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ConocoPhillips 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 CD5-24 50103207990000 2190060 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 July 1, 2020 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Second Quarter, 2020 To whom it may concern: Please find attached the second 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 second quarter of 2020. The disposal permit for CD5-24 expired in the second quarter of 2020. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, G. L. Alvord Alaska Drilling Manager G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 G. L. Alvord Digitally signed by G. L. Alvord Date: 2020.07.01 16:13:39 -08'00' 219-0067. 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):316894052020/Q10000 n/a n/an/a n/a2020/Q20000 n/a n/an/a n/aYYYY/Q#0YYYY/Q#0Total Ending Volume (bbls):316089405Other (Explain) Printed Name:Title:Phone Number:907-265-6120ConocoPhillips Alaska, Inc2. Address:4b. Well Status: Oil Gas WAG 103-20799-00-00CD5-24PO Box 100360, Anchorage, Alaska12. Remarks and Approved SubstancesDescription(s):5b. Sundry approval date:4/22/2019Report 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.Drilling ManagerSignature:Date:7/1/2020G.AlvordInitial DisposalContinuation Final4a. Well Class:StratigraphicService 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 SIDESubmit in DuplicateG. L. AlvordDigitally signed by G. L. Alvord Date: 2020.07.01 16:32:58 -08'00'RBDMS HEW 7/14/2020 ConocoPhillips January 8, 2020 Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Fourth Quarter, 2019 To whom it may concern: G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 CDS-Z1-i Please find attached the fourth quarter 2019 annular disposal reports for the Colville River Unit and Greater Moose's tooth unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2019. No annular disposal permits expired in the fourth quarter of 2019. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, A -c. Lk G. L. Alvord Alaska Drilling Manager RECEIVED JAN 10 2020 AGGCC LL 0 w Q z 0 2 2i 0 U Z 0 W CO Z 0 U U) V Z J 0 coJ m U n 7 E V LL w U L O a o N N u p ow p G E z Z z Z Z O0) Z' ..a N cu OO N 0C N = 0 N Z In T Q ❑coa O cu U 0) �D I p� N CU O _ Q) o > m a 0-2 y oo am z z z z z O.c aZE f E oa 43 a � w z o N i` z os �^ � Q � o E? z -o N c Z z Z z Z N d ¢ ii ❑ om w co n ro ai m Q U o Q 0 �0 Q `o @ a PI ❑ O O O O N ❑ ❑ a OJ E a ti Z a 0 N ❑ o p y ¢ N o N = m p d N N a❑ ❑ a -� O o O o o O o ❑ El 3= > E > v v m O o V O L D L � N mo❑❑15 ❑ ` C O rn C N z N O y x N r Eo 3:o Eg °' ❑ u� o m O) 7 °o c U O O O O O W K a y CO) y y .2 O W N N N N ICU' N❑ O M a v cz-7 v'� a ❑ �. E Q N 6 ❑ N N OI N F- 4 L m 3 c 0) a in N LL m ac O 3 O O O O N a N N N U N O y N N a O ¢ w m O C O a a CM ma N t N i E❑ y o U a E c 3 a o m M E m E o o �` (O CO m o o o M o o M a o N o c o a E N O. x- = V E p N N @ O N a m K❑ C� N - a N L ❑ t O a N O U U a C N t0 2:1 E o 0 Cc It - a a L m m v ❑ L m g U o a m a� � a a N C7 o N N N ❑ - m U n 7 E ORIGINATED ALASKA E -LINE SERVICha 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION iiVUUb TRANSISAL DATE: r TRA MITTAL #: ' FIELD BP North Slope 0 0 0 EGA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc.CJily 1 1 0 1 0 Attn: NSK-69 700 G Street OCT 1)1019 Anchorage, Alaska 99501 AOGCC L0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR L0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 nt Narry Signature ase return via e-mail a copy to both Alaska E -Line Services and C n o Phillips Alaska: ❑ ❑aUo ❑ ❑ 000 0 N ❑ N ❑ UIU U N U❑ U m UR U _T. _Im Im _1 1,4 16 _ I N p Q Q Q Q Q Q a O❑ 0- M aa aa0. O a Up p UU❑ U❑ U NO o LL LL❑a LLpa ir N 3 y xI U. 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Ow UN UN UN UMI U UN U 7 C C N C N C N C N C N C N C N C N C N C N O E U C U C U C 0 E C U E O O T O T O T O T O T O T O T O T O T O T M ¢ W¢ O LL O LL O LL O M_ O O LL O an d a0i d a0i d d v v d vl d vl d v1 w v mal v c W W f0 w w W to w w w w w w w U) w w w w W to N= W N W N W N W LL' W W N W m L) m— — — — m — m m m m m m m m —— — U o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Q N N N N N n n n n n r M Q M M M M M M M M M N Q N N N N N r n n r n r n r n r n ao o ro eo m ao m J 0 m O E E U m 16,C O E O N U c u N Im m m m m m m m m m m `w m 'Im m m m m m m m m m m a m w m -a :a m a r m r m m m m > oy 0 y0 0 y0 0 0 0 e0} 0 e0e}} 0 0 Op O M IU U U U U U U U U U U U ❑ O ❑ ❑ ❑ ❑C)❑ ❑ ❑ ❑ O o ❑ W W W W W W w W W W W J W nr m nt m m m m m m m m m 0 0 0 0 0 0 M M M M M M U U U U U U w w w w w w U U O .0 O 2 c Z o o 0 6 0i E (� O 0 W -- rn 0 D N ❑ ❑ ❑ ❑ ❑ ❑ m N K K w K w w NI LLZ W W W W W W O E > I �I —1 K ml .- ml � � ml � m N .- N � � N H � W CI J OU D 0 L) n C) U J D L) 7 C3 U D U U J J L0 IL lL IL LL VI IL �I lL IL �I ti U N r c U �I U N C U al U N C U U N C U U N C U U N .0 U C U N C U W O LL '621 O LL 2 11 p LL 2 LL O LL O O LL o p N N W N W N W N W N W N W N W W N N S -- 0 N 0 N 0 N 0 N 0 N 0 N N N N N O 2 c U O � ❑W E 0 W -- rn 0 ro n N c U) m m m m m m m m y O 0 00 0 O O m m m 75 m m m m m = 2M LM RM M P 0 0 0 0 0 0 0 0 0 M M M M M M M M M M M M M M M M M M U U U U m W ❑W W W J N E E U 0'. E 2 z ❑ w >m W E n U 2 0 a O K y F m Q o c 0 U K O O ? U a` (7 EE E O U U O M U U U U ❑W 2W w W -- U U U U m W ❑W W W J N E E U 0'. E 2 z ❑ w >m W E n U 2 0 a O K y F m Q o c 0 U K O O ? U a` (7 EE E O U U O a c� d 3 J O 7 ro r 71 U O o w N d d — C o M I d m •€ E n Ili E E v a g � v 71 U O ConocoPhillips October 8. 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Third Quarter, 2019 To whom it may concern: G. L. Alvord I %laska Drilling Manager Jrilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 CD5-Z'l (Z(f-00G) 4h;K,l Please find attached the seachd quarter 2019 annular disposal for the Colville River Unit and Greater Moose's tooth unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the third quarter of 2019, as well as total volumes disposed into annuli for which disposal authorization expired during the third quarter of 2019. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, 14LO-A G. L. Alvord Alaska Drilling Manager z ur cm C Z O Z m m m A N m m 0 m r y 1� L rg I N N r ^ O m O O H N D O » 3 O d N j N O O 3 C¢ OO o' = 3 a, O � O N x o N¢ x �, 0 o U ri rn FT N 0 rn 0 3 2 3 m 3 7 J 6 O d � N ❑ m c- - I/- N d � n � " J J ^• l] N W J d � d O G o 3 5 D O N N O d O F d o- ^ O O J S 6 d 3 S❑ N A A D O N 0 3 c Ely n� 3 c Z F o W a L m m E "a N O m J ❑N » N OD O �" m m a CD O O O J fJ a d J o S N 3 U m 0 z m N O O y ❑ A A 3a K O O O O O O ❑ O O d O O z V o a ❑ ❑ m C 0 o o" d m ❑ = ry O O O W J m No O Z Z Z Z Z Z 3 CD p z o m O z m o z � D m ao� 3 0 O Z Z Z Z z � a N s (Dm 4i y o c �° a O o w N N toil (D O v .� m o N Q. O 'o O O� O CD S A O CD v O c o N <D ? :�% m (D Q Z Z Z Z Z f„ D D D D o a m N �com m r y 1� L rg I WELL LOG TRANSMITTAL #905848120 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suiten 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: C]35 -Z4 Run Date: 7/19/2019 219oc 3113 August 22, 2019 The technical data listed below is beiz�&g submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD5-24 Digital Data, Digital Log Image file, 311E) viewers 50-103-20799-00 RECEIVED 1 CD Rom AUG 2 7 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: 2ilxy. Signed: 219005 31040 Schlumberger Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska, Inc. Dispatched To: Well Name: CD5-24 Date Dispatched: Transmittal #: 25JUL19-SP01 AOGCC: Natural Resource Tech 25 -Jul -19 Service Order #: 19AKA0076 Dispatched By: Stephanie Pacillo Product I Description Hardcopy Digital Copy Logging Date LWD Recorded Mode Prints: N/A Contents on CD 22 -Mar -19 Scope Resistivity 2" MD x 2" TVD x 5" MD x 5" TVD REC EIVED x JUL 11 2019 AO CC 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 GYRO Survey x CID 1 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.Osterkamoto")conocoohilli .com Alaska PT tCenter slb.com Attn: Tom Osterkamp Attn: Steph nie Pa 'llo Received By: Schlumberger -Private STATE OF ALASKA ALASI SIL AND GAS CONSERVATION COMMISSIG. REPORT OF SUNDRY WELL OPERATIONS RECENED JUL 110 2019 1. Operations Abandon ❑ 'lug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ OperatiOns shutdowd Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ forate New Pool ❑ Repair Well ❑ Reenter Susp Well ❑ Other: ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Exploratory ❑ Stratigraphic❑ Service ❑ 219-006 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20799-00-00 7. Property Designation (Lease Number): e. Well Name and Number: ASRC-NPR4, ASRC-NPR2, ASRC-NPR5, ASRC-AA092344 CRU CD5-24 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 31,040 feet Plugs measured None feet true vertical 7,856 feet Junk measured None feet Effective Depth measured 31,040 feet Packer measured 13700,12970,13632 feet true vertical 7,856 feet true vertical 7614,7430, 7603 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 115' MD 115' TVD SURFACE 2,197 feet 10 3/4 " 2,235' MD 2175' TVD INTERMEDIATE 13,848 feet 7 5/8 " 13,882' MD 7640' TVD A Sand LINER 8,009 feet 4 1/2 " 21,709' MD 7755' TVD Perforation depth:Frac Sleeves/Pert Measured depth: 14461-14463, 15227-15229,15957-15959, 17413.17416, 18419,19267-19270, 20076-20078, 20894-20887, 21649-21659 feet True Vertical depth: 7672-7672, 7686-7686, 7691-7691, 7697-7697, 7700-7700, 7728-7728, 7739-7739,77437743, 7749-7749, 7755-7755 feet Tubing (size, grade, measured and true vertical depth) 4.5 x 3.5 L-80 13,716' MD 7,616' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- HRD-EZXP LINER TOP PACKER 13,700' MD 7,614' TVD PACKER - BAKER PREMIER PROD. PACKER TC -ll 12,970'MD 7,430'TVD PACKER - HALLIBURTON TNT PACKER 13,632' MD 7,603' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): 15956-21709 Treatment descriptions including volumes used and final pressure: Total Well -10 stages, 2,734,354 lbs placed...... see attached schmatic 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: 0 e e 452 681 Subsequent to operation: 2357 2438 248 1531 456 14. Attachments (required per 20AAC 2&070,25.071, 825.283) 15. Well Class after work: Daily Report of Well Operations O ` Exploratory ❑ Development ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0/Q�•1't 16. Well Status after work: Oil p Gas E]WDSPL E]PPrintedU Printed and Electronic Fracture Stimulation Data LVJ A GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ ;USP ❑ 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: 319-239 Contact Name: Adam Klem Authorized Name: Adam Mann Contact Email: adam.klem@ConocoPhillips.com Authorized Title: Sr. Complions Engineer 7- Contact Phone: (907) 263-4529 Authorized Signature: Date: Form 10-404 Revised 4/2017 "Df"f '//6/20/?9/-r RBDMS�UL t 61019 QYr�zi/ ubmi[ Original Only WN$ PPnD WELLNAME CDS-24 WELLBORE CDS-24 ConocoPhillips aa5ka.lnc. MULTIPLEUTEFLLLB, Ccei]I1yA19121041 PM Last Tag VUY`al Wlxruh lxLL) AnMlation CePMINLBI End Wle WeIIWre Iai1MW By ...................................................................... IAST TAG'. CD5-24 lennak HANGEa, uaLast Rev Reason Anes. End Uale w.nlwre LasiMM By Rev Reasons Past Fran Weliwark- Updated FRAC delink ]11512019 CD5-24 Ipp.a .......................................... ...._._.. Casing Strings Casing Description DID (in) ID lot Tophlon Bet cepn lM1ael set II(Nol_. wvren I _ Gran. mP Thread CONDUCTOR 20 1925 36.9 115.0 115.0 A53B Casing Omcnplion OD hot 10 had TeplKasl SN OapM IMLs) Bel doer IN01... MUn B... Grain Top nand SURFACE 10314 995 3].5 2,234.5 2,1]4.] 65.50 1-80 TXP-M CONDUCTOR; 3&>1150 Casing camnigron INTERMEDIATE OD (in) Io EN Tdgei SetOpMkMB1 Sat Di nVE-."A'san 11... G. 75/8 688 34.2 13,882.1 ],640.3 29.)0 L80 T.NThmtl TXP Case,..'.... OD(n) look Topdtl(9) SatpapMMKM SM Dupe IN01... Mean k. -C"'. Top Threat NIPPLE, 2,1a&e A SAND PRODUCTION 4112 396 13,700.0 21,708.5 7755.2 12.60 L-80 Hytl5fi3 LINER Liner Details SURFACE; a7.SZ6a.5 NommallD Tap Maul TopfriD)(MB) Topici 1. Des corn (in) 137000 ],613] 8112 PACKER "HRP{^ZXP Liner Top Packer(11.28 5740 do LPT; a,1a20 recepticle,5 74" IDI 13,7199 7,6168 81.12 PA KOFF 'RS" Package Seal Nipple 4270 13,722.3 ),61).1 8112 HANGER -DG" Fhp4-0ck Liner Hanger 4,820 13,729.4 7,6182 8112 XO -Reducing X0, 5.5 H563 x 4-117'563 3.920 14,461.1 ),6]19 8892 Baker fare shmike ,Hyd 3 2645 GAS Dn:eeao2 SleevelPOG 26 Sot ID 15,20.1 7.6858 8897 Bidnerfainguagoonfil Hyd563 2595 SleeverPod 2.59E Seat ID 15,956S 7,691.5 8971 FRAC Baker frac sleeve AT HydG63 2545 SleevelPOn 2.5,16 Seat ID 16,686.3 7,696 953 .8 8Bake, ac Slago.4, Hyd53 2495 (Lis DCT, 12,n1Za SleevelPOd 2.495" Seat ID 17,4132 7700.3 8964 Baker ore sleeve AS, Hytl563 2.455 SleevinPod 2,456' SAM ID 18,418.6 7,728.0 89.17 RM Baker frac sleeve Nd, Hytl5fi3 2.415 SleeoWPft 241&Seat ID GWGE;1Zea0.0 19,287.4 7,738.6 89.68 A Baker frac sleeve AS, Hytl563 2975 xo'. u.aes BleevPJPOd 2,37S Seat ID PACKER: usw.a 20,075.9 7,]43.1 89.6] a r acseave ,Hyd53 2.335 Sleevepert 2335"Seat ID 6LIeNG SLEEVE u,gap.a 20,884.0 J,Jo 8941 FRA aker teas sleeve Ml, HydI 2.295 NIPPLE. 13,000 Sleevelpon 2291 Seat ID Tubing Strings Tuning D=6onpToo Sbme Ma... m(M Topar"N sm D=ptn'it s=1 Depin lrvD) (... wl plLlk Gntle Top connmdon TUBING 4.5"x 4112 3.96 350 13.)16.0 ]fit B2 12.80 L -BD TSH BIre 3.5 "COMPLETION Completion Details Top lrvDl Topmcl Nominal Top MKB) MNB) 1•) paps Co. ID (in) 35.0 35.0 0.00 HANGER FMC 4-1Y8' Tubing Hanger Hydrl HYD 563 3.958 PACKER, Disi 2,148.8 2,096.8 2647 NIPPLE NIPPLE,LANDIN 112-,-W.3.813 ', TSH Blue .013 1219450 ],420.2 67.04 GAUGE SLB Solid Gauge Marginal wl i light encapsulated l wire, TSH Blue 3BN NIPPLE', 13,67&2 12,9615 7,4267 67.35 XO XO JOINT, 4112,12.601,180 TSH Drug x ill• H563 2.992 100.QOR, 1&021)2 12,969.6 74298 67.50 PACKER Baker premier prodlxtion packer 1112 TC -11 2.067 SEAL MAY. 1&M7.1 12,990.8 ],43).8 6790 L SLEEVE,SLIDING, 3-12'APCv-112813". STOP, XProfile 2.613 SLEEVE 13,006.) ).443] 68.19 NIPPLE NEPLE,IUkNDING,3-112 X, 2813'.Hyddl 563 -High Burs, 2.813 13,Wl 71 ),6029 80.55 PACKER Hallibudon TNT packer, }117VAMTOP 2900 13,6)8.2 7,fi103 81.13 NIPPLE NIPPLr NDING,3 112,%, 281T,EUE 81d 2.813 13,696.2 I 76131 I LOCATOR jehior MCChanical loom EOE Bid 2.980 INTERMEDIATE: x x1SEM. 1 13,6W.1 I IPIJ21 81.13 11REALASSY 1B.K.1 WL G(Shear scrota Uttar below 10CMI 2980 Frac Summary Hy1Wk Flacala: 14MI 0 1 aMrloO Proppanl DeugnWpb) PmpwMln FormMbnhig 61132019 ]1,]00.0 69,001.0 ,hook.h.:,gicc. I 6101' 6tlrI DaY Tep Depth (Ma) BMntl(BI Llnkb FluWSystem Vol Clsan Mbl) V. SIurry(bbll 1 61132019 21,8490 21,8990 Hybor G. Gelled Salt Water 2,095.00 2,120.00 Hydri Fracture: lease I Sand Dab 611312019 Pmppanl Dusl2nMf16) PNppaMln Fmmelon (MI ]1,]00.0 74222.0 Bpe 8W10ab Top DapM al sM(nKBI Link to FWN Sysbm Vol Chan MMlVol8lure" 2 61M2019 20,8850 20,086.0 Hybor G. Gelled Salt Water 1,244.00 1,325.00 HyMwk Finae..n6eM.o I sbrtdau, Prapwnl Desi2ne4 Pb) Pmrl In Formation add 611312019 71,7000 68,4750 Xy1aWk Fracen;tT,a1&0 I Ser osa Mh 3 811312019 Top Da MKBI Mm MKB) Unk b Flukl Bys*M Val Chan (bad 20,076 ,0 20,0]].0 Hybor G, Gelled Salt Water 1,24000 Vol SlurarBal) 1,315.00 Bbrt 0. Pmpwnl 0eai2nW Big Pmpp-tIn Fwmalbn0d 61132019 )1,)00.0 69,8810 SpF SW pNe Top D¢pM MKM Bnn MKS) Unkb FluMByatem Vol CMs(ol, V0181urry(bbq Hyrads F,wn., 1&al&o I 4 fi1131 9 192670 19260.0 Hybor G. Gelled Salt Wafer 1.24000 1,31800 BtMOah Designed lib) pmPWMln Fwarradd M 61132019 7P,,nl )1,700.0 ]6.)88.0 Hryrnals.F 49,12.'6).0 I Sp• SIM DMe Top Dupe MKB) aM IRKO) LInXMFluid System VM Clean (bhp Vel Slur0 5 611312(119 18419.0 18,620.0 Hybor G, Gelled Salt Water 1,531.00 1,814.00 Sdui PMPWntloioga (Ibl pmppaMln FwmMbn(M) Hossulkrmro.a;m.meo 61152019 71,]Oo0 71,042.0 epp Sbn Dab Top Depth addict Bim MKB) OIN W Fluid System VOILMMMbI) VDIS1troi bll 6 6/1512019 17413.0 17,414.0 Hybor G, Gelled Salt Water 1,891.00 1,968.00 1pkokLFnce.e:2,fl5.0 I Sbn Dab 611512019 Pmppanl Despned(e) go.pand In Fwmabon(IN 98132.0 89,320.0 3pA Sbrt Oab Top Depth MKIN Btm (XKB) Link b Fluff Bysbm vMChan Mbn VOI81urry(bbp 7 61152019 16,686.0 18,88].0 Hybor, G. Gelled Salt Water 99100 1,088.00 H ageac F.sswm', 21649.0 A&1ND PXOOUCTION DNER', 11.7W.621,706.a CD5-24 FRAC STIMULATE DTTMSIJOBTYP SUMMARYOPS 6/10/19 DRILLING SET 4.5" CATCHER @ 12580' RKB. PULLED SOV @ 12512' SUPPORT - RKB. REPLACE WITH DV. PULLED CATCHER @ 12580' CAPITAL RKB. PULL 4.5" EVO TREVE PLUG @ 12600' RKB. PULLED DUAL FLAPPER VLV @ 13678' RKB. **NO VISIBLE DEFECT IN VLV**. SET 2.81" XX PLUG @ 13678' RKB. MITT TO 5200 psi. **PASS**. MIT -IA TO 3850 psi. **PASS**. PULL 2.81" XX PLUG @ 13678' RKB. **READY FOR FRAC**. 6/13/19 DRILLING PERFORMED FRACTURE STIMULATION TREATMENT OF SUPPORT - INTERVALS 1 - 5 PER DESIGN, RAMPING 20/40 WANLI CAPITAL PROPPANT FROM 1 - 4 PPG STAGES PUMPING 25# HYBOR-G FLUID SYSTEM AT 31 - 39 BPM. PLACED TOTAL PROPPANT VOLUME OF 358,367#. FREEZE PROTECTED TUBING WITH 35 BBL LVT. RELOAD SAND AND SEAWATER FOR INTERVALS 6 - 10 TREATMENT. JOB IN PROGRESS. 6/15/19 DRILLING PERFORMED FRACTURE STIMULATION TREATMENT OF SUPPORT -STAGES 6 - 10. CAPITAL PUMPED #25 HYBOR-G XLINK WITH 20/40 WANLI PROPPANT. STAGE 6 PUMPED 1 - 4 PPG SLURRIES AT 35 BPM. STAGES 7 - 10 PUMPED 1 - 6 PPG SLURRIES AT 40 BPM. TOTAL PROPPANT = 436,334#. FREEZE PROTECTED WELL WITH 35 BBL LVT MINERAL OIL. JOB COMPLETE. Hydraulic Fracturing Fluid Product Component Information Disclosure ® Job Start Date Job End Date dell State E. County ® API Number: Operator Name: dell Name and Number: E. Latitude: Longitude: . Datum: IST Federal Well: Ingredient Indian Well: True Vertical Depth: Total Base Water Volume (gal): Total Base Non Water Volume: 6/13/2019 6/15/2019 Alaska Harrison Bay 50-103-20799-00-00 ConocoPhillips Company/Burlington Resources CD5-24 Hvdraulic Fracturina Fluid Composition: 70.31329100 151.22617200 NAD83 NO NO 7,832 571,797 0 RaC FOCUS Chemical Disclosure Registry GROUNDWATER Oil&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)" rl. by mass)"' Sea Water Operator Base Fluid Water 7732-18-5 96.00000 81.29094 Density = 8.390 Ingredients Listed Above Listed Above Water 7732-18-5 100.00000 0.06705 CL-31 CROSSLINKER Halliburton Crosslinker Listed Below SP BREAKER Halliburton Breaker Listed Below SAND-COMMON WHITE-100 MESH, SSA-2, BULK (100003676) Halliburton Proppant Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below Wanli 20/40 Wadi Proppant Company Additive Listed Below MO-67 Halliburton pH Control Additive Listed Below BE-6 MICROBIOCIDE Halliburton Biocide Listed Below CL-22 UC Halliburton Crosslinker Listed Below OPTIFLO-III Halliburton Breaker DELAYED RELEASE BREAKER Listed Below WG -36 GELLING Halliburton Gelling Agent AGENT Listed Below items above are Trade Names with the exception of Base Water items belm are the individual ingredients Corundum 1302-74-5 1 65.00000 9.12550 Mullite 1302-93-8 45.00000 6.31765 Sodium chloride 7647-14-5 4.00000 3.38819 Crystalline silica, quartz 14808-60-7 100.00000 0.80048 Guar gum 9000-30-0 100.00000 0.24141 Borate salts Proprietary 60.00000 0.05749 Potassium formate 590-294 60.00000 0.05749 Ethanol 64-17-5 60.00000 0.04340 Oxylated phenolic resin Proprietary 30.00000 0.02894 Potassium metaborate 13709-94-9 60.00000 0.02761 Heavy aromatic 64742-94-5 petroleum naphtha 30.00000 0.02170 Ammonium persulfate 7727-54-0 100.00000 0.02030 Cured acrylic resin Proprietary 30.00000 0.00609 Naphthalene 91-20-3 5.00000 0.00362 Poly(oxy-1.2-ethanediyl), 127087-87-0 alpha-(4-nonylphenyl)- omega-hydroxy-, branched 5.00000 0.00362 Sodihydroxide 1310-73-2 umium 30.00000 0.00321 Potass hydroxide 1310-58-3 5.00000 0.00230 2-Bromo-2-nitro-1,3- 52-51-7 propanediol 100.00000 0.00152 Acrylate polymer Proprietary 1.00000 0.00096 Denise Tuck,, 3000 N. Sam Houston Pkwy E., - Houston, TX 77032, 281-871-6226 Sodium glycollate 2836-32-0 1.00000 0.00096 Sodium carboxymethyl 9004-32-4 1.00000 0.00096 cellulose 1,2,4 Tnmethylbenzene 95-63-6 1.00000 0.00072 Sodium persuHate7775-27-1 100.00000 0.00032 Sodium sulfate 7757-82-6 0.10000 0.00000 ' Total Water Volume sources may include various types of water including fresh water, produced water, and recycled! water " Information is based on the maximum potential for concentration and thus the total may be over 100% 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 FOP), 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) HALLIBURTON r Conoco Phillips Alaska CD5-24 Intervals 1-10 A -Sand Formation Harrison Bay County, AK API: 50-103-20799 Prepared for: Adam Klem 6/15/219 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. MALLIBURTON Table of Contents Page(S) Conoco Phillips Alaska - CD5-24 TOC 3 &ecutive Summary Wellbore Information 4 5-6 Actual Design Interval Summary 7 -17 Fluid System-Proppant Summary 18 Interval l Plots 19-29 Interval2 Plots 30-33 Interval3 Plots 34-37 Inteml4 Plots 38.41 Interval5 Plots 42.45 Interval 6 Plots 46-53 Intenral 7 Plots 54-S7 Interval8 Plots 58-61 lntenral9 Plots 62-65 Interva110 Plots 66-69 Appendix 70 Well Summary 71 Chemical Summary 72 Planned Design 73-74 Water Straps Day 1 75 Water Straps Day 2 76 Water Analysis Day 1 77 Water Analysis Day 2 78 Real -Time QC 19 Fann 15 Field Break Test Day 1 80 Fann 15 Field Break Test Day 2 81 Fann 15 Zone 1 82 Fann 15 Zone 2 83 Fann 15 Zone 3 84 Fann 15 Zone 4 85 Fann 15 Zone 5 86 Fann 15 Zone 6 87 Fann 15 Zone ] 88 Fann 15 Zone 8 89 Fann 15 Zone 9 90 Fann 15 Zone 10 91 Event Log Day 1 92 Event Log Day 2 93 Lab Testing 94-s5 Conoco Phillips Alaska - CD5-24 TOC Engineering Executive Summary On June 13, 2019 a stimulation treatment was performed in the A -Sand formation on the CD5-24 well in Harrison Bay County, AK. The CD5-24 was a 10 stage Horizontal Sleeve Design. The proposed treatment consisted of: 1,000 gallons of Sea Water 446,842 gallons of #25 HyborG 34,252 gallons of #25 WaterFrac G 1,000 gallons of Freeze Protect 790,728 pounds of Wanli 20/40 The actual treatment fully completed 10 of 10 stages. 0 stages were skipped, and 0 stages screened out or were otherwise cut short of design. The actual treatment consisted of: 0 gallons of Sea Water 510,450 gallons of #25 HyborG 61,347 gallons of #25 WaterFrac G 0 gallons of Freeze Protect 795,380 pounds of Wanli 20140 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: During the Job the ADP had issues with the computer freezing up. During Interval 6, the ADP froze in 1ppg proppant, requiring the well to be flushed. The computer was reset. After resetting the computer there was a secondary issue with the mixing bowl that required shutting down to fix. During Interval 9 the computer froze on the ADP a second time during proppant. The ADP was run in manual to finish the proppant and flush the well. In order to have excess water in case of any other events, operations were suspended between intervals 9 and 10 to fill water. During the refill the ADP computer was removed and replaced. After pumping the Minifrac, pad volumes were increased. MO -67 concentrations were adjusted to maintain a pH near 10. Rate was increased to 40bpm based off of treating pressures and downhole responses. All Freeze Protect was pumped by Little Red after the frac had concluded and a 5-10-15 minute was taken. Each Freeze Protect was 35bbl of LVT. 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. 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 - CD5-24 Executive Summary Conoco Phillips Alaska-CD5-24 Wellbore Information IT 31, Conoco Phillips Alaska-CD5-24 Wellbore Information Conoco Phillips Alaska-CD5.24 Actual Design Conoco Phillips Alaske - cosQJ Actual Design CD5-24 - A -Sand - Interval 1 14.6 Interval Summary Start DatelTime: 6/13/19 11:04 End Date/Time: 6/13/19 13:23 Pump Time: 139 min Initial Rate (Breakdown): 14.6 bpm Initial Surface Pressure (Breakdown): 2,617 psi Initial BH Pressure (Breakdown): 5,394 psi Max Rate: 36.2 bpm Max Surface Pressure: 5,437 psi Max BH Pressure: 7,369 psi Average Rate: 31.7 bpm Average Missile Pressure: 4,553 psi Average Surface Pressure: 4,538 psi Average BH Pressure: 6,704 psi Average Missile HHP: 3,533 hhp Initial OA Pressure: 0 psi Max OA Pressure: 51 psi Max Proppant Concentration: 4.02 Ppg Average Visc: 19 cp Average Temp: 80.66 F Average pH: 10.25 ISDP: 4867 psi Final Fracture Gradient: 0.628 Pam Final 5 min: 4817 psi Final 10 min: 4802 psi Final 15 min: 4792 psi Proppant Summary Wanli 20/40 Pumped: 69,001 lbs Total Proppant Pumped' : 69,001 lbs Proppant in Formation: 69,001 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #25 HyborG Volume: 72,097 gal 1,717 bbis #25 WaterFrac G Volume: 13,795 gal 328 bbis Fluid Summary (by stage description) Pad Volume: 17,925 gal 427 bbis Proppant Laden Fluid Volume: 33,151 gal 789 bbis Spacer Volume: 3,479 gal 83 bbis Flush Volume: 13,795 gal 328 bbis Minifrac Volume: 4,210 gal 100 bbis Spacer and Ball Drop Volume: 1,363 gal 32 bbis Flood Lines Volume: 11,969 gal 285 bbis Interval Status: Completed Conoco Phillips Alaska - CD5-24 Interval Summary 7 head opened at 680psi surface pressure, 3620psi downhole. uue to pressure response far ig the minifrac was capped at 28bpm. Due to high pH samples, the concentration of MO - as dropped down to 0.15gpt. Minifrac Started at 11:04 and finished at 11:37. Max Pressure 6393psi surface, 8586psi downhole. Average pressure was 3554psi surface, 5936psi nhole and 3539psi on the missile. Average rate for the minifrac and flush was 27.71 bpm, 5bpm for the entire zone. Pumped for 33 minutes. Well restarted pumping at 12:39. Pad nes increased after minifrac results. )r proppant are taken from software calculations based on multiple variables. Is billed off of weight ticket volumes and may vary slightly from this number Conoco Phillips Alaska - CD5-24 Interval Summary Engineer. Keegan Lambe Treater: Daniel Faur Supervisor: Chad Burkett Customer Engineer Scott Pessetto Customer Rep: Phil Rafferty - Interval 2 Start Date/Time: 6/13/19 13:23 End Datelfime: 6/13/19 14:04 Pump Time: 41 min Initial Rate (Breakdown): 15.4 bpm Initial Surface Pressure (Breakdown): 6,067 psi Initial BH Pressure (Breakdown): 7,920 psi Max Rate: 35.2 bpm Max Surface Pressure: 5,048 psi Max BH Pressure: 7,037 psi Average Rate: 33.3 bpm Average Missile Pressure: 4,503 psi Average Surface Pressure: 4,486 psi Average BH Pressure: 6,703 psi Average Missile HHP: 3,680 hhp Initial OA Pressure: 51 psi Max OA Pressure: 198 psi Max Proppant Concentration: 3.98 ppg Average Visc: 20.4 CP Average Temp: 81.8 F Average pH: 10.08 Proppant Summary Wanli 20/40 Pumped: 74,222 lbs Total Proppant Pumped' : 74,222 lbs Proppant in Formation: 74,222 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls #25 HyborG Volume: 52,266 gal 1,244 bbls #25 WaterFrac G Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 18,031 gal 429 bb/s Proppant Laden Fluid Volume: 32,858 gal 782 bbls Spacer and Ball Drop Volume: 1,377 gal 33 bbls Interval Status: Completed for proppant are taken from software calculations based on multiple variables t is billed off of weight ticket volumes and may vary -slightly from this number. rieatec Daniel Faur Supervisor Chad Burkett Customer Engineer. ScottPessetto Customer Rep: Phil Rafferty Conoco Phillips Alaska - CD5-24 Interval Summary 9 s-e.�rre Start Date/Time: 6/13/19 14:04 End Date/Time: 6/13/19 14:40 Pump Time: 36 min Initial Rate (Breakdown): 15.5 bpm Initial Surface Pressure (Breakdown): 6,038 psi Initial BH Pressure (Breakdown): 7,900 psi Max Rate: 39.7 bpm Max Surface Pressure: 5,588 psi Max BH Pressure: 7,247 psi Average Rate: 36.9 bpm Average Missile Pressure: 4,646 psi Average Surface Pressure: 4,630 psi Average BH Pressure: 6,632 psi Average Missile HHP: 4,198 hhp Initial OA Pressure: 194 psi Max OA Pressure: 318 psi Max Proppant Concentration: 3.89 Ppg Average Visc: 19 cP Average Temp: 84.4 F Average PH: 9.88 proppant Summary Wanli 20140 Pumped: 68,475 lbs Total Proppant Pumped' : 68,475 lbs Proppant in Formation: 68,475 lbs Fluid Summary (by Fluid description) Sea Water Volume: 0 gal 0 bbis #25 HyborG Volume: 52,096 gal 1,240 bbis #25 WaterFrac G Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 18,003 gal 429 bbls Proppant Laden Fluid Volume: 33,150 gal 789 bbis Spacer and Ball Drop Volume: 943 gal 22 bbls Interval Status: Completed Pad Volume extended to 425bbl. Pumped to design. Engineer: Keegan Lambe Treater: Daniel Faur Supervisor: Chad Burkett 'Valuos for proppant are IaFen from software calculations based on maniple variables Customer Engineer Scott Pessetto Proppant is billed off of weight ticket volumes and may vary slightly from this number Customer Rep: Phil Rafferty Conoco Phillips Alaska - CD5-24 Interval Summary 10 CD5-Y4 - A -Sand - Interval 4 Interval Summary Start Date/Time: 6/13/19 14:40 End Date/Time: 6/13/1915:16 Pump Time: 36 min Initial Rate (Breakdown): 15.4 bpm Treater.' Initial Surface Pressure (Breakdown): 6,018 psi Chad Burkett 'Values for proppent are taken from software celculallons based on multiple variables. Initial BH Pressure (Breakdown): 7,657 psi Customer Rep: Phil Rafferty Max Rate: 39.7 bpm Max Surface Pressure: 6,026 psi Max BH Pressure: 7,911 psi Average Rate: 36.7 bpm Average Missile Pressure: 4,656 psi Average Surface Pressure: 4,648 psi Average BH Pressure: 6,635 psi Average Missile HHP: 4,189 hhp Initial OA Pressure: 317 psi Max OA Pressure: 379 psi Max Proppant Concentration: 3.94 Ppg Average Visc: 19.8 CP Average Temp: 85 F Average pH: 9.92 Proppant Summary Wanli 20/40 Pumped: 69,881 lbs Total Proppant Pumped' : 69,881 lbs Proppant in Formation: 69,881 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls #25 HyborG Volume: 52,083 gal 1,240 bbls #25 WaterFrac G Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pad Volume: 17,892 gal 426 bbls Proppant Laden Fluid Volume: 32,976 gal 785 bbls Spacer and Ball Drop Volume: 1,215 gal 29 bbls Interval Status: Completed Pad Volume extended to 425bbl. Pumped to design. Engineer.. Keegan Lambe Treater.' Daniel Faur Supervisor: Chad Burkett 'Values for proppent are taken from software celculallons based on multiple variables. Customer Engineer. Scott Pessetto Proppam is billed off of weight ticket volumes and may vary slightly frau this number Customer Rep: Phil Rafferty Conoco Phillips Alaska - CD5-24 Interval Summary 11 CD5-24 - A -Sand - Interval 5 Interval Summary Start Date/Time: 6/13/19 15:16 End Date/Time: 6/13/19 15:59 Pump Time: 43 min Initial Rate (Breakdown): 15.4 bpm Initial Surface Pressure (Breakdown): 6,018 psi Initial BH Pressure (Breakdown): 7,657 psi Max Rate: 39.8 bpm Max Surface Pressure: 5,183 psi Max BH Pressure: 6,900 psi Average Rate: 38.7 bpm Average Missile Pressure: 4,617 psi Average Surface Pressure: 4,621 psi Average BH Pressure: 6,551 psi Average Missile HHP: 4,374 hhp Initial OA Pressure: 369 psi Max OA Pressure: 416 psi Max Proppant Concentration: 3.92 Ppg Average Visc: 18.4 CP Average Temp: 9.78 F Average pH: 66.4 ISDP: 5134 psi Final Fracture Gradient: 0.664 psi/ft Final min: 5023 psi Final 10 min: 4996 psi Final 15 min: 4982 psi Proppant Summary Wanli 20/40 Pumped: 76,788 lbs Total Proppant Pumped" : 76,788 lbs Proppant in Formation: 76,788 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #25 HyborG Volume: 52,659 gal 1,254 bbis #25 WaterFrac G Volume: 11,638 gal 277 bbis Fluid Summary (by stage description) Pad Volume: 17,951 gal 427 bbis Proppant Laden Fluid Volume: 34,708 gal 826 bbis Flush Volume: 11,638 gal 277 bbis Interval Status: Completed Comments: Pad Volume extended to 425bbl. Pumped to design. Little Red pumped 35bbl of LVT for Freeze Engineer: Keegan Lambe Protect. Treater Daniel Faur Supervisor: Chad Burkett 'Values for pmppant aretaken from software calculations based on multiple vanables. Customer Engineer. Scott Pessetto Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Phil Rafferty Conoco Phillips Alaska - CD5-24 Interval Summary 12 Start Date/Time: 6115/19 9:42 End Date/Time: 6115/19 11:20 Pump Time: 98 min Initial Rate (Breakdown): 15.4 bpm Initial Surface Pressure (Breakdown): 5,372 psi Initial BH Pressure (Breakdown): 7,058 psi Max Rate: 40.3 bpm Max Surface Pressure: 5,447 psi Max BH Pressure: 6,928 psi Average Rate: 21.2 bpm Average Missile Pressure: 3,016 psi Average Surface Pressure: 2,977 psi Average BH Pressure: 5,447 psi Average Missile HHP: 1,569 hhp Initial OA Pressure: 0 psi Max OA Pressure: 235 psi Max Proppant Concentration: 4.05 PPg Average Visc: 20 cP Average Temp: 95.2 F Average pH: 9.78 Proppant Summary Wanli 20/40 Pumped: 71,042 lbs Total Proppant Pumped" : 71,042 lbs Proppant in Formation: 71,042 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #25 HyborG Volume: 62,277 gal 1,483 bbis #25 WaterFrac G Volume: 17,132 gal 408 bbis Fluid Summary (by stage description) Pre -Pad Volume: 7,109 gal 169 bbis Pad Volume: 17,921 gal 427 bbis Proppant Laden Fluid Volume: 35,574 gal 847 bbis Flush Volume: 17,132 gal 408 bbis Spacer and Ball Drop Volume: 1,673 gal 40 bbis Interval Status: Completed pad stage one of the pumps lost ahead gasket. ADP Computer froze, requinng a flush to Engineer: Keegan Lambe ie computer. After reestablishing crosslink, ADP mixer bowl would not spin. Came down to Treater. Daniel Faur he mixing bowl. Stepped back into the Proppant in 0.5ppg intervals. Pumped from 09:43 to Supervisor: Chad Burkett 10:29 to 10:33 and 10.56 to 11:20 for a total of 63 minutes. Well was opened at 09:42. I Customer Engineer Scott Pessetto Customer Rep: Phil Rafferty Conoco Phillips Alaska - CD5-24 Interval Summary 13 - Interval 7 Start Date/Time: 6/15/19 11:20 End Date/Time: 6/15/19 11:50 Pump Time: 30 min Initial Rate (Breakdown): 15.6 bpm Initial Surface Pressure (Breakdown): 5,553 psi Initial BH Pressure (Breakdown): 7,321 psi Max Rate: 40.5 bpm Max Surface Pressure: 5,280 psi Max BH Pressure: 6,802 psi Average Rate: 37.2 bpm Average Missile Pressure: 4,220 psi Average Surface Pressure: 4,181 psi Average BH Pressure: 6,181 psi Average Missile HHP: 3,845 hhp Initial OA Pressure: 233 psi Max OA Pressure: 382 psi Max Proppant Concentration: 5.95 Jut Average Visc: 18 cP Average Temp: 93.1 F Average pH: 9.87 Proppant Summary Wanli 20140 Pumped: 89,320 lbs, Total Proppant Pumped" : 89,320 lbs Proppant in Formation: 89,320 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls #25 HyborG Volume: 41,609 gal 991 bb/is #25 WaterFrac G Volume: 0 gal 0 bb/s Fluid Summary (by stage description) Pad Volume: 14,842 gal 353 bbls Proppant Laden Fluid Volume: 25,504 gal 607 bbls Spacer and Ball Drop Volume: 1,263 gal 30 bbls Interval Status: Completed Interval pumped to design prop. Increased rate to 40bpm. Engineer: Keegan Lambe Treater. Daniel Faur Supervisor. Chad Burkett 'Values for pricall are taken from software calculations based on multiple variables Customer Engineer. Scott Pessetto Proppam is billed off of weight ticket volumes and may vary slightly train this number Customer Rep: Phil Rafferty Conoco Phillips Alaska - CDS-24 Interval Summary 14 CD5-24 - A -Sand - Interval 8 Interval Summary Start Date/Time: 6/15119 11:50 End Date/Time: 6/15/19 12:18 Pump Time: 28 min Initial Rate (Breakdown): 15.7 bpm Treater: Initial Surface Pressure (Breakdown): 2,721 psi Chad Burkett 'Values for proppant are taken from software calculations based on multiple variables Initial BH Pressure (Breakdown): 7,048 psi Customer Rep: Phil Rafferty Max Rate: 40.6 bpm Max Surface Pressure: 5,147 psi Max BH Pressure: 6,788 psi Average Rate: 38.2 bpm Average Missile Pressure: 4,236 psi Average Surface Pressure: 4,199 psi Average BH Pressure: 6,227 psi Average Missile HHP: 3,961 hhp Initial OA Pressure: 381 psi Max OA Pressure: 473 psi Max Proppant Concentration: 6.24 ppg Average Visc: 17 cP Average Temp: 94.1 F Average pH: 9.81 Proppant Summary Wanli 20/40 Pumped: 92,110 lbs Total Proppant Pumped- : 92,110 lbs Proppant in Formation: 92,110 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #25 HyborG Volume: 41,088 gal 978 bbls #25 WaterFrac G Volume: 0 gal 0 bbls Fluid Summary (by stage description) Pre -Pad Volume: 0 gal 0 bbis Pad Volume: 14,866 gal 354 bbls Proppant Laden Fluid Volume: 24,975 gal 595 bbis Spacer and Ball Drop Volume: 1,247 gal 30 bills Interval Status: Completed Interval pumped to design. Rate increased to 401opm. Engineer: Keegan Lambe Treater: Daniel Faur Supervisor: Chad Burkett 'Values for proppant are taken from software calculations based on multiple variables Customer Engineer Scott Pessett0 Pmppant Is billed off of weight ticket volumes and may vary slightly from this number Customer Rep: Phil Rafferty Conoco Phillips Alaska - CDS-24 Interval Summary 15 IWe rre Start Date/Time: 6/15/19 12:18 End Date/Time: 6/15/19 12:53 Pump Time: 35 min Initial Rate (Breakdown): 15.7 bpm Initial Surface Pressure (Breakdown): 5,134 psi Initial BH Pressure (Breakdown): 7,048 psi Max Rate: 41.3 bpm Max Surface Pressure: 5,360 psi Max BH Pressure: 6,591 psi Average Rate: 39.8 bpm Average Missile Pressure: 4,399 psi Average Surface Pressure: 4,366 psi Average BH Pressure: 6,109 psi Average Missile HHP: 4,286 hhp Initial OA Pressure: 473 psi Max OA Pressure: 536 psi Max Proppant Concentration: 6.60 ppg Average Visc: 19 CP Average Temp: 94.1 F Average pH: 9.83 ISDP: 5026 psi Final Fracture Gradient: 0.654 psw Final 5 min: 4871 psi Final 10 min: 4823 psi Final 15 min: 4789 psi Proppant Summary Wanli 20/40 Pumped: 95,003 lbs Total Proppant Pumped' : 95,003 lbs Proppant in Formation: 95,003 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #25 HyborG Volume: 40,045 gal 953 bbis #25 WaterFrac G Volume: 9,677 gal 230 bbis Fluid Summary (by stage description) Pad Volume: 14,730 gal 351 bbis Proppant Laden Fluid Volume: 25,315 gal 603 bbis Flush Volume: 9,677 gal 230 bbis Interval Status: Completed IP Screen from again during the interval. Finished the zone and Hushed the well. uunng tiro one the pumps had an internal issue. Rate was swapped around. During the rate drop the proppant ncentration spiked up to 6.6ppg. Rate increased to 40bpm. for proppant are taken from software calculations based on multiple variables. t is billed off of weight ticket volumes and may vary slightly from this number_ Engineer: Keegan Lambe Treater. Daniel Faur Supervisor Chad Burkett Customer Engineer. Scott Pessetto Customer Rep: Phil Rafferty Conoco Phillips Alaska - CD5-24 Interval Summary 16 CD5-24 - A -Sand - Interval 10 15.4 Interval Summary Start Date/Time: 6/15119 15:47 End Date/Time: 6/15119 16:27 Pump Time: 40 min Initial Rate (Breakdown): 15.4 bpm Initial Surface Pressure (Breakdown): 5,155 psi Initial SH Pressure (Breakdown): 7,267 psi Max Rate: 41.0 bpm Max Surface Pressure: 5,987 psi Max BH Pressure: 6,232 psi Average Rate: 34.7 bpm Average Missile Pressure: 3,948 psi Average Surface Pressure: 3,908 psi Average BH Pressure: 5,731 psi Average Missile HHP: 3,360 hhp Initial OA Pressure: 61 psi Max OA Pressure: 289 psi Max Proppant Concentration: 5.90 A09 Average Visc: 18 cP Average Temp: 85.3 F Average pH: 9.64 ISDP: 5063 psi Final Fracture Gradient: 0.660 psil t Final 5 min: 4984 psi Final 10 min: 4923 psi Final 15 min: 4876 psi Proppant Summary Wanli 20/40 Pumped: 88,859 Ibs Total Proppant Pumped' : 88,859 lbs Proppant in Formation: 88,859 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis #25 HyborG Volume: 44,230 gal 1,053 bb/s #25 WaterFrac G Volume: 9,105 gal 217 bbis Fluid Summary (by stage description) Pad Volume: 14,728 gal 351 bbis Proppant Laden Fluid Volume: 25,556 gal 608 bbis Flush Volume: 9,105 gal 217 bbis Spacer and Ball Drop Volume: 3,946 gal 94 bbis Interval Status: Completed re Interval 10 was started, water tanks were sucked dry and the bottoms placed Into a to consolidate fluid. A single water truck was offloaded as well. Zone pumped to fluid i Red pumped 35 bbl LVT for freeze protect. for proppant are taken from software calculations based on multiple variables. t is billed off of weight ticket volumes and may vary slightly from this number. Treater Daniel Faur Supervisor: Chad Burkett Customer Engineer. Scott Pessetto Customer Rep: Phil Rafferty Conoco Phillips Alaska - CD5-24 Interval Summary 17 Customer Conoco Phillips Alaska Formation A -Sand teare Cos -24 API 50-10380799 Elate lune 13, 2019 Wellsummary HALLIBURTON a a tl flc,.