-26 Database: EDT 14 Alaska Production Iroject Western North Slope, North Slope Alaska, United States flap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Aap Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-26 Well Position +N/ -S Version: 1 0 +E/ -W Position Uncertainty Depth From (TVD) Wellbore CD5-26 Magnetics Model Name 0.0 usft Northing: 0.0 usft Easting: 0.0 usft Wellhead Elevation: Sample Date BGGM2018 10/1/2019 Design CD5-26 Date Audit Notes: To Version: 1 0 Phase: Vertical Section: Depth From (TVD) 2,089.7 (usft) 2,223.0 39.3 Survey Program Date From To (usft) (usft) Survey (Wellbore) 74.0 2,054.8 CD5-26 Srvy 1 - SLB_NSG+Battery+SAG 2,089.7 2,173.9 CD5-26 Srvy 2 - SLB_MWD+GMAG (CD 2,223.0 2,223.0 CD5-26 Srvy 3 - SLB_MWD-Inc_Only_Fi 2,316.8 15,219.4 CD5-25 Srvy 4 - SLB_MWD+GMAG (CD 15,281.5 15,281.5 CD5-26 Srvy 5 - SLB_MWD-Inc_Only_Fi 15,367.3 26,411.9 CD5-25 Srvy 6 - SLB_MWD+GMAG (CD 26,472.1 33,704.7 CD5-25 Spry 7 - SLB_MWD+GMAG (CD Survey 5,965,780.64 usft Latitude: 349,057.94 usft Longitude: 0.0 usft Ground Level: Declination Dip Angle (1 (1) 15.93 80.72 ACTUAL +N/ -S (usft) 0.0 Tie On Depth: +E/ -W (usft) 0.0 39.3 Direction (°) 162.79 70° 18'48.943 N 151 ° 13'24.027 W 33.7 usft Field Strength (nT) 57,364.93728501 Tool Name Description Survey Date GYD-GC-SS Gyrodata gyro single shots 10/12/2019 11:3: MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc110/12/2019 2:1 [ MWD -INC -ONLY (INC>10°) MWD-INC_ONLY_FILLER ( INC>10°) 10/15/2019 3:35 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc110/15/2019 3:44 MWD-INC_ONLY (INC>10°) MWD -INC _ONLY -FILLER ( INC>10°) 10/28/2019 3:35 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correcl10/28/2019 3:44 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc111/11/2019 3:44 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.3 0.00 0.00 39.3 -33.7 0.0 0.0 5,965,780.6 349,057.9 0.0 0.00 UNDEFINED 74.0 0.13 201.33 74.0 1.0 0.0 0.0 5,965,780.6 349,057.9 0.4 0.03 GYD-GC-SS (1) 168.1 0.08 358.40 168.1 95.1 -0.1 -0.1 5,965,780.6 349,057.9 0.2 0.05 GYD-GC-SS (1) 262.4 0.03 36.71 262.4 189.4 0.0 0.0 5,965,780.7 349,057.9 0.1 -0.03 GYD-GC-SS (1) 357.3 0.18 126.88 357.3 284.4 -0.1 0.1 5,965,780.6 349,058.0 0.2 0.08 GYD-GC-SS (1) 451.7 0.00 95.13 451.7 378.7 41 0.2 5,965,780.5 349,058.1 0.2 0.20 GYD-GC-SS (1) 546.2 0.32 9.03 546.2 473.2 0.1 0.3 5,965,780.7 349,058.2 0.3 -0.04 GYD-GC-SS(1) 640.7 0.24 46.97 640.7 567.7 0.5 0.4 5,965,781.1 349,058.4 0.2 -0.36 GYD-GC-SS(1) 734.5 0.34 107.95 734.4 661.5 0.6 0.8 5,965,781.2 349,058.8 0.3 -0.29 GYD-GC-SS (1) 12/6/2019 9:50:56AM Page 2 COMPASS 5000.14 Build 85H Company: NADConversion Project: Western North Slope Site: CD5 Alpine West Pad Well: CD5-26 Wellbore: CD5-26 Design: CD5-26 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well CD5-26 CD5-26 Actual @ 73.0usft (D25) CD5-26 Actual @ 73.0usft (D25) True Minimum Curvature EDT 14 Alaska Production 12/6/2019 9:50:56AM Page 3 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 828.5 2.13 175.79 828.5 755.5 -1.3 1.2 5,965,779.3 349,059.1 2.2 1.58 GYD-GC-SS (1) 923.1 4.17 176.22 923.0 850.0 -6.5 1.6 5,965,774.2 349,059.4 2.2 6.64 GYD-GC-SS(1) 1,017.3 4.92 169.96 1,016.9 943.9 -13.8 2.5 5,965,766.7 349,060.2 1.0 13.98 GYD-GC-SS (1) 1,111.8 5.96 168.70 1,111.0 1,038.0 -22.7 4.2 5,965,757.9 349,061.7 1.1 22.88 GYD-GC-SS (1) 1,205.9 7.64 163.55 1,204.4 1,131.4 -33.4 6.9 5,965,747.1 349,064.2 1.9 33.99 GYD-GC-SS (1) 1,300.7 9.57 161.42 1,298.1 1,225.1 -47.0 11.2 5,965,733.5 349,068.2 2.1 48.17 GYD-GC-SS(1) 1,394.9 11.05 160.80 1,390.7 1,317.8 -62.9 16.7 5,965,717.4 349,073.3 1.6 65.02 GYD-GC-SS (1) 1,489.4 13.41 158.51 1,483.1 1,410.1 -81.6 23.7 5,965,698.5 349,080.0 2.6 84.99 GYD-GC-SS (1) 1,583.2 I 15.61 159.30 1,573.9 1,500.9 -103.6 32.1 5,965,676.4 349,088.0 2.4 108.45 GYD-GC-SS (1) 1,677.6 17.52 161.39 1,664.4 1,591.4 -128.9 41.2 5,965,650.9 349,096.5 2.1 135.34 GYD-GC-SS (1) 1,771.8 19.16 162.19 1,753.8 1,680.8 -157.1 50.4 5,965,622.6 349,105.2 1.8 164.95 GYD-GC-SS(1) 1,864.3 20.94 163.32 1,840.7 1,767.7 -187.4 59.8 5,965,592.1 349,113.9 2.0 196.67 GYD-GC-SS(1) 1,958.3 23.43 165.40 1,927.7 1,854.7 -221.6 69.3 5,965,557.8 349,122.8 2.8 232.14 GYD-GC-SS (1) 2,054.8 25.71 168.36 2,015.5 1,942.5 -260.6 78.4 5,965,518.5 349,131.1 2.7 272.15 GYD-GC-SS (1) 2,089.7 26.88 168.90 2,046.7 1,973.7 -275.8 81.4 5,965,503.3 349,133.8 3.4 287.51 MWD+IFR2+SAG+MS (2) 2,173.9 28.32 169.51 2,121.4 2,048.4 -314.1 88.7 5,965,464.8 349,140.3 1.7 326.29 MWD+IFR2+SAG+MS (2) 2,223.0 29.20 169.51 2,164.4 2,091.4 -337.3 93.0 5,965,441.5 349,144.2 1.8 349.75 MWD -INC -ONLY (INC>10°) (3) 2,316.8 29.99 167.81 2,246.0 2,173.0 -382.7 102.1 5,965,395.9 349,152.4 1.2 395.83 MWD+IFR2+SAG+MS (4) 2,409.3 31.28 165.11 2,325.5 2,252.6 -428.5 113.2 5,965,349.9 349,162.5 2.0 442.85 MWD+IFR2+SAG+MS (4) 2,504.6 35.53 162.13 2,405.2 2,332.2 1178.9 128.1 5,965,299.3 349,176.3 4.8 495.33 MWD+IFR2+SAG+MS (4) 2,597.3 39.21 160.92 2,478.8 2,405.8 -532.2 145.9 5,965,245.7 349,193.1 4.1 551.53 MWD+IFR2+SAG+MS (4) 2,691.3 42.79 160.18 2,549.7 2,476.7 -590.3 166.5 5,965,187.1 349,212.5 3.8 613.14 MWD+IFR2+SAG+MS (4) 2,784.9 46.47 161.05 2,616.3 2,543.4 -652.4 188.3 5,965,124.6 349,233.0 4.0 678.88 MWD+IFR2+SAG+MS (4) 2,879.7 50.03 162.54 2,679.4 2,606.5 -719.5 210.3 5,965,057.1 349,253.7 3.9 749.55 MWD+IFR2+SAG+MS (4) 2,975.1 52.05 162.30 2,739.4 2,666.4 -790.2 232.7 5,964,986.0 349,274.7 2.1 823.68 MWD+IFR2+SAG+MS (4) 3,068.0 53.86 161.93 2,795.4 2,722.4 -860.8 255.5 5,964,914.9 349,296.1 2.0 897.88 MWD+IFR2+SAG+MS (4) 3,162.3 56.05 161.58 2,849.5 2,776.5 -934.1 279.7 5,964,841.2 349,318.8 2.3 975.02 MWD+IFR2+SAG+MS (4) 3,257.6 59.48 161.47 2,900.4 2,827.4 -1,010.6 305.2 5,964,764.2 349,342.8 3.6 1,055.65 MWD+IFR2+SAG+MS (4) 3,352.5 62.28 160.19 2,946.5 2,873.6 -1,088.9 332.5 5,964,685.4 349,368.4 3.2 1,138.52 MWD+IFR2+SAG+MS (4) 3,445.8 63.95 160.80 2,988.7 2,915.8 -1,167.3 360.2 5,964,606.4 349,394.6 1.9 1,221.66 MWD+IFR2+SAG+MS (4) 3,541.1 64.41 161.21 3,030.2 2,957.2 -1,248.4 388.2 5,964,524.8 349,420.9 0.6 1,307.37 MWD+IFR2+SAG+MS (4) 3,635.2 64.37 163.21 3,070.9 2,997.9 -1,329.2 414.1 5,964,443.5 349,445.2 1.9 1,392.22 MWD+IFR2+SAG+MS (4) 3,730.1 64.38 163.65 3,111.9 3,039.0 -1,411.2 438.5 5,964,361.0 349,467.9 0.4 1,477.76 MWD+IFR2+SAG+MS (4) 3,823.4 64.37 163.52 3,152.3 3,079.3 -1,491.9 462.2 5,964,279.9 349,490.1 0.1 1,561.85 MWD+IFR2+SAG+MS (4) 3,917.6 64.44 164.13 3,193.0 3,120.0 -1,573.5 485.9 5,964,197.8 349,512.1 0.6 1,646.86 MWD+IFR2+SAG+MS (4) 4,011.3 64.20 164.07 3,233.6 3,160.6 -1,654.7 509.1 5,964,116.2 349,533.6 0.3 1,731.22 MWD+IFR2+SAG+MS (4) 4,106.2 64.37 163.85 3,274.8 3,201.8 -1,736.9 532.7 5,964,033.5 349,555.6 0.3 1,816.71 MWD+IFR2+SAG+MS (4) 4,200.0 64.31 163.81 3,315.4 3,242.4 -1,818.1 556.2 5,963,951.9 349,577.5 0.1 1,901.27 MWD+IFR2+SAG+MS (4) 4,293.3 64.11 162.93 3,356.0 3,283.0 -1,898.6 580.3 5,963,870.9 349,599.9 0.9 1,985.26 MWD+IFR2+SAG+MS (4) 4,390.0 64.22 162.03 3,398.1 3,325.1 -1,981.5 606.5 5,963,787.4 349,624.4 0.8 2,072.27 MWD+IFR2+SAG+MS (4) 12/6/2019 9:50:56AM Page 3 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-26 Project: Western North Slope TVD Reference: CD5-26 Actual @ 73.0usft (D25) Site: CD5 Alpine West Pad MD Reference: CD5-26 Actual @ 73.0usft (D25) Well: CD5-26 North Reference: True Wellbore: CD5-26 Survey Calculation Method: Minimum Curvature Design: CD5-26 Database: EDT 14 Alaska Production Survey 12/6/2019 9:50:56AM Page 4 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,484.3 64.25 161.25 3,439.1 3,366.1 -2,062.2 633.2 5,963,706.3 349,649.5 0.7 2,157.18 MWD+IFR2+SAG+MS (4) 4,578.3 64.08 159.68 3,480.1 3,407.1 -2,141.9 661.5 5,963,626.0 349,676.2 1.5 2,241.76 MWD+IFR2+SAG+MS (4) 4,671.5 64.25 159.15 3,520.7 3,447.7 -2,220.5 691.0 5,963,546.9 349,704.1 0.5 2,325.50 MWD+IFR2+SAG+MS (4) 4,766.3 64.34 158.61 3,561.8 3,488.8 -2,300.1 721.8 5,963,466.7 349,733.3 0.5 2,410.66 MWD+IFR2+SAG+MS (4) 4,860.3 64.31 157.72 3,602.5 3,529.6 -2,378.8 753.3 5,963,387.4 349,763.2 0.9 2,495.13 MWD+IFR2+SAG+MS (4) 4,954.7 64.34 156.95 3,643.4 3,570.5 -2,457.3 786.1 5,963,308.3 349,794.4 0.7 2,579.82 MWD+IFR2+SAG+MS (4) 5,049.6 64.27 156.88 3,684.6 3,611.6 -2,536.0 819.6 5,963,228.9 349,826.3 0.1 2,664.92 MWD+IFR2+SAG+MS (4) 5,142.6 64.35 156.89 3,724.9 3,651.9 -2,613.0 852.5 5,963,151.2 349,857.7 0.1 2,748.26 MWD+IFR2+SAG+MS (4) 5,237.3 64.20 157.31 3,766.0 3,693.0 -2,691.6 885.7 5,963,072.0 349,889.3 0.4 2,833.14 MWD+IFR2+SAG+MS (4) 5,331.1 64.47 157.77 3,806.6 3,733.7 -2,769.7 918.0 5,962,993.2 349,920.0 0.5 2,917.34 MWD+IFR2+SAG+MS (4) 5,426.6 64.47 158.76 3,847.8 3,774.8 -2,849.8 949.9 5,962,912.5 349,950.3 0.9 3,003.27 MWD+IFR2+SAG+MS (4) 5,520.7 64.43 158.92 3,888.4 3,815.4 -2,929.0 980.6 5,962,832.7 349,979.4 0.2 3,087.99 MWD+IFR2+SAG+MS (4) 5,612.4 64.43 159.16 3,927.9 3,855.0 -3,006.2 1,010.1 5,962,755.0 350,007.4 0.2 3,170.48 MWD+IFR2+SAG+MS (4) 5,704.5 64.34 159.43 3,967.8 3,894.8 -3,083.9 1,039.5 5,962,676.7 350,035.2 0.3 3,253.44 MWD+IFR2+SAG+MS (4) 5,799.0 64.31 160.19 4,008.7 3,935.7 -3,163.8 1,068.9 5,962,596.2 350,062.9 0.7 3,338.43 MWD+IFR2+SAG+MS (4) 5,893.3 64.38 160.23 4,049.5 3,976.6 -3,243.8 1,097.7 5,962,515.7 350,090.1 0.1 3,423.36 MWD+IFR2+SAG+MS (4) 5,987.1 64.42 160.42 4,090.1 4,017.1 -3,323.5 1,126.2 5,962,435.4 350,117.0 0.2 3,507.92 MWD+IFR2+SAG+MS (4) 6,080.8 63.95 161.02 4,130.9 4,057.9 -3,403.1 1,154.0 5,962,355.3 350,143.2 0.8 3,592.15 MWD+IFR2+SAG+MS (4) 6,175.3 64.00 161.50 4,172.4 4,099.4 -3,483.5 1,181.3 5,962,274.3 350,168.9 0.5 3,677.08 MWD+IFR2+SAG+MS (4) 6,272.1 63.92 161.80 4,214.8 4,141.9 -3,566.1 1,208.7 5,962,191.3 350,194.6 0.3 3,764.02 MWD+IFR2+SAG+MS (4) 6,366.0 63.89 161.52 4,256.1 4,183.2 -3,646.1 1,235.2 5,962,110.7 350,219.5 0.3 3,848.32 MWD+IFR2+SAG+MS (4) 6,457.9 63.96 161.57 4,296.6 4,223.6 -3,724.4 1,261.4 5,962,031.9 350,244.1 0.1 3,930.89 MWD+IFR2+SAG+MS (4) 6,552.3 63.95 160.99 4,338.0 4,265.0 -3,804.7 1,288.6 5,961,951.1 350,269.7 0.6 4,015.60 MWD+IFR2+SAG+MS (4) 6,646.6 63.99 161.42 4,379.4 4,306.4 -3,885.0 1,315.9 5,961,870.3 350,295.4 0.4 4,100.36 MWD+IFR2+SAG+MS (4) 6,741.1 63.89 160.74 4,420.9 4,347.9 -3,965.2 1,343.4 5,961,789.5 350,321.2 0.7 4,185.16 MWD+IFR2+SAG+MS (4) 6,835.7 63.90 161.84 4,462.5 4,389.5 -4,045.7 1,370.6 5,961,708.5 350,346.9 1.0 4,270.12 MWD+IFR2+SAG+MS (4) 6,929.1 63.80 161.24 4,503.7 4,430.7 -4,125.2 1,397.2 5,961,628.4 350,371.8 0.6 4,353.95 MWD+IFR2+SAG+MS (4) 7,023.4 63.86 160.33 4,545.3 4,472.3 -4,205.1 1,425.0 5,961,548.0 350,398.1 0.9 4,438.49 MWD+IFR2+SAG+MS (4) 7,117.2 63.90 160.29 4,586.6 4,513.6 -4,284.4 1,453.4 5,961,468.2 350,424.8 0.1 4,522.64 MWD+IFR2+SAG+MS (4) 7,211.4 63.86 160.02 4,628.0 4,555.1 -4,364.0 1,482.1 5,961,388.0 350,452.0 0.3 4,607.18 MWD+IFR2+SAG+MS (4) 7,307.5 63.96 159.85 4,670.3 4,597.3 -4,445.1 1,511.7 5,961,306.4 350,479.9 0.2 4,693.35 MWD+IFR2+SAG+MS (4) 7,401.3 63.99 160.94 4,711.5 4,638.5 -4,524.5 1,540.0 5,961,226.4 350,506.6 1.0 4,777.59 MWD+IFR2+SAG+MS (4) 7,494.1 64.10 160.94 4,752.1 4,679.1 -4,603.3 1,567.3 5,961,147.1 350,532.2 0.1 4,860.96 MWD+IFR2+SAG+MS (4) 7,590.3 64.05 161.33 4,794.1 4,721.2 -4,685.2 1,595.3 5,961,064.6 350,558.6 0.4 4,947.48 MWD+IFR2+SAG+MS (4) 7,684.2 63.99 161.40 4,835.3 4,762.3 -4,765.2 1,622.2 5,960,984.1 350,583.9 0.1 5,031.84 MWD+IFR2+SAG+MS (4) 7,777.6 64.07 160.74 4,876.2 4,803.2 -4,844.7 1,649.5 5,960,904.2 350,609.6 0.6 5,115.79 MWD+IFR2+SAG+MS (4) 7,871.1 64.06 159.92 4,917.0 4,844.1 -4,923.8 1,677.8 5,960,824.5 350,636.3 0.8 5,199.73 MWD+IFR2+SAG+MS (4) 7,965.2 64.09 158.64 4,958.2 4,885.2 -5,002.9 1,707.7 5,960,744.8 350,664.6 1.2 5,284.20 MWD+IFR2+SAG+MS (4) 8,059.8 63.96 157.81 4,999.6 4,926.7 -5,081.9 1,739.3 5,960,665.1 350,694.6 0.8 5,369.01 MWD+IFR2+SAG+MS (4) 8,154.1 63.90 158.03 5,041.1 4,968.1 -5,160.4 1,771.1 5,960,586.0 350,724.8 0.2 5,453.44 MWD+IFR2+SAG+MS (4) 12/6/2019 9:50:56AM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-26 Project: Western North Slope TVD Reference: CD5-26 Actual @ 73.Ousft (D25) Site: CD5 Alpine West Pad MD Reference: CD5-26 Actual @ 73.Ousft (D25) Well: CD5-26 North Reference: True Wellbore: CD5-26 Survey Calculation Method: Minimum Curvature Design: CD5-26 Database: EDT 14 Alaska Production [Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°tloo') (ft) Survey Tool Name 8,245.6 64.19 157.81 5,081.1 5,008.1 -5,236.6 1,802.0 5,960,509.2 350,754.2 0.4 5,535.37 MWD+IFR2+SAG+MS (4) 8,340.2 64.09 158.30 5,122.4 5,049.4 -5,315.6 1,833.8 5,960,429.6 350,784.4 0.5 5,620.20 MWD+IFR2+SAG+MS (4) 8,434.2 63.93 159.32 5,163.6 5,090.6 -5,394.4 1,864.4 5,960,350.3 350,813.4 1.0 5,704.49 MWD+IFR2+SAG+MS (4) 8,528.5 64.00 159.18 5,205.0 5,132.0 -5,473.6 1,894.4 5,960,270.4 350,841.8 0.2 5,789.09 MWD+IFR2+SAG+MS (4) 8,622.8 64.16 159.15 5,246.2 5,173.2 -5,552.9 1,924.6 5,960,190.6 350,870.3 0.2 5,873.70 MWD+IFR2+SAG+MS (4) 8,717.7 63.96 159.86 5,287.7 5,214.7 -5,632.8 1,954.4 5,960,110.1 350,898.6 0.7 5,958.93 MWD+IFR2+SAG+MS (4) 8,811.7 64.13 159.90 5,328.9 5,255.9 -5,712.2 1,983.5 5,960,030.1 350,926.1 0.2 6,043.36 MWD+IFR2+SAG+MS (4) 8,905.7 64.02 160.40 5,369.9 5,297.0 -5,791.7 2,012.2 5,959,950.0 350,953.2 0.5 6,127.81 MWD+IFR2+SAG+MS (4) 9,000.4 64.03 160.45 5,411.4 5,338.4 -5,871.9 2,040.7 5,959,869.3 350,980.1 0.0 6,212.81 MWD+IFR2+SAG+MS (4) 9,094.3 64.05 161.30 5,452.5 5,379.5 -5,951.7 2,068.4 5,959,789.0 351,006.1 0.8 6,297.18 MWD+IFR2+SAG+MS (4) 9,188.1 64.09 161.30 5,493.5 5,420.5 -6,031.6 2,095.4 5,959,708.6 351,031.6 0.0 6,381.51 MWD+IFR2+SAG+MS (4) 9,282.3 64.00 161.87 5,534.7 5,461.8 -6,111.9 2,122.2 5,959,627.7 351,056.7 0.6 6,466.20 MWD+IFR2+SAG+MS (4) 9,376.8 64.19 162.64 5,576.0 5,503.1 -6,192.9 2,148.1 5,959,546.3 351,081.0 0.8 6,551.22 MWD+IFR2+SAG+MS(4) 9,470.9 64.09 163.48 5,617.1 5,544.1 -6,273.9 2,172.8 5,959,464.8 351,104.0 0.8 6,635.86 MWD+IFR2+SAG+MS (4) 9,565.2 64.25 163.61 5,658.2 5,585.2 -6,355.3 2,196.8 5,959,382.9 351,126.4 0.2 6,720.80 MWD+IFR2+SAG+MS(4) 9,659.6 64.12 163.82 5,699.3 5,626.3 -6,436.9 2,220.7 5,959,300.8 351,148.6 0.2 6,805.78 MWD+IFR2+SAG+MS (4) 9,754.0 63.96 164.05 5,740.6 5,667.6 -6,518.5 2,244.1 5,959,218.9 351,170.4 0.3 6,890.61 MWD+IFR2+SAG+MS (4) 9,849.1 64.00 162.86 5,782.3 5,709.4 -6,600.4 2,268.5 5,959,136.5 351,193.1 1.1 6,976.07 MWD+IFR2+SAG+MS (4) 9,943.1 64.06 162.11 5,823.5 5,750.5 -6,681.0 2,293.9 5,959,055.4 351,216.9 0.7 7,060.59 MWD+IFR2+SAG+MS (4) 10,037.7 64.02 161.67 5,864.9 5,791.9 -6,761.8 2,320.4 5,958,974.0 351,241.7 0.4 7,145.64 MWD+IFR2+SAG+MS (4) 10,131.7 64.19 160.90 5,905.9 5,833.0 -6,841.9 2,347.5 5,958,893.5 351,267.2 0.8 7,230.12 MWD+IFR2+SAG+MS(4) 10,226.6 64.02 160.51 5,947.4 5,874.4 -6,922.5 2,375.7 5,958,812.3 351,293.8 0.4 7,315.44 MWD+IFR2+SAG+MS (4) 10,321.2 64.13 161.11 5,988.7 5,915.8 -7,002.8 2,403.6 5,958,731.5 351,320.2 0.6 7,400.44 MWD+IFR2+SAG+MS (4) 10,415.1 63.98 161.27 6,029.8 5,956.8 -7,082.7 2,430.9 5,958,651.0 351,345.8 0.2 7,484.84 MWD+IFR2+SAG+MS (4) 10,509.9 64.14 160.69 6,071.3 5,998.3 -7,163.3 2,458.7 5,958,569.9 351,371.9 0.6 7,570.05 MWD+IFR2+SAG+MS (4) 10,603.3 63.67 160.73 6,112.4 6,039.4 -7,242.5 2,486.4 5,958,490.2 351,398.0 0.5 7,653.91 MWD+IFR2+SAG+MS (4) 10,697.2 63.65 159.82 6,154.1 6,081.1 -7,321.7 2,514.8 5,958,410.4 351,424.8 0.9 7,737.99 MWD+IFR2+SAG+MS (4) 10,791.2 63.58 159.54 6,195.8 6,122.9 -7,400.7 2,544.0 5,958,330.8 351,452.5 0.3 7,822.08 MWD+IFR2+SAG+MS (4) 10,884.5 63.59 158.96 6,237.3 6,164.4 -7,478.9 2,573.6 5,958,252.1 351,480.5 0.6 7,905.50 MWD+IFR2+SAG+MS (4) 10,979.1 63.59 158.89 6,279.4 6,206.4 -7,557.9 2,604.1 5,958,172.5 351,509.4 0.1 7,990.01 MWD+IFR2+SAG+MS (4) 11,073.2 63.35 158.94 6,321.5 6,248.5 -7,636.5 2,634.4 5,958,093.3 351,538.1 0.3 8,074.03 MWD+IFR2+SAG+MS (4) 11,167.1 63.52 159.02 6,363.4 6,290.5 -7,714.9 2,664.5 5,958,014.4 351,566.6 0.2 8,157.82 MWD+IFR2+SAG+MS (4) 11,263.9 63.45 158.87 6,406.6 6,333.7 -7,795.6 2,695.6 5,957,933.0 351,596.1 0.2 8,244.20 MWD+IFR2+SAG+MS (4) 11,357.2 63.97 157.93 6,448.0 6,375.0 -7,873.5 2,726.4 5,957,854.5 351,625.4 1.1 8,327.67 MWD+IFR2+SAG+MS (4) 11,451.4 64.13 158.86 6,489.2 6,416.2 -7,952.2 2,757.6 5,957,775.2 351,654.9 0.9 8,412.09 MWD+IFR2+SAG+MS (4) 11,545.3 63.97 160.07 6,530.3 6,457.3 -8,031.3 2,787.2 5,957,695.6 351,682.9 1.2 8,496.36 MWD+IFR2+SAG+MS (4) 11,640.164.04 160.63 6,571.8 6,498.8 -8,111.5 2,815.9 5,957,614.8 351,710.0 0.5 8,581.48 MWD+IFR2+SAG+MS (4) 11,732.1 64.00 160.57 6,612.2 6,539.2 -8,189.5 2,843.4 5,957,536.2 351,735.9 0.1 8,664.18 MWD+IFR2+SAG+MS(4) 11,825.3 63.99 160.58 6,653.0 6,580.0 -8,268.5 2,871.2 5,957,456.7 351,762.1 0.0 8,747.87 MWD+IFR2+SAG+MS (4) 11,920.4 64.03 160.96 6,694.7 6,621.7 -8,349.2 2,899.4 5,957,375.4 351,788.7 0.4 8,833.27 MWD+IFR2+SAG+MS (4) 12/612019 9:50:56AM Page 5 COMPASS 5000.14 Build 85H Company: Project: Site: Well: Wellbore: Design: Survey NADConversion Western North Slope CD5 Alpine West Pad CD5-26 CD5-26 CD5-26 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well CD5-26 CD5-26 Actual @ 73.0usft (D25) CD5-26 Actual @ 73.0usft (D25) True Minimum Curvature EDT 14 Alaska Production 12/6/2019 9:50:56AM Page 6 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 12,014.8 64.13 160.53 6,735.9 6,663.0 -8,429.4 2,927.4 5,957,294.7 351,815.0 0.4 8,918.12 MWD+IFR2+SAG+MS (4) 12,110.8 64.02 160.45 6,777.9 6,704.9 -8,510.8 2,956.2 5,957,212.8 351,842.2 0.1 9,004.40 MWD+IFR2+SAG+MS (4) 12,206.5 63.96 160.59 6,819.9 6,746.9 -8,591.9 2,984.9 5,957,131.2 351,869.3 0.1 9,090.34 MWD+IFR2+SAG+MS (4) 12,299.7 63.97 160.47 6,860.8 6,787.8 -8,670.8 3,012.8 5,957,051.7 351,895.6 0.1 9,173.97 MWD+IFR2+SAG+MS(4) 12,394.1 63.87 160.39 6,902.3 6,829.3 -8,750.7 3,041.2 5,956,971.2 351,922.4 0.1 9,258.73 MWD+IFR2+SAG+MS (4) 12,489.4 63.94 160.04 6,944.2 6,871.2 -8,831.3 3,070.2 5,956,890.1 351,949.7 0.3 9,344.26 MWD+IFR2+SAG+MS (4) 12,583.1 63.78 159.84 6,985.5 6,912.5 -8,910.3 3,099.0 5,956,810.5 351,977.0 0.3 9,428.28 MWD+IFR2+SAG+MS (4) 12,677.3 63.72 159.80 7,027.2 6,954.2 -8,989.6 3,128.2 5,956,730.7 352,004.5 0.1 9,512.64 MWD+IFR2+SAG+MS (4) 12,771.3 63.87 159.94 7,068.7 6,995.7 -9,068.7 3,157.2 5,956,651.0 352,031.9 0.2 9,596.83 MWD+IFR2+SAG+MS (4) 12,865.6 63.84 160.87 7,110.2 7,037.2 -9,148.5 3,185.6 5,956,570.7 352,058.7 0.9 9,681.41 MWD+IFR2+SAG+MS (4) 12,960.0 63.81 161.31 7,151.8 7,078.9 -9,228.6 3,213.0 5,956,490.0 352,084.6 0.4 9,766.07 MWD+IFR2+SAG+MS (4) 13,054.0 63.75 161.58 7,193.4 7,120.4 -9,308.6 3,239.9 5,956,409.5 352,109.8 0.3 9,850.45 MWD+IFR2+SAG+MS (4) 13,147.4 64.00 161.75 7,234.5 7,161.6 -9,388.2 3,266.3 5,956,329.4 352,134.6 0.3 9,934.29 MWD+IFR2+SAG+MS (4) 1 13,239.9 64.30 161.93 7,274.8 7,201.9 -9,467.2 3,292.2 5,956,249.8 352,158.9 0.4 10,017.46 MWD+IFR2+SAG+MS (4) 13,334.2 64.35 161.26 7,315.7 7,242.7 -9,547.9 3,319.0 5,956,168.6 352,184.1 0.6 10,102.46 MWD+IFR2+SAG+MS (4) 13,428.3 64.37 161.83 7,356.4 7,283.4 -9,628.4 3,345.9 5,956,087.7 352,209.3 0.5 10,187.25 MWD+IFR2+SAG+MS (4) 13,522.7 65.16 160.95 7,396.7 7,323.7 -9,709.3 3,373.1 5,956,006.2 352,235.0 1.2 10,272.62 MWD+IFR2+SAG+MS (4) 13,618.1 66.70 158.03 7,435.6 7,362.6 -9,790.9 3,403.7 5,955,924.0 352,263.8 3.2 10,359.61 MWD+IFR2+SAG+MS (4) 13,713.4 69.56 156.85 7,471.1 7,398.1 -9,872.5 3,437.6 5,955,841.7 352,296.1 3.2 10,447.62 MWD+IFR2+SAG+MS (4) 13,807.3 71.97 156.24 7,502.0 7,429.0 -9,953.8 3,472.9 5,955,759.8 352,329.8 2.6 10,535.72 MWD+IFR2+SAG+MS (4) 13,902.0 74.30 156.17 7,529.5 7,456.5 -10,036.7 3,509.4 5,955,676.1 352,364.6 2.5 10,625.73 MWD+IFR2+SAG+MS (4) 13,995.8 76.69 156.41 7,553.0 7,480.0 -10,119.9 3,545.9 5,955,592.3 352,399.5 2.6 10,715.97 MWD+IFR2+SAG+MS (4) 14,088.7 78.89 155.97 7,572.6 7,499.6 -10,203.0 3,582.6 5,955,508.5 352,434.5 2.4 10,806.18 MWD+IFR2+SAG+MS (4) 14,183.0 80.90 155.60 7,589.2 7,516.2 -10,287.7 3,620.7 5,955,423.0 352,470.8 2.2 10,898.37 MWD+IFR2+SAG+MS (4) 14,276.8 82.27 155.12 7,602.9 7,529.9 -10,372.0 3,659.4 5,955,338.0 352,507.8 1.5 10,990.32 MWD+IFR2+SAG+MS (4) 14,370.6 83.92 154.95 7,614.2 7,541.2 -10,456.4 3,698.7 5,955,252.8 352,545.4 1.8 11,082.58 MWD+IFR2+SAG+MS (4) 14,464.3 83.36 153.98 7,624.5 7,551.6 -10,540.4 3,738.8 5,955,167.9 352,583.9 1.2 11,174.77 MWD+IFR2+SAG+MS (4) 14,558.3 83.43 154.52 7,635.4 7,562.4 -10,624.5 3,779.4 5,955,083.1 352,622.7 0.6 11,267.04 MWD+IFR2+SAG+MS (4) 14,653.4 83.46 153.91 7,646.2 7,573.2 -10,709.6 3,820.5 5,954,997.2 352,662.1 0.6 11,360.51 MWD+IFR2+SAG+MS (4) 14,747.5 83.42 153.96 7,657.0 7,584.0 -10,793.6 3,861.6 5,954,912.4 352,701.5 0.1 11,452.88 MWD+IFR2+SAG+MS (4) 14,841.7 83.61 153.08 7,667.6 7,594.6 -10,877.4 3,903.3 5,954,827.8 352,741.5 0.9 11,545.29 MWD+IFR2+SAG+MS (4) 14,936.8 83.45 152.45 7,678.3 7,605.3 -10,961.3 3,946.5 5,954,743.0 352,783.0 0.7 11,638.26 MWD+IFR2+SAG+MS (4) 15,030.9 83.58 151.87 7,689.0 7,616.0 -11,044.1 3,990.2 5,954,659.4 352,825.0 0.6 11,730.22 MWD+IFR2+SAG+MS (4) 15,125.7 83.48 151.35 7,699.6 7,626.6 -11,126.9 4,035.0 5,954,575.7 352,868.1 0.6 11,822.57 MWD+IFR2+SAG+MS (4) 15,219.4 83.51 151.77 7,710.2 7,637.3 -11,208.7 4,079.3 5,954,493.0 352,910.8 0.4 11,913.89 MWD+IFR2+SAG+MS (4) 15,281.5 83.96 151.00 7,717.0 7,644.0 -11,263.0 4,108.9 5,954,438.2 352,939.3 1.4 11,974.47 MWD-INC_ONLY(INC>10°)(5) 15,367.3 84.03 148.75 7,726.0 7,653.0 -11,336.8 4,151.7 5,954,363.6 352,980.6 2.6 12,057.60 MWD+IFR2+SAG+MS (6) 15,438.9 84.36 146.36 7,733.2 7,660.3 -11,396.9 4,189.9 5,954,302.7 353,017.6 3.4 12,126.37 MWD+IFR2+SAG+MS (6) 15,536.1 85.86 146.49 7,741.5 7,668.5 -11,477.5 4,243.5 5,954,221.0 353,069.5 1.5 12,219.24 MWD+IFR2+SAG+MS (6) 15,633.2 86.78 147.37 7,747.8 7,674.8 -11,558.7 4,296.3 5,954,138.7 353,120.7 1.3 12,312.43 MWD+IFR2+SAG+MS (6) 12/6/2019 9:50:56AM Page 6 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-26 Project: Western North Slope TVD Reference: CD5-26 Actual @ 73.0usft (D25) Site: CD5 Alpine West Pad MD Reference: CD5-26 Actual @ 73.0usft (D25) Well: CD5-26 North Reference: True Wellbore: CD5-26 Survey Calculation Method: Minimum Curvature Design: CD5-26 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,723.5 88.03 147.36 7,751.8 7,678.9 -11,634.7 4,345.0 5,954,061.8 353,167.8 1.4 12,399.40 MWD+IFR2+SAG+MS (6) 15,818.1 88.84 146.25 7,754.4 7,681.5 -11,713.8 4,396.8 5,953,981.7 353,218.0 1.5 12,490.32 MWD+IFR2+SAG+MS (6) 15,914.1 89.70 146.68 7,755.7 7,682.7 -11,793.9 4,449.8 5,953,900.6 353,269.4 1.0 12,582.49 MWD+IFR2+SAG+MS (6) 16,009.2 90.37 146.01 7,755.6 7,682.6 -11,873.9 4,501.1 5,953,819.5 353,319.1 1.6 12,674.11 MWD+IFR2+SAG+MS (6) 16,104.1 89.85 149.53 7,755.4 7,682.4 -11,955.1 4,550.3 5,953,737.4 353,366.7 1.7 12,766.23 MWD+IFR2+SAG+MS (6) 16,199.3 88.87 150.75 