[orde0 Fluids Prospremints Interval AverageMax Sea Water 925 Hirt.. X25 Watv,Fmr G Tmal Fluid Wanii 20/40 Total Proppant al bbl 61 Pmssure Pate Visc Temp pH BH Pressure Bate gal bbl 790728 790728 bbl gal bbl gal bbl It, Ibs 1 2 4 6 0 9 10 6704 6703 E632 6635 6551 5447 6181 6227 6109 1 5731 31.7 33.3 36.9 36.7 J. 21.2 37.2 38.2 398 34.7 19 M 19 20 18 20 18 17 19 18 8066 82 84 85 10 95 93 94 94 85 103 7369 10.1 7037 9.9 ]24] 9.9 7911 86.4 6900 9.8 6928 9.9 6802 9.8 6]88 9.8 6591 9.5 6232 36.2 353 397 393. 39.8 40.3 40.5 40.6 a1.3 41.0 ]2,09] 52,M5 52,096 52,003 52.659 62,M 41,609 43,086 48045 44230 1,]3] 1,244 1,240 1,240 1.254 1,403 991 9]8 953 1,053 13,795 11,630 17,02 9fi]> 9,105 328 277 408 230 217 85,892 52,266 52,096 52,083 64,297 29,409 41,609 41,088 49,]22 53,335 2045 2,2" 3,240 1,240 1531 11891 991 WB 1.184 1,270 69,001 74,222 68,475 69,881 76,788 71,042 89320 92,ll0 95,003 80059 69,001 74,222 68,475 69'881 76,788 71,042 89,320 93,110 95.003 80,059 Minimum Average Maximum '00"53 511145 72097 1215 1]1] 9105 12269 17132 217 M2 408 41088 5] 160 85892 978 ]363 2045 68475 ]9470 95003 68415 ]94]0 95003 tl flc,.[orde0 ' UPS members for proppantare taken M1om soLLson. "Proppant is billed from Weight Ticket volumes Conoco Phillips Alaska -C05-24 Flub System-Proppant Summary 18 Fluids PmPPants Average Mex gas Water 925 Hygienist 125 Wateffe" Total Fluid Wan1120/40 Total Procreator Pressure Rare V- Temp pH Pressure Rate gal bbl al bbl al had gal bbl Ibs TWI 1.000 24 446.842 10,639 34252 016 483,096 11,502 790728 790728 3.51 79ll 41.3 0 0 S10p50 1J, 154 61.34] 1,461 503,]97 13,614 T94,]Ol ]94,]01 12Stl JO Ifi Weight THkett ]95,300 795,380 ' UPS members for proppantare taken M1om soLLson. "Proppant is billed from Weight Ticket volumes Conoco Phillips Alaska -C05-24 Flub System-Proppant Summary 18 Pressure Test - Day 7 111 Global Kickout Pressure (psi) P1 Kickout Pressure (Psi) J 6I112D19 Time till.,<Ul7 Global Event Log 04 Pressure Test-Globals 10:20:47 ❑5 Pressure Test -Locals 10:21:02 Q Pressure Test -Max Pressure 9481 psi 10:26:14 ❑7 Pressure Test -S Minute 10:31:14 ❑8 Pressure Test -Good Test 10:31:48 Customer: CONOCOR-0LLPS NORTH SLOPE- EBUS I Job Date: 13 -Jun -2019 Well Oescription: CD524 LAM: 50-10320799 Conoco Phillips Alaska -CDS -24 Interval I Plots 19 Pop -Off Test - Day 1 11 Global Kickout Pressure (psi) Pt Kickout Pressure EMM19 rY13ILu1Y Time Global Event Log F[CN2 Pop Off Test 10:34:04 N2 Pop@ 7721psi 10:37:27 N2 Pop 7733 10:44:27 Good Test Bleed Down 10:46:05 Customer: CONOCOPHILLIPS NORTH SLOP E-EBUSJob Date: 13,1un-2019 Sales Order#: 905713807 --e Wel Description: CD524 UWI: 50.101 Conoco Phillips Alaska -CDS -24 Interval l Plots 2D A 3.1 2.: 2. 1 3 0.( Blender Chemical Plot - Dav One Bucket Tests 61 CL -3i Conc(gal/Mgal) A 81 CL -22 UC Conc -LA2 (gal/Mgal) A B1 Opliflo-III Conc -DA2 (Ib/Mgal) B 81 SP Breaker Conc -DA1 (Ib/Mgal) B E I E i i Oustorrer: 08:08 0809 08:10 08:11 08:12 &t12019 fi113/2019 Time CONOCOPFYLLIPS NORTH SLOPE- EBU3 I =Date: 13-Jun2079 Sales Ortler #: 905713907 ""-" 1: CDS 24 INN: 50.103-20799 Conoco Phillips Alaska-CD5-24 Interval t Plots 21 ADP Chemical Plot - Dav One Bucket Tests A I B2 MO -67 Conc -LA5 (gal/Mgal) A I B 08:20 06:22 08:24 08:26 08:26 08:30 W WM19 &1Y2019 Time Custorrer: CONOCOPHLLIPS NORTH SLOPE- EBUS Job Date: 13 -Juin -2019 Sales Order #: 9057138D7 Well Description: CD524 LAA1: 50-10&20799 Conoco Phillips Alaska -CD5Q6 Interval l Plots 22 Treatment Plot - MiniFrac Slurry Proppant Conic (Ib/gal) A B Gauge BH Pres (psi) C BH Proppant Conc (Ib/gal) A Actual BH Temp (`F) — C D C D 6/13/2019 6113/2019 Time Custoner. OONOCOPHILLIPS NORTH SLOPE- EBL1S Job Date: 13Jsi 1 2019 Sales Order #: 905713607 vM, Description: CD524 INN: 50-10320799 Conoco Phillips Alaska -CDS-24 Interval 1 Plots 11 Blender Chemical Plot - MiniFrac A 3.( 2.'. 2.( 1.( 1.( 19 131 CL -31 Conic -tA1 (gal/Mgal) A Bt CL -22 UC Conic -LA2 (gal/Mgal) A 61 Optiflo-lll Conic -DA2 (Ib/Mgap B B1 SP Breaker Conic -DA1 (Ib/Mgal) B 1 I I I 0.0 11:05 11:10 11:15 11:20 11:25 11:30 11:35 6/132019 &13/2019 Time Custoi er: COWOCOPHILLIPS NORTH SLOPE- EBUS I Job Date: 13 -Jun -2019 Sales Order #: 905713607 WeliDescription: CD5 24 IPM: 50-103-20799 3 i 7 9 Conoco Phillipa Alaska -CDS -24 Int mall Plots 24 A 2.1 NEW ADP Chemical Plot - MiniFrac 82 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B 62 MO -67 Conc -LA5 (gaVMgal) A i I 11:10 11:15 11:20 11:25 11:30 11:35 613/2019 Time 6/3/2019 Custorter. CONOODWILLIPS NORTH SLOPE- EBUS I Job Date: 134un-2019 Sales Order #: 905713807 Well Descripton: CD524 LMA: 50-103-20799 B 125 M 75 i0 25 11 Conoco Phillips Alaska-C05�24 Interval1 Plots 25 Treatment Plot - Interval 7 Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C B Gauge SH Pres (psi) A Actual BH Temp ('F) D C D .,.: u1e 6'1312019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBIAS I =Date: .13j. 019 Sales Order #: 905713607 V Ul Description: CD524 IPM: 50-10320799 75 50 25 00 Conoco Phillips Alaska - CD5-24 Intervall Plotz 26 A 3.( 2.5 2.( 1.0 0.' 0.0 12:40 12:50 13:00 13:10 13:20 13:30 6/1&2019 Time eINW19 Customer: CONOCOPFNLLIPS NORTH SLOPE- EBUS I Job Date: 13 -Jun -2019 Sales Order #: 905713607 Well Description: CD524 LMA: 5Q103_20799 Blender Chemical Plot - Interval 1 B1 CL -31 Conic -LAI (gal/Mgal) A B1 CL -22 UC Conc -LA2 (gaUMgal) A Bt Optiflo-lll Conc -DA2 (Ib/Mgal) B B1 SP Breaker Conc -DAT (Ib/Mgal) B I 3 i 4 3 0 Conoco Phillips Alaska-CD5-24 Interval I Plots 27 ADP Chemical Plot - Interval 1 B2 Lo9urt-3oDD Conc -LA2 (gal/Mgal) A 82 WG -36 Conc -DA1 (Ib/Mgal) B B2 MO -67 Conc -IJ15 (gal/Mgal) A I i I 0.0 12:40 12:50 13:00 13:10 13:20 1330 6I13r2019 Time WIN2019 Oustorrer. CONOOOPHILLIPS NORTH SLOPE- EBUS I .lob Date: 73Jun2019 Sales Order 7k: 905773607 Well Description: CDS 24 LW: 50-10320799 B 125 M 75 i0 t5 11 Conoco Phillips Alaska - CD5-24 Interval 1 Plots 28 Net Pressure Plot - Interval 1 — Net auge BH Pres (psi) A A —BH Proppant Conc (Ib/gal) B B Time (min) Customer: CONOCOPHLLIPS NORTH SLOPE- EBUS Job Date: 13 -Jun -2019 Seles Order #: 905713807 Well Des liptbn: CD524 NM: 50.103-20799 Conoco Phillips Alaska-CD5-24 Interval l PbU 29 A B 10000, 1 8000 7000 1 Treatment Plot - Interval 2 Treating Pressure (psi) A Slurry Rate (bpm) E >lurry Proppant Cone (Ib/gap C BH Proppant Cone (Ib/gal) C D 0 x251 13:30 13:40 13:50 14:00 14:10 61132010 &132019 Time Customer: CONOCOPHILLIPS NORTH SLOPE -EBUS Job Date: 13 -Jun -2019 I Saks Ohler* 905713607 —' Wel Description: CDs 24 1 ME 50-103-20799 175 150 125 100 75 Conoco Phillips Alaska -CDS -24 Interval2 Plotz 30 Blender Chemical Plot - Interval 2 B1 ClMgal) A 31 CL -22 UC Cone -LA2 (gaW l) A A 61 OptiHo-lll Conc -DA2 (Ib/Mgal) B 131 SP Breaker Cone -DA1 (Ib/Mgal) B I B 13:30 13:40 13:50 14:00 14:10 &1N2019 e11312019 Time Customer: CONOCOPHLLIPS NORTH SLOPE- BBUS I Job Date: 13-J2019Sales Order #: 905713807 Well Description: CD524 Udvl: 50-10320799 Conoco Phillips Alaska - C135-24 Interval2 Plots 31 ADP Chemical Plot- Interval 2 B2 Lo'u6,' 00D Conc -LA2 (gal/Mgal) A B2 WG-36 Conic -DA1 (Ib/Mgal) B A 62 M067 Conc -LA5 (gal/Mgal) A 13:30 13:40 13:50 14:00 14:10 6I13I2019 6/13/2019 Time Custorrer CONOCOPHILLIPS NORTH SLOPE- EBt13 I Job Date: 13 -Jun -2019 I Sales Order #: 905713807 Well Descriptbrt: CDS 24 t4M: 50-103.20799 Conoco Phillips Alaska-CD5-24 lnW.12 Plats Net Pressure Plot - Interval 2 — Net Gauge BH Pres (psi) A A — BH Proppant Conc (Ib/gal) B B Time (min) Costorrrer CONOCOPHILLIPS NORTH SLOPE -EBUS I Job Dale: 13.1u 2019 Sales Order#: 9057131107 �p Well Desenptiom CD524 UWL 50-103-20799 Conoco Phillips Alaska -CDS-24 InWool2 Plots 33 1 1 Treatment Plot - Interval 3 Slurry Proppant Conc (Ib/gal) A B Gauge BH Pres (psi) C BH Pr, A Actual 1C (lb/gal) (°F) — C DI C D 6/132019 Time 6/132019 Cmtornec CONOCOPHILLIPS NORTH SLOPE -EBUS I Job Date: 13 -Ju 2019 Sales Orcler#: 905713807 V" Well Description: CD524 UWI: 50-10320799 175 150 125 100 Conoco Phillips Alaska -CDS-24 Interval3 Plots 34 Blender Chemical Plot - Interval 3 B1 CL -31 Cone -LA1 (gal/Mgal) A B1 CL -22 UC Cone -LA2 (gal/Mgap A A B1 Optiflo-III Cone -DA2 (Ib/Mgal) B B1 SP Breaker Cone -DA1 (Ib/Mgal) B B Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBLIS Job Date: 13 -Jun -2019 Sales Order #: 905713807 Wel Description: COS 24 UVN: 50-103-20799 Conoco Phillips Alazka -CDS-24 Interval3 Plots ADP Chemical Plot - Interval 3 B2 Losulf--300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B A B2 MO -67 Conc -LA5 (gal/Mgal) A rylanma Time 6/1312019 CLstw : CONOCOPHLLIPS NORTH SLOPE- EBLS I Job Date: 13 -Jun -2019 Sales Order #: 905713807 Well Description: CD524 LW: 50-103-20799 Conow Phillips Alaska -CDS-24 Interval3 Plots 36 Net Pressure Plot - Interval 3 — Net Gauge BH Pres (psi) A A — BH Proppant Conc (Ib/gal) B B I Time (min) C,-etomer: CONOCOPHILLIPS NORTH SLOPE -EBUS I Job Date: 13Jurv2019 Saks Ortler#: 905773607 Wei Description: CDs 24 UW, : 56103-20799 Conoro Phillips Alaska -C95 -)A Interval3 Plotz 37 Treatment Plot - Interval 4 Slurry Proppant Cone (Ib/gap C BH Proppant Cone (Ib/gal) C A B Gauge BH Pres (psi) A Aclual BH Temp ff) D C D 14:50 15:00 15:10 15:20 6113/2D19 &13/2019 Time Custonec CONOCOPHILLIPS NORTH SLOPE- EBUS I Job Date: 13Jun-2019 Sales Order #: 905713807 Wall Description: C05 24 UM 50-103-20799 75 .10 75 Conow Phillips Alaska-CD5-24 Inteml4 Mrs 38 Blender Chemical Plot - Interval 4 Bt CL -31 Conc -LA1 (gat/Mgal) A B1 CL -22 UC Conc -LA2 (gal/Mgal) A A Bt Optiflo-lll Conc -DA2 (Ib/Mgal) B B1 SP Breaker Conc -DA1 (ib/Mgal) B B Custo r: CONOCOPFILLIPS NORTH SLOPE- EB1S I Job Date: 13 -Jun -2019 Sales Order #: 905713807 Nell Description: CD524 WN: 50-103-20799 Conoco Phillips Alaska -CDS-24 Inte;al4 Plots ADP Chemical Plot - Interval 4 B2 Losurf-3DOD Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B A B2 MO -67 Conc -LA5 (gal/Mgal) A &1=01s Time enmzDts Custorter. CONOCOPHLLIPS NORTH SLOPE- EBL6 .bb Dale: 13-Jun-2019Saks Order #: 905713807 Well Description: CD5 24 11VN: 50.103-20799 Conoco Phillips Alaska - CDS-24 Interval4 Plots 40 Net Pressure Plot - Interval 4 — Net Gauge BH Pres (psi) A A — BH Proppant Conic (Ib/gal) B Time (min) Ctatomer: CONOCOPHILLIPS NORTH SLOPE -EBUS Job Date: 13,Iun-2019 Sales Order#: 905713607 Well Description: CD524 UWI: 50-103-20799 Conoco Phillips Alaska -2544 Intemal4 Plots Treatment Plot - Interval 5 Slurry Proppant Cone (Ib/gal) A B Gauge BH Pres (psi) — C BH Pr( A Actual Int Cone (lb/ga0 Temp ('F)— C D C lime Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS I Job Date: 13 -Jun -2019 Saks Order R: 905713807 Well Description: COS 24 UM 50-103-20799 75 50 25 00 Conan Phillips Alaska-CD5-24 Interval5 Plots 42 Blender Chemical Plot - Interval 5 31L-31 Conc -LA1 (gal/Mgap A 61 CL -22 LIC Conc -LA2 (gal/Mgap A A B1 OCptil 1 Conc -DA2 (Ib/Mgap B 61 SP Breaker Conc -DA1 (Ib/Mgap B B Time Custoner: CONDOOPHILLIPS NORTH SLOPE- EBUS Job late: 13-Jun2019 Sales Order k: 905713807 Well Description: CD524 lPM 50-103-20799 Conoco Phillips Alaska-CD5-24 Interval 5 Plots ADP Chemical Plot - Interval 5 A 2.( 1! U 1.( O.f O.E 0.4 0.`e B2 Los 3COOOD Conc -LA2 (gal/Mgal) A B2 WG -36 Cone -DA1 (Ib/Mgal) B 82 MOfi7 Conc -LA5 (gal/Mgal) A 0 I 0.0 15:20 15:25 15:30 15:35 15:40 15:45 15:50 15:55 1600 WINW19 WIW2019 Time Custoner: CONOCOPHLLIPS NORTH SLOPE- MUS Job Date: 13 -Jun -2019 Sales Order #: 905713807 ""'�" Wed Description: CD524 LAM: 50-103-20799 B 125 M 75 i0 15 Conoco Phillips Alaska -CDS-24 Intemal5 Plots 44 Net Pressure Plot - Interval 5 — Net Gauge BH Pres (psi) A A — BH Proppent Conc (Ib/gal) B B I Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE -EBUS Job Date: 13-Jun2019 ISales Orcler#: 905713807 WeliDescription: CD524 UWI: 50-103-20799 Coraco Phillips Alaska -CDS-24 Interval5 Plots 45 Pressure Test - Day 2 Treating Pressure (psi) Treating Pressure @Pump (psi) N Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 8/15/2019 6/152019 Time Oustooer: OONOOOR LLIPS NORTH SLOPE- ®US I Job Date: 15 -Jun -2019 Sales Order #: 0905713807 Well Description: CD524 LMIL 50-10320799 Conoco Phillips Alaska -CDS-24 Interval Plots 46 Global Event Log Q Pressure Test-Globals 08:45:51 0 Pressure Test -Locals 08:46:30 ❑7 Pressure Test- Max Pressure 9506psi 08:50:26 ❑8 Pressure Test -Good Test 085526 Oustooer: OONOOOR LLIPS NORTH SLOPE- ®US I Job Date: 15 -Jun -2019 Sales Order #: 0905713807 Well Description: CD524 LMIL 50-10320799 Conoco Phillips Alaska -CDS-24 Interval Plots 46 Nitrogen Pop -Off Test - Day 2 11 Global Kickout Pressure (psi) P1 Kickout Pressure (psi) 09:10 09:15 09:20 09:25 6/1512019 6/1Srz019 Time Global Event Log 12 No Pop 09:14:58 1© Pop Q 7767psi 09:21:30 [R Pop Q 7714psi 09:26:07 Customer: C ONOCOPHILLIPS NORTH SLOPE -EBUS Job Date: 15Jun-2019 Sales Orcler#:0905713807—' Well Description: CD524 UWI: 50-103-20799 Conoco Phillips Alaska -COS-24 Ma.16 Plots 47 Blender Chemical Plot - Day 2 Bucket Tests A I B1 Optl9o-111 Conc -DA2 (Ib/Mgap B B1 SP Breaker Conc -DAI (Ib/Mgap B I B ume Custoner: COHOOOPHILLIPS NORTH SLOPE- ®US I Job Date: 15 -Jun -2019 Sales Ortler #: 0905713807 ""'—" Well Description: CD524 WN: 50-103-20799 Conoco Phillips Alaska-CD5-24 Inta,.l6 Plots a6 ADP Chemical Plot - Day 2 Bucket Tests A I 62 MO -67 Conc -LAS (gal/Mgal) A g tiiv'eutn Time Ni512019 Customer: CONOCOPFMLLIPS NORTH SLOPE- EBUS I Job Date: 15 -Jun -2019 Saks Order*. 0905713807 Well Description: CD524 LMA: 50.103-20799 Congo Phillips Alaska-CD5-24 Inteml6 Plotz 49 A 100 6000 5000 1 Treatment Plot - Interval 6 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gal) C 6 Gauge BH Pres (psi) A Actual BH Temp (°F) D C 1 09:40 10:00 1020 10:40 11:00 11:20 &152019 6/152019 Time Customer.CONOCOPHILLIPS NORTH SLOPE Job Date: 15 -Jun -2019 Sales Order #: 0905713807 Well Description: CD524 uWl: 50-103-20799 IN 175 150 125 100 75 Conoco Phillips Alaska -CDS-24 Interval6 Plots 50 Blender Chemical Plot - Interval 6 Bi CL -31 CDnc -LA1 (gat/Mgap A Bi CL -22 UC Conc -LA2 (gal/Mgal) A A 81 OptiBD-Ill CDnc -DA2 (Ib/Mgal) B 61 SP Breaker Conc -DA1 (Ib/Mgal) B B 3. 2. 2. 0. II 10.00 10:20 10'40 11:00 1120 &1W2019 Time WIV2019 Custo r: CONOCOPI-IILLIPS NORTH SLOPE- EBUS I JDb ate: 15 -Jun -2019 Saks Order #: 0905713807 Well Description: CDS 24 UVut 50-10320799 Conom Phillips Alaska - CD5-24 Inmrval6 Plots 51 i 10.00 10:20 10'40 11:00 1120 &1W2019 Time WIV2019 Custo r: CONOCOPI-IILLIPS NORTH SLOPE- EBUS I JDb ate: 15 -Jun -2019 Saks Order #: 0905713807 Well Description: CDS 24 UVut 50-10320799 Conom Phillips Alaska - CD5-24 Inmrval6 Plots 51 ADP Chemical Plot - Interval 6 B2 Losurt-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgal) B B2 M087 Conc -LA5 (gal/Mgal) A I I I I 0.0 10:00 1020 10:40 11:00 11:20 6/15/2019 fi/15/2019 Time Customer: CONODOPHILLIPS NORTH SLOPE- E6L18 Job Date: 15 -Jun -2019 Sales Order #: 0905713807 Well Description: CD524 LAM: 50-10320790 B 25 71 5 Ef 15 Conoco Phillips Alaska -CDS-24 Interval6 Plots 52 Net Pressure Plot - Interval 6 Net Gauge BH Pres (psi) A A —BH Proppant Conc (Ib/gal) B B Time (min) Cusromer: CONOOOPHILUPS NORTH SLOPE- EBUS I Job Date: 15 -Jun -2019 Sass Order #: 0905713807 Well Description: CD5 24 LAAd: 50-103-20799 Conoco Phillips Alaska-CD5-24 InW.16 Plots 53 A 10000 Treatment Plot - Interval 7 Treating Pressure (psi) A SlurryRate (bpm) B Slurry Proppant Conc (Ib/gap C BH Proppant Conc (Ib/gal) C Gauge BH Pres (psi) A Actual BH Temp l -F) D C D 6116r2019 6`15/2019 Time Customer. CONOCOPHILLIPS NORTH SLOPE -EBUS I Job Date: 15 -Jur -2019 Sales Order#: 0905713807' Well Description: CD524 UWI: 50-10320799 75 r Conoco Philli,Alaska-CU5-24 Interval? Plots 54 Blender Chemical Plot - Interval 7 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Cone -LA2 (gal/Mgal) A A B7 OptiBo-III Conc -DA2 (Ib/Mgal) B B1 SP Breaker Cone -DA1 (Ib/Mgal) B 6115`2019 6/1512019 Time Custoner: CONOCOPPNLLIPS NORTH SLOPE- EBDS I Job Date: 15 -Jun -2019 Sales Order #: 0905713607 Well Description: CD5 24 LAM: 50-103-20799 Conoco Phillips Alaska - CDS-24 interval? Plots ADP Chemical Plot- Interval 7 B2 Losurf-300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DAi (Ib/Mgal) B A 62 MO -67 Conc -LAS (gal/Mgal) A I B rime Custoner: CONOCOPHILLIPS NORTH SLOPE- EBL6 I Job Date: 15 -Jun -2019 Sales Order* 0905713807 Well Description: CD524 LAM: 50-103-20799 Conoco Phillips Alaska - CD5 24 Interval? Plots 56 Net Pressure Plot - Interval 7 Net Gauge BH Pres (psi) A A —BH Proppant Conc (Ib/gal) B B Time (min) Custoner. CONOCOPHILLIPS NORTH SLOPE- EBt1S Job Date: 15 -Jun -2019 Sales Order #: 0905713807 VNell Description: CD524 LW: 50-103-20799 Conoco Phillips Alaska - CD5.24 Interval? Plots Treatment Plot - Interval 8 Treating Pressure (psi) A Slurry Rate (bpm) B Slurry Proppant Conc (Ib/gal) C BH Proppant Conc (Ib/gap C Gauge BH Pres (psi) A ACtLlal BH Temp ("F) D C D &15,zo19 &1&2019 Time Customer. COIJOCOPHILLIPS IJOR SLOPE- EBUS Job Date: 15-Juri-2019 Saks Order A 0905713807 WeII Description: CD5 24 LAM: 50-103-20799 Conoco Phillips Alaska-CD5-24 IMerval8 Plots 75 50 25 00 Blender Chemical Plot - Interval 8 B7 CL -31 Conc -LAI (gal/Mgal) A BI CL -22 UC Conc -LA2 (gal/Mgal) A A B1 Optiflo-111 Conc -DA2 (Ib/Mgal) - - B B1 SP Breaker Conc -DA1 (Ib/Mga1) B B lime Custorrer: CANOCOPHILL S NORTH SLOPE- EBUS Job Date: 15-J.n2019 Sales Order #: 0905713807 Well Description: CD524 LMA: 50-103-20799 Con. Phillips Ahs"-CD5-24 Inteml8 Plots ADP Chemical Plot - Interval 8 B2Losurt300D Conc -LA2 (gal/Mgal) A B2 WG -36 Conc -DA1 (Ib/Mgap B A B2 M087 Conc -LAS (gal/Mgap A 11:50 11:55 12:00 1205 12:10 12:15 12:20 rvlszDls e/15/2019 Time Custarer CONOCOPHILLIPS NORTH SLOPE- EBUS I Job Date: 15 -Jun -2019 Sales Order #: 0905713607 Wen Description: CD5 24 ldM: 50-103-20799 Conoco Phillips Alaska-CD5-24 Interval a Plots Net Pressure Plot - Interval 8 —Net Gauge BH Pres (psi) A A — BH Proppan[ Conc (Ib/gal) B lu Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS I Job Date: 15 -Jun -2019 Sales Omer #: 0905713807 Well Description: CD524 uW1: 50-103-20799 Conoco Phillips Alaska -M5 24 Intery l8 Plots 61 Treatment Plot - Interval 9 Slurry Proppant Conc (Ib/gaq C BH PR A B Gauge SH Pres (psi) A Actual nt Conic (lb/gal) Temp (`F) — CD C D Custoner: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 15 -Jun -201 B Saks Order #: 0905713807 V 11 Description: CD524 UWI: 50-10320799 Ell Conoco Phillips Alaska - CD5-24 interval Plots 62 A 3.0 2.5 r'1<i7 1.5 1.0 0.5 0.0- 12:20 12:25 12:30 12:35 12:40 12:45 12:50 Nt5/e019 6/1&2019 Time Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 15 -Jun -2019 Sales Order #: 0905713807 Well Description: CD524 INN: 50-103-20799 Blender Chemical Plot - Interval 9 Bi CL -31 Conc -LAi (gal/Mgap B7 Optiflo-lll Con c -DA2 (Ib/Mgap A B B1 CL -22 UC Conc -LA2 (gal/Mgal) A 61 SP Breaker Conc -DA1 (Ib/Mgap B 0 0 0 0 B -6 -5 -4 -3 2 1 W Conoco Phillf, Alaska - CD5-24 Inteml9 Plots 63 ADP Chemical Plot - Interval 9 B2 Losuri 30OD Conc -LA2 (gal/Mgal) A B2 WG -36 Cone -DA1 (Ib/Mgal) B A 62 MO -67 ConC -LAS (gal/Mgal) A B 12:20 12:25 12:30 12:35 12:40 12:45 WIV2019 6115/2019 Time Custwrer: CONOCOPHILLIPS NORTH SLOPE- EBLIS I Job Date: 15 -Jun -2019 Sales Order #: 0905713807 Mll Description: CD5 24 IM7: 50-10320799 Congo Phillips Alaska-CD5-24 Interval9 Pl u Net Pressure Plot - Interval 9 Net Gauge SH Pres (psi) A A — BH Proppant Conc (Ib/gal) B Time (min) Cn31DM1Er: CONOCOPFILLIPS NORTH SLOPE- EBUS I =Date: Sales Order #: 0905713807 Wall Description: Cos 24 INN: 50-103-20799 Concw Phillips Alaska -CD5Q6 Intery l9 Plots 1 1 Treatment Plot - Interval 10 Slurry Proppant Conc (Ib/gal A B Gauge SH Pres (psi) - C BH Proppant Conc (lb/gal) C A Actual SH Temp (°F) D C D &1&2019 - - WW2519 Time wstorrer: WPIQWPMLLIPS NORTH SLOPE -ESUS Job Qate' 50-103-20799 Sales Order #: 0905713807 We ll Description: CD5 24 � 75 Conoco Phillips Alaska -Cps-24 Interval 10 Plots 66 A 3.( 2.1 2.( 11 1.0 0.5 Act Blender Chemical Plot - Interval 10 B1 CL -31 Conc -LA1 (gal/Mgal) A B1 CL -22 UC Conic -LA2 (gal/Mgal) A 81 OptiBo-111 Conc -DA2 (Ib/Mgal) B B1 SP Breaker Conic -DA1 (Ib/Mgal) B I MIA 15:50 15:55 16:00 16:05 16:10 16:15 16:20 16:25 a/1S/2019 fi115/2019 Time Custoner: CONOCOPHILLIPS NORTH SLOPE- EBUS I Job Date: 15 -Jure -2019 Sales Order 0: 0905713807 Well Description: CDS 24 LAM: 50-103-20799 3 i i V 8 Conoco Phillips Alaska -CDS-24 Interval 10 Plots 67 ADP Chemical Plot - Interval 10 B2 Losurf--300D Conc -LA2 (gaVMgal) A 82 WG -36 Conc -DAi (Ib/Mgal) B A B2 MO£7 Conc -LA5 (gal/Mgal) A B 2.0 125 1.8 1.f 1! 1.: L( 0A O.( 0., 0.: 0.( 15:50 15:55 16:00 16:05 16:10 16:15 1620 1625 ans/a01s Time &15/2019 Customer: CONOCOPFiILLIPS NORTH SLOPE- EBUS I Job Date: 15 -Jun -2019 Sales Order #: 0905713807 Well Description: CD5 24 IMA: 50-10320799 M '5 R ?5 Conom Phllll0 Alaska - CD5-24 Inaerval 10 Plocs fig Net Pressure Plot - Interval 10 Net Gauge BH Pres (psi) A — BH Proppant Conc (Ib/gap B B Time (min) Customer. CONOCOPHILLIPS NORTH SLOPE -EBUS I Job Date: 15 -Jun -2019 I Sales Order*: 0905713007 WM' Well Description: CD524 ME 50-103-20799 Conoco Phillips Alaska - CDS-26 Interval 10 Plots HALLIBURTON Conoco Phillips Alaska CD5-24 Intervals 1-10 A -Sand Formation Harrison Bay County, AK API: 50-103-20799 Prepared for: Adam Klem 61151219 Sale Ortlor# 9057131>07 Stimulation Treatment Appendix - Well Summary - Chemical Summary - Planned Design - Water Straps - Water Analysis - Real -Time QC - Field Break Test - Fann 15 Minute - Field Break Test - Event Log - Lab Testing Conoco Phillips Alaska - CD5-24 Appendix 70 CDS-24 Interval Highlights Interval Date Designed Proppant (lbs) proppant in Formation (lbs) Vol Clean (bbl) Vol Slurry (bbl) Top Perf (ft) Bottom Perf (ft) Fluid System 1 6/13/2019 71700 69001 2045 2,120 21,649 21,699 HyborG 2 6/13/2019 71700 74222 1244 1,325 20,885 20,886 HyborG 3 6/13/2019 71700 68475 1240 1315 20,076 20,077 HyborG 4 6/13/2019 71700 69881 1240 1316 19,267 19,268 HyborG 5 6/13/2019 71700 76788 1531 1614 18,419 18,420 HyborG 6 6/15/2019 71700 71042 1891 1968 17,413 17,414 HyborG 7 6/15/2019 90132 89320 991 1088 16,686 16,687 HyborG 8 6/15/2019 90132 92110 978 1078 15,956 15,957 HyborG 9 6/15/2019 90132 95003 1184 1287 15,227 15,228 HyborG 10 6/15/2019 90132 88859 1270 1366 14,461 14,462 HyborG Conoco Phillips Alaska - CD5-24 Well Summary 71 Customer Conoco Phillips Alaska Formation A -Sand Lease CD5-24 API 50-103-20799 Date 6/13/2019 .-i C...,,.. M, HALLIBURTON Conoco Phillips Alaska -CD5-24 Chemical Summary 72 Liquid Additives Dry Additives Interval LOSu-ODOD MO -67 CL -22 UC CL -31 LVT-200 WG -36 BE -6 O ti Flo -III SP (gal) (901) leo') (gal) (goo (PPt) (PPt) (Apt) (Apt) Prime Up 0 0 0 0 0 0 0 0 0 1 80 11 65 32 0 2001 13 172 0 2 50 6 47 24 0 1306 8 105 0 3 52 5 47 23 0 1313 8 104 0 4 48 5 47 23 0 1257 8 104 0 5 58 4 31 25 0 1441 10 115 10 6 75 7 59 32 0 1905 12 160 0 7 42 4 37 19 0 1091 6 80 0 8 41 5 37 19 0 IDIO 6 80 0 9 49 5 46 21 0 1202 7 100 0 10 505 46 20 0 1151 8 130 8 Total 545 57 462 239 0 13677 86 1150 18 W/o Prime Up 545 57 462 239 0 13677 86 1150 18 Conoco Phillips Alaska -CD5-24 Chemical Summary 72 Conoco Phillips Alaska - CD5-26 Planned Design 73 e 00®mem®gym Conoco Phillips Alaska - CD5-24 Planned Design 74 Customer: Conoco Phillips Alaska Well: CDS-24 Date: 6/13/2019 Formation: A -Sand SOM 905713807 Carmo Platho Alaska -CD5d4 Water Straps Day 1 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Atigan CDS 106 20,142 480 108 11 1,809 43 2 Atigan CDS 106 20,142 480 101 11 1,809 43 3 Atigan CD5 107 20,336 484 106 11 1,809 43 4 Atigan CDS 107 20,336 484 109 11 1,809 43 5 Atigan CDS 105 19,949 475 30\7 11 1,809 43 6 Atigan CDS 102 19,368 461 104 11 1,809 43 7 Atigan CDS 106 20,142 480 105 11 1,809 43 8 Atigan CDS 106 20,142 480 104 11 1,809 43 9 Atigan CDS 106 20,142 480 101 11 1,809 43 10 Atigan CDS 105 19,949 475 102 46 8,286 197 11 Atigan CDS 106 20,142 480 100 83 1,413 34 12 Atigan CD5 105 19,949 475 97 105 19,949 475 13 Atigan CDS 105 19,949 475 98 105 19,949 475 14 Atigan CDS 106 20,142 480 103 46 8,286 197 15 Atigan CDS 105 19,949 475 104 11 1,809 43 16 Atigan CDS 106 20,142 480 104 11 1,809 43 17 Atigan CDS 10620,142 480 105 11 1,809 43 18 Atigan CDS 106 20,142 480 105 11 1,809 43 19 Atigan CDS 106 20,142 480 99 11 1,809 43 20 Atigan CDS 104 19,755 470 98 11 1,809 43 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 401,100 9,550 85,022 2,024 316,077 7,526 Pre -lob Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 0 477 0 477 0 477 0 477 Carmo Platho Alaska -CD5d4 Water Straps Day 1 Customer: Conoco Phillips Alaska Well: CDS-24 Date: 6/15/2019 Formation: A -Sand SOtt: 905713807 Cen M.H., aa4a-coS24 water Sups D,2 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature ('F) Inches Gallons Barrels 1 Atigan CDS 11 1,809 43 NA 0 22 1 2 Atigan CDS 11 1,809 43 NA 0 22 1 3 Atigan CDS 11 1,809 43 NA 0 22 1 4 Atigan CDS 11 1,809 43 NA 0 22 1 5 Atigan CD5 23 4,182 100 NA 10 1,627 39 6 Atillan CD5 105 19,949 475 105 9 1,444 34 7 Atigan CDS 105 19,949 475 105 8 1,262 30 8 Atigan CDS 105 19,949 475 107 7 1,079 26 9 Atigan CDS 105 19,949 475 108 7 1,079 26 10 Atigan CDS 105 19,949 475 104 39 6,920 165 11 Atigan CDS 105 19,949 475 106 47 8,494 202 12 Atigan CD5 105 19,949 475 95 56 10,367 247 13 Atigan CDS 105 19,949 475 98 42 7,479 178 14 Atigan CDS 105 19,949 475 103 41 7,288 174 15 Atigan CDS 105 19,949 475 108 42 7,479 178 16 Atigan CDS 105 19,949 475 109 8 1,262 30 17 Atigan CDS 10519,949 475 106 9 1,444 34 S8 Atigan CDS 105 19,949 475 103 8 1,262 30 19 Atigan CDS 108 20,529 489 106 9 1,444 34 20 Atigan CDS 105 19,949 475 106 1 8 1 1,262 1 30 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 311,231 7,410 61,281 1,459 249,949 5,951 Pre -Job Barrel Bottoms Zones: Volume Needed for Intervals (BBL): Number of Tanks Needed: Tank Bottoms BBL: 1 0 494 0 494 0 494 0 494 Cen M.H., aa4a-coS24 water Sups D,2 mmre.m�Pru,.u.rM.z. w,,.,.,.m•m,Yt Gramma, HALLIBURTON Alaska EmPRI Field ¢C Prepb Water Analysis on W.U.n Conoco Phillips Well Name: CN -24 Dayl Water Source: CDS Specter Gra Testing Temperature DisoWetl bon Fear chloride Cr sulfite .10um Magnesium Total Linear 50 a Ue no."I Total VI Water H GN N PoM-bo¢link H Crmidink Bacteria -F mg/L m8/L ma/L malt mg/L mg/L cP (YIN) MValue Triple Hydrometer Dlgital Thermometer Strip Strip Strip Tortion Total Hardrett Ttretlon FANN-35 Mmus Calcium Probe Probe Probe - My meter 1 1.006 52.1 0 2,210 200 700 500 1,2W 21.0 ].39 ]A1 1024 Y 91014 2 1.003 60.2 0 1,610 200 500 7W 1,200 19.0 ].E4 7.26 10.19 Y 1,030 3 1.002 64.1 0 1,350 200 500 7W 1.200 160 716 7.29 10.24 Y 1,20] 4 1.002 66.5 0 IAN 200 400 600 1,000 190 ].28 7.34 1018 y 1,661 5 1.00E 67.2 0 1,010 200 am am 1,000 190 ]24 7.28 1031 Y 1,930 6 1.004 61.2 5 1,610 200 400 1,000 1pW 19.0 ].39 7.36 1010 Y 948 7 1.002 613 0 11350 200 am 1,000 190 ]28 7.35 1012 Y 4,364 0 1.004 623 0 1330 200 300 600 200 7.33 7.39 1031 Y 2,3]6 9 1.002 62.1 0 1180 2W 400 am 200 7.29 7.32 1019 Y 4,552 30 1.004 61.3 0 1AW 200 400 1,000 180 RS ].34 1018 Y 4,081 11 1.004 62.4 D 1,]50 IW 400 am 210 7.21 7.36 10.15 y 3,0]6 12 1.002 63.3 5 1,610 R1,4W 200 400 am 20.0 7.22 7.35 1016 Y 5,12] 13 1.000 ]3.1 D 1.610 200 400 am 20.0 ].19 ].36 10.16 y 5,4]9 14 1.W2 ]4.6 0 1230 IW 300 1,100 19.0 ]23 7.30 1018 Y 2.968 15 1.004 ]9.1 0 1,480 200 am Bm 20.0 ].18 ].31 1D.22 P 60416 1.000 ]0.] 0 1,610 2m 400 9m 100 ]21 ]38 10.15 Y 1309 17 1.002 79.1 0 1,350 200 4m SW 190 ]23 ].29 10.13 Y 3,291 ]7.1 0 1,480 200 300 900 100 7.21 7.E8 10.30 Y 1,m1 19 1.003 85.1 O 1.610 200 400 5m WD 210 7.20 ].29 1D.15 Y 822 EO 1.m2 86.1 0 1480 2m 400 BW 1,200 19.0 7.23 7.26 1016 Y 1,638 portage 1.003 60.8 1 1501 200 410 760 1170 194 ]35 ].32 10.18 2839 Maximum 1.Om 86.1 5 1- Em ]W 1,1m IAN 21.0 ].39 To 1D.30 9,014 Minimum 1.002 523 0 1p10 200 300 500 900 100 718 726 10.10 604 Range O.OM 34.0 S 1,200 0 400 600 500 10 OZl n.15 0.20 8,41D mmre.m�Pru,.u.rM.z. w,,.,.,.m•m,Yt uwv Nulu,au.a ,za' a wam,wtyr mrx Company: HALLISURTON Alaska District Field QC Prejob Water Am. y is on Location Conoco Phillips Well Name: CDS-24 Dar,2 Water Soum: DS specific GravityTemperature Tied, DksoMed Iron Fes chloride Sulfate Calcium Ma{msium Total Linea ISO.,) G° Mei Hardness Vita Wahr N Gel X Pps6Cmsslink H Oosdink Bacteria 7 mg/L mg/L mg/L m L ni mg/L cP (YIN) BQValue Lack p Hydrometer Digital Thermometer Still Strip Ssnp rilmd.on Total Hardness Tt,.b.a FANN-35 Mlnus UNium Probe Probe Probe - Mycometer 6 1.002 86.8 0 1,010 200 400 1'00 2,40] 19.0 7.21 7.31 10.10 y 1,125 7 1.002 88.1 0 1,480 200 400 1.000 11400 19.0 224 7.35 10.OD y 1,132 8 1002 69.4 0 910 200 IW 11000 1,400 21.D 7.20 ].31 1020 Y 993 9 1.004 68.1 0 1,230 200 400 000 11200 200 7.30 ].3] 10.10 Y 1,177 20 1.002 67.8 0 1,010 200 IW Bb 1,200 19.0 7.26 7.34 9.90 Y 17,811 11 1.004 ]3.E 0 1,010 200 400 1,WD 1,400 21.0 7.14 7.28 9.97 Y 6,20. 12 1.002 63.3 5 LAW 20D 400 609 3,BNP20.0i0l6fi ].35 10.16 Y 5,12] 13 1.004 ]3.1 0 1,610 20D 400 800 1,2007.36 1016 Y 5.4]9 14 1.002 6].6 5 1350 20D 400 800 1,2007.41 1020 Y 4659 15 1.002 65.3 0 1,350 200 400 1'00 1,4007.35 9.90 Y 25,352 36 1.004 69.4 0 1,350 200 480 800 1,2007.31 10.10 y 1,021 1] 1.802 ]1.0 0 1,010 200 400 800 1,2007.32 1010 Y 1,01418 1.004 69.a 0 1,120 200 400 800 1,200].35 10.13 Y 19 1.004 71.1 5 1,010 200 400 700 1,100P21.0 7.32 1014 Y ]86 20 1.004 76.5 0 1,230 200 400 920 1,3207.31 10.22 Y &423 Extra Water Load 1.042 78.2 0 1,010 20] 400 1,000 1,400].34 10.10 Y 2,698 Avera a 1.003 72.4 1 12W 200 400 864 1269],34 10.03 5300 Maximum 1.004 8.9.1 5 1,610 200 400 1,000 1.480].41 1020 25,352 Minimum 1.002 63.3 0 910 200 900 600 1,000 ]38 9.90 786 Penge D.W2 24.8 5 700 01 A.400 2.0 0.13 0.30 - 24,566 uwv Nulu,au.a ,za' a wam,wtyr mrx HALLIBURTON Cualamer: CanowPfiilll Wska Inc. wdlna,rrt&# 1 13,2 Oele: Aneet3, 2018 Imenrel Su Vi[c L. NR I I Tem °F XL H Comnmma Imcoal SIN Vise Lw r H Tem °F XL H COmmente 1 Mini -F2 19 71 82 103 (J13R01'1 6 Pad i0 7.4 '1] 9J fi/I N2U19 Pad 19 74 72 111.6 IN 18 75 91 27 IX 19P73 80 IO2 2X 18 75 98 9.% 20 19 80 10.2 3X 24 7.4 99 98 3X 19 B5 ILL2 4X 20 )A 93 '1) 49 19 85 111.1 2 Ped 20 %0 -1. 7- (J13/2019 ) Pad I% 74 93 97 6/15/2019 IX 20 83 1142 IX Itl 7.4 93 97 20 21 82 W.1 2X Itl 7.4 93 99 3# 22 84 10 3X 18 74 93 9!1 49 19 80 99 4d 1% 74 93 99 SN I8 7.4 93 99 6# 19 ]q 94 10.1 3 Pad 17 82 10 W13201'1 % Pad ❑ 73 W 97 6/15/2019 IX 19 82 10 IX 17 72 93 98 11 29 20 86 9.9 2X 17 7 2 '» 9.7 39 19 72 86 96 3X Itl 72 99 10 40 20 7,1 86 99 49 V 73 94 9.8 5X 18 73 96 97 fiX 18 9.4 91 99 J Pa]j207.1 85 10 113/2019 9 Pad 19 73 97 9.8 6115/2019 IX 8< 9.8 IN 19 74 97 9.8 2# 85 99 2X 19 74 93 98 3#1 85 10 3M 19 73 93 9.8 4X1 85 99 4 119 72 93 9.8 4X1 85 99 5X 19 ).4 93 99 6X 19 ]d 93 99 5 Ped1 85 98 113/2019 10 Pad 18 ]5 tlI 92 1152019IX2 85 9.9 IX Itl 2X 90 9) 2# 2 18 4 8] 'Jtl I% 2 85 9] 4p 18 mg(l Sp 19 6W 20 ALASKA DISTRICT LABORATORY 16 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Prejob Break Test —Day I speak rests as no u R � Z� 20 5 ' t0 Date: Company: ConocoPhiliips Project No: Well Name: CDS-24 Stage(s): BHST (GF); 166 Water Source: Depth: 7760 Water pH: Formation: A -Sand Hydration pH: Analyst: XLnw& Hydration Viso: 19 Prejob Break Test —Day I speak rests as no u R � Z� 20 5 ' t0 7lmelml .seal An sh6mpH onnmmnilone Temp F PH LOSURF4000 CL -22 UC CLdi 41047 OptllloAl Break Test 75 10.10 1.00 0.90 0.45 0.26 2.00 Conoro Phillips Alntr. CM24 Fann]s Phe Bmk 7np Ury l ra aaat���aaa�aaa��teat�ateat�aaa�aaa��a�aaa�aaa► e� ��al�a�llllll���a�llla�a��a�a�a�a� 7lmelml .seal An sh6mpH onnmmnilone Temp F PH LOSURF4000 CL -22 UC CLdi 41047 OptllloAl Break Test 75 10.10 1.00 0.90 0.45 0.26 2.00 Conoro Phillips Alntr. CM24 Fann]s Phe Bmk 7np Ury l ra Temp F PX LOSVRFJOOD clu UC CL41 Break Test 75 10.10 1.00 0.90 0.45 'w"°f bme—if P Prejob Break Test Day 1 Brtak Tesb ALASKA DISTRICT LABORATORY mom.