7,756.5 7,683.5 -12,037.7 4,597.7 5,953,653.9 353,412.4 1.6 12,859.10 MWD+IFR2+SAG+MS (6) 16,294.2 89.22 152.93 7,758.1 7,685.1 -12,121.3 4,642.5 5,953,569.4 353,455.5 2.3 12,952.24 MWD+IFR2+SAG+MS (6) 16,384.3 89.60 153.89 7,759.0 7,686.0 -12,201.8 4,682.8 5,953,488.0 353,494.2 1.1 13,041.12 MWD+IFR2+SAG+MS (6) 16,483.7 89.78 154.91 7,759.5 7,686.5 -12,291.5 4,725.7 5,953,397.6 353,535.3 1.0 13,139.43 MWD+IFR2+SAG+MS (6) 16,578.9 89.70 155.78 7,760.0 7,687.0 -12,378.0 4,765.5 5,953,310.2 353,573.3 0.9 13,233.88 MWD+IFR2+SAG+MS (6) 16,674.7 89.74 157.42 7,760.4 7,687.4 -12,465.9 4,803.5 5,953,221.7 353,609.5 1.7 13,329.04 MWD+IFR2+SAG+MS (6) 16,765.1 89.57 155.61 7,761.0 7,688.0 -12,548.8 4,839.5 5,953,138.0- 353,643.9 2.0 13,418.90 MWD+IFR2+SAG+MS (6) 16,864.9 89.36 155.46 7,761.9 7,688.9 -12,639.6 4,880.9 5,953,046.4 353,683.4 0.3 13,517.92 MWD+IFR2+SAG+MS (6) 16,959.4 89.05 154.74 7,763.2 7,690.2 -12,725.4 4,920.7 5,952,959.9 353,721.4 0.8 13,611.59 MWD+IFR2+SAG+MS (6) 17,055.4 89.16 155.33 7,764.7 7,691.7 -12,812.3 4,961.1 5,952,872.1 353,760.2 0.6 13,706.65 MWD+IFR2+SAG+MS (6) 17,149.5 89.08 154.62 7,766.2 7,693.2 -12,897.6 5,000.9 5,952,786.1 353,798.2 0.8 13,799.85 MWD+IFR2+SAG+MS (6) 17,243.9 89.22 156.22 7,767.6 7,694.6 -12,983.5 5,040.2 5,952,699.4 353,835.8 1.7 13,893.52 MWD+IFR2+SAG+MS (6) 17,339.3 89.54 154.37 7,768.6 7,695.6 -13,070.1 5,080.1 5,952,612.0 353,873.9 2.0 13,988.09 MWD+IFR2+SAG+MS (6) 17,435.0 89.39 150.74 7,769.5 7,696.5 -13,155.1 5,124.2 5,952,526.2 353,916.3 3.8 14,082.26 MWD+IFR2+SAG+MS (6) 17,530.3 89.47 145.76 7,770.4 7,697.5 -13,236.0 5,174.3 5,952,444.3 353,964.7 5.2 14,174.43 MWD+IFR2+SAG+MS (6) 17,625.8 89.05 144.00 7,771.7 7,698.7 -13,314.1 5,229.2 5,952,365.1 354,018.1 1.9 14,265.28 MWD+IFR2+SAG+MS (6) 17,720.9 88.94 146.07 7,773.3 7,700.4 -13,392.1 5,283.7 5,952,286.0 354,071.0 2.2 14,355.89 MWD+IFR2+SAG+MS (6) 17,815.8 89.50 148.24 7,774.6 7,701.6 -13,471.8 5,335.2 5,952,205.3 354,120.9 2.4 14,447.24 MWD+IFR2+SAG+MS (6) 17,909.8 89.95 151.03 7,775.1 7,702.1 -13,552.9 5,382.7 5,952,123.3 354,166.7 3.0 14,538.79 MWD+IFR2+SAG+MS (6) 18,005.4 90.22 152.70 7,774.9 7,702.0 -13,637.2 5,427.8 5,952,038.1 354,210.1 1.8 14,632.62 MWD+IFR2+SAG+MS (6) 18,099.5 90.23 154.06 7,774.6 7,701.6 -13,721.3 5,469.9 5,951,953.2 354,250.6 1.4 14,725.46 MWD+IFR2+SAG+MS (6) 18,195.1 89.60 154.09 7,774.7 7,701.7 -13,807.2 5,511.7 5,951,866.4 354,290.6 0.7 14,819.93 MWD+IFR2+SAG+MS (6) 18,289.2 89.28 153.20 7,775.6 7,702.7 -13,891.6 5,553.5 5,951,781.3 354,330.7 1.0 14,912.84 MWD+IFR2+SAG+MS (6) 18,385.0 89.61 152.73 7,776.6 7,703.6 -13,976.9 5,597.0 5,951,695.1 354,372.5 0.6 15,007.23 MWD+IFR2+SAG+MS (6) 18,478.2 89.35 152.15 7,777.4 7,704.4 -14,059.5 5,640.2 5,951,611.6 354,413.9 0.7 15,098.89 MWD+IFR2+SAG+MS (6) 18,572.9 89.71 152.64 7,778.2 7,705.2 -14,143.4 5,684.1 5,951,526.8 354,456.1 0.6 15,192.06 MWD+IFR2+SAG+MS (6) 18,667.0 89.67 152.41 7,778.7 7,705.7 -14,226.9 5,727.5 5,951,442.5 354,497.8 0.2 15,284.64 MWD+IFR2+SAG+MS (6) 18,760.9 89.32 152.99 7,779.5 7,706.5 -14,310.4 5,770.5 5,951,358.2 354,539.2 0.7 15,377.09 MWD+IFR2+SAG+MS (6) 18,855.0 89.47 154.38 7,780.5 7,707.5 -14,394.8 5,812.3 5,951,273.0 354,579.3 1.5 I 15,470.08 MWD+IFR2+SAG+MS (6) 18,950.3 89.33 155.18 7,781.5 7,708.5 -14,480.9 5,852.9 5,951,186.1 354,618.1 0.9 15,564.39 MWD+IFR2+SAG+MS (6) 19,044.4 89.22 155.01 7,782.7 7,709.7 -14,566.3 5,892.5 5,951,099.9 354,656.0 0.2 15,657.65 MWD+IFR2+SAG+MS (6) 19,138.9 89.33 154.55 7,783.9 7,710.9 -14,651.8 5,932.7 5,951,013.7 354,694.5 0.5 15,751.22 MWD+IFR2+SAG+MS (6) 19,233.4 89.32 154.83 7,785.0 7,712.0 -14,737.1 5,973.1 5,950,927.5 354,733.2 0.3 15,844.72 MWD+IFR2+SAG+MS (6) 19,326.7 89.54 154.31 7,785.9 7,713.0 -14,821.5 6,013.2 5,950,842.4 354,771.6 0.6 15,937.13 MWD+IFR2+SAG+MS (6) 19,422.3 89.36 153.63 7,786.9 7,713.9 -14,907.4 6,055.2 5,950,755.7 354,811.8 0.7 16,031.60 MWD+IFR2+SAG+MS (6) 12/6/2019 9:50:56AM Page 7 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-26 Project: Western North Slope TVD Reference: CD5-26 Actual @ 73.0usft (D25) Site: CD5 Alpine West Pad MD Reference: CD5-26 Actual @ 73.0usft (D25) Well: CD5-26 North Reference: True Wellbore: CD5-26 Survey Calculation Method: Minimum Curvature Design: CD5-26 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 19,516.3 89.50 153.22 7,787.8 7,714.8 -14,991.4 6,097.2 5,950,670.8 354,852.1 0.5 16,124.34 MWD+IFR2+SAG+MS (6) 19,611.3 89.22 153.80 7,788.9 7,715.9 -15,076.4 6,139.6 5,950,585.0 354,892.8 0.7 16,218.06 MWD+IFR2+SAG+MS (6) 19,705.8 89.51 154.69 7,789.9 7,716.9 -15,161.5 6,180.6 5,950,499.0 354,932.1 1.0 16,311.52 MWD+IFR2+SAG+MS (6) 19,801.2 89.25 153.06 7,790.9 7,718.0 -15,247.2 6,222.7 5,950,412.6 354,972.4 1.7 16,405.78 MWD+IFR2+SAG+MS (6) 19,895.7 89.33 152.28 7,792.1 7,719.1 -15,331.1 6,266.0 5,950,327.8 355,014.0 0.8 16,498.75 MWD+IFR2+SAG+MS (6) 19,991.1 89.43 152.19 7,793.1 7,720.2 -15,415.6 6,310.5 5,950,242.5 355,056.8 0.1 16,592.58 MWD+IFR2+SAG+MS (6) 20,087.2 89.32 151.73 7,794.2 7,721.2 -15,500.3 6,355.6 5,950,156.8 355,100.2 0.5 16,686.93 MWD+IFR2+SAG+MS (6) 20,181.6 89.54 151.84 7,795.1 7,722.1 -15,583.5 6,400.2 5,950,072.8 355,143.2 0.3 16,779.57 MWD+IFR2+SAG+MS(6) 20,276.7 89.54 152.92 7,795.9 7,722.9 -15,667.7 6,444.3 5,949,987.7 355,185.5 1.1 16,873.08 MWD+IFR2+SAG+MS (6) i 20,371.0 89.26 153.40 7,796.9 7,723.9 -15,752.0 6,486.9 5,949,902.6 355,226.5 0.6 16,966.14 MWD+IFR2+SAG+MS (6) 20,466.4 89.15 154.52 7,798.2 7,725.2 -15,837.6 6,528.8 5,949,816.1 355,266.6 1.2 17,060.36 MWD+IFR2+SAG+MS (6) 20,561.2 89.29 153.93 7,799.5 7,726.5 -15,922.9 6,570.0 5,949,730.0 355,306.0 0.6 17,154.04 MWD+IFR2+SAG+MS (6) 20,656.3 89.68 152.66 7,800.3 7,727.4 -16,007.9 6,612.8 5,949,644.2 355,347.1 1.4 17,247.89 MWD+IFR2+SAG+MS (6) 20,751.4 89.19 151.24 7,801.3 7,728.3 -16,091.9 6,657.5 5,949,559.4 355,390.1 1.6 17,341.33 MWD+IFR2+SAG+MS (6) 20,846.8 89.12 151.46 7,802.7 7,729.7 -16,175.5 6,703.2 5,949,474.8 355,434.1 0.2 17,434.73 MWD+IFR2+SAG+MS (6) 20,941.6 89.15 152.95 7,804.1 7,731.1 -16,259.4 6,747.4 5,949,390.1 355,476.6 1.6 17,527.92 MWD+IFR2+SAG+MS (6) 21,037.3 89.30 154.00 7,805.4 7,732.4 -16,345.0 6,790.1 5,949,303.6 355,517.6 1.1 17,622.36 MWD+IFR2+SAG+MS (6) 21,131.3 89.15 154.61 7,806.7 7,733.7 -16,429.7 6,830.9 5,949,218.1 355,556.7 0.7 17,715.35 MWD+IFR2+SAG+MS (6) 21,226.4 89.08 154.43 7,808.2 7,735.2 -16,515.6 6,871.8 5,949,131.5 355,595.8 0.2 17,809.42 MWD+IFR2+SAG+MS (6) 21,321.7 89.19 153.89 7,809.6 7,736.6 -16,601.4 6,913.3 5,949,044.9 355,635.7 0.6 17,903.68 MWD+IFR2+SAG+MS (6) 21,416.5 89.26 151.28 7,810.9 7,737.9 -16,685.5 6,957.0 5,948,959.9 355,677.6 2.8 17,996.93 MWD+IFR2+SAG+MS (6) 21,511.7 89.29 150.80 7,812.1 7,739.1 -16,768.7 7,003.0 5,948,875.8 355,722.0 0.5 18,090.09 MWD+IFR2+SAG+MS (6) 21,606.2 89.37 151.10 7,813.2 7,740.2 -16,851.4 7,048.9 5,948,792.2 355,766.2 0.3 18,182.62 MWD+IFR2+SAG+MS (6) 21,701.4 89.01 151.29 7,814.5 7,741.5 -16,934.8 7,094.8 5,948,707.9 355,810.4 0.4 18,275.85 MWD+IFR2+SAG+MS (6) i 21,797.2 89.20 151.55 7,816.0 7,743.0 -17,018.9 7,140.6 5,948,622.9 355,854.5 0.3 18,369.78 MWD+IFR2+SAG+MS (6) 21,891.8 88.94 151.36 7,817.6 7,744.6 -17,102.0 7,185.8 5,948,538.9 355,898.0 0.3 18,462.52 MWD+IFR2+SAG+MS (6) 21,986.6 89.43 149.90 7,818.9 7,745.9 -17,184.6 7,232.3 5,948,455.4 355,942.8 1.6 18,555.23 MWD+IFR2+SAG+MS (6) 22,081.3 89.59 147.42 7,819.7 7,746.7 -17,265.5 7,281.6 5,948,373.5 355,990.5 2.6 18,647.05 MWD+IFR2+SAG+MS (6) 22,176.9 88.53 147.68 7,821.3 7,748.3 -17,346.2 7,332.9 5,948,291.9 356,040.1 1.1 18,739.29 MWD+IFR2+SAG+MS (6) 22,272.3 88.33 149.16 7,823.9 7,750.9 -17,427.4 7,382.8 5,948,209.7 356,088.4 1.6 18,831.61 MWD+IFR2+SAG+MS (6) 22,365.8 88.29 152.12 7,826.7 7,753.7 -17,508.8 7,428.6 5,948,127.3 356,132.6 3.2 18,922.99 MWD+IFR2+SAG+MS (6) 22,461.7 89.01 152.37 7,828.9 7,755.9 -17,593.7 7,473.3 5,948,041.6 356,175.5 0.8 19,017.24 MWD+IFR2+SAG+MS (6) 22,556.9 89.99 152.03 7,829.7 7,756.8 -17,677.8 7,517.6 5,947,956.6 356,218.2 1.1 19,110.79 MWD+IFR2+SAG+MS(6) 22,651.7 89.91 151.12 7,829.8 7,756.9 -17,761.2 7,562.8 5,947,872.3 356,261.6 1.0 19,203.75 MWD+IFR2+SAG+MS (6) 22,747.4 90.10 151.31 7,829.8 7,756.8 -17,845.2 7,608.9 5,947,787.5 356,306.0 0.3 19,297.60 MWD+IFR2+SAG+MS (6) 22,842.7 89.25 151.60 7,830.4 7,757.4 -17,928.9 7,654.4 5,947,702.9 356,349.8 0.9 19,391.03 MWD+IFR2+SAG+MS (6) 22,937.2 89.46 152.12 7,831.4 7,758.4 -18,012.1 7,699.0 5,947,618.7 356,392.7 0.6 19,483.74 MWD+IFR2+SAG+MS (6) 23,032.9 90.02 152.11 7,831.9 7,758.9 -18,096.7 7,743.7 5,947,533.2 356,435.8 0.6 19,577.84 MWD+IFR2+SAG+MS (6) 23,126.8 90.01 152.59 7,831.8 7,758.9 -18,179.9 7,787.3 5,947,449.2 356,477.7 0.5 19,670.19 MWD+IFR2+SAG+MS (6) 23,222.4 90.02 153.19 7,831.8 7,758.8 -18,265.0 7,830.9 5,947,363.3 356,519.5 0.6 19,764.33 MWD+IFR2+SAG+MS (6) 12/6/2019 9:50.56AM Page 8 COMPASS 5000.14 Build 85H Conocoftillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-26 Project: Western North Slope TVD Reference: CD5-26 Actual @ 73.0usft (D25) Site: CD5 Alpine West Pad MD Reference: CD5-26 Actual @ 73.Ousft (D25) Well: CD5-26 North Reference: True Wellbore: CD5-26 Survey Calculation Method: Minimum Curvature Design: CD5-26 Database: EDT 14 Alaska Production Survey 12/612019 9:50:56AM Page 9 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/4S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 23,317.2 89.56 153.55 7,832.2 7,759.2 -18,349.8 7,873.4 5,947,277.7 356,560.3 0.6 19,857.89 MWD+IFR2+SAG+MS (6) 23,411.0 89.64 154.38 7,832.8 7,759.8 -18,434.0 7,914.5 5,947,192.6 356,599.7 0.9 19,950.56 MWD+IFR2+SAG+MS (6) 23,506.1 89.60 153.80 7,833.4 7,760.5 -18,519.6 7,956.1 5,947,106.2 356,639.6 0.6 20,044.59 MWD+IFR2+SAG+MS (6) 23,600.8 89.78 152.64 7,834.0 7,761.0 -18,604.1 7,998.8 5,947,020.9 356,680.5 1.2 20,137.95 MWD+IFR2+SAG+MS (6) 23,695.5 89.67 152.24 7,834.4 7,761.4 -18,688.0 8,042.6 5,946,936.1 356,722.6 0.4 20,231.07 MWD+IFR2+SAG+MS (6) 23,789.4 89.28 152.64 7,835.3 7,762.3 -18,771.3 8,086.0 5,946,852.0 356,764.4 0.6 20,323.42 MWD+IFR2+SAG+MS (6) 23,883.7 89.58 152.23 7,836.2 7,763.2 -18,854.9 8,129.7 5,946,767.5 356,806.3 0.5 20,416.25 MWD+IFR2+SAG+MS (6) 23,979.0 89.22 152.30 7,837.2 7,764.2 -18,939.3 8,174.0 5,946,682.3 356,849.0 0.4 20,509.96 MWD+IFR2+SAG+MS (6) 24,074.4 89.40 152.27 7,838.4 7,765.4 -19,023.7 8,218.4 5,946,597.0 356,891.6 0.2 20,603.75 MWD+IFR2+SAG+MS (6) 24,168.0 89.46 152.13 7,839.3 7,766.3 -19,106.5 8,262.0 5,946,513.4 356,933.6 0.2 20,695.71 MWD+IFR2+SAG+MS (6) 24,262.1 89.64 151.06 7,840.0 7,767.0 -19,189.3 8,306.8 5,946,429.7 356,976.7 1.2 20,788.03 MWD+IFR2+SAG+MS (6) 24,357.7 89.67 151.28 7,840.6 7,767.6 -19,273.0 8,352.9 5,946,345.1 357,021.1 0.2 20,881.66 MWD+IFR2+SAG+MS (6) 24,452.7 89.36 150.85 7,841.4 7,768.4 -19,356.1 8,398.8 5,946,261.0 357,065.3 0.6 20,974.65 MWD+IFR2+SAG+MS (6) 24,547.5 89.19 150.92 7,842.6 7,769.6 -19,438.9 8,444.9 5,946,177.3 357,109.8 0.2 21,067.41 MWD+IFR2+SAG+MS (6) 24,642.4 89.33 151.14 7,843.8 7,770.9 -19,522.0 8,490.9 5,946,093.4 357,154.1 0.3 21,160.35 MWD+IFR2+SAG+MS (6) 24,737.5 89.33 150.50 7,844.9 7,772.0 -19,605.0 8,537.3 5,946,009.5 357,198.8 0.7 21,253.36 MWD+IFR2+SAG+MS (6) 24,832.5 89.32 150.25 7,846.1 7,773.1 -19,687.5 8,584.2 5,945,926.0 357,244.0 0.3 21,346.12 MWD+IFR2+SAG+MS (6) 24,927.8 89.78 150.49 7,646.8 7,773.8 -19,770.4 8,631.4 5,945,842.2 357,289.5 0.5 21,439.24 MWD+IFR2+SAG+MS (6) 25,022.6 89.74 148.39 7,847.2 7,774.2 -19,852.0 8,679.5 5,945,759.6 357,336.0 2.2 21,531.45 MWD+IFR2+SAG+MS (6) 25,118.4 89.61 147.19 7,847.8 7,774.8 -19,933.1 8,730.6 5,945,677.6 357,385.4 1.3 21,623.95 MWD+IFR2+SAG+MS (6) 25,211.5 89.26 147.67 7,848.7 7,775.7 -20,011.6 8,780.7 5,945,598.1 357,434.0 0.6 21,713.76 MWD+IFR2+SAG+MS (6) 25,308.1 89.14 149.89 7,850.0 7,777.0 -20,094.2 8,830.8 5,945,514.5 357,482.4 2.3 21,807.48 MWD+IFR2+SAG+MS (6) 25,397.5 89.84 153.45 7,850.8 7,777.8 -20,172.8 8,873.2 5,945,435.1 357,523.2 4.1 21,895.14 MWD+IFR2+SAG+MS (6) 25,492.8 90.14 156.21 7,850.8 7,777.9 -20,259.1 8,913.7 5,945,348.0 357,562.0 2.9 21,989.58 MWD+IFR2+SAG+MS (6) 25,590.1 90.79 154.86 7,850.0 7,777.1 -20,347.6 8,954.0 5,945,258.7 357,600.5 1.5 22,086.02 MWD+IFR2+SAG+MS (6) 25,687.3 89.91 152.84 7,849.4 7,776.5 -20,434.9 8,996.9 5,945,170.5 357,641.6 2.3 22,182.11 MWD+IFR2+SAG+MS (6) 25,783.2 89.01 150.27 7,850.4 7,777.4 -20,519.1 9,042.5 5,945,085.4 357,685.5 2.8 22,276.10 MWD+IFR2+SAG+MS (6) 25,875.3 88.88 148.76 7,852.0 7,779.1 -20,598.6 9,089.3 5,945,005.1 357,730.6 1.6 22,365.79 MWD+IFR2+SAG+MS (6) 25,969.3 88.74 148.19 7,854.0 7,781.0 -20,678.7 9,138.4 5,944,924.0 357,778.1 0.6 22,456.83 MWD+IFR2+SAG+MS (6) 26,066.6 89.22 149.68 7,855.7 7,782.8 -20,762.0 9,188.6 5,944,839.7 357,826.6 1.6 22,551.25 MWD+IFR2+SAG+MS (6) 26,164.0 89.65 150.72 7,856.7 7,783.7 -20,846.5 9,237.0 5,944,754.2 357,873.3 1.2 22,646.31 MWD+IFR2+SAG+MS (6) 26,257.4 89.11 150.28 7,857.7 7,784.7 -20,927.8 9,283.0 5,944,672.1 357,917.7 0.7 22,737.56 MWD+IFR2+SAG+MS (6) 26,354.2 89.36 151.29 7,859.0 7,786.0 -21,012.3 9,330.2 5,944,586.6 357,963.2 1.1 22,832.27 MWD+IFR2+SAG+MS (6) 26,411.9 89.40 151.67 7,859.6 7,786.6 -21,062.9 9,357.8 5,944,535.4 357,989.7 0.7 22,888.80 MWD+IFR2+SAG+MS (6) 26,472.1 89.77 152.56 7,860.1 7,787.1 -21,116.1 9,385.9 5,944,481.7 358,016.8 1.6 22,947.97 MWD+IFR2+SAG+MS (7) 26,564.7 89.27 154.87 7,860.8 7,787.9 -21,199.1 9,426.9 5,944,397.9 358,056.1 2.6 23,039.37 MWD+IFR2+SAG+MS (7) 26,660.2 89.52 152.97 7,861.8 7,788.9 -21,284.9 9,468.9 5,944,311.3 358,096.4 2.0 23,133.75 MWD+IFR2+SAG+MS (7) 26,756.3 89.52 152.14 7,862.6 7,789.7 -21,370.2 9,513.2 5,944,225.1 358,138.9 0.9 23,228.32 MWD+IFR2+SAG+MS (7) 26,852.6 89.45 152.32 7,863.5 7,790.5 -21,455.4 9,558.0 5,944,139.0 358,182.1 0.2 23,322.97 MWD+IFR2+SAG+MS (7) 26,946.9 89.42 152.85 7,864.4 7,791.5 -21,539.1 9,601.5 5,944,054.5 358,223.8 0.6 23,415.76 MWD+IFR2+SAG+MS (7) 12/612019 9:50:56AM Page 9 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well CD5-26 Project: Western North Slope TVD Reference: CD5-26 Actual @ 73.0usft (D25) Site: CD5 Alpine West Pad MD Reference: CD5-26 Actual @ 73.Ousft (D25) Well: CD5-26 North Reference: True Wellbore: CD5-26 Survey Calculation Method: Minimum Curvature Design: CD5-26 Database: EDT 14 Alaska Production Survey 128/2019 9.50:56AM Page 10 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°N00') (ft) Survey Tool Name 27,045.0 88.82 153.54 7,865.9 7,793.0 -21,626.7 9,645.7 5,943,966.0 358,266.3 0.9 23,512.55 MWD+IFR2+SAG+MS (7) 27,136.3 88.90 154.84 7,867.8 7,794.8 -21,708.8 9,685.4 5,943,883.1 358,304.3 1.4 23,602.75 MWD+IFR2+SAG+MS (7) 27,232.5 89.00 155.72 7,869.5 7,796.5 -21,796.2 9,725.7 5,943,794.9 358,342.8 0.9 23,698.16 MWD+IFR2+SAG+MS (7) 27,327.1 89.21 152.98 7,871.0 7,798.0 -21,881.5 9,766.6 5,943,708.9 358,382.0 2.9 23,791.69 MWD+IFR2+SAG+MS (7) 27,421.4 89.07 152.01 7,872.4 7,799.4 -21,965.1 9,810.1 5,943,624.4 358,423.8 1.0 23,884.42 MWD+IFR2+SAG+MS (7) 27,516.8 88.89 151.73 7,874.1 7,801.1 -22,049.2 9,855.1 5,943,539.4 358,467.1 0.3 23,978.08 MWD+IFR2+SAG+MS (7) 27,611.4 89.13 149.94 7,875.8 7,802.8 -22,131.8 9,901.2 5,943,456.0 358,511.5 1.9 24,070.60 MWD+IFR2+SAG+MS (7) 27,706.0 89.59 147.04 7,876.8 7,803.8 -22,212.4 9,950.6 5,943,374.3 358,559.3 3.1 24,162.27 MWD+IFR2+SAG+MS (7) 27,801.3 89.30 145.59 7,877.7 7,804.8 -22,291.8 10,003.5 5,943,294.0 358,610.6 1.6 24,253.71 MWD+IFR2+SAG+MS (7) 27,897.1 89.55 144.02 7,878.7 7,805.7 -22,370.0 10,058.7 5,943,214.6 358,664.2 1.7 24,344.82 MWD+IFR2+SAG+MS (7) 27,995.9 90.03 143.74 7,879.1 7,806.1 -22,449.8 10,117.0 5,943,133.6 358,720.8 0.6 24,438.27 MWD+IFR2+SAG+MS(7) 28,083.6 90.52 141.95 7,878.6 7,805.7 -22,519.7 10,169.9 5,943,062.7 358,772.4 2.1 24,520.74 MWD+IFR2+SAG+MS (7) 28,182.6 90.05 141.56 7,878.1 7,805.2 -22,597.5 10,231.2 5,942,983.8 358,832.1 0.6 24,613.08 MWD+IFR2+SAG+MS (7) 28,278.6 90.35 142.85 7,877.8 7,804.8 -22,673.3 10,290.0 5,942,906.7 358,889.4 1.4 24,702.99 MWD+IFR2+SAG+MS (7) 28,373.5 89.72 143.29 7,877.8 7,804.8 -22,749.2 10,347.0 5,942,829.8 358,944.8 0.8 24,792.30 MWD+IFR2+SAG+MS (7) 28,465.6 89.23 145.25 7,878.6 7,805.6 -22,824.0 10,400.8 5,942,753.9 358,997.1 2.2 24,879.64 MWD+IFR2+SAG+MS (7) 28,560.9 89.41 146.00 7,879.7 7,806.7 -22,902.6 10,454.7 5,942,674.2 359,049.3 0.8 24,970.72 MWD+IFR2+SAG+MS (7) 28,657.7 89.45 146.98 7,880.7 7,807.7 -22,983.3 10,508.1 5,942,592.5 359,101.1 1.0 25,063.59 MWD+IFR2+SAG+MS (7) 28,753.8 89.48 148.52 7,881.6 7,808.6 -23,064.5 10,559.3 5,942,510.2 359,150.7 1.6 25,156.37 MWD+IFR2+SAG+MS (7) 28,848.9 89.45 149.94 7,882.5 7,809.5 -23,146.3 10,608.0 5,942,427.5 359,197.7 1.5 25,248.83 MWD+IFR2+SAG+MS (7) 28,942.2 89.41 151.11 7,883.4 7,810.4 -23,227.5 10,653.9 5,942,345.4 359,242.0 1.3 25,340.02 MWD+IFR2+SAG+MS (7) 29,041.8 89.31 153.59 7,884.5 7,811.5 -23,315.7 10,700.1 5,942,256.3 359,286.4 2.5 25,437.97 MWD+IFR2+SAG+MS (7) 29,132.8 89.34 153.91 7,885.6 7,812.6 -23,397.3 10,740.4 5,942,173.9 359,325.0 0.4 25,527.84 MWD+IFR2+SAG+MS (7) 29,228.3 89.48 155.49 7,886.6 7,813.6 -23,483.7 10,781.2 5,942,086.7 359,364.1 1.7 25,622.38 MWD+IFR2+SAG+MS (7) 29,323.6 89.45 156.39 7,887.5 7,814.5 -23,570.7 10,820.0 5,941,999.0 359,401.2 0.9 25,716.96 MWD+IFR2+SAG+MS (7) 29,419.0 89.45 157.27 7,888.4 7,815.4 -23,658.3 10,857.5 5,941,910.6 359,436.9 0.9 25,811.81 MWD+IFR2+SAG+MS (7) 29,514.6 89.27 156.62 7,869.4 7,816.5 -23,746.3 10,895.0 5,941,821.8 359,472.6 0.7 25,906.97 MWD+IFR2+SAG+MS (7) 29,609.8 89.66 155.23 7,890.3 7,817.4 -23,833.3 10,933.8 5,941,734.2 359,509.7 1.5 26,001.47 MWD+IFR2+SAG+MS (7) 29,705.2 89.69 155.21 7,890.9 7,817.9 -23,919.8 10,973.8 5,941,646.8 359,547.9 0.0 26,096.02 MWD+IFR2+SAG+MS (7) 29,801.2 89.72 152.65 7,891.4 7,818.4 -24,006.1 11,016.0 5,941,559.8 359,588.3 2.7 26,190.85 MWD+IFR2+SAG+MS (7) 29,896.8 89.69 153.20 7,891.9 7,818.9 -24,091.2 11,059.5 5,941,473.8 359,630.1 0.6 26,285.04 MWD+IFR2+SAG+MS (7) 29,990.8 89.35 153.79 7,892.6 7,819.7 -24,175.4 11,101.5 5,941,388.8 359,670.4 0.7 26,377.87 MWD+IFR2+SAG+MS (7) 30,086.5 88.82 156.42 7,894.2 7,821.2 -24,262.1 11,141.7 5,941,301.3 359,708.9 2.8 26,472.61 MWD+IFR2+SAG+MS (7) 30,182.8 89.14 156.62 7,895.9 7,822.9 -24,350.4 11,180.1 5,941,212.2 359,745.5 0.4 26,568.32 MWD+IFR2+SAG+MS (7) 30,279.1 89.27 156.12 7,897.2 7,824.2 -24,438.6 11,218.7 5,941,123.2 359,782.3 0.5 26,664.06 MWD+IFR2+SAG+MS (7) 30,369.9 89.38 157.91 7,898.3 7,825.3 -24,522.2 11,254.1 5,941,039.0 359,816.0 2.0 26,754.38 MWD+IFR2+SAG+MS (7) 30,464.8 89.45 158.33 7,899.3 7,826.3 -24,610.3 11,289.5 5,940,950.2 359,849.6 0.4 26,848.93 MWD+IFR2+SAG+MS (7) 30,562.8 89.44 157.59 7,900.2 7,827.2 -24,701.1 11,326.3 5,940,858.6 359,884.6 0.8 26,946.64 MWD+IFR2+SAG+MS (7) 30,655.6 89.82 158.57 7,900.8 7,827.8 -24,787.2 11,360.9 5,940,771.9 359,917.5 1.1 27,039.08 MWD+IFR2+SAG+MS (7) 30,753.1 90.04 158.71 7,900.9 7,828.0 -24,878.0 11,396.4 5,940,680.5 359,951.1 0.3 27,136.28 MWD+IFR2+SAG+MS (7) 128/2019 9.50:56AM Page 10 COMPASS 5000.14 Build 85H ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-26 Project: Western North Slope TVD Reference: CD5-26 Actual @ 73.Ousft (D25) Site: CD5 Alpine West Pad MD Reference: CD5-26 Actual @ 73.Ousft (D25) Well: CD5-26 North Reference: True Wellbore: CD5-26 Survey Calculation Method: Minimum Curvature Design: CD5-26 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 30,847.7 89.30 159.27 7,901.5 7,828.5 -24,966.3 11,430.3 5,940,591.5 359,983.3 1.0 27,230.67 MWD+IFR2+SAG+MS (7) 30,947.6 89.28 159.34 7,902.7 7,829.7 -25,059.7 11,465.6 5,940,497.3 360,016.7 0.1 27,330.41 MWD+IFR2+SAG+MS (7) 31,038.3 89.20 158.15 7,903.9 7,830.9 -25,144.3 11,498.5 5,940,412.2 360,047.9 1.3 27,420.87 MWD+IFR2+SAG+MS (7) 31,133.5 89.59 156.88 7,904.9 7,831.9 -25,232.3 11,534.9 5,940,323.5 360,082.5 1.4 27,515.70 MWD+IFR2+SAG+MS (7) 31,229.0 89.72 152.27 7,905.5 7,832.5 -25,318.4 11,575.9 5,940,236.5 360,121.7 4.8 27,610.13 MWD+IFR2+SAG+MS (7) 31,325.0 89.69 153.55 7,906.0 7,833.0 -25,404.0 11,619.7 5,940,150.1 360,163.7 1.3 27,704.79 MWD+IFR2+SAG+MS (7) 31,420.7 89.31 151.60 7,906.8 7,833.9 -25,488.9 11,663.7 5,940,064.3 360,206.1 2.1 27,798.96 MWD+IFR2+SAG+MS (7) 31,515.9 88.89 154.11 7,908.3 7,835.3 -25,573.6 11,707.2 5,939,978.8 360,247.8 2.7 27,892.71 MWD+IFR2+SAG+MS (7) 31,614.3 88.80 149.28 7,910.3 7,837.3 -25,660.1 11,753.8 5,939,891.3 360,292.7 4.9 27,989.19 MWD+IFR2+SAG+MS (7) 31,708.6 88.45 147.21 7,912.6 7,839.6 -25,740.3 11,803.4 5,939,810.2 360,340.7 2.2 28,080.47 MWD+IFR2+SAG+MS (7) 31,803.9 88.54 146.17 7,915.1 7,842.1 -25,819.9 11,855.7 5,939,729.5 360,391.3 1.1 28171.96 MWD+IFR2+SAG+MS (7) 31,899.8 89.53 145.31 7,916.7 7,843.7 -25,899.2 11,909.7 5,939,649.2 360,443.7 1.4 28,263.69 MWD+IFR2+SAG+MS (7) 31,993.8 89.35 145.34 7,917.6 7,844.6 -25,976.5 11,963.1 5,939,570.9 360,495.6 0.2 28,353.30 MWD+IFR2+SAG+MS (7) 32,088.9 89.03 145.20 7,919.0 7,846.0 -26,054.6 12,017.3 5,939,491.6 360,548.2 0.4 28,444.01 MWD+IFR2+SAG+MS (7) 32,179.0 88.96 146.92 7,920.5 7,847.6 -26,129.4 12,067.6 5,939,415.9 360,597.0 1.9 28,530.28 MWD+IFR2+SAG+MS (7) 32,278.8 89.28 144.30 7,922.1 7,849.1 -26,211.7 12,124.0 5,939,332.5 360,651.7 2.6 28,625.56 MWD+IFR2+SAG+MS (7) 32,367.4 89.41 144.44 7,923.1 7,850.1 -26,283.7 12,175.6 5,939,259.5 360,701.8 0.2 28,709.61 MWD+IFR2+SAG+MS (7) 32,464.0 89.82 145.19 7,923.7 7,850.7 -26,362.6 12,231.3 5,939,179.4 360,755.9 0.9 28,801.53 MWD+IFR2+SAG+MS (7) 32,564.6 90.18 145.41 7,923.7 7,850.7 -26,445.4 12,288.5 5,939,095.6 360,811.5 0.4 28,897.49 MWD+IFR2+SAG+MS (7) 32,659.6 89.68 146.93 7,923.8 7,850.9 -26,524.3 12,341.4 5,939,015.6 360,862.8 1.7 28,988.50 MWD+IFR2+SAG+MS (7) 32,754.8 89.68 146.77 7,924.4 7,851.4 -26,603.9 12,393.4 5,938,934.9 360,913.2 0.2 29,080.01 MWD+IFR2+SAG+MS (7) 32,849.4 89.79 146.17 7,924.8 7,851.8 -26,682.9 12,445.7 5,938,855.0 360,963.9 0.6 29,170.87 MWD+IFR2+SAG+MS (7) 32,944.1 89.84 147.22 7,925.1 7,852.1 -26,762.0 12,497.7 5,938,774.8 361,014.3 1.1 29,261.83 MWD+IFR2+SAG+MS (7) 33,040.5 88.53 148.57 7,926.5 7,853.5 -26,843.6 12,549.0 5,938,692.2 361,063.8 2.0 29,355.01 MWD+IFR2+SAG+MS (7) 33,134.3 89.56 150.39 7,928.1 7,855.1 -26,924.4 12,596.6 5,938,610.4 361,109.8 2.2 29,446.29 MWD+IFR2+SAG+MS (7) 33,229.0 89.27 151.51 7,929.0 7,856.0 -27,007.2 12,642.5 5,938,526.8 361,154.1 1.2 29,538.90 MWD+IFR2+SAG+MS (7) 33,325.3 89.03 148.51 7,930.5 7,857.5 -27,090.6 12,690.7 5,938,442.5 361,200.6 3.1 29,632.81 MWD+IFR2+SAG+MS (7) 33,420.7 88.96 147.85 7,932.1 7,859.1 -27,171.6 12,741.0 5,938,360.4 361,249.2 0.7 29,725.15 MWD+IFR2+SAG+MS(7) 33,512.7 89.07 146.68 7,933.7 7,860.7 -27,249.0 12,790.7 5,938,282.1 361,297.4 1.3 29,813.71 MWD+IFR2+SAG+MS (7) 33,610.5 88.97 148.14 7,935.4 7,862.4 -27,331.4 12,843.4 5,938,198.6 361,348.4 1.5 29,908.07 MWD+IFR2+SAG+MS (7) 33,704.7 86.57 146.83 7,939.0 7,866.1 -27,410.8 12,894.0 5,938,118.2 361,397.4 2.9 29,998.87 MWD+IFR2+SAG+MS (7) 33,768.0 86.57 146.83 7,942.8 , 7,869.9 -27,463.6 12,928.5 5,936,064.7 361,430.9 0.0 30,059.57 PROJECTED to TD 121612019 9:50:56AM Page 11 COMPASS 5000.14 Build 85H PTD alp /0;'- Loepp, Victoria T (CED) From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod@contractor.conocophillips.com> Sent: Tuesday, December 31, 2019 11:16 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]Re: Extension of time for CD5-26 and CD5-261-1 Follow Up Flag: Follow up Flag Status: Flagged Thank you and have a safe and Happy New Year! Ift A From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, December 31, 201910:53 AM To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann. Haggerty -Sherrod @contractor.conocophillips.com> Subject: [EXTERNAL]Re: Extension of time for CD5-26 and CDS-26L1 Ann, Extension is granted for 1 week to Jan 10,2020. Happy New Year Ann! Victoria Sent from my iPhone On Dec 31, 2019, at 10:39 AM, Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty- Sherrod contractor.conocophillips.com> wrote: Good morning, I am writing to ask for an extension of time on the due date for CD5-26 and CD5-26L1 which is currently due on Friday, January 3, 2020. Many of the engineers involved in supplying data for the 10- 407 are out on vacation and not due to return until 1/6/20. 1 just returned from vacation on 2/30 but the person filling in for me did ask for the data we needed but I think people were already gone for vacation — taking that time off that could not be carried over to the new year. Any extension you can give us would be greatly appreciated. Thanks, Ann Schlumberger Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska, Inc. Dispatched To: Well Name: CD5-26 Date Dispatched Service Order #: 19AKA0087 2 19 107 3 162 4 Transmittal #: 10DEC19-SP01 AOGCC: Natural Resource Tech 10 -Dec -19 Dispatched By: Stephanie Pacillo Product I Description Hardcopy Di ital Copy Logging Date LWD Recorded Mode Prints: N/A Contents on CD 18 -Nov -19 Scope*Service 2" MD / TVD x 5" MD / TVD x RECEIVED D C 10 2019 oGCC Digital Data N/A Contents on CD DLIS / LAS Data x Surveys N/A Contents on CD Directional Survey Nad27 x Directional Survey Nad83 x CD 1 CD Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom. Osterkamp(a)conocophillips.com Alaska PTSPrintCenter()slb.com Attn: Tom Osterkamp Attn: Stephanie Pacillo Received By: 1 �(, � 22M Loepp, Victoria T (CED) From: Klem, Adam <Adam.Klem@conocophiIli ps.com> Sent: Monday, December 9, 2019 8:00 AM To: Loepp, Victoria T (CED) Cc: Wallace, Chris D (CED) Subject: Re: [EXTERNAL]Re: CD5-26 Pressure Test Follow Up Flag: Follow up Flag Status: Flagged Victoria, we had a good passing tubing PT over the weekend. Any update on the frac sundry? We are looking to be ready to pump tomorrow barring weather delays. From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, December 6, 2019 7:37:17 PM To: Klem, Adam <Adam.Klem @conocophillips.com> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: [EXTERNAL]Re: CDS-26 Pressure Test Please repeat tubing pressure test. Thanx, Victoria Sent from my iPhone On Dec 6, 2019, at 6:08 PM, Klem, Adam <Adam.Klem@conocophillips.com> wrote: Victoria, On CD5-26 we are prepping for our frac next week. We just had a good passing MITIA to 4200psi for 30 min as per my frac sundry. However 15 minutes into the MITT at 5500psi pressure dropped off pretty rapidly. No pressure increase was seen in the IA. When we pulled the plug, the 0 rings for the equalizing sub were ruined, leading us to determine the plug had failed. My question is that is the 15 minute pressure test for the tubing sufficient when combined with the 30 min MITIA or do we need to try and repeat the MITT? Due to inclination at the nipple profile, we have been having issues with slick line so we would probably need coil tubing to perform another MITT which would delay us several days. Thanks, Adam Klem Adam Klem THE STATE 01ALASKC1 GOVERNOR MIKE DUNLEAVY Completion Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-26 Permit to Drill Number: 219-107 Sundry Number: 319-544 Dear Mr. Klem: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, e M. rice Chair DATED this 1 day of December, 2019. RBDMSDEC 0 9 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECTNED DEC 2 - 2019 -&:5- j2/s C7� 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑� ` Repair Well ❑ ` ' s bper`�{o"ir s 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: ConocoPhillips Exploratory ❑ Development Stratigraphic ❑ Service ❑ 219-107 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20806-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CRU-CD5-26 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ASRC-NPR4,ASRC-AA092344;ASRC-NPR2, ASRC-NPR5 Colville River Unit, Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 33,768' 7,943' 33,768' 7,943' 6500 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 115' 115' Surface 2,143' 10-3/4" 2,240' 2,190' 5210 2470 Intermediate 15,185' 7-5/8" 15,282' 7,717' 6890 4790 Production Liner 19,142' 4-1/2" 33,735' 7,943' 7,780 6,350 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none n/a 4.5" & 3.5" L80 14,610' Packers and SSSV Type: Halliburton TNT, No SSSV Packers and SSSV MD (ft) and TVD (ft): 14,086'& 14,548' MD, 7,572'& 7,639' TVD 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 12/10/2019 15. Well Status after proposed work: Commencing Operations: OIL E] ` WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Adam Klem Contact Name: Adam Klem Authorized Title: Completion Engineer Contact Email: adam.kIernC@conocophillips.com Contact Phone: 907-263-4529 Authorized Signature: 1;` /�- Date: 1, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RB®IVIS _'*�/DEC 0 9 2019 Post Initial Injection MIT Req'd? Yes F-1No Yr Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: 4 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �r� /z/s/i q Form rm 10-403 Revise ki 1017 Approved applicatio i v" AvL date of approval. G� RIG4, Submit Form and Attachments in Duplicate CD5 - 26 Alpine A/C Dual Lateral Producer Final Schematic 20" 94# H-40 Welded Conductor to 115' MD 10-3/4" 45.5# L-80 HYD 563 x BTC Surface Casing at 2,240' MD 4-'/2" x 1 " GLM 4-1/2" 12.6# L-80 Hyd 563 4-'/2' x 1" GLM 7 5/8" 29.7# L-80 TXP Intermediate Casing at 15,281' MD 39# at heel TOC: 12,510' MD/ 6,953' TVD 4-'/2"x1"GLM Upper Completion: 1) 4'/z"-12.6# Hyd 563 tubing 2) Shallow nipple profile 3.813" X profile 3) 3x 4-'/2" x 1" Camco KBMG GLM w/ DV 4) SLB DHG 5) TNT Packer 6) High Pressure 2.813" X sliding sleeve -up to open 7) High Burst X Nipple profile, 2.813" 8) TNT Packer 9) XN Nipple profile, 2.813" Lower Completion: 10)ZXP liner top packer & Flexlock Liner Hanger XO 5" Hydril 521 Box X 4-'/2" H563 pin 11) 4.5" Hydril563 12.6# L-80 w/ Frac Ports C sand Lateral 6 1/2" Hole TD 14,369'- 17,932' MD -------------------------------------------------------------------- 4'/2" 12.6# L-80 Hyd563 Liner w/ frac ports 0 0 0 Fol I 0 0 0 0 0 o 0 0 o ------------------------------------------------------------------------------------------------------------- A sand Lateral 6 1/2" Hole TD ZXP liner top packer 15,282' — 33,768' MD at 14,593' MD 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). TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Jason C. Parker Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD5-26 Well ) under the Provisions ) of 20 AAC 25.280 ) STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) Jason C. Parker, being first duly sworn, upon oath, deposes and states as follows: My name is Jason C. Parker. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. 1 am a Senior Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAP') 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On December 2, 2019, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 2"d day of December, 2019. Jaso . P STATE OF ALASKA ) H THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 2,d day of December, 2019, by Jason C. Parker. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA n NOTARY PUBLIC REBECCA SWENSEN My Commission Expires Aug. 27, 202Q. ConocoPhillips Alaska December 2, 2019 VIA CERTIFIED MAIL To: Operator and Owners (shown on Exhibit 2) Jason C. Parker Senior Landman Land & Business Development ConocoPhillips Company 700 G Street Anchorage, AK 99501 Office: 907-265-6297 Fax: 907-263-4966 jason.c.parker@cop.com Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for CD5-26 Well AA -92347 (ASRC), AA -92344 (ASRC), ASRC-NPR2, ASRC-NPR3, ASRC-NPR4, and ASRC-NPR5 Colville River Unit, Alaska CPAI Contract No. 203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Colville River Unit working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the CD5-26 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about December 2, 2019. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well is currently planned to be drilled as a directional horizontal well on leases AA -92347 (ASRC), AA -92344 (ASRC), ASRC-NPR2, ASRC-NPR3, ASRC-NPR4, and ASRC-NPR5, as depicted on Exhibit 1, and has locations as follows: Location FNL FEL Township Rancle Section Meridian Surface 438' - 2919" T11 N R4E 18 Umiat Top Open Interval 1113' 4138' T11N R4E 29 Umiat Bottomhole 1580' 788' T1 ON R4E 9 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well ("Notification Area"), which includes the reservoir section. Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, � - Jason C. Parke Senior Landman Attachments: Exhibits 1 & 2 Exhibit 1 43 + n� Q • Frac Port ASRC.NPR3 cb �¢' 4 B�,uti S SSA, cash ASRC-NPR2 Well Trajectory 1 0 Open Interval m $ b Q Half Mile Frac Port Buffer C ASRC-NPR4 Q Half Nile Well Track Buffer 1AA092347 � ADL387208 Wells Wthin Track Buffer Well Pad i 0, Alpine PA Unit Boundary CPAI Lease CA v, o C, ADL380077 ASRC-AA1092344 i ADL387209 i ADL38890 AA_'r081817 I ASRC-NPR2 IIIN,1.i1 . IIINRat_ ADL3889D5 1)t1NR411 ASRC-NPR4 ADL38 AA092675j ADL390337 -AA094167_ u.-•---•-•-•- - O�a� - - -.._......_...-..- (inePA z i E ConocoPhillips i IC, ASRC-NPR5 Alaska i i J CDS-26 r Colville River Unit N Lease Plat -•-•--•-•-•-•.----------------- -----•-----•--- • 0 0.25 0.5 0.75 , 1 11/21/2019 Miles Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attn: Misty Alexa, NS Development Manager Owner (Non-OperatorY None Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage, Alaska 99503-5963 Attn: Teresa Imm, Executive VP, Regional and Resource Development Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuiqsut, AK 99789-0187 Attn: Joe Nukapigak, President Section 2 - Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles �� 1. y d ASRC-NPR3 q? C ! AA 092347 I� t c ASRC AA0+92344 \ADL387209 AA7081817 31, i Frac Port �oS ASRC-NPR2 L% Well Trajectory a Open Interval o i Half Mile Frac Port Buffer SRC-NPR4 Q Half We Well Track Buffer i ADL387208 Wells within Track Buffer (r: - Well Pad Cr TION. R3F Alpine PA ' Unit Boundary r�r CPAI Lease Q> T ON R4 E ASRC-NPR4 ADL380077 ADL38 {'pl' AA092675 j \ADL387209 AA7081817 31, i ASRC-NPR2 111�R3F T.11iolt-lE ADL388905 TION. R3F ' T ON R4 E ASRC-NPR4 ADL38 AA092675 j .._.._.._.._.._. ADL39033T tea' -AA094167--- ----------•- I ine PA _ f ✓ r ConocoPhillips 113 ASRC-NPRS Alaska / CD5-26 1 Colville River Unit N Lease Plat ---•----------- ----------------- 1 0 0.25 0.5 0.75 11/21/2019 Miles Table 1: Wells within .5 miles Well Name API Well Type Status CD5-25 501032076500 INJ ACTIVE CD5-25L1 501032076560 INJ ACTIVE CD5-313 501032071400 PROD ACTIVE CD5-98 501032080300 PROD ACTIVE 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 in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. 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: 10 & %" casing cement pump report on 10/13/2019 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg LiteCrete lead and 15.8ppg class G cement, displaced with mud. Full returns were seen throughout the job. The plug bumped at 1000 psi and the floats were checked and they held. The 7 & 5/8" casing cement report on 10/26/2019 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G tail. Full returns were seen throughout the job. The plug bumped at 900 psi, and the floats were checked and they held. Full returns were seen throughout the job. U� j �2— �� /ZD /mac Summary 17- , g All casing is cemented in accordance with 20 AAC 25.0 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 10/15/2019 the 10-3/4" casing was pressure tested to 3,500 psi for 30 mins. On 10/28/2019 the 7-5/8" casing was pressure tested to 3,500 psi for 30 mins. 4; 1 ?0 C-DPIJ / z1312,Mr The 3.5" & 4.5" tubing will be pressure tested to,4-,aQ psi prior to frac'ing. The 7-5/8" casing will be pressure tested to,4,2�psi prior to frac'ing. 4-I'1ops; C -Z) t -i 2-1312- 01 ti AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,480 Annulus pressure during frac 3,800 Annulus PRV setpoint during frac 3,900 7 5/8" Annulus pressure test 4,180 3.5" & 4 1/2" Tubing pressure Test 4,180 Nitrogen PRV 7,980 Highest pump trip 7,480 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/4" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 4.5" 12.6 L-80 8,430 psi 7,500 psi 3.5" 9.3 L-80 10,160 psi 10,535 psi Table 2: Wellbore pressure ratings Stimulation Surface Rig -Up 14 v� N y � � C E F Iv Y W L Norul dwnd Q Pop -ON Tank • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3g00 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV Pop -Off Tank Pump Truck } Bleed t Tattle Tale Tai. 14 v� N y � � C E F Iv Y W L Norul dwnd Q Pop -ON Tank • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3g00 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV Pop -Off Tank Pump Truck Alpine 1 OK Frac Tree t 4� , i i t - vt (0E 10 I Ai Ckr�-in " '[i: n: 9 Pit, UlK FRAC rREE ,art '• 1r 7 t M� 8 3w..£..L { 'n E/ ( f i gvFl ��• x i�.11-L C'6"' kl. to Bi 3 _aa Gu o.. ems..',%.. 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 Alpine A interval is approximately 30' TVD thick at the heel of the lateral and generally maintaining the same thickness to the toe. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to be at 15,626' MD/ -7,674' TVDSS. The estimated fracture gradient for the Alpine A sandstone is 12.5 ppg. The overlying confining zone consists of greater than 500' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 12,875' 'MD/ -7,042 TVDSS. The underlying confining zone consists of approximately 1800' TVD of Kingak shales. The estimated fracture gradient for the Kingak interval ranges from 15-18 ppg. Fracture gradient increases down section. The top of the Kingak shale interval ranges from - -7,760' TVDSS at the heel to - -7,895' TVDSS at the toe of the well (no MD as the Kingak interval was not penetrated in the CD5-26 wellbore). 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. Casina & Cement assessments for all wells that transect the confining zone: CD5-98: The 7 & 5/8" casing cement report on 6/23/2019 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 15.8ppg Class G tail. The plug bumped at 1600 psi, and the floats were checked and they held. Partial losses were observed during cement operations, however the cement was logged and TOC was determined to be at 12,850' MD. CD5-313: The 7-5/8" casing cement pump report on 7/25/2015. Full returns were not seen throughout the job. The cement job was pumped with 15.8 ppg Class G cement, displaced with 11.1 ppg LSND. The plug bumped at 1,140 psi and the floats held. CD5-25 and CD5-25L1: The 7-5/8" casing cement pump report on 7/25/2015. Full returns were not seen throughout the job. The cement job was pumped with 12.2ppg lead cement and 15.8 ppg Class G tail cement, displaced with 10.6 ppg WBM. The plug bumped at 1,000 psi and the floats held. N Ln 0 U ? y OG -0 N C m m N N m L o v - � 9 O m O o u u o u `d m m c a o f m a q o a w N tD u a � O N Zrl N rtl O O O F O F N o 0 w v O 0 cw 0 0 v `d a � v O d y u O 6 O H _ u C d N lV ' , ' � a " c d d p a 0 m c N O G 6 Q N V O 0 6 L O F Z n n C O N Q 0 Q N 0 N a— Fo- O d U ro n ro r ro n N 7 Q � Q > Q i Q M U 2 N C N N N 4 V 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 no faults or fracture systems transect the Alpine A formation or enter the confining zone within one half mile radius of the wellbore trajectory for CD5-26. z ( V Any faults that are within the half mile radius of the wellbore do not extend up through the ItS confining interval, and 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. Based on our knowledge of the principle stress direction in the Alpine A formation, along with the well path, all of the fractures will be longitudinal, running parallel to the wellbore. Because of this the fractures will only intersect faults that intersect the wellbore. As we did not see faults in the well bore, we do not expect any of our hydraulic fractures to intersect faults. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Well Depth Depth Vertical ace ment Displace Loss Name MD (ft) TVDSS (ft) (bbls/hr) C135-26 NA NA NA NA Davies, Stephen F (CED) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, December 4, 2019 4:01 PM To: Davies, Stephen F (CED); Smith, Matt Subject: RE: [EXTERNAL]CRU CDS-26 (PTD 219-107, Sundry 319-544) - Requests Steve, My apologies. We crossed it in the intermediate so we forgot about it. Yes, we did cross a fault in the intermediate section at 14,232' MD with —25' of throw. This fault does not extend up through the confining interval, and fracture gradients within the fault seal interval would not be exceeded during the fracture stimulation and would therefore confine injected fluids to the pool. This fault also intersects the CD5-25 @ 19,199' MD/ 7656' TVDSS and the CD5-251_1 at 19,086' MD/ 7537' TVDSS. Well Depth Depth Vertical Loss Name MD (ft) TVDSS (ft) Displacement (bbls/hr) (ft) CD5-26 14,232' -7,524' 25' 0 Adam From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Wednesday, December 4, 2019 2:38 PM To: Smith, Matt<Matt.Smith2@conocophillips.com> Cc: Klem, Adam <Adam.Klem@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD5-26 (PTD 219-107, Sundry 319-544) - Requests Matt, One more question: The fault analysis section (Section 11) states that there are no faults of fracture systems identified within %: mile of the wellbore. However, on the accompanying map (Plat 2), there is a thick, southeast -trending line shown at the top of governmental Section 29. Does that line represent a fault? If so, what is the vertical displacement of that fault? Does it intersect any of the wells within the AOR? At what depths? Does it cut through the upper confining layers? If so, how shallow is the top of the fault? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies_@alaska {,o_v_. From: Davies, Stephen F (CED) Sent: Wednesday, December 4, 2019 8:49 AM Plat 2: CD5-26 Fault Analysis v CIO ASRC-NPR3 , w ASRC-NPR2 CD5 jAA092347 � \ `ASRC-NPR4 1 vJ ASRC AA092344 t 1 L .t r i • Frac Port Well Trajectory Open Interval Half Nile Frac Port Buffer Q Half Nile Well Track Buffer ADL387208 Fault in Frac Port Buffer Wells within Frac Pori Buffer - Well Pad L — Alpine PA �— — Unit Boundary ® CPAI Lease ,i ADL380077 - IADL387209 ADL38890 \ASRC"lASRC-NPR2 '6 1811817— -r _ I 1 lADL388905 7'1ItiR31 TI l;�ML ri0`It3t' i \0-\,,tIZ4E ASRC-NPR4 ADL36 1 j AA092675 ADL390337 •-AAosals7- �:,.-.-•-----•_-- °_.._.._-.---_.._ I ine PA z z jN F C� ConocoPhillips 9 to ASRC-NPRS Alaska CD5-26 i Colville River Unit Fault Plat - ----•-------................ 00.25 0.5 0.75 1 11/21/2019 Miles SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD5-26 was completed in 2019 as a dual lateral horizontal producer in the Alpine A and C formations. The well was completed with 3.5" tubing. The well was completed with 4.5" tubing, with 3.5" tubing isolating the C lateral. In the A sand is a 4.5" liner with ball actuated sliding sleeves. We will establish injection and drop a ball which will shift a sleeve open to establish the first frac stage. We will then pump the 1st stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing 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. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 25 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 26,852 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU HES Frac Equipment. 6. PT Surface lines to 9,500 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Bring up pumps and increase annulus pressure from 2,500 psi to 3,800 psi as the tubing pressures up. 9. Pump the Frac job by following attached HES schedule @ 35bpm with a maximum expected treating pressure of 6,500 psi. 10. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 11. 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O L O E O L U ova, L m SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) Davies, Stephen F (CED) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, December 4, 2019 4:01 PM To: Davies, Stephen F (CED); Smith, Matt Subject: RE: [EXTERNAL]CRU CD5-26 (PTD 219-107, Sundry 319-544) - Requests Steve, My apologies. We crossed it in the intermediate so we forgot about it. Yes, we did cross a fault in the intermediate section at 14,232' MD with ^25' of throw. This fault does not extend up through the confining interval, and fracture gradients within the fault seal interval would not be exceeded during the fracture stimulation and would therefore confine injected fluids to the pool. This fault also intersects the CD5-25 @ 19,199' MD/ 7656' TVDSS and the CD5-251_1 at 19,086' MD/ 7537' TVDSS. Well Depth Depth Vertical Loss Name MD (ft) TVDSS (ft) Displacement (bbls/hr) CD5-26 14,232' -7,524' 25' 0 Adam From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Wednesday, December 4, 2019 2:38 PM To: Smith, Matt <Matt.Smith2@conocophillips.com> Cc: Klem, Adam <Adam.Klem @conocophillips.com> Subject: RE: [EXTERNAL]CRU CD5-26 (PTD 219-107, Sundry 319-544) - Requests Matt, One more question: The fault analysis section (Section 11) states that there are no faults of fracture systems identified within % mile of the wellbore. However, on the accompanying map (Plat 2), there is a thick, southeast -trending line shown at the top of governmental Section 29. Does that line represent a fault? If so, what is the vertical displacement of that fault? Does it intersect any of the wells within the AOR? At what depths? Does it cut through the upper confining layers? If so, how shallow is the top of the fault? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (CED) Sent: Wednesday, December 4, 2019 8:49 AM To: Smith, Matt <Matt.Smith2@conoa illips.com> Cc: Klem, Adam <Adam.Klem @conocophillips.com> Subject: RE: [EXTERNAL]CRU C135-26 (PTD 219-107, Sundry 319-544) - Requests Thank you Matt. I appreciate your help. Thanks again, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Smith, Matt <Matt.Smith2@conocophillips.com> Sent: Wednesday, December 4, 2019 6:58 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Klem, Adam <Adam.Klem @conocophillips.com> Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]CRU CD5-26 (PTD 219-107, Sundry 319-544) - Requests Steve, please see attached. Schlumberger is currently going through the QC process for the logs, and should be submitting copies of the logs to you directly as well, but this should suffice for now. If you need anything else, please let me know. Thanks, Matt Smith Drilling l,:nbineer — Alaska PVNS 700(1S1 Am im,v(ri Ai vsK-. A10-1704 OI ru l i 1.907.20',.41124 0 1 1 : 1 .432.200.0432 Nf� I I .smi 1112,a (-UP.( ().Ni From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Tuesday, December 03, 2019 4:29 PM To: Klem, Adam <Adam.Klem@conocophillips.com>; Smith, Matt<Matt.Smith2@conocophillips.com> Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]CRU CD5-26 (PTD 219-107, Sundry 319-544) - Requests Adam and Matt: In addition to the digital well log and survey data requested below, could you also please provide copies of the cement reports for the 10-3/4" and 7-5/8" casings that are dated 10/13/19 and 10/26/19, respectively? Thanks for your help, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE: This e-mail messa, cluding any attachments, contains information from the aka Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (CED) Sent: Tuesday, December 3, 2019 2:44 PM To: Klem, Adam <Adam.Klem@conocophillips.com>; Smith, Matt<Matt.Smith2@conocophillips.com> Subject: FW: [EXTERNAL]CRU CD5-26(PTD 219-107) Early termination of drilling Adam and Matt: Could you please provide digital well log data in .las format and directional survey data in Excel spreadsheet or ASCII table format for CD5-26? Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Smith, Matt<Matt.Smith2@conocophillips.com> Sent: Tuesday, December 3, 2019 11:13 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Klem, Adam <Adam.Klem@conocophillips.com> Subject: Re: [EXTERNAL]CRU CD5-26(PTD 219-107) Early termination of drilling Hi Victoria, As we were drilling, our sand thinned from —9' thick once we exited the window, down to ^'1' thick to no sand at our last MWD reading. This was unexpected based on our pre -drill interpretation of offset wells and seismic, and made it non- economic to continue drilling, due to no reservoir quality sand, so we decided to call TD at that depth. If you need further explanation please let me know. Thanks, Matt Smith 432-269-6432 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, December 3, 2019 11:03:15 AM To: Smith, Matt <Matt.Smith2@conocophillips.com>; Klem, Adam <Adam.Klem @conocophillips.com> Subject: [EXTERNAL]CRU CD5-26(PTD 219-107) Early termination of drilling Matt, Please provide additional information on the early TD and the "ran out of sand" explanation. 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. Loeppaalaska.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 From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Monday, December 2, 2019 8:16 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: CD5-26 Frac Sundry All, Just want to give you a heads up before I submit this sundry. I had planned on turning it into you ^20 working days before we plan to frac. However last Wednesday we ran out of sand in our upper lateral causing us to TD early, shaving 12 days off the drilling time. So now we are looking to be ready to frac on 12/10/19. 1 know this is less than ideal, and you cannot guarantee that the sundry will be approved in time, but I wanted to reach out and give you a heads up and see if there is anything I can do to help with the approval process. I will be swinging by with it today. Matt Smith will be sending the cement log for it today as well. Thanks, hope you all had a good Thanksgiving. Adam Klem Senior Completions Engineer Alpine ConocoPhillips Alaska 700 G St ATO 1712 Anchorage, AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Monday, December 2, 2019 8:36 AM To: Klem, Adam Cc: Davies, Stephen F (CED); Schwartz, Guy L (CED); Boyer, David L (CED) Subject: Re: CD5-26 Frac Sundry Adam, Thanx for the heads up. Please submit today and we will do our best. Thanx, Victoria Sent from my iPhone On Dec 2, 2019, at 8:15 AM, Klem, Adam <Adam.Klem@conocophillips.com> wrote: All, Just want to give you a heads up before I submit this sundry. I had planned on turning it into you —20 working days before we plan to frac. However last Wednesday we ran out of sand in our upper lateral causing us to TD early, shaving 12 days off the drilling time. So now we are looking to be ready to frac on 12/10/19. 1 know this is less than ideal, and you cannot guarantee that the sundry will be approved in time, but 1 wanted to reach out and give you a heads up and see if there is anything I can do to help with the approval process. I will be swinging by with it today. Matt Smith will be sending the cement log for it today as well. Thanks, hope you all had a good Thanksgiving. Adam Klem Senior Completions Engineer Alpine ConocoPhillips Alaska 700 G St ATO 1712 Anchorage, AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com Loepp, Victoria T (CED) From: Smith, Matt <Matt.Smith2@conocophillips.com> Sent: Monday, December 2, 2019 9:39 AM To: Loepp, Victoria T (CED) Cc: Klem, Adam; Schwartz, Guy L (CED) Subject: RE: [EXTERNAL]RE: CD5-26 Top of Cement log Follow Up Flag: Follow up Flag Status: Flagged Top of hydrocarbon (Kuparuk), is at 7288' TVDKB / 13,270' MD. Matt Smith Drilling Engineer — Alaska WNS 700 G ST ANCHORAGE ALASKA, ATO -1704 OFFICE: +1.907.263.4324 CELL: +1.432.269.6432 MATT. SMITH2(a-)cORCOM From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, December 02, 2019 9:16 AM To: Smith, Matt <Matt.Smith2@conocophillips.com> Cc: Klem, Adam <Adam.Klem@conocophillips.com>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: [EXTERNAL]RE: CD5-26 Top of Cement log Matt, Please let me know shoe depth as well as top of hydrocarbon. Is a current schematic available? Victoria From: Smith, Matt <Matt.Smith2@conocophillips.com> Sent: Monday, December 2, 2019 9:07 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Klem, Adam <Adam.Klem @conocophillips.com>; Schwartz, Guy L (CED) <Ruy.schwartz@alaska.gov> Subject: CD5-26 Top of Cement log Victoria, Please find attached the cement log run on CD5-26. TOC is shown at -12,510' MD / 6,953' TVD. If you have any questions please let me know. Hope you had a good vacation! Thanks, Matt Smith Drilling Engineer — Alaska WNS 700 G ST ANCHORAGE ALASKA, ATO -1704 CD6 - 26 Alpine AIC Dual Lateral Producer Final Schematic i 2(Y" 94# H-40 Welded i i Conductorto 115 Iv1D 1 i € i i 10-314" 45.5# L-80 HYD 563 x BTC Surface Casing at 2,24(Y MD 4-Y:` x 1" GLIA 4-112" 126# L-80 Hyd 563 4-Y.' x 1" GLW1 7 518" 29.7# L-80 TXP Intermediate Casing at 15,281' MD 39# at heel Upper Completion: 1) 4 W-126# Hyd 563 tubing 2) Shallow nipple profile 3.813 X profile 3)3x4-'h'x 1`CamcoKBlv1G GLtvlw/DV 4) SLB DHG 5) TNT Packer 6) High Pressure 2.813' X sliding sleeve -up to open 7) High Burst X Nipple profile, 2.813- 8) TNT Packer 9) XN Nipple profile, 2.813 Lower Completion: 10)ZXP liner top packer & Flexlock Liner Hanger XO 5' Hydril 521 Box X 4-Yz' H563 pin 11) 4.5' Hydril563 12.6# L-80 va' Frac Ports TOC 12,510' MD/ ti 6,953' TVD 4•/` x 1" GLM Upper TNT Packer at 14.086' } HP Sliding sleeve for Selectivity 3-112" 9.3#TN110SS TNT Production Packer` at Zo 1 d, 548' tv) D XP linertop packer at 14,593' MD C sand Lateral 6 112` Hole TD 14,369= 17,932' MD 4-11:" 12.6# L-80 Hyd563 Liner W frac ports A sand Lateral 6 1t2' Hole TD 15,287— 33, 768' fvt D Company: ConocoPhillips Alaska, Inc. Well: CD5-26 Field: Coleville River Unit State: Alaska Country: USA Schlumhepgep SonicScope Top of Cement i2 31 a o M D T° c P7 -D al9— lo-,-A- Loepp, Victoria T (CED) From: Smith, Matt <Matt.Smith2@conocophillips.com> Sent: Monday, December 2, 2019 9:39 AM To: Loepp, Victoria T (CED) Cc: Klem, Adam; Schwartz, Guy L (CED) Subject: RE: [EXTERNAL]RE: CD5-26 Top of Cement log Follow Up Flag: Follow up Flag Status: Flagged Top of hydrocarbon (Kuparuk), is at 7288' TVDKB / 13,270' MD. Matt Smith Drilling Engineer — Alaska WNS 700 G ST ANCHORAGE ALASKA, ATO -1704 OFF[CE: +1.907.263.4324 CELL: +1.432.269.6432 MATT. SM1THNiC coP.COM From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, December 02, 2019 9:16 AM To: Smith, Matt<Matt.Smith2@conocophiIli ps.com> Cc: Klem, Adam <Adam.Klem @co nocophillips.com>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: [EXTERNAL]RE: CD5-26 Top of Cement log Matt, Please let me know shoe depth as well as top of hydrocarbon. Is a current schematic available? Victoria From: Smith, Matt <Matt.Smith2@conocophillips.corr» Sent: Monday, December 2, 2019 9:07 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Klem, Adam <Adam.Klem @conocophilIips.com>; Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov> Subject: CD5-26 Top of Cement log Victoria, Please find attached the cement log run on CD5-26. TOC is shown at —12,510' MD / 6,953' TVD. if you have any questions please let me know. Hope you had a good vacation! Thanks, Matt Smith Drilling Engineer — Alaska WNS 700 G S'r ANCHORAGE ALASKA. ATO -1704 CD5 - 26 Alpine AIC Dual Lateral Producer Final Schematic I 2U94# H-40 Welded t 1 Conductorto 115 MD I I I I I 1 I I 10-314"45.5# L-80 HYD 563 x I BTC I Surface Casing at 2,24(Y MD 1 I I I 1 4-Y.' x 1" GLM I I I 1 1 1 I I 4-112" 126# L-80 Hyd 563 t I t I I I I 4-Yz` x 1" GLM I I I I 1 7 518" 29.7# L-80 TXP I Intermediate Casing at 15,281' MD 39# at heel I I I 1 Upper Completion: 1) 4 V-126## Hyd 563 tubing 2) Shallow nipple profile 3.813" X profile 3) 3x 4Yz' x 1' Camco KBM G GLM wl DV 4) SLB DHG 5) TNT Packer 6) High Pressure 2.813" X sliding sleeve -up to open 7) High Burst Nipple profile, 2.813" 8) TNT Packer 9)XN Nipple profile, 2.813" Lower Completion: 10)ZXP liner top packer & Flexlock Liner Hanger XO 5' Hydril 521 Box X 4-Y,' H563 pin 11) 4.5" Hydril563 12.6# L-80 W Frac Ports TOG 12, 510' M Dl ` 6,953' TVD 4-W x 1" GLIO 1 Upper TNT Packer at 14,086' HP Sliding sleeve for Selectivity 3-112" 9.3#TN110SS TNT Production Packer~ - .w at ZXP finer top packer 14,548'M D at 14,593' MD C sand Lateral 6 112' Hole TD 14,369'- 17, 932' Ivl D 4-1!:" 12.6# L-80 Hyd563 Liner W frac ports A sand Lateral 6 1t2' Hale TD 15.28 2' — 33,76 8' h1 D P770 X19-/0 -7- Loepp, Victoria T (CED) From: Smith, Matt <Matt.Smith2@conocophillips.com> Sent: Tuesday, October 22, 2019 12:05 PM To: Loepp, Victoria T (CED) Cc: Hobbs, Greg S Subject: CD5-26 FIT Information Attachments: CD5-26 Surface casing - FIT.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please find attached FIT chart for our current well, CD5-26. If you need anything further, please let me know. Thanks, Matt Smith Drilling Engineer — Alaska WNS 700 G ST ANCHORAGE ALASKA, ATO -1704 OFFICE: +1.907.263.4324 CELL: +1.432.269.6432 MATT. SMITH2 _coP.COM 1 E E LLi)LA CD LA Ln LA LA LA LA LA LA LA LA U') lA u, �Lf)N r` -'NN :O O N O NNNNNNr- o 0 0 0 o O0 V y Tn d r 7 m OLACD Cl 0000 00CD0 0000000000 > CO C oNLAO LAOLAO tAOLA O LAOLAOLAOLAOLAO _(D Q 000 NN Cl) MV 'IT LA LA(A(fl1-1-0000OOO m Li m d 3 a �0 0000 Ln0Ln o oLnLno •� LA O LA O I- LA N O O !-- Il_ LA U)O i ZT •- �- N N M t * LA (O i- 00 00 0 0 .a N ' CL E (DQ 7 N O�NM SLAco1,- 000') — NM�LA C 3 0- >a LO O •� 0000 O O t(7 to c 0 000 O 0 O 0 0 00 0 0 Y N y Y C Q Cfl LA ' lA lA to M LA LA M � C m }, L O—N CO �f LAOt` Od7O Ln N to CD m n > O 6N1 C NM > m O ZD .+ 0000 O o 0 000 O 00000 N 3 ' N Na LAO NLA LA I` LOU') ON OO 1,:, Ln oOLA I -M— 0 000 CON _ 00 (D d C _ c: r r r CN N N"T d � Q E E y Q ct- L^ 00 00 O N `7 CO 00 O N E a.0 IN :nW � N 04 CV ; a Y 0 N N N LA CL: "J111111111 LL p r 4) U - N c C) -0 'D V o C Q �+ I V/ Lu '�C- O\ V) N ai .� L CDo N M n -i J -i nai Lna •- a 4) p M OLA 00 � � W a mO X60) o00000� a Q =a O Co s o o= a Z J p _d LU = C "a LL o (: �-C .. .. .. m s �+ o J U) o Ii 0 C _c�*' •� N N ` �_ W o Cl) 0 E N E D f- LO o� Cl)a CL �� 7t3 + W O N a` C) .- p =CA LL. L) pwi O to �?5 7 Q co 0 to O K (� LU f- ` E N d 0) m �- .^ LL O CO Q p r o O N # O i a w E rn U) 1 LL X t o o r u cV _cU w0)CL wQ N 0 n �. O \ N Vi = N N w w LZ Q; R -i CL-i-iM �_ 0 fl Q ai O U?OJ C O tL 09 C - '7 FL m 00 coO v C N•-•- rLni% > N uj �H li d + z C LL p = rte+ rnw', p cn 'nv M 5D E -- la U> x E isN 00 � N 00 i D 0 p) >� p„ N W N� N N N d _ CO) _ IA �•- rn ��,, Hd C Li. o Q R O O d = _ O gI Y Q 4) Ld o � Y S SM S U p o 0) lN Cl)Z N 3unSS3Ud E = W U E E THE STATE 01ALAJKCl GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Colville River Field, Alpine Oil Pool, CRU CD5-26 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-107 Surface Location: 438' FNL, 2919' FEL, SEC. 18, TI IN, R4E, UM Bottomhole Location: 1580' FNL, 789' FEL, SEC. 9, TION, R4E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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, Daniel T. Seamount, Jr. Commissioner c�� DATED this 1J 'day August, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 =EE JUL l9 206 1a. Type of Work: 1b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp E] 1c. Spe ' o e for: Drill Q • Lateral ElStratigraphic Test ❑ Development - Oil Q • Service - Winj ❑ Single Zone ❑' Coalbed Gas Gas Hydrates L] Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 CRU-CD5-26 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, Alaska, 99510-0360 MD: 33734 TVD: 7874 Colville River Unit ' Alpine Pool , 4a. Location of Well (Governmental Section): 7. Property Designation_ Surface: 438' FNL, 2919' FEL, Sec. 18, T11 N, R4E, UM ASRC-NPR4,ASRC-AA092344.ASRC-NPR2, ASRC-NPR5 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: o q2P 1788' FNL, 3786' FEL, Sec. 29, TI IN, R4E, UM 932669, 340757, 932128, 342658 8/10/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1580' FNL, 789' FEL, Sec. 9, T1 ON, R4E, UM 5032, 3122, 8719, 3200 3699' to AA095318 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 74.5 15. Distance to Nearest Well Open Surface: x- 349057 y- 5965780 Zone -4 GL / BF Elevation above MSL (ft): 33.7 to Same Pool: 1539' CD5-25L1 16. Deviated wells: Kickoff depth: 750 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3950 * Surface: 3163 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 78.6 B Welded 79 41 41 120 120 10 yds 13.5" 10.75" 45.5 L-80 TXP 2206 41 41 2247 2189 978sx 11.Oppg, 271 s 15.8ppg G 9.875x11" 7.625" 29.7 L-80 TXP 15239 41 41 15280 7713 978sx 15.8ppg Class G 6.5" 4.5" 12.2 L-80 T -Blue 18604 ' 15130 7738 33734 7874 1 Lined with blank pipe and frac ports 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? YesO No ❑ 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program e Time v. Depth Plot e Shallow Hazard Analysis e✓ F-] Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirementse 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Matt Smith Authorized Name: Chip Alvord Contact Email: matt. Smlth2 CO .COm Authorized Title: Drilling Manager Contact Phone: 907-263-4324 / Authorized Signature: �. Date: 7r L 2 0lej Commission Use Only Permit to Drill (? / API Number: Permit Approva See cover letter for other Number: / "!�% 50- � - _�-� Date: requirements. 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: [+]� Other: ZZ�P t�St �0 3�1j S t Samples req'd: Yes ❑ ,No[/� Mud log req'd: Yes ❑ No[� f✓ n (/ r� C'5t 2 �� F measures: Yes /No Directional sv req'd: Yes Fg/No❑ fr ❑ j a� L� Y q Ittl rt (/ Ci / /` /-C t L9/ ✓crf<r k q V r✓ I-, ✓1 t� Spacing exception req'd: Yes ❑ No � Inclination -only svy req'd: Yes ❑ NoE?" 1 a• r' p2!' f%r¢ C 2 S- D S�ti� ! Post initial injection MIT req'd: Yes ❑ No t}C>� CG la/,b j (rbh'�f,��rfc�« ca 5� L�TIF�% wl-i rh Gt✓a/ k . it ch e -d Oane_-1, h`d05 o f "TID'r" ✓Q I APPROVED BY Approved by: COMMISSIONER THE COMMISSION Dates Z ��/s��/ % Submit Form and Form 10-401 Revised 5/2017 Th S per i isvalid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate gIwioll-'k nRiniui 7-:;;,,� CRU CD5-26(PTD 219-107) Conditions of Approval: Approval is granted to run the (USIT)Sonic on upcoming well CRU CDS-26 (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 (and lengths) 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. (USIT)Sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure 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. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 25, 2019 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CRU CD5-26 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine A and Alpine C production well from the CD5 drilling pad with rig Doyon 25. The intended spud date for this well is 9/28/2019. - CRU CD5-26 is planned to be an Alpine A and C dual lateral production well, with the Alpine C lateral covered in the CD5- 26L1 PTD. The 13-1/2" surface hole will TD above the C-30 sand. The surface hole will then be cased with 10-3/4" casing and cemented to surface. The intermediate section will be drilled with a 9-7/8" x 11" underreamer BHA and Managed Pressure Drilling technology. This hole will be subsequently cased with a 7-5/8" casing string to surface and cemented to 250' TVD above the uppermost hydrocarbon bearing interval. The suface by intermediate casing annulus will then be evaluated for future annular disposal by performing a leak -off test. The 6-1/2" production section will then be horizontally drilled and completed as an producer in the Alpine A reservoir. Alpine A sand lateral will be lined with 4-1/2" liner. A second lateral, CD5-26L1, will then be drilled in the Alpine C Sand and lined with 4-1/2" liner as well, with the upper completion covered in the corresponding PTD application. The well will be hydraulicly stimulated. Please find attached the information required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application For Permit to Drill per 20 AAC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 AAC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 AAC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 AAC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Greg Hobbs at 263-4749 (greg.s.hobbs@ConocoPhillips.com) or Chip Alvord at 265-6120. Sincerely, cc: Matthew Digitally signed by C135-26 Well File / Ann Haggerty -Sherrod ATO 1530 Matthew Smith Johnson N oku ATO 1720 Smith Date: 2079.07.2912:09:34 J -08,00, Chip Alvord ATO 1570 Matt Smith Katheryn Hoffineister ATO 1760 Drilling Engineer Lanston Chin Kuukpik Corp Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 CD5-26 Applicationfor Permit to Drill Document ConocoPhillips' Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (fi)............................................................ 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ............................................ 3 Requirements of 20 AAC 25.050(b)............................................................................................................. 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of20AAC 25.005 (c)(4)) .........................4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (c)(5)).......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))...........5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) ..........................5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ..........................................7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) .........................7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ...................................7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) .........................7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................9 (Requirements of 20 AAC 25.005 (c)(14))............................................................................. 9 15. Attachments................................................................................................................9 Attachment r Cement Summary.................................................................................................................. 9 CD5-26 APD Page 1 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 Attachment 2 Drilling Hazards Summary.................................................................................................... 9 Attachment 3 Completion Schematic...........................................................................................................9 Attachment4 Directional Plan...................................................................................................................9 CD5-26 APD Page 2 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 1. Well Name (Requirements of 20 AAC 25.005 ()9) The well for which this application is submitted will be designated as CRU CD5-26 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 438' FNL, 2919' FEL, Sec. 18, TI IN, ME, UM NAD 1927 RKB Elevation 74.5' AMSL Northings: 5,965,780 Eastings: 349,057 Pad Elevation 33.7' AMSL Top of Productive Horizon Heel 1073' FNL, 4160' FEL, Sec. 29, TI IN, R4E, UM NAD 1927 Northings: 5,953, 785 Eastings: 353,277 Measured De th, RKB: 16,025' Total Vertical Depth, RKB: 7,767' Total Vertical Depth, SS: 7,692' Total Depth Toe 1580' FNL, 789' FEL, Sec. 9, T10N, ME, UM NAD 1927 Northings: 5,937,999 Eastings: 361,298 Measured Depth, RKB: 33,734' Total Vertical Depth, RKB: 7,874' Total Vertical Depth, SS: 7,840' Requirements of 20 AA 25.050(b) Please see Attachment 4: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3)) Please reference BOP and diverter schematics on file for Doyon 25. CD5-26 APD Page 3 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 4. Drilling Hazards Information (Requirements of20AAC25.005 (c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MDMD ft Fracture Gradient(psi)si Pore pressure ASP Drilling 20 120/ 120 10.9 51 56 10.75 2,247 / 2,189 14.5 964 1,432 7.625 15,280 / 7,713 12.5 3,950 3 163 4.5 33,734 / 7,874 12.5 3,950 n/a PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP= [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (O.l x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling below 20" conductor ASP = [(FG x 0.052) - 0.1] D _ [(10.9 x 0.052) - 0.1] x 120 = 56 psi OR ASP= FPP - (0.1 x D) = 964 - (0.1 x 2189') = 745 psi Drilling below 10-3/4" surface casing ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2189' = 1432 psi OR ASP = FPP - (0.1 x D) = 3950 - (0.1 x 7713') = 3179 psi Drilling below 7-5/8" intermediate casing ASP = [(FG x 0.052) - 0.1] D _ [(12.5 x 0.052) - 0.1] x 7713 = 4242 psi OR ASP = FPP - (0.1 x D) = 3950- (0.1 x 7874') = 3163 psi CD5-26 APD Page 4 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensityfor differential sticking, Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005 (c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Csg/Tbg Hole Sze weight Grade Conn. Length Top MD/TVD atm MD/TVD Cement Program OD (in) (ft) (ft) (ft) (in) 20 42 94 H-40 Welded 80 41/41 120/ 120 10 yards Cement to Surface with 10.75 13.5 45.5 L-80 BTM 2,206 41/41 2,247 / 2,189 978 sx DeepCrete Lead 11.0 ppg, 271 sx Class G Tail Slurry 15.8 ppg 7.625 9 875 29.7 L-80 TXP BTCM 15,239 41/41 15,280 / 7,713 978 sx of Class G at 15.8 ppg 4.5 6.5 12.2 L-80 Blue 18,604 15,130 / 7,698 33,734 / 7,874 No cement, Perforation Sub 7. Diverter System Information(Requirements of20 AAC 25.005(c)(7)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h) (2) is granted. At CD5, more than twenty-four penetrations have been completed and there has not been a significant indication of shallow gas or gas hydrates above the C30 where casing will be set. CD5-26 APD Page 5 of 14 Printed. 