--...�aaa����a�aa���aaa��� 15 Minute Farm Model 56 Crosslinked Fluid Report Fluid System: Date: I Company: ConocoPhillips Project No: Well Name: C05-24 Stage(s):_ BHST VF): 158 Water Source: Depth: 7750 Water pH:_ Formation: A -Sand Hydration pH:_ Analyst: %rXeafa Hydration Visc: 19 cpg Temp F PX LOSVRFJOOD clu UC CL41 Break Test 75 10.10 1.00 0.90 0.45 'w"°f bme—if P Prejob Break Test Day 1 Brtak Tesb me below arc In gLIOns per thousand r M047 Op11110-111 0.10 2.00 Time lmimsecl Canxn.lIaa5.... -'r," Fenn 11 ".. Break Tar raV l a1 mom.--...�aaa����a�aa���aaa��� LMI me below arc In gLIOns per thousand r M047 Op11110-111 0.10 2.00 Time lmimsecl Canxn.lIaa5.... -'r," Fenn 11 ".. Break Tar raV l a1 Canrco PM1illips Plaska. CDS 2< iann 153one 1 HALLIBURTON F"'°"°° "°°P Zone ICrosslinkTests ALASKA DISTRICT LABORATORY —Pa° —i oon —zPPe —3Mg —4 FP9 15 Minute Farm Model 36 Crosslinked Fluid Report 000 Fluid System: 3600 Date: 6/13/2019 Company: ConocoPhillips Project No: 3000 Well Name: CDS 24 Stage(s): 1 21. BHST (nF): 166 Water Source: CDS 200° Depth: 7560 Water pH: 0 w t500 Formation: ASand Hydration pH: 7.40 ' low Analyst: ;LLGaw Hydration Wsc: 19 p@ 82 soo 0 aroo ol.co ozoo 03:00 oa:Do 06:00 oe.m oroo 08 00 c0:oo lo.00 noo Izoo 1300 14W r°:w All CMMIGW concenlrallone Mb an In aalws w IMuvandI Ms rOouw T.,O F PH LOSURF400D C622 UC CL5l M047 0011 11 MiniFrac 82 10.20 1.00 0.90 0.45 0.26 2.00 Pad iPPG 80 10.10 1.00 0.90 0.46 0.20 2.00 2PPG 3PPG 4PPG Canrco PM1illips Plaska. CDS 2< iann 153one 1 Cmrco VM111tiq...-mS34 Fann B bn.3 HALLIBURTON Zone 2 Crosslink Tests ALASKA DISTRICT LABORATORY —rue —1 PPa —2 PW —3 m —4 PP9 16 Minute Farm Model 35 Crosslinked Fluid Report 4DOD Fluid System: Hybor G v G Date: 6/13/2019 Company: ConocoPhillips Project No: 30°0 Well Name: CD -5 24 Stage(s): 2 X00 BHST(dF): 155 Water Source: CDS o 300°04 Depth: 7550 Water pH: Formation: A -Sand Hydration pH: 7.40 toW Analyst: R.""r Hydration Ysc: 21 -P@ 83 sW a 0000 ala° 02'.00 MW UN OW W'm 07M WW MCC tom I1:0D 120° 1300 14:W 1500 nmdimin. a<I Ma mlcalm MrMionsM arom allorm rtWusand l aomdamrthousM ]-PF PH LOSaRF. D CL$2 UC CLH M08] OoiOo4U Pad 1 ppg 83 10.20 1.00 0.90 0.45 0.10 2.00 2 ppg 3 ppg 4 ppg Cmrco VM111tiq...-mS34 Fann B bn.3 t.t.- 11,IIIIpx Naha..1 . Fann IS Zone 3 HALLIBURTON FWM'ahiokevaf0°p Zone 3 Crosslink Tests ALASKA DISTRICT LABORATORY —pad —1 pre —2 Pop —3m —4 ppg 15 Minute Fann Model 35 Crossiinked Fluid Report 4500 bppp Fluid System: Hybor G Company: Well Name: Date: ConocoPhillips Project No: CD-624 Stage(s): 6/13/2019 3 35W 'a �m u 2500 BHST (°F): 1165 Water Source: CDS 0 26m Depth: Formation: 7660 Water pH: A-Sand Hydration pH: 7.20 = X500 a 1000 Analyst: t,Lae4p Hydration Visc: 19 P@ 86 sa0 0 00:00 Ot oO 0230 03:00 09.00 os:00 0600 07:M MM MM 1000 1100 12M 1300 1400 ISM rata lml sac) NICMmlwl aoncemmtipnv Eelax a.e In albns mou.and I uMa .tlwuvM Tempi PX LOSURF-3000 CL-U UC CIA1 MOdr oollb-0I Pad 82 10.00 1.00 0.90 0.46 0.10 2.00 ppg 2 PPg 3 ppg 86 9.60 1.00 0.90 0.45 0.10 2.00 4 ppq t.t.- 11,IIIIpx Naha..1 . Fann IS Zone 3 Comm PMlllpa Alaska - C➢ 24 1-11 n.. HALLIBURTON °""° " °°^ Zone 4 Crosslink Tests ALASKA DISTRICT LABORATORY —p. —1 PW —2 con —3pM —4 ppg 15 Minute Farm Model 35 Crosslinked Fluid Report oco 300 Fluid System: Hybor G Date: 6/13/2019 Company: ConocoPhillips Project No: 300° Well Name: CD -524 Stage(s): 4 3500 BHST ff): 155 Water Source: CD6 =2000 Depth: 7550 Water pH:°g +No Formation: A -Sand Hydration pH: 7.20 5;+000 Analyst: T,Larvlr Hydration Visc: 20 c 86 Soo 0 CO:CO O+: CO pIN 030 NO ON %W 07M NO W:W 107 +100 1200 +3W 14:m 1500 Time (min:.) All cMmlcal c—trallona lM am InaU-s wrtMusandI Pounft perlhousaM Temp F VH LOSURFJOOD CL -22 UC CL41 MOd7 001Oo41 Pad 86 10.00 1.00 0.90 0.46 0.10 2.00 1 PP9 2 ppg 3 ppg 4 ppg Comm PMlllpa Alaska - C➢ 24 1-11 n.. C—. inlllip Al.,G-.0 ,. ynnt5IDne5 HALLISURTON w"'°°m ^°"°° ° zone 5 Crosslink Tests ALASKA DISTRICT LABORATORY —Pae —1 ppa —zppp —3 ppp —4 ppg 15 Minute Farm Model 35 Crosslinked Fluid Repoli No Fluid System: Hybor G Date: 6/13/2019 2soo Company: ConocoPhillips Project No: W0° Well Name: CD -624 Stage(s): 6 2500 BHST j°Fj: 165 Water Source: CDS 20o0 Depth: 7560 Water pH: g +500 Formation: ASand Hydration pH: 7.10 +Wo Analyst: W.&U* Hydration Visci 18 P@ 85 Soo 0 WCO Ot:O] 0200 0300 NM MM 0800 000 W:W MW +O:W ++W 12:W 1300 4M ISM Timalmin:aaq Nl c°eMcal mxplllmlb11f 6610WeTl° albm ni°ouund/ Pounds erft,ouzaM TempF PH L0SURF1000 CL -22 UC CLJ+ M0a7 001flo4li Pad 86 9.80 1.00 0.90 0.46 0.10 2.00 1 ppg 2 ppg 3 ppg 4 ppg C—. inlllip Al.,G-.0 ,. ynnt5IDne5 .—. PMIIIq..I.-(DSII Fann IS IDm6 HALLIBURTON °""° °"°°^ Zone 6 Crosslink Tests ALASKA DISTRICT LABORATORY —v,e —11, —2M —3 ppg —4 ppg 15 Minute Farm Model 36 Crosslinked Fluid Report oDoo Fluid System: Hybor G 45M Date: 6/15/2019 4000 Company: ConocoPhillips Project No: 35M Well Name: C05 24 Stage(s): 6 = woo BHST(IF): 155 Water Source: CDS �nOD Depth: 7550 Water pH: 0 2oo se sw we we Id Formation: ASand Hytlration pH: 7.60 1w0 Analyst: "Mw Hydration Vise: 20 cp 93 Me D ao:oo of a0 m:ao o3.aD of u0 asao ao:0o 0700 a3:oo rero tom 11:W lzao 1330 1400 15o0 rlmolmr .sKl arCMmmM wz°mauw, E,low,rc in galbns 1nw„ner W6 r1noD°am Temp°F pH LOSURF.D CL3LS CL 31 M047 008"1 Pad 93 9.90 1.00 0.90 0.45 0.10 2.00 1 PPg 2 ppg 98 9.80 1.00 0.90 0.45 0.10 2.00 3 ppg d ppq .—. PMIIIq..I.-(DSII Fann IS IDm6 Conoco Phdli, Hlazka CD526 Event Log DaV1 92 cm000 Ph nrp: Ah:kx. G)saa Fann 11...m HALLIBURTON Zone 10 Crosslink Tests ALASKA DISTRICT LABORATORY —p,a —1 PA —2 P, —appy —a PPy —5 ppg 16 Minute Farm Model 35 Crosslinked Fluid Report 500 Fluid System: Hybor G Date: 6/1512019 30°° Company: ConocoPhillips Project No: 25x0 Well Name: CD -524 Stage(s): 10 pyo BHST rF): 155 Water Source: CD5 o i5N Depth: 7550 Water pH: Formation: A -Sand Hydration PH: 7.30 > l000 Analyst: %Loved, Hydration Visc: 18 -PC 93 1500 0 0000 01:00 oz:m o3:ao oa:0o ys:a0 05:aa m:m ae:ao ay.ao 10a0 15c0 12:0) taaa ta.ao tsoo rimelm�n. xl All chemlcY co—MAt Ong aio.. am In aahons W tWuasndl MaPcz Wtnoo..m Temp -F Pv LOSURFa00e CL33t¢ CIL 31 MOb7 Op00oO Pad 1 ppg 84 9.60 1.00 0.90 0.46 0.10 2.00 2 Pp9 3 ppg 4 ppg 5ppg 6ppg cm000 Ph nrp: Ah:kx. G)saa Fann 11...m 010100 MMMMMMMEMMM Tme lwn:u J Tempi PX LOSORFJ D CL- UC CL41 M047 OPIIIo4ll pad 1 pp9 2 PP9 3pp9 93 9.90 1.00 0.90 0.45 0.10 2.00 4 pp9 6 ppg 6 pp9 c ,Fhlllly. Ae:kx 1.1.14 1-11 IDnel ALASKA DISTRICT LABORATORY 15 Minute Farm Model 05 Crosslinked Fluid Report Fluld System: Hybor G Date: 1 Company: ConocoPhillips Project No: Well Name: CD -624 Stage(s);_ BHST(nF): 156 Water Source:_ Depth: 7550 Water pH:_ Formation: ASand Hydration pH:_ Analyst: 9tzmw Hydration Vise: 20 cp@ 010100 MMMMMMMEMMM Tme lwn:u J Tempi PX LOSORFJ D CL- UC CL41 M047 OPIIIo4ll pad 1 pp9 2 PP9 3pp9 93 9.90 1.00 0.90 0.45 0.10 2.00 4 pp9 6 ppg 6 pp9 c ,Fhlllly. Ae:kx 1.1.14 1-11 IDnel 35W MIS 2Wo 2000 r p 1500 5 I= soo Zone 9 Crosslink Tests Pad .1M —2M —3 PP9 —4 PP9 �5PP9 Temp"F PH LOSURFJOOD CL42IIC C111 M08T OptlMJll Pad 1 ppg 2 ppg 3 ppg 93 9.80 1.00 0.90 0.46 0.10 2.00 4 ppg 5 ppg 6 ppg I I I I I I I I I 00 W 0950 10W 1100 1200'. TM (inin:—) I...PIi,14I Plaska-01�14 Fann 152-9 m ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Hybor G Date: _ Company: ConocoPhillips Project No: Well Name: CDS 24 Stage)s): BHST ff): 166 Water Source: Depth: 7560 Water pH:_ Formation: A -Sand Hydration pH:_ Analyst: A,LM* Hydration Visc: 19 cpl 35W MIS 2Wo 2000 r p 1500 5 I= soo Zone 9 Crosslink Tests Pad .1M —2M —3 PP9 —4 PP9 �5PP9 Temp"F PH LOSURFJOOD CL42IIC C111 M08T OptlMJll Pad 1 ppg 2 ppg 3 ppg 93 9.80 1.00 0.90 0.46 0.10 2.00 4 ppg 5 ppg 6 ppg I I I I I I I I I 00 W 0950 10W 1100 1200'. TM (inin:—) I...PIi,14I Plaska-01�14 Fann 152-9 m corcu..iho. Al 1., cos xa HALLIBURTON "'"""° °"°°= Zone 8 Crosslink Tests ALASKA DISTRICT LABORATORY —Pm —1 ppa —2 ppg —a M —4 ppg —5 ppg 15 Minute Farm Model 36 Crosslinked Fluid Report aso0 Fluid System: Hybor G Date: 611 312 01 9 X0°0 Company: ConocoPhillips Project No: zsao Well Name: CDS 24 Stage(s): 8 2000 BHST (oF): 155 Water Source: CD6 c 1s00 TV Depth: 7650 Water pH: Formation: ASand Hydration PH: 7.40 5; 1000 it Analyst: 96L^"* Hydration 1lsc: 17 CPR 93 500 0 0000 0100 ox:00 0:0 oa:oo asw aa:OD 0i:o0 ae.a0 os oo 1000 n:aa 12M 13aD uao Ism Timer. e<I Ru chemical—cemMbns Ce arc in gallons wthousand/ uMs H—saM Temp F PH LOSURFdND C6¢0UC CL41 mob? Op"wn, Pad 93 9.70 1.00 0.90 0.45 0.10 2.00 1 ppg 2 PP9 3 PP9 4 PP9 5 ppg 6 ppg corcu..iho. Al 1., cos xa Conoco Phillips Alaska - CDS-24 Even[ Log Day 2 93 HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2067967-1 Customer: Conoco Phillips Well Name & Number: CD5-24 Fluid System: Hybor G Date: May 22, 2019 0 minutes at 511 1 /sec 10 minutes the shear rate was decreased to 100 1/sec Seawater Technician(s) Performing Testing: Amanda Morrison Reviewed & Approved By: rmer: Conoco Phillips Fluid System: Hybor G Bob Type: B5 Name: CD5-24 Water Source: Seawalcr Shear Rate (1/sec): 5111100 Mpg 22 2019 BHST ('F): 155 Lab Project ID: 2067967-1 Test No: I DESIGNFLUID Water Analysis Lot Chemical Units Chemical Concentrations BE -6 ppt 0.15 0.15 0.15 0.15 LOSuh300D Bpt I.00 1.00 100 1.00 WG -36 p t 25.00 2500 25.00 25.00 SP Breaker t 0.25 0.50 CL-22UC 8pt 090 0.90 0.90 0.90 CL31 apt 045 0.45 0.45 0.45 MO -67 8pt 1 0.25 0.25 0.25 025 Opti0o 111 ppt 2.00 2.00 200 •cnlcufared ".lues Test No: Water PH Base Gel (4) Base Gel Vise (cP) Base Gel pH Base Gel Temp. ('F) Buffered pH Crosslink pH Final pH Test Temp. (.F)l Break Time (hCmin) 1 1 1' s h Gel llydre8on(511/s) Min. Viscosiw(a P) Temp_(oF). 25.00 2500 79�62 7.85 7.89 70 70 9.55 9.50 9.62 . 9.76 8.65 8.55 8.96 8.55 155 1 155 1 155 155 4:40 1 2:07 1 130 1 058 Test Notes: 600 50D u 400 a rc at di BREAKTEST CHART ......... "ar Rate -vace'V '^"""Shear Pate-Vlrcovity ---- ^Shear Pate �Vlscouty -vir-My .... Shear Pah -Vit.vty - -- Temperature - Temperature - -- Temperature _.... __......._.. Fes-- -- ��--------__..-- - Ah She., Rare Viscosity ..... ... Shear Rate Temperature - -- Temperature -- Temperature 160 150 140 130 20 300 rp" y 110 Zoo 6 vv loo loo --.-..___...- 90 BO 0 0:00 1:12 2:24 3:36 Time, h:mm 448 6:00 uj O I ® N C)1 L W L O o co 0 2 0 a 0 U V '^ _' 00 Y Q < > i w J Q LL U) � 00 Z wUZ CVn( a u) LL 00 Q r�/ J_ Ids 00 CL Q L J Li. Q r a � o Q Q Q .. tr Q,' m '= u z Z Z Z Z 0 0)p N (O V C N p N O fn = O 7 N m 0 J O N N (D N O G O v Q a) .yE o oo ¢ a g a ¢ a�-o z z z z z O a v ❑ .c E w d E CC z ❑ N a m p C N t0 s m o rn Q Q Q Q Q E oO a a z Z 2 Z Z N N D c L O m 2i G O w co r m Oi ¢] O Q `o D a ❑? D - U U❑ ❑ D 6 Z D O r a ❑ m o o N p d m N C m o 0 0� 0 0 LO a 0 w❑ D E 0 °cn ❑ N O C U O goo El o p ❑ D ❑ s m C ` O N N j- ❑ O U E O n ° d x Y V O c o o o d Eci o o m v MOD O (n m 1= ❑ o U � r '9 `O � y N Z O L � 0] >. v � o. ❑ E a m n m ¢ M N y a E F y a � ❑ a d a mD w m Q U o 0 o O m O -o N-65 o a o Q ❑ L w O D U` O m F 6, N O ❑ > CL U N ? O y D Y U C U O O - w D °- N D ._. N N N C N N V � N N ✓i 01 M Q O c O ¢ O ¢ O D C E E N n L O m U m 3 E Z E o O t m N N d n o r o o o (O o o (O a$ o N o E M U ,S �° l ❑ D_ O1 N OI N C y¢j W Q N O =_ D �_' OQ a o E O c ¢ O r m N Z N y D D L O U N s ❑ L �p O U U D N N N O➢ m E"i. .�. d 'd W U C N N O N N N❑ - ConocoPhillips July 8, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Second Quarter, 2019 To whom it may concern: G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone. 907-265-6120 Please find attached the second quarter 2019 annular disposal for the Colville River Unit and Greater Moose's tooth unit wells. This report shows the volumes disposed into surface casing by production casing annuli during the second quarter of 2019, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2019. Please call Chip Alvord at 265-6120 or Greg Hobbs at 263-4749 should you have any questions. Sincerely, A -e - a,',- G. 'LG. L. Alvord Alaska Drilling Manager A 11P6- ".JL.941'GLJ STATE OF ALASKA At A- .A fill AMr1 r -'AC r`nkICCDVAn 1kl nn&A% bll kl JU1 n Q on1n VY VVIYIIY.�JIVIY WELL COMPLETION OR RECOMPLETION REPORT - " LUIJ AN 1a. Well Status: Oil o Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Clas . 20AAC25A05 20MC25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 2. Operator Name: 6. Date Comp., Susp., or ConocoPhillips Alaska, Inc. Abend.: 6/4/2019 Developments Exploratory ❑ Service ❑ Stratigraphic Test ❑ 14. Permit to Drill Number/ Sundry: .219-006/319-1341319-200 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 2/17/2019 50.103-20799-00-00 4a. Location of Well (Governmental Section): . Surface: 426' FNL, 2881' FEL, Sec 18, T11N, R4E, UM Top of Productive Interval: 4436' FNL, 971' FEL, Sec22, T11 N, R3E, UM ' 8. Date TO Reached: 3/20/2019 16. Well Name and Number: CRU CD5-24 9. Ref Elevations: KB:71 GL:34 BF: 17. Field / Pool(s): Collville River Unit/Alpine Oil Pool Total Depth: 2929' FNL, 4622' FEL, See 3, T10N, R4E, UM t 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ASRC.NPR4, ASRC-AA092344, ASRC.NPR2, 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 349096 y- 5965792 • Zone- 4 TPI: x_ ,3� •)95331 6w, y- 5956789 Zone- 4 Total Depth: x- 362809 y- 5941903 • Zone- 4 11. Total Depth MDITVD: 3104017857 A R -NPR5 19. DNR Approval Number: 932669, 340757, 932128, 342658 12. SSSV Depth MDfrVD: N/A 20. Thickness of Permafrost MD/iVD: 1325/1320 1 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 Ift 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, formayon tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/ResCast-MiJltra-Sonic Casing Integrity, SonicScope Top of Cement 23. CASING, LINER AND CEMENTING RECORD `MDSETTING CASING WT. PER FT GRADE SETTING DEPTH DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20 78.6 L-80 37 115 37 115 42 10 yds. 10.75 45.5 L -80 37 2234 37 2175 13.5 1140sx 11.0ppg, Class B, 41 tax 15.8ppg, Class G 7.625 29/7 L-80 34 13882 34 7640 9.875x11 Stage 1:313sx 13.Oppg Class G Stage 2:634sx 15.8ppg Class G 4.75 12.2 1 L-80 13700 21708 17614 7755 6.75 Liner 24. Open to production or injection? Yes ❑� No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): FRAC SLEEVE/PORT@: 14461-14463 MD and 7672-7672 TVD 15227-15229 MD and 7686-7686 TVD SIZE DEPTH SET (MD) IPACKER SET (MDJTVD) 41/2 13716 1 12970/7430 13632(7603 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No R] 15957-15959 MD and 7691-7691 TVD COMPLETION 16686-16689 MD and 7697-7697 TVD DATE, Per 20 AAC 25.283 (i)(2) attach electronic and printed information 17413-17416 MD and 7700-7700 TVD & 1W 18419-18421 MD and 7728-7728 TVD V RI IED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 19267-19270 MD and 7739-7739 TVD 1 / 20075-20078 MD and 7743-7743 TVD -�(�- 20885-20887 MD and 7749-7749 TVD Pert Pup@ 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 6/22/2019 GAS LIFT Date of Test: 6/22/19-7/212019 Hours Tested: 229 Production for Test Period Oil -Bbl: 21538 Gas -MCF: 21730 Water -Bbl: 6960 Choke Size: 74/128 Gas -Oil Ratio: 830scf/B0 Flow Tubi&Q Press. 475 Casino Press: 1 00 si Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: 35 Water -Bbl: 0 Oil Gravity -API (corr): 4 r Form 10-407 Revised 5/2017 0 - 10/g /19 CONT/ UED ON PAGE 2 RBDIVIS..�eV"J(f Q 201fubmit ORIGINIAL onk 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q 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 Q 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 14336 7669 • information, including reports, per 20 AAC 25.071. Formation @ TPI -Alpine A C30 2394 2313 ' K3 4783 3775 . K2 5325 4018 ALBIAN 97 6295 4452 , ALBIAN 96 9267 5780 HRZ 12283 7129 KALUBIK 12502 7228 KUPARUK C 12750 7339 LCU/MILUVEACH 12764 7345 . TD 31040 7857 r Formation at total depth: AI ine 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, paleontological report. production or II test results, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Tom Polasek Authorized Title: Alaska Drilling Manager Contact Email: Tom.G.Polasek0 co .com Authorized�+ Q� �Zv ( Contact Phone: 263-3740 1 Signature: Date: 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 1 b: 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 10407 Revised 5/2017 Submit ORIGINAL Only Page 1 of 1 CD5 " 24 Alpine A/C Dual Lateral Producer Proposed 8chamatlo C send Lateral 4•11V x 1" OLM 6 314" Hole TD 13,332% 27,266' MD ------ --1-'- O O O o O o __________________________________- Premier Packer at 13,000 MD •4-%'i 12.661-4 HP Sliding sleeve for o 0 o p o selectivity 13.041'MD....................... 3.112" 9.30 TN110$$ TNT Production Pecker A send at 6 13.661' MD 2XP liner top packer (whipstock 13 RAH'4—! file:///S:/ANC/Longtemn/Drilling%20&%20 W ells%200ps/Alpine/CD5/CD5-24/Schematics... 7/2/2019 20" 0" H40 Welded Upper Completion; j Conductorto 115'MD 1)4 W-12.66 T881ue tubing 1 2) Shallow nipple profile 3,813" IC 1 3) 4'A" x 1" Camoo KBMG GLM ( I pinned for 2600 pal cask 1 4) Premier Pecker 1 6) X Nipple profile, 2.81 a" 6) TNT Packer I 7) X NIDOIe profile, 2.613" 10.914" 46.10 L40 HYD 563 z Lower Completion: I RTC 8) Plop and drop liner In t7 wo 1 - Surface Casing fit 2,293' MD - no Junction -4.6" 12.00 L-60 w/ ped pups 1 a) 2XP liner top packer A Flsxlocl - 4-'A° x 1" OLM XO 6" Hydnl 621 Box X 4=A" H I I I A.5" Hydril503 12.00 L-00 w/ F 1 I I 1 I I 1 4.1/2" 12.50 L40 TSBIUe 1 1 1 1 1 I 4-K" x 1" OLM 1 1 7 6/a" 29.76 L-80 Hyd 663 x 8TC i Intermediate Casing at 13,1198'1101D C send Lateral 4•11V x 1" OLM 6 314" Hole TD 13,332% 27,266' MD ------ --1-'- O O O o O o __________________________________- Premier Packer at 13,000 MD •4-%'i 12.661-4 HP Sliding sleeve for o 0 o p o selectivity 13.041'MD....................... 3.112" 9.30 TN110$$ TNT Production Pecker A send at 6 13.661' MD 2XP liner top packer (whipstock 13 RAH'4—! file:///S:/ANC/Longtemn/Drilling%20&%20 W ells%200ps/Alpine/CD5/CD5-24/Schematics... 7/2/2019 WNS PROD WELLNAME _ CDS-24 WELLBORE CD5-24 CO�I�CIJrI Well Attributr Max Angle 1 TD ll��lp$ �jyia Fiala Name WeIIMre APUUVA Welltare Ste+us ncl ('I MOIh Aetalm lhKBl Alaska. Inc ALPINE 501032079900 PROD 0.22 28,296.oe 310400 commm[ xis lvpm) Da+e Anndation Ene BeN xaGmlm RNRelease Bece ® SSSV: NIPPLE LAST W0: 36.90 6/42019 MULTIPLE LATERALS, COSH, 7YP v10 os 47 AM Last Tag 'errs" nma 0.1) Annamon I fumakedold I End beat I Welloore I Latmom By ............................._.............. ........... ..... .............................. LAST TAG. CDS-24 jenna9 Last Rev Reason HANGER. ]50 Ann.AXon I EndOab Welllp�e Last MM By Rev Reason: Post Frac P7ellwork e",neo19 CD5-24 daylg ........... Casing Strings ............................................................ Gsinp)-1,lon 00(in) ID (in) Top IhKB) set Deal laxB) set Oepa, IVO)... WULen(L. Grade Torinvad CONDUCTOR 20 1925 36.9 115.0 115.0 A536 cannot; OD (let ID (in) Top al set Oaptlll lMtB1 SN Dpth(TVD)... WULen(I_. Graft Top The..SURFACE 10314 9.95 375 2,234.5 2.1747 45.50 1,;30 TXP-M Gskq Description OD fir.) to lin) Top MB) set depth lakBl BN OpM(TVp)... WULen(I._Grade Tap Tllmtl INTERMEDIATE )SIB 688 342 13,882.1 ).640.3 29.70 U80 TXP CONDIrcossinsti Gshq Oescnption OD (1n) to AnToplKKk) set Dam laKB) BN Dpro I, )-. WULen(L. Grade Tap Thread A SAND PRODUCTION 4112 3.96 13.7000 21,708.5 7.7552 1260 L-80 Hyd563 L!kEP. Liner Details NIPPLE:214E9 Nominal ID Tapmxal Tplrvo)a0m) Ttp Acer) Item been, cam (In) SURFACEWI5-2234.5 13,7000 7,613.7 81.12 PACKER "HRD 'Z XP Liner Top Packer (11.28 5740 recapOctI A' ID) 13,7199 7,616.8 81.12 PACKOFF "RS' Rackoff Seal Nipple 4270 GASUFE4,+32,0 .1 81,12 HANGER "D Flex -Lock Liner Hanger 4820 13722.3 7617 ' 137294 7618.2 81,12 XO - Reducing XO, SSH563 x 4-117' 563 3.920 14,461.1 7671.9 88.92 FRA Ifiser ac sleeve 0, HY,1563 2,645 SleevelPolt 2645" SeaND 15,227.1 7,6858 80.97 FRUZ Baker bac,sleeve X, Hyd562.595 SleaverPo595"SeaL10 n 2 GAS LIFT. 1115 15,956.6 7,691S 09.71 READ BaMrfmcsleeye#7 Hytl 2.545 SleevdPon 2.545" Seat 16,686.3 7,6968 09.53 FRAI! Baker fran, sleeve N6, Hy,1553 2.495 SleevdPon 2,495" Seat ID rseeve M5, Hytl 2455 17,413.2 7.7003 89TUG FC a rac shavelPon 2.4W' Seat IT Gas uFr; +zs+za 18,4186 ).)28.0 89.1) FRA Baker Sac sleeve ,Hytl 3 2415 O415"Seat ID elPn 2 $leye 19,267.4 ).7M6 8960 FRAC Baker frac, sleeve 113,Hytl 2.375 Sleeni 2.375c Seat ID 20,075.9 7.7431 8987 FRAC-BaW lose sleave ,Hytl 2.335 SleevdPort 2.335" Seat ID 1 GAUGE 1'4.9450 20,8846 ).)491 89.41 FRAC Baketrac sleeve tll, Hytl563 2.295 Sleevdpon 2,295- Seat ID %Oa29ats Tubing Strings PAcKER:+z.SMd Tueinp Eve -I bn spine Ma...I01in1 Top lnkB) sal 0epin (x. sH DepM (rv0)l... W111Nx) cede rp connection TUBING 4.5"x 412 3.96 35.0 13)16.0 7,fi162 126D L-80 TSH Blue SLOW SLEEVE: R.WO.a 3.5"COMPLETION Completion Details NIPPLE, 13.0057 nettle, Topincl Nommal Top (hK6) IaxB) 19 Item Dee Com 10 (in) 35.0 35.0 0.00 HANGER FMC 4-12' Tubing Hanger Hydrin HYD 563 3.950 2,1468 2,096.8 2647 NIPPLE NIPPLE,IANDINGA I2';'%':3.813", TSH Blue 3.013 12945.0 7,4202 6204 GAUGE BOB Solid Gauge Mandrel vel l turn encapsulated l wire. TSH Bine 3,889 2961.5 7,4267 6735 XO XO J0INT,412';12.fi#,L8 T 11Blue x 3-12-H563 2.992 12,969.6 7,429.8 67,50 PACKER Baker premier production packer 1117 TC -II 2867 PAOKE4, 13.a3tT 12990.6 7,4378 61,90 SLIDING SLEEVE,SLIDIN 12" ARENA. 2.813", SLB, X Profile 2.813 SLEEVE 13,0067 7,4437 68.1 NIPPLE NIPPLE,IANDING, 18",X,2.813-,Hydrii5fi3-Higb Burd 2813 MPPLE:+aW.2 13,6317 7,fi029 8055 PACKER Halliburton TNT Packer, 312' VAMTOP 2900 13,6782 7,610.3 81.13 NIPPLE N IPPLE LANDINGSV2',X, 2.813-,EUE BN 2813 LOCAroR: t3e9az 13,6962 /,613.1 81.13 LOCATOR Baker Mechanical locarob EUE SM 2980 sats, Assn, +A.11 13,697.1 7,6132 81.13 SEAL ASSY Baker WLEG(Shear screws LILLY below lDrstop 2980 Mandrel inserts at ea N Top Ron) no des? M -)a) New Madel OD boa Vtt+e S Typ Latah P TRO Ron ]rye V.ILn) lel) man Da@ Com 4,132.0 134643 Camco KBMG 1 GAS LIFT LV BK 0188 1, 4.0 61168019 2 8.8402 5,5898 Camco KBMG 1 GAS LIFT GLV BK 0188 1885.0 6/188019 INTERMEDIATE:30.213M21 3 12512.3 I 9 Damcn KBMG 1 1 JUAN LIFT IUV BK D25D I lai Notes: General d Safety Em Dab Am.. 1112019 NTE View Schematic wl Alaska Stllemafi,10.0 A Sava PROescTeN LINER', d5 13 Ted fiKo and 5 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Sten Depth Start 7me End Time Dur(no Pease Op code Activity Code Time P -T -X Opearnon (ItKB) End Depth(W13) 2/14/2019 2/15/2019 24.00 MIRU MOVE MOB P Mob rig to CD5-24 0.0 0.0 00:00 00:00 2/15/2019 2/15/2019 15.50 MIRU MOVE MOB P Mob sub to CD5 pad. 0.0 0.0 00:00 15:30 2/15/2019 2/15/2019 5.50 MIRU MOVE MOB P Spot sub over CD5-24. Spot pipe 0.0 0.0 15:30 21:00 shed. Skid dg floor over well. Spot mud pits, motors. 2/15/2019 2/16/2019 3.00 MIRU MOVE RURD P Hook up service lines, mud lines, 0.0 0.0 21:00 00:00 (steam @ 21::30hrs). 2/16/2019 2/16/2019 4.00 MIRU MOVE RURD P Stage riser, RU. Work through 0.0 0.0 00:00 04:00 acceptance checklist. 2/16/2019 2116/2019 2.00 MIRU MOVE RURD P Install valves. N/U riser for 0.0 0.0 04:00 06:00 measurements. UD riser for fabrication. Take on DrilPlex spud mud. 2/16/2019 2116/2019 3.00 MIRU MOVE RURD P N/U lower riser section. R/U 0.0 0.0 06:00 09:00 accumulator lines to annular. 2/16/2019 2/16/2019 3.00 MIRU MOVE RURD P N/U annular to sliplock adapter. 0.0 0.0 09:00 12:00 Remove lower riser section. 2/16/2019 2116/2019 4.00 MIRU MOVE RURD P N/U lower riser section and test run 0.0 0.0 12:00 16:00 upper riser for welder. MU flange on kill line. run wires f/ MWD. Install gauge on sliplock adapter. Install mwd sensor on mud line.(On high line power @ 14:00 hrs) 2/16/2019 2116/2019 2.50 MIRU MOVE RURD P N/U upper riser section. Install 0.0 0.0 16:00 18:30 turnbuckles, hole fill line, bleeder lines. Flood lines and inspect for leaks. Continue R/U MWD cabin 2/1612019 211612019 3.50 MIRU MOVE RURD T R/U MWD cabin. Install hydraulic 0.0 0.0 18:30 22:00 lines to annular. Prep rig floor f/ BHA. 2/1612019 211712019 2.00 MIRU MOVE PULD T R/U MWD cabin. P/U HWDP, DC and 0.0 T-0- 22:00 00:00 rack back. 2/1712019 211712019 2.00 MIRU MOVE PULD T PU and rack back 5" HWDP and DC. 0.0 0.0 00:00 02:00 1 Continue rigging up MWD cabin 211712019 211712019 0.75 MIRU MOVE CLEN T Clean and clear rig floor. 0.0 0.0 02:00 02:45 211712019 2117/2019 1.75 MIRU MOVE PULD P PJSM. PU and RIH w/ BHA to 99'. 0.0 99.0 02:45 04:30 211712019 2117/2019 0.50 MIRU MOVE SFTY P Pre Spud mtg w/ all parties. Review 99.0 99.0 04:30 05:00 checklist. 2117/2019 2117/2019 0.50 MIRU MOVE CIRC P Function annular. Fill lines and hole. 99.0 99.0 05:00 05:30 Inspect for leaks. All good. 2117/2019 211712019 0.25 MIRU MOVE WASH P Wash down to 115'. 450 gpm. 520 psi. 99.0 115.0 05:30 05:45 60 rpm. 1 k ft/lbs tq. 211712019 211712019 6.25 SURFAC DRILL DDRL P Drill ahead from 115' MD to 554' MD, 115.0 554.0 05:45 12:00 500 gpm, 920 psi, 60 rpm, 3.21k Tq. ADT=3.36 hrs, TVD=554' 211712019 211812019 12.00 SURFAC DRILL DDRL P Drill ahead from 554' MD to 1,675' 554.0 1,675.0 12:00 00:00 MD, PU 110k, SO 108k, ROT 109k, 500/750 gpm, 920/2160 psi, 60/70 rpm, WOB 5/10k 411 k onloff Tq. TR=4.61. TS=1.84. ADT=6.45 hrs, TVD=1,661' 2118/2019 2/18/2019 0.75 SURFAC DRILL DDRL P Drill ahead from 1,675' MD to 1,786' 1,675.0 1,786.0 00:00 00:45 MD, PU 110k, SO 108k, ROT 109k, 500/750 gpm, 920/2160 psi, 60/70 rpm, WOB 5110k 4/1k onloff Tq. TR=.66. TS=O. ADT=.66 hrs, TVD=1,765' Page 1156 Report Printed: 712/2019 Uperations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth startTime EM Time Der (hr) Phase Op Code Activity Code Time P -T -X Ope on (OKE) End Depth (We, 2/18/2019 2/18/2019 1.50 SURFAC DRILL BKRM T BR OOH f/ 1,786'to 1,675'. 800 gpm. 1,786.0 1,786.0 00:45 02:15 2160 psi. 60 rpm. Retake and confirm survey 2/18/2019 2/18/2019 6.25 SURFAC DRILL DDRL P Drill ahead from 1766' MD to 2245' 1,786.0 2,245.0 02:15 08:30 MD, PU 125k, SO 125k, ROT 123k, 800 gpm, 2340 psi, 70 rpm, WOB 10k 3/1.9k on/off Tq. TR=.4.64 TS=1.25. ADT=.5.79 hrs, TVD=2185.20' 2/18/2019 2118/2019 1.00 SURFAC CASING CIRC P Circulate nut plug sweep around. 2,245.0 2,145.0 08:30 09:30 Racking back 1 std per BU. (2 stds racked back to 2145'). 800gpm. 2340 psi. 70 rpm. 2k tq. 2/18/2019 2/18/2019 0.25 SURFAC CASING OWFF P Flow check. Static. 2,145.0 2,145.0 09:30 09:45 2/18/2019 2/18/2019 2.00 SURFAC CASING BKRM P Attempt to POOH on elevators and 2,145.0 1,392.0 09:45 11:45 observed swabbing. SR OOH f/ 2145' to 1392'. 800gpm. 2050psi. 40 rpm. 1.5k tq. 2/18/2019 2/18/2019 0.25 SURFAC CASING CIRC P Circulate nut plug sweep around. 1,392.0 1,392.0 11:45 12:00 500gpm. 860 psi. 40 rpm. 1.5k tq. 2/18/2019 2/18/2019 1.75 SURFAC CASING BKRM P BR OOH f/ 1392'to 587'. 450 gpm. 1,392.0 587.0 12:00 13:45 730 psi. 30 rpm. 1.5k tq. 2/18/2019 2/18/2019 1.00 SURFAC CASING TRIP P POOH f/ 587 to 100'. 450 gpm. 620 587.0 100.0 13:45 14:45 psi. (hole unloaded @ 250'). 2/18/2019 2/18/2019 0.75 SURFAC CASING CIRC P Circulate nut plug sweep around. 425 100.0 100.0 14:45 15:30 gpm. 550 psi. 40 rpm. 2/18/2019 2/18/2019 0.75 SURFAC CASING BHAH P LID BHA. 100.0 0.0 15:30 16:15 2/18/2019 2/18/2019 1.25 SURFAC CASING BHAH P Clean and dear rig floor. Monitor hole 0.0 0.0 16:15 17:30 on TT. 2/18/2019 2/18/2019 1.75 SURFAC CASING RURD P RU to run casing. 0.0 0.0 17:30 19:15 2118/2019 2/18/2019 1.00 SURFAC CASING PUTB P PJSM. PU and RIH w/ shoe track and 0.0 125.0 19:15 20:15 check floats. Good. 2/18/2019 2/18/2019 1.00 SURFAC CASING PUTB P RIH wl 10 3/4" csg to 329'. Taking 125.0 329.0 20:15 21:15 weight @ 329'. 2/18/2019 2/19/2019 2.75 SURFAC CASING PUTB T Wash and work csg V 329' to 391' 1- 329.0 391.0 21:15 00:00 6bpm. 40-120psi. 20k weight down while working casing. Up 72k.. Down 72k 2/19/2019 2/19/2019 0.50 SURFAC CASING PUTS T Wash and work casing from 391' MD 391.0 354.0 00:00 00:30 to 354' MD 1-6bpm. 40-120psi. 20k weight down while working casing. Up 72k.. Down 72k 2/19/2019 2/19/2019 2.50 SURFAC CASING PUTS T Rack back double 10-3/4" casing with 354.0 354.0 00:30 03:00 10' pup. 2/19/2019 2/19/2019 8.75 SURFAC CASING PUTB P Continue RIH 10-3/4" 45.5ppf L-80 354.0 1,400.0 03:00 11:45 TXP-M casing from 354' MD to 1,400' MD. Wash down as needed with 8bpm 120psi 5 rpm 7-10k ft -lbs torque. Hard spot from 820' MD to 1,017' MD. 2/19/2019 2/19/2019 0.25 SURFAC CASING CIRC P Circulate btms up at 1,400' MD 8bpm 1,400.0 1,400.0 11:45 12:00 130psi. 2/19/2019 2/19/2019 3.75 SURFAC CASING PUTB P Continue wash down 10-3/4" 45.5ppf 1,400.0 2,197.0 12:00 15:45 L-80 TXP-M casing from 1,400' MD to 2,197' MD. with 8bpm 160psi 5 rpm 7- 10k ft -lbs torque. 2/19/2019 2/19/2019 0.50 SURFAC CASING HOSO P M/U hanger & landing it. Wash down 2,197.0 2,234.0 15:45 1615 w/3 bpm @ 200 psi & land on hanger @ 2,234'. P/U wt 145 k, SIO wt 130 k. Page 2/56 Report Printed: 71212019 Uperations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKS) End Depth(ftKB) 2/19/2019 2/19/2019 2.00 SURFAC CEMENT CIRC P Circ & cond mud for cement job. 2,234.0 2,234.0 16:15 18:15 Stage flow rate up to 8 bpm @ 150 psi. Reciprocate pipe 10', PJSM on cementing operations. 2/19/2019 2/20/2019 5.75 SURFAC CEMENT CMNT P Dowell pump 3 bbls H2O & PT to 2,234.0 2,234.0 18:15 00:00 250/3500 psi (good). Dowell pump 75 bbls 10.5ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 396 bbls 11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement and 85 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 185 bbls 11847 stks 10 ppg DrillPlex with 8 bpm / 750 psi. Reduce pumps to 3 bpm / 460 psi. last 10 bbls. Bump plug, pressure 500 psi over to 1060 psi for 5 min. Check floats. F/C good. CIP @ 00:24 His. Calculate 225 bbls good cement to surface. Full returns during cement job. 2/20/2019 2/20/2019 0.50 SURFAC CEMENT CMNT P Cont. to displace w/186.7 bola total @ 2,234.0 2,234.0 00:00 00:30 1847 stks 10 ppg DrillPlex with 8 bpm / 750 psi. Reduce pumps to 3 bpm / 460 psi. last 10 bbls. Bump plug, pressure 500 psi over to 1060 psi for 5 min. Check floats. F/C good. CIP @ 00:24 Hrs. Calculate 225 bbls good cement to surface. Full returns during cement job. 2/20/2019 2/20/2019 0.50 SURFAC CEMENT WWWH P Flush annular with black water 3X's. 0.0 0.0 00:30 01:00 Shut in annular for water flow mitigation. 2/20/2019 2/20/2019 11.00 SURFAC CEMENT WOC P W.O.C. - SIMOPS, Clean & clear floor. 0.0 0.0 01:00 12:00 RID volant. NOV derrick ispection. Service rig, top drive & drawworks. Work on MP2's. C/O elements on 3- 1/2" X 6" VBR's. Remove bolts on speed head. Stage well cap in cellar. Clean pits. 2/20/2019 2/21/2019 12.00 SURFAC CEMENT WOC P W.O.C. - SIMOPS, Continue clean 0.0 0.0 12:00 00:00 pits, Tighten ram doors, Hook up choke/Flare line, Stage and M/U section of BHA. 12psi on annulus at 2400 hm. 2/21/2019 2/21/2019 1.50 SURFAC CEMENT WOC P W.O.C. - SIMOPS, Stage well head 0.0 0.0 00:00 01:30 equipment in cellar. UD mouse hole 2/21/2019 2/21/2019 1.00 SURFAC CEMENT RURD P Drain annulus & verify zero pressure. 0.0 0.0 01:30 02:30 Open annular & UD landing it. 2/21/2019 2/21/2019 4.25 SURFAC WHDBOP NUND P R/D flow line, drain lines, hole 0.0 0.0 02:30 06:45 fill/bleeder lines & riser sections. N/D annular, diverter spool & starter head. 2/21/2019 2/21/2019 2.25 SURFAC WHDBOP NUND P Test run water mitigation well cap. Cap 0.0 0.0 06:45 09:00 would not fit over landing ring & hanger as designed. Split apart well cap 3/16" & finesse over landing ring & hanger. Confirm placement with well head. test seals on well cap & will not hold pressure. Remove well cap. 2/21/2019 2/21/2019 1.00 SURFAC WHDBOP NUND P Finish NIU well head & test to 1000 0.0 0.0 09:00 10:00 1 psi for 10 min (good) 2/21/2019 2/21/2019 6.25 SURFAC WHDBOP NUND P NIU 13-5/8" BOPE and MPD 0.0 0.0 10:00 16:15 1 equipment. Page 3156 Report Printed: 7/2/2019 operations Summary (with Timelog Depths) CDS-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tirne Dur(hr) Phase Op Code Adivity Code Time P-T-X Operation (aKB) End Depth(ftKB) 2/21/2019 2/21/2019 6.25 SURFAC WHDBOP BOPE P R/U BOP lest equipment and lest 0.0 0.0 16:15 22:30 BOPE w15 test joint. Annular 250 / 2500 psi for 5 min, Remaining test 250 / 3500 psi for 5 min. 4" Demco, Choke valves 1 - 14, Choke needle valve, Upper/lower 3-1/2" X 6" VBR's & blind rams, 5" Dad/FOSV, HCR / Man choke/kill, Top drive lower IBOP failed test. Accumulator test, Initial 2950 psi, final 1250 psi, (precharge 1000 psi on bottles) 1st 200 psi recharge = 35 sec's, full recharge = 195 seconds. Nitrogen Bottles x4 = 2,125 psi. Gas alarms and PVT alarms tested. Draw down on chokes 1,11500 psi. AOGCC Guy Cook witness test. 2/21/2019 2122/2019 1.50 SURFAC WHDBOP MPDA P R/U test equipment. Test MPD 0.0 0.0 22:30 00:00 equipment 250/1200 psi. while prepairing to change out manual and auto IBOP on top drive. 2/22/2019 22212019 2.25 SURFAC WHDBOP MPDA P Test MPD 250 11200 spi for 5 0.0 0.0 00:00 02:15 min.nRemove MPD test plug. Install trip nipple. SIMOPS - Flush gas buster & B/D choke/kill lines. 2/22/2019 2122/2019 2.00 SURFAC WHDBOP RGRP T C/O Auto/Man IBOP assy. 0.0 0.0 02:15 04:15 222/2019 21222019 1.75 SURFAC WHDBOP BOPE T R/U test equipment. Test Auto/Man 0.0 0.0 04:15 06:00 IBOP 250 / 3500 psi for 5 min. R/D testing equip. 2/22/2019 222/2019 2.00 SURFAC WHDBOP RGRP T Install torque fedder rings on top drive 0.0 0.0 06:00 08:00 & wire tie same. Secure top drive. 2/22/2019 2/22/2019 1.00 SURFAC WHDBOP RURD P M/U test it. Install wear ring. Install 90' 0.0 0.0 08:00 09:00 mouse hole. 2/22/2019 2/2212019 2.00 SURFAC CEMENT BHAH P M/U 9-7/8" X 11" BHA as per SLB to 0.0 853.0 09:00 11:00 853'. Change out jars. 2122/2019 2/22/2019 1.00 SURFAC CEMENT TRIP P RIH from 853' MD to 1,978' MD. 853.0 1,978.0 11:00 12:00 2/22/2019 2/22/2019 0.50 SURFAC CEMENT DHEQ P Shallow hole test MWD tools with 1,978.0 1,978.0 12:00 12:30 450gpm 1000psi. 2122/2019 2122/2019 1.00 SURFAC CEMENT SLPC P Slip & cut 38' drill line. (Circulate 1,978.0 1,978.0 12:30 13:30 BTM's up with 4bpm 160psi) 2/222019 2/222019 0.50 SURFAC CEMENT SVRG P Service rig and top drive at 1,978'10D. 1,978.0 1,978.0 13:30 14:00 2/2212019 222/2019 2.00 SURFAC CEMENT PRTS P R/U testing equip. Test casing to 3500 1,978.0 1,978.0 14:00 16:00 psi & chart for 30 min 3.5bbls pumped. R/D testing equip. 2/22/2019 222/2019 0.50 SURFAC CEMENT WASH P Wash and ream from 1,978' MD to 1,978.0 2,147.0 16:00 16:30 2,147' MD. 500gpm 1270psi 50rpm 2.5kf Abs. 2/22/2019 212212019 3.75 SURFAC CEMENT DRLG P Drill out cement & shoe track from 2,147.0 2,245.0 16:30 20:15 2,147' MD to 2,235' MD. Clean out rat hole from 2,235' MD to 2,245' MD. w/ 400-500 gpm, 800-1270 psi, 30 - 60 rpm, 1.3 k fUlbs Displace to new 9.6 ppg LSND on the fly after drilling shoe. 2/2212019 2/22/2019 0.75 SURFAC CEMENT DDRL P Drill 20' new formation from 2,245' MD 2,245.0 2,265.0 20:15 21:00 to 2,265' MD / 2,202' TVD w/600 gpm, 1300 psi, 62 rpm, 2.5 k ft/lbs. ECD: 10.16PP9 2/22/2019 2/2212019 0.50 SURFAC CEMENT BKRM P BROOH from 2,285' MD to 2,167' MD 2,265.0 2,167.0 21:00 21:30 & circ hole clean w/500 gpm, 970 psi, 50 rpm, 1.5 k ff/Ibs. Page 4156 Report Printed: 7/212019 . Uperations Summary (with Timelog Depths) CDS-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log sten Depth Stan Tme End Time our (hr) phase Op Cade AcWty Code Time P-T-X Operation (ftKB) End Depth (111(B) 2/22/2019 2/22/2019 0.75 SURFAC CEMENT FIT P Blow down top drive, R/U testing 2,167.0 2,167.0 21:30 22:15 equip. FIT to 18.0 ppg with 9.6ppg mud 950 psi. R/D testing equip. 