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 510.0 ppg by use of solids control system and dilutions where necessary. Intermediate• Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.8 — 11.0 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (F1oPro) weighted to 9.0 — 9.5 ppg with calcium carbonate and KCl and utilize MPD for adding backpressure during connections. Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-26 APD Page 6 of 14 Printed: 29 -Jul -19 Surface Intermediate Production Hole Size in. 13.5 9.875 x 11 6.5 Casing Size in. 10.75 7.625 4.5 Density PPG 9.0-10.0 9.6-10.8 8.8-9.5 PV CP 30-80 10 10 YP Ib./100 ftz 100-200 20-28 10-15 Funnel Viscosity s/qt. 300 50-60 40-50 Initial Gels Ib./100 ftz 50 10 6 10 Minute Gels Ib./100 ftz 60 15 8 API Fluid Loss cc/30 min. N.C. — 15.0 5.0 4.0 HPHT Fluid Loss cc/30 min. n/a 8.0-12.0 10.0 pH 11.0 9.5-10.0 9.0-9.5 Surface Hole: A mixed -metal oxide fresh water drilling fluid (Drilplex) will be used for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight 510.0 ppg by use of solids control system and dilutions where necessary. Intermediate• Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.8 — 11.0 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill -in fluid (F1oPro) weighted to 9.0 — 9.5 ppg with calcium carbonate and KCl and utilize MPD for adding backpressure during connections. Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-26 APD Page 6 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 9. Abnormally Pressured Formation Information (Requirements of20AAC25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20AAC25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20AAC25.005(x)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 25 onto CD5-26. 2. Rig up and test riser, dewater cellar as needed. 3. Drill 13.5" hole to the surface casing point as per the directional plan (LWD Program: GR). 4. Run and cement 10-3/4" surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low / 3500 psi high (24 hr. AOGCC notice). 7. Pick up and run in hole with 9-7/8" x 11" drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3500 psi for 30 minutes. 9. Drill out 20' of new hole and perform LOT. Maximum LOT to 18.5 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. ✓ 10. Drill 9-7/8" x 11" hole to section TD, using Managed Pressure Drilling to maintain near constant bottom hole pressure on connections in shale formation (LWD Program: GR/RES). 11. Change out upper pipe rams to 7-5/8" solid bodies and test same to 3,500 psi. 12. Run 7-5/8" casing and cement to 250' TVD above the hydrocarbon bearing zones (cementing schematic attached). 13. Change upper pipe rams to 3-1/2" x 6" VBRs. 14. Test BOPE to 250 psi low / 3,500 psi high (24 hr. AOGCC notice). 15. Pick up and run in hole with 6-1/2" drilling BHA. Log top of cement with sonic tool in recorded mode. 16. Chart casing pressure test to 3500 psi for 30 minutes. 17. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 16.0 ppg. Minimum required leak -off value is 11.0 ppg EMW. 18. Drill 6-1/2" hole to section TD (LWD Program: GR/RES). 19. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC with AOGCC after download and process recorded data. CD5-26 APD Page 7 of 14 Printed: 29 -Jul -19 20. Run 4-1/2" liner, set liner hanger and packer. 21. Run and set whipstock for kickoff in the Alpine C Sand. 22. Mill window and at least 20 feet of new formation. 23. POOH and lay down milling BHA. 24. End PTD for CD5-26 and begin PTD for CD5-26L1. Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 CD5-26 APD Page 8 of 14 Printed. 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well C135-26 will be injected into a permitted surface casing x production casing annulus on CD5. The CD5-26 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. Significant hydrocarbon zones include only the Alpine and Kuparuk sand based on pre -drill interpretations. There will be 500' of cement placed above the top of the Kuparuk reservoir. Once C135-26 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,189') + 1,500 psi = 2,866 psi Pore Pressure = 1,049 psi Th erefore Differential = 2,866 — 1,049 = 1,817 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85% of Burst 85% of (ppf) Type Collapse Burst 10-3/4" 45.5 L-80 3 HYD563/BTCM 2470 psi 2100 psi 5210 psi 4429 psi 7-5/8" 29.7 L-80 3 HYD563/BTCM 4790 psi 4071 psi 6890 psi 5856 psi 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan CD5-26 APD Page 9 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 Attachment 1 - Cement Summary CD5-26 Cementing Program: CD5-26 Cement Schematic 29'94# H-40 Welded Ccnductorto 115 10-314" 45.5# L-80 HYD563/BTCM 2,247 MD 12,189' TVD @ 31° inc- 9-718" x 11" Hole Top of Cement 12936 MD 17,120' TVD Kuparuk C 13,510' MD / 7,370' TVD KOP in Alpine C Alpine C 14,095' MD 17,575' TVD 14,092' MD / 7,574' TVD 1 4 1 Alpine A 7-518" 29,7 L-80 HYD 563 X BTCM , `� Casing 16,025' MD 17,767, 7,76T TVD 15,280'M D / 7,713' TVD @ 84° 1 I ti I 7 1 I �♦ rr f I � I CD5-26 A Sand 6-1/2" Hole i I CD5-26L1 C Sand 6-112" Hole 33,734'10D/7,874@890 ;—____- 29,814'MD17,804@89° CD5-26 APD Page 10 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 10.75" Surface Casing run to 2,247' MD / 2,189' TVD Cement from 2247' MD to 1747'(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1747' to surface with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1325' MD), zero excess in 20" conductor. Lead slurry from 1,747' MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (120'- 41� X 1.3645 ft3/ft X 1.0 (0% excess) = 108 ft3 Permafrost to Conductor (1,325'- 120') X 0.3637 ft3/ft X 3.5 (250% excess) = 1,547 ft3 Top of Tail to Permafrost (1,747'- 1,325') X 0.3637 ft3/ft X 1.5 (50% excess) = 232 ft3 Total Volume = 108 + 1,547 + 232 = 1,887 ft3 => 978 sx of 11.0 ppg DeepCrete @ 1.93 ft3 /sk Tail slurry from 2,247' MD to 1,747' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,249'-1,749') X 0.3637 ft3/ft X 1.50 (50% excess) = 273 ft3 Shoe Joint (80� X 0.5400 ft3/ft X 1.0 (0% excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 271 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.17 ft3/sk 7.625" Intermediate Casing run to 15,280' MD / 7,713' TVD Top of slurry is designed to be at 12,936' MD, which is 250' TVD above the prognosis shallowest hydrocarbon bearing zone Kuparuk C. Assume 40% excess annular volume. * 11" Under reamer is 90' above the 9-7/8" bit. Tail slurry from 15,318' MD to 12,936' MD with 15.8 ppg Class G + additives Shoe to top of 9-7/8" Hole (15,280'- 15,200') X 0.2148 ft3/ft X 1.40 (40% excess) = 27 ft3 11" Hole to to Top of Cement (15,200'- , 12,936 X 0.3428 ft3/ft X 1.40 (40% excess) = 1,086 ft Shoe Joint (80� X 0.2578 ft3/ft X 1.0 (0% excess) = 21 ft3 Total Volume = 27+1,086 + 21 = 1134 ft3 => 978 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.16 ft3/sk CD5-26 APD Page 11 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 Attachment 2 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level I Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight, decreased Gas Hydrates Low mud viscosity, increased circulating times, controlled drilling rates, Abnormal Reservoir Pressure Low low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use Hydrogen Sulfide gas Low weighted sweeps. Hydrogen Sulfide gas Low Reduced pump rates, mud rheology, lost circulation material, use of Lost Circulation Low low density cement slurries 9-7/8" x 11" Hole / 7-5/8" Casing Interval Event Risk Level I Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent Lost circulation Low circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on tris Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills, increased mud weight. No mapped faults occur Abnormal Reservoir Pressure Low across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, Hydrogen Sulfide gas Low mud scavengers mud scavengers 6-1/2" Open Hole Production Interval Event Risk Level I Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent Lost circulation Low circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on tris Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, Hydrogen Sulfide gas Low mud scavengers CD5-26 APD Page 12 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 Well Proximitv Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drillina Area Risks: Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on location to deal with losses. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach and instability in the intermediate interval will require higher mud weights and managed pressure drilling in order to stabilize the formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. CD5-26 APD Page 13 of 14 Printed: 29 -Jul -19 Application for Permit to Drill, Well CRU CD5-26 Saved: 29 -Jul -19 Attachment 3 — Completion Schematic (includes Alpine C lateral, as detailed in CD5-261-1 PTD) CD5 - 26 Alpine A/C Dual Lateral Producer Proposed Schematic C sand Lateral 4-i' x 1" GLM 6 1/2" Hole TD 14,095'- 29,814' MD — — \ --———————————— — — — — —— 4-'ls"12.6#L-80 Hyd 563 Liner w/ perf pups 0 0 0 0 0 0 0 i i I Upper TNT Packer ----------------------------------- 4 ' l 12.6# L-80 Hyd563 Liner wt frac ports HP Sliding sleeve for Selectivity " 0 0 o 0 0 0 0 0 0 (� ----------------------------------I 3-112" 9.3# TAJ110SS TNT Production Packer A sand Lateral at 6 1/2' Hole TD 14,650' MD ZXP liner top packer 15,280' — 33,734' MD at 15.130' MD CD5-26 APD Page 14 of 14 Printed: 29 -Jul -19 I 20" 94# H-40 Welded Upper Completion: Conductor to 115' MD 1) 4 %`-12.6# Hyd 563 tubing j 2) Shallow nipple profile 3.813" ID I 3) 4-i" x 1' Camco KBMG GLM (xx') w/DCK2 I pinned for 2500 psi casing to tbg shear 4) TNT Packer 5) X Nipple profile, 2.813" I 6) TNT Packer I 7) X Nipple profile, 2.813" I 10-314" 45.5# L-80 HYD 563 x Lower Completion: I 13TC 8) Plop and drop liner in C sand I Surface Casing at 2,24T MD - na junction I -4.5" 12.6# L-60 w/ perf pups t 9) ZXP liner top packer 8 Flexlock Liner Hanger 4 I" x 1 GLM XO 5" Hydril 521 Box X 4-!' H563 pin I I I -4.5" Hydril563 12.6# L-80 w/ Frac Ports I I I I I 4-112" 12.6# L-80 Hyd 563 I I I I I I 4-%d' x 1" GLM I t 1 7 5/8" 29.7# L-80 TXP t Intermediate Casing at 15,280' MD I I 39# at heel C sand Lateral 4-i' x 1" GLM 6 1/2" Hole TD 14,095'- 29,814' MD — — \ --———————————— — — — — —— 4-'ls"12.6#L-80 Hyd 563 Liner w/ perf pups 0 0 0 0 0 0 0 i i I Upper TNT Packer ----------------------------------- 4 ' l 12.6# L-80 Hyd563 Liner wt frac ports HP Sliding sleeve for Selectivity " 0 0 o 0 0 0 0 0 0 (� ----------------------------------I 3-112" 9.3# TAJ110SS TNT Production Packer A sand Lateral at 6 1/2' Hole TD 14,650' MD ZXP liner top packer 15,280' — 33,734' MD at 15.130' MD CD5-26 APD Page 14 of 14 Printed: 29 -Jul -19 14:28, July 24 2019 CD5-26 wp07 a 10-3/4 x 13-1/2 7-5/8 x 9-7/8 by 11 4-1/2 x 6-3/ I d I W 0 o - m 0 U cv P F- 0 O a55 rn 2 m 028 0 m d U 0 0 6750 13500 20250 27000 33750 Measured Depth 10-3/4 x 1 3-1/2-- Plan D25 @ 74.50usft (D25) Z0o �'�roQ 0000 0 4-1/2 x 6-3/4 h o 0 o 7-5/8 x 9-7/8 by 17 0 0 ->a �yQ)�o4%oc000000000100000000 h^ p 0 0 0 0 0 0 00 0 �O 0 0 0 0 0 0 0 W D) O N co 7� 10 r-- M M O N 27 0 4500 9000 13500 18000 22500 27000 400 800 1200 1600 2000 2400 2800 Depth From Depth To Survey/Plan Tool 40.80 2200.00 CD5-26 wp07 (CD5-26) GYD-GC-SS 2200.00 3700.00 CD5-26 wp07 (CD5-26) MWD OWSG 2200.0015200.00 CD5-26 wp07 (CD5-26) MWD+IFR2+SAG+MS 15200-001 6700.00 CD5-26 wp07 (CD5-26) MWD OWSG 15200.00 3373C24 CD5-26 wp07(CD5-26) MWD+IFR2+SAG+MS 7.302 i lan Surnmar 330 21 150 60 12 41 500 500 --690 690 - 870 870 - 1060 1060 - 1240 240 - 1430 430 - 1610 1610 -� 1800 1800 - 3130 K:113130 4450 -1PB14450 - 5780 5780 - 7100 90 7100 --- 8430 8430 9750 9750 11080 11080 -� 12400 12400 15060 15060 17720 0 17720 - 20390 20390 - 23050 23050 - 25710 25710 28370 28370 31030 31030 - 33696 2264.00 2335.52 10-3/4 x 13-1/2 7713.50 15280.567-5/8 x 9-7/8 by 11 Magnetic Model & Date: BGGM2018 25 -Oct -19 7874.29 33696.00 4-1/2 x 6-3/4Magnetic North is 15.90° East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.71 ° 57362nT Sec MD Inc Azi TVD +N/ -S +F/ -W Dleg TFace VSecl Target Annotation Occepted by 1 40.80 0.00 0.00 40.80 0.00 0.00 0.00 0.00 0.00 Lithology Column 2 750.00 0.00 0.00 750.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 165° TF, for 300' 3 1050.00 4.50 165.00 1049.69 -11.37 3.05 1.50 165.00 11.60 Start 2'/100' DLS, 0° TF, for 226.44' 4 1352.05 10.54 165.00 1349.00 49.54 13.27 2.00 0.00 50.52 5 1453.76 10.54 165.00 1449.00 -67.51 18.09 0.00 0.00 68.85 1399.0 6 2335.52 32.58 165.00 2264.00 -378.61 101.45 2.50 0.00 386.09 7 2355,52 32.58 165.00 2280.85 -389.01 104.24 0.00 0.00 396.69 Base Permfr 8 3414.33 64.20 160.67 2975.23 -1133.34 341.88 3.00 -7.41 1171.82 913610.12 64.20 160.67 7413.00 -9795.46 3379.64 0.00 0.0010307.16 2303.1 1014147.56 78.09 152.00 7586.55 -10258.99 3584.48 3.00 -320810813.84 C-30 11 14347.56 84.09 152.00 7617.50 -10433.38 3677.19 3.00 0.0011011.06 CD5-26 Tgt 01 TopC 071619 2- 1215280.56 84.09 152.00 7713.50 -11252.62 4112.83 0.00 0.0011937.78 CDS26 Tgt 02 B3 Int 071619 1315300.56 84.09 152.00 7715.56 -11270.39 4122.16 0.00 0.0011957.65 C-10 1415815.06 87.00 152.00 7755.50 -11723.26 4362.94 0.56 -0.0812469.82 1516165.06 87.00 152.00 7773.82 -12031.87 4527.03 0.00 0.0012818.84 1616434.47 89.69 151.90 7781.59-12269.51 4653.65 1.00 -2.0813087.71 377 17 33734.24 89.69 151.90 7874.50 -27530.24 12801.27 0.00 0.00 30360.94 CD5-26 Tgt 03 TD 071619 4r2X-3 K-2 1419b 97 Sub 97 Permit Pack sa,os Alb 96 Well fails against main bore, and also with CD5-98. 771 TDp 760 Dispensation will need to be applied - 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 surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.] approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 7 100 feet lateral tolerance. repared by Checked by Occepted by Approved by: S. Del -app V. Osara J. Ryan CoP DE 0008£; i i LpdM 9Z-5a� `o OOOZ,B; o N00018" O 00 't 0000 � N .� 0006: o 0008,31 O OozeN 0009,3 00990;; OOov_ 0 00088'' i _o N 00OZ2 0001Z'. , p _.Ln co O L6 OOOOZ : T 1/ U ¢ 0006 [ cz _Q U ::D Q Q Q0081 fl OOOL! o C 0 CO O U 00 j7� o o�3 rn LL O�� t - c Q 000 / L9 o T O QQQ , � T OQQ Q� V� O Z) Y o ©�QX 6 Y O� �9 O 0 E . U U 000/ N °°�_ LO000 o m000 IQQo> b,p O O O LC) O O O O O LO O O O O O LC) O C? co O � yldaa IE01IJ9A anal T T 0; O o N 0 0 c9� O _ C> .7 O Lo CL0 Q pp pppj\ 0 `o op C� T O ppp Q o p o Q p poop o //� p Q pop Qpm\ pp pp pp !� �.v Qp o x N W o Q pQ op 00 Q Cfl O i + cn p p p � ! .. p p pp �p pt9� �p 3 amp- Q Q CD •V ap O _^ N00 O T \ C x C? CD O 14.ft O O L9 N c LO a O c O CD CDVT O O O O O O O O O O O n O Y O V/ I mLlTJoN/(-)MnoS N N ConocoPhillips Alaska Inc WNS Western North Slope CD5 Alpine West Pad Plan: CD5-26 (11 C) - Slot 26 50103xxxxx00 CD5-26 Plan: CD5-26 wp07 Standard Proposal Report 24 July, 2019 ConocoPhilli s p sConocoPhillip Database: EDT 14 Alaska Production Company: ConocoPhillipsAlaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-26 (11C) Wellbore: CD5-26 Design: CD5-26 wp07 ConocoPhillips Standard Proposal Report Local Coordinate Reference: Well Plan: CD5-26 (11 C) - Slot 26 TVD Reference: Plan D25 @ 74.50usft (D25) MD Reference: Plan D25 @ 74.50usft (D25) North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Ist, CD5Alpine West Pad Position: From: Map Position Uncertainty: 0.00 usft Well Plan: CD5-26 (11 C) - Slot 26 Well Position +N/ -S -4.65 usft +E/ -W -160.86 usft Position Uncertainty 0.00 usft Ground Level: 33.70 usft Wellbore CD5-26 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°I (nT) BG GM2018 10/25/2019 15.90 80.71 57,362 Design CD5-26 wp07 Audit Notes: Version: Phase: Vertical Section: Depth From (TVD) (usft) 40.80 Plan Survey Tool Program Date 7/24/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) 1 40.80 2,200.00 CD5-26 wp07 (CD5-26) 2 2,200.00 3,700.00 CD5-26 wp07 (CD5-26) 3 2,200.00 15,200.00 CD5-26 wp07 (CD5-26) 4 15,200.00 16,700.00 CD5-26 wp07 (CD5-26) 5 15,200.00 33,734.24 CD5-26 wp07 (CD5-26) PLAN Tie On Depth: 40.80 +N/ -S +El -W Direction (usft) (usft) (°) 0.00 0.00 155.06 Tool Name Remarks GYD-GC-SS Gyrodata gyro single shots MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + A MWD OWSG OWSG MWD - Standard MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + A 7/24/2019 12:34 13PM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips philii Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-26(11C) Wellbore: CD5-26 Design: CD5-26 wp07 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Plan Sections 0.00 0.00 0.00 0.00 0.00 Measured 1.50 0.00 Vertical 2.00 0.00 Depth Inclination Azimuth Depth +N/ -S +E/ -W (usft) (°) (°) (usft) (usft) (usft) 40.80 0.00 0.00 40.80 0.00 0.00 750.00 0.00 0.00 750.00 0.00 0.00 1,050.00 4.50 165.00 1,049.69 -11.37 3.05 1,352.05 10.54 165.00 1,349.00 -49.54 13.27 1,453.76 10.54 165.00 1,449.00 -67.51 18.09 2,335.52 32.58 165.00 2,264.00 -378.61 101.45 2,355.52 32.58 165.00 2,280.85 -389.01 104.24 3,414.33 64.20 160.67 2,975.23 -1,133.34 341.88 13,610.12 64.20 160.67 7,413.01 -9.795.46 3,379.64 14,147.56 78.09 152.00 7,586.55 -10,258.99 3,584.48 14,347.56 84.09 152.00 7,617.50 -10,433.38 3,677.19 15,280.56 84.09 152.00 7,713.50 -11,252.82 4,112.83 15,300.56 84.09 152.00 7,715.56 -11,270.39 4,122.16 15,815.06 87.00 152.00 7,755.50 -11,723.26 4,362.94 16,165.07 87.00 152.00 7,773.82 -12,031.87 4,527.03 16,434.47 89.69 151.90 7,781.59 -12.269.51 4,653.65 33,734.24 89.69 151.90 7,874.50 -27.530.24 12,801.27 ConocoPhillips Standard Proposal Report Well Plan: CD5-26 (11 C) - Slot 26 Plan D25 @ 74.50usft (D25) Plan D25 @ 74.50usft (D25) True Minimum Curvature Dogleg Build Turn Rate Rate Rate (°HOOusft) (°/100usft) (°/100usft) 0.00 0.00 0.00 0.00 0.00 0.00 1.50 1.50 0.00 2.00 2.00 0.00 0.00 0.00 0.00 2.50 2.50 0.00 0.00 0.00 0.00 3.00 2.99 -0.41 0.00 0.00 0.00 3.00 2.59 -1.61 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.56 0.56 0.00 0.00 0.00 0.00 1.00 1.00 -0.04 0.00 0.00 0.00 TFO (°) Target 0.00 0.00 165.00 0.00 0.00 0.00 0.00 -7.41 0.00 -32.08 0.00 CD5-26 Tgt 01 TopC i 0.00 CD5-26 Tgt 02 B3 Int 0.00 -0.08 0.00 -2.08 0.00 CD5-26 Tgt 03 TD 07 7/24/2019 12:34 13PM Page 3 COMPASS 5000.14 Build 85H Conocophillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Coordinate Reference: Well Plan: CD5-26 (11 C) - Slot 26 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Plan D25 @ 74.50usft (D25) Project: Western North Slope MD Reference: Plan D25 @ 74.50usft (D25) Site: CD5 Alpine West Pad North Reference: True Well: Plan: CD5-26 (11C) Survey Calculation Method: Minimum Curvature Wellbore: CD5-26 Design: CD5-26 wp07 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +El -W Section Rate Rate Rate (usft) N (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) 40.80 0.00 0.00 40.60 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0.00 0.00 700.00 0.00 0.00 0.00 0.00 0.00 0.00 750.00 0.00 0.00 750.