2/22/2019 2/22/2019 0.50 INTRMI DRILL REAM P Wash and ream from 2,167' MD to 2,167.0 2,265.0 22:15 22:45 2,265' MD. 500gpm 970psi 50rpm 2.5kft/lbs. 2/22/2019 2/22/2019 0.75 INTRMI DRILL DDRL P Drill ahead from 2,265' MD to 2,355' 2,265.0 2,355.0 22:45 23:30 MD 2,281' TVD, 750 gpm, 2000 psi, ECD 10.3 ppg, P/U wt 125 k, S/O wt 125 k, ROT wt 125 k, 60 rpm, Trq On/Off 1.3/1.33 k ft/Ibs 2/22/2019 2/23/2019 0.50 INTRMI DRILL CIRC P Drop 1.25" Torlon ball to open reamer. 2,355.0 2,355.0 23:30 00:00 Pump down @ 200 gpm w/ 200 psi 3min , 50 gpm w/ 70 psi for 7 min, Ball landed and pressure increased to 1070psi. then dropped to 70psi. Initial 750gpm 2000psi 30 rpm 1.81tlbs TRPM=4179, After ball drop, 750gpm 1500psi 30 rpm 1.8ftIbsTRPM=3593 (indication of reamer open). Ledge test with 1 Ok at blade depth 2253' MD. Back ream w/ 750 gpm 1500 psi. Shutdown RPMs, pull 1O overpull against shoe (indication reamer open). 2/23/2019 2/23/2019 12.00 INTRMI DRILL DDRL P Drill ahead f/2,355to 3,861'MD 1 2,355.0 3,861.0 00:00 1200 3,308' TVD, ADT 7.66 Hrs, ECD 10.7 ppg, 800 gpm, 2200 ps, PU wt 145 k, SO wt 129 k, ROT wt 135 k, 180 rpm, Trq On/Off 7/3 k ft/lbs 2/23/2019 2/24/2019 12.00 INTRMI DRILL DDRL P Drill ahead f/3,861' MD to 5,880' MD / 3,861.0 5,880.0 12:00 00:00 4,264' TVD, ADT 9.17 Hrs, ECD 10.83 ppg, 800 gpm, 2480 ps, PU wt 160 k, SO wt 140 k, ROT wt 145 k, 180 rpm, Trq On/Off 11/4 k ft/lbs 430bbis Dilution at 5,080' MD solids from 7.5 to 4.5%. 2/24/2019 2/24/2019 12.00 INTRMI DRILL DDRL P Drill ahead f/5,880' MD to 7,817'MD/ 5,880.0 7,817.0 00:00 12:00 5,073' TVD, ADT 8.34 Hrs, ECD 10.91 ppg, 800 gpm, 2530 psi, PU wt 182 k, SO wt 140 k, ROT wt 158 k, 180 rpm, Trq On/Off 16/7 k ft/lbs 550bbis Dilution at 5,300' MD to reduce solids. 2/24/2019 2/25/2019 12.00 INTRMI DRILL DDRL P Drill ahead 1/7,817' MD to 9,758' MO / 7,817.0 9,758.0 12:00 00:00 5,979' TVD, ADT 8.8 Hrs, ECD 10.8 ppg, 800 gpm, 2570 psi, PU wt 207 k, SO wt 156 k, ROT wt 175 k, 180 rpm, Trq OntOff 17/9 k ft/Ibs 550bbls Dilution at 9,370' MD to reduce solids. 2/25/2019 2/25/2019 12.00 INTRMI DRILL DDRL P Drill ahead f/9,758' MD to 11,482' MD / 9,758.0 11,482.0 00:00 12:00 6,768' TVD, ADT 9.17 His, ECD 10.9 ppg, 800 gpm, 2820 psi, PU wt 245 k, SO wt 170 k, ROT wt 200 k, 180 rpm, Trq On/Off 22/11.2 k ft/lbs. 2/25/2019 2/25/2019 0.75 INTRMI DRILL DDRL P Drill ahead (/11,482' MD to 11,576' 11,482.0 11,576.0 12:00 12:45 MD 16,810- TVD, ADT 0.75 Hrs, ECD 10.9 ppg, 800 gpm, 2820 psi, PU wt 245 k, SO wt 170 k, ROT wt 200 k, 180 rpm, Trq On/Off 22/11.2 k ft/lbs. 2/25/2019 2/25/2019 2.00 INTRMI DRILL CIRC P Circulate and condition mud at 11,576' 11,576.0 11,576.0 12:45 14:45 MD with 800gpm 3180 psi 120- 160rpm 12/15 k ft/Ibs Torque. (Weight up to 10.3ppg with spike fluid). 2/25/2019 2/25/2019 0.25 INTRMI DRILL OWFF P Observe well for flow (static) 11,576.0 11,576.0 14:45 15:00 Page 5/56 ReportPrinted: 7/212019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log and Dem Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operabon (WS) End Depth (ftKa) 2/25/2019 2/25/2019 0.75 INTRMI DRILL MPDA P Pulled trip nipple and installed RCD 11,576.0 11,576.0 1500 15:45 bearing. Tuned the chokes for drilling and broke in bearing w/ 50/100 rpm, 12.5117k TO. 2/25/2019 2/25/2019 6.25 INTRMI DRILL DDRL P Drill ahead f/11,576' MD to 11,968' 11,576.0 11,966.0 15:45 22:00 MD 16,985' TVD, ADT 4.94 Hrs, ECD 11.1 ppg, 800 gpm, 32000 psi, PU wt 245 k, SO wt 170 k, ROT wt 200 k, 180 rpm, Trq On/Off 22111.2 k ft/lbs. 2/25/2019 2/25/2019 0.50 INTRMI DRILL CIRC T Circulate and condition at 11,968' MD 11,968.0 11,968.0 22:00 22:30 at 800gpm 3180 psi 120-140 rpm 15- 17 k ft/lbs. Trouble shooting power drive. 2/25/2019 2/26/2019 1.50 INTRMI DRILL DDRL T Drill ahead f/11,968' MD to 12,062' 11,968.0 12,062.0 22:30 00:00 MD 17,027' TVD, ADT 0.94 Hrs, ECD 11.3 ppg, 800 gpm, 3200 psi, PU wt 245 k, SO wt 170 k, ROT wt 200 k, 180 rpm, Trq On/Off 22/11.2 k fUlbs. 2/26/2019 2/26/2019 3.00 INTRMI DRILL CIRC T DTF Circ & cond mud for 3 B/U w/800 12,062.0 11,953.0 00:00 03:00 1 1 gpm, 3200 psi, 120 rpm, 17 k trq. 2/26/2019 2/26/2019 1.25 INTRMI DRILL CIRC T Obtain base parameters. Drop ball & 11,953.0 11,953.0 03:00 04:15 close under reamer. Confirm reamer dosed. (Reamer open: 750 gpm, 2910 psi, 3710 trpm / Reamer Closed: 750 gpm, 3120 psi, 4336 trpm) 2126/2019 2126/2019 0.50 INTRMI DRILL OWFF T F/C (static). SIMOPS - Line up MPD 11,953.0 11,953.0 04:15 04:45 equipment. 2/26/2019 2/26/2019 7.75 INTRMI DRILL SMPD T StripOOH as per MPD schedule 11,953.0 2,167.0 04:45 12:30 V11,953' MD to 2,167' MD 2/26/2019 2/26/2019 0.75 INTRM1 DRILL OWFF T F/C (static). Pull RCD & install trip 2,167.0 2,167.0 12:30 13:15 nipple. Function test BOP's (SIMOPS: Blow down MPD choke) 2/26/2019 2/26/2019 1.00 INTRMI DRILL CIRC T Pump HI Vis sweep at 2,167' MD and 2,167.0 2,167.0 13:15 14:15 circulate with 740gpm 1910psi 80 rpm 2k Wilds torque. 2/26/2019 2/26/2019 2.00 INTRMI DRILL TRIP T POOH f/585 MD to 211' MD. Rack 2,167.0 211.0 14:15 16:15 back HWDP & Jars. 2/26/2019 2/2612019 1.50 INTRMI DRILL BHAH T PJSM: UD BHA as per Schlumberger 211.0 0.0 16:15 17:45 reps f/211' MD. 2/26/2019 2/26/2019 0.75 INTRMI DRILL GLEN T Clean and clear rig floor. 0.0 0.0 17:45 18:30 2/26/2019 2/26/2019 1.25 INTRMI DRILL BHAH T PJSM: PIU BHA as per Schlumberger 0.0 207.0 18:30 19:45 reps to 207' MD. 2126/2019 2126/2019 1.25 INTRMI DRILL TRIP T RIH f/207' MD to 2,164' MD. 207.0 2,164.0 19:45 21:00 2126/2019 2/26/2019 0.50 INTRMI DRILL DHEO T Fill pipe and Shallow hole test MWD 2,164.0 2,164.0 21:00 21:30 tools. 2/26/2019 2/27/2019 2.50 INTRMI DRILL TRIP T RIH (/2,164' MD to 6,022' MD. Fill pipe 2,164.0 6,022.0 21:30 00:00 every 20 stands 2/27/2019 2/27/2019 4.25 INTRMI DRILL TRIP T RIH f/6,022'to 11,856' MD. Fill pipe 6,022.0 11,856.0 00:00 04:15 every 20 stands 2/27/2019 2/2712019 5.00 INTRMI DRILL CIRC T Mud wt out of spec. Observed 10.6+ 11,856.0 11,856.0 04:15 09:15 ppg going in w/11.3 ppg max coming out. Circ & cond mud back to 10.3 ppg. Stage flow rate f/130 gpm to 710 gpm. FCP = 710 gpm, 3100 psi, 10.91 ppg ECD, 10.3 ppg In/Out 2/27/2019 2/27/2019 0.25 INTRMI DRILL OWFF T F/C (slight ooze & slowing down) 11,856.0 11,856.0 09:15 09:30 SIMOIPS - PJSM on RCD 2/27/2019 2/27/2019 0.50 INTRMI DRILL MPDA T Pull trip nipple & install RCD bearing. 11,856.0 11,856.0 09:30 10:00 Page 6156 Report Printed: 7/212019 e Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time Eno Tlme Dur (hr) Phase op Cocle ActKity Code Time PJA Operation (aKB) EM Depth (flKB) 2/27/2019 2/27/2019 1.50 INTRMI DRILL CIRC T Obtain base parameters. Drop ball & 11,856.0 11,856.0 10:00 11:30 open under reamer. Confirm reamer open. (Reamer Closed: 707 gpm, 3080 psi, 3945 trpm / Reamer open: 707 gpm, 2600 psi, 3359 trpm) 2/27/2019 2/27/2019 1.50 INTRMI DRILL REAM T W&R f/11,856 to 12,062'w/800 gpm, 11,856.0 12,062.0 11:30 13:00 3180 psi, 120 rpm, 12 - 14 k trq 2/27/2019 2/28/2019 11.00 INTRMI DRILL DDRL P Drill ahead f/12,062' MD to 12,869' 12,062.0 12,869.0 13:00 00:00 MD 17,392' TVD, ADT 8.85 Hrs, ECD 11.3 ppg, 800 gpm, 3470 psi, ROT wt 195 k, 150 rpm, Trq On 20 k ft/lbs. 2/28/2019 2/28/2019 12.00 INTRMI DRILL DDRL P Drill ahead f/12,869' MD to 13,555' 12,869.0 13,555.0 0000 12:00 MD / 7,687' TVD, ADT 9.77 Hrs, ECD 11.3 ppg, 800 gpm, 3590 psi, ROT wt 200 k, 150 rpm, Trq OnlOff 24/18k ft/lbs. Holding 11.3ppg EMW on connections. 2128/2019 2/28/2019 4.50 INTRMI DRILL DDRL P Drill ahead f/13,555' MD to 13,897' 13,555.0 13,897.0 12:00 16:30 MD / 7,642' TVD, ADT 3.9 Hrs, ECD 11.3 ppg, 800 gpm, 3700 psi, PU wt 275 k, SO wt 165 k ROT wt 205 it, 150 rpm, Trq On/Off 24/16k fUlbs. Holding 11 1.3ppg EMW on connections. 2/28/2019 2/2812019 5.75 INTRMI CASING CIRC P Circulated and condition mud w/ 13,897.0 13,897.0 16:30 22:15 800/500 gpm, 3700/1630 psi, (Choke 100% open)120/150 rpm, 17k TQ, and maintained 11.5 ppg ECD. Proceeded to weight up system f/ 10.3 ppg to 10.6 ppg to 10.8ppg. reducing rate to 500 gpm to maintain 11.5 ppg ECD. Top drive rpm at 100/110 for 40min, Increased to 150rpm with no change noticed at shakers. Shakers dean after 3rd btm's up. 2/28/2019 2/28/2019 1.00 INTRMI CASING CIRC P Dropped 1 5/8" ball to close reamer 13,897.0 13,897.0 22:15 23:15 and pumped down w/ 250 gpm, 720 psi, for 26 min. Dropped rate to 100 gpm, 460 psi and seated ball. Pressured up to 2000 psi and observed reamer close. increased rate to 500 gpm and noted increase in pump pressure 1720/1940psi and turbine RPM 220012773. 2/28/2019 3/1/2019 0.75 INTRMI CASING BKRM P Back ream out hole from 13,897' MD 13,897.0 13,649.0 23:15 00:00 to 13,649' MD with 500gpm 1860psi 120rpm 15k ft/lbs torque. Maintain 11.5ppg ECD. 3/1/2019 3/1/2019 5.75 INTRMI CASING BKRM P BROOH f/13,649'to 11,856' 13,649.0 11,856.0 00:00 05:45 w/500gpm 1860 - 1790 psi, 120 - 80 rpm 18 - 14 k ft/Ibs torque. Maintain 11.5ppg ECD. 3/1/2019 3/112019 6.00 INTRMI CASING CIRC P Ciro &cond for B/U. Pumped sweep 11,856.0 11,761.0 05:45 11:45 to aid in hole cleaning. Maintained 11.5ppg ECD max. Initial 500 gpm, 1680 psi, 80 rpm & Final 630 gpm, 2550 psi, 120 rpm. Racked back 1 stand f/11,856' MD to 11,761' MD. 3/1/2019 3/1/2019 0.50 INTRMI CASING OWFF P F/C at 11,761' MD (slight ooze then 11,761.0 11,761.0 11:45 12:15 static). SIMOPS - Line up MPD to StdpOOH 3/1/2019 3/1/2019 5.75 INTRMI CASING SMPD P StdpOOH as per MPD schedule 11,761.0 5,701.5- 12:15 18:00 f/11,76T MD to 5,701' MD Tight hole at 5,701' MD attempt to work through without sucess. Page 7156 Report Printed: 7/2/2019 operations Summary (with Timelog Depths) C D5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Sten Dept Start Time End Time Dur (hr) Phase Op Code Activity Code Tmis P -T -X Operation (fixe) End Depth (fiKin 3/1/2019 3/1/2019 2.00 INTRM1 CASING CIRC P RIH from 5,701' MD to 5,834' MD. 5,701.0 5,834.0 1800 2000 Circulate and condition mud staging pumps up to 660gpm 2000psi with 30rpm Trq 5 k ft/lbs. (Slow rpm due to RCD bearing leak) Maintain 3/1/2019 3/1/2019 0.25 INTRMI CASING OWFF P FIC (slight ooze then static) 5,834.0 5,834.0 20:00 20:15 3/1/2019 311/2019 0.50 INTRMI CASING MPDA P Pull RCD & install trip nipple. 5,834.0 5,774.0 20:15 20:45 3/1/2019 3/2/2019 3.25 INTRMI CASING BKRM P BROOH f/5,774' MD to 5,300' MD 50- 5,774.0 5,175.0 20:45 00:00 3007hr 5/1 Oklbs, 5,300' MD to 5,175' MD back ream at 1 0007h with 0/5klbs w/660 gpm, 2080psi, 140 rpm, 6.5 k trq. 11.5ppg ECD. Shakers clean. 3/2/2019 3/2/2019 6.00 INTRMI CASING BKRM P BROOH f/5,175' MD to 2,070' MD 5,175.0 2,070.0 00:00 06:00 w/660 gpm, 2080psi, 140 rpm, 6.5 k trq. 11.5ppg ECD. Shakers started to un -load at 2,300' MD. 3/2/2019 3/2/2019 1.00 INTRMI CASING CIRC P Pump weighted nut plug sweep & circ 2,070.0 2,070.0 06:00 07:00 casing clean w/650 gpm, 1580 psi, 80 rpm, 2.1 k trq 3/2/2019 3/2/2019 0.25 INTRMI CASING OWFF P F/C (static) SIMOPS - B/D top drive & 2,070.0 2,070.0 07:00 07:15 prep to POOH 3/2/2019 3/2/2019 1.25 INTRMI CASING TRIP P POOH (/2,070' MO to 294' MD 2,070.0 294.0 07:15 08:30 3/2/2019 3/2/2019 0.75 INTRMI CASING CIRC P Pump nut plug sweep to aid in 294.0 208.0 08:30 09:15 polishing up BHA & rack back last stand of HWDP f/294' MD to 208' MD. 3/2/2019 3/2/2019 1.75 INTRMI CASING BHAH P UD BHA as per DD f/208' MD (Bit 208.0 0.0 09:15 11:00 Grade: 0 -1 -WT -G -X -I -ER -TD & Reamer Grade: 1 -1 -WT-A-X-I-ER-TD) 3/2/2019 3/2/2019 1.25 INTRMI CASING WWWH P M/U stack washer &Flush stack. UD 0.0 0.0 11:00 12:15 same. SIMOPS - Clean & clear floor 3/2/2019 3/2/2019 2.25 INTRMI CASING BOPE P PJSM - C/O upper pipe rams to 7 5/8". 0.0 0.0 12:15 14:30 Pull wear ring. Set test plug & R/U to lest BOPE. SIMOPS - Clean & clear floor. Mobilize casing running tools to rig floor. 3/2/2019 3/2/2019 0.75 INTRMI CASING BOPE P Test annular preventer to 250 for 5 0.0 0.0 14:30 15:15 min / 2500 psi for 5 min. Test upper pipe rams to 250 for 5 min 13500 psi for 5 min. 3/2/2019 3/2/2019 0.25 INTRMI CASING BOPE P R/D testing equipment. Drain stack. 0.0 0.0 15:15 15:30 3/2/2019 3/2/2019 2.00 INTRMI CASING RURD P R/U to run casing. R/U Volant 0.0 0.0 15:30 17:30 w/torque turn, spider's & elevators & strap tongs. 3/2/2019 3/3/2019 6.50 INTRMI CASING PUTB P PJSM on running casing. M/U 7-5/8" 0.0 2,145.0 17:30 0000 shoe track & check floats (Shoe, 2 jls, float collar, 1 jt, baffle collar, X/O, 6 joints Eagle casing, X10, 2 -joints TXP no centralizers, 5-TXP joints, RATag joint,). RIH w/7-5/8" 29.7# TXP casing to 2,145' MD. P/U: 109k S/O: 109k. Torque turned only Eagle rasing. 3/3/2019 3/3/2019 5.75 INTRMI CASING PUTB P RIH 7-5/8"29.7#TXP casing f/2,145' 2,145.0 5,199-0- 00:00 05:45 1 to 5,1991. 3/3/2019 3/3/2019 2.00 INTRMI CASING CIRC P Circ & cond mud for 1 B/U Stage 5,199.0 5,199.0 05:45 07:45 pumps f/1 bpm to 5 bpm, 180 - 210 psi. Reciprocate pipe. PU wt 160 k / SO wt 140 k Page 8166 Report Printed: 71212019 - Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log start Depot start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (8Ka) End Depth (a(a) 3/3/2019 3/4/2019 16.25 INTRMI CASING PUTS P RIH 7-5/8" 29.7# TXP & Eagle casing 5,199.0 10,893.0 07:45 00:00 f/5,199' MD to 10,893' MD (M/U stage tool & Bakerl-ok between its 199 & 200) 3/4/2019 314/2019 1.50 INTRMI CASING PUTS P RIH 7-518" 29.7# TXP & Eagle casing 10,893.0 11,316.0 00:00 01:30 f/10,893' MD to 11,316' MD 31412019 314/2019 8.50 INTRMI CASING CIRC P Circ & cond mud. Stage up flow rate 11,316.0 11,316.0 01:30 10:00 w/Ini ial 1 bpm @ 430 psi & Final 5 bpm @ 330 psi, 10.8 ppg In 110.9 ppg Out. Reciprocate pipe. PU wt 272 k / SO wt 180 k 3/4/2019 3/412019 10.75 INTRMI CASING PUTS P RIH 7-5/8" 29.7# Eagle & TXP casing 11,316.0 13,842.0 10:00 20:45 f/11,316' MD to 13,842' MD. AT 13,766' MD S/O wt 124k, Pump down at 1/2-1 bpm 420psi. SIO wt 160K with pumps. 3/4/2019 314/2019 0.75 INTRMI CASING HOSO P M/U hanger & landing jt. Wash down 13,842.0 13,882.0 20:45 21:30 w/2 bpm 1480 psi & land on hanger @ 13,882' MD (S/O wt 160-170 k,) Work landing joint and increasing pump rate. Max break over P/U 435k. 3/4/2019 3/512019 2.50 INTRMI CEMENT CIRC P Circulate and condition mud, cut mud 13,882.0 13,882.0 21:30 00:00 weight back from 10.8ppg to 10.6ppg, stage pumps up to 7 bpm 1480 psi. Circ & cond mud for cement job. Reciprocate casing PU wt 325 k / SO wt 167 k 3/5/2019 315/2019 3.50 INTRMI CEMENT CIRC P Circulate and condition mud, cut mud 13,882.0 13,882.0 00:00 03:30 weight back from 10.8ppg to 10.6ppg, stage pumps up to 7 bpm / 480 psi. Circ & cond mud for cement job. Reciprocate casing PU wt 325 k / SO wt 167k Mud weight in 10.6ppg 10.7+ out 3/5/2019 3/5/2019 4.50 INTRMI CEMENT CMNT P Dowell pump 1.2 bbls H2O & PT to 13,882.0 0.0 03:30 08:00 4500 psi (good). Dowell pump 60 bbls 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 110 bbls 13.0 ppg 1.97 ft3/sx yield Class G lead cement and 130 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 4.5 bpm. Drop lop plug. Dowell pump 20 bbls H2O. Rig displace with 605 bbls (6,050 slks @ 96%) 10.6 ppg LSND with 7 bpm 1180 - 800 psi. Reduce pumps to 4 bpm / 760 psi. last 60 bbls. Reduce pumps to 2 bpm 1750 psi. last 60 bbls. Bump plug, pressure up to 1100 psi for 5 min. Check floats. FIC good. CIP @ 07:45 Hrs. Full returns during cement job. 10.6ppg inlout Note: Cup on Volant tool started leaking while finishing pumping lead cement. Land on hanger and continue pumping job with casing swedge. 315/2019 3/5/2019 12.00 INTRMI CEMENT WOC P Pressure up on casing @ 2bpm, Open 0.0 0.0 08:00 20:00 stage 2 tool with 3,150psi, Continue circulate at lbpm 80psi while WOC and UD 5" drill pipe from derrick with hoist/single joint elevators. Rig down Volant CRT. Page 9/56 Report Printed: 7/2/2019 Uperations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log SM Depth Start Time End Time Our (hr) phase Op Code Activity Code Time P-T-X Operation (fiKB) End Depth (ftKB) 3/5/2019 3/5/2019 2.00 INTRMI CEMENT CMNT P PJSM. Mix/pump 60 bbls 10.9 ppg 0.0 0.0 20:00 22:00 Mud Push II spacer @3.8 BPM. 165 psi. MbYpump 73 BBL 11.2 ppg CMT@ 4.7 BPM, 209 psi. Drop closing plug and kick out w/ 20 BBL water @ 5.7 BPM, 182 psi. Displace w/ 10.6 LSND @ 7 BPM, 380 psi. After 237 BBL away, slow to 2 BPM, 160 psi. After 242.5 BBL away, bump plug and pressure up to 1990 psi. CIP@ 21:55. Bleed pressure off string and OWFF-(static) to confirm ES Cementer is closed. Full returns. 3/5/2019 3/5/2019 0.75 INTRMI CEMENT OWFF P Monitor well. Static. UD landing jt. 0.0 0.0 22:00 22:45 3/5/2019 3/6/2019 1.25 INTRMI CEMENT WWWH P Drain stack, Make up stack washer 0.0 0.0 2245 00:00 and wash hanger area at 9.5bpm, UD same. Attempt to set pack off, 1" from bottom out. Pull paskoff and wash with open ended drill pipe. 3/6/2019 3/6/2019 0.50 INTRMI CEMENT WWWH P M/U 5" single open ended drill pipe. 0.0 0.0 00:00 00:30 Wash above hanger to clear debris. 3/6/2019 3/6/2019 1.00 INTRMI CEMENT W WSP P Set FMC pack off, lock down and test 0.0 0.0 00:30 01:30 1 1 1250/5000psi 10min. Witness by COPA 3/6/2019 3/6/2019 2.25 INTRMI CEMENT WOC P Hold PJSM, change out UPR f/ 7 5/8" 0.0 0.0 01:30 03:45 casing rams to 3.5X6" VBRs. Simops: Change out saver sub f/ 4.5' IF to 4" XT-39. While WOC 3/6/2019 3/6/2019 6.25 INTRMI CEMENT WOC P Continue UD 5' drill pipe from derrick 0.0 0.0 03:45 10:00 in mouse hole. While WOC 3/6/2019 3/6/2019 2.00 INTRMI WHDBOP BOPE P Clean and clear dg floor, R/U BOP test 0.0 0.0 10:00 12:00 equipment and 4" test joint. Set test plug and purge lines. Note: Freeze protected 10 3/4" x 7 5/8" annulus (performed LOT 535psi with 10.6ppg on first test, 372psi with 10.6ppg on second test, then flushed with 300 bbls of fresh water, followed by 80 bbls of diesel for freeze protect. 3/6/2019 3/6/2019 6.00 INTRMI WHDBOP BOPE P Held PJSM, Test BOPE w/4" & 4.5' 0.0 0.0 12:00 18:00 test joints to 250/3500 psi for 5/5 min each on 4" TJ, tested Annular, 4" Demco, #1 -14, upper IBOPauto and manual, upper 3.5' X 6" VBR, HCRchoke and kill, Man IBOP, XT-39 Dart, XT-39 FOSV, Man choke/kill, Lower 3.5' x 6" VBR. On 4.5' TJ, tested Annular, upper 3.5X6" VBR, lower 3.5X5' VBR. Tested Blind rams. Flow test Hyd and man chokes. Accumulator test -system pressure=2975 psi, Ann=750 psi, After function all components: Sys psi=1500 psi, Man psi=1350 psi, Ann psi=750 psi. 200 psi recovery--36 sec. TSR=181 sec, 4 bottle N2 avg=2100 psi, Tested all rig gas alarms. Test wilness by Adam Earl AOGCC. 3/6/2019 3/6/2019 1.25 INTRMI WHDBOP RURD P R/D test equipment and install T' wear 0.0 0.0 18:00 19:15 bushing. Lock down same. 3/6/2019 3/6/2019 0.75 INTRM1 CEMENT BHAH P Stage BHA tools and equipment to rig 0.0 0.0 19:15 20:00 1 I I floor. 3/6/2019 3/6/2019 2.75 INTRMI CEMENT BHAH P PIU and RIH with 6.75' BHA #4 to 0.0 380.0 20:00 22:45 I I 38U MD. Page 10166 Report Printed: 712/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Smrt Depth Start Time EM Tuna Our (hr) Phase Op Code Acbiy Code Time P-T-X Dperawn (flKe) End Depth (flKB) 3/6/2019 3/7/2019 1.25 INTRMI CEMENT PULD P P/U 4" singles and RIH to 1,805' MD. 380.0 1,805.0 22:45 00:00 3/7/2019 3/7/2019 0.75 INTRMI CEMENT PULD P P/U 4" XT-39 14.0# singles and RIH 1,805.0 2,281.0 00:00 00:45 from 1,805' MD to 2,281' MD. 3/7/2019 3/7/2019 0.50 INTRMI CEMENT DHEQ P Fill pipe and surface test equipment 2,281.0 2,281.0 00:45 0115 180-220gpm 1050-1510psi 3/7/2019 3/7/2019 3.75 INTRMI CEMENT PULD P P/U 4" 4" XT-39 14.0# singles and 2,281.0 5,604.0 01:15 05:00 1 1 1 RIH from 2,281' MD to 5,604' MD. 3/7/2019 3/7/2019 1.00 INTRMI CEMENT WASH P Fill pipe, break circulation at 5,604' 5,604.0 5,759.0 05:00 06:00 MD, wash in hole from 5,604' MD to stage collar at 5,759' MD, 150gpm 1010psi. P/U: 121k S/O: 105k 3/7/2019 317/2019 3.25 INTRM1 CEMENT DRLG P Drilloul stage collar at 5,759' MD, 5,759.0 5,768.0 06:00 09:15 160gpm 1050psi P/U: 134k S/O: 118k ROT: 116k with 4k lbs torque at 10RPM. Wash and ream through stage collar with and without pumps. (All ok) 3/7/2019 3/7/2019 1.50 INTRMI CEMENT WASH P Wash and ream from 5,768' MD to 5,768.0 6,079.0 09:15 10:45 6,079' MD 150gpm 940psi ROT: 115k with 3k Ibs torque at 10RPM. 3/7/2019 3/7/2019 9.50 INTRMI CEMENT PULD P P/U 4" 4" XT-39 14.0# singles and 6,079.0 13,015.0 10:45 20:15 RIH from 6,079' MD to 13,015' MD. Break in new pipe from 11,086' MD. 3/7/2019 3/7/2019 1.25 INTRMI CEMENT SLPC P Cut and slip 98' drill line at 13,015' 13,015.0 13,015.0 20:15 21:30 MD. 3/712019 3/7/2019 1.25 INTRMI CEMENT SVRG P Service dg and top drive. Tighten shot 13,015.0 13,015.0 21:30 22:45 1 1 1 pin assembly on tap drive. 3/7/2019 3/7/2019 0.50 INTRMI CEMENT PULD P P/U 4" 4"XT-3914.0# singles and 13,110.0 13,110.0 22:45 23:15 RIH from 13,015' MD to 13,110' MD. Break in new pipe. 3/7/2019 3/8/2019 0.75 INTRMI CEMENT DLOG P Logged RA tag, 200gpm 1833psi. P/U: 13,110.0 13,205.0 23:15 00:00 205k S/O: 115k ROT: 160k. Log down without rotation: Periscope 13,103' MD Impulse 13,102' MD Log up without rotation: Impulse 13,097' MD Log down with rotation: Impulse 13,105' MD Attempt to log up lost signal with tools. Unable to continue logging. Pump pressure dropping due to air in mud system. 3/8/2019 3/8/2019 1.00 INTRMI CEMENT DLOG P Logged RA tag, 200gpm 1833psi. P/U: 13,205.0 13,205.0 00:00 01:00 205k S/O: 1151k ROT: 160k. Log down without rotation: Periscope 13,103' MD Impulse 13,102' MD Log up without rotation: Impulse 13,097' MD Log down with rotation: Impulse 13,105' MD Attempt to log up lost signal with tools. Unable to continue logging. Pump pressure dropping due to air in mud system. 3/8/2019 3/8/2019 0.75 INTRMI CEMENT PULD P P/U 4" 4" XT-39 14.0# singles and 13,205.0 13,556.0 01:00 01:45 1 I RIH from 13,205' MD to 13,885' MD. Break in new pipe. 3/8/2019 3/8/2019 1.25 INTRMI CEMENT CIRC P Circulate and condition mud at 13,885' 13,556.0 13,585.0 01:45 03:00 1 MD 200gpm 2050psi P/U: 214k SIO: 113k. Page 11156 Report Printed: 71212019 Uperations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start OepM O De sent Time End Time Der(hr) Phase Op Code Adiviry Code Time P -T -X Operetion End Depm (flKB) 3/8/2019 3/8/2019 1.50 INTRMI CEMENT PRTS P Test 7-5/8" casing test with 10.4+ppg 13,585.0 13,585.0 03:00 04:30 mud to 3,500psi for 30min. (Good test) 3/8/2019 3/8/2019 1.50 INTRMI CEMENT COCF P Wash and ream from 13,585' MD to 13,585.0 13,757.0 04:30 06:00 13,757' MD 150gpml410psi ROT: 155k P/U: 216k SIO: 113k with 10.2k lbs torque at 20RPM. 3/8/2019 3/8/2019 7.75 INTRMI CEMENT DRLG P Drill Baffle collar @ 13,759' MD, Drill 13,757.0 13,897.0 06:00 13:45 shoe track shoe track to 13,882' MD, then rathole to 13,897' MD @ 150-200 gpm, 1840-2310 psi, 20 rpm, 12klbs tprque. 3/8/2019 3/8/2019 0.50 INTRMI CEMENT DDRL P Drill formation from 13,897' MD to 13,897.0 13,917.0 13:45 14:15 13,917' MD, 7,644' TVD. 220gpm 3, 11 Opsi 50 rpm 15k torque. ADT= 0.5 hrs, 3/8/2019 3/8/2019 1.25 INTRMI CEMENT CIRC P Circulate and condition mud for FIT & 13,917.0 13,917.0 14:15 15:30 rack back 1 stand from13,917' MD to 13,870' MD w/225 gpm, 2500 psi, 50 rpm, 14klbs torque. 3/8/2019 3/8/2019 0.25 INTRMI CEMENT REAM P Back ream from 13,019' MD to 13,870' 13,917.0 13,870.0 15:30 15:45 MD 225gpm 2500psi 50rpm 14klbs torque. 3/8/2019 3/8/2019 0.50 INTRMI CEMENT OWFF P Flow check at 13,870' MD (static) 13,870.0 13,870.0 15:45 16:15 3/8/2019 3/8/2019 0.75 INTRMI CEMENT FIT P Perform FIT to 12.5 ppg EMW, 13,870.0 13,870.0 16:15 17:00 pressure up to 835 psi max, with 10.4ppg. Total 1.6 bbl pumped, 1.6 bbl bled back. 3/8/2019 3/8/2019 0.75 PROD1 DRILL MPDA P Pull trip nipple & install RCD bearing. 13,870.0 13,870.0- 17:00 17:45 3/8/2019 3/8/2019 0.75 PRODI DRILL REAM P Wash and ream from 13,870' MD to 13,870.0 13,917.0 17:45 18:30 13,917' MD w/220 gpm, 2300 psi, 30 rpm, 13.8 klbs. Torque. Break in RCD element. 3/8/2019 3/8/2019 0.75 PROD1 DRILL DDRL P Drill formation from 13,917' MD to 13,917.0 13,955.0 18:30 19:15 13,955' MD. P/U: 190k S/O: 1351k ROT: 160k, 240gpm 2400psi 60 rpm 15klbs torque. While displace with 9.Oppg flopro. 3/8/2019 3/8/2019 1.50 PRODI DRILL CIRC P Continue displace with 9.Oppg flopro 13,955.0 13,955.0 19:15 20:45 at 13,955' MD. 220gpm 2350psi 50rpm 13.8kibs torque. 3/8/2019 3/8/2019 0.25 PROD1 DRILL OWFF P Formation finger print, (Static) 13,955.0 13,955.0 20:45 21:00 3/8/2019 3/9/2019 3.00 PROD1 DRILL DDRL P Drill formation from 13,955' MD to 13,955.0 14,093.0 21:00 00:00 14,093' MD 7,660' TVD. PIU: 190k S/O: 135k ROT: 160k, 240gpm 2400psi 60 rpm 15k torque. ECD: 9.78ppg ADT= 3.75 hrs. Break in new pipe. 3/9/2019 3/9/2019 12.00 PRODI DRILL DDRL P Drill 6-3/4" Alpine A lateral from 14,093.0 15,390.0 00:00 12:00 14,093' MD to 15,390' MD / 7,690' TVD, ADT 9.75 firs, ECD 10.06 ppg, 240 gpm, 2730 psi, PU: 195k, SO: 130k, ROT: 163k, 70rpm, Trq On/Off 13.2/8.2 k fl/lbs, 20k WOB. Closing MPD chokes on connections & monitoring pressure. Page 12156 ReportPrinted: 7/2/2019 . Uperations Summary (with Timelog Depths) C D5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log sten Depth startTime End Time our (hr) Phese Op Cade Activity Cotle Time P -T -X OpetalWn (fIKB) End Depth(Wfl) 3/9/2019 3/9/2019 1.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 15,390.0 15,419.0 12:00 13:00 15,390' MD to 15,419' MO / 7,690' TVD, ADT 9.75 Hrs, ECD 10.06 ppg, 240 gpm, 2730 psi, PU: 195k, SO: 130k, ROT: 163k, 70rpm, Trq On/Off 13.2/8.2 k fUlbs, 20k WOB. Closing MPD chokes on connections & monitoring pressure. 3/9/2019 3/9/2019 1.75 PRODi DRILL CIRC T Circulate at 15,419' MD (Motor failure) 15,419.0 15,419.0 13:00 14:45 240gpm 2950psi 50rpm 8klbs torque. 3/9/2019 3/9/2019 0.25 PROD1 DRILL OWFF T Finger print flow back (Static) 15,419.0 15,419.0 14:45 15:00 3/9/2019 3/9/2019 2.75 PRODt DRILL SMPD T StripOOH as per MPD schedule from 15,419.0 13,870.0 15:00 17:45 15,419' MD to 13,870' MD. 3/9/2019 3/9/2019 1.50 PROD1 DRILL CIRC T Circulate at 13,870' MD (Motor failure) 13,870.0 13,870.0 17:45 19:15 240gpm 2750psi 30rpm 5klbs torque. Possible plug jets. Final circulate rate 209 at 3500psi. 3/9/2019 3/9/2019 1.25 PROD1 DRILL OWFF T Finger print flow back, 24psi initial 13,870.0 13,870.0 19:15 20:30 build in 5 min. (monitored 4 build up cycles) 13psi final build up in 5 min. Monitor pressure build up 25min 64psi. Bled back 0.1 bbl gain. Monitor build up 5 min 10psi. 3/9/2019 3/9/2019 2.50 PROD1 DRILL CIRC T Circulate at 13,870' MD, weight up to 13,870.0 13,870.0 20:30 23:00 9.5ppg 240gpm 2875psi 30rpm 5kibs torque. Possible plug jets. Final circulate rate 209 at 3500psi. 3/9/2019 3/9/2019 0.25 PRODi DRILL OWFF T Flow check (Static) 13,870.0 13,870.0 23:00 23:15 3/9/2019 3/10/2019 0.75 PROD1 DRILL SMPD T StripOOH as per MPD schedule from 13,870.0 13,110.0 23:15 00:00 13,870' MD to 13,110' MD. 3/10/2019 3/10/2019 6.50 PROD1 DRILL SMPD T StripOOH as per MPD schedule from 13,110.0 3,037.0 00:00 06:30 1 13,110' MD to 3,037" MD. 3/10/2019 3/10/2019 0.25 PROD1 DRILL OWFF T Flow check (fluid serrated) 3,037.0 3,037.0 06:30 06:45 3/10/2019 3/10/2019 0.50 PROD1 DRILL MPDA T Remove RCD and install trip nipple. 3,037.0 3,037.0 06:45 07:15 3/10/2019 3/10/2019 0.25 PROD1 DRILL OWFF T Flow check (Static) 3,037.0 3,037.0 07:15 07:30 3/10/2019 3/10/2019 1.50 PROD1 DRILL TRIP T POOH from 3,037' MD to 380' MD. 3,037.0 380.0 07:30 09:00 3/10/2019 3/10/2019 0.25 PROD? DRILL OWFF T Flow check (Static) Function rams. 380.0 380.0 09:00 09:15 3/10/2019 3/10/2019 2.75 PROD1 DRILL BHAH T Continue POOH rack back 4" HWT 380.0 0.0 09:15 12:00 drill pipe, UD BHA.(3 plugged jets in bit) 1 -2 -CT -X -0 -PN -DMF 3/10/2019 3/10/2019 0.50 PRODi DRILL CLEN T Clean and clear rig floor. 0.0 0.0 12:00 12:30 3/10/2019 3/10/2019 2.25 PROD1 DRILL BHAH T P/U BHA/Bit #5 RIH to 385' MD 0.0 385.0 12:30 14:45 3/10/2019 3/10/2019 0.75 PROD1 DRILL TRIP T RIH from 385' MD to 2,282' MD. 385.0 2,282.0 14:45 15:30 3/10/2019 3/10/2019 0.50 PROD1 DRILL DHEQ T Fill pipe and shallow test MWD tools. 2,282.0 2,282.0 15:30 16:00 (good test) 3/16/2019 3/10/2019 7.50 PROD1 DRILL TRIP T Continue RIH from 2,282' MD to 2,282.0 13,876.0 16:00 23:30 13,876' MD. Fill pipe every 20 stands. 3/10/2019 3/11/2019 0.50 PRODi DRILL SLPC T Cut and slip 45' drill line 13,876.0 13,876.0 23:30 00:00 3/11/2019 1.00 PROW DRILL SLPC T Finish cut and slip drill line. Service 13,876.0 13,876.0 13/11/2019 00:00 01:00 and visual inspect equipment. Page 13156 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log sten Depth Start Tama End Time Our (hr) Phase Op Code Adivity Code Time P -T -x Operation (e(B) End Depth (ftKB) 3/11/2019 3/11/2019 0.50 PROD1 DRILL SFTY T POOH from 13,876' MD to 13,815' MD 13,876.0 13,815.0 01:00 01:30 and PJSM on installing RCD. 3/11/2019 3/11/2019 0.50 PROD1 DRILL MPDA T Remove trip nipple and install RCD. 13,815.0 13,876.0 01:30 02:00 SIH from 13815' MD to 13,876' MD 3/11/2019 3/11/2019 0.25 PROD1 DRILL CIRC T Break circulation 150gpm 700psi, 13,876.0 13,876.0 02:00 02:15 PJSM on displace well with 9.0ppg Flopro. 3/11/2019 3/11/2019 3.50 PROD1 DRILL CIRC T Pump 40bbls Hi -Vis spacer and 13,876.0 13,876.0 02:15 05:45 displace 9.5ppg vis brine with 9.Oppg Flopro at 150gpm 700-1160psi, PU: 169k, SO: 137k, ROT: 155k, 20rpm, Trq 4.5k It/lbs Max gas 6390 units 3/11/2019 3/11/2019 1.00 PROD1 DRILL SMPD T Strip IH from 13,876' MD to 15,302' 13,876.0 15,302.0 05:45 06:45 MD. 3/11/2019 3/11/2019 0.50 PROD1 DRILL WASH T Wash and ream from 15,302' MD to 15,302.0 15,419.0 06:45 07:15 15,415' MD 240gpm 2200psi 40rpm Trq 6k ft/lbs 3/11/2019 3/11/2019 4.75 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 15,419.0 15,777.0 07:15 12:00 15,419' MD to 15,777' MD / 7,690' TVD, ADT 2.73 Hrs, ECD 10.09 ppg, 240 gpm, 2800 psi, PU: 180k, SO: 130k, ROT: 156k, 65rpm, Trq On/Off 8.3/6 k ft/lbs, 10k WOB. Closing MPD chokes on connections & monitoring pressure. 3/11/2019 3/11/2019 10.50 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 15,777.0 16,986.0 12:00 22:30 15,777' MD to 16,986' MD / 7,699' TVD, ECD 10.2 ppg, 240 gpm, 2790 psi, PU: 187k, SO: 124k, ROT: 1551k, 75rpm, Trq On/Off 9.5/7.4 k ft/lbs, 1G- 0.12k 12kWOB. Closing MPD chokes on connections & monitoring pressure. 3/11/2019 3/11/2019 0.50 PROD1 DRILL CIRC T Lost communication with surface 16,986.0 16,986.0 22:30 23:00 equipment. Changed out data acquisition and regained communication. 3/11/2019 3/12/2019 1.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 16,986.0 17,093.0 23:00 00:00 16,986' MD to 17,093' MD / 7,700' TVD, ECD 10.2 ppg, 240 gpm, 2790 psi, PU: 1871k, SO: 1241k, ROT: 155k, 75rpm, Trq OntOff 9.5/7.4 k ft/lbs, 10- 12k WOB. Closing MPD chokes on connections & monitoring pressure. 3/12/2019 3/12/2019 12.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 17,093.0 18,248.0 00:00 12:00 17,093' MD to 18,248' MD / 7,726' TVD, ECD 10.24 ppg, 240 gpm, 3080 psi, PU: 194k, SO: 130k, ROT: 157k, 75rpm, Trq On/Off 10.5/7.8 k 0/lbs, IOk WOB. Closing MPD chokes on connections & monitoring pressure. 3/12/2019 3/13/2019 12.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 18,248.0 19,579.0 12:00 00:00 18,248' MD to 19,579' MD / 7,739' TVD, ECD 10.38 ppg, 240 gpm, 3360 psi, PU: 195k, SO: 120k, ROT: 157k, 75rpm, Trq On/Off 11.6/8.7 k ft/lbs, 10/13k WOB. Closing MPD chokes on connections & monitoring pressure. Page 14156 ReportPrimed: 7/212019 Uperations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time Dur(hr) Phase Op Cotle Aniry cattle Time P -T -X Operation utKB) End Depth(%KB) 3/13/2019 3/13/2019 12.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 19,579.0 21,009.0 00:00 12:00 19,579' MD to 21,009' MD / 7,750' TVD, ECD 10.57 ppg, 240 gpm, 3600 psi, PU: 195k, SO: 110k, ROT 150k, 75rpm, Trq On/Off 12.2/9 k ft/lbs, 12k WOB. Closing MPD chokes on connections & monitoring pressure. 3/13/2019 3/13/2019 3.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 21,009.0 21,341.0 1200 1500 21,009' MD to 21,341' MD 17,751' TVD, ECD 10.34 ppg, 240 gpm, 3600 psi, PU: 200k, SO: 110k, ROT. 150k, 75rpm, Trq On/Off 12.9/9.7 k fUlbs, 10- 13k WOB. Closing MPD chokes on connections & monitoring pressure. 3/13/2019 3/13/2019 3.75 PROD1 DRILL CIRC T Circulate and condition mud 240gpm 21,341.0 21,290.0 1500 1845 3230psi 70 rpm , POOH from 21,341' MD to 21,290' MD. 3/13/2019 3/13/2019 0.75 PROD1 DRILL OWFF T Finger print flow back (Static) Blow 21,290.0 21,290.0 18:45 19:30 down top drive. 3/13/2019 3/14/2019 4.50 PROD1 DRILL SMPD T StripOOH as per MPD schedule from 21,290.0 17,107.0 19:30 00:00 21,290' MD to 17,107' MD. 3/14/2019 3/14/2019 2.75 PROD1 DRILL SMPD T StripOOH as per MPD schedule from 17,107.0 13,876.0 00:00 02:45 17,107' MD to 13,876' MD. 3/14/2019 3/14/2019 1.75 PROD1 DRILL CIRC T Circulate btms up at 13,876' MD 13,876.0 13,876.0 02:45 04:30 240gpm 2470psi 40rpm 6klbs torque. 3/14/2019 3/14/2019 0.25 PROD1 DRILL OWFF T Finger print flow back, 45psi initial 13,876.0 13,876.0 04:30 04:45 build in 5 min. (monitored 4 build up cycles) 23psi final build up in 5 min. Total bled back 0.3bbl. 3/14/2019 3/14/2019 2.75 PROD! DRILL CIRC T Circulate at 13,876' MD, Pump 32bbls 13,876.0 13,876.0 04:45 07:30 Hi -vis spacer, displace with 9.5ppg Vis -Brine 200gpm 1910-1520psi 40rpm 6klbs torque. 3/14/2019 3/14/2019 0.50 PROD? DRILL OWFF T Flow check (Static). Pump 30bbls 13,876.0 13,876.0 07:30 08:00 10.2ppg slug, 200gpm 1500psi. Blow down T/D. 3/14/2019 3/14/2019 2.00 PROD1 DRILL SMPD T StripOOH as per MPD schedule from 13,876.0 11,025.0 08:00 10:00 13,876' MD to 11,025' MD. 3/14/2019 3/14/2019 0.50 PROD1 DRILL CIRC T Pump 2nd 31 bbl 10.3ppg slug at 11,025.0 11,025.0 10:00 10:30 200gpm 1500psi, Blow down T/D. 3/14/2019 3/14/2019 2.00 PROD1 DRILL SMPD T StripOOH as per MPD schedule from 11,025.0 6,370.0 10:30 12:30 11,025' MD to 6,370' MD, 3/14/2019 3/14/2019 0.25 PROD? DRILL OWFF T Flow check (Static). 6,370.0 6,370.0 12:30 12:45 3/14/2019 3/14/2019 0.50 PROD1 DRILL MPDA T Remove RCD and install trip nipple. 6,370.0 6,370.0 12:45 13:15 3/14/2019 3/14/2019 1.50 PROD1 DRILL TRIP T POOH from 6,370' MD to 3,708' MD. 6,370.0 3,708.0 13:15 14:45 3/14/2019 3/14/2019 3.50 PROD1 DRILL PULL T POOH from 3,708' MD to 385' MD. 3,708.0 385.0 14:45 18:15 UD 4" drill pipe with excessive hardband wear. 3/14/2019 3/14/2019 0.25 PROD1 DRILL OWFF T Flow check (Static). PJSM UD BHA 385.0 385.0 18:15 18:30 3/14/2019 3/14/2019 2.00 PROD? DRILL BHAH T Continue POOH rack back 4" HINT 385.0 0.0 18:30 20:30 drill pipe, UD BHA#5 .(1 plugged jet in bit) 0-1-WT-G-X-0-PN-DTF 3/14/2019 3/14/2019 1.25 PROD1 DRILL CLEN T Clean and Clear rig floor, SIMOPS 0.0 0.0 20:30 21:45 Service Accumulator and patch hole on rig floor. 3/14/2019 3/14/2019 1.50 PROD1 DRILL BOPE T Make up and pull wear ring and set 0.0 0.0 21:45 23:15 1 1 test plug. R/U to test BOPS. Page 15156 Report Printed: 712/2019 Uperations Summary (with Timelog [.Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur (hr) Phase Op Code AMvity Cace Time P -T -X Operation mKB) End Depth(nKB) 3/14/2019 3/15/2019 0.75 PROD1 DRILL BOPE T Test BOPs with 4" test joint. Annular 0.0 0.0 23:15 00:00 250/2500psi 5/5min, Test 3-1/2" X 6" VBR top drive IBOP, 250/3500psi 5/5min. AOGCC waived wittiness of BOP test by Matthew Herrera 18:01 hrs 3/13/2019. 3/15/2019 3/15/2019 4.25 PROD1 DRILL BOPE T Held PJSM, Test BOPE w/ 4" & 4.5" 0.0 0.0 00:00 04:15 test joints to 250/3500 psi for 5/5 min each on 4" TJ, tested Annular, 4" Demoo, #1 -14, upper IBOPauto and manual, upper 3.5" X 6" VBR, HCRchoke and kill, Man IBOP, XT -39 Dart, XT -39 FOSV, Man choke/kill, Lower 3.5" x 6" VBR. On 4.5" TJ, tested Annular, upper 3.5"x6" VBR, lower 3.5"x6" VBR. Tested Blind rams. Flow test Hyd and man chokes. Accumulator test -system pressure=2950 psi, Annu -950 psi, After function all components: Sys psi=1300 psi, Man part 300 psi, Ann psi=950 psi. 200 psi recovery --30 sec. TSR=177 sec, 4 bottle N2 avg=2150 psi, Tested all dg gas alarms. AOGCC waived withness of BOP test by Matthew Herrera 18:01 hrs 3113/2019. 3/15/2019 3/1512019 1.00 PROD1 DRILL BOPE T RID test equipment, Retrieve test 0.0 0.0 04:15 05:15 plug, Install wear ring. B/D choke and kill lines. 3/15/2019 3/15/2019 3.00 PRODi DRILL BHAH T PJSM, P/U BHA #6. to 322' MD. 0.0 322.0 05:15 08:15 3/15/2019 3/15/2019 1.00 PRODi DRILL CLEN T Pipe shed management, Clean and 322.0 322.0 0815 0915 clear rig floor. 3/15/2019 3/15/2019 2.25 PROD? DRILL PULD T P/U break in new 4" drill pipe, P/U 322.0 2,219.0 09:15 11:30 singles from 322' MD to 2,219' MD. 3/15/2019 3/15/2019 1.00 PRODt DRILL DHEQ T Shallow hole test MWD tools at 2,219' 2,219.0 2,219.0 11:30 12:30 MD with 200-280gpm 810-1440psi. B/D top drive. 3/15/2019 3/15/2019 2.50 PRODt DRILL PULD T P/U break in new 4" drill pipe, P/U 2,219.0 3,835.0 12:30 15:00 singles from 2,219' MD to 3,835' MD 3/15/2019 3/15/2019 6.00 PRODt DRILL TRIP T RIH with stands from 3,835' MD to 3,835.0 13,058.0 15:00 21:00 13,058' MD. Fill pipe every 20 stands. 3/15/2019 3/15/2019 0.50 PROD1 DRILL DLOG T Log RaTag froml3,058' MD to 13,150' 13,058.0 13,150.0 21:00 21.30 MD. 240gpm 1610psi. (RaTag at 13,103' MD) 3/15/2019 3/15/2019 0.25 PROD1 DRILL TRIP T Continue RIH from 13,150' MD to 13,150.0 13,625.0 21:30 2145 13,625' MD. 3/15/2019 3/15/2019 1.50 PROD1 DRILL SLPC T Cut and slip 42' drill line. Service rig. 13,625.0 13,625.0 21:45 23:15 3/15/2019 3/16/2019 0.75 PROD1 DRILL MPDA T Remove trip nipple and install RCD. 13,625.0 13,625.0 23:15 00:00 3/16/2019 3/16/2019 3.00 PROD1 DRILL CIRC T Pump 40bbls Hi -Vis spacer and 13,625.0 13,625.0 00:00 03:00 displace 9.5ppg vis brine with 9.0ppg Flopro at 150gpm 700-1160psi, PU: 169k, SO: 137k, ROT: 155k, 20rpm, Trq 4.5k ft/lbs Max gas 6390 units Page 16/56 ReportPrinted: 7/212019 - Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operator (fiK6) End Depth(tKB) 3/16/2019 311612019 4.50 PROD1 DRILL SMPD T Strip IH from 13,625' MD to 18,852' 13,625.0 18,852.0 03:00 07:30 MD. 3/16/2019 3/16/2019 2.50 PROD1 DRILL CIRC T Break circulation at 18,852' MD, swap 18,852.0 18,852.0 07:30 10:00 out stands to replace bad joint. M/U torque erratic, Inspect saver sub. 3/1612019 3/16/2019 1.75 PROD1 DRILL RGRP T Change out top drive saver sub, 18,852.0 18,852.0 10:00 11:45 Stroke pipe intermittenty (20-30') 3/1612019 3/16/2019 2.25 PROD1 DRILL SMPD T Strip IH from 18,852' MD to 21,230' 18,852.0 21,230.0 11:45 14:00 MD. 3/16/2019 3/16/2019 2.75 PROD1 DRILL WASH T Wash and ream from 21,230' MO to 21,230.0 21,341.0 14:00 16:45 21,341' MD 280gpm 2980psi 120rpm, Trq 9.5 k Nibs, Trouble shoot MWD Tools. 3/16/2019 311612019 0.50 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 21,341.0 21,377.0 16:45 17:15 21,341' MD to 21,377' MO / 7,751' TVD, ADT 0.25 Hrs, ECD 10.63 ppg, 280 gpm, 3130 psi,. Closing MPD chokes on connections & monitoring pressure. 3116/2019 3/16/2019 1.00 PRODi DRILL CIRC T Circulate at 21,356' MD while change 21,377.0 21,356.0 17:15 18:15 out swivel packing. 3/16/2019 3/16/2019 0.25 PROD1 DRILL WASH T Wash and ream from 21,356' MD to 21,356.0 21,377.0 18:15 18:30 21,377' MD 280gpm 3000psi 120rpm, Trq 9.5 k Nlbs, 3/1612019 3/17/2019 5.50 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 21,377.0 22,012.0 18:30 00:00 21,377' MD to 22,012' MD / 7,760' TVD, ADT 3.98 Hrs, ECD 10.7 ppg, 280 gpm, 3010 psi, PU: 205k, SO: 100k, ROT: 155k, 120rpm, Trq On/Off 12.519.5 k Nlbs, 14/15k WOB. Closing MPD chokes on connections & monitoring pressure. 3/17/2019 3/17/2019 12.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 22,012.0 23,506.0 0000 1200 22,012' MD to 23,506' MD / 7,779' TVD, ADT 8.65 Hrs, ECD 10.89 ppg, 270 gpm, 3010 psi, PU: 207k, SO: 95k, ROT: 155k, 120rpm, Trq On/Off 14.5/10 k fl/lbs, 10/15k WOB. Closing MPD chokes on connections & monitoring pressure. 3/17/2019 3/18/2019 12.00 PROW DRILL DDRL P Drill 6-3/4"Alpine A lateral from 23,506.0 25,068.0 12:00 00:00 23,506' MD to 25,068' MD / 7,795' TVD, ADT 9.05 Hrs, ECD 11.07 ppg, 270 gpm, 3410 psi, PU: 210k, SO: 100k, ROT: 150k, 130rpm, Trq On/Off 15.5/11.5 k Nlbs, 12/15k WOB. Closing MPD chokes on connections & monitoring pressure. 3/18/2019 3/18/2019 12.00 PRODt DRILL DDRL P Drill 6-3/4" Alpine A lateral from 25,068.0 26,700.0 00:00 12:00 25,068' MD to 26,700' MD / 7,812' TVD, ADT 9.05 Hrs, ECD 11.21 ppg, 270 gpm, 3450 psi, PU: 215k, SO: Ok, ROT: 160k, 120rpm, Trq On/Off 16/11.1 k UK 15k WOB. Closing MPD chokes on connections & monitoring pressure. Lost SIO weight at 25,596' MD Mud losses 15/20bph Page 17/56 ReportPrinted: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 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 rtKB) End Depth (flKB) 3/18/2019 3/19/2019 12.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral from 26,700.0 28,325.0 12:00 00:00 26,700' MD to 28,325' MD 17,830' TVD, ADT 9.18 Hrs, ECD 11.15 ppg, 270 gpm, 3630 psi, PU: 215k, SO: Ok, ROT: 160k, 120rpm, Trq On/Off 17/11.5 k fUlbs, 12/15k WOB. Closing MPD chokes on connections & monitoring pressure. Mud losses 15/20bph 3/19/2019 3/19/2019 12.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral f/28,325' to 28,325.0 29,340.0 00:00 12:00 29,340' MD / 7,842' TVD, ADT 9.74 His, ECD 11.04 ppg, 270 gpm, 3210 psi, PU: 215k, SO: Ok, ROT: 160k, 120rpm, Trq On/Off 14/11.2 k ft/lbs, 12/15k WOB. Closing MPD chokes on connections & monitoring pressure. Mud losses 15/20bph 3/19/2019 3/20/2019 12.00 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral f/29,340'to 29,340.0 29,873.0 12:00 0000 29,873' MD / 7,847' TVD, ADT 9.74 Hrs, ECD 10.69 ppg, 270 gpm, 3460 psi, PU: 217k, SO: Ok, ROT. 160k, 120rpm, Trq On/Off 14/10.5 k ft/lbs, 5/8k WOB. Closing MPD chokes on connections & monitoring pressure. Mud losses 15/20bph 3/20/2019 3/20/2019 12.00 PRODt DRILL DDRL P Drill 6-3/4" Alpine A lateral f/29,873' to 29,873.0 30,647.0 00:00 1200 30,647' MD / 7,853' TVD, ADT 8.88 Hrs, ECD 10.89 ppg, 270 gpm, 3500 psi, PU: 235k, SO: N/A, ROT: 164k, 120rpm, Trq On/Off 18/12 k ft/lbs, 12/18k WOB. Closing MPD chokes on connections & monitoring pressure. Mud losses 15/20bph 3/20/2019 3/20/2019 2.75 PROD1 DRILL DDRL P Drill 6-3/4" Alpine A lateral f/30,647'to 30,647.0 31,040.0 12:00 1445 TD of 31,040' MD / 7,857' TVD , ADT 2 Hrs, ECD 11.15 ppg, 270 gpm, 3690 psi, PU: 220k, SO: N/A, ROT: 161k, 125rpm, Trq On/Off 21/11.5 k ft/lbs, 15/17k WOB. Closing MPD chokes on connections & monitoring pressure. Mud losses 15/20bph. 3/20/2019 3/20/2019 0.50 PROD1 DRILL DDRL T Lost all communication wit directioanl 31,040.0 31,040.0 14:45 1515 & logging tools. Trouble shoot MWD tool. TO @ 31,040' MD. 7,857' TVD 3/20/2019 3/20/2019 5.00 PROD1 CASING CIRC P Circulate 2 bottoms up from 31,040'to 31,040.0 30,833.0 15:15 2015 30,833' MD @ 270gpm 3300psi. 130rpm. 16k tq, Racking back a stand after each bottoms up. 3/20/2019 3/21/2019 3.75 PROD1 CASING BKRM P BROOH f/ 30,833'to 28,929'@ 270 30,833.0 28,929.0 20:15 0000 gpm. 3100 psi. 130 rpm. 15k tq. 3/21/2019 3/21/2019 7.75 PROD1 CASING BKRM P BROOH f/ 28,929'to 25,406" @ 270 28,929.0 25,406.0 00:00 07:45 gpm. 2900 psi. 130 rpm. 11.5k tq. 3/21/2019 3/21/2019 3.50 PROD1 CASING SMPD P Line up to SOON. SOOH f/ 25,406't/ 25,406.0 22,081.0 07:45 11:15 22,081' as per shedule. 350/80 psi out/in slips. up wt 206k. 3/21/2019 3/21/2019 0.50 PROD1 CASING OWFF P Flow check. 22,081.0 22,081.0 11:15 11:45 3/21/2019 3/21/2019 3.25 PROD1 CASING CIRC P Break circulation and displace to 9.5 22,081.0 22,081.0 11:45 15:00 ppg vis -brine. @ 280 gpm. 2170 psi. 40 rpm. 8k tq. 205k/127k u/d wt. 3/21/2019 3/21/2019 0.50 PROD1 CASING OWFF P Take SPR. Flow check (static). 22,081.0 22,081.0 15:00 1530 Page 18156 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) C D5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Siert Time End Time our(no Phase op Cafe Activity Cone Time P-T.X Operation Start Depth (flKB) End Depth(flKB) 3/21/2019 3/21/2019 7.00 PROD1 CASING SMPD P SOOH it 22,081't/ 13,815' as per 22,081.0 13,815.0 15:30 22:30 shedule. 150/50 psi outtin slips. 1801135k Wd wt. 3/21/2019 3/21/2019 0.25 PROD1 CASING BOPE P Function test rams. 13,815.0 13,815.0 22:30 22:45 3/21/2019 3/22/2019 1.25 PROD1 CASING CIRC P Circulate BU 270 gpm. 1530 psi. 30 13,815.0 13,815.0 22:45 00:00 rpm. 4.5k tq. 3/22/2019 3/22/2019 0.50 PROD1 CASING OWFF P Flow check (static) 13,815.0 13,815.0 00:00 00:30 3/2212019 3/22/2019 5.50 PROD1 CASING SMPD P SOOH UD 4" DP. f/ 13,815' to 9,686 13,815.0 9,686.0 00:30 06:00 per stripping schedule 150180 psi outlin. 3/22/2019 3/22/2019 0.50 PRODi CASING OWFF P Flow check (static) 9,686.0 9,686.0 06:00 06:30 3/22/2019 3/22/2019 0.50 PROD1 CASING MPDA P Pull RCD bearing assembly. Install trip 9,686.0 9,686.0 06:30 07:00 nipple. 3/22/2019 3/22/2019 0.25 PROD1 CASING OWFF P Line up on trip tank. flow check. 9,686.0 9,686.0 07:00 07:15 minimal losses 3/22/2019 3/22/2019 0.50 PROD? CASING CIRC P Pump 30 bbl 10.45 ppg slug. 9,686.0 9,686.0 07:15 0745 3/22/2019 3/22/2019 8.75 PRODI CASING PULD P POOH UD 4 " DP f/ 9,686 to 231' 9,686.0 231.0 07:45 1630 3/22/2019 3/22/2019 0.25 PROD1 CASING OWFF P Flow check. Minimal losses. PJSM 231.0 231.0 16:30 16:45 UD BHA. 3/22/2019 3/22/2019 0.75 PRODi CASING BHAH P UD BHA as per SLB f/231' to 81' 231.0 81.0 16:45 17:30 3/22/2019 3/23/2019 6.50 PROW CASING WAIT T Phase 3 condition. Wait on weather to 81.0 81.0 17:30 00:00 pass. Monitor well on trip tank. 2.5 bbls/hr losses 3/23/2019 3/23/2019 4.00 PROD1 CASING WAIT T Phase 3 condition. Wait on weather to 81.0 81.0 00:00 04:00 pass. Monitor well on trip tank. 2.5 bbls/hr losses 3/23/2019 3123/2019 0.75 PROD1 CASING BHAH P UD BHA as per SLB 1/81'to surface. 81.0 0.0 04:00 04:45 (NM Stabilizer worn completely down. Bit Grade 1 -1 -ER -S -X -IN -NO -TD 3/23/2019 3/23/2019 1.75 COMPZI CASING RURD P R/U to run liner. Power tongs, slips, & 0.0 0.0 04:45 06:30 elevators 3/23/2019 3/23/2019 7.50 COMPZI CASING PUTB P RIH w/4-1/2", 12.6#, L-80, Hyd 563 0.0 7,975.0- 06:30 14:00 liner w/Frac Sleeves to 7,975' (197 Its & 9 Frac Sleeves) 3/23/2019 3/23/2019 0.50 COMPZ1 CASING RURD P RID casing running tools & equipment. 7,975.0 7,975.0 14:00 14:30 C/O Handling equipment. 3/23/2019 3/23/2019 0.50 COMPZI CASING OTHR P M/U Flex look liner hanger & HRD-E 7,975.0 8,122.0 14:30 15:00 ZXP Liner lop packer w/sealbore extension. Add Pal mix. M/U Bumper sub, XO to 8,030' M/U 1 stand of 4" 14# DP & RIH to 8,122'. 3/23/2019 3/23/2019 0.50 COMPZI CASING OTHR P Break circulation and stage up to 5 8,122.0 8,122.0 15:00 15:30 bpm. 350 psi. PU 120k/S0 105k/Rot 110k. Take parameters w/ pumps off 10/20/30 rpm 2k ft/lbs tq. 3/23/2019 3/23/2019 3.75 COMPZI CASING RUNL P RIH wAiner on DP f/8,122'to 13,728' 8,122.0 13,728.0 15:30 19:15 3/23/2019 3/23/2019 0.25 COMPZI CASING OTHR P Break circulation and stage up to 5 13,728.0 13,728.0 19:15 19:30 bpm. 350 psi. PU 170k/SO 140k/Rot 155k. Take parameters w/ pumps off 10/20/30 rpm 4k f Ilbs tq. 3/23/2019 3/24/2019 4.50 COMPZI CASING RUNL P RIH Winer on DP f/ 13,728'to 13,728.0 17,053.0 19:30 00:00 17,053' 3/24/2019 3/24/2019 6.00 COMPZI CASING RUNL P RIH w/liner on DP f/17,053'to 21,708' 17,053.0 21,708.0 00:00 06:00 Page 19/56 Report Printed: 71212019 Operations Summary (with Timelog Depths) CD5-24 • 1 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Tune Our(h) phase Op cod. Activity Code Time P -T -X Operation (fixe) End Depth(fd(B) 3/24/2019 3/24/2019 0.50 COMPZ1 CASING HOSO P P/U working single ans space out liner 21,708.0 21,708.0 06:00 06:30 on depth. Break circ & obtain base parameters. 2 bpm, 190 psi, PU wt 195k, SO wt 130 k 3/24/2019 3/24/2019 0.25 COMPZ1 CASING OWFF P FIC (static) 21,708.0 21,708.0 0630 06:45 3/24/2019 3/24/2019 1.75 COMPZ1 CASING PACK P Set liner hanger/packer as per Baker. 21,708.0 13,700.0 06:45 08:30 Drop 1.625" ball. Pump down w/3 - 2 bpm. Ball on seat 1149 stks. Pressure up to 2500 psi to set Flex -Lock Liner Hanger. Slack off to block wt and confirm set. Pressure up to 4200 psi to set HRD-E Liner Top Packer. P/U to expose dogs. Slack of to block wt & confirm set. Pressure test liner top packer to 2000 psi & chart for 10 min (good). TOL -13,700'1 Shoe @ -21,708' 3124/2019 3/2412019 0.25 COMPZ1 WELLPR TRIP P UD working single & POOH 1 stand to 13,700.0 13,651.0 08:30 08:45 above top of liner to 13,651' 3/24/2019 3/24/2019 3.75 COMPZ1 WELLPR CIRC P Circ B/U w/250 gpm, 750 psi. 13,651.0 13,651.0 08:45 12:30 Observed significant gas on B/U. Circ an additonal B/U thru gas buster to aid on removing gas from mud system. 3/24/2019 3/24/2019 0.25 COMPZ1 WELLPR RURD P PJSM on slip & cut. R/U to slip & cut. 13,651.0 13,651.0 12:30 12:45 B/D choke lines. 3/24/2019 3/24/2019 1.00 COMPZ1 WELLPR SLPC P Slip & cul drill line. SIMOPS - Cont to 13,651.0 13,651.0 12:45 13:45 1 1 1 circ & cond w/125 gpm, 230 psi. 3/24/2019 3/24/2019 0.50 COMPZ1 WELLPR SVRG P Service rig. SIMOPS - Cont to ciro & 13,651.0 13,651.0 13:45 14:15 cond w/125 gpm, 230 psi. 3/24/2019 3/24/2019 0.25 COMPZ1 WELLPR OWFF P F/C (static) 13,651.0 13,651.0 14:15 14:30 3/24/2019 3/24/2019 0.25 COMPZ1 WELLPR CIRC P Pump dry. B/D top drive 13,651.0 13,651.0 14:30 14:45 3/24/2019 3/24/2019 1.25 COMPZ1 WELLPR TRIP P POOH & rack 14 stands 15.7# DP 13,651.0 12,323.0 14:45 16:00 fill 3,651'to 12,323' 3/24/2019 3/24/2019 3.50 COMPZ1 WELLPR PULD P Cont. to POOH while UD 14# DP 12,323.0 8,803.0 16:00 19:30 f/12,323' to 8,803'. 3124/2019 3/24/2019 3.00 COMPZ1 WELLPR TRIP P POOH f/ 8803'to 1012'. Racking back 8,803.0 1,012.0 19:30 22:30 DP in derrick. j 3124/2019 3/24/2019 0.25 COMPZ1 WELLPR OWFF P FIC. Slight losses. 1,012.0 1,012.0 22:30 22:45 3/24/2019 3/2412019 0.25 COMPZ1 WELLPR TRIP P POOH f/ 1012'to 67'. Racking back 1,012.0 67.0 22:45 23:00 DP in derrick. 3/24/2019 3/24/2019 0.50 COMPZ1 WELLPR BHAH P UD liner running tools. 67.0 0.0 23:00 23:30 3/24/2019 3125/2019 0.50 COMPZ1 WELLPR CLEN P Clean and clear rig floor. Prep to plu 0.0 0.0 23:30 00:00 whipstock. Monitor hole on TT. 3/25/2019 3/2512019 1.00 COMPZ1 WELLPR CLEN P Clean and clear rig floor. SIMOPS - 0.0 0.0 00:00 01:00 Mobilize whipstock milling components to rig floor. Monitor hole Ion TT. 3/25/2019 3/25/2019 0.25 COMPZ1 WELLPR RURD P Retrieve wear ring. 0.0 0.0 01:00 01:15 3/25/2019 3/25/2019 4.75 PROD2 WHPST BHAH P M/U whipstock milling BHA as per 0.0 579.0 01:15 06:00 Baker & SLB (35 k shear bolt / MWD tool face offset is 79 degrees) 3125/2019 3125/2019 1.25 PROD2 WHPST TRIP P RIH f/579'to 2,380' 579.0 2,380.0 06:00 07:15 3/25/2019 3/25/2019 0.75 PROD2 WHPST DHEO P Shallow hole test MWD slim pulse 2,380.0 2,380.0 07:15 08:00 tools w/320 gpm, 1190 psi. Page 20/56 Report Printed: 71212019 operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log start Depth Sten Tune End Time Our (hr) Posse Op Code Activity Code Time P -T -X Operation (RKB) End Depth (ftKB) 3/2512019 3/25/2019 7.00 PROD2 WHPST TRIP P RIH f/2,380'to 13,414' 2,380.0 13,414.0 08:00 15:00 3/25/2019 3/25/2019 2.00 PROD2 WHPST DLOG P Log RA tag & orient whipstock 13,414.0 13,696.0 15:00 17:00 f/13,414'to 13,696'w/280 gpm 11560 psi (RA tag logged on depth @ 13,104'). Orient whipstock 47 degrees left. PU wt 180 k / SO 148 k. 3/25/2019 3/25/2019 0.50 PROD2 WHPST WPST P Engage seals on TOL f/13,700'to 13,696.0 13,706.0 17:00 17:30 13,706'. Set whipstock anchor with 20 K WOB. Pull IOk over and confirm anchor set. Slack of 35 k WOB and shear bolt on mills. PIU and confirm free. TOW @ 13,355'& BOW @ 13,368' 3125/2019 3/25/2019 1.00 PROD2 WHPST CIRC P POOH 1 stand to 13,350'& circ B/U 13,706.0 13,350.0 1730 1830 w/280 gpm 11540 psi. 3/25/2019 3/25/2019 0.25 PROD2 WHPST OWFF P FIC (static) 13,350.0 13,350.0 18:30 18:45 3/25/2019 3125/2019 1.00 PROD2 WHPST PRTS P Test seals to 2500 psi f/ 10 13,350.0 13,350.0 18:45 19:45 minutes.Good test. 31252019 312512019 2.25 PROD2 WHPST PULD P POOH and LID DP f/ 13,350'to 13,350.0 13,159.0 19:45 22:00 13,159'. LID 3 aids DP from derrick while waiting on slickline to arrive. 3/25/2019 326/2019 2.00 PROD2 WHPST SLKL P PJSM and RU slickline to retrieve 13,159.0 13,159.0 22:00 00:00 slimpulse tool. 326/2019 3262019 2.00 PROD2 WHPST SLKL P RIH with 2.2" OD slick line retrieval 13,159.0 13,159.0 00:00 02:00 tool. Not able to make it past upper Baker Extreme magnet @ 12,931' 3/26/2019 3/26/2019 7.25 PROD2 WHPST SLKL T POOH with slick line & inspect tools. 13,159.0 13,159.0 02:00 09:15 C/O tools to 1.9" OD tools. RIH thru magnets & engage top of MWD slimpulse tool. Attempt to POOH & not able to pass thru lower Baker Extreme magnet @ 13,069'. Double check minimum ID's with Baker Fishing Shop & confirm that the minimum ID was 2.0". Release from slimpulse tool. POOH & RIO slick line. 312612019 3126/2019 0.75 PROD2 WHPST CIRC T Break circ & confirm flow path Gear. 13,159.0 13,159.0 09:15 10:00 Pump 30 bbls of 10.2 ppg dry job. B/D top drive. 326/2019 326/2019 4.75 PROD2 WHPST TRIP T POOH with milling assy 1/13,159'to 13,159.0 227.0 10:00 14:45 227' 326/2019 3/26/2019 1.25 PROD2 WHPST BHAH T Rack back Baker magnets. LID MWD 227.0 227.0 14:45 16:00 tools. Inspect milling BHA 3/26/2019 3/26/2019 0.50 PROD2 WHPST SVRG T Service rig. SIMOPS - Clean & clear 227.0 227.0 16:00 16:30 floor 3/26/2019 3/26/2019 6.00 PROD2 WHPST TRIP T RIH w/milling suspension BHA f/ 227' 227.0 13,123.0 16:30 22:30 to 13,123'. 3/26/2019 3126/2019 0.50 PROD2 WELLPR OWFF P Flow check. (static). C/O handling 13,123.0 13,123.0 22:30 23:00 equipment to plu landing joint. 3/26/2019 3126/2019 0.25 PROD2 WELLPR THGR P MU hanger and landing joint. Land 13,123.0 13,161.0 23:00 23:15 hanger. Mill @ 13,161'. PU 180k. SO 150k. 3126/2019 3262019 0.50 PROD2 WELLPR RURD P LD landing joint. RU to test BPV. 0.0 0.0 23:15 23:45 326/2019 3/27/2019 0.25 PROD2 WELLPR MPSP P Test BPV to 2500 psi. f/ 10 minutes. 0.0 0.0 23:45 00:00 Good fres(. 3/27/2019 3/27/2019 0.15 PROD2 WELLPR MPSP P RX) BPV testing tools & equipment. 0.0 0.0 00:00 00:45 Page 21156 Report Printed: 712/2019 Uperations Summary (with Timelog Lepths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth SUMMme end Time Our (hn Phase Op Code Activit' Code Time P -T -X Operetion rIK8) End Depth (ftKB) 3/27/2019 3/27/2019 3.25 PROD2 WELLPR CLEN P Clean drip pan. Pull covers to access 0.0 0.0 00:45 04:00 under rotary table & clean same. Clean & clear dg floor. Clean pipe racks. SIMOPS - B/D lines & prep to N/D MPD equipment. 3/27/2019 3/27/2019 0.50 PROD2 WELLPR W W WH P M/U Johnny Wacker & flush stack. B/D 0.0 0.0 04:00 04:30 top drive, choke & kill lines. 3/27/2019 3/27/2019 6.25 PROD2 WELLPR NUND P Remove flow box & flow line. 0.0 0.0 04:30 10:45 Disconnect choke & kill lines. N/D MPD & BOPE equipment. Rack back BOPE. 3/27/2019 3127/2019 1.25 PROD2 WELLPR NUND P NIU dry hole tree as per FMC. Install 0.0 0.0 10:45 12:00 test dart & fill tree with diesel 3/27/2019 3127/2019 1.75 PROD2 WELLPR PRTS P Pressure test tree void 250/5000 psi 0.0 0.0 12:00 13:45 for 10 min (good). Pressure test tree 250/5000 psi for 10 min (good) 3/27/2019 3/27/2019 4.25 PROD2 WELLPR FRZP P R/U Ball Mill & pressure test lines to 0.0 0.0 13:45 18:00 2500 psi. Pump 85 bbls freeze protect diesel w/3 bpm @ 890 psi. Let U -Tube & stabilize. SHOPS - Prep rig for DeMob. 3/27/2019 3/27/2019 0.50 PROD2 WELLPR MPSP P FMC install BPV. & Ball Mill test to 0.0 0.0 18:00 18:30 2500 psi in direction of flow. Well secure. Final pressures: OA= 250 psi, IA = 0 psi, Tbg = 0 psi 3/27/2019 3128/2019 5.50 PROD2 WELLPR DMOB P Prep for rig for DeMob. SIMOPS - 0.0 0.0 18:30 00:00 clean pits. Rig released @ 24:00 Hrs. Final wellview report for Doyon 19 4/24/2019 4124/2019 18.00 PROD2 MOVE MOB P Prep rig for move. Separate modules 0.0 0.0 00:00 18:00 and prep for move to CD5-24. 4/24/2019 4125/2019 6.00 PROD2 MOVE DMOB P Derrick Sub and Pipe shed on CD5 0.0 0.0 18:00 00:00 pad by midnight. Moving pipe racks and assorted equipment with flatbeds. 4 rig modules 2 fuel tanks 2 equipment trailers 1 shop left on location to be moved. Takes about 5 hours to move the modules from CD2 to CD5. We moving two at a time. 4/25/2019 4/25/2019 8.00 PROD2 MOVE MOB P Sows hook up and move Pump room 0.0 00:00 08:00 and Engine room modules from CD2 to CD5. Continue moving assorted rig equipment on flatbeds. 4/25/2019 4/25/2019 9.00 PROD2 MOVE MOB P Sows return to CD2 from CD5 and 08:00 17:00 hook up to Shaker/Mud pit modules and Casing shed and move from CD2 to CD5. All modules on CD5 now. Concurrently Prep pad for modules with herculite. 4/25/2019 4/25/2019 1.50 PROD2 MOVE RURD P Spot Derrick sub over CD5-24. 17:00 18:30 4125/2019 4126/2019 5.50 PROD2 MOVE RURD P Move pit complex modules into 18:30 00:00 position with sow. Set rig mats, transition to pull pipe shed into position, stomp pipe shed into sub complex. Concurently move 2 parts trailers and 1 shop tom CD2 to CD5. Page 22/56 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Steri Depth Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (flK8) End Deplh(tiKB) 4/26/2019 4/26/2019 6.00 PROD2 MOVE RURD P Stomp pipe shed into place, shim and 00:00 06:00 pin to sub. Lay herculite for Casing shed/Office module. Set mats place Casing shed/Office module in place with sow. Stomp Pits into place and shim. Set Cellar walls and shim. Position Pump Module with sow. 4/26/2019 4/26/2019 3.00 PROD2 MOVE RURD P Stomp Pump module in place and 06:00 09:00 shim. Position and set Power module in place and shim. 4/26/2019 4/26/2019 3.00 PROD2 MOVE RURD P Raise derrick and skid rig floor over 09:00 12:00 well. Continue working on interconnect hook up. 4/26/2019 4/26/2019 1.50 PROD2 MOVE RURD P Lower C-section, raise rattle chute, 12:00 13:30 and continue working on interconnects. Steam up rig. 4/26/2019 4/26/2019 6.50 PROD2 MOVE RURD P Prepare derrick to scope up. Plug in 13:30 20:00 1 1 1 power module to sub. 4/26/2019 4/26/2019 1.50 PROD2 MOVE RURD P Scope derrick up. Tie up stopping 20:00 21:30 lines, clean and clear rig floor. 4/26/2019 4/27/2019 2.50 PROD2 MOVE RURD P Continue to work interconnects, hook 21:30 00:00 up Kelly hose, well house flooring, site control office. Bring in electric pump into pit area for cutting transfer. Rig sweep of staris/handrails, and landings. Trim excess herculite around modules, make a loose tool round -up. 4/27/2019 4/27/2019 6.00 PROW MOVE RURD P Bring cuttings transfer pump into 00:00 06:00 pump room and chain fall and come along to pit 1. NOVOS installation. 4/27/2019 4/27/2019 6.00 PROD2 MOVE RURD P Prep cutting tank (pit 1) for eddy pump 06:00 12:00 install. Begin NOVOS install in drillers cabin. Continue Ball mill integration to pump module. Pull rotary table, clean and inspect and install new mud seal. Rig on highline power. 4/27/2019 4/27/2019 6.00 PROD2 MOVE RURD P Continnue Eddy pump install, NOVOS 12:00 18:00 install, Work on installing new UPS in cabin, Continue with Ball mill integration into pump module. Install 1502 flange on well head and prep for displacement. Continue working on rotary and start loading 4" drill pipe to pipe shed. 4/27/2019 4/28/2019 6.00 PROD2 MOVE RURD P Rig up FMC lubricator to tree. Test 1800 0000 lubricator and pull BPV. Rigged up to rock diesel out of wellbore to tiger tank. Steamed tiger tank line, Test lines to 1000 psi. Pump 31 bbls down IA to reverse out tubing. Swapped line to pump down tubing and pumped 141 bbls total at 4 bpm, 725 psi. Blow down injection line mud pump, and tiger tank lines. Rig down hoses, disconnect from tiger tank. 4/28/2019 4/28/2019 3.00 PROW MOVE RURD P Set BPV and lest from IA to 1000 psi —7 00:00 03:00 for 10 minutes. Blow down lines and rig down. Monitor IA fro 30 minutes. No flow. Change out upper and lower rams to 2 7/8" x 55' VBR's Page 23156 Report Printed: 712/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log start Depth start Time End Time Dur(m) Phase Op Code Anvity Code Time P -T -X Operation (fiKa) End Dep0(flKa) 4/28/2019 4/28/2019 9.00 PROD2 MOVE RURD P Rig up to remove Tree. (FMC 03:00 12:00 DINO" , on Doyon 141) Continue with Eddy pump install and NOVOS install. Continue with Ball Mill integration. Finish loading 4" in pipe shed and tallied same. 4/28/2019 4/28/2019 6.00 PROD2 MOVE RURD P Continue with Eddy pump install and 12:00 18:00 NOVOS install. Continue with Ball Mill integration to pump module. Prep mast for cylinder inspection. 4/28/2019 4/29/2019 6.00 PROD2 MOVE RURD P FMC arrive. Nipple down tree and 18:00 00:00 install blanking plug. Nipple up adapter riser, DSA, Riser, and BOP stack. Start installing choke and kill lines. 4/29/2019 4/29/2019 6.00 PROD2 MOVE NUND P Continue to nipple up BOP& Choke 0.0 0.0 0000 06:00 and Kill line, Prep toTest BOP 4/29/2019 4/29/2019 6.00 PROD2 MOVE RURD P Continue work on NOVOS software, 0.0 0.0 0600 1200 install and Test tools as per NOV Reps. Cont./w Ball Mill integration and eddy pump install. SIMOPS test MPD orbit valve. 4/29/2019 4/29/2019 6.00 PROD2 MOVE RURD P Continue with NOVOS software install 0.0 0.0 1200 18:00 & testing, Cont./w Ball mill integration and eddy pump install, SIMOPS on PS -21 Slips, worked on trip nipple adjustment.Prepare for BOP Test. 4/29/2019 4/29/2019 3.00 PROD2 MOVE BOPE P R/U to test ROPE, fill stack and purge 0.0 0.0 18:00 21:00 air from system. SIMOPS integration of rig with Ball Mill. 4/29/2019 4/30/2019 3.00 PROD2 MOVE BOPE P Continue BOP testing, AOGCC Lou 0.0 0.0 21:00 0000 Laubenstien waived witness. SIMOPS take on 320bls Vis Brine, and 275bls Flow Pro. 4/30/2019 4/30/2019 6.00 PROD2 MOVE RURD P Continue with BOP test, Take on 0.0 0.0 00:00 0600 320bls of Vis Brine and 275bls Flow Pro 4/30/2019 4/30/2019 6.00 PROD2 MOVE RURD P Rig up and pull FMC blanking plug, 0.0 12,302.0 0600 12:00 rigged up 4" elevators and power tongs, MU H563 jt of tbg & BOLDS. Pulled and laid don hanger, pup, and 3 -1/2 TSH Blue Box / 3-1/2 XT39 pin X - over. PU Wt.173k. MU TD to Mill String, circulated with 9.5ppg Visc- Brine, staged up to 7 -bpm at 1173 psi. Fluid out 16%, PU Wt. 168k, S/O Wt. 140k. 4/30/2019 4/30/2019 3.00 PROD2 MOVE RURD P Continue to circulate w/ 9.5 Visc- 12,302.0 13,364.0 1200 1500 Brine, @ 7-bpm/1 1 73psi total stokes pumped 12,302. PIU & RIH w/10 joints of 4" DP, tagged top of window @ 13,364' MD obtained parameters as per Baker Rep. 400 GPM @ 2061 psi while rotating at 90 rpm, P/U Wt. 170k, S/O Wt, 137k, ROT Wt. 152k. Service Rig, test lines from Ball mill to pits.. 4/30/2019 5/1/2019 9.00 PROD2 MOVE RURD T Troubleshoot Top Drive./ Drive Fault 13,364.0 13,364.0 15:00 00:00 Replace Encoder 5/1/2019 5/1/2019 2.50 PROD2 MOVE RURD T Cont. Troubleshooting Top Drive 13,364.0 13,364.0 00:00 02:30 5/1/2019 5/1/2019 0.50 PROD2 WHPST MILL P Establish milling parameters @ 90 13,364.0 13,364.0 02:30 03:00 rpm, 4k ftlbs, 400 GPM, with 1910 psi on std pipe, PU Wt. 163k, SO Wt, 135k. Re -lest Gas Alarms, Page 24156 Report Printed: 712/2019 Operations Summary (with Timelog Depths) r„l . CDS-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Cur (ho Phase Op Carte Activity Code Time P -T -X Operation (flKB) End Depth (M) 5/1/2019 5/1/2019 9.00 PROD2 WHPST MILL P Milling Window as Per Baker, Rotating 13,364.0 13,398.0 03:00 1200 -Tagged Whipstock @ 13,364' MD, 90 -120 RPM, torque 8-10k, at 450 GPM, 1910 psi, 16-20% flow out, PU-163k, SO -135k, Rotating Wt. -157k, Pumped 2ea High Visc sweeps as needed, TOW - 13,364'/ BOW - 13.378' MD. Inclination - 77DEG., Orientation - 48LOHS, Milled Depth - 13,398' MD. 5/1/2019 5/1/2019 1.75 PROD2 WHPST MILL P Pumped Super sweep while rotating 12:00 13:45 and reciprocating from 13,350'to 13,398' MD at 450 GPM and 2640 psi. Continued, and pumped sweep out of hole. Worked mill through window and continued to dress and polish as required. PU-Wt. 163k, SO -Wt. 135k, Total strokes pumped 7237. Shut down pumps, drifted mill through window without pump or rotary. 5/1/2019 5/1/2019 0.75 PROD2 WHPST MILL P Pulled out of hole and racked one 13:45 1430 stand, circulated and conditioned mud until returns were clean at 450 GPM with 2640 psi. Shut down pumps and observed well for flow - well static. 5/1/2019 5/1/2019 3.50 PROD2 WHPST SLPC P Cut and slip drill line. Continued to 14:30 1800 monitor well as per hole fill, calibrated Amphion and Totco. SIMOPS - inspected and replaced belt on top drive. 5/1/2019 5/2/2019 6.00 PROD2 WHPST MILL P Located and recorded slow pump 18:00 00:00 rates, MP#1; 30 SPM @ 440 psi, and 40 SPM @ 580 psi. MP#2; 30 SPM @ 460 psi, and 40 SPM @ 490 psi. 12,830' MD, MW 9.4 ppg. Pulled out of hole from 13,278' MD, PU Wt. 167k, SO Wt. 135k, continued to 12,830' MD. Flow Checked well - Static. Pumped 35 bbl. of 12.0 ppg Dry Job at 40 SPM and 575 psi. B/D Top Drive and continued to pull out of hole from 12,830'to 9,000' MD. Current rate of pull; 60 ft/min and observed no over pull. 5/2/2019 5/2/2019 5.50 PROD2 WHPST TRIP P Continued to pull 4" DP out of hole 9,000.0 200.0 00:00 05:30 from 9,000' MD to 200' MD at a rate 75ft per min. Average fluid loss, 41bbls. Flow check well prior to pulling non - shearing tools through the BOP stack. Well remained static. 5/2/2019 5/2/2019 3.25 PROD2 WHPST BHAH P Performed Pre -job Safety meeting and 200.0 0.0 05:30 0845 laid down milling bottom hole assembly from 200' MD to surface. Laid down bottom hole assembly as instructed by Baker rep. Cleaned magnets and disposed whickers. 5/2/2019 5/2/2019 1.00 PROD2 WHPST BHAH P Clean and clear rig floor 0.0 0.0 08:45 0945 SIMOPS ID test performed on Top Drive. 5/2/2019 5/2/2019 1.50 PROD2 WHPST WWWH P Flushed and cleaned stack using the 0.0 0.0 09:45 11:15 jetted clean out tool, Blew down and flushed both choke and kill lines and functioned all valves. Set wear - bushing at 35.01 RKB and ran in lockdown screws as per FMC Rep. Wear -bushing dimensions; ID - 6.875" OD — 10.250" total length 12.0" Page 25156 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) C D5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 5/2/2019 5/2/2019 0.75 PROD2 WHPST BHAH P Performed Pre-Job Safety Meeting 0.0 112.0 1115 1200 and made up the 6-3/4" bottom hole drilling assembly as per instructed by Schlumberger from surface to 112" MD. PU Wt. 60k / SO Wt, 62k, 5/2/2019 5/2/2019 1.50 PROD2 WHPST BHAH P Continued to make up drilling bottom 112.0 350.0 1200 1330 hole drilling assembly from 112' MD to 350' MD. PU Wt. 65k / SO WL 70k 5/2/2019 5/2/2019 4.50 PROD2 WHPST PULD P Continued to single in hole on 350.0 2,377.0 13:30 18:00 elevators with 4" DP from 350' MD to 2377' MD monitoring fluid displacement in trip tank. PU Wt.-75k I SO Wt.-83k, filling hole/pipe every 20 joints. Performed shallow hole test, MWD, followed with sonic log 40' at 900 ft per hour and 6 barrels per min. at 1072 psi, cycled pump to put sonic in sleep mode. 5/2/2019 5/3/2019 6.00 PROD2 WHPST PULD P Continue to single in hole on elevators 2,377.0 6,052.0 18:00 0000 with BHA from 2377' MD to 6,052' MD, Monitoring fluid displacement and fill up, filling pipe every 60 joints. PU Wt. 108k /SO Wt. 103k. 5/3/2019 5/3/2019 3.00 PROD2 WHPST PULD P Continue to run in hole on elevators 6,052.0 8,000.0 00:00 0300 with 4.0" DP XT39 from 6,052' to 8,000'MD while monitoring fluid displacement in pit 3. PU Wt. — 313k / SO Wt. -115k. Continue to fill pipe every 60 joints as specified. 5/3/2019 5/3/2019 5.50 PROD2 WHPST QEVL P Filled pipe at 8,000' MD at 60 SPM 8,000.0 10,994.0 03:00 0830 with 1260 psi. SIMOPS—performed downlink and enabled SLB Sonicscope log tool as per SLB DD. Continued to single in hole on elevators from 8,000'to 10,994' MD. Running in hole at 30' per min, continued to monitor fluid displacement on pit 3. PU Wt. 140k / SO Wt. 125k. 5/3/2019 5/3/2019 2.50 PROD2 WHPST QEVL P Picked up 4.0" DP XT39 stands from 10,994.0 13,055.0 08:30 11:00 Dereck and ran in hole. Continue running in hole at 30' per min as per required for SLB's Sonicscope, from 10,994'to 13,081' MD. PU WT. 148k / SO Wt. 123k while continuing to fill pipe every 20 stands. Monitored fluid displacement going to pit 2. 5/3/2019 5/3/2019 0.50 PROD2 WHPST RGRP T Troubleshoot Top Drive DDI and NOV 13,055.0 13,055.0 11:00 11:30 1 1 - SIMOPS serviced Top Drive 5/3/2019 5/3/2019 0.50 PROD2 WHPST MPDA P PJSM with MPD Rep. Blow down hole 13,055.0 13,055.0 11:30 1200 fill lines, pulled trip nipple and prep to install MPD bearing. 5/3/2019 5/3/2019 1.00 PROD2 WHPST MPDA P Install MPD bering and re-install 13,055.0 13,055.0 12:00 1300 master bushings, hooked up RCD catch can curtain. 5/3/2019 5/3/2019 2.50 PROD2 WHPST DISP P Displaced well to 9.0 ppg Flo-Pro at 13,055.0 13,055.0 13:00 1530 248 GPM with 1240 psi while rotating pipe at 40 rpm. Torque was recorded at 5k ft lbs. Flow rate was decreased for the last 15min to 122 GPM's at 430 psi while to continue to rotate at 40 rpm. Torque remained at 5k ft lbs.. Page 26156 Report Printed: 712/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log n De Sun Depth Start`flr End Time our(hh Phase op Cotle Advi Gotle ry Time P -T -X Operation End Depen (%(B) 5/3/2019 5/3/2019 1.00 PROD2 WHPST CIRC P WellWorc ran a bais test on the 13,055.0 13,055.0 1530 16:30 coriolis meters, 30 min 248 GPM, 1240 psi and 40 rpm and 15 min at 122GPM at 430 psi while continuing at 40 rpm's. Rotated through both tests withTorque at 5k ft lbs. 5/3/2019 5/3/2019 2.00 PROD2 WHPST RGRP T Trouble shot top drive torque issue, 13,055.0 13,055.0 16:30 18:30 removed NOVOS software and tested at 60 rpm with no change. Re -installed NOVOS, tension encoder belt on drive motor was found to be loose. Corrected problem. Re -calibrated block height on TOTCO and Amphion, SIMOPS: observe well for flow, MPD 6 Psi, to 26 psi in 20 min. 5/3/2019 5/3/2019 1.00 PROD2 WHPST DLOG P Logged 250 GPM at 1190 psi from 13,055.0 13,214.0 18:30 19:30 13,055' MD to 13,214' MD 5/3/2019 5/3/2019 1.00 PROD2 WHPST WASH P Washed down from 13,214' to 13,390' 13,214.0 13,390.0 19:30 2030 MD, pumped 1 bbl per min and pushed BHA through window. 5/3/2019 5/4/2019 3.50 PROD2 DRILL KOST P Established Slow pump Rates at 13,398.0 13,462.0 20:30 00:00 13,085' MD with 9.0 ppg Flo -Pro: MP1 - 20 SPM - 360 psi, 30 SPM - 520 psi / MP2 - 20 SPM - 340 psi, 30 SPM 520 psi. Drilled ahead kicking off, worked BHA through window from 13,398' MD to 13,462' MD. Pumped 250 GPM with 1700 psi, PU Wt. 181k, SO Wt. 124k, ROT 151 it, Kicked off with 40-60 RPM, WOB 10-20k, Torque: 5-14k ft lbs. Total losses 0 bbls. / O.A Pressure 0.0 psi 5/4/2019 5/4/2019 6.00 PROD2 DRILL KOST P Continue to kick off and build section, 13,462.0 13,518.0 00:00 06:00 Worked BHA through window from 13,462'to 13,518' MD. Pumping 260 GPM at 1765 psi PU Wt. 183k SO Wt. 123k Rotating Wt. 151 it. Drilling parameters; 40-100 RPM, WOB 10- 20k Ft lbs. Experenoed communication issues with SLB power drive resulting in tool failure at 13,460' MD. 5/4/2019 5/4/2019 2.25 PROD2 DRILL PMPO T Hole build deemed unattainable, 13,518.0 13,271.0 06:00 08:15 pumped out of hole from 13,518'to 13,271' MD at 42 GPM and 200 psi. Rotated through window at 40 RPM with 6-12k ft lbs. torque. Drag was recorded between 2-10k through the window. 5/4/2019 5/4/2019 3.00 PROD2 DRILL DISP T Held a Pre -Job Safety Meeting and 13,271.0 13,190.0 08:15 11:15 Displaced Well with 9.5 ppg Visc Brine at 210 GPM. Initial Circulation pressure 1200 psi, final circulation pressure 1060 psi as 40 40 RPM, 6k It lbs. torque, while reciprocating DP from 13, 271'to 13,190' MD. 5/4/2019 5/4/2019 0.50 PROD2 DRILL OWFF T Shut pumps off and observed well for 13,190.0 13,190.0 11:15 11:45 flow. (Well was observed as static.) 