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 165° TF, for 300' 800.00 0.75 165.00 800.00 -0.32 0.08 0.32 1.50 1.50 0.00 900.00 2.25 165.00 899.96 -2.84 0.76 2.90 1.50 1.50 0.00 1,000.00 3.75 165.00 999.82 -7.90 2.12 8.06 1.50 1.50 0.00 1,050.00 4.50 165.00 1,049.69 -11.37 3.05 11.60 1.50 1.50 0.00 Start 2°/100' DLS, 0° TF, for 226.44' i 1,100.00 5.50 165.00 1,099.50 -15.58 4.18 15.89 2.00 2.00 0.00 1,200.00 7.50 165.00 1,198.85 -26.52 7.11 27.04 2.00 2.00 0.00 1,276.44 9.03 165.00 1,274.50 -37.13 9.95 37.86 2.00 2.00 0.00 Hold for 101.25' 1,300.00 9.50 165.00 1,297.75 -40.79 10.93 41.60 2.00 2.00 0.00 1,352.05 10.54 165.00 1,349.00 -49.54 13.27 50.52 2.00 2.00 0.00 1,377.70 10.54 165.00 1,374.22 -54.07 14.49 55.14 0.00 0.00 0.00 Start 2.5°/100' DLS, 0° TF, for 872.18' 1,400.00 10.54 165.00 1,396.15 -58.01 15.54 59.16 0.00 0.00 0.00 1,402.90 10.54 165.00 1,399.00 -58.53 15.68 59.68 0.00 0.00 0.00 Base Permfrost 1,453.76 10.54 165.00 1,449.00 -67.51 18.09 68.85 0.00 0.00 0.00 1,500.00 11.70 165.00 1,494.37 -76.13 20.40 77.63 2.50 2.50 0.00 1,600.00 14.20 165.00 1,591.82 -97.77 26.20 99.70 2.50 2.50 0.00 1,700.00 16.70 165.00 1,688.20 -123.49 33.09 125.93 2.50 2.50 0.00 1,800.00 19.20 165.00 1,783.33 -153.25 41.06 156.28 2.50 2.50 0.00 1,900.00 21.70 165.00 1,877.02 -186.99 50.10 190.69 2.50 2.50 0.00 2,000.00 24.20 165.00 1,969.10 -224.65 60.19 229.09 2.50 2.50 0.00 2,100.00 26.70 165.00 2,059.39 -266.15 71.31 271.40 2.50 2.50 0.00 2,200.00 29.20 165.00 2,147.72 -311.41 83.44 317.56 2.50 2.50 0.00 2,249.88 30.44 165.00 2,190.99 -335.37 89.86 341.99 2.50 2.50 0.00 Hold for 20' 2,269.88 30.94 165.00 2,208.19 -345.23 92.51 352.05 2.50 2.50 0.00 Start 3°/100' DLS, -7.01° TF, for 1125.99' 2,300.00 31.70 165.00 2,233.92 -360.36 96.56 367.47 2.50 2.50 0.00 2,335.52 32.58 165.00 2,264.00 -378.61 101.45 386.09 2.50 2.50 0.00 10-3/4 x 13-112 2,355.52 32.58 165.00 2,280.85 -389.01 104.24 396.69 0.00 0.00 0.00 2,382.52 33.39 164.81 2,303.50 -403.21 108.06 411.18 3.00 2.98 -0.70 C-30 2,400.00 33.91 164.69 2,318.05 -412.55 110.61 420.73 3.00 2.98 -0.68 2,500.00 36.89 164.07 2,399.56 -468.33 126.22 477.88 3.00 2.98 -0.62 2,600.00 39.87 163.53 2,477.94 -527.94 143.55 539.24 3.00 2.98 -0.54 2,700.00 42.85 163.05 2,552.99 -591.21 162.55 604.63 3.00 2.98 -0.48 2,800.00 45.84 162.62 2,624.50 -657.99 183.18 673.88 3.00 2.99 -0.43 2,900.00 48.82 162.24 2,692.27 -728.07 205.38 746.79 3.00 2.99 -0.39 3,000.00 51.81 161.89 2,756.12 -801.28 229.09 823.17 3.00 2.99 -0.35 3,100.00 54.80 161.56 2,815.87 -877.41 254.23 902.80 3.00 2.99 -0.32 712412019 12,34:13PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska lnc WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-26 (11 C) Wellbore: CD5-26 Design: CD5-26 wp07 Planned Survey Well Plan- CD5-26 (11 C) -Slot 26 Measured Plan D25 @ 74.50usft (D25) Depth Inclination Plan D25 @ 74.50usft (D25) (usft) (°) True 3,143.44 56.10 C-10 +E/ -W 3,200.00 57.79 3,300.00 60.78 3,395.87 63.65 Hold for 10183.66' (usft) 3,400.00 63.77 3,414.33 64.20 3,500.00 64.20 3,600.00 64.20 3,700.00 64.20 3,800.00 64.20 3,900.00 64.20 4,000.00 64.20 4,100.00 64.20 4,200.00 64.20 4,300.00 64.20 4,400.00 64.20 4,500.00 64.20 4,600.00 64.20 4,700.00 64.20 4,800.00 64.20 4,900.00 64.20 5,000.00 64.20 5,100.00 64.20 5,200.00 64.20 5,248.36 64.20 K-3 -0.26 5,300.00 64.20 5,400.00 64.20 5,500.00 64.20 5,600.00 64.20 5,700.00 64.20 5,800.00 64.20 5,818.14 64.20 K-2 0.00 5,900.00 64.20 6,000.00 64.20 6,100.00 64.20 6,200.00 64.20 6,300.00 64.20 6,400.00 64.20 6,500.00 64.20 6,600.00 64.20 6,700.00 64.20 6,785.39 64.20 Alb 97 0.00 6,800.00 64.20 6,900.00 64.20 6,953.10 64.20 Sub 97 0.00 7,000.00 64.20 7,100.00 64.20 7/24/2019 12:34:13PM ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan- CD5-26 (11 C) -Slot 26 TVD Reference: Plan D25 @ 74.50usft (D25) MD Reference: Plan D25 @ 74.50usft (D25) North Reference: True Survey Calculation Method: Minimum Curvature Page 5 COMPASS 5000.14 Build 85H Vertical Vertical Dogleg Build Turn Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 161.43 2,840.50 -911.33 265.59 938.35 3.00 2.99 -0.31 161.26 2,871.35 -956.25 280.75 985.47 3.00 2.99 -0.30 160.98 2,922.42 -1,037.58 308.58 1,070.95 3.00 2.99 -0.28 160.72 2,967.11 -1,117.69 336.40 1,155.32 3.00 2.99 -0.27 160.71 2,968.94 -1,121.19 337.62 1,159.01 3.00 2.99 -0.26 160.67 2,975.23 -1,133.34 341.88 1,171.82 3.00 2.99 -0.26 160.67 3,012.52 -1,206.13 367.40 1,248.58 0.00 0.00 0.00 160.67 3,056.04 -1,291.08 397.20 1,338.18 0.00 0.00 0.00 160.67 3,099.57 -1,376.04 426.99 1,427.78 0.00 0.00 0.00 160.67 3,143.09 -1,461.00 456.79 1,517.38 0.00 0.00 0.00 160.67 3,186.62 -1,545.96 486.58 1,606.98 0.00 0.00 0.00 160.67 3,230.14 -1,630.92 516.37 1,696.58 0.00 0.00 0.00 160.67 3,273.67 -1,715.87 546.17 1,786.18 0.00 0.00 0.00 160.67 3,317.20 -1,800.83 575.96 1,875.78 0.00 0.00 0.00 160.67 3,360.72 -1,885.79 605.76 1,965.38 0.00 0.00 0.00 160.67 3,404.25 -1,970.75 635.55 2,054.98 0.00 0.00 0.00 160.67 3,447.77 -2,055.70 665.35 2,144.58 0.00 0.00 0.00 160.67 3,491.30 -2,140.66 695.14 2,234.17 0.00 0.00 0.00 160.67 3,534.82 -2,225.62 724.93 2,323.77 0.00 0.00 0.00 160.67 3,578.35 -2,310.58 754.73 2,413.37 0.00 0.00 0.00 160.67 3,621.87 -2,395.54 784.52 2,502.97 0.00 0.00 0.00 160.67 3,665.40 -2,480.49 814.32 2,592.57 0.00 0.00 0.00 160.67 3,708.93 -2,565.45 844.11 2,682.17 0.00 0.00 0.00 160.67 3,752.45 -2,650.41 873.91 2,771.77 0.00 0.00 0.00 160.67 3,773.50 -2,691.49 888.31 2,815.10 0.00 0.00 0.00 160.67 3,795.98 -2,735.37 903.70 2,861.37 0.00 0.00 0.00 160.67 3,839.50 -2,820.32 933.49 2,950.97 0.00 0.00 0.00 160.67 3,883.03 -2,905.28 963.29 3,040.57 0.00 0.00 0.00 160.67 3,926.55 -2,990.24 993.08 3,130.17 0.00 0.00 0.00 160.67 3,970.08 -3,075.20 1,022.88 3,219.76 0.00 0.00 0.00 160.67 4,013.61 -3,160.16 1,052.67 3,309.36 0.00 0.00 0.00 160.67 4,021.50 -3,175.57 1,058.08 3,325.62 0.00 0.00 0.00 160.67 4,057.13 -3,245.11 1,082.47 3,398.96 0.00 0.00 0.00 160.67 4,100.66 -3,330.07 1,112.26 3,488.56 0.00 0.00 0.00 160.67 4,144.18 -3,415.03 1,142.05 3,578.16 0.00 0.00 0.00 160.67 4,187.71 -3,499.99 1,171.85 3,667.76 0.00 0.00 0.00 160.67 4,231.23 -3,584.94 1,201.64 3,757.36 0.00 0.00 0.00 160.67 4,274.76 -3,669.90 1,231.44 3,846.96 0.00 0.00 0.00 160.67 4,318.28 -3,754.86 1,261.23 3,936.56 0.00 0.00 0.00 160.67 4,361.81 -3,839.82 1,291.03 4,026.16 0.00 0.00 0.00 160.67 4,405.34 -3,924.78 1,320.82 4,115.76 0.00 0.00 0.00 160.67 4,442.50 -3,997.32 1,346.26 4,192.26 0.00 0.00 0.00 160.67 4,448.86 -4,009.73 1,350.61 4,205.35 0.00 0.00 0.00 160.67 4,492.39 4,094.69 1,380.41 4,294.95 0.00 0.00 0.00 160.67 4,515.50 4,139.81 1,396.23 4,342.53 0.00 0.00 0.00 160.67 4,535.91 -4,179.65 1,410.20 4,384.55 0.00 0.00 0.00 160.67 4,579.44 -4,264.61 1,440.00 4,474.15 0.00 0.00 0.00 Page 5 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: CD5-26 (11 C) - Slot 26 Company: ConocoPhillips Alaska Inc NMS TVD Reference: Plan D25 @ 74.50usft (D25) Project: Western North Slope MD Reference: Plan D25 @ 74.50usft (D25) Site: CD5 Alpine West Pad North Reference: True Well: Plan: CD5-26 (11C) Survey Calculation Method: Minimum Curvature Wellbore: CD5-26 Design: CD5-26 wp07 Planned Survey-- -� Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100usft) (°/100usft) (°/100usft) 7,200.00 64.20 160.67 4,622.96 4,349.56 1,469.79 4,563.75 0.00 0.00 0.00 7,300.00 64.20 160.67 4,666.49 -4,434.52 1,499.59 4,653.35 0.00 0.00 0.00 7,400.00 64.20 160.67 4,710.01 -4,519.48 1,529.38 4,742.95 0.00 0.00 0.00 7,500.00 64.20 160.67 4,753.54 -4,604.44 1,559.17 4,832.55 0.00 0.00 0.00 7,600.00 64.20 160.67 4,797.07 -4,689.40 1,588.97 4,922.15 0.00 0.00 0.00 7,700.00 64.20 160.67 4,840.59 -4,774.35 1,618.76 5,011.75 0.00 0.00 0.00 7,800.00 64.20 160.67 4,884.12 -4,859.31 1,648.56 5,101.35 0.00 0.00 0.00 7,900.00 64.20 160.67 4,927.64 -4,944.27 1,678.35 5,190.94 0.00 0.00 0.00 8,000.00 64.20 160.67 4,971.17 -5,029.23 1,708.15 5,280.54 0.00 0.00 0.00 8,100.00 64.20 160.67 5,014.69 -5,114.18 1,737.94 5,370.14 0.00 0.00 0.00 8,200.00 64.20 160.67 5,058.22 -5,199.14 1,767.73 5,459.74 0.00 0.00 0.00 8,300.00 64.20 160.67 5,101.75 -5,284.10 1,797.53 5,549.34 0.00 0.00 0.00 8,400.00 64.20 160.67 5,145.27 -5,369.06 1,827.32 5,638.94 0.00 0.00 0.00 8,500.00 64.20 160.67 5,188.80 -5,454.02 1,857.12 5,728.54 0.00 0.00 0.00 8,600.00 64.20 160.67 5,232.32 -5,538.97 1,886.91 5,818.14 0.00 0.00 0.00 8,700.00 64.20 160.67 5,275.85 -5,623.93 1,916.71 5,907.74 0.00 0.00 0.00 8,800.00 64.20 160.67 5,319.37 -5,708.89 1,946.50 5,997.34 0.00 0.00 0.00 8,900.00 64.20 160.67 5,362.90 -5,793.85 1,976.29 6,086.94 0.00 0.00 0.00 9,000.00 64.20 160.67 5,406.42 -5,878.80 2,006.09 6,176.53 0.00 0.00 0.00 9,100.00 64.20 160.67 5,449.95 -5,963.76 2,035.88 6,266.13 0.00 0.00 0.00 9,200.00 64.20 160.67 5,493.48 -6,048.72 2,065.68 6,355.73 0.00 0.00 0.00 9,300.00 64.20 160.67 5,537.00 -6,133.68 2,095.47 6,445.33 0.00 0.00 0.00 9,400.00 64.20 160.67 5,580.53 -6,218.64 2,125.27 6,534.93 0.00 0.00 0.00 9,500.00 64.20 160.67 5,624.05 -6,303.59 2,155.06 6,624.53 0.00 0.00 0.00 9,600.00 64.20 160.67 5,667.58 -6,388.55 2,184.85 6,714.13 0.00 0.00 0.00 9,700.00 64.20 160.67 5,711.10 -6,473.51 2,214.65 6,803.73 0.00 0.00 0.00 9,800.00 64.20 160.67 5,754.63 -6,558.47 2,244.44 6,893.33 0.00 0.00 0.00 9,900.00 64.20 160.67 5,798.15 -6,643.42 2,274.24 6,982.93 0.00 0.00 0.00 9,928.36 64.20 160.67 5,810.50 -6,667.52 2,282.69 7,008.34 0.00 0.00 0.00 Alb 96 10,000.00 64.20 160.67 5,841.68 -6,728.38 2,304.03 7,072.53 0.00 0.00 0.00 10,100.00 64.20 160.67 5,885.21 -6,813.34 2,333.83 7,162.12 0.00 0.00 0.00 10,200.00 64.20 160.67 5,928.73 -6,898.30 2,363.62 7,251.72 0.00 0.00 0.00 10,300.00 64.20 160.67 5,972.26 -6,983.26 2,393.41 7,341.32 0.00 0.00 0.00 10,400.00 64.20 160.67 6,015.78 -7,068.21 2,423.21 7,430.92 0.00 0.00 0.00 10,500.00 64.20 160.67 6,059.31 -7,153.17 2,453.00 7,520.52 0.00 0.00 0.00 10,600.00 64.20 160.67 6,102.83 -7,238.13 2,482.80 7,610.12 0.00 0.00 0.00 10,700.00 64.20 160.67 6,146.36 -7,323.09 2,512.59 7,699.72 0.00 0.00 0.00 10,800.00 64.20 160.67 6,189.89 -7,408.04 2,542.39 7,789.32 0.00 0.00 0.00 10,900.00 64.20 160.67 6,233.41 -7,493.00 2,572.18 7,878.92 0.00 0.00 0.00 11,000.00 64.20 160.67 6,276.94 -7,577.96 2,601.97 7,968.52 0.00 0.00 0.00 11,100.00 64.20 160.67 6,320.46 -7,662.92 2,631.77 8,058.12 0.00 0.00 0.00 11,200.00 64.20 160.67 6,363.99 -7,747.88 2,661.56 8,147.71 0.00 0.00 0.00 11,300.00 64.20 160.67 6,407.51 -7,832.83 2,691.36 8,237.31 0.00 0.00 0.00 11,400.00 64.20 160.67 6,451.04 -7,917.79 2,721.15 8,326.91 0.00 0.00 0.00 11,500.00 64.20 160.67 6,494.56 -8,002.75 2,750.95 8,416.51 0.00 0.00 0.00 11,600.00 64.20 160.67 6,538.09 -8,087.71 2,780.74 8,506.11 0.00 0.00 0.00 11,700.00 64.20 160.67 6,581.62 -8,172.66 2,810.53 8,595.71 0.00 0.00 0.00 11,800.00 64.20 160.67 6,625.14 -8,257.62 2,840.33 8,685.31 0.00 0.00 0.00 11,900.00 64.20 160.67 6,668.67 -8,342.58 2,870.12 8,774.91 0.00 0.00 0.00 12,000.00 64.20 160.67 6,712.19 -8,427.54 2,899.92 8,864.51 0.00 0.00 0.00 12,100.00 64.20 160.67 6,755.72 -8,512.50 2,929.71 8,954.11 0.00 0.00 0.00 12,200.00 64.20 160.67 6,799.24 -8,597.45 2,959.51 9,043.71 0.00 0.00 0.00 12,300.00 64.20 160.67 6,842.77 -8,682.41 2,989.30 9,133.30 0.00 0.00 0.00 7/24/2019 12:34:13PM Page 6 COMPASS 5000.14 Build 85H K a. ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-26 (11 C) Wellbore: CD5-26 Design: CD5-26 wp07 Planned Survey Well Plan: CD5-26 (11 C) - Slot 26 TVD Reference: Measured MD Reference: Plan D25 @ 74.50usft (025) Depth Inclination Azimuth (usft) (°) (°) 12,400.00 64.20 160.67 12,500.00 64.20 160.67 12,600.00 64.20 160.67 12,700.00 64.20 160.67 12,800.00 64.20 160.67 12,900.00 64.20 160.67 12,972.55 64.20 160.67 FCS - Top 0.00 6,973.35 13,000.00 64.20 160.67 13,100.00 64.20 160.67 13,200.00 64.20 160.67 13,245.95 64.20 160.67 Kalubik 7,060.40 -9,107.20 13,300.00 64.20 160.67 13,400.00 64.20 160.67 13,500.00 64.20 160.67 13,510.16 64.20 160.67 Kup C -9,253.79 3,189.68 13,521.65 64.20 160.67 LCU 7,147.45 -9,277.12 13,579.53 64.20 160.67 Start 3°/100' DLS, -32.65° TF, for 529.79' 13,600.00 64.20 160.67 13,610.12 64.20 160.67 13,700.00 66.49 159.11 13,800.00 69.06 157.44 13,900.00 71.64 155.82 14,000.00 74.24 154.25 14,092.42 76.65 152.83 Alp C -9,531.99 3,287.24 14,100.00 76.85 152.72 14,109.31 77.09 152.58 Adjust TF to 0°, for 200' 10,118.89 14,147.56 78.09 152.00 14,152.18 78.23 152.00 UJU 0.00 0.00 14,200.00 79.67 152.00 14,300.00 82.67 152.00 14,309.31 82.95 152.00 Hold for 933' 3,353.28 10,227.89 14,347.56 84.09 152.00 14,400.00 84.09 152.00 14,500.00 84.09 152.00 14,600.00 84.09 152.00 14,700.00 84.09 152.00 14,800.00 84.09 152.00 14,900.00 84.09 152.00 15,000.00 84.09 152.00 15,100.00 84.09 152.00 15,200.00 84.09 152.00 15, 242.31 84.09 152.00 enc„nf Tc +r, n^ f., 9n• 10,480.96 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: CD5-26 (11 C) - Slot 26 TVD Reference: Plan D25 @ 74.50usft (D25) MD Reference: Plan D25 @ 74.50usft (025) North Reference: True Survey Calculation Method: Minimum Curvature Vertical -10,433.38 3,677.19 Vertical Dogleg Build Turn Depth +N/ -S +E/.W Section Rate Rate Rate (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 6,886.30 -8,767.37 3,019.09 9,222.90 0.00 0.00 0.00 6,929.82 -8,852.33 3,048.89 9,312.50 0.00 0.00 0.00 6,973.35 -8,937.28 3,078.68 9,402.10 0.00 0.00 0.00 7,016.87 -9,022.24 3,108.48 9,491.70 0.00 0.00 0.00 7,060.40 -9,107.20 3,138.27 9,581.30 0.00 0.00 0.00 7,103.92 -9,192.16 3,168.07 9,670.90 0.00 0.00 0.00 7,135.50 -9,253.79 3,189.68 9,735.90 0.00 0.00 0.00 7,147.45 -9,277.12 3,197.86 9,760.50 0.00 0.00 0.00 7,190.97 -9,362.07 3,227.65 9,850.10 0.00 0.00 0.00 7,234.50 -9,447.03 3,257.45 9,939.70 0.00 0.00 0.00 7,254.50 -9,486.07 3,271.14 9,980.87 0.00 0.00 0.00 7,278.03 -9,531.99 3,287.24 10,029.30 0.00 0.00 0.00 7,321.55 -9,616.95 3,317.04 10,118.89 0.00 0.00 0.00 7,365.08 -9,701.90 3,346.83 10,208.49 0.00 0.00 0.00 7,369.50 -9,710.54 3,349.86 10,217.60 0.00 0.00 0.00 7,374.50 -9,720.30 3,353.28 10,227.89 0.00 0.00 0.00 7,399.69 -9,769.47 3,370.53 10,279.75 0.00 0.00 0.00 7,408.60 -9,786.86 3,376.63 10,298.09 0.00 0.00 0.00 7,413.01 -9,795.46 3,379.64 10,307.16 0.00 0.00 0.00 7,450.50 -9,872.16 3,407.73 10,388.55 3.00 2.55 -1.74 7,488.32 -9,958.14 3,442.00 10,480.96 3.00 2.57 -1.67 7,521.95 -10,044.57 3,479.36 10,575.09 3.00 2.58 -1.62 7,551.28 -10,131.23 3,519.72 10,670.68 3.00 2.60 -1.57 7,574.50 -10,211.30 3,559.57 10,760.10 3.00 2.61 -1.53 7,576.24 -10,217.86 3,562.95 10,767.47 3.00 2.61 -1.51 7,578.34 -10,225.92 3,567.12 10,776.53 3.00 2.61 -1.51 7,586.55 -10,258.99 3,584.48 10,813.84 3.00 2.62 -1.50 7,587.50 -10,262.98 3,586.61 10,818.36 3.00 3.00 0.00 7,596.67 -10,304.42 3,608.64 10,865.22 3.00 3.00 0.00 7,612.02 -10,391.67 3,655.02 10,963.89 3.00 3.00 0.00 7,613.18 -10,399.82 3,659.35 10,973.11 3.00 3.00 0.00 7,617.50 -10,433.38 3,677.19 11,011.06 3.00 3.00 0.00 7,622.90 -10,479.44 3,701.68 11,063.15 0.00 0.00 0.00 7,633.19 -10,567.27 3,748.37 11,162.48 0.00 0.00 0.00 7,643.48 -10,655.10 3,795.06 11,261.80 0.00 0.00 0.00 7,653.76 -10,742.92 3,841.75 11,361.13 0.00 0.00 0.00 7,664.05 -10,830.75 3,888.45 11,460.46 0.00 0.00 0.00 7,674.34 -10,918.58 3,935.14 11,559.79 0.00 0.00 0.00 7,684.63 -11,006.41 3,981.83 11,659.11 0.00 0.00 0.00 7,694.92 -11,094.24 4,028.52 11,758.44 0.00 0.00 0.00 7,705.21 -11,182.07 4,075.21 11,857.77 0.00 0.00 0.00 7,709.57 -11,219.23 4,094.97 11,899.80 0.00 0.00 0.00 7/24/2019 12:34:13PM Page 7 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: CD5-26 (11 C) - Slot 26 Company: ConocoPhillips Alaska Inc WNS TVD Reference: Plan D25 @ 74.50usft (D25) Project: Western North Slope MD Reference: Plan D25 @ 74.50usft (D25) Site: CD5 Alpine West Pad North Reference: True Well: Plan: CD5-26 (11C) Survey Calculation Method: Minimum Curvature Wellbore: CD5-26 Vertical Design: CD5-26 wp07 Vertical Dogleg 7/24/2019 12:34 13PM Page 8 COMPASS 5000.14 Build 85H Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (1) (1) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) 15,262.31 84.09 152.00 7,711.62 -11,236.80 4,104.31 11,919.66 0.00 0.00 0.00 Start 0.56°/100' DLS, -0.08° TF, for 514.51' 15,280.56 84.09 152.00 7,713.50 -11,252.82 4,112.83 11,937.78 0.00 0.00 0.00 7S/8 x 9-7/8 by 11 15,300.00 84.09 152.00 7,715.50 -11,269.90 4,121.90 11,957.10 0.00 0.00 0.00 15,300.56 84.09 152.00 7,715.56 -11,270.39 4,122.16 11,957.65 0.00 0.00 0.00 15,400.00 84.66 152.00 7,725.31 -11,357.77 4,168.62 12,056.47 0.56 0.56 0.00 15,500.00 85.22 152.00 7,734.13 -11,445.73 4,215.38 12,155.94 0.56 0.56 0.00 15,600.00 85.79 152.00 7,741.97 -11,533.75 4,262.18 12,255.49 0.56 0.56 0.00 15,700.00 86.35 152.00 7,748.83 -11,621.84 4,309.01 12,355.11 0.56 0.56 0.00 15,776.82 86.78 152.00 7,753.43 -11,689.54 4,345.01 12,431.68 0.56 0.56 0.00 Hold for 350' 15,800.00 86.91 152.00 7,754.70 -11,709.98 4,355.88 12,454.80 0.56 0.56 0.00 15,815.06 87.00 152.00 7,755.50 -11,723.26 4,362.94 12,469.82 0.56 0.56 0.00 15,900.00 87.00 152.00 7,759.95 -11,798.15 4,402.76 12,554.52 0.00 0.00 0.00 16,000.00 87.00 152.00 7,765.18 -11,886.33 4,449.64 12,654.24 0.00 0.00 0.00 16,025.25 87.00 152.00 7,766.50 -11,908.59 4,461.48 12,679.41 0.00 0.00 0.00 Alp A 16,100.00 87.00 152.00 7,770.41 -11,974.50 4,496.53 12,753.96 0.00 0.00 0.00 16,126.82 87.00 152.00 7,771.82 -11,998.15 4,509.10 12,780.70 0.00 0.00 0.00 Start 1°/100' DLS, -2.08° TF, for 269.41' 16,165.07 87.00 152.00 7,773.82 -12,031.87 4,527.03 12,818.84 0.00 0.00 0.00 16,200.00 87.35 151.99 7,775.54 -12,062.68 4,543.42 12,853.68 1.00 1.00 -0.04 16,300.00 88.35 151.95 7,779.29 -12,150.88 4,590.38 12,953.47 1.00 1.00 -0.04 16,396.23 89.31 151.92 7,781.26 -12,235.77 4,635.64 13,049.53 1.00 1.00 -0.04 Hold for 17299.77' 16,400.00 89.35 151.91 7,781.30 -12,239.10 4,637.42 13,053.29 1.00 1.00 -0.04 16,434.47 89.69 151.90 7,781.59 -12,269.51 4,653.65 13,087.71 1.00 1.00 -0.04 16,500.00 89.69 151.90 7,781.94 -12,327.32 4,684.51 13,153.14 0.00 0.00 0.00 16,600.00 89.69 151.90 7,782.48 -12,415.53 4,731.61 13,252.99 0.00 0.00 0.00 16,700.00 89.69 151.90 7,783.02 -12,503.75 4,778.70 13,352.83 0.00 0.00 0.00 16,800.00 89.69 151.90 7,783.56 -12,591.96 4,825.80 13,452.68 0.00 0.00 0.00 16,900.00 89.69 151.90 7,784.09 -12,680.17 4,872.90 13,552.53 0.00 0.00 0.00 17,000.00 89.69 151.90 7,784.63 -12,768.39 4,919.99 13,652.37 0.00 0.00 0.00 17,100.00 89.69 151.90 7,785.17 -12,856.60 4,967.09 13,752.22 0.00 0.00 0.00 17,200.00 89.69 151.90 7,785.70 -12,944.81 5,014.19 13,852.07 0.00 0.00 0.00 17,300.00 89.69 151.90 7,786.24 -13,033.03 5,061.28 13,951.91 0.00 0.00 0.00 17,400.00 89.69 151.90 7,786.78 -13,121.24 5,108.38 14,051.76 0.00 0.00 0.00 17,500.00 89.69 151.90 7,787.31 -13,209.45 5,155.48 14,151.61 0.00 0.00 0.00 17,600.00 89.69 151.90 7,787.85 -13,297.67 5,202.57 14,251.45 0.00 0.00 0.00 17,700.00 89.69 151.90 7,788.39 -13,385.88 5,249.67 14,351.30 0.00 0.00 0.00 17,800.00 89.69 151.90 7,788.93 -13,474.09 5,296.77 14,451.15 0.00 0.00 0.00 17,900.00 89.69 151.90 7,789.46 -13,562.31 5,343.86 14,550.99 0.00 0.00 0.00 18,000.00 89.69 151.90 7,790.00 -13,650.52 5,390.96 14,650.84 0.00 0.00 0.00 18,100.00 89.69 151.90 7,790.54 -13,738.73 5,438.06 14,750.69 0.00 0.00 0.00 18,200.00 89.69 151.90 7,791.07 -13,826.95 5,485.15 14,850.53 0.00 0.00 0.00 18,300.00 89.69 151.90 7,791.61 -13,915.16 5,532.25 14,950.38 0.00 0.00 0.00 18,400.00 89.69 151.90 7,792.15 -14,003.37 5,579.35 15,050.23 0.00 0.00 0.00 18,500.00 89.69 151.90 7,792.69 -14,091.59 5,626.44 15,150.07 0.00 0.00 0.00 18,600.00 89.69 151.90 7,793.22 -14,179.80 5,673.54 15,249.92 0.00 0.00 0.00 18,700.00 89.69 151.90 7,793.76 -14,268.01 5,720.64 15,349.76 0.00 0.00 0.00 18,800.00 89.69 151.90 7,794.30 -14,356.23 5,767.73 15,449.61 0.00 0.00 0.00 18,900.00 89.69 151.90 7,794.83 -14,444.44 5,814.83 15,549.46 0.00 0.00 0.00 7/24/2019 12:34 13PM Page 8 COMPASS 5000.14 Build 85H r ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: CD5-26 (11 C) - Slot 26 Company: ConocoPhillips Alaska Inc WNS TVD Reference: Plan D25 @ 74.50usft (D25) Project. Western North Slope MD Reference: Plan D25 @ 74.50usft (D25) Site: CD5 Alpine West Pad North Reference: True Well: Plan: CD5-26 (11C) Survey Calculation Method: Minimum Curvature Wellbore: CD5-26 Azimuth Depth Design: CD5-26 wp07 Section Rate Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (`/t00usft) 19,000.00 89.69 151.90 7,795.37 -14,532.65 5,861.93 15,649.30 0.00 0.00 0.00 19,100.00 89.69 151.90 7,795.91 -14,620.87 5,909.02 15,749.15 0.00 0.00 0.00 19,200.00 89.69 151.90 7,796.44 -14,709.08 5,956.12 15,849.00 0.00 0.00 0.00 19,300.00 89.69 151.90 7,796.98 -14,797.30 6,003.22 15,948.84 0.00 0.00 0.00 19,400.00 89.69 151.90 7,797.52 -14,885.51 6,050.31 16,048.69 0.00 0.00 0.00 19,500.00 89.69 151.90 7,798.06 -14,973.72 6,097.41 16,148.54 0.00 0.00 0.00 19,600.00 89.69 151.90 7,798.59 -15,061.94 6,144.51 16,248.38 0.00 0.00 0.00 19,700.00 89.69 151.90 7,799.13 -15,150.15 6,191.60 16,348.23 0.00 0.00 0.00 19,800.00 89.69 151.90 7,799.67 -15,238.36 6,238.70 16,448.08 0.00 0.00 0.00 19,900.00 89.69 151.90 7,800.20 -15,326.58 6,285.80 16,547.92 0.00 0.00 0.00 20,000.00 89.69 151.90 7,800.74 -15,414.79 6,332.89 16,647.77 0.00 0.00 0.00 20,100.00 89.69 151.90 7,801.28 -15,503.00 6,379.99 16,747.62 0.00 0.00 0.00 20,200.00 89.69 151.90 7,801.82 -15,591.22 6,427.09 16,847.46 0.00 0.00 0.00 20,300.00 89.69 151.90 7,802.35 -15,679.43 6,474.18 16,947.31 0.00 0.00 0.00 20,400.00 89.69 151.90 7,802.89 -15,767.64 6,521.28 17,047.16 0.00 0.00 0.00 20,500.00 89.69 151.90 7,803.43 -15,855.86 6,568.38 17,147.00 0.00 0.00 0.00 20,600.00 89.69 151.90 7,803.96 -15,944.07 6,615.47 17,246.85 0.00 0.00 0.00 20,700.00 89.69 151.90 7,804.50 -16,032.28 6,662.57 17,346.70 0.00 0.00 0.00 20,800.00 89.69 151.90 7,805.04 -16,120.50 6,709.67 17,446.54 0.00 0.00 0.00 20,900.00 89.69 151.90 7,805.57 -16,208.71 6,756.76 17,546.39 0.00 0.00 0.00 21,000.00 89.69 151.90 7,806.11 -16,296.92 6,803.86 17,646.24 0.00 0.00 0.00 21,100.00 89.69 151.90 7,806.65 -16,385.14 6,850.96 17,746.08 0.00 0.00 0.00 21,200.00 89.69 151.90 7,807.19 -16,473.35 6,898.05 17,845.93 0.00 0.00 0.00 21,300.00 89.69 151.90 7,807.72 -16,561.56 6,945.15 17,945.77 0.00 0.00 0.00 21,400.00 89.69 151.90 7,808.26 -16,649.78 6,992.25 18,045.62 0.00 0.00 0.00 21,500.00 89.69 151.90 7,808.80 -16,737.99 7,039.34 18,145.47 0.00 0.00 0.00 21,600.00 89.69 151.90 7,809.33 -16,826.20 7,086.44 18,245.31 0.00 0.00 0.00 21,700.00 89.69 151.90 7,809.87 -16,914.42 7,133.54 18,345.16 0.00 0.00 0.00 21,800.00 89.69 151.90 7,810.41 -17,002.63 7,180.63 18,445.01 0.00 0.00 0.00 21,900.00 89.69 151.90 7,810.94 -17,090.84 7,227.73 18,544.85 0.00 0.00 0.00 22,000.00 89.69 151.90 7,811.48 -17,179.06 7,274.83 18,644.70 0.00 0.00 0.00 22,100.00 89.69 151.90 7,812.02 -17,267.27 7,321.92 18,744.55 0.00 0.00 0.00 22,200.00 89.69 151.90 7,812.56 -17,355.49 7,369.02 18,844.39 0.00 0.00 0.00 22,300.00 89.69 151.90 7,813.09 -17,443.70 7,416.12 18,944.24 0.00 0.00 0.00 22,400.00 89.69 151.90 7,813.63 -17,531.91 7,463.21 19,044.09 0.00 0.00 0.00 22,500.00 89.69 151.90 7,814.17 -17,620.13 7,510.31 19,143.93 0.00 0.00 0.00 22,600.00 89.69 151.90 7,814.70 -17,708.34 7,557.41 19,243.78 0.00 0.00 0.00 22,700.00 89.69 151.90 7,815.24 -17,796.55 7,604.50 19,343.63 0.00 0.00 0.00 22,800.00 89.69 151.90 7,815.78 -17,884.77 7,651.60 19,443.47 0.00 0.00 0.00 22,900.00 89.69 151.90 7,816.32 -17,972.98 7,698.70 19,543.32 0.00 0.00 0.00 23,000.00 89.69 151.90 7,816.85 -18,061.19 7,745.79 19,643.17 0.00 0.00 0.00 23,100.00 89.69 151.90 7,817.39 -18,149.41 7,792.89 19,743.01 0.00 0.00 0.00 23,200.00 89.69 151.90 7,817.93 -18,237.62 7,839.99 19,842.86 0.00 0.00 0.00 23,300.00 89.69 151.90 7,818.46 -18,325.83 7,887.08 19,942.71 0.00 0.00 0.00 23,400.00 89.69 151.90 7,819.00 -18,414.05 7,934.18 20,042.55 0.00 0.00 0.00 23,500.00 89.69 151.90 7,819.54 -18,502.26 7,981.28 20,142.40 0.00 0.00 0.00 23,600.00 89.69 151.90 7,820.07 -18,590.47 8,028.38 20,242.25 0.00 0.00 0.00 23,700.00 89.69 151.90 7,820.61 -18,678.69 8,075.47 20,342.09 0.00 0.00 0.00 23,800.00 89.69 151.90 7,821.15 -18,766.90 8,122.57 20,441.94 0.00 0.00 0.00 23,900.00 89.69 151.90 7,821.69 -18,855.11 8,169.67 20,541.79 0.00 0.00 0.00 24,000.00 89.69 151.90 7,822.22 -18,943.33 8,216.76 20,641.63 0.00 0.00 0.00 24,100.00 89.69 151.90 7,822.76 -19,031.54 8,263.86 20,741.48 0.00 0.00 0.00 24,200.00 89.69 151.90 7,823.30 -19,119.75 8,310.96 20,841.32 0.00 0.00 0.00 24,300.00 89.69 151.90 7,823.83 -19,207.97 8,358.05 20,941.17 0.00 0.00 0.00 7/24/2019 12:34:13PM Page 9 COMPASS 5000.14 Build 85H V-11 ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: CD5-26 (11 C) - Slot 26 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Plan D25 @ 74.50usft (1325) Project: Western North Slope MD Reference: Plan 025 @ 74.50usft (1325) Site: CD5 Alpine West Pad North Reference: True Well: Plan: CD5-26 (11C) Survey Calculation Method: Minimum Curvature Wellbore: CD5-26 (°/100usft) 24,400.00 Design: CD5-26 wp07 7,824.37 -19,296.18 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) ('HOOusft) (°/100usft) 24,400.00 89.69 151.90 7,824.37 -19,296.18 8,405.15 21,041.02 0.00 0.00 0.00 24,500.00 89.69 151.90 7,824.91 -19,384.39 8,452.25 21,140.86 0.00 0.00 0.00 24,600.00 89.69 151.90 7,825.45 -19,472.61 8,499.34 21,240.71 0.00 0.00 0.00 24,700.00 89.69 151.90 7,825.98 -19,560.82 8,546.44 21,340.56 0.00 0.00 0.00 24,800.00 89.69 151.90 7,826.52 -19,649.03 8,593.54 21,440.40 0.00 0.00 0.00 24,900.00 89.69 151.90 7,827.06 -19,737.25 8,640.63 21,540.25 0.00 0.00 0.00 25,000.00 89.69 151.90 7,827.59 -19,825.46 8,687.73 21,640.10 0.00 0.00 0.00 25,100.00 89.69 151.90 7,828.13 -19,913.68 8,734.83 21,739.94 0.00 0.00 0.00 25,200.00 89.69 151.90 7,828.67 -20,001.89 6,781.92 21,839.79 0.00 0.00 0.00 25,300.00 89.69 151.90 7,829.20 -20,090.10 8,829.02 21,939.64 0.00 0.00 0.00 25,400.00 89.69 151.90 7,829.74 -20,178.32 8,876.12 22,039.48 0.00 0.00 0.00 25,500.00 89.69 151.90 7,830.28 -20,266.53 8,923.21 22,139.33 0.00 0.00 0.00 25,600.00 89.69 151.90 7,830.82 -20,354.74 8,970.31 22,239.18 0.00 0.00 0.00 25,700.00 89.69 151.90 7,831.35 -20,442.96 9,017.41 22,339.02 0.00 0.00 0.00 25,800.00 89.69 151.90 7,831.89 -20,531.17 9,064.50 22,438.87 0.00 0.00 0.00 25,900.00 89.69 151.90 7,832.43 -20,619.38 9,111.60 22,538.72 0.00 0.00 0.00 26,000.00 89.69 151.90 7,832.96 -20,707.60 9,158.70 22,638.56 0.00 0.00 0.00 26,100.00 89.69 151.90 7,833.50 -20,795.81 9,205.79 22,738.41 0.00 0.00 0.00 26,200.00 89.69 151.90 7,834.04 -20,884.02 9,252.89 22,838.26 0.00 0.00 0.00 26,300.00 89.69 151.90 7,834.57 -20,972.24 9,299.99 22,938.10 0.00 0.00 0.00 26,400.00 89.69 151.90 7,835.11 -21,060.45 9,347.08 23,037.95 0.00 0.00 0.00 26,500.00 89.69 151.90 7,835.65 -21,148.66 9,394.18 23,137.80 0.00 0.00 0.00 26,600.00 89.69 151.90 7,836.19 -21,236.88 9,441.28 23,237.64 0.00 0.00 0.00 26,700.00 89.69 151.90 7,836.72 -21,325.09 9,488.37 23,337.49 0.00 0.00 0.00 26,800.00 89.69 151.90 7,837.26 -21,413.30 9,535.47 23,437.34 0.00 0.00 0.00 26,900.00 89.69 151.90 7,837.80 -21,501.52 9,582.57 23,537.18 0.00 0.00 0.00 27,000.00 89.69 151.90 7,838.33 -21,589.73 9,629.66 23,637.03 0.00 0.00 0.00 27,100.00 89.69 151.90 7,838.87 -21,677.94 9,676.76 23,736.87 0.00 0.00 0.00 27,200.00 89.69 151.90 7,839.41 -21,766.16 9,723.86 23,836.72 0.00 0.00 0.00 27,300.00 89.69 151.90 7,839.95 -21,854.37 9,770.95 23,936.57 0.00 0.00 0.00 27,400.00 89.69 151.90 7,840.48 -21,942.58 9,818.05 24,036.41 0.00 0.00 0.00 27,500.00 89.69 151.90 7,841.02 -22,030.80 9,865.15 24,136.26 0.00 0.00 0.00 27,600.00 89.69 151.90 7,841.56 -22,119.01 9,912.24 24,236.11 0.00 0.00 0.00 27,700.00 89.69 151.90 7,842.09 -22,207.22 9,959.34 24,335.95 0.00 0.00 0.00 27,800.00 89.69 151.90 7,842.63 -22,295.44 10,006.44 24,435.80 0.00 0.00 0.00 27,900.00 89.69 151.90 7,843.17 -22,383.65 10,053.53 24,535.65 0.00 0.00 0.00 28,000.00 89.69 151.90 7,843.70 -22,471.87 10,100.63 24,635.49 0.00 0.00 0.00 28,100.00 89.69 151.90 7,844.24 -22,560.08 10,147.73 24,735.34 0.00 0.00 0.00 28,200.00 89.69 151.90 7,844.78 -22,648.29 10,194.82 24,835.19 0.00 0.00 0.00 28,300.00 89.69 151.90 7,845.32 -22,736.51 10,241.92 24,935.03 0.00 0.00 0.00 28,400.00 89.69 151.90 7,845.85 -22,824.72 10,289.02 25,034.88 0.00 0.00 0.00 28,500.00 89.69 151.90 7,846.39 -22,912.93 10,336.11 25,134.73 0.00 0.00 0.00 28,600.00 89.69 151.90 7,846.93 -23,001.15 10,383.21 25,234.57 0.00 0.00 0.00 28,700.00 89.69 151.90 7,847.46 -23,089.36 10,430.31 25,334.42 0.00 0.00 0.00 28,800.00 89.69 151.90 7,848.00 -23,177.57 10,477.40 25,434.27 0.00 0.00 0.00 28,900.00 89.69 151.90 7,848.54 -23,265.79 10,524.50 25,534.11 0.00 0.00 0.00 29,000.00 89.69 151.90 7,849.08 -23,354.00 10,571.60 25,633.96 0.00 0.00 0.00 29,100.00 89.69 151.90 7,849.61 -23,442.21 10,618.69 25,733.81 0.00 0.00 0.00 29,200.00 89.69 151.90 7,850.15 -23,530.43 10,665.79 25,833.65 0.00 0.00 0.00 29,300.00 89.69 151.90 7,850.69 -23,618.64 10,712.89 25,933.50 0.00 0.00 0.00 29,400.00 89.69 151.90 7,851.22 -23,706.85 10,759.98 26,033.35 0.00 0.00 0.00 29,500.00 89.69 151.90 7,851.76 -23,795.07 10,807.08 26,133.19 0.00 0.00 0.00 29,600.00 89.69 151.90 7,852.30 -23,883.28 10,854.18 26,233.04 0.00 0.00 0.00 7/24/2019 12:34:13PM Page 10 COMPASS 5000.14 Build 85H ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Plan: CD5-26 (11C) Wellbore: CD5-26 Design: CD5-26 wp07 local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Plan: CD5-26 (11 C) - Slot 26 Plan D25 @ 74.50usft (D25) Plan D25 @ 74.50usft (D25) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (°MOOusft) (°/100usft) (°/100usft) 29,800.00 89.69 151.90 7,853.37 -24,059.71 10,948.37 26,432.73 0.00 0.00 0.00 29,900.00 89.69 151.90 7,853.91 -24,147.92 10,995.47 26,532.58 0.00 0.00 0.00 30,000.00 89.69 151.90 7,854.45 -24,236.13 11,042.56 26,632.42 0.00 0.00 0.00 30,100.00 89.69 151.90 7,854.98 -24,324.35 11,089.66 26,732.27 0.00 0.00 0.00 30,200.00 89.69 151.90 7,855.52 -24,412.56 11,136.76 26,832.12 0.00 0.00 0.00 30,300.00 89.69 151.90 7,856.06 -24,500.77 11,183.85 26,931.96 0.00 0.00 0.00 30,400.00 89.69 151.90 7,856.59 -24,588.99 11,230.95 27,031.81 0.00 0.00 0.00 30,500.00 89.69 151.90 7,857.13 -24,677.20 11,278.05 27,131.66 0.00 0.00 0.00 30,600.00 89.69 151.90 7,857.67 -24,765.41 11,325.14 27,231.50 0.00 0.00 0.00 30,700.00 89.69 151.90 7,858.20 -24,853.63 11,372.24 27,331.35 0.00 0.00 0.00 30,800.00 89.69 151.90 7,858.74 -24,941.84 11,419.34 27,431.20 0.00 0.00 0.00 30,900.00 89.69 151.90 7,859.28 -25,030.06 11,466.43 27,531.04 0.00 0.00 0.00 31,000.00 89.69 151.90 7,859.82 -25,118.27 11,513.53 27,630.89 0.00 0.00 0.00 31,100.00 89.69 151.90 7,860.35 -25,206.48 11,560.63 27,730.74 0.00 0.00 0.00 31,200.00 89.69 151.90 7,860.89 -25,294.70 11,607.72 27,830.58 0.00 0.00 0.00 31,300.00 89.69 151.90 7,861.43 -25,382.91 11,654.82 27,930.43 0.00 0.00 0.00 31,400.00 89.69 151.90 7,861.96 -25,471.12 11,701.92 28,030.28 0.00 0.00 0.00 31,500.00 89.69 151.90 7,862.50 -25,559.34 11,749.01 28,130.12 0.00 0.00 0.00 31,600.00 89.69 151.90 7,863.04 -25,647.55 11,796.11 28,229.97 0.00 0.00 0.00 31,700.00 89.69 151.90 7,863.58 -25,735.76 11,843.21 28,329.82 0.00 0.00 0.00 31,800.00 89.69 151.90 7,864.11 -25,823.98 11,890.30 28,429.66 0.00 0.00 0.00 31,900.00 89.69 151.90 7,864.65 -25,912.19 11,937.40 28,529.51 0.00 0.00 0.00 32,000.00 89.69 151.90 7,865.19 -26,000.40 11,984.50 28,629.36 0.00 0.00 0.00 32,100.00 89.69 151.90 7,865.72 -26,088.62 12,031.59 28,729.20 0.00 0.00 0.00 32,200.00 89.69 151.90 7,866.26 -26,176.83 12,078.69 28,829.05 0.00 0.00 0.00 32,300.00 89.69 151.90 7,866.80 -26,265.04 12,125.79 28,928.90 0.00 0.00 0.00 32,400.00 89.69 151.90 7,867.33 -26,353.26 12,172.88 29,028.74 0.00 0.00 0.00 32,500.00 89.69 151.90 7,867.87 -26,441.47 12,219.98 29,128.59 0.00 0.00 0.00 32,600.00 89.69 151.90 7,868.41 -26,529.68 12,267.08 29,228.44 0.00 0.00 0.00 32,700.00 89.69 151.90 7,868.95 -26,617.90 12,314.18 29,328.28 0.00 0.00 0.00 32,800.00 89.69 151.90 7,869.48 -26,706.11 12,361.27 29,428.13 0.00 0.00 0.00 32,900.00 89.69 151.90 7,870.02 -26,794.32 12,408.37 29,527.97 0.00 0.00 0.00 33,000.00 89.69 151.90 7,870.56 -26,882.54 12,455.47 29,627.82 0.00 0.00 0.00 33,100.00 89.69 151.90 7,871.09 -26,970.75 12,502.56 29,727.67 0.00 0.00 0.00 33,200.00 89.69 151.90 7,871.63 -27,058.96 12,549.66 29,827.51 0.00 0.00 0.00 33,300.00 89.69 151.90 7,872.17 -27,147.18 12,596.76 29,927.36 0.00 0.00 0.00 33,400.00 89.69 151.90 7,872.71 -27,235.39 12,643.85 30,027.21 0.00 0.00 0.00 33,500.00 89.69 151.90 7,873.24 -27,323.60 12,690.95 30,127.05 0.00 0.00 0.00 33,600.00 89.69 151.90 7,873.78 -27,411.82 12,738.05 30,226.90 0.00 0.00 0.00 33,696.00 89.69 151.90 7,874.29 -27,496.50 12,783.26 30,322.75 0.00 0.00 0.00 TD: 33696' MD, 7874.5' TVD -44/2 x 6-3/4 33,700.00 89.69 151.90 7,874.32 -27,500.03 12,785.14 30,326.75 0.00 0.00 0.00 33,734.24 89.69 151.90 7,874.50 -27,530.24 12,801.27 30,360.94 0.00 0.00 0.00 7/24/2019 12:34:13PM Page 11 COMPASS 5000.14 Build 85H ,., Conocophillips Database: EDT 14 Alaska Production Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc -NMS TVD Reference: Project: Western North Slope MD Reference: Site: CDs Alpine West Pad North Reference: Well: Plan: CD5-26 (11C) Survey Calculation Method: Wellbore: CD5-26 0.00 Design: CD5-26 wp07 -10,504.61 Design Targets plan misses target center by 37.20usft at 14425.23usft Target Name (7625.49 TVD, -10501.60 N, 3713.46 E) Circle (radius 100.00) hit/miss target Dip Angle Dip Dir. TVD +NI -S +El -W Shape (1) (1) (usft) (usft) (usft) CD5-26 Tgt C Intersecti[ 0.00 0.00 7,580.50 -10,433.38 3,677.19 plan misses target center by 36.80usft at 14343.38usft MD (7617.07 TVD, -10429.71 N, 3675.24 E) Circle (radius 100.00) (in) 2,335.52 2,264.00 10-3/4 x 13-1/2 10.750 13.500 CD5-26 Tgt Base C 0501 0.00 0.00 7,588.50 -10,504.61 3,715.94 plan misses target center by 37.20usft at 14425.23usft MD (7625.49 TVD, -10501.60 N, 3713.46 E) Circle (radius 100.00) C135-26 Tgt 01 TopC 07, 0.00 0.00 7,617.50 -10,433.38 3,677.19 plan hits target center Circle (radius 100.00) CD5-26 Tgt 02 B3 Int 07 0.00 0.00 7,713.50 -11,252.82 4,112.83 plan hits target center Circle (radius 100.00) CD5-26Tgt Top A05061 0.00 0.00 7,764.50 -11,729.78 4,369.51 plan misses target center by 8.95usft at 15824.36usft MD (7755.99 TVD, -11731.46 N, 4367.30 E) - Circle (radius 100.00) CD5-26 (11C -A) T02 TOE 0.00 0.00 7,874.50 -27,530.24 12,801.27 plan hits target center Circle (radius 100.00) CD5-26 (11C) T02 Toe 0 0.00 0.00 7,874.50 -27,530.24 12,801.27 plan hits target center Circle (radius 100.00) CD5-26 Updated Toe 05 0.00 0.00 7,874.50 -27,530.24 12,801.27 plan hits target center Circle (radius 100.00) CD5-26 Tgt 03 TD 0716 0.00 0.00 7,874.50 -27,530.24 12,801.27 plan hits target center Circle (radius 100.00) Casing Points ConocoPhillips Standard Proposal Report Well Plan: CD5-26 (11 C) - Slot 26 Plan D25 @ 74.50usft (D25) Plan D25 @ 74.50usft (D25) True Minimum Curvature Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,335.52 2,264.00 10-3/4 x 13-1/2 10.750 13.500 15,280.56 7,713.50 7-5/8 x 9-7/8 by l l 7.625 11.000 33,696.00 7,874.29 4-1/2 x 6-3/4 4.500 5.750 7/242019 12:34.13PM Page 12 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well Plan: CD5-26 (11 C) - Slot 26 Company: ConocoPhillips Alaska Inc WNS TVD Reference: Plan D25 @ 74.50usft (D25) Project: Western North Slope MD Reference: Plan D25 @ 74.50usft (D25) Site: CD5 Alpine West Pad North Reference: True Well: Plan: CD5-26 (11 C) Survey Calculation Method: Minimum Curvature Wellbore: CD5-26 C-30 0.00 Design: CD5-26 wp07 C-10 0.00 Formations Measured Vertical Vertical Dip Depth Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 1,402.90 1,399.00 Base Permfrosl 0.00 2,382.52 2,303.50 C-30 0.00 3,143.44 2,840.50 C-10 0.00 5,248.36 3,773.50 K-3 0.00 5,818.14 4,021.50 K-2 0.00 6,785.39 4,442.50 Alb 97 0.00 6,953.10 4,515.50 Sub 97 0.00 9,928.36 5,810.50 Alb 96 0.00 12,972.55 7,135.50 FCS - Top 0.00 13,245.95 7,254.50 Kalubik 0.00 13,510.16 7,369.50 Kup C 0.00 13,521.65 7,374.50 LCU 0.00 14,092.42 7,574.50 Alp C 0.00 14,152.18 7,587.50 UJU 0.00 16,025.25 7,766.50 AlpA 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +E/ -W (usft) (usft) (usft) (usft) Comment 750.00 750.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 165° TF, for 300' 1,050.00 1,049.69 -11.37 3.05 Start 2°/100' DLS, 0° TF, for 226.44' 1,276.44 1,274.50 -37.13 9.95 Hold for 101.25' 1,377.70 1,374.22 -54.07 14.49 Start 2.5°/100' DLS, 00 TF, for 872.18' 2,249.88 2,190.99 -335.37 89.86 Hold for 20' 2,269.88 2,208.19 -345.23 92.51 Start 3°/100' DLS, -7.01' TF, for 1125.99' 3,395.87 2,967.11 -1,117.69 336.40 Hold for 10183.66' 13,579.53 7,399.69 -9,769.47 3,370.53 Start 3°/100' DLS, -32.65° TF, for 529.79' 14,109.31 7,578.34 -10,225.92 3,567.12 Adjust TF to 0°, for 200' 14,309.31 7,613.18 -10,399.82 3,659.35 Hold for 933' 15,242.31 7,709.57 -11,219.23 4,094.97 Adjust TF to 0°, for 20' 15,262.31 7,711.62 -11,236.80 4,104.31 Start 0.56°/100' DLS, -0.08° TF, for 514.51' 15,776.82 7,753.43 -11,689.54 4,345.01 Hold for 350' 16,126.82 7,771.82 -11,998.15 4,509.10 Start 1°/100' DLS, -2.08° TF, for 269.41' 16,396.23 7,781.26 -12,235.77 4,635.64 Hold for 17299.77' 33,696.00 7,874.29 -27,496.50 12,783.26 TD: 33696' MD, 7874.5' TVD 7/24/2019 12:34:13PM Page 13 COMPASS 5000.14 Build 85H a Z 0 or or p 5u v CL m N VJ O m V n o m I N w o K Y b 0 + o p U 0 D o m O c 3 w Q� m M a y U c ID EN r, a CL ■- ■- C R O m LL W CL R v/ 5 m a i s d �, U ■,—w �, m y a m W A N N �. li t O to o� O y N !C D. p o O C Q.� ?� O i O C3o z °' a o �LL �0 N m o U � �./ N m m a = w Q N crj m O N U C Lh 0 to O ' v E z z c V � Z.) EL V V Q > � U) N F a' Co O w v7 C7 � n in r- CDCL 3 co N U 1 U r Ir W N L() U EL L O ^O^ CL O O N ci Q m E m O C N N w w N w w w w w w N w N w N N w w w w w m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m a o_ a a a a n a d a a s n_ a a a n_ a a s n. n. a s d a d a- 0 O O N 0 c m c m C m C m C m c m c m m C m C m m - _m m m m QNi m N _m ❑ � C ❑ N C ❑ � C ❑ � C ❑ � C ❑ � C ❑ � C ❑ � C ❑ N C ❑ m v m as a� m m v m m m m � as m v m m v as m v m m as m m m U W U U W U U W U U W U U W U U W U U W U U W U U W U U M M N a m m M M m M n m m O m m O m n m n O O O V V OI N n m OI m m W m m � V m � V N m V m m m N N M N W m u) m n 7 O 0 W m 0 (O 7 7 m d' O 61 OI m 01 OI m � N m n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 s O O o�, o o s o o s o s N o� 3 3n o sn sn o sn o o m o n 0 0 m n n m O N m O N )O n N N n N N m N N N N N O 01 O N N a M V N a N 30 30 N 30 30 3(J O m r m 0 m n m N M m n V m� IlJ m N )O r 7 7 m m n m m 0i m m m m OJ OR M V UJ m q � O m � O W n m N r m N V M m m V n n 3n n n o n n o in u� 3n sn m m rn m m rn 3n N N M M '- M � � N M Ol N O) 3T M O n O n sn m rn m m rn N cp N <O O N m 6J O r m N N m N N N N O N N O N )n m m N m 7 O n V V N V n N N m a N m M m M M m M M M 30 M n o o m o O) )O n m m n m M m M M N M m o m OJ O V N V M V t0 m V to m lt7 In m l(1 l[l m OI m tT m m n O m m m r m m m V n m V n m n O n f Of` V r V n )O M V rn rn m v � ry o (I! 0 co n O n o o v o v m n co m m m o� m m � m rn of m ai m c�i m m c�i m m n rn m n cD co c�i co rn m v n n sn r� n t� n r 2 n sn n w m o rn rn o co M Ol N m Ql M O n O n N! m O] cN m O] r N m r N m O N m QI O r m N N m N N � N N � Ol N N O N sn n )n sn ti )O m V N (O m N O) V T n d' V N V V N N m •7 N m V M m M M m M M M S M � N N t W C 0) % U 1 a m N Z A • d LL a d ' W L,� N m❑z Z Z N m❑ 0 0 0 d r r 7 r r r ❑❑ ❑❑❑ ❑❑❑ N ❑U a U U U ❑m� U UE OO6 ❑OrI ❑m� U? ❑ ❑ ❑ 1N U U U U U U U U U U U U U U U U U U ' 0 i •E ? 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Q- r N N N M M MtM� MtMtU U U MtMtMttNo mN mN Nto Nm Nm N Z` cV NN❑ttO OtoO ❑ to ❑ ❑ ❑ ❑ ❑ ❑ ❑ O ❑ O ❑ ❑ ❑ ❑ N % Q U U U U U U pp ap p� U U U X X X U U 0. a0 U m U U U U U U U Li a d U v,, a a n. v a v a a a,, , O N M d 2 J J J M M M M M M O V M M M to to to to m m C a U M O r E 4, to N N N M M M M M M M M M M M M M M M N N N M M M N N N N N to tq t[) tq til t() t!) t() ❑ ❑ ❑ t[) tfJ t[J tq tt) tf1 — — .- .- ter.. ter.. .— ��//�� d o e to to to to m 0❑❑ 0❑ O ❑❑❑ U U U ❑❑❑ 0❑ ❑ n n n m m m M •y� O m O❑ C 0 0 0 0❑ U V U :.ic.i U U U U N N N N N N N Z •a o a d ° U U U U U d d m In E ❑❑❑❑❑❑ ❑ O C p7 ZG N N N N N M M M M M M M M M M M M M M M M M M U U U U U U U V m d E A to td to to to 6 6 � to LA th tb to A to to to th to to tb to c c c c c c c m r O ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ in ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ m m m m m m m m U U U U U U U U U U U U U U U U U U U U U U U U a a a a a a a Q H K y 14 m O 7 LA m rn N m N bi 0 0 a c c c (HRf1 E @ c O '0 O '0 O c O O O O O U U% U U U UN U U U U U U U UE%aC pC aC N aT ryW N aaa0 LL LL L LL LL LL LL LL LL m c a) NN N a) N a) N a) a) w a) a) ti a) W m a1 a) a) a) a1 E U U Q U U U U [J U U U U U U U c c c c c c c c c c c E m m m m m m m 2 a) m v (D m w (D m v a) m m m m m am a c a c fl. @ c c n m@ `m `m N = m a = W a .0 a = a =a n a = a = W a) N a) a) Fu U U w U U w U U w U U w U U w U U w U U U U U m 10 W M 10 m m M W f� m 10 M N N N N I� M N M m W N N M W Vc u0 Cl N f- M CNr� VN WN M Im� �N CC!C11mW (m�0O W t M NV fm'- N CN t0 uVV m V m 1� O W V N N N _v LL U O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m o 0 o ui ui 0 0 0 0 0 0 o ui o 0 tri o 0 0 0 04 0 n O 10 O O O O (- 1 r- O n r- O n h 1n O 04 U) N Q S 10 mm M N m00 m O M V N m m f- M m M m N 0 0 M M R y j M M N M M �2 N M � O n m V m V m N to N CO 0 M W N O V O M 10 V m C n V N m V W W N m M fl O m 10 f� m m O W y 0 m N 1- n W m N N � � m � � f� � � N 04 N N .- Q Eu - m W m O O O 0 n u1 m m m ncny W i 00 0 > > > > > 3 3 3 n 'Dw 3 °01 n 3 ami O ❑ a) ;41� > > > > > > O O O O O O O N ❑ ❑ ❑ 1!1 In 1n ❑ n n n n n n 3 w w w Y 3 a o 0 1) m V 10 N 10 O N m IL aa O a 0 ❑ ❑ ❑ ❑ ❑ U U U U U In 'o h Of C N y LL y 0 0 0 `o m � p ❑ ❑ ❑ ❑ ❑ C E- 0 o 0 0 M M M M M M m 3 o (V (V N M M M W m o 0 0 N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N NN N N N N C,0 ❑ N N N a] a1 a) a3 N a] a3 a7 LL LL o_ LL a a s a a a a a7 L N a7 m a7 a a a a a a N a7 N N m d a LL a a a. N a a- 0 0 a c c c (HRf1 E @ c O '0 O '0 O c O O O O O U U% U U U UN U U U U U U U UE%aC pC aC N aT ryW N aaa0 LL LL L LL LL LL LL LL LL m c a) NN N a) N a) N a) a) w a) a) ti a) W m a1 a) a) a) a1 E U U Q U U U U [J U U U U U U U c c c c c c c c c c c E m m m m m m m 2 a) m v (D m w (D m v a) m m m m m am a c a c fl. @ c c n m@ `m `m N = m a = W a .0 a = a =a n a = a = W a) N a) a) Fu U U w U U w U U w U U w U U w U U w U U U U U m 10 W M 10 m m M W f� m 10 M N N N N I� M N M m W N N M W Vc u0 Cl N f- M CNr� VN WN M Im� �N CC!C11mW (m�0O W t M NV fm'- N CN t0 uVV m V m 1� O W V N N N _v LL U O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m o 0 o ui ui 0 0 0 0 0 0 o ui o 0 tri o 0 0 0 04 0 n O 10 O O O O (- 1 r- O n r- O n h 1n O 04 U) N Q S 10 mm M N m00 m O M V N m m f- M m M m N 0 0 M M R y j M M N M M �2 N M � O n m V m V m N to N CO 0 M W N O V O M 10 V m C n V N m V W W N m M fl O m 10 f� m m O W y 0 m N 1- n W m N N � � m � � f� � � N 04 N N .- Q Eu - LL] W O O W m O O N O O 10 O O m m m O M m m O m 10 O m m N m m m m m m 0 0 m V O LL) O O O n O n W O n m N m n m O M m N � m m r 10 M N M M c- N N N � � R W N I� W .-- m W O O W O V 10 10 V � N N N M V N 1A m 0 I� m m W O W m m N V 10 W O O W m O O N 0 0 10 O O m m m O M CR m O m 10 O m m N ID m m m m m 0 0 m V V V O V V O V W m V V M V W W 10 o in o 0 o r� o n W o 1n m in n v r� n m o M N M M ! N N N m W m O O O 0 n u1 m m m ncny i V M V W O > > > > > 3 3 3 n 'Dw 3 °01 n 3 ami O ❑ a) > > > > > > > > > > > O O O O O O O N ❑ ❑ ❑ 1!1 In 1n ❑ n n n n n n O c c c m m O p 3 a o 0 1) m V 10 N 10 O N m m rn 3 3 3 O E d O 1-� O O N m m O O M ❑ ❑ ❑ ❑ ❑ U U U U U N N M M M N N N M M M M M M M M M c I(1 A N N ❑ ❑ ❑ ❑ ❑ ❑ C N y LL y w to th U U U U U U oc � p ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0 n U U U U U U M M M M M M 3 o (V (V N M M M W m o 0 0 ep a N Qf M a N t m 10 m m m V M V W m C,0 ❑ n a m m M M M E w d W � LL. N YI X � s p � U U m m m m m m m m m o U O Q m v v v z a, QC O = m U E Z W O m - N N N M M M M M M M M M V V V 10 10 10 M M M M M M LL] W O O W m O O N O O 10 O O m m m O M m m O m 10 O m m N m m m m m m 0 0 m V O LL) O O O n O n W O n m N m n m O M m N � m m r 10 M N M M c- N N N � � R W N I� W .-- m W O O W O V 10 10 V � N N N M V N 1A m 0 I� m m W O W m m N V 10 W O O W m O O N 0 0 10 O O m m m O M CR m O m 10 O m m N ID m m m m m 0 0 m V V V O V V O V W m V V M V W W 10 o in o 0 o r� o n W o 1n m in n v r� n m o M N M M ! N N N rp u� iq ncny n > > > > > 3 3 3 n 'Dw 3 °01 n 3 ami O ❑ a) > > > > > > > > > > > O O O O O O O W ❑ ❑ ❑ 1!1 In 1n ❑ n n n n n n ❑ V U m c c c m m Q u1 3 a o E m rn 3 3 3 M M M 001 N Uz ❑ ❑ ❑ ❑ ❑ U U U U U N N M M M N N N M M M M M M M M M c I(1 A N N ❑ ❑ ❑ ❑ ❑ ❑ C N y LL y 6 6 to th U U U U U U o a m `o ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ U U U U U U U U U U U M M M M M M d W W (V (V N M M M 1n 0 0 0 0 N N M M M M M M M M M C,0 ❑ n a E U U U U U U U U U U U im N N N ? U U m m m m m m m m m > > > >>> L U o m v v v T m m m v� ul N QC O = v v V Z W O W W N N M M M N N N M M M M M M M M M V V V 10 10 10 M M M M M M d °i — 10 m ❑ ❑ ❑ O ❑ 10 10 10 b w m ❑ ❑ ❑ O ❑ ❑ w 10 10 10 u'1 ❑ ❑ ❑ ❑ ❑ ❑ w U U U U U U U U U U U U U U U U U v c a Z c c c c c c c c c c c c c c c c U « p a] a1 al a3 al al a1 al al a5 a] a1 al al a3 M a3 � W a5 al u a a a a s a a a a a a a a a a a a A d U r er m M rp u� iq > > > O n 3 3 3 n 'Dw 3 °01 n 3 ami O ❑ ❑ ❑ ❑ n � U _ U M M M J W ❑ ❑ ❑ 1!1 In 1n ❑ U U U ❑ ❑ U U ❑ V U m c c c m m Q u1 o i 0 0 0 0 0 3 3 3 3 3 ro ro m m Co N N N N X 0 0 0 0 U U U U U 0 0 0 o v O O O O N Fp WO O O O M Cl! n N n r 0 0 0 0 0 ro o 0 0 0 0 0 0 0 N 0 N N N LL N N �2 t2 U t4 C � N n N V1 N O f6 N 12:4$, J W y 24 2019 CD5-26 wp07 300 c 0 ,1200 U) m c a� U 0 a� X100 Q) U Ladder View 0 5000 10000 15000 20000 25000 30000 Measured Depth SURVEY PROGRAM CASING DETAILS pth From Depth To Survey/Plan Tool T D MD Nam 40.80 2200.00 CD5-26 wp07 (CD5-26) GYD-GC-SS 2264.00 2335.52 10-3/4 x 13-1/2 2200.00 3700.00 CD5-26 wp07 (CD5-26) MWD OWSG 7713.50 15280.567-5/8 x 9-7/8 by 11 2200.0015200.00 CD5-26 wp07 (CD5-26) MWD+IFR2+SAG+MS 7874.29 33696.00 4-1/2 x 6-3/4 15200.00 16700.00 CD5-26 wp07 (CD5-26) MWD OWSG 15200.00 33734.24 CD5-26 wp07 (CD5-26) MWD+IFR2+SAG+MS co J m a NM d N J O_ N 3 N N U o co UI LO o LO 60 N CJ 0 0 c 0 ro 0- 0 co 0 S30- 0 ci30 0 1 0 550 1100 1650 Partial Measured Depth 2200 2750 L MID U M > O CY a 3 a rn NN U-) C,o U U � U ��pp (moo NCvj i TO m. O o o U m U U 0 6� U 00 T -i U U Ojinnlive N "� 0 O o o 00010 N U U `O r U o 0 U U 'T UO Ono O N > ti =3 ^ O Oo O o O O M > LO U 0 > O O 00T c~n ixv p 3 U o c r ^ 'o 3 CL � w a�c"�O m 0 60 coM L MLO 3 o p > p U U r 0 a U 3 0 O M U Ln 3 O LO U U O N LO O V R a _T 7 a (uin}sn 0008) BUNIJON co It ® O u L � U U LM 0 ■� 0 b cn 0 0 0 O n -F p,0 O D ■ Q q0 Ob O O, o L + cm 0 01 - (b 00 0 0 a 3 c O o 0 0 -- LO0 CD r Z r 0'0 0e, co w CJ Cl) O M O CO 1 O n O N 0 M 0 O Cl) tic O Oo rML A 11 co �O Q 3 5 0 Cl) to 3 N J co LLO 0 Q Q U U > N O cl O O 0.