5/4/2019 5/4/2019 0.75 PROD2 DRILL MPDA T Held Pre -Job Safety Meeting for the 13,190.0 13,190.0 11:45 12:30 RCD's bearing removal. Removed bearing and installed trip nipple. 5/4/2019 5/4/2019 0.50 PROD2 DRILL DISP T Pumped 70 bbl of 10.1 ppg Dry Job, 13,190.0 13,190.0 12:30 13:00 Blew Down Top Drive and MPD skid. Page 27/56 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) C D5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dcr(hr) Phase Op Code Activity Code Time P -T -X Operation (fiKB) End Depth(flKB) 5/4/2019 5/4/2019 5.00 PROD2 DRILL TRIP T Held Pre -Job Safety meeting, Pumped 13,190.0 3,675.0 1300 18:00 out of hole from 13,190' MD to 3,675' MD Racked back stands in derrick PU Wt, 90k SO Wt. 90k: continue to monitor hole fill in pit 2. 5/4/2019 5/4/2019 2.50 PROD2 DRILL TRIP T Held Pre -job safety meeting and 3,675.0 398.0 1800 2030 continued to pull out of hole. Pulled from 3,675' to 398' MD racking back 4" DP in Derrick. Flow check well prior to pulling non -shear able tooling across BOP's. Well - Static. Maintained constant and monitored hole fill on pit 2. 5/4/2019 5/4/2019 3.00 PROD2 DRILL BHAH T Held Pre -job safety meeting for laying 398.0 0.0 20:30 23:30 down 6-3/4" rotary steerable. Laid down BHA to pipe shed and maintained constant hole fill. Gauged reamer and bit, cleaned rig floor and prepped to pick up new BHA. 5/4/2019 5/5/2019 0.50 PROD2 DRILL BHAH T Clean and clear, SIMOPS- Serviced 0.0 0.0 23:30 00:00 top drive and blocks. SLB DO downloaded tools in csg shed, PU up new BHA components, cross -overs, and tools. 5/5/2019 5/5/2019 1.00 PROD2 DRILL BHAH T Picked up new BHA# 9 with SLB. 0.0 109.0 00:00 01:00 Maintained constant hale fill while monitoring pit 2. Pit watcher manually strapping every 10 min. Pick up motor, bit - and bit sub. Performed tool offset per MWD at 297 degrees, RIH, SO Wt. 50k, PU Wt. 52k. 5/5/2019 5/5/2019 5.00 PROD2 DRILL TRIP T Tripped in hole on elevators from 109' 109.0 7,000.0 01:00 0600 to 7,000' MD with 4.0" OR Maintained hole fill over top. Drag limit set at 10k, filling pipe every 20 -stands. Performed shallow hole test as per SLB DD. PU Wt. 120k, SO Wt, 102k. 5/5/2019 5/5/2019 5.00 PROD2 DRILL TRIP T Continued to run in hole from 7,000 to 7,000.0 13,439.0 0600 11:00 13,439' MD with 4.0" OR PU Wt. 177k, SO Wt. 134k, monitored displacement on pit 2, filling every 20 stands for displacement. Logged from 13,085' MD to RA marker at 13,145' MD at 250 GPM and 1,190 psi. at 250 foot per hour 5/5/2019 5/5/2019 1.00 PROD2 DRILL REAM T Reamed down from 13,349'to 13,518' 13,349.0 13,518.0 11:00 12:00 1 1 1 MD at 227 GPM 5/5/2019 5/5/2019 6.00 PROD2 DRILL KOST T Drilled production hole from 13,518.0' 13.518.0 13,689.0 12:00 1800 to 13,689.0' MD, 7,628' TVD, WOB 2- 20k, GPM 253 at 1480 psi, 40 RPM torque, 8k- off 6k ft lbs. Flow out at 14%, PU Wt. 178k, SO Wt. 130k, Rotating Wt. 150k, 5/5/2019 5/5/2019 1.00 PROD2 DRILL KOST T Continue to drill from 13,689' to 13,689.0 13,711.0 18:00 1900 13,711' MD, 7,628' ND WOB 2-20k ft.ibs. GPM 253 GPM at 1480 psi. RPM 40, Torque on 8k, torque off 6k ft.lbs. Flow out remained 14%. PU Wt. 181k SO Wt. 128k, rotating wt. 151 k, Actual rotating time .841firs /Actual Slide time 3.5hrs. /Actual Drilling time 4.34hrs. / Total Bit time - 4.34hrs. / Total Jar time - 9.59hrs. Page 28/56 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 I& Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Sten Depth Stag lune End Time our (hr) Phase Op Code Activity Code Time P -T -X Operatmn (flKB) EM Depth (flKB) 5/5/2019 5/5/2019 2.50 PROD2 DRILL CIRC T PU and circulated whilst reciprocating 13,711.0 13,610.0 19:00 21:30 from 13,711' to 13,610' MD. Racked back one stand and pumped 35 BBL Hi-Visc Sweep (Vis -150) at 3 bbls per min with 400 psi. Circulated sweep out at 250 GPM with 1530 psi. 40 RPM, torque 7k ft.lbs. Total strokes pumped 6,300. Flow checked well, well -static. 5/5/2019 5/6/2019 2.50 PROD2 DRILL TRIP T Tripped out of hole on elevators from 13,610.0 13,364.0 21:30 00:00 13,610' to 13,364' MD whilst bringing the BHA across the whip stock with pumps off and no rotating. Pulled at 15ft per min with 10k over pull and immediate fall off. Continued to pull inside csg to 12,638' MD. Obtained Slow Pump Rates and pumped 80 bbls of 10.1 dry job at 200 GPM with 1000 psi. Calibrated TOTCO block height simultaneously with Circulation. Blew down top drive. 5/6/2019 5/6/2019 6.00 PROD2 DRILL TRIP T Held Pre -Job Safety meeting. continue 13,364.0 1,528.0 00:00 06:00 to trip out of hole from 12,638' to 1,528' MD with 4" DP, racked back in derrick. Continued to monitor fluid displacement per pit 1. PU Wt. 172k SO Wt. 122k at 11,425' MD 5/6/2019 5/6/2019 1.00 PROD2 DRILL TRIP T Continued to trip out of hole from 1,528.0 387.0 06:00 07:00 1,528'to 387' MD, while monitoring fluid displacement, shut pumps in and observed well for flow. (Well Static) PU Wt. 51k SO Wt. 56k. 5/6/2019 5/6/2019 2.00 PROD2 DRILL BHAH T Held Pre -Job meeting. Laid down BHA 387.0 0.0 07:00 09:00 #9 from 387'to floor. Cleaned and clear drill floor removed strip automatic pick up BHA #10 and associated tools to rig floor. 5/6/2019 5/6/2019 0.50 PROD2 DRILL SVRG T Serviced Top drive, traveling blocks 0.0 0.0 09:00 09:30 and iron roughneck. Changed hose on iron roughneck. 5/6/2019 5/6/2019 1.50 PROD2 DRILL BHAH T Held Pre -job Safety meeting as per 0.0 340.0 09:30 11:00 SLB DD and pick and made up BHA #10. 5/6/2019 5/6/2019 1.00 PROD2 DRILL TRIP T Held Pre -Job Safety meeting and 340.0 2,237.0 11:00 12:00 tripped in hole from 340' to 2,237' MD with 4.0" DP PU Wt. 75k SO Wt. 80k. Monitor fluid displacement on pit 2 and ran Shallow hole test at 253 GPM and 1030 psi. 5/6/2019 5/6/2019 6.00 PROD2 DRILL TRIP T Continued to trip in hole from 2,237'to 2,237.0 11,937.0 12:00 18:00 11,937' MD with 4.0" DP / PU Wt. 125k, SO Wt. 125k, continue to monitor fluid displacement. 5/6/2019 5/6/2019 2.00 PROD2 DRILL TRIP T Continued to trip in hole from 11,937' 11,937.0 13,076.0 18:00 20:00 to 13,076' MD with 4.0" OF. PU Wt. 174k SO Wt. 127k while monitoring fluid displacement on pit 2, filling pipe every 20 stands. 5/6/2019 5/6/2019 1.50 PROD2 DRILL SVRG P Slip and cut drill line. Slipped 15 13,076.0 13,076.0 20:00 21:30 wraps, (118") and inspected dead man anchor brass for excessive wear. Performed derrick inspection. Greased -blocks, checked the crown-o-matic, calibrated Amphion hook sensor and blocks. Calibrated TOTCO block height at stand; 134 at 13,076' MD. Page 29166 Report Printed: 71212019 . Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log sent Depth Stan Time End lime Dur (hp Phase Op Cade Achviy Code Tima PJA Operation (MR) End Depth (W) 5/6/2019 5/6/2019 2.00 PROD2 DRILL SVRG T Inspected saver -sub, identified XT -39 13,076.0 13,076.0 21:30 23:30 thread damage and replaced. 5/6/2019 5/7/2019 0.50 PROD2 DRILL MPDA T Held Pre -Job Safety meeting with 13,076.0 13,076.0 23:30 00:00 MPD rep. Removed Trip nipple and installed RCD bearing 5/7/2019 5/7/2019 1.00 PROD2 DRILL MPDA T Complete install of RCD bearing and 13,076.0 13,076.0 00:00 01:00 calibrate chokes 5!7/2019 5/7/2019 2.25 PROD2 DRILL DISP T Displace well to 9.Oppg Flow Pro @ 13,076.0 13,266.0 01:00 03:15 240gpm. ICP 1615psi FCP 1450psi. Rotating 40rpm, 7k torque, recip pipe from 13,266 to 13,171 5/7/2019 5/7/2019 0.25 PROD2 DRILL OWFF T Monitor well via MPD for 10 min. Takle 13,266.0 13,312.0 03:15 03:30 slow pump rates 5/7/2019 5/7/2019 0.50 PROD2 DRILL DLOG T PJSM, rack back 1 std, log RA tag 13,312.0 13,164.0 03:30 04:00 from 13,124 to 13,164 pumping 230gpm, 1350psi SPP at 250fph 5/7/2019 5/7/2019 0.50 PROD2 DRILL TRIP T RIH, PU 182k, SO 125k, observed 5- 13,164.0 13,455.0 04:00 04:30 6k drag when BHA passing thru window 5/7/2019 5!7/2019 1.00 PROD2 DRILL TRIP T Questionable MU torque on MU of std 13,455.0 13,361.0 04:30 05:30 138, inspected saver sub and found gauled threads. LD single and double, BD top drive 5/7/2019 5/7/2019 2.00 PROD2 DRILL TRIP T PJSM and CO saver sub. Break in 13,361.0 13,361.0 05:30 07:30 saver sub and inspect. all good. 5/7/2019 5/7/2019 0.50 PROD2 DRILL TRIP T RIH w/4" DIP 13,361.0 13,554.0 07:30 08:00 5/7/2019 5/7/2019 1.50 PROD2 DRILL WASH T Wash and ream in hole, circulating 13,554.0 13,711.0 08:00 09:30 266gpm, 1970psi SPP, rotating 40rpm, 71k torque, ECD 9.82ppg 5/7/2019 5/7/2019 2.50 PROD2 DRILL DDRL P Drill 6.75' production hole, pumping 13,711.0 13,929.0 09:30 12:00 265gpm, SPP 1950 on bottom, 1940psi off bottom, 15k WOB, 120rpm, 7-9k torque, PU 175k, SO 124k, Rot 150k, ADT 1.72, Bit hrs 1.72, jar hrs 43.42 5/7/2019 5/7/2019 6.00 PROD2 DRILL DDRL P Drill 6.75' production hole, pumping 13,929.0 14,166.0 12:00 18:00 275gpm, SPP 2060psi on bottom, 2050psi off bottom, 15k WOB, 120rpm, 81k torque, PU 176k, SO 122k, Rot 151 k, ADT 4.75, Bit hrs 6.47, jar hrs 48.17 5/7/2019 5/8/2019 6.00 PROD2 DRILL DDRL P Drill 6.75' production hole, pumping 14,166.0 14,595.0 18:00 00:00 275gpm, SPP 2310psi on bottom, 2295psi off bottom, 15k WOB, 120rpm, 9k torque, PU 178k, SO 122k, Rot 151k, ADT 3.20, Bit hrs 9.67, jar hrs 51.37 5/8/2019 5/8/2019 6.00 PROD2 DRILL DDRL P Drill 6.75' production hole, pumping 14,595.0 15,172.0 00:00 06:00 2759pm, SPP 2330psi on bottom, 2275psi off bottom, 15k WOB, 110rpm, 11k torque, PU 176k, SO 122k, Rot 151 k, ADT 3.65, Bit hrs 13.32, jar hrs 55.02. Closing MPD choke on connections after pumps off. Observed increasing backpressure during connections from connection gas while choke dosed. Initiated MPD ramp to trap10.00ppg EMW during connections. Max gas 11,966 units Page 30166 Report Printed: 7/212019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time our (hr) Phase Op Cade Activity Code Tema P -T -X Operation (rtKB) End Depth(fiKB) 5/8/2019 5/8/2019 6.00 PROD2 DRILL DDRL P Drill 6.75" production hole, pumping 15,172.0 15,545.0 06:00 12:00 282gpm, SPP 2480psi on bottom, 2470psi off bottom, 17k WOB, 100rpm, 12k torque, PU 182k, SO 113k, Rot 148k, ADT 3.94, Bit hrs 17.26, jar hrs 58.96. Using MPD ramp during connections reduced but did not eliminate connection gas. Begin drilling while holding 28psi backpressure w/MPD. Max gas 7,742 units 5/8/2019 5/8/2019 6.00 PROD2 DRILL DDRL P Drill 6.75" production hole, pumping 15,545.0 16,082.0 12:00 18:00 280gpm, SPP 2550psi on bottom, 2540psi off bottom, 8-17k WOB, 100rpm, 11-131k torque, PU 183k, SO 112k, Rot 1481k, ADT 4.09, Bit hrs 21.35, jar hrs 63.05. Pumped 20bbl lo- vis/20 bbl hi -vis sweep at 15,830' MD. Holding 28-130psi backpressure while drilling. Max gas 8,580 units 5/8/2019 5/8/2019 4.25 PROD2 DRILL DDRL P Drill 6.75" production hole, pumping 16,082.0 16,379.0 18:00 22:15 277gpm, SPP 2480psi on bottom, 2540psi off bottom, 8-15k WOB, 100rpm, 11-12k torque, PU 182k, SO 113k, Rot 148k, ADT 3.06, Bit hrs 23.81, jar hrs 65.51. ECD=10.47ppg. Holding 100-130psi backpressure while drilling. Max gas 6,200 units. Background gas leveled off at about 6,000 units. 5/8/2019 5/9/2019 1.75 PROD2 DRILL DDRL P Drill 6.75" production hole, pumping 16,379.0 16,497.0 22:15 00:00 277gpm, SPP 2480psi on bottom, 2540psi off bottom, 8-15k WOB, 100rpm, 11-12k torque, PU 182k, SO 113k, Rot 148k, ADT .90, Bit hrs 25.31, jar hrs 67.01. ECD=10.47ppg. Holding 100-130psi backpressure while drilling. Max gas 6,200 units. Background gas leveled off at about 6,000 units. Preparing to increase mud weight from 9.1 to 9.5ppg. 5/9/2019 5/9/2019 6.00 PROD2 DRILL DDRL P Drill 6.75" production hole, pumping 16,497.0 16,825.0 00:00 06:00 275 gpm, SPP 2550 psi on bottom, 2475 psi off bottom, 12k WOB, 100 rpm, 12k torque, PU 182k, SO 113k, Rot 146k 8.5k torque, ADT 3.63, Bit hrs 28.94, jar hrs 70.64. ECD=10.29 ppg. Holding 75 psi backpressure while drilling. Max gas 9,600 units. avg background gas 5,800 units. Pumped 20 bbl lo-vis/20 bbl hi -vis sweep. Increasing mud weight from 9.1 to 9.4 ppg 5/9/2019 5/9/2019 6.00 PROD2 DRILL DDRL P Drill 6.75" production hole, pumping 16,825.0 17,350.0 06:00 12:00 261 gpm, SPP 2570 psi on bottom, 2570 psi off bottom, 15.5k WOB, 100 rpm, 12.7k torque, PU 188k, SO 106k, Rot 147k IOk torque, ADT 4.36, Bit hrs 33.3, jar hrs 75. ECD=10.83 ppg. Not holding backpressure while drilling. Max gas 4,800 units, avg background gas 4,000 units. Increasing mud weight from 9.4 to 9.5 ppg. Page 31156 Report Printed: 712/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Lop De Statl Depth Slab rime EM Time Dor (hr) Phase Op Cade tiY Acv Code rime P -T -X Operation In End Depth (XKB) 5/9/2019 5/9/2019 6.00 PROD2 DRILL DDRL P D6116.75" production hole, pumping 17,350.0 17,770.0 12:00 18:00 261 gpm, SPP 2440 psi on bottom, 2440 psi off bottom, 13-14k WOB, 100 rpm, 131k torque, PU 187k, SO 103k, Rot 147k 9k torque, ADT 3.7, Bit hrs 37, jar hrs 78.7. ECD=10.49 ppg. Not holding backpressure while drilling. Max gas 2,600 units. avg background gas 300 units. 550 bbl 9.5 ppg mud dilution @ 15:45. 5/9/2019 5/10/2019 6.00 PROD2 DRILL DDRL P Drill 6.75" production hole, pumping 17,770.0 18,057.0 18:00 00:00 261 gpm, SPP 2557 psi on bottom, 2535 psi off bottom, 12k WOB, 100 rpm, 12k torque, PU 196k, SO 91 k, Rot 146k 9.5k torque, ADT 4.03, Bit hrs 41.03, jar hrs 82.73. ECD=10.69 ppg. Holding 65 psi backpressure while drilling. Max gas 3,515 units. avg background gas 3200 units. 5/10/2019 5/10/2019 5.00 PROD2 DRILL DDRL P Drill 6.75" production hole, looking for 18,057.0 18,201.0 00:00 05:00 C -sand, pumping 273 gpm, SPP 2600 psi on bottom, 2590 psi off bottom, 7- 1Ok WOB, 100 rpm, 11-12k torque, PU 196k, SO 91 k, Rol 146k 9.5k torque, ADT xx, Bit hrs xx, jar hrs xx. ECD=10.698 ppg. Holding 75 psi backpressure while drilling and 390 on connections. Max gas 5,830 units. Pump 20 bbl lo-vis/20 bbl hi -vis sweep at 18,110' MD 5/10/2019 5/10/2019 0.50 PROD2 DRILL SVRG P Service top drive and blocks. Perform 18,201.0 18,201.0 05:00 05:30 derrick inspection. 5/10/2019 5/10/2019 0.50 PROD2 DRILL DDRL P Drill 6.75" production hole, looking for 18,201.0 18,245.0 05:30 06:00 C -sand, pumping 261 gpm, SPP 2600 psi on bottom, 2590 psi off bottom, 7- 1Ok WOB, 100 rpm, 12.51k torque, PU 207k, SO 91k, Rol 148k 10k torque, ADT 4.51, Bit hrs 45.54, jar hrs 87.24. ECD=10.72 ppg. Holding 75 psi backpressure while drilling and 390 psi on connections. Max gas 6,263 units. avg background gas 3200 units. 5/10/2019 5/10/2019 2.50 PROD2 DRILL CIRC T Rack back std. CBU at 262 gpm, 2660 18,245.0 18,110.0 06:00 08:30 psi SPP, rotating 60 rpm, 10k torque, recip pipe full stand. Discussing plan forward with town. 5/10/2019 5/10/2019 0.75 PROD2 DRILL MPDA T Fingerprint well using MPD at 18,176' 18,110.0 18,176.0 08:30 09:15 MD rotating 5 rpm, 10k torque, Close choke 3 min, open 10 sec. Initial SIP 390 psi and 190 psi after 6 cycles. Shut in for pressure build up 15 min, 390 psi. 5/10/2019 5/10/2019 2.00 PROD2 DRILL CIRC T CBU at 262 gpm, 2660 psi SPP, rotate 18,176.0 18,110.0 09:15 11:15 60 rpm, 101k torque, recip pipe, max gas 11839 units 5/10/2019 5/10/2019 0.25 PROD2 DRILL OWFF T Shut in and monitor well with 390 psi 18,110.0 18,110.0 11:15 11:30 trapped pressure. 5/10/2019 5/10/2019 6.50 PROD2 DRILL BKRM T BROOH pumping 261 gpm, 2760 psi, 18,110.0 17,353.0 11:30 18:00 rotating 60 rpm, 10-17k torque. Maintain 590-535 psi backpressure pumps off and 190-150 psi pumps on. PU 203k, SO 80k, Rotating 140k, 11k torque. Weighting up from 9.5 ppg to 9.8 ppg Page 32/56 ReportPrinted: 7/2/2019 . Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cotle TIM P -T -X Operation (rt K8) End Depth (fiKB) 5/10/2019 5/10/2019 2.50 PROD2 DRILL BKRM T BROOH pumping 261 gpm, 2760 psi, 17,353.0 16,800.0 18:00 2030 rotating 60 rpm, 10-17k torque. Maintain 590-535 psi backpressure pumps off and 190-150 psi pumps on. PU 201k, SO 78k, Rotating 138k, 11k torque. 5/10/2019 5/1112019 3.50 PROD2 DRILL SMPD T Strip Out Of Hole, holding 16,800.0 15,200.0 20:30 00:00 backpressure w/injection pump, 520 psi out of slips and 400 psi in slips. PU 195k, SO 100k. Pull tight, 30k over and packing off at 16,152. Backream thru section then pulled clean. 5/11/2019 5/11/2019 3.00 PROD2 DRILL SMPD T Strip Out Of Hole, holding 15,200.0 13,570.0 00:00 03:00 backpressure w/injection pump, 520 psi out of slips and 400 psi in slips. PU 190k, SO 110k. 5111/2019 5/11/2019 3.00 PROD2 DRILL SMPD T Strip Out Of Hole, holding 13,570.0 13,450.0 03:00 06:00 backpressure w/injection pump. Oberseved 30k overpull at 13,562' MD, 16 degree doglegs, BHA just outside window. Attempted to work thru. RIH 2 skis, rotate, recap and circulate 60 rpm, 60 spm, 71 torque, PU 146k, SO 140k. Rotate thru tight section at 40 rpm 5/11/2019 5/11/2019 1.00 PROD2 DRILL SMPD T Strip Out Of Hole, observe IOk drag 13,450.0 13,261.0 06:00 07:00 as BHA pulled third window, holding backpressure vi/injection pump, 520 psi out of slips and 400 psi in slips. PU 183k, SO 121 k. 5/1112019 5/11/2019 3.00 PROD2 DRILL DISP T PJSM, displace cased hole to 11.0 13,261.0 13,261.0 07:00 10:00 ppg NaBr brine at 210 gpm rotating 40rpm, 61k torque, rotating wt 150k PU 174k SO 127k, ICP 1620 psi, FCP 1410 psi 5/11/2019 5/11/2019 0.75 PROD2 DRILL OWFF T Monitor well via MPD for 10 minutes, 13,261.0 13,621.0 10:00 10:45 pressure build from 6 psi to 10 psi. Monitor well at RCD for 30 min, static. SIMOPS BO TP, service TO and blocks, inspect saver sub 5/11/2019 5/11/2019 8.75 PRO02 DRILL SMPD T PJSM, Strip Out Of Hole, holding 13,621.0 600.0 10:45 19:30 backpressure wlinjection pump, 120 psi out of slips and 40 psi in slips. PU 55k, SO 55k. 5/1112019 5/11/2019 0.50 PROD2 DRILL OWFF T Monitor well, static 600.0 600.0 19:30 20:00 5/11/2019 5/11/2019 2.00 PROD2 DRILL MPDA T Pull RCD, install trip nipple. 600.0 600.0 20:00 22:00 5/11/2019 5/12/2019 2.00 PROD2 DRILL BHAH T Handle BHA, rack back HWDP &jars, 600.0 0.0 22:00 00:00 LD smart tools 5/12/2019 5/12/2019 2.00 PROD2 WHDSOP RURD P Drain stack, pull wear ring, make up 0.0 0.0 00:00 02:00 stack washer and wash stack. Blow down top drive 5112/2019 5112/2019 2.00 PROD2 WHDBOP BOPS P Drain stack and set test plug, monitor 0.0 0.0 02:00 04:00 well via annulus valve in cellar. masks up floor valve to dart valve, make up head pin, fill lines, stack and choke manifold with water. Shell test to 2500 psi, good test Page 33/56 ReportPrinted: 71212019 r Operations Summary (with Timelog bepths) 4, CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Op Code Activit' Code Time P-T-x Operation Btan Depth (ffKB) End Depth (f l,a) 5/12/2019 5/12/2019 5.00 PROD2 WHDBOP BOPE P Test BOPS 250 psi low, 3500 psi high. 0.0 0.0 04:00 09:00 Charted each for 5 min. Chokes tested to 1500 psi. Annular 250 psi and 2500 psi. Test with 4" & 4.5" test joints. Upper and lower 2-7/8" x 5-1/2" VBRs, 4" Floor and dart valves. Upper and lower IBOPs. Perform Koomey draw down test. Tests witnessed by AOGCC Adam Earl. 5/12/2019 5/12/2019 1.00 PROD2 WHDBOP RURD P Rig down test equipment, blow down 0.0 0.0 09:00 10:00 lines, pull test plug and run wear bushing. 5/12/2019 5/12/2019 2.00 PROD2 DRILL BHAH T PJSM, PU & MU BHA#11, motor kick 0.0 295.0 10:00 1200 off assembly, PU 50k SO 54k 5/12/2019 5/12/2019 7.50 PROD2 DRILL TRIP T PJSM, RIH, fill every 20 stands, 295.0 13,330.0 12:00 1930 monitor displacement on pit 2, shallow pulse test at 2000' MD pumping 250 gpm, 1170 psi. PU 153k SO 113k 5/12/2019 5/12/2019 1.00 PROD2 DRILL MPDA T Pull trip nipple and install RCD 13,330.0 13,330.0 19:30 20:30 bearing. Prep for displacement 5/12/2019 5/12/2019 2.50 PROD2 DRILL DISP T Displace 11.0 ppg brine from cased 13,330.0 13,330.0 20:30 2300 hole with 9.9 ppg Flo pro, reciping pipe, pumping 220 gpm rotating 20 rpm 7k torque 1500-1900 psi. PU 148k SO 133k 5/12/2019 5/13/2019 1.00 PROD2 DRILL SMPD T Orient motor for trip thru window PU 13,330.0 13,330.0 23:00 00:00 173k SO 123k 5/13/2019 5/13/2019 3.50 PROD2 DRILL SMPD T Continue to strip in hole monitoring 13,330.0 16,300.0 00:00 03:30 displacement via pit 2, fill every 20 IS S. PU 190k SO 105k 5/13/2019 5/13/2019 0.50 PROD2 DRILL KOST T Break circulation and orient 180 down 16,300.0 16,300.0 03:30 04:00 for kick off 5/13/2019 5/13/2019 2.00 PROD2 DRILL KOST T Begin troughing to kick off sidetrack. 16,300.0 16,380.0 04:00 06:00 Pumping 250 gpm,2200-2400 psi 5/13/2019 5/13/2019 6.00 PROD2 DRILL DDRL T Drilling sidetrack (time drilling) w/MPD 16,380.0 16,406.0 06:00 12:00 pumping 250 gpm, 2300 psi on bottom, 2200 psi off, 2-20k WOB. Holding 15 psi backpressure with pumps on and 400 psi pumps off. PU 190k SO 105k, Max Gas 402 units. ADT 4.21, Bit Hrs 4.21, Jar Hrs 91.45 5/13/2019 5/13/2019 6.00 PROD2 DRILL DDRL T Drilling sidetrack w/MPD pumping 253 16,406.0 16,494.0 12:00 18:00 gpm, 2500 psi on bottom, 2250 psi off, 8k WOB, 40 rpm. Holding 15 psi backpressure with pumps on and 400 psi pumps off. PU 192k SO 113k, Rot 149k, Torque 10k, Max Gas 253 units. ADT 4.54, Bit Hrs 8.75, Jar Hrs 95.99 ART .41 AST 4.13 5/13/2019 5/14/2019 6.00 PROD2 DRILL DDRL T Drilling sidetrack w/MPD pumping 250 16,494.0 16,590.0 18:00 00:00 gpm, 2550 psi on bottom, 2500 psi off, 12k WOB, 40 rpm. Holding 15 psi backpressure with pumps on and 400 psi pumps off. PU 191k SO 105k, Rot 141k, Torque 10k, Max Gas 1170 units. ADT 2.89, Bit Hrs 11.64, Jar Hrs 98.88, ART 0.34, AST 2.55 5/14/2019 5/14/2019 2.50 PROD2 DRILL DDRL T Drilling sidetrack w/MPD pumping 252 16,590.0 16,638.0 00:00 02:30 gpm, 2550 psi, 8k WOB, 40 rpm. PU 191k SO 105k, Rot 141k, Torque 10k, Max Gas 1725 units. ADT 1.53, Bit Hrs 13.17, Jar Hrs 100.41, ART 0.54, AST 0.99 Page 34/56 Report Printed: 7/2/2019 Uperations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log I Start CPN rt De StartTime End Time our (hr) Phase OP Code Ac dy Code Time P -T -X OParatlon End dePM (flXB) 5/14/2019 5/14/2019 1.50 PROD2 DRILL CIRC T CBU while rotating & reciprocating @ 16,638.0 16,638.0 02:30 04:00 253 gpm, 40 rpm, 2350 psi, 8k torque, max gas 2275 units 5/14/2019 5/14/2019 0.50 PROD2 DRILL SRW T Take survey on bottom 16,638.0 16,638.0 04:00 04:30 5/14/2019 5/14/2019 5.00 PROD2 DRILL SMPD T SOOH @ 1250 fph holding 560 psi 16,638.0 13,315.0 04:30 09:30 backpressure out pof slips and 420 in slips. PU 180k, SO 116k. Orient motor 47L to pull BHA thru window. Observed 7k drag. 5/14/2019 5/14/2019 1.00 PROD2 DRILL CIRC T CBU while rotating & reciprocating @ 13,315.0 13,315.0 09:30 10:30 247 gpm, 30 rpm, 2040 psi, 6k torque, max gas 2108 units. SIMOPS PJSM on Displacement 5/14/2019 5/14/2019 2.00 PROD2 DRILL CIRC T Displace cased hole to 11.0 ppg NaBr 13,315.0 13,315.0 10:30 12:30 brine at 249 gpm, 2040 psi, rotating 30rpm, 6k torque, max gas 211 units 5/14/2019 5/14/2019 0.75 PROD2 DRILL OWFF T Monitor well via MPD for 15 minutes, 13,315.0 13,315.0 12:30 13:15 pressure build from 8 psi to 16 psi. Monitor well at RCD for 30 min, static. SIMOPS BD TD, service TO 5/14/2019 5/14/2019 7.25 PROD2 DRILL SMPD T SOOH @ 1250 fph holding 130 psi 13,315.0 900.0 13:15 20:30 backpressure out pof slips and 40 in slips. PU xxk, SO xxk. 5/14/2019 5/14/2019 1.00 PROD2 DRILL MPDA T Monitor well then pull RCD bearing 900.0 900.0 20:30 21:30 and install trip nipple 5/14/2019 5/14/2019 0.50 PROD2 DRILL TRIP T POOH last 8 aids DP 900.0 295.0 21:30 22:00 5/14/2019 5/14/2019 1.50 PROD2 DRILL BHAH T Handle / LD BHA 295.0 0.0 22:00 23:30 5/14/2019 5/15/2019 0.50 PROD2 DRILL SLPC T Slip 400; drilling line 0.0 0.0 23:30 00:00 5/15/2019 5/152019 1.00 PROD2 DRILL SLPC T Slip & Cut drilling line 0.0 0.0 00:00 01:00 5/15/2019 5/15/2019 0.50 PROD2 DRILL SVRG T Service top drive, blocks and crown 0.0 0.0 01:00 01:30 5/152019 5/15/2019 1.00 PROD2 DRILL BHAH T Uploading MWD tools 0.0 0.0 01:30 02:30 5/152019 5/15/2019 0.50 PROD2 DRILL MPDA T Makeup RCD bearing onto 10' DP pup 0.0 0.0 02:30 03:00 5/15/2019 5/15/2019 3.00 PROD2 DRILL BHAH T Make up RSS BHA#12 0.0 341.0 03:00 06:00 5/15/2019 5/15/2019 7.50 PROD2 DRILL TRIP T TIH on 4" DP. PU 177k, SO 130k. 341.0 13,076.0 06:00 13:30 Filling pipe every 20 stds. 5/15/2019 5/152019 1.00 PROD2 DRILL DLOG T Log RA tag at 13,166' MD pumping 13,076.0 13,171.0 13:30 14:30 250 gpm, 1720 psi, running in at 250 fph 5/15/2019 5/152019 1.00 PROD2 DRILL MPDA T Pull trip nipple and run RCD bearing 13,171.0 13,171.0 14:30 15:30 5/152019 5/15/2019 2.50 PROD2 DRILL CIRC T PJSM, Displace cased hole to 9.9 ppg 13,171.0 13,171.0 15:30 18:00 Flo -Pro pumping 250 gpm, rotating 40 rpm, 6k torque while maintaining 10.7 ppg EMW w/MPD. ICP 2000 psi, FCP 1850 psi. PU 176k, SO 109k, Rotating 152k, 6k torque. 5/15/2019 5/15/2019 2.50 PROD2 DRILL SMPD T Strip in hole on MPD holding 200 psi 13,171.0 16,350.0 16:00 20:30 backpressure out of slips and 400 psi in slips. 5/152019 5/15/2019 2.50 PROD2 DRILL REAM T Fill pipe,line up on Poor Boy degasser, 16,350.0 16,621.0 20:30 23:00 wash and ream down taking surveys along sidetrack. Pumping 250 gpm, 2100 psi SPP. Page 36156 ReportPrinted: 7/2/2019 thl Operations Summary (with Timelog Depths) Adbufrf C D5-24 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 (flKB) End Depth (flKB) 5/15/2019 5/16/2019 1.00 PROD2 DRILL DDRL T Drilling C-sand w/MPD pumping 251 16,621.0 16,714.0 23:00 00:00 gpm, 2150 psi SPP, rotating 100 rpm, 14k WOB, 10k torque. PU 181k, SO 105k, Rotating 148k torque 9k, ECD 10.9 ppg, Max gas 1250 units. ADT .73, Bit hrs .73 Jar hrs 101.4 5/16/2019 5/16/2019 0.50 PROD2 DRILL DDRL T Lost backpressure while making a 16,714.0 16,779.0 00:00 00:30 connection. kicked on injection pump at 42 gpm to pump across top of well thru MPD chokes. Floats not holding, mud was circulated up drillstring and out the stump. Quickly made connection and drilled stand down while discussing options. Drilled at 253 gpm, 2250 psi, 100 rpm 9k WOB, 12k torque. PU 191 k, SO 105k, Rotating 148k, torque 8k, ECD 10.97, Max gas 1345 units. 5/16/2019 5/16/2019 1.00 PROD2 DRILL CIRC T CBU and begin troubleshooting floats. 16,779.0 16,779.0 00:30 01:30 Trap pressure with MPD and cycle SPP bleeder and observed pressure build up up in drill string. 5/16/2019 5/16/2019 2.00 PROD2 DRILL CIRC T Troubleshooting floats. Recip drill 16,779.0 16,779.0 01:30 03:30 string, lowering string as fast as possible and stopping as fast as Amphion controls allow, trap pressure in well and cycle SPP bleeder, floats holding. Open MPD choke and pump at drilling rate. Trap pressure and cycle bleeder, floats not holding. Repeat recip and pumping, floats held. Pump to-vis / hi-vis sweep and test floats after sweep in open hole, floats holding. 5/16/2019 5/16/2019 2.50 PROD2 DRILL DDRL T Resume drilling w/MPD at 253 gpm, 16,779.0 16,969.0 03:30 06:00 2240 psi, 100 rpm 12k WOB, 13k torque. PU 181k, SO 105k, Rotating 148k, torque 8k, ECD 10.98, Max gas 799 units. ADT 2.62, Bit Hrs 3.35, Jar Hrs 103.76 5/16/2019 5/16/2019 6.00 PROD2 DRILL DDRL T Drilling w/MPD at 248 gpm, 2170 psi, 16,969.0 17,444.0 06:00 12:00 100 rpm 12-17k WOB, 11-13k torque. PU 181 k, SO 110k, Rotating 146k, torque 9k, ECD 10.87, Max gas 2327 units. ADT 3.52, Bit His 6.87, Jar His 107.28 5/16/2019 5/16/2019 6.00 PROD2 DRILL DDRL T Drilling w/MPD at 261 gpm, 2250 psi, 17,444.0 17,822.0 12:00 18:00 75 rpm 0-14k WOB, 11-1 A torque. PU 186k, SO 107k, Rotating 145k, torque 9k, ECD 10.92, Max gas 1019 units. ADT 4.45, Bit Hrs 11.32, Jar His 111.73 5/16/2019 5/17/2019 6.00 PROD2 DRILL DDRL T Drilling w/MPD at 253 gpm, 2501 psi, 17,822.0 18,280.0 18:00 00:00 100 rpm 0-14k WOB, 13-14k torque. PU 188k, SO 103k, Rotating 145k, torque 10.5k, ECD 11.0, Max gas 1427 units. ADT 4.31, Bit Hrs 15.63, Jar Hrs 116.04 5/17/2019 5/17/2019 6.00 PROD2 DRILL DDRL P Drilling w/MPD at 250 gpm, 2706 psi, 18,280.0 18,870.0 00:00 06:00 100 rpm 0-14k WOB, 15k torque. PU 189k, SO 96k, Rotating 136k, torque 9k, ECD 11.27, Max gas 1938 units. ADT 4.32, Bit Hrs 19.95, Jar Hrs 102.36 Page 36/56 ReportPrinted: 7/2/2019 Operations Summary (with Timelog Depths) C D5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation Stag Depth (WS) EM DBPM(WS) 5/17/2019 5/17/2019 2.50 PROD2 DRILL DDRL P Drilling w/MPD while troubleshooting 18,870.0 19,061.0 06:00 08:30 MWD Observed pressure spike when flow was increased to 265 gpm. SPP was erratic afterwards. Pumping at 250-265 gpm, 2706 psi, 100 rpm 0- 14k WOB 14k torque. PU 191 k, SO 93k, Rotating 138k, torque 10k, ECD 11.38, Max gas 7086 units. ADT 1.53, Bit Hrs 21.48, Jar Him 120.36 5/17/2019 5/17/2019 3.50 PROD2 DRILL CIRC T Pump 20 bbl to -vis sweep while 19,061.0 19,061.0 08:30 1200 rotating and reciprocating pipe at 120- 265 gpm, 1000-2706 psi, 5-60 rpm, 10 -14k torque, PU 191k, SO 93k, Rotating 138k, 10k torque. ECD 11.38, max gas 4962. Circulated 7564 stks 5/17/2019 5/17/2019 1.00 PROD2 DRILL SIPS T Determine pore pressure (fingerprint) 19,061.0 19,061.0 12:00 13:00 using MPD. Trap pressure with MPD and follow MPD Drawdown Procedure. Pore pressure still in 10.5 ppg EMW range. Gained 3 bbls 5/17/2019 5/17/2019 1.00 PROD2 DRILL DDRL T Continue troubleshooting MWD, 19,061.0 19,075.0 13:00 - 14:00 staging pumps 120-675 gpm, pump lo- vs/hi-vis sweep while attempting to drill ahead, ADT 0.25, Bit Hrs 21.73, Jar Hrs 120.36 5/17/2019 5/17/2019 1.75 PROD2 DRILL DDRL T Rack back 1 stand and circulate 1 19,075.0 19,060.0 14:00 15:45 hole volume, take SPRs, send downlink to put powerddve in neutral position. Pumping at 265 gpm, 2706 psi, 30 rpm 10-14k, torque. PU 191 k, SO 93k, Rotating 138k, torque 10k, ECD 11.38, Max gas 7086 units. Circulated 5566 stks 5/17/2019 5/17/2019 3.00 PROD2 DRILL SMPD T SOOH w/MPD at 1000 fph, holding 19,075.0 17,700.0 15:45 18:45 backpressure using injection pump, 400 psi in slips, 500 psi out. PU 198k, SO 102k, 5/17/2019 5/17/2019 0.75 PROD2 DRILL REAM T Encountered tight hole at 17,700' MD, 17,700.0 17,700.0 18:45 19:30 WEPS reamer at 1st fault. 30k overpull & packing off. Work pipe thru rotating and circulating as hole allowed. 5/17/2019 4.50 PROD2 DRILL SMPD T Continue to SOOH w/MPD at 1000- 17,700.0 13,820.0 15118/2019 19:30 00:00 2000 fph, holding backpressure using injection pump, 560 psi in slips, 440 psi out. PU 185k, SO 101k, 5/18/2019 5/18/2019 1.00 PROD2 DRILL SMPD T Continue to SOOH per schedule 13,820.0 13,260.0 00:00 01:00 maintaining 500 psi backpressure in slips and 440 psi out using injection pump.Pulled tight and 30k over at 13562' MD, BHA across window. Pump at 40 spm, 1205 psi, hosting 20 rpm. Observed 10k overpull as BHA came thm windo. Shut down pumps and rotaity and continued pulling. Pulled 25k over at 13,507' MD. Continued pulling w/o pumps or rotary. PU 180k, SO 91k. 5/18/2019 5/18/2019 2.50 PROD2 DRILL CIRC T CBU rotating and reciprocating pipe. 13,260.0 13,260.0 01:00 03:30 Pumping 210-253 gpm, 1260-2300 psi, 5-6k torque. 5/18/2019 5/18/2019 3.00 PROD2 DRILL CIRC T Displace rased hole to 10.95 ppg KW 13,260.0 13,148.0 03:30 06:30 brine. Pumping 210 gpm, 1100-1600 psi, 5-6k torque Page 37156 ReportPrinted: 7/2/2019 Operations Summary (with Timelog Depths) r CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Stan Depth rt De start Tire End Time Dur (hr) Phase O Code Op Ac vi Code ry Time P -T- X Opereiin End Depth (nKa) 511812019 5/18/2019 1.00 PROD2 DRILL OWFF T Close MPD chokes and verify no 13,148.0 13,148.0 06:30 07:30 1 pressure, well static 5/18/2019 5/1812019 8.50 PROD2 DRILL SMPD T SOOH @ 5000-10,000 fph per 13,148.0 1,000.0 07:30 16:00 schedule. Holding 40 psi backpressure w/MPD in slips and 120 psi out. PU 80k, SO 68k. 5/18/2019 5118/2019 0.75 PROD2 DRILL OWFF T Monitor well - static 1,000.0 1,000.0 16:00 16:45 5/18/2019 5/1812019 0.75 PROD2 DRILL MPDA T PU 15' DP pup and RIH to retrieve 1,000.0 1,000.0 16:45 17:30 RCD element, lay pup out of drill Floor w/RCD. Install trip nipple. 5/18/2019 5/18/2019 1.50 PROD2 DRILL SHAH T LD BHA per Schlumberger. 1,000.0 0.0 17:30 19:00 33 bbls fluid lost to hole during trip out. 5118/2019 5118/2019 1.50 PROD2 DRILL SLPC T PJSM, Slip and cut 71' drilling line. 0.0 0.0 19:00 20:30 5/18/2019 5118/2019 0.50 PROD2 DRILL SVRG T Service top drive, blocks and crown. 0.0 0.0 20:30 21:00 1 1 calibrate COM. 5/18/2019 5/18/2019 0.50 PROD2 DRILL SHAH T Load, stage and prep MWD tools. 0.0 0.0 21:00 21:30 SIMOPS PM on rotary table and PJSM - PU BHA 5/18/2019 5/19/2019 2.50 PROD2 DRILL BHAH T MU BHA#13 per Schlumberger 0.0 400.0 21:30 00:00 5119/2019 5/19/2019 8.00 PROD2 DRILL TRIP T TIH filling pipe every 20 stds, shallow 400.0 13,258.0 00:00 08:00 pulse test MWD at 2140' MD, log RA tag at 13,105' MD PU 145k, SO 115k 5/19/2019 5/19/2019 0.75 PROD2 DRILL MPDA T Pull trip nipple and install MPD/RCD 13,258.0 13,258.0 08:00 08:45 1 1 bearing & element 5/192019 5/19/2019 3.25 PROD2 DRILL CIRC T PJSM, Displace cased hole to 9.9 ppg 13,258.0 13,258.0 08:45 12:00 Flo -Pro, rotating and reciprcating pipe, pumping 210 gpm, 1650 psi SPP, 30 rpm, PU 176k, SO 121k, Rotating 151k, torque 7k. Commissioning NOVOS with NOV tech. 8493 stks pumped. 5/19/2019 5/192019 3.25 PROD2 DRILL SMPD T Strip in hole w/MPD holding 440 psi in 13,258.0 17,680.0 12:00 15:15 slips and 220 psi out. Filling pipe every 20 skis. PU 189k, SO 104k 5/19/2019 5/19/2019 1.25 PROD2 DRILL SMPD T Encounterd tight spots, establish 17,680.0 17,515.0 15:15 16:30 reaming, 3-5 bpm pressure spikesf at 17,680 - 17,700, the 3rd of 4 faults to cross. Wash and ream hole, pressure increasing and ECD's increasing, reduce flow rate, rack back 2 stands, above 1st fault to clean hole. pump 3 bpm, 1350-1400 psi, 30-60 rpm. 5/19/2019 5/19/2019 2.00 PROD2 DRILL CIRC T CBU divert returns to gas buster after 17,515.0 17,515.0 16:30 18:30 seeing 10,000 units gas, rotating, reciprocating pipe. Pumping 3 bpm, 1100 psi, 30 rpm, rotating wt 124k, torque 10k, 6200 stks. 5/19/2019 5/20/2019 5.50 PROD2 DRILL REAM T Work BHA thru faults at 17,513, 17,515.0 18,700.0 18:30 00:00 17,648, 17680 & 17,819' MD. Vary rotary, 10-60 rpm, and pump rates, 3-6 bpm, as needed to work in hole. SPP 980-2350, torque 6-15k (torque limit). 5/20/2019 520/2019 1.50 PROD2 DRILL REAM Wash and ream to bottom pumping 3- 18,700.0 19,075.0 00:00 01:30 I 6 bpm, 980-2350 psi, rotating 10-60 rpm, 6-13k torque Page 38/56 Report Printed: 7212019 Uperations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log sten Depth Start Time End Time our (hr) Phase op COAs Acfivdy Code Time P-T-x Operation (IIKB) End Depth(ftKB) 5/20/2019 5/20/2019 4.50 PROD2 DRILL DDRL P Resume drilling. Pumping 253 gpm, 19,075.0 19,562.0 01:30 06:00 2450 psi SPP, rotating 100 rpm, 13k WOB, 15k-17k torque. PU 195k, SO 94k, Rotating wt 143k, torque 10k, ECD 11. 18, max gas 897 units. Maintain 460 psi backpressure with MPD pumps off. ADT 3.27, Bit Hrs 3.27, Jar Hrs 125.41 5/20/2019 5/20/2019 6.00 PROD2 DRILL DDRL P Drilling and commissioning NOVOS. 19,562.0 20,294.0 06:00 12:00 Pumping 253 gpm, 2550 psi SPP, rotating 100 rpm, 13k WOB, 15k-17k torque. PU 199k, SO 95k, Rotating wt 150k, torque 10k, ECD 11.30, max gas 1834 units. Maintain 460 psi backpressure with MPD pumps off. ADT 4.03, Bit Hrs 7.3, Jar Hrs 129.44 5/20/2019 5/20/2019 6.00 PROD2 DRILL DDRL P Drilling ahead. Pumping 265 gpm, 20,294.0 20,655.0 12:00 18:00 2726 psi SPP, rotating 100 rpm, 9k WOB, 15k-17k torque. PU 199k, SO 95k, Rotating wt 150k, torque 14k, ECD 11. 16, max gas 636 units. Maintain 460 psi backpressure with MPD pumps off. ADT 4.69, Bit Hrs 11.99, Jar Hrs 134.13 5/20/2019 5/21/2019 6.00 PROD2 DRILL DDRL P Drilling ahead. Pumping 261 gpm, 20,655.0 21,152.0 18:00 00:00 2768 psi SPP, rotating 100 rpm, 11k WOB, 16k-18kk torque. PU 205k, SO 86k, Rotating wt 147k, torque 11.5k, ECD 11.16, max gas 1224 units. Maintain 460 psi backpressure with MPD pumps off. ADT 4.51, Bit Hrs 16.5, Jar Hrs 138.64 5/21/2019 5/21/2019 6.00 PROD2 DRILL DDRL P Continue to drill 6.75" production hole 21,152.0 21,533.0 00:00 0600 with MPD from 21,152'to 21,533' MD, TVD 7,635'. Weight on bit 14k with 260 gpm at 2,505 psi. Rotating at 75 rpm with 17k ft/lbs. Pick up weight- 205k, slack-off weight 86k, off bottom rotating weight 147k at 11.5k ft/lbs. ECD 11.19 ppg max gas 667 units. MPD back pressure with pumps off 460 psi. Actual Drilling Time-4.6 hrs., Bit hours — 21.10, Jar hours —143.24. 5/21/2019 5/21/2019 6.00 PROD2 DRILL DDRL P Continue to drill 6.75" production hole 21,533.0 21,846.0 06:00 12:00 with MPD from 21,533'to 21,846' MD, TVD 7,638'. Weight on bit 14k with 265 gpm at 2,915 psi. Rotating at 75 rpm with 13k Mbs. Pick up weight — 201 k, slack off weight 84k, off bottom rotating weight 146k at 11.5k ft/lbs. ECD 11.19 ppg, max gas 700 units. MPD back pressure with pumps off 460 psi. Actual Drilling time — 4.4 hours, Bit hours-25.5, Jar hours- 147.64. Pumped anti-jamming sweep @ 21,820' MD. 5/21/2019 5/21/2019 6.00 PROD2 DRILL DDRL P Continue to drill 6.75" production hole 21,846.0 22,112.0 12:00 18:00 with MPD from 21,846'to 22,112' MD, TVD 7,645'. Weight on bit 14k with 265 gpm at 2,815 psi. Rotating at 100 rpm with 13k ft/lbs. Pick up weight — 210k, off bottom rotating weight 146k at 11.5k Mbs. ECD 11.15 ppg, max gas 667 units. MPD back pressure with pumps off 460 psi. Actual Drilling time — 4.9 hours, Bit hours — 30.4, Jar hours — 152.54. Page 39156 Report Printed: 7/212019 Uperations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Acvvity Cade Time P -T -X OperaYon Start Depth (ftKB) End Depth (ftKB) 5/21/2019 5/22/2019 6.00 PROD2 DRILL DDRL P Continue to drill as directed from 22,112.0 22,255.0 18:00 0000 22,112'to 22,255' MD. TVD 7,649'. Weight on bit 9k with 269 gpm at 3060 psi. Rotating at 90 rpm with 15-16k flU bs. Pick up weight 210k and slack off weight N/A. Off bottom weight and rotating torque, 1471k at 11.5 ft/lbs. ECD 11.1 ppg, max gas 5012 units. MPD back pressure with pumps off 460 psi. Actual drilling time 5.49 Inns. Bit hours 35.89, Jar hours 158.03. Pumped Anti -Jamming Sweep, 22,165' MD. 5/22/2019 5/22/2019 3.00 PROD2 DRILL DDRL P Continue to drill production hole with 22,255.0 23,310.0 00:00 0300 MPD from 22,255'to 22,310' MD. TVD was surveyed at 7,653'. Weight on bit 10k with 262 gpm at 2,901 psi. Rotating at 90 rpm with 12k fUlbs. Pick up weight — 212k, slack off weight N/A -0. Off bottom rotating weight 1471k at 11.5k ft/lbs. ECD remained at 11.19 ppg, max gas 5012 units. MPD back pressure with pumps off 460 psi. Actual Drilling time — 2.83 hours, Bit hours — 38 72, Jar hours — 160.86. 5/22/2019 5/22/2019 2.00 PROD2 CASING CIRC P 241-1 TD was determined at 22,310'. 22,290.0 22,210.0 03:00 05:00 Racked back one stand and began to circulate from 22,290'to 22,210' MD while rotating and reciprocating at 60 rpm and 12k ft/lbs., at 64 strokes per minute and 270 gpm with 3,010 psi. ECD remained at 11.11 ppg flow out was at 26%. Pick up weight was 150k while rotating and slack -off weight was 144k. Total strokes pumped 5,190. 5/22/2019 5/22/2019 1.00 PROD2 CASING BKRM P Back reamed out of hole from 22,210' 22,210.0 22,010.0 05:00 0600 to 22,010 MD. Rotating at 35 rpm at 11-12kft/lbs. /lbs. with 270 gpm, and 3,045 psi. ECD was 11.13 ppg and the Max gas was 236 units. Flow out was recorded at 27% with a slack off weight of 268k. Began circulation bottoms up, total strokes pumped 2100. 5/22/2019 5/22/2019 3.50 PROD2 CASING CIRC P Circulated bottoms up twice (2X) while 22,096.0 22,007.0 06:00 0930 rotting and reciprocating from 22,096' to 22,007' MD with 270 gpm and 2,995 psi. Flow out recorded at 26% with 35- 60 rpm. Torque at 11k fUlbs. rotating weight was recorded at 150k rotating torque is Ilk ft/lbs. total stroke Pumped 13,887. 5/22/2019 5/22/2019 1.50 PROD2 CASING BKRM P Efforts were made to strip out of hole 22,007.0 21,732.0 09:30 11:00 with MD from 22,007'to 21,723' MD. As per the stripping schedule, pulling 1000' feet per hour while holding 640 psi on backside. Experienced tight hole conditions at 21,705' MD with 20k over -pull. Made up top drive and backed reamed 2 stands out of hole at 40 rpm and 265 gpm with 2,885 psi. Rotating weight was 145k, pick up weight was 157k while monitoring displacement into pits 3 and 4. Dropped the 1.93" drift in stand # 227. Page 40156 Report Printed: 712/2019 Operations Summary (with Timelog Depths) CDS-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Star) Depth (ftKB) End Depth (ftKB) 5/22/2019 5/22/2019 1.00 PROD2 CASING SMPD P Continued to strip out of hole from 21,532.0 20,960.0 1100 1200 21,532'to 20,960' MD at 1000' ft per minute per schedule while maintaining 640 psi out of slips, and 460 psi in slips. Pick up weight was 205k and slack off weight 85k while monitoring fluid displacement in pit 3 and 4. total losses for 12hrs were 15 bbls. 5/22/2019 5/22/2019 1.00 PROD2 CASING SMPD P Continued to strip out of hole from 20,960.0 20,527.0 12:00 13:00 20,960'to 20,527' MD at 1000' ft per minute per schedule while maintaining 640 psi out of slips, and 460 psi in slips. Pick up weight was 205k and slack off weight 85k while monitoring fluid displacement in pit 3 and 4. Pulled into tight spot at 20,527' MD, 5/22/2019 5/22/2019 3.00 PROD2 CASING BKRM P Back reamed out of hale from 20,527' 20,527.0 20,198.0 13:00 1600 to 20,198' MD while staged pumps up from 2-5 barrels per minute to 3-5 bbls per minute; 3-bbls per min. @ 1143 psi; 4 bbls per minute @ 1,476 psi; and 5 bbls per minute @ 1913 psi and observed 23% flow out. Continue to rotate from 20-50 rpm with 10k ft/lbs. experienced tight hole at 20,373' MD while pumping 2ea open hole volumes and pulling at 75 ft per hr. Total strokes pumped 5,103 while monitoring returns in pit 3 and 4. 5/22/2019 5/22/2019 2.00 PROD2 CASING SMPD P Continued to strip out of hole from 20,198.0 18,990.0 16:00 18:00 20,198'to 18,990' MD at 1000' ft per minute per schedule while maintaining 640 psi out of slips, and 460 psi in slips. Pick up weight 195k and slack off weight 90k while monitoring fluid displacement in pit 3 and 4. Pulled into tight spot at 20,527' MD. 5/22/2019 5/22/2019 2.00 PROD2 CASING SMPD P Continued to strip out of hole from 18,990.0 17,835.0 18:00 20:00 18,990'to 17,835' MD at 1000' ft per minute per schedule while maintaining 640 psi out of slips, and 460 psi in slips. Pick up weight 191 it and slack off weight 94k while monitoring fluid displacement in pit 3 and 4. Pulled light at 20,527' MD. Overpull — 22k at 17,835' MD. 5/22/2019 5/22/2019 1.50 PROD2 CASING BKRM P Back reamed out of hole from 17,860 17,835.0 17,450.0 20:00 21:30 to 17,450' MD, staged pumps up to 35 strokes per min at 235 gpm and 1240- 1170 psi. Noted flow out at 23% at 30 rpm and 8-9k ft/lbs. continue to monitor displacement in pit 3 and 4. Max gas 330 units while holding 460 psi on backside with pumps off and 12 psi with pumps on. 5/22/2019 5/22/2019 1.50 PROD2 CASING BKRM P Circulated bottoms up while back 17,450.0 17,150.0 21:30 23:00 reaming out of hole from 17,450' to 17,150' MD while staging pumps up to 60 strokes per min at 2,220 psi and 25% flow out. Rotating at 30 rpm and 8-9k ft/lbs. while monitoring displacement in pits 3 and 4. Max gas 530 nits, held 460 psi with pumps off and 120 psi with pumps on. Page 41/56 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Tune our (hr) Phase Op Corte Activity Code Time P -T -X Operation start Depth (ftKB) End Depth (WB) 5/22/2019 5/23/2019 1.00 PROD2 CASING SMPD P Continue to strip out of hole with MPD 17,150.0 16,400.0 23:00 00:00 from 17,150'to 16,400.0' MD at 1000' R per hr. as per stripping schedule while maintaining 640 psi out of slips and 460 psi in slips. Pick up weight — 185k and slack off weight 97k while continuing to monitor fluid displacement in pits 3 and 4. 5/23/2019 5/23/2019 3.00 PROD2 CASING SMPD P Continue to strip out of hole with MPD 16,400.0 13,642.0 00:00 03:00 from 16,400'to 13,642' MD at 2,000 ft per hr. as per stripping schedule while constantly maintaining 640 psi out of slips, and 460 psi while in slips. Pick up weight 181 k, & slack off wt. 106k. Continued to monitor fluid returns in pits 3 & 4. 5/23/2019 5/23/2019 1.50 PROD2 CASING SMPD P Continue to strip out of hole, pulled 13,642.0 13,498.0 03:00 04:30 BHA through window maintaining 640 psi out of slips, and 460 psi in slips. Pick up weight was 181k and slack off 104k. Monitored fluid displacement in pits 3 & 4. Observed 22k over -pull at 13,562' MD while pumping 30 SPM at 126 GPM and 1010 psi with 23% flow out. Rotating at 40 rpm to pull through until 13,498' MD. Note—Pulled 18k over with no rotation and no pumps until window cleared. 5/23/2019 5/23/2019 0.50 PROD2 CASING CIRC P Racked back one stand above window 13,498.0 13,258.0 04:30 05:00 and rotated with 5k Nibs. while reciprocating from 13,258'to 13,164' MD at 60 strokes per min, maintaining 2,090 psi. Pick up weight was 175k, slack off 101 k and observed 23% flow out. Total strokes pumped 1600. Held PJSM for displacement of Pro -Flo to 10.9 ppg KW brine. 5/23/2019 5/23/2019 2.59 PROD2 CASING CLEN P Displaced Pro -Flo with "10.9" ppg KW 13,258.0 13,258.0 05:00 07:35 Brine while rotating and reciprocating from 13,258' to 13,164' MD at 60 strokes per min and 2090 psi. Observed 27'% flow out with 5k ft/lbs. of continuous torque. Tested NOVOS as per commissioning procedure. Total Strokes pumped - 5760. 5/23/2019 5/23/2019 1.41 PROD2 CASING OWFF P Observe well for flow, while performing 13,258.0 13,258.0 07:35 09:00 SIMOPS on top Drive and iron roughneck. 5/23/2019 5/23/2019 3.00 PROD2 CASING SMPD P Continue to strip out of hole with MPD 13,258.0 10,277.0 09:00 12:00 from 13,258' to 10,277' MD at 5,000 ft per hr. as per stripping schedule while maintaining 120 psi on backside out of slips and 40 psi while in slips. Pick up weight 145k, slack off 117k while monitoring returns in pits 3 & 4. 5/23/2019 5/23/2019 4.50 PROD2 CASING SMPD P Continue to strip out of hole with MPD 10,277.0 2,503.0 12:00 16:30 from 10,277'to 2,503' MD at 5,000 ft/hr. as per stripping schedule. Continue to maintain 120 psi while out of slips and 40 psi in slips. Pick up weight was 75k and slack off 70k. Continued to monitor returns in pits 2 & 3. Page 42/56 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time Ertl TimeSr our (m) Phase Op Code A viry Code Time P -T -X Operabon (W13) h End D apm (WO) 5/23/2019 5/23/2019 1.25 PROD2 CASING SMPD P Continued to strip out of hole with 2,503.0 1,000.0 16:30 17:45 MPD from 2,503' to 1,000 MD at 10,000 ft/hr. as per stripping schedule while maintaining 120 psi out of slips and 40 psi in slips. Pick up weight was 75k and slack off 70k, while continuing to monitor returns in pits 2 & 3. 5/23/2019 5/23/2019 2.25 PROD2 CASING OWFF P Observed Well for Flow, started at .51 1,000.0 1,000.0 17:45 20:00 bbls per hr. continued to observe near static at .01 bbls per hr.. Performed Pre -Job safety meeting for pulling RCD bearing and installation of trip nipple. 5/23/2019 5/23/2019 1.00 PROD2 CASING MPDA P Pull RCD bearing and installed trip 1,000.0 955.0 20:00 21:00 nipple. Pulled and racked 7 stands into derrick. 5/23/2019 5/23/2019 2.00 PROD2 CASING BHAH P Laid down BHA#13 as directed by 955.0 339.0 21:00 23:00 Schlumberger representative. 5/23/2019 5/23/2019 0.50 PROD2 CASING CLEN P Cleaned Rig floor and collected debris 339.0 0.0 23:00 23:30 from mud filter above BHA for analysis. 5/2312019 5/24/2019 0.50 PROD2 WHDBOP RURD P Pulled wear bushing and installed test 0.0 0.0 23:30 00:00 1 plug for regulatory BOP testing. 5/24/2019 5/24/2019 0.50 PROD2 WHDBOP RURD P RU and tested BOP stack, performed 0.0 0.0 00:00 00:30 shell test to 3,500 psi for 5 -min., test good 5/24/2019 5/24/2019 5.00 PROD2 WHDBOP BOPE P Tested BOP's and associated well 0.0 0.0 00:30 05:30 control equipment with 3-1/2" and 4- 1/2" test joints to 250 psi low and 3,500 psi high for 5 -min. Charted all tests with exception to the manual and hydraulic chokes. Tested annular, and 2-7/8"x 5-1/2" VBR's in the upper and lower pipe rams. Tested blind rams, and the 4.0" HCR and manual choke and kill valves. Tested the choke manifold, valves 1 through 15, tested hyd. and manual chokes at 2,000psi, charted both hold and bleed off pressures for each. Tested the 4" TIW & Dart including both upper and lower IBOP valves. Performed Koomey drawdown test with the accumulators set at 3,000 psi, and manifold pressure at 1,500 psi. Functioned required components resulting the build at the following pressures and time. Accumulators after closure, 1,800 psi. 200 psi attained - 14 seconds. Full pressure attained with both Zea. electric and 2ea. air pumps; 96 seconds. Nitrogen bottles qty and psi, ,6ea. and 1,983 psi. total qty of failures - none. Test time - 4.5 hrs. Witness waived by AOGCC Rep. Mathew Herrera. 5/24/2019 5/24/2019 0.50 PROD2 WHDBOP RURD P Pulled Test Plug and installed wear- 0.0 0.0 05:30 06:00 bushing 5/2412019 5/24/2019 1.75 COMPZ2 CASING BOPE P Blew down equipment, clean and 0.0 0.0 06:00 07:45 cleared rig floor, rigged up to run 4- 1/2" L80 H563 12.6# liner #1. Page 43156 Report Printed:712/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation start Depm (ftKB) EndDepth(8KB) 5/24/2019 5/24/2019 4.25 COMPZ2 CASING RUNL P Performed Pre -Job Safety meeting for 0.0 3,212.0 07:45 1200 assembling and running Liner #1 in Alpine C -sands. Ran liner from surface to 3,210' MD while installing 6- 1/2" centralizers every other joint with a make-up of 3,800k It/lbs. Pick up weight — 75k, slack off - 70k. Monitored fluid displacement on pit 3. OA pressure — 0 psi. Losses 0 bbls 5/24/2019 5/24/2019 1.00 COMPZ2 CASING RUNL P Made up Baker Hydraulic Release 3,212.0 3,307.0 12:00 1300 Drill Down Extreme (HRDE) 5.0" x 7.0" liner setting sleeve. Installed 2 floats and x -over and ran assembly in hole on 4-1/2" DP. Circulated between lbbls/per min at 105 psi, increased circulation to 3-bbls per min at 315 psi. Pick up weight was 75k, Slack off weight — 70k. 5/24/2019 5/24/2019 5.00 COMPZ2 CASING RUNL P Continued to trip liner assembly on 3,307.0 11,195.0 13:00 1800 elevators with 4-1/2" DP from 3,307' to 11,195' MD. Monitored fluid returns on pit 3 filling hole every 20 stands. Pick up — 98k Slack off — 90k. 5/24/2019 5/24/2019 2.00 COMPZ2 CASING RUNL P Continued to trip liner assembly on 11,195.0 13,286.0 18:00 20:00 elevators with 4-1/2" DP from 11,195' to 13,286' MD. Monitored fluid returns on pit 3 filling hale every 20 stands. Pick up weight 157k Slack off weight - 121k. 5/24/2019 5/24/2019 0.50 COMPZ2 CASING MPDA P Performed Pre -Job Safety meeting for 13,286.0 13,286.0 20:00 20:30 trip nipple and RCD bearing installation. Pulled trip nipple and installed bearing as per MPD rep. 5/24/2019 5/24/2019 2.50 COMPZ2 CASING RUNL P Obtained parameters as per Baker 13,286.0 15,945.0 20:30 23:00 Rep. For lbbl/min; Pick up weight 150k, Slack off 130k, Torque 5k ft/lbs. 2bbl/min; pick up weight -160k, slack off weight -125k, Torque 5.5k ft/Ibs. Worked liner slowly through window at 15 fUmin and lbbl min with 120 psi pump pressure. Did not observe any weight infraction through transition. No -rotary. Continued to trip in hole on elevators from 13,286' to 15,945' MD. while monitoring fluid displacement on pit 3. Pick up weight 167k, slack off weight 110k, while continuing to fill every 20 stands. 5/24/2019 5/25/2019 1.00 COMPZ2 CASING DISP P Performed Pre -Job Safety meeting for 15,945.0 15,945.0 23:00 00:00 fluid displacement of 11.0 KW brine to 9.9 Flo -Pro. 5/25/2019 5/25/2019 2.50 COMPZ2 CASING DISP P Displace to 9.90 ppg Flo -Pro at 4 15,945.0 15,945.0 00:00 02:30 bbl./per min. Pressures set at 1400 psi while reciprocating pipe. Total strokes — 6800, final pressure 1000 psi. Circulated 9.9 ppg through both mud pumps and injection pump, obtained slow pump rates. Encountered float failure, attempted to function closed with pump to no -avail. Surged pipe, flappers closed. SPR's at 14,945' MD, TVD- 7,571' MW — 9.9 ppg. MP #1 — 30 SPM -BP 270 psi / 40 SPM -BP 1000psi; MP #2 — 30 SPM -BP 270 psi / 40 SPM -BP 1000psi Page 44156 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CDS-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (hr) Phase Op Code Adivily Code Time P -T -x Operation Stan Depth (ftKB) End Depth(ftKB) 5/25/2019 5/25/2019 3.50 COMPZ2 CASING RUNL P Continued to trip into hole on elevator 15,945.0 18,710.0 02:30 0600 from 15,945'to 18,710' MD with MPD while monitoring fluid displacement in pit 3. Filled hole, pick up weight 178k, slack off weight 100k filling hole every 20 stands. 5/25/2019 5/25/2019 5.00 COMPZ2 CASING RUNL P Continued to trip into hole on elevator 18,710.0 20,640.0 06:00 11:00 from 18,71 O'to 20,640' MD with MPD while monitoring fluid displacement in pit 3. Diminishing SO wt, work pipe occasionaly to get moving. Last 2 stands required rotary to get weight down, 20 rpm, 5-6K tq Filled hole, pick up weight 200k, slack off weight 85k filling hole every 20 stands. 5/25/2019 5/25/2019 1.00 COMPZ2 CASING OTHR P Dropped 29/32" Ball and pumped 20,640.0 20,640.0 11:00 1200 3bbl. per min. for 150bbls, at 1,490 strokes. Reduced pump from 3 bbls per/min to 2 bbls per/min. and continued to pump. Seated ball at 1630 stks, Pressure up to 3,300 psi to release liner running tool. 5/25/2019 5/25/2019 0.50 COMPZ2 CASING RUNL P Released Liner as per Baker Rep. at 20,640.0 20,640.0 12:00 1230 20,640' MD, verified released, picked up 8' and tag, verify TOL at 17,456'. Pick up weight 185k slack off - 102k. Increased pressure to blow ball while holding 400 psi on backside, at 1 bbl per min. with rig pump. Increased pressure to 4,500 psi, isolated rig pump and utilized test pump to increase pressure, sheared ball seat at 4,655 psi. 5/25/2019 5/25/2019 5.50 COMPZ2 CASING SMPD P Circulated and pulled pipe without 17,083.0 17,083.0 12:30 18:00 downward movement or rotary. to 17,083' MD at 6 bbls per/min at 1,550 psi. Flow out was observed between 25-30%. Max Gas was recorded at 11,775 units, continue pump till all gas out, pick up weight 176k, slack off weight 85k at 130 — 190 psi on MPD. Total pumped strokes -17,750. 5/25/2019 5/26/2019 6.00 COMPZ2 CASING SMPD P Strip out of hole from 17,083' to 17,083.0 13,083.0 18:00 0000 13,083' MD per stripping schedule while maintaining 440 psi on slips and 640 psi while pulling. No downward movement with running tool, Pick up weight 170K Slack off weight— 0.0. Continue to monitor returns in pits 4 and 5 while manual strapping every 5 stands. Gas units have been observed between 24-193. Li%= 100 units) O/A Pressure - 50 psi @ 23:30 Total Losses for day - 20 bbls. Page 45156 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code AcW,ty Code Time P -T -X Operation (ftKB) End Depth(ftKB) 5/26/2019 5/26/2019 2.75 PROD2 CASING DISP P Performed a Pre -Job Safety meeting 13,083.0 13,100.0 00:00 02:45 for displacement with all parties involved. Pumped lea 30 bbl. spacer followed by displacement of the 10.9 ppg Pro -Flo with 10.9 ppg Brine. Pumped at 6 bbl. per/min. at 2,500 psi while pulling pipe with a 90' upstroke. Monitored spacer followed with the 10.9 ppg brine to surface. Total Strokes 6,534, at initial circulation of 6 bbl. Per/min and 1,190 psi. Final pressure while maintaining 6 bbls. per/min — 770 psi while using both mud and injection pumps. Obtained slow pump rates at / 13,100' MD, 7,571' TVD, MW 10.9 ppg at (02:30.) Mud pump #1: (30 SPM -BP 0/295 psi; 40 SPM -BP 0/440 psi.) Mud pump #2: (30 SPM -BP 0/290; 40 SPM -BP 0/420 psi.) 5/26/2019 5/26/2019 2.00 PROD2 CASING OWFF P SIMOPS: Observe well for flow post 13,100.0 13,100.0 02:45 04:45 displacement and slip and cut drill line. Preformed Pre -Job safety meeting for Slip and cut. Slipped 133' of drill line. Inspected saver sub, and deadman drum anchor. Re -calibrated Amphion and Totco. Re -installed SLB line sensor and performed derrick inspection. Continuously observed and recorded well condition, well = .01 bbl. Per/hr. 5/26/2019 5/26/2019 1.25 PROD2 CASING SMPD P Strip out of hole from 13,100' MD to 13,100.0 12,200.0 04:45 06:00 12,200' MD per stripping schedule while maintaining 440 psi back pressure in slips and 640 psi out of slips using mud pump 1 at 4 bbls. Per/min. Pick up weight — 165k while monitoring fluid in pit 4. Manually Strapped every 5 -stands. 5/26/2019 5/26/2019 6.00 PROD2 CASING SMPD P Continue to strip out of hole with MPD 12,200.0 3,135.0 06:00 1200 from 12,200'to 3,135' MD per schedule while maintaining 440 psi back pressure in slips and 640 psi out of slips with mud pump #1 at 4 bbls. Per/min. No downward pipe movement as per Baker Rep. Pick up weight— 100k, continued to monitor fluid displacement in pit 4. Continued to manually strap every 5 stands. 5/26/2019 5/26/2019 1.25 PROD2 CASING SMPD P Continue to strip out of hole from 3,135.0 1,000.0 12:00 1315 3,135'to 1,000' MD. as per stripping schedule while maintaining 440 psi back pressure in slips and 640 psi out of slips using mud pump #1 at 4 bbls. Per/min. Continued with no downward movement as per Baker Rep. Continued to monitor fluid displacement in pit 4 and manually strap every 5 stands. 5/26/2019 5/26/2019 1.75 COMPZ2 CASING OWFF P Observed well for flow for 10min -well 1,000.0 1,000.0 13:15 15:00 Static. Perform Pre -Job Safety meeting to pull RCD bearing and install trip nipple. Aired up boot and function tested lines, lined up on hole fill line. Page 46/56 Report Printed: 7/2/2019 Uperations Summary (with Timelog Depths) 1;6 CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Tome End Time Our (hr) Phase Op Code AcAM Code tv Time P-T-% Operefion en(ftKB)De Start Oepfh End OepN (flKB) 5/26/2019 5/26/2019 0.75 COMPZ2 CASING SMPD P Pulled out of hole from 1,000' MD to 1,000.0 0.0 15:00 15:45 surface MD. Pick up weight - 46k while maintaining no downward pipe movement as per Baker Rep. Monitored fluid displacement in pit 1 and manually strap every 5 stands. 5/26/2019 5/26/2019 0.50 COMPZ2 CASING PULD P Laid down Baker liner running tool as 0.0 0.0 15:45 16:15 per Baker Rep. laid down float subs, bumper jars as a complete unit in pipe shed. 5/26/2019 5/26/2019 0.50 COMPZ2 CASING BHAH P Cleared and cleaned dg floor. Rigged 0.0 0.0 16:15 16:45 up to run 4-1/2" Hydril 563 tubing with Doyon casing. 5/26/2019 5/26/2019 1.25 COMPZ2 CASING BHAH P Made up and Tripped in hole with liner 0.0 662.6 16:45 18:00 #2 assembly as per detail from surface to 662.6' MD. Pick up weight 56k slack off weight 52k. Make up torque — 3,800ft/Ibs. thread lube; Seal Guard ECF, utilizing double stacked tongs. Monitored fluid displacement with hole fill on trip pit 3. 5/26/2019 5/26/2019 1.00 COMPZ2 CASING BHAH P Made up liner Setting sleeve, 2 Float 662.6 757.9 18:00 19:00 subs and Bumper sub assembly as per Baker Rep. Rn in hole with 1 stand and circulated liner volume. Pumped at 2 bbl. Per/min with 80 psi ensuring liner flow path was not obstructed. SIMOPS — Changed out ST-80 Iron Roughneck transmission. 5/2612019 5/27/2019 5.00 COMPZ2 CASING RUNL P Trip in hole with Liner#2 from 757.9' 757.9 8,263.0 19:00 00:00 to 8,263' MD. Pick up weight 125k slack off weight - 105k. Trip speed, 90 iNmin as per Baker Rep. Monitoring fluid displacement in Pit 2 with hole fill using mud pump #1, Continue to fill hole every 20 stands .TOTAL Losses - 0.0 BBL. O/A Pressure - 0 psi. 5/27/2019 5/27/2019 3.00 PROD2 CASING RUNL P Cont. to run liner#2 on drill pipe from 8,263.0 13,108.0 00:00 03:00 8,263'to 13,108' MD at 90ft per/min. Continued to monitor fluid displacement in pit 2, filling hole every 20 stands. 5/27/2019 5/27/2019 0.75 PROD2 CASING MPDA P Performed Pre-Job Safety meeting to 13,108.0 13,108.0 03:00 03:45 remove trip and install MPD bearing. 5/27/2019 5/27/2019 0.25 PROD2 CASING RUNL P Established PU/SO/ROT weights and 13,108.0 13,108.0 03:45 04:00 Torque at 1 bpm, 10 and 20 RPM. 1 bbl. Per/min. 140 psi; 2 bbl. Perlmin. 240 psi; 3 bbl. per/min. 430 psi with 10 and 20 rpms. Pick up weight— 1701k, Slack off weight— 124k, and ROT weight 137k 5/27/2019 512712019 1.00 PROD2 CASING RUNL P Cont. to run liner 92 on drill pipe from 13,108.0 14,022.0 04:00 05:00 I I 13,108' to 14,022' MD. Pick up weight 168k and slack off 118k. Page 47156 Report Printed: 7/212019 Operations Summary (with Timelog Depths) MW CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log start Time End Time Our (m) Phase Op cme Activity Cafe Time RT -X Operation Stan Dern (ftKB) End Depth(ftKB) 5/27/2019 5/27/2019 1.75 PROD2 CASING RUNL P Picked up to 14,023 and dropped ball 14,022.0 13,391.0 05:00 06:45 (29/32 - .900" Dia.) and circulated down at 2 bbls. per/min. with 430 psi, ball on seat at 1221 strokes, (123 bbls.). Pressured up to 3,000 psi and released liner as per Baker Rep. at desired depth of 13,391' MD, verified Top of Liner, picked up 8' and came back down to tag. Pick up weight 172k Slack off weight 130k. Racked back one stand, Stand -141, and pressured up at 4616 psi, blowing the ball seat setting the liner. 5/27/2019 5/27/2019 2.50 C0MPZ2 CASING CIRC P Picked up to 13,340' MD and 13,391.0 13,340.0 06:45 0915 circulated staging up to 6 bbls. Per/min. at 863 psi observing 22 flow back, Gas was observed at 1675 units. Added 11.9 ppg spike fluid while monitoring returns in pits 1 and 2. Total Strokes pumped 7745, or 780 bbls. 5/27/2019 5/27/2019 0.50 COMPZ2 CASING OWFF P Observed well for Flow — well Static 13,340.0 13,340.0 09:15 09:45 5/27/2019 5/27/2019 2.25 C0MPZ2 CASING SMPD P Stripped out of hole with MPD from 13,340.0 10,494.0 09:45 12:00 13,340' MD to 10,494' MD as per schedule without downward or rotation while maintaining 180 psi back pressure in slips and 80 psi out of slips. Continue to monitor hole fill in pit 2, Pick up weight recorded at 155k. O/A pressure — 200 psi 5/27/2019 5/27/2019 5.00 C0MPZ2 CASING SMPD P Continued to strip out of hole from 10,494.0 6,800.0 12:00 17:00 10,494' to 6,800' MD with MPD as per stripping schedule with 100 psi in slips and 100 psi out of slips without downward movement or rotation. Racked back 37 stands and laying down remainder. Continue to monitor fluid in pit 2. Pick up weight 125k. 5/27/2019 5/27/2019 0.50 C0MPZ2 CASING SVRG P Serviced Iron Roughneck, ST -80. 6,800.0 6,800.0 17:00 17:30 5/27/2019 5/27/2019 0.50 C0MPZ2 CASING SMPD P Cont. to strip out of hole with MPD 6,800.0 6,450.0 17:30 1800 from 6,800' to 6,450' MD as per schedule while laying down drill pipe in pipe shed. Maintaining 80 — 100 psi back pressure in and out slips, continue to monitor returns on pit 2. No downward or rotational movement of pipe. pick up weight 124k. 5/27/2019 5/28/2019 6.00 C0MPZ2 CASING SMPD P Continue to strip out of hole from 6,450.0 1,000.0 18:00 00:00 6,450' to 1000' MD with MPD as per schedule maintaining 100 psi out of slips and 80 psi in slips. Monitoring fluid displacement and hole fill on pit 2. No downward pipe movement or rotation. Pick up weight -60k. O/A-0 psi / Total losses — 25.8 bbls. 5/28/2019 5/28/2019 0.75 C0MPZ2 CASING MPDA P Observe well for flow — Well Static. 1,000.0 1,000.0 00:00 00:45 Performed a Pre -Job Safety Meeting for removal of the RCD bearing and installing trip nipple. Picked up a 15' pup and removed bearing, installed trip nipple. Page 48156 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Sten Time Entl Time our (h Phase Op Cotle Activity Cotle Time P -T -X Opeetion Stan Depth dtKB) End Dept(ftKB) 5/28/2019 5/28/2019 1.75 COMPZ2 CASING PULL P Contnel out of hole from 1,000.0 0.0 00:45 0230 1000'to surface laying down DP in pipe shed. Monitored fluid displacement in pit 2 while continually filling hole over top. No downward movement or rotation with Baker running tool. Disassembled BHA as per Baker Rep. and laid down. Pick up weight 55k at 500' MD. 5/28/2019 5/28/2019 3.50 COMPZ2 EVALWB SRW P Performed Pre -job Safety meeting 0.0 13,222.0 02:30 06:00 with CAST M E -line crew with Well Tech Tractor. Inspected all 3rd party lifting equipment and rigging. Rigged up equipment and installed line wiper and cable cutter for well control contingency. Continuous hole -fill over top while monitoring returns in trip pit 2. Run in hole with E -Line and to 13,222' from surface without tractor at 45ft per min. Logged from 13,222' to 8,000' MD. Cable cutting equipment in place on rotary for well contingency. 5/28/2019 5/28/2019 6.00 COMPZ2 EVALWB SRW P Continue with E -Line verifying csg 13,222.0 8,000.0 06:00 12:00 wear and cement from 13,222' to 8,000' MD at 72 shots per scan, 12 scans per foot at 1 9f per/min. Continued hole fill over top and monitored returns in pit 3. 5/28/2019 5/28/2019 6.00 COMPZ2 EVALWB SRW P Continue with E -Line verifying csg 8,000.0 0.0 12:00 18:00 wear and cement from 8,000' to 300' MD, survey completed at 72 shots per scan, 12 scans per foot at 1 9f per/min Continued hole fill over top and monitored returns in pit 3. 5/28/2019 5/28/2019 2.25 COMPZ2 EVALWB SRW P Laid down E -Line tooling and rig down 0.0 0.0 18:00 20:15 equipment, staged Baker tooling for whipstock BHA and retrieval. 5/28/2019 5/29/2019 3.75 COMPZ2 FISH BHAH P Performed Pre -Job Safety Meeting, 0.0 3,551.0 20:15 00:00 Made up Whipstock retrieval BHA, total length 225.0'. RIH on 4" drill pipe. Shallow hole test, (1,650' MD) at 495 psi and 225 gpm. Continue running in hole to 3,551 MD. Pick up weight 80k Slack off weight — 72k. Filling pipe every 20 stands and manually strapping returns in pit # 3. 5/29/2019 5/29/2019 5.00 COMPZ2 FISH TRIP P Continue to run in hole with whipstock 3,551.0 13,065.0 00:00 05:00 retrieval BHAfrom 3,551'to 13,065' MD. Pick up weight 154k, slack off weight 121k noted at 13,065' MD. Filling every 20 stands and manually strapping pits 2 and 3 every 5 stands while hole filling over top. Observed 7bbl gain on trip, stopped and flow checked well @ 10,585' MD, Well Static. 5/29/2019 5/29/2019 1.00 COMPZ2 FISH MPDA P Observed well for flow for 10 min, well 13,065.0 13,065.0 05:00 0600 static. Performed Pre -job Safety meeting for removing trip nipple and installing MPD bearing. Pulled nipple and installed bearing at 13,065' on 15' pup as per MPD Rep. 5/29/2019 5/29/2019 1.50 COMPZ2 FISH DLOG P Logged for RA tag from 13,138'to 13,065.0 13,175.0 06:00 07:30 13,175' MD 250' HR, 22% flow out at 6 bbl. per/min and 21,239 psi. Tagged at 13,171' MD. Page 49/56 Report Printed: 7/212019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time Eno Time our (hr) Phase Do Code Activity Code Time P -T -x Operation Start Depth (flKB) End Depth (flKB) 5/29/2019 5/29/2019 4.50 COMPZ2 FISH FISH P Oriented retrieval hook per 13,175.0 13,369.0 07:30 12:00 Baker/Schlumberger Reps. Washed down slot area and attempted to hook whipstock. Reciprocated from 13,345' to 13,381' MD. Pick up weight 175k, and Slack off 126k at 6.5 bbls. Per/min. and 1,493 psi. Attempted again with pumps off, again rotated at 5 rpm, at 4k ft/lbs. from 13,366 to 13,374' MD. Rotating weight 149k. Brought pumps on to rate, re -oriented to 47 degrees left while rotating left. Engaged hook slot at 13,369' MD. Pick up weight 15k over and let Jars relax while reducing pump rate to 2bbls per/min. at 235 psi. Flow out rate — 15%. O/A pressure 0.0, Losses for 0.0 bbls. 5/29/2019 5/29/2019 0.50 COMPZ2 FISH FISH P Pick up and attempt to release anchor, 13,369.0 13,348.0 12:00 12:30 pull 70k hit jars at 200-240k. Pick up weight 180k slack off— 130k. Once released, picked up 7.0' to pull out of seals at 13,348.0 MD. Pit on stand by for monitoring losses. 5/29/2019 5/29/2019 1.75 COMPZ2 FISH OWFF P Monitored hole for losses on pit 3 at 2 13,348.0 13,348.0 12:30 14:15 bbls. per/min (83 gpm) at 228 psi with a flow at 14%. MPD flow out was 75 gpm. (Loss rate was 16 bbls per/hr. Swapped to pump with MPD injection line at 2 bbls. per/min. and 50 psi. and flow out was observed at 13%. MPD flow out was at 81 gpm. Loss rate was 8 bbls. per/hr. 5/29/2019 5/29/2019 2.25 COMPZ2 FISH CIRC P Stabbed back into seals and stopped 13,368.0 13,368.0 14:15 1630 losses at 13,368' MD while monitoring hole at 2bbls per/min. and 45 psi. Flow out was 14%. SIMOPS —Weighted up 100bbl. Hi -Vis Pill. 5/29/2019 5/29/2019 1.50 COMPZ2 FISH CIRC P Pumped 100bbi of Hi Vis at 4bbls 13,368.0 13,361.0 16:30 18:00 per/min and 623 psi. Observed flow out at 20%. Reduced pump rate to 2bbls per/min for the last 20 bbls and pulled back up 7.0' and out of seals. Total Strokes pumped, 2,322. 5/29/2019 5/29/2019 0.50 COMPZ2 FISH OWFF P Picked up to 13,350' MD with 193k 13,361.0 13,350.0 18:00 1830 and racked back on stand. Flow checked well, Well Static. SIMOPS Performed post jar derrick inspection and blew down top drive. 5/29/2019 5/30/2019 5.50 COMPZ2 FISH SMPD P Stripping out of hole with MPD from 13,350.0 6,022.0 18:30 00:00 13,350'to 6,022' MD while holding Annular back pressure with mud pump 1. No downward movement as per Baker Rep. Manually strapping trip pit every 5 stands. Pick up weight 117k at 6,022' MD. BP = 80 psi -13,500' MD to 12,800' MD BP = 60 psi - 12,800' MD to 9,900' MD BP = 40 psi — 9,900' MD to 6,022' MD Page 50156 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Cade Time P -T -X Operetion Start Depth (ftKB) End Depth(ftKB) 5/30/2019 5/30/2019 3.75 COMPZ2 FISH SMPD P Continue to Strip out of hole with MPD 6,022.0 1,000.0 00:00 0345 from 6,022'to 1,000' MD while holding 40 psi back pressure utilizing mud pump 1. Pick up eight 65k at 1,000' MD. Manually strapping trip pit every 5 stands. No downward pipe movement as per Baker Rep. 5/30/2019 5/30/2019 0.25 COMPZ2 FISH OWFF P Observed well for flow for 15 min. Well 1,000.0 1,000.0 03:45 04:00 Status: Static. 5/30/2019 5/30/2019 0.50 COMPZ2 FISH MPDA P Performed Pre -job Safety Meeting for 1,000.0 1,000.0 04:00 04:30 RCD bearing removal and trip nipple installation. Pulled Bearing and installed trip nipple. 5/30/2019 5/30/2019 3.25 COMPZ2 FISH TRIP P Pulled out of hale from 1000'to 225' 1,000.0 0.0 04:30 07:45 MD, pick up weight 50k. Observed well for Flow prior to pulling non - shearing equipment across BOP'S. Racked 4" HWDP and laid down Baker whipstock BHA as per Baker Rep. Continuously maintained constant hole fill over top. Manually strapped trip tank every 5 stands. 5/30/2019 5/30/2019 1.00 COMPZ2 WELLPR SHAH P Cleared and cleaned rig floor prepped 0.0 0.0 07:45 08:45 for Baker Cleanout BHA. 5/30/2019 5/30/2019 1.25 COMPZ2 WELLPR BHAH P Made up Baker Cleanout BHA as per 0.0 104.0 08:45 10:00 Baker Rep, from surface to 104' while monitoring returns on pit 1 with constant hole fill over top. Pick up weight 55k, slack off 50k. 5/30/2019 5/30/2019 2.00 COMPZ2 WELLPR TRIP P Tripped in hole from 104' to 3,150' MD 104.0 3,150.0 10:00 12:00 while monitoring returns on pit 1. Pick up weight 65k, slack off weight 80k. 5/30/2019 5/30/2019 3.00 COMPZ2 WELLPR TRIP P Continued to trip in hole with Baker 3,150.0 8,050.0 12:00 15:00 Clean out BHA from 3,150.0' to 8,050' MD, continuous fill every 20 stands and monitoring returns on pit 1. Pick up weight 151k, slack off weight 106k 5/30/2019 5/30/2019 2.50 COMPZ2 WELLPR TRIP P Continjue to run hole with Baker Clean 8,050.0 13,038.0 15:00 17:30 out Assy. from 8,050'to 13,038' MD filling every 20 stands and monitoring displacement on pit 10 Pick up wieght - 164k, Slack off wieght 123k. 5/30/2019 5/30/2019 1.00 COMPZ2 WELLPR TRIP P Continue to run hole with Baker Clean 13,038.0 13,038.0 17:30 18:30 out Assy. from 8,050'to 13,038' MD filling every 20 stands and monitoring displacement on pit 10 Pickup weight - 164k, Slack off weight 123k. 5/30/2019 5/30/2019 0.50 COMPZ2 WELLPR WASH P Pump down with Baker clean out BHA 13,038.0 13,739.0 18:30 1900 from 13,038' to 13,739' MD tagged top of liner at 13,739' MD, setting down 10k. Pick up weight 178k, Slack off weight 128k at 2 bbls per/min, 20 GPM, and 200 psi. 5/30/2019 5/30/2019 2.00 COMPZ2 WELLPR CIRC P Circulated bottoms up at 4200 strokes 13,718.0 13,730.0 19:00 21:00 while reciprocating from 13,718'to 13,730' MD cleaning casing. 