� to Ln � N C? l!j T 7 (uoisn 098) bui4UoN O O LO Lo U U U Lr ^L W ME C/) O� 7"1 Qo 0 � ■ O o 1�� LO L / r N o 0 ` 01 O O{ Ol Q � ■ O t7 T 0 O� O� y U � o o O ``' u_' cz . O O f O NO .N r 0 0 3 U w r v�N �( 0 Q� O O O ' O O r O O r N O f o C o 0 N oa 1 -LO ON O 0 0 �- 3 M till 11 11 till (uiMsn 09 L) bui4uoN TVD MD Name 2264.00 2335.52 10-3/4 x 13-1/2 7713.50 15280.567-5/8 x 9-7/8 by 11 7874.29 33696.00 4-1/2 x 6-3/4 41 II 11 14:11, Juty 24 2019 CD5-26 wp07 870 TC View 1060 1 .. 16I 1240 SURVEY PROGRAM 1240 1430 1 ri1 �ti,: SECTION DETAILS From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 40.80 2200.00 GYD-GC-SS 40.80 0.00 0.00 40.80 0.00 0.00 2200.00 3700.00 MWD OWSG 750.00 0.00 0.00 750.00 0.00 0.00 KOP: Start 1.5%100' DLS, 165°TF, for 300' 2200.0015200.00 MWD+IFR2+SAG+MS • • 1050.00 4.50 165.00 1049.69 1.50 165.00 Start 21/100' DLS, 0°TF, for 226.44' 15200.0016700.00 MWD OWSG 1352.05 10.54 165.00 1349.00 2.00 0.00 15200.00 33734.24 MWD+IFR2+SAG+MS 1453.76 10.54 165.00 1449.00 0.00 0.00 2335.52 32.58 165.00 2264.00 2.50 0.00 1506 1s772 - 1.1 2355.52 32.58 165.00 2280.85 0.00 0.00 1 39 E0390 3414.33 64.20 160.67 2975.23 3.00 -7.41 1#13050 - 13610.12 64.20 160.67 7413.00 0.00 0.00 2837 ��• ' OF'8370 14147.56 78.09 152.00 7586.55 3.00 -32.08 C1030 14347.56 84.09 152.00 7617.50 3.00 0.00 CD5-26 Tgt 01 TopC 071619 15280.56 84.09 152.00 7713.50 0.00 0.00 CD5-26 Tgt 02 B3 Int 071619 15300.56 84.09 152.00 7715.56 0.00 0.00 15815.06 87.00 152.00 7755.50 0.56 -0.08 16165.06 87.00 152.00 7773.82 0.00 0.00 16434.47 89.69 151.90 7781.59 1.00 -2.08 33734.24 89.69 151.90 7874.50 0.00 0.00 CD5-26 Tgt 03 TD 071619 TVD MD Name 2264.00 2335.52 10-3/4 x 13-1/2 7713.50 15280.567-5/8 x 9-7/8 by 11 7874.29 33696.00 4-1/2 x 6-3/4 41 II 11 6S/ 690 870 870 1060 1 .. 16I 1240 1240 1430 1 ri1 �ti,: t;1430 1610 �I�f ••� 800 / AW, 3130 4450 4450 5780 5780 -7100 • • ��7100 1 8430 - 9750 9750 1: 11080 - 1240 12400 - 1506 1s772 - 1.1 ;- 1 1 39 E0390 I 1 1#13050 - 2571 I 2837 ��• ' OF'8370 3103 C1030 3369 CASING DETAILS TVD MD Name 2264.00 2335.52 10-3/4 x 13-1/2 7713.50 15280.59-5/8 x 9-7/8 by 11 7874.29 33696.00 4-1/2 x 6-3/4 Minor Risked 14:14, July 24 2019 CD5-26 wp07 TC View SURVEY PROGRAM LOS SECTION DETAILS From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 40.80 2200.00 GYD-GC-SS 500 40.80 0.00 0.00 40.80 0.00 0.00 2200.00 3700.00 MWD OWSG 750.00 0.00 0.00 750.00 0.00 0.00 KOP: Start 1.51/100' DLS, 165°TF, for 300' 2200.0015200.00 MWD+IFR2+SAG+MS 870 1050.00 4.50 165.00 1049.69 1.50 165.00 Start 21/100' DLS, 0°TF, for 226.44' 15200.0016700.00 MWD OWSG 1352.05 10.54 165.00 1349.00 2.00 0.00 15200.0033734.24 MWD+IFR2+SAG+MS 1453.76 10.54 165.00 1449.00 0.00 0.00 1060 1240 2335.52 32.58 165.00 2264.00 2.50 0.00 1240 1430 2355.52 32.58 165.00 2280.85 0.00 0.00 1610 3414.33 64.20 160.67 2975.23 3.00 -7.41 1610 1800 13610.12 64.20 160.67 7413.00 0.00 0.00 1800 3130 ' 14147.56 78.09 152.00 7586.55 3.00 -32.08 ►� wi n l��'Lttij; i, ,/ 1 14347.56 84.09 152.00 7617.50 3.00 0.00 CD5-26 Tgt 01 TopC 071619 13130 11/ 15280.56 84.09 152.00 7713.50 0.00 0.00 CD5-26 Tgt 02 B3 Int 071619 ®R,,..-��,.;�..- 15300.56 84.09 152.00 7715.56 0.00 0.00 15815.06 87.00 152.00 7755.50 0.56 -0.08 16165.06 87.00 152.00 7773.82 0.00 0.00 16434.47 89.69 151.90 7781.59 1.00 -2.08 Q � • .8430 33734.24 89.69 151.90 7874.50 0.00 0.00 CD5-26 Tgt 03 TD 071619 CASING DETAILS TVD MD Name 2264.00 2335.52 10-3/4 x 13-1/2 7713.50 15280.59-5/8 x 9-7/8 by 11 7874.29 33696.00 4-1/2 x 6-3/4 Minor Risked LOS 41 500 500 690 690 870 870 1060 1060 1240 1240 1430 p.1430 1610 1610 1800 1800 3130 ' 1 qty ' • 1 ►� wi n l��'Lttij; i, ,/ 1 4450 13130 11/ ®R,,..-��,.;�..- 4450 - 5780 5780 - 7100 7100 8430 �� Via_: ��. �, Q � • .8430 9750 9750 1108 . 1r�'�iiiil'►.�C'';,i-.f�G ;�.--�...w3:d��illi%r►,tri d , • , • � • • i11080 � 1240 � 1 411 1506 15060 1772 Wi 17720 2039 - i 'A r1 •1 I ► .1 �' 1 50 2571 •�: 1 •__ �I� ' X 1 2837 i c i�I 1 • 018370 31 1 S 41030 33W O O ■ LL F-6 15 O O LO T r 0 co O O 0 0 0 0 0 0 0 (o O O f O O O O O O O O 00 CO N O Lf) T f- M M O O O CO �t Cl, T O M In 0o O M LO O v 0 f- M O f- M O (O 0 'C'^Y) r- O N 'It (.000 T ',I-, 1 fes rA '91- ITT- r N LO I� O M M Lf) CO00 W LO CO T T T T T M � Ln I` 00 0) T T T T N N N N M M I I T O O O O O O O O O O O O O O O O O O O O O O O It O O � O It CO T O M LO CO O M Ln M O W N O Ln M Ln (D M O N It W M T It r- T � � O It O r- M O r- M O T T T T T M It Ln I- W M T N U') I- O M LO M T T T T T N N N N M 0 C) ell O r - N U N T M M O Q ti N LO 0 ui D N' -d' �>� O 0000000- O OO O O O W O COO �CnN(nN Im- 00000000 000000000 Zr� x OOIn 00001 ONOOOOON O 070-+ C� x r N ~ (O C'7 0' 0 J Itd) r x ~02222 Q O 000000 C) 1-00000000 W r00 Q 0000000(0(00000000) 0 o O o O o v H O O O O N 0 0 0 L o 6 L o L o L L) O O N N N N N N r r L O O O O V (D 0 N ® O n L n L O (D (D (D (D (0 co (D L() Ln LC) LO LC) U) LL) Ln r---- r--------- O O O O co fl-NISN Z LP O O I� r �N CM u2 c2m Cf) m00m NLn('') p000LnCpNNC7N(DCOCD(DCDCOf-� 00000 �oJOOOO U rco � CO O O O r- L!) 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NAD27 - , Region: alaska r Latitude/Longitude Decimal Degrees • UTM Zone: True South • State Plane Zone: 4 Units: us -ft Legal Description (NAD27 only) Legal Description--- Township: escription --Township: 011 FN --,l Range: 004 E Meridian: JU T Section: 18 FNL + 437.34287 IFEL wl 12919.1180 Transform Quit Help W CD5-26wp05 Surface Casing M CPAI Coordinate Cons,erter From: -- - --- --- ---- — ,- To: 1 Datum: NAD83 _ Region: alaska -Datum: NAD27 Region: lalaska r Latitude/Lon itude Latitude/Lon itude 9 Decimal Degrees � 9 Decimal Degrees E C" UTM Zone: South UTM Zone: True 1 ` South i r- State Plane Zone: q Units: us -ft � C State Plane Zone: q Units: us -ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: f Ending Coordinates: X: 11489104.88 Y 5965146 04 _.................. I Transform i CD5-26wp05 Surface Casing w M CPM Coordinate Converter From: - Datum NAD83 Region: alaska r LatitudelLongitude IDecimal Degrees i UTM Zone: J South G' State Plane Zone: q _ Units: us k r Legal Dcscoption NAD IN nly) X: 349151.7109168 Y: 5965400.07995503 Quit Help — ❑ X To: — Datum: INAD27 Region: alaska r Latitude/Longitude Decimal Degrees t UTM Zone: True r South State Plane Zone: F--:-] Units: us -ft t+` Legal Description (NAD27 only) Starting Coordinates: Legal Description—--- --- x' 1489184.880- Township: 011 N - Range: 004 E Y: 5965146.04 Meridian: [U ______j Section: 118 ------...-------------------------------._.__ ..------ ------ ...--..._.-- FNL 815.96247 IFEL 12819.1787 :........................................................... Transform Quit Help CD5-26wp05 Top of Production Alpine C M CPAI Coordinate Con- erter — ❑ x From _ _^ To: Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska + r Latitude/Longitude Decimal DegreesLatitudelLongitude Decimal Degrees r UTM Zone: F_ j"' South I r~` UTM Zone: True r South f: State Plane Zone: q + Units: us ft ' State Plane Zone: q Units: us -ft + r Legal Description (NAD27 only) r Legal Description (NAD 27 only) -- Starting Coordinates: - — — Ending Coordinates: X: 11492443.89 ( X: 352410.350047355 Y 5955246.38 Y: 5955500.24797852 i Transform r CD5-26wp05 Top of Production M CPAI Coordinate Converter - From: - Datum: NAD 83Region: alaska + C Latitude/Longitude IDecimal Degrees 1^ UTM Zone: F South G Skate Plane Zone: q Units: us ft + n" Legal Des_riptior (NAD27 ortlfl S Carting Coordinates: - - - - X: 1492443.89 Y: 15955246.38 Alpine C Q uit Help — ❑ x To: Datum: NAD27 Region: alaska Latitude/Longitude IDecimalDegrees UTM Zone: True South 4 ` State Plane Zone: q + Units: us-fk 6' Legal Description (NAD27 only) Legal Description - - - - - Township: 011 N + Range: 004 fjEE Meridian: U + Section:29 FNL 89.909554 FEL 4680.3387 Transform Quit Help CD5-26wp05 Intermediate Casing I M CPAI Coordinate Converter i From: Datum: N4D83 Region: alaska E r Latitude/Longitude Decimal Degrees t UTM Zone: �— r South r State Plane Zone:q Units: us -ft Legal Description (NAD27 only) Starting Coordinates: - — X: 11492976 Y 5954194 ❑ X To: Datum: INAD27 Region: alaska . f Latitude/Longitude Decimal Degrees jE i C UTM Zone: True South State Plane Zone: q Units: us -ft Legal Description (NAD27 only) Ending Coordinates: X: 352942.421620329 Y: 5954447.84284323 .................. :.:.......... ......................... _ Transform i Quit Help CD5-26wp05 Intermediate Casing I M CPAI Coordinate Converter — ❑ X From: - To: Datum: p83 _ Region: alaska Datum: NAD27 Region: alaska . • Latitude/Longitude Decimal Degrees C Latitude/Longitude Decimal Degrees • UTM Zone: rr" r South r UTM Zone: True r South f� State Plane Zone: q Units: us -ft ( State Plane Zone: q Units us fk r Legal Description (NAD27 only! I a� Legal Description (NAD27 only) Starting Coordinates: - - X: 11492976 Y: 5954194 i -Legal Description - --- Township: 011 N . Range: 004 E Meridian: JU Section:29 FNL 1131.7666 FEL . 4131.2506 rFNL ........._.::...:.::ransform..::.:.........:�:::.:..........:. Quit Help ? Ti CD5-26wp05 Top Alpine A M CPAI Coordinate Converter - From: ---- ---- To: Datum: NAD$3 Region: alaska t Latitude/Longitude IDecimalDegiees it UTM Zone: i — r- South r: State Plane Zone: q Units: us ft r Legal Description (NAD27 only) F- Starting Coordinates: X: 11493311.34 Y: 15953531.39 f Datum: NAD27 Region: alaska t` Latitude/Longitude Decimal Degrees UTM Zone: True r South State Plane Zone:q Units: us -ft r Legal Description (NAD27 only) Ending Coordinates: - -- X: 353277.737274E8— Y: 53277.737274658Y 5953785.2168982 € Transform ] Quit Help CD5-26wp05 Top Alpine A M CPAI Coordinate Converter From: Datum: NAD83 Region: jalaska Latitude/Longitude IDecimalDegrees�� r UTM Zone: r South r Skate Plane Zone:14 _ Units: us -ft r Legal De ception (W027 onlyl ( Starting Coordinates: X: 11493311.34 Y: 15953531.39 — ❑ X Datum: NAD27 - Region: lalaska 11 i Latitude/Longitude IDecimaiDegrees r UTM Zone: True r South t State Plane Zone: q Units: us -ft f Legal Description (NAD27 only) Legal Description- Township: 011 N Range: 004E Meridian: ["u----7- Section:29 FNL1787.7689 FEL � 3785.2213 Transform Quit Help CD5-26wp05 TD M CPAI Coordinate Converter From: - -- - - ---- - --- -- -- ----- - , t i Datum: INAD83 Region: alaska C' Latitude/Longitude IDecimal Degrees�__j { C" UTM Zone: ( South C Stake Plane Zone: q -1Uniks: us -ft i" Legal Description (NAD27 only) Starting Coordinates: - X 1501334 Y: 15937746 # CD5-26wp05 TD M CPAI Coordinate Converter ❑ X To: --- Datum: NAD27 7, Region: alaska r Latitude/Longitude Decimal Degrees+� f- UTM Zone: True T_ South State Plane Zone:4 Units s- uft r Legal Description (NAD27 only) Ending Coordinates: - r...................................... .......... ......... r Transform s X: 361299.761788747 Y: 5937999.40703466 Quit Help - ❑ x CFrom: ---- - To: __ -- -------------- Datum: INAD83 Region: alaska ! Datum: NAD27 _ Region: alaska r Latitude/Longitude Decimal Degrees i �� i �" Latitude/Longitude Decimal Degrees .� r UTM Zone: - r South � r UTM Zone: True r South r: Skate Plane Zone:__:q Units: us -ft r State Plane Zone: q _ Units: us -ft r Legal Description (:NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: Legal Description ----- X: 1 escription ---X 1501334 Township: 010 N Range: 004 E Y 5937746 Meridian: JU j Section:Ig FNL 1580.2775 IFEL 1787.97208 Quit Ii Transform i Help L L ♦ V 0 a m N Ln Q m U co Q� J LO N Q o )N 0(D N a M U M O LLO Q U N M � ' � U ti S� M o o 0 0 � H 0 3 O N c _ a_ N M W Q U O ■ OO O c N o co co in o r r r Lr �i Q S LC U s0 w 0 n Ln O N LO O rn V Q w 0 N N U O (ui/}sn 0009) 6ui4lJoN rn Q U i AL W V / 0 CL m N � H U co 0 V N � � N I- ❑ U � CO N M � Vcn M ❑ O U M M S� U 09 O OM N a c W o 0 3 o 0 � 0)c .N N ca LU 0 U O O o S U OLO 0 Q o rn N LO U V 0 N tR N 7 J o (ui/l}sn 0009) 6ulWON 0 N � � I- ❑ U � CO N M � M ❑ O U S� U 09 O N a 0 3 N 0 U O O o S U 0 Q o rn U REVI DATE IBY ICK JAPPI DESCRIPTION REV IDATE I BY I Ln APP DESCRIPTION 1 4/24/15 CZ I DB C.A. UPDATED PER K150003ACS 1 2 5/2/16 CZ I GD I C.A. UPDATED PER K160003ACS ALPINE SATELLITE DEVELOPMENT W LOCATION OF THIS SURVEY T12 CD -5 PAD T11 N CD4 TO ALPINE CD5 � D .•lit ACCESS ROAD CD N z O CP \ � +O -7 Z Di LL dT O C IF r� VICINITY MAP NOT TO SCALE LEGEND: O PROPOSED CONDUCTOR • EXISTING CONDUCTOR SECTION 7, T. 11 N., R. 4 E., U.M. SECTION 18, T. 11 N., R. 4 E., U.M. P PD CD -5 °F C'013 PAD UDDER '�agaa� SN° X00 Lp�o DESIGN ao 0 oxo% con"GG��r000 X��%�'••!••• X NN!4�G05�x14 oo�Qoao % PLANT N N a NOTE: 15.40 52" CONDUCTOR CD5-x14 WAS PLUGGED AND°i� � ��' 0 ABANDONED LC MF APRIL 2016. r` Z,r KUUKPIK UMIAQ ALPINE SURVEY OFFICE PHONE :907-670-4739 y� ALPINE MODULE: CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD -5 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 15-03-02-1 04/18/2015 1 CE-CD50-1025 1 1 OF 3 2 U '.F- (3) -+ 4J f� E 4- 0 O O M CN 1E C a--+ O 4--J M U O L 4- Z � Q O c: L— o O O '~ L co � U i co c E O N_ L L O X� O O O E 4-1 cu 4-+ N •L Co w N Q) 4A Q� ro U m L N F— T V fB N N F- 4 -J ro •1-J C O c O U v ^N,, hW cn L a� v C 4J E � N Q E 4 � O 4J � 4 � C U C OC -0 v C co Q1 C N V) +1 m O 4A vI Q � cu = � (U - _ O O " Q co -0 a) 4- q---0 O U CII N cn Q Q C10 C = ro - 0 O N O U C Q co O +t Lr) 4 O a+ v bo L- N L +r N C O N C N J 41 w U O O v r E (n lie L O O C U (Uro dO C L O _0U -0N C: � N D C Z U '- C — co LLU (1)N C N N Y L Li N Q) 4A Q� ro U m L N F— T V fB N N F- 4 -J ro •1-J C O c O U v ^N,, hW cn L a� ■ i, ■ L Q m O L f� N QJ t f� U W Qi L a� > L N Q) N f0 QJ L U L O 0 c (O N O i (n U U f0 C O m O L ■ Q) WWI El ■ ■ I on te a, � O N L � N > L v � }' O _ N f0 U Y {n L U 41 Q. O � a -J U N O U � �U QJ Q� L 1{. L Mo > d-+ L s L N M 4- 4- (BQ) U cn 0- E .� ru CU O 3 N U U U N O a+ N C M O O L m V)v O > > .� E L >` U fB _0U a.+ O O M u :3CT O = -0 Q QJ Y N M v0O N N O O N N u O m U N N (n N CD f0 L fB 4" C i C — CQ) — N M C ■ ■ ■ ■ on te Well: CRU CD5-26 <== Data Input Name: V Loepp <_= Data Input Mud Weight (ppg) 9.60 <_= Data Input Weak point or LOT - Measured depth (ft) 2,247- <== Data Input Weak point or LOT True vertical depth (ft) 2,189' <== Data Input Weak point or LOT - Hole angle (deg) 27.00 <== Data Input Weak point or LOT - Hole size (in) 10.750" <== Data Input Weak point pressure or LOT - EMW (ppg) 12.50 <_= Data Input Zone of interest - Measured depth (ft) 16,280' <== Data Input Zone of interest - True vertical depth (ft) 7,713' — Data Input Zone of interest - Hole angle (deg)4.0° — Data Input Zone of interest - Hole size (in) 7.625" — Data Input Zone of interest - Pore pressure EMW (ppg) 10.00 — Data Input Gas gradient (psi/ft) 0.1 — Data input Bottom hole assembly OD (in) 8. " — Data Input Bottom hole assembly length (ft) 200' — Data Input Drill pipe OD (in) 5.500" — Data Input BHA annular vol. @ zone of interest (bbl/ft) -0.0057 DP annular vol. @ zone of interest (bblt t) 0.02 71 DP annular vol. weak oint bbl/ft 0.0829 Additional safety margin (psi) 0.00 — Data input Weak point pressure (psi): PIo 1,423 psi Weak point pressure - Safety margin: Pmax 1,423 psi Pmax EMW 12.50 ppg Max anticipated formation pressure (psi): Pf 4,011 psi Weak Pt to Zone of Interest distance (TVD ft): OH {TVD) 5,524' Weak Pt to Zone of Interest distance (MD ft): OH (MD) 13,033' Maximum influx height at the bit (TVD ft): H {TVD) 358' Maximum influx height at the bit (MD ft): H (MD) 816' Calc. volume of (H) around BHA: V1bha -1.1 bb! Calc. volume of (H) around drill pipe: V1dp 16.7 bb! Calc. volume that H equals @ initial shut in: V1 15.6 bbl Caic. vol. that H equals @ weak point (MD ft): VWp 33.3 bbl Calc. volume of Vwp @ initial shut in: V2 11.8 bbl Kick Tolerance: V2 11.8 bbl NOTE: TRANSMITTAL LETTER CHECKLIST WELL NAME:K<� e PTD: Z12— /Development l2 -- Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: 1� POOL: v Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -_� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. 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 (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, ALPINE OIL - 120100 Well Name: COLVIL_L_E_RIV UNIT CRU CD5-26 Program DEV __ Well bore seg ❑ PTD#: 2191070 Company ConocoPhillips Alaska. Inc. Initial Class/Type DEV/PEND GeoArea 890 Unit 50360 On/Off Shore On Annular Disposal ❑ Administration 1 Permit _fee attached ________________________________ ___ Yes -------------------------- --- 2 Lease number appropriate_ - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Surf_ Loo $,-Top Prod Int lie in ASRC-NPR4; Portion_of Well Passes Thru ASRC-AA092344; 3 Unique well name and number _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - Portion of Productive- Interval lies in ASRC-N_PR2; TD lies in_ASRC-NPR5. 4 Well located in-a-definedpool _ _ _ _ _ - - Yes COLVILLE_RIVER, ALPI_NE_OIL - 120100, governed by CO 4430. - - - 5 Well located proper distance from_ drilling unit -boundary -------------- - -- Yes - _ _ - - - _ CO No._ 443C contains_ no-spacing-restrictionswith respect to drilling_unit --------- - - - - 6 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - Yes CO No. 4430 has na interwell spacing restrictions. Wellbore will be more than 500' - - _ _ - - - 7 Sufficient acreage available in -drilling unit_ - _ - - _ - - Yes from an external property line -where- ownership or landownership_changes- -- - - - - - - - - - - - - - - - - - - - 8 -If-deviated, is -wellbore plat -included - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes NOTE: Lowest portion of well _lies outside_ of Colville River Unit. Statewide_ spacing requirements apply. As 9 Operator only affected party- - - - - - - - - - - - - - Yes - - - - planned, well conforms to spacing requirements_of CO.443C and_20_AAC_25.055._ 10 Operator has.appropriate- bondinforce -- - -- ------ - -------------- Yes------------------- ---------------------------------------------------- 11 Permitcan be issued without conservation order_ - - - - - - Yes - - _ - _ _ _ - - _ Appr Date 12 Permit_ can be issued without administrative_ approval Yes -______----------- 13 Can permit be approved before 15-day_wait----------- Yes . - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - SFD 7/31/2019 14 Well located within area and -strata authorized by Injection Order # (put 10# in_comments)_(For_ NA_ --------------------------------------------------------------- 15 area All wells -within 1/4_mile area of review identified (For service Well only)- - - - - - - - - - - - - - - NA_ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - _ - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre -produced injector: of pre production Less than 3 months_ (For service well only) _ _ NA- . - - . _ - - - 17 Nonconven. gas conforms -to AS31.05.030Q.1_.A),(j,2.A-D) - - - - - - - - - - - - - - - - - - - - - NA - - - - - _ - - - - _ - - _ - - _ _ _ _ _ _ _ - - - - - -- - - 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - Yes 79' conductor provided_ - ---- ---- ---- ---- Engineering 19 Surface casing_p_rotects all -known_ USDWs - - - - - - - _ Yes - Surface casing set to 22 -47' -MD - - - - - - - - - 20 CMT_vol_adequate_to circulate_on conductor & surf_csg - - - - - - - - - - - - - - - - - - - - - - -Yes - - - - - - - 170%_excess cement - _ - - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 21 CMT_wladequate _totie-in -long string tosurfcsg--------------- - - No - - - - - - - - - - - - - - - - - - 22 CMT -will coverall known productive horizons- - - - - - - - - - - - - - - _ No Productive- interval will be completed with uncemented pipe with frac ports 23 Casing designs adequate for C,_T, B &_permafr_ost_ Yes - - - _ - _ _ - 24 Adequate -tankage or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes -- - - - - - Rig has steel tanks; a11_waste_to approved disposal wells_ - _ _ - - - - - - - 25 If -a -re -drill, has_a 10-403 for abandonment been approved - - .. _ - NA. - - - - _ - _ - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate wellbore separation proposed _ - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Anti -collision analysis compiete; Major risk failures: CD5-90, CD5-98 in zone_ 27 If_diverter required, does it meet regulations_ _ _ - _ _ _ Yes Diverter waiver granted per 20 AAC 25.035(h)(2) Appr Date 28 Drilling fluid- program schematic & equip list adequate_ ----------------- Yes - - - - Max formation_ pressure is 3950 psig(7.9 ppg EMW); will drill 8.8-10.8 ppg EMW- - - - - - - - - - VTL 8/13/2019 29 BOPEs,-do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ - - -------------------------------------------------- 30 BOPE_press rating appropriate; test to -(put prig in comments)- - - - - - - - - - - - - - - - - - - Yes - - - - - - - MPSP is 3163 psig; will test BOPs_to 35Q0_psig _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - 31 Choke -manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - _ - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operationshutdown- - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes- _ - _ _ _ _ _ _ _ _ - ------------------------------------------------------- 33 Is presence_ ofH2Sgas probable -------------------------------------- Yes ------- H2Smeasures required ___----- _-__--------- -------------___-_-_ 34 Mechanical condition of wells within AOR verified (For -service well only) _ - - - - - - - NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit can be issued w10 hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - Although _H2S was not encountered in offset wells, rig g will be equipped with _operational- sensors/alarms. Geology 36 Data - - - -ted on potential overpressure zones Yes Planned mud weights appear _adequate to control the _operator's forecast of most likely pore pressures_ Appr Date 37 Seismic analysis_ of shallow gas zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA- - _ - - - - - in the_operat_or's geologic prognosis._ No abnormally geo pressured strata are anticipated. Managed SFD 7/31/2019 38 Seabed condition survey (if off -shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ - - - - - - Pressure_ Drilling technique will be used -to maintain -borehole stability in shale ---------- - - 39 39- Contact name/phone for weekly -progress reports [exploratory only_] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ . _ _ _ _ _ _ _ _ _ - _ - _ - - _ - - - - - - - - - - - - - - - - - - - - - - _ - - - _ - _ - _ _ _ - - _ _ _ - - - - - - _ _ _ - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date �/i / l