20 gpm at 200psi, with 14% flow out at 2 bbls. per/min. Pick up weight 164k, Slack off weight 136k. Page 51/56 ReportPrinted: 7/212019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time Eno Time our ( Phase Op Code Activity Code Time P -T -X Operabon Stan Depth (WS) End Depth (MB) 5/30/2019 5/30/2019 1.0.0 0 COMPZ2 WELLPR CIRC P Continued to circulate and reciprocate 13,730.0 13,718.0 21:00 22:00 from 13,718'to 13,730' MD for one complete bottom up, totaling 4,300 strokes, last 100 bbls at 3bbls. per/min, and 4bbls. per/min at 340 and 495 psi. Pick up weight 164k Slack off weight 136k. 5/30/2019 5/30/2019 0.50 COMPZ2 WELLPR OWFF P Shut pump off and Observed well 13,718.0 13,730.0 22:00 22:30 through MPD outlet for flow 30 min. Well Status: Slight loss. 5/30/2019 5/31/2019 1.50 COMPZ2 WELLPR STRP P Blew down top drive and established 13,730.0 12,934.0 22:30 0000 circulation with mud pump through the injection line at 2 bbls. per/min. Stripped out of hole from 13,730' to 12,934' MD laying down 15.7# drill pipe to the pipe shed while maintaining 40 psi annular back pressure at 2 bbls. per/min. Pick up weight 165k Slack off weight 134k O/A pressure at 22:00 was 25 psi. Total losses for day; 137.82 bbls. 5/31/2019 5/31/2019 6.00 COMPZ2 WELLPR PULD P Continue to lay down 15.7# DP and 12,934.0 8,236.0 00:00 06:00 strip out of hole with MPD from 12,934' to 8,236' MD at 60f /min maintaining 40 psi back pressure at 2bbls/min. Pick up weight 165k, Slack off weight 134k. 5/31/2019 5/31/2019 5.25 COMPZ2 WELLPR PULD P Continue to lay down 15.7# DP and 8,236.0 2,222.0 06:00 11:15 strip out of hole with MPD from 8,236' to 2,222' MD at 90ft/min maintaining 40 psi back pressure at 3bbls/min. Pick up weight 125k, Slack off weight 120k. 5/31/2019 5/31/2019 1.00 COMPZ2 WELLPR MPDA P Conducted Pre -Job Safety Meeting for 2,222.0 2,222.0 11:15 12:15 removing RCD bearing and install Trip nipple. Observed well for flow - Static Loss. Rig up air to injection pump, blew down MPD system. Pulled bearing and installed Trip nipple. Pick up weight - 73k. Continue to fill over top while monitoring returns and strapping over pit 3. 5/31/2019 5/31/2019 0.75 COMPZ2 WELLPR PULD P Continue to pull out of hole from 2,222' 2,222.0 1,785.0 12:15 13:00 to 1,785' MD laying down singles in pipe shed. Continue to maintain hole fill over top while strapping manually pit 3 every 15 singles. 5/31/2019 5/31/2019 0.50 COMPZ2 WELLPR SVRG P Serviced Top Drive and Blocks, 1,785.0 1,785.0 13:00 13:30 inspected ST -80 and saver sub. 5/31/2019 5/31/2019 2.00 COMPZ2 WELLPR PULD P Continue to pull out of hole from 1,785' 1,785.0 198.0 13:30 15:30 to 198' MD laying down singles and maintaining continuous hole fill over top. Manually strapping pit 3 every 15 joints. 5/31/2019 5/31/2019 1.50 COMPZ2 WELLPR BHAH P Observed well for flow for 10 min. 198.0 0.0 15:30 17:00 (Static Loss) Performed Pre -Job safety meeting for non sheering equipment across BOP's. Layed down 4" HWDP and Baker BHA. Cleaned magnets with min debris. 5/31/2019 5/31/2019 1.00 COMPZ2 WELLPR BHAH P Clean and cleared rig floor lay down of 0.0 0.0 17:00 18:00 all tools and BHA assembly. Page 52156 Report Printed: 7/212019 Operations Summary (with Timelog Depths) CDS-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X operation Stat) Depth (ftKB) End Depth (ftKB) 5/31/2019 5/31/2019 1.00 COMPZ2 WELLPR PULD P Performed Pre-Job Safety meeting for 0.0 0.0 18:00 19:00 running in hole with remaining 6 stands of 4" in derrick and laid them down in pipe shed. 5/31/2019 5/31/2019 1.00 COMPZ2 RPCOMP WWWH P As per FMC Rep. pulled wear bushing 0.0 0.0 19:00 20:00 and made up stack washing tool. Flushed stack at 400 gpm while rotating 40-60 rpm. 5/31/2019 5/31/2019 1.50 COMPZ2 RPCOMP RURD P Rigged up Schlumberger and Doyon 0.0 0.0 20:00 21:30 casing equipment to run completion ubing. 5/31/2019 5/31/2019 1.00 COMPZ2 RPCOMP PUTB P Conducted PrejobSafety meeting in 0.0 0.0 21:30 2230 conjunction with third party and crew change for picking up and running completion equipment. 5/31/2019 6/1/2019 1.50 COMPZ2 RPCOMP PUTB P Verified tubing city and run order in 0.0 77.0 22:30 00:00 pipe shed with new crew, Picked up Baker WLEG and 3-1/2" tubing, ran in hole to 77.32' MD. Pick up weight 47k, Slack off weight 44k. Tour losses - 62 bbls. 6/1/2019 6/1/2019 2.00 COMPZ2 RPCOMP PUTB P Continue to run 4-1/2" Completion 77.0 780.0 00:00 02:00 string from 77'to 780' MD as per running detail while graphing all 4-1/2" Tenaris Blue threaded connections. Continually monitoring hole fill and manually strapping active pit 2 for losses. Pick-up weight 48k, Slack-off weight 54k. 6/1/2019 6/1/2019 0.50 COMPZ2 RPCOMP PUTB P Pressure tested the SLB solid gauge 780.0 780.0 02:00 02:30 mandrel to 5,000 psi for min, test good. Witnessed by CPAI rig supervisor. 6/1/2019 6/1/2019 0.50 COMPZ2 RPCOMP PUTB P Pipe Shed's skate failed to function 780.0 780.0 02:30 03:00 properly and the hydrualic pump identified. SIMOPS - serviced top drive, blocks, drag chains and elevators while continuing to fill hole and monitor losses in active pit. 6/1/2019 6/1/2019 3.00 COMPZ2 RPCOMP EQRP T Further investigated failure on 780.0 780.0 03:00 0600 hydraulic pump #2. Conducted a Pre- Job Safety Meeting for the pump's replacement and electrical testing. All energy sources, both hydraulic and electrical devises were lock and tagged out. The pump was identified as non-serviceable and requiring replacement. The pumps electric motor and fuses were also checked, requiring pump and fuses to be replaced and expedited. Continued with rig SIMOPS while constantly filling hole and monitoring losses in pit 2. 6/1/2019 6/1/2019 6.00 COMPZ2 RPCOMP EQRP T Continued to investigate the root 780.0 780.0 06:00 12:00 cause of initial failure. Waiting on arrival of the 175-amp fuses and pump. Replaced pump and required fuse, repair completed. Continued with rig SIMOPS while constantly filling hole and monitoring losses in pit 2, at 6 bbls. per hr Root cause of failure - inconclusive, DDI to submit failure report. Page 53156 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CDS-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Steil Tme End Time Dur (hr) Phase Op Cotle Activity Cotle Time P -T -X Operation Start Depth (fl(B) End Depth (flKB) 6/1/2019 6/1/2019 6.00 COMPZ2 RPCOMP PUTB P Conducted Pre -Job Safety meeting for 780.0 3,401.0 12:00 1800 running upper completion as per detail from 780'to 3,401' MD. Pick-up weight 73k to slack -off weight 75k. Rotation weight - 5,360ft/lbs. Continue to hole FII while monitoring losses in pit 2. 6/1/2019 6/2/2019 6.00 COMPZ2 RPCOMP PUTS P Continue to run 4-1/2" upper 3,401.0 7,055.0 18:00 00:00 completion as per detail from 3,401' to 7,055' MD. Pick-up weight 82k to slack -off weight 74k. Rotation weight - 5,360ft/lbs. Continue to hole fill while monitoring losses in pit 2. Daily loss to formation - 133 bbl. 6/2/2019 6/2/2019 6.00 COMPZ2 RPCOMP PUTB P Continue running in hole with TSH 7,055.0 10,554.0 00:00 06:00 Blue 4-1/2" completion as per detail from 7,055'to 10,554' MD. Pick up weight 120k, Slack off weight 100k. Torque turn all connections to 5,360ft/Ibs. Continued to monitor displacement on pit 2 with constant hole fill. 6/2/2019 6/2/2019 6.00 COMPZ2 RPCOMP PUTB P Continue running in the hole with 4- 10,554.0 13,585.0 06:00 1200 1/2" TSH Blue completion as per detail. From 10,554'to 13,585' MD Pick up weight 138k, slack off weight 105k, continued to torque turn all connections to 5,360ft/lbs. Monitor displacement on pit 2. 6/2/2019 6/2/2019 0.50 COMPZ2 RPCOMP PUTB P Conducted Pre -Job Safety meeting for 13,585.0 13,720.0 12:00 12:30 running in the hole as per detail from 13,585'to 13,720' MD Tagged no-go with 15k. Pick up weight 142k slack off weight 109k, Torque turn all connection to 5,360ft/lbs. Monitor displacement on pit 2. 6/2/2019 6/2/2019 0.75 COMPZ2 RPCOMP PUTB P Tagged at 13,720 X5 with 15k 1/4 turn 13,720.0 13,720.0 12:30 13:15 string to the right, tagged X5 1/2 turn string left. left tag X5 6/2/2019 6/2/2019 1.25 COMPZ2 RPCOMP PUTB P Laid down joint 318 to 13,707' MD 13,720.0 13,707.0 13:15 14:30 Picked up landing joint and X/O and head pin, reversed circulated through cement line for returns. Closed annular and reverse circulated 10bbls at 1 bpm, pressure at 220 psi, verified returns in pit, rigged down cement line/landing joint. 6/2/2019 6/2/2019 0.50 COMPZ2 RPCOMP PUTB P Spaced out landing joint laid down 13,707.0 13,707.0 14:30 15:00 joint 318 and 317, Picked up 9.92' pup joint, picked back up tubing joint 317. 6/2/2019 6/2/2019 2.00 COMPZ2 RPCOMP PUTB P As per FMC rep. Made up landing joint 13,707.0 13,707.0 15:00 17:00 and tubing hanger on string. 320ea cannon clamps, and Bea mid joint clamps were accounted for. As per SLB and FMC terminated TEC wire on tbg hanger and tested to 5,000 psi for 5 -min. Witnessed by COP Co. Rep. SIMOPS while rigging down SLB and Doyon casing crews. Cleared and clean rig floor. 6/2/2019 6/2/2019 2.25 COMPZ2 RPCOMP PUTB P Run in hole to 13,696 MD' closed 13,707.0 13,696.0 17:00 1915 annular preventer reversed circulated 75 bbls 11.0 PPG CI -Brine chase with 310 bbls of 11.0 ppg brine staging up to 4 bpm at 410 psi FCP. Page 54/56 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) 1-[ CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Stad Time End Time our (hr) Phase Op Code Activity Gods Time P -T-% Operation Sean Depth (flKB) End Depth (flKB) 6/2/2019 6/2/2019 0.75 COMPZ2 RPCOMP PUTB P Bled off pressure, opened kill line, 13,696.0 13,702.0 19:15 20:00 verified zero (0) pressure and landed tubing hanger. Ran in tie down pins as per FMC rep. Torqued tie down pins to 450ft/lbs. 6/2/2019 6/3/2019 4.00 COMPZ2 RPCOMP PACK T Rigged up to circulate through tbg 13,702.0 13,702.0 20:00 00:00 while pressuring up to 3,800 psi with mud pumps at 2bpm, pumped 6.5 bbls, isolated mud pumps and picked up test pump to 4,250 psi. shut in pump and observed pressure chart. Set packers as per Haliburton and Baker reps. Continue to chart pressure for 30 min. Encountered min leakage and bumped pressure back to 4,250 psi, closed in and pressure dropped to 150 psi. Shut down operations and inspected all surface lines, valve alignment and connections, no leaks were identified in line up. Isolated tbg from line configuration and pressure tested to 2,500 psi for 5 -min without leaks. Attempted to re -test tbg again at 2 bpm, achieved pressure at 450-500 psi with pressure fluctuations. Pumped 9 bbls away with no returns to the pits. Shut down and pressure bled off. Pumped down I/A at .5 bbl, at 500 psi. shut pump down and held pressure for 5 -min. Bled pressure off and concluded the flapper valve in bottom section had failed. Contacted management for plan forward. Well remained on vacuum, while monitoring pit 9. SIMOPS: Broke down frac tree and picked to rig floor, prepped for wireline rig up, placed 4.0" Demco valve on mud pump #1. OA pressure 0 psi/total losses 102 bbls. 6/3/2019 6/3/2019 6.00 COMPZ2 RPCOMP WAIT T Waiting on E -line, rigged down surface 0.0 0.0 00:00 06:00 pumping equipment and blew down cement line, top drive, gas buster, choke and kill lines. Set herculite and mats for CD -98, cleaning pits and worked on general housekeeping. 6/3/2019 6/3/2019 6.00 COMPZ2 RPCOMP WAIT T Continued to work SIMOPS; staged 0.0 0.0 06:00 12:00 frac equipment, continue to cllean trip tank, inspected moving system, reviewed stage 5 handling equipment on rig floor. remove FOSV and x -over filled tubing. 19 bbls to fill. conducted Pre -Job Safety Meeting as per Haliburton reps; staged wire line tools on rig floor filled tbg every 30 min. loss rate, 5 bph. 6/3/2019 6/3/2019 1.50 COMPZ2 RPCOMP SLKL T Conducted Pre -Job Safety Meeting for 0.0 0.0 12:00 13:30 rigging up a -line equipment and slick line running tools. Page 55156 Report Printed: 7/2/2019 Operations Summary (with Timelog Depths) CD5-24 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur lhT Phase on Code Actsity Code Time P -T -X Operation Start Depth (ftKB) End Depih(ftKa) 6/3/2019 6/3/2019 4.50 COMPZ2 RPCOMP SLKL T Set timer on 4-1/2" Evotrieve Bridge 0.0 12,600.0 13:30 1800 plug f/2hrs, 55min. Run in hole with slick line to depth, 12,600' MD. E -line string and pick up weight 775lbs. Waited on plug timer, plug set, picked up to tag and confirm, 1 000'wire line depth. Pressure up down tbg to 1000 psi for 5 -min, (charted) bled pressure pulled out of hole. Rigged down Haliburton slick line equipment. 6/3/2019 6/3/2019 3.50 COMPZ2 RPCOMP PRTS P Cleared and cleaned floor of 12,600.0 0.0 18:00 21:30 equipment. Rigged up and pressure down tog with mud pump with 4 bbl. to 3,850 psi and changed to test pump. Continued to 4200 psi and held for 30 - min. Charted, test good. Bled pressure to 2000 psi and blocked. Re -aligned direction of flow with mud pump 2 and pump in the I/A to 3,850 psi for 30 - min. Charted, test -good. Bled pressure from I/A to 0 psi, followed by bleeding the 2000 psi off tbg. Re- aligned flow path with returns from tbg to the pits and pressured up the I/A to 2400 psi and sheared the SOV Charted and shear good. Circulated down the I/A at 1.5 bbl. per/min taking returns up the tbg for 5-mins. At 390 psi. 6/3/2019 6/3/2019 2.00 COMPZ2 RPCOMP MPSP P Observed well for 10 min, well static. 0.0 0.0 21:30 23:30 Laid down landing joint and picked up HP BPV and installed in tbg hanger with T -bar. Pressure tested the BPV through the I/A and up the tbg for 15 min at 2500 psi. Charted, Test -good. Bled pressure and observed well for 30 -min for flow. Well static. Observed well for flow - well static. SIMOPS- Blew down gas buster kill, choke and injection line. 6/3/2019 6/4/2019 0.50 COMPZ2 WHDBOP NUND P Nipple down BOP's Removed choke 0.0 0.0 23:30 00:00 and kill lines. 6/4/2019 6/4/2019 2.00 COMPZ2 WHDBOP NUND P Nipple down BOP's, HP riser, DSA 0.0 0.0 00:00 02:00 and Adaptor Flange. 6/4/2019 6/4/2019 4.00 COMPZ2 WHDBOP NUND P NU Adaptor Flange to tubing head. 0.0 0.0 02:00 06:00 Test I wire per Comco Rep. NU Frac Tree assembling individual pieces per FMC Rep. 6/4/2019 6/4/2019 2.50 COMPZ2 WHDBOP NUND P Torque all bolts on Frac Tree and RU 0.0 0.0 06:00 08:30 to test. SIMOPS: Remove Kelly hose F/ Top Drive. and install Bridle Lines on Traveling Blocks. RD interconnects between modules. BD water and steam lines. Disconnect from Hi -Line @ 07:00. 6/4/2019 6/4/2019 3.00 COMPZ2 WHDBOP PRTS P Test tree adapter flange void 500 psi/5 0.0 0.0 08:30 11:30 min, 5000 psi / 10 min. Test tree 250 psi / 10 min (charted) 10,000 psi / 10 min. Dry Rod Dart from BPV. Secure Well. Well secure @ 11:45 6/4/2019 6/4/2019 0.50 DEMOB MOVE RURD P Disconnect module interconnects, 0.0 0.0 11:30 12:00 RDMO Rig Released 12:00. Page 56156 Report Printed: 7/2/2019 NADConversion Western North Slope CD5 Alpine West Pad CD5-24 CD5-24 ConocoPhillips Definitive Survey Report 03 April, 2019 Final Definitive Survey Verified and Signed -off All targets andlor well position objectives have been achieved. 0 Yes ❑ No I have checked to the hest of my ability that the following data is correct: C] Surface Coordinates F1 Declination & Convergence GRS Survey Corrections Survey Tod Codes Digitally by BrandonTemple SIB DE: Brandon TernpleDat;2019.D4.03 09:45:10 08'09 Client Representative: tom.g.polasek@conocophillips.corrm-7: -- Date: 4019 ConocoPhillips Company: NADConversion Project: Western North Slope Site: CD5 Alpine West Pad Well: Rig: CD5-24 Wellbore: CDS-24 Design: CD5-24 ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: CD5-24 CD5-24 actual @1 70.60usft C05-24 actual Cat 70.60usft True Minimum Curvature OAKEDMPI Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Rig: CD5-24 Well Position +N/S 0.00 usft +EI -W 0.00 usft Position Uncertainty D.00 usft Wellbore CD5-24 Magnetics Model Name BGGM2018 Northing: 5,965,791.46 usft Latitude: 70° 18' 49.057 N Easling: 349,096.49 usft Longitude: 151° 13'22.909 W Wellhead Elevation: 0.00 usft Ground Level: 33.70 usft Sample Date Declination (9 2/15/2019 16.27 Dip Angle Field Strength P) Inn 80.74 57,387 Design CD5-24 Date Audit Notes: From To Version: 1.0 Phase: ACTUAL Tie On Depth: 36.90 Vertical Section: Depth From (TVD) +WS +EI -W Direction _GWD70 (CD5-24) (usft) (usft) (usft) P) 11,977.66 CDS-24 Srvy 2-SLE_MWD+GMAG(CD 36.90 0.00 0.00 159.37 Survey Program Date From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Data 113.03 2,193.19 CD5-24 Srvy 1 - SLB _GWD70 (CD5-24) GYD-GCSS Gyrodata gyro single shots 2/17/2019 10:03 2,287.10 11,977.66 CDS-24 Srvy 2-SLE_MWD+GMAG(CD TVDSS MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 2122/201910:03 12,071.41 13,298.67 CD5-24 Srvy 3- SLB _MWD+GMAG (CD MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 2/27/201910:03 13,394.32 15,301.08 CD5-24 Srvy 4-SLB_MWD+GMAG(CD (usft) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/10/2019 5:53:- 15,400.72 21,197.61 CD5-24 Srvy 5-SLB_MWD+GMAG (CD MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/8/2019 5:53:0 21,250.86 30,964.31 CD5-24 Srvy 6-SLB_MWD+GMAG(CD 0.00 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/15/2019 5:53. - Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Seating DLS Section (usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) ("/100) (ft) Survey Tool Name 36.90 0.00 0.00 36.90 -33.70 0.00 0.00 5,965,791.46 349,096.49 0.00 0.00 UNDEFINED 113.03 0.11 213.34 113.03 42.43 -0.W -0.04 5,965,791.40 349,096.44 0.14 0.04 GYD-GC-SS(1) 140.11 0.16 268.42 140.11 69.51 -0.06 -0.09 5,965,791.38 349,096.39 0.49 0.05 GYD-GC-SS(1) 231.26 0.21 241.24 231.26 160.66 4.17 -0.37 5,965,791.30 349,096.12 0.11 0.03 GYD-G"S(1) 322.05 0.31 213.32 322.05 251.45 4.45 -0.65 5,965,791.02 349,095.83 0.17 0.20 GYD-GC-SS(1) 412.88 0.41 199.77 412.88 342.28 -0.% -0.89 5,965,790.52 349,095.58 0.14 0.59 GYD-GC-SS(1) 507.56 0.69 210.61 507.55 435.95 -1.77 -1.30 5,965,789.72 349,095.15 0.31 1.20 GYD-GC-SS(1) 596.26 1.38 184.88 596.24 525.64 3.30 -1.66 5,965,788.20 34%094.76 0.92 2.50 GYD-GC-SS(1) 689.54 2.21 169.30 689.47 618.87 6.18 -1.42 5,965,785.31 349,094.94 1.02 5.29 GYD-GC-SS(1) 781.66 3.00 166.33 781.50 710.90 -10.27 452 5,965,781.21 349,095.76 0.87 9.43 GYD-GC-SS(1) 4/38019 9:43:48AM Page 2 COMPASS 5000.14 Build 850 Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well Rig: CD5-24 Project: Western North Slope TVD Reference: CDS-24 actual @ 70.60usft Site: CD5 Alpine West Pad MD Reference: CD5-24 actual @ 70.60usft Well: Rig: CDS-24 North Reference: True Wellbore: CDS-24 Survey Calculation Method: Minimum Curvature Design: CD5-24 Database: OAKEDMPI Survey 4!32019 9:43:4aAM Page 3 COMPASS 5908.14 Build 850 Map Map Vertical MD Inc An TVD NDSS +N/ -S +Ef-W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (G1100') (ft) Survey Tool Name 877.15 4.12 151.22 876.80 80620 -15.95 1.17 5,955,775.50 349,097.34 1.22 15.34 GYD-GC-SS (1) 968.42 4.95 158.80 967.78 897.18 -22.72 3.65 5,965,768.67 349,099.68 0.93 22.55 GYD-GCSS(1) 1,062.72 6.49 159.08 1,061.61 991.01 31.49 7.03 5,965,759.84 349,102.88 1.63 31.95 GYD-GC-SS(1) 1,157.98 7.80 159.14 1,156.13 1,085.53 -42.55 11.25 5,965,748.69 349,106.88 1.38 43.80 GYD-GCSS(1) 1,250.95 10.0 159.05 1,247.97 1,177.37 56.00 16.38 5,965,735.15 349,111.74 2.37 58.18 GYD-GCSS(1) 1,345.17 10.94 158.66 1,340.62 1,270.02 -71.97 22.56 5,965,719.06 349,117.60 1.00 75.30 GYD-GCSS(1) 1,440.07 12.82 158.77 1,433.49 1,362.89 -90.17 29.65 5,965,700.72 349,124.32 198 94.84 GYD-GCSS(1) 1,533.33 14.45 158.55 1,524.12 1,453.52 -110.65 37.66 5,965,680.09 349,131.91 1.75 116.82 GYD-GCSS(1) 1,627.42 16.69 158.59 1,614.75 1,544.15 -134.15 46.88 5,965,656.40 349,140.66 2.38 142.07 GYD-GCSS(1) 1,723.00 19.40 157.74 1,705.62 1,635.02 -161.63 57.91 5,965,628.72 349,151.13 2.85 171.67 GYD-GCSS(1) 1,816.44 20.47 158.16 1,793.46 1,722.86 -191.16 69.86 5,965,598.96 349,162.49 1.16 203.52 GYD-GC-SS(1) 1,909.87 22.06 158.28 1,880.52 1,809.92 -222.62 82.44 5,965,567.25 349,174.43 1.70 237.39 GYD-GCSS(1) 2,004.68 23.46 158.39 1,967.95 1,897.35 -256.71 95.98 5,965,532.90 349,187.28 1.48 274.06 GYD-GCSS(1) 2,097.92 25.35 159.02 2,052.05 1,982.25 -292.61 109.96 5,965,496.73 349,200.54 2.05 312.59 GYD-GC-SS(1) 2,193.19 27.54 159.23 2,138.15 2,067.55 -332.25 125.07 5,965,456.79 349,214.85 2.30 355.01 GYD-GC-SS(1) 2,287.10 29.05 158.54 2,220.04 2,150.24 573.77 141.12 5,965,414.96 349,230.05 1.65 399.52 MWD+IFR-AK-CAZSC(2) 2,381.15 31.85 158.28 2,301.91 2,231.31 418.08 158.66 5,965,370.31 349,246.70 2.98 447.17 MWD+IFR-AK-CAZSC(2) 2,475.75 35.55 156.23 2,380.60 2,310.00 -466.46 178.99 5,965,321.54 349,266.05 4.09 499.61 MWD+IFR-AK-CAZSC(2) 2,568.61 38.40 154.24 2,454.94 2,384.34 517.26 202.46 5,965,270.2B 349,288.49 3.32 655.42 MW13+1FR-AK-CAZSC(2) 2,664.01 40.85 151.33 2,528.27 2,457.67 571.22 230.25 5,965,215.78 349,315.19 3.23 615.71 MWD+IFR-AK-GAZSC(2) 2,758.13 43.14 148.87 2,598.22 2,527.62 525.78 261.66 5,955,160.60 349,345.50 3.00 677.84 MWD+IFR-AK-CAZSC(2) 2,851.35 45.23 147.20 2,665.06 2,594.46 580.88 296.07 5,965,104.82 349,378.79 2.57 741.53 MWD+IFR-AK-CAZSC(2) 2,944.71 47.35 146.38 2,729.57 2,650.97 -737.34 333.03 5,965,047.64 349,414.61 2.36 807.39 MWD+IFR-AK-CAZSC(2) 3,039.00 50.19 145.49 2,791.71 2,721.11 -796.07 372.76 5,964,908.13 349,453.14 3.09 876.35 MWD+IFR-AK-CAZSC(2) 3,133.35 50.78 144.91 2,851.75 2,781.15 555.83 414.30 5,964,927.64 349,493.47 0.78 946.92 MWD+IFR-AK-CAZSC(2) 3,228.87 50.85 145.26 2,912.10 2,841.50 -916.55 456.68 5,964,865.99 349,534.62 0.29 1,018.67 MWD+IFR-AK-CAZSC(2) 3,321.71 50.87 145.89 2,970.70 2,900.10 -975.94 497.38 5,969,805.80 349,574.12 0.53 1,088.60 MWD+IFR-AK-CAZSC(2) 3,416.63 50.28 146.47 3,030.98 2,960.38 -1,036.85 538.19 5,964,744.08 349,613.70 0.78 1,159.99 MWD+IFR-AK-CAZSC(2) 3,510.04 50.32 14610 3,090.65 3,020.05 -1,096.84 577.77 6,964,6B3.31 349,652.06 0.19 1,230.07 MWD+IFR-AK-CAZSC(2) 3,603.31 50.28 146.56 3,150.23 3,079.63 -1,156.7B 617.24 5,964,622.60 349,690.31 0.12 1,300.07 MWDNFR-AK-CAZSC(2) 3,696.15 51.17 146.08 3,210.26 3,139.66 -1,217.87 657.96 5,969,560.71 349,729.79 1.02 1,371.69 MWD+IFR-AK-CAZ-SC (2) 3,792.75 52.69 145.30 3,268.59 3197.99 -1,279.38 699.94 5,964,498.37 349,770.52 1.73 1,443.95 MWD+IFR-AK-CAZSC(2) 3,886.51 53.88 144.57 3,324.65 3,264.05 -1,340.89 743.12 5,964,436.01 349,812.46 1.41 1,516.73 MWD+IFR-AK-CAZ-SC(2) 3,979.40 54.83 144.44 3,378.78 3,308.18 -1,402.35 786.95 5,964,373.69 349,855.04 1.03 1,589.69 MWD+IFR-AK-CAZSC(2) 4,074.40 56.09 143.64 3,43264 3,362.04 -1,465.69 832.91 5,964,309.44 349,899.71 1.50 1,665.15 MWD+IFR-AK-CAZ-SC(2) 4,166.74 57.92 143.72 3,482.93 3,412.33 -1,528.09 878.78 5,964,246.14 349,944.31 1.98 1,739.71 MWD+IFR-AK-CAZ-SC (2) 4,260.53 59.25 143.95 3,531.81 3,461.21 -1,592.70 926.01 5,964,160.59 349,990.23 1.43 1,816.83 MWD+IFR-AK-CA2-SC (2) 4,354.62 60.94 142.96 3,578.72 3,508.12 -1,658.22 974.58 5,964,114.11 350,037.47 2.01 1,895.26 MWD+IFR-AK-CAZ-SC(2) 4,449.20 62.51 141.63 3,623.52 3,552.92 -1,724.11 1,025.52 5,964,047.22 350,087.06 2.07 1,974.87 MWD+IFR-AK-CAZ-SC(2) 4,543.80 62.79 140.72 3,666.99 3,596.39 -1,789.57 1,078.20 5,963,980.72 350,138.43 0.90 2,054.69 MWD+IFR-AK-WSC(2) 4!32019 9:43:4aAM Page 3 COMPASS 5908.14 Build 850 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: CDS-24 Project Western North Slope TVD Reference: CDS-24 actual @ 70.60usft Site: CD5 Alpine West Pad MD Reference: C05-24 actual ® 70.60us0 WON: Rig: CD5-24 North Reference: True Watiboro: CD5-24 Survey Calculation Method: Minimum Curvature Wall CD5-24 Database: OAKEDMPt 4/3/2019 9:43:4aAM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS *W -S +EI -W Northing Easting DLS Section (wft) (') (') Nam (usf) Wait) (MR) (R) IR) (11001 (f" Survey Tool Name 4,637.98 62.98 140.78 3,709.91 3,63931 -1,854.49 1,131.24 5,963,914.75 350,190.15 0.21 2,134.13 MWD+IFR-AK-CAZSC (2) 4,731.94 63.20 141.84 3,752.44 3,681.84 -1,919.89 1,183.61 5,%3,848.32 350,241.19 1.03 2,213.79 MWD+IFR-AK-CAZSC (2) 4,826.43 63.34 142.92 3,794.94 3,724.34 -1.986.73 1,235.13 5,963,780.46 350,291.35 1.03 2,294.50 MWD+IFR-AK-CAZSC(2) 4,921.19 63.38 144.18 3,837.43 3,766.83 -2.054.86 1,285.45 5,963,711.34 350,340.28 1.19 2,375.99 MWD+IFR-AK-CAZSC(2) 5,015.96 63.56 144.50 3,879.76 3,809.16 -2,123.75 1,334.88 5,963,641.47 350,388.32 0.36 2,457.88 MWD+IFR-AK-CAZSC(2) 5,110.19 63.52 144.57 3,921.75 3,851.15 -2,192.46 1,383.82 5,963,571.80 350,435.87 0.08 2,539.42 MW0+IFR-AK-CAZSC(2) 5,203.53 63.45 144.19 3,963.42 3,892.82 -2,260.36 1,432.47 5,963,502.95 350,483.13 0.37 2,620.10 MWD+IFR-AK-CAZSC(2) 5,296.20 63.38 144.79 4,004.89 3,934.29 -2,327.81 1,480.60 5,963,434.54 350,529.90 0.58 2,700.19 MWD+IFR-AK-CAZSC(2) 5,390.12 63.49 144.37 4,046.89 3,976.29 -2.396.27 1,529.29 5,963,365.12 350,577.20 0.42 2,781.42 MWD+IFR-AK-CAZSC(2) 5,484.59 63.35 144.% 4,089.16 4,018.56 -2,465.15 1,578.21 5,963,295.28 350,624.72 0.49 2,8133.11 MWD+IFR-AK-CAZ-SC(2) 5,578.94 63.34 144.30 4,131.49 4,060.89 -2,533.87 1,627.08 5,963,225.60 350,672.20 0.53 2,944.64 MWD+IFR-AK-CAZSC(2) 5,674.11 63.37 143.27 4,174.17 4,103.57 -2,602.50 1,677.34 5,963,155.98 350,721.06 0.97 3,026.58 MWD+IFR-AK-CAZ-SC(2) 5,768.20 63.35 142.12 4,216.36 4,145.76 -2,669.39 1,728.31 5,963,088.08 350.770.67 1.09 3,107.14 MWD+IFR-AK-CAZ-SC(2) 5,862.59 63.55 141.93 4,258.55 4,187.95 -2,735.95 1,780.26 5,%3,020.49 350,821.28 0.28 3,187.73 MWD+IFR-AK-CAZ-SC(2) 5,955.4 63.44 141.86 4,299.81 4,229.21 -2,801.05 1,831.32 5,962,954.39 350,871.01 0.14 3,2613.65 MWD+IFR-AK-CAZ-SC(2) 6,049.97 63.46 141.95 4,342.24 4,271.64 -2,1367.88 1,883.71 5,962,806.52 350,922.04 0.09 3,347.65 MWD+IFR-AK-CAZ-SC (2) 6,144.70 6332 142.98 4,384.67 4,314.07 -2,935.04 1,935.31 5,962,818.34 350,972.28 0.98 3,428.69 MWD+IFR-AK-CAZ-SC(2) 6,238.09 63.46 143.64 4,426.50 4,355.90 .1,002.0 1,905.20 5,962,750.40 351,020.81 0.65 3,5%.92 MWD+IFR-AK-CAZSC (2) 6,333.29 63.37 143.80 4,469.11 4,398.51 3,070.63 2,035.57 5,962,680.78 351,069.79 0.18 3,590.90 MWD+IFR.AK-CAZSC (2) 6,426.70 63.49 144.00 4,510.89 4,440.29 3,138.13 2,064.80 5,962,612.31 351,117.65 0.23 3,671.42 MWD+IFR-AK-CAZSC (2) 6,521.04 63.34 143.58 4,553.11 4,482.51 3,206.20 2,134.64 5,962,543.25 351,166.10 0.43 3,752.68 MWD+IFR-AK-CAZSC (2) 6,615.67 63.39 142.07 4,595.53 4,524.93 3,273.60 2,185.75 5,962,474.85 351,215.84 1.43 3,833.77 MWD+IFR-AK-CAZSC(2) 6,710.06 63.48 141.69 4,637.74 4,567.14 3,340.01 2,237.86 5,962,407.40 351,266.61 0.37 3,914.29 MWD+IFR-AK-CAZSC(2) 6,803.95 63.51 142.31 4,679.65 4,609.05 3,406.22 2,289.59 5,962,340.17 351,316.99 0.59 3,994.48 MWD+IFR-AK-CAZSC(2) 6,89B.34 63.56 142.79 4,721.71 4,651.11 3,473.31 2,340.97 5,962,272.07 351,367.01 0.46 4,075.36 MWD+IFR-AKLAZSC(2) 6,991.% 63.49 142.81 4,763.05 4,692.45 3,539.42 2,391.15 5,962,204.97 351,415.85 0.08 4,154.91 MWD+IFR-AK-CAZSC(2) 7,086.D3 63.45 142.33 4,805.47 4,734.87 3,606.89 2,442.80 5,%2,136.48 351,466.12 0.45 4,236.25 MWD+IFR-AK-CAZSC(2) 7,182.09 63.42 141.69 4,848.43 4,777.83 3,674.60 2,495.68 5,962,067.72 351,517.63 0.60 4,318.25 MWD+IFR-AK-CAZSC(2) 7,275.31 63.45 141.15 4,890.12 4,819.52 -3,739.78 2,547.68 5,962,001.52 351,568.30 0.52 4,397.57 MWD+IFR-AK-CAZSC(2) 7,370.35 63.46 140.26 4,932.59 4,861.99 3,805.58 2,601.52 5,961,934.66 351,620.81 0.84 4,478.12 MWD+IFR-AK-CAZ-SG(2) 7,464.58 63.49 140.62 4,974.67 4,904.07 3,B70.58 2,655.22 5,961,868.59 351,673.19 0.34 4,557.87 MWD+IFR-AK-CAZ-SC(2) 7,559.07 63.56 140.54 5,016.80 4,946.20 3,935.92 2,708.93 5,961,802.19 351,725.57 0.11 4,637.94 MWD+IFR-AK-CAZSC(2) 7,653.86 63.37 140.62 5,059.14 4,988.54 4,001.43 2,762.78 5,961,735.62 351,778.09 0.21 4,718.23 MWD+IFR-AK-CAZ-SC(2) 7,746.93 63.52 140.99 5,100.75 5,030.15 4,%5.95 2,815.39 5,961,670.06 351,829.39 0.39 4,797.15 MWD+IFR-AK-CA2SC(2) 7,841.43 63.35 141.44 5,143.01 5,072.41 4,131.84 2,868.33 5,961603.12 351,880.99 0.46 4,877.46 MWD+IFR-AK-CAZ-SC(2) 7,935.29 63.36 142.34 5,185.11 5,114.51 -0,197.85 2,920.11 5,961,536.09 351,931.43 0.86 4,957.48 MWD+IFR-AK-CAZ-SC(2) 8,029.67 63.46 143.21 5,22235 5,156.75 4,265.5 2,971.16 5,961,467.89 351,981.12 0.83 5,038.36 MWD+IFR-AK-CAZSC(2) 8,121.50 63.32 143.73 5,268.48 5,197.88 4,331.02 3,020.04 5,961,400.95 352.028.65 0.53 5,117.32 MWD+IFR-AK-CAZ-SC(2) 8,216.00 63.39 144.41 5,310.% 5,240.26 4,399.41 3,069.60 5,%1,331.58 352,076.63 0.65 5,198.79 MWD+IFR-AK-CAZSC(2) 8,309.69 63.43 144.53 5,352.80 5,282.20 4,467.60 3,118.29 5,961,262.44 352,124.13 0.12 5,279.75 MWD+IFR-AK-CAZSC(2) 4/3/2019 9:43:4aAM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: C135-24 Project: Western North Slope TVD Reference: CD5-24 actual @ 70.60usft $Ile: CD5 Alpine West Pad MD Reference: CD5-24 actual @ 70.60usft Wal: Rig: CD5-24 North Reference: True Welbore: CD5-24 Survey Calculation Method: Minimum Curvature Design: CDS-24 Database: OAKEDMP7 Survey Map Map vertical MD In AZI TVD TVDSS +N1 -S +E/ -W Northing Easting DLS Section (usft) (1) r) (usft) (usft) (usft) (uslp (ft) (ft) (9100') (ftI Survey Tool Name 8,403.42 63.49 145.10 5,394.68 5,324.08 4,536.13 3,165.60 5,961,192.95 352,171.06 0.55 5,36091 MWD+11FRAK-CAZSC(2) SA97.41 63.48 144.83 5,436.64 5,366.04 4,604.99 3,214.88 5,961,123.14 352,217.94 0.26 5,442.37 MWD+IFR-AK-CAZ-SC(2) 8,589.88 63.59 145.36 5,477.85 5,407.25 4,672.88 3,262.25 5,961,054.32 352,263.93 0.53 5,522.60 MVMAFRAK-CAZ-SC(2) 8,684.21 63.33 145.87 5,520.00 5,449.40 4,742.52 3,309.91 5,960,983.73 352,310.18 0.56 5,604.56 MWD+IFR-AK-CAZ-SC(2) 8,778.46 63.43 145.68 5,562.23 5,491.63 4,812.19 3,357.30 5,960,913.13 352,356.16 0.21 5,686.46 MW13+11FRAK-CAZ-SC(2) 8,873.29 63.48 145.47 5,604.61 5,534.01 4,882.17 3,405.26 5,960,842.21 352,402.70 0.21 5,76B.85 MWD+IFR-AK-CAZ-SC (2) 8,967.47 63.50 145.89 5,646.65 5,576.05 4,951.77 3,452.713 5,960,771.67 352,448.80 0.40 5,850.73 MWD+IFR-AK-CAZ-SC(2) 9,059.38 63.52 146.72 5,687.64 5,617.04 -5,020.21 3,498.41 5,960,702.33 352,493.05 0.81 5,930.85 MWD+IFR-AK-CAZ-SC(2) 9,153.52 63.49 147.02 5,729.64 5,659.04 5,090.77 3,544.46 5,960,630.87 352,537.66 0.29 6,013.12 MWD+IFR-AK-CAZ-SC(2) 9,247.41 63.42 147.49 5,771.60 5,701.0 5,161.41 3,589.89 5,960,559.33 352,581.66 0.45 6,095.24 MWD+IFRAK-CAZ-SC(2) 9,342.66 63.46 147.74 5,814.19 5,743.59 5,233.36 3,635.53 5,960,486.49 352,625.84 0.24 6,176.65 MWD+IFR-AK-CAZ-SC(2) 9,436.91 63.55 147.02 5,856.24 5,785.64 5,304.41 3,681.00 5,96.414.55 352,669.87 0.69 6,261.16 MWD+IFRAK-CAZ-SC(2) 9,531.42 63.44 146.39 5,898.42 5,827.82 5,375.10 3,727.42 5,960,342.94 352,714.86 0.61 6,343.68 MWD+IFR-AK-CAZSC(2) 9,625.77 63.45 145.44 5,940.60 5,870.00 -5,445.00 3,774.72 5,960,272.12 352,760.74 0.90 6,425.75 MWD+IFR-AK-CAZ-SC(2) 9,720.37 63.47 145.44 5,982.87 5,912.27 5,514.69 3,822.73 5,960,201.47 352,807.34 0.02 6,507.90 MWD+IFR-AK-CAZ-SC(2) 9,815.39 63.36 145.07 6,025.39 5,954.79 5,584.51 3,871.16 5,960,130.70 352,854.35 0.37 6,590.30 MWD+IFR-AK-CAZSC(2) 9,908.15 63.59 144.60 6,066.82 5,996.22 5,652.36 3,916.96 5,960,061.91 352,900.77 0.52 6,670.64 MWD+IFRAK-CAZ-SC(2) 10,003.79 63.49 143.43 6,109.43 6,038.83 5,721.64 3,969.26 5,959,991.63 352,949.67 1.10 6,753.20 MWD+IFRAK-CAZSC(2) 10,097.87 63.46 142.32 6,151.45 6,080.85 5,788.76 4,020.07 5,959,923.52 352,999.11 1.06 6,833.92 MWD+1FRAK4;AZSC(2) 10,192.55 63.39 140.73 6,193.81 6,123.21 5,855.05 4,072.75 5,959,856.19 353,050.45 1.50 6,914.51 MWD+IFRAK-CAZSC(2) 10,286.72 63.41 139.93 6,235.97 6,165.37 5,919.86 4,126.50 5,959,790.31 353,102.88 0.76 6,994.11 MWD+IFRAK-0AZSC(2) 10,380.60 63.46 139.96 6,277.96 6,207.36 5,984.13 4,180.54 5,959,724.97 353,155.61 0.06 7,073.30 MWD+IFRAK-CAZSC(2) 10,474.77 63.39 139.75 6,320.09 6,249.49 6,048.51 4,234.84 5,959,659.52 353,208.60 0.21 7,152.66 MWD+IFRAK-CAZSC(2) 10,570.21 63.40 138.50 6,362.83 6,292.23 6,113.03 4,290.68 5,959,593.89 353,263.13 1.17 7,232.74 MWD+IFRAK-CAZSC(2) 10,664.39 63.32 137.71 6,405.06 6,334.46 6,175.70 4,346.89 5,959,530.12 353,318.07 0.75 7,311.19 MWD+IFRAK-CAZSC(2) 10,758.08 63.44 137.93 6,447.04 6,376.44 6,237.77 4,403.13 5,959,466.94 353,373.05 0.25 7,389.09 MWD+IFRAK-CAZSC(2) 10.851.43 63.36 138.10 6,468.84 6,418.24 6,299.81 4,458.97 5,959,403.79 353,427.62 0.18 7,466.83 MWD+IFR-AK-CAZSC(2) 10,944.33 63.39 138.06 6,530.47 6,459.87 6,361.60 4,514.45 5,959,340.89 353,481.85 0.05 7,544.21 MNN+IFR-AK-CAZSC (2) 11,036.71 63.42 138.70 6,571.83 6,501.23 6,423.36 4,569.32 5,959,278.06 353,535.46 0.62 7,621.33 MWD+IFRAK-CAZ6C (2) 11,130.78 63.40 140.21 6,613.93 6,543.33 6,487.28 4,624.00 5,959,213.05 353,588.84 1.44 7,700.42 MWD+IFRAK-CAZSC (2) 11,225.37 63.26 141.86 6,656.39 6,585.79 6,553.00 4,677.15 5,959,146.29 353,640.65 1.57 7,780.65 MWD+IFRAK-CAZSC (2) 11,319.51 63.36 143.76 6,6913.68 6,628.08 6,620.00 4.727.99 5,959,078.28 353,690.13 1.81 7,861.26 MM+IFR-AK-CAZSC (2) 11,413.00 63.40 144.54 6,740.57 6,669.97 6,687.74 4,776.94 5,959,009.57 353,737.71 0.75 7,941.91 MWD+IFRAK-CAZSC (2) 11,507.23 63.39 144.64 6,782.77 6,712.17 4,756.41 4,825.75 5,958,939.9.1 353,755.13 0.10 8,023.37 MWD+IFR-AK-CAZSC (2) 11,601.01 63.43 144.91 6,824.75 6,754.15 6,824.91 4,874.12 5,958,870.48 353,832.11 0.26 8,104.53 MWD+IFR-AK-CAZSC (2) 11,694.70 63.31 145.53 6,866.74 6,796.14 6,893.70 4,921.90 5,958,800.75 353,878.49 0.61 8,185.74 MWD+IFRAK-CAZSC(2) 11,788.60 63.32 147.43 6,908.91 6,838.31 6,963.64 4,968.23 5,958,729.90 353,923.40 1.81 8,267.52 MWD+IFR-AK-CAZSC (2) 11,883.29 63.51 147.85 6,951.29 6,880.69 -7,035.1B 5,013.54 5,958,657.413 353,967.26 0.45 8,350.43 MWD+IFR-AK-CAZSC(2) 11,977.66 63.87 147.06 6,993.12 6,922.52 -7,106.49 5,059.04 5,958,585.27 354,011.32 0.85 8,433.20 MWD+IFR-AK-CAZSC (2) 12,071.41 64.05 147.15 7,033.98 6,963.38 -7,177.34 5,104.87 5,958,513.52 354,055.71 0.62 8,515.65 MWD+IFR-AK-CAZSC(3) 44419 9:43:48AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: CD5-24 Project: Western North Slope TVD Reference: CD5-24 actual Q 70.60usft Site: CD5 Alpine West Pad MD Reference: CD5-24 actual @ 70.60usft Well: Rig: CD5-24 North Reference: True Wellbore: CD5-24 Survey Calculation Method: Minimum Curvature Design: CD5-24 Database: OAKEDMPI 4/&2019 9:43:48AM Page 6 COMPASS 5000.14 Build 85D Map Map Vertical MD Int AZI TVD TVDSS +NI -S +E1 -W Northing Easting DLS Section MOM (1) (') (usfq (usft) (wall) (usR) (It) (11) (°11001 (N) Survey Tool Name 12,165.42 62.99 147.76 7,075.60 7,005.00 -7,248.39 5,150.22 5,958,441.58 354,099.62 1.66 8,598.12 MAD+IFR-AK-CAZ-SC(3) 12,260.29 63.03 147.27 7,118.66 7,048.06 -7,319.70 5,195.62 5,958,369.37 354,143.57 0.46 8,680.86 MWD+IFR-AK-CAZ-SC(3) 12,354.36 62.85 146.29 7,161.45 7,090.85 -7,389.78 5,241.51 5,958,298.39 354,188.05 0.95 8,762.61 MWDAFR-AK-CAZSC(3) 12.48.67 63.11 145.48 7,204.30 7,133.70 -7,459.34 5,288.63 5,958,227.91 354,233.76 0.81 8,844.31 MWD+IFR-AK-CAZSC(3) 12,542.88 63.61 143.49 7,246.54 7,175.94 -7,527.87 5,337.55 5,958,158.41 354,281.28 1.96 8,925.69 MWD+IFR.AK-CAZSC (3) 12,638.34 63.54 142.97 7,289.03 7,218.43 -7,596.35 5,388.72 5,958,088.92 354,331.06 0.49 9,007.80 MWD+IFR-AK-CAZSC (3) 12,732.51 63.42 141.31 7,331.08 7,260.48 -7.662.87 5,440.43 5,958,021.38 354,381.42 1.58 9,088.28 MW0+1FR-AK-CAZSC (3) 1$826.22 64.93 141.08 7,371.90 7,301.30 -7,728.60 5,493.29 5,957,954.60 354,432.95 1.63 9,168.42 MWD+IFR-AK-0AZSC(3) 12,922.38 66.62 140.92 7,411.35 7,340.75 -7,796.75 5,548.48 5,957,885.36 354,48675 1.76 9,251.64 MWD+IFR-AK-CAZSC(3) 13,015.13 68.35 141.39 7,446.87 7,376.27 -7,663.48 5,602.22 5,957,817.57 354,539.13 1.92 9,333.02 MWD+IFR-AK-CAZSC(3) 13,110.90 70.22 140.78 7,480.74 7,410.14 -7,933.17 5,658.49 5,957,746.77 354,593.98 2.04 9,418.07 MWD+IFR-AK-CAZSC(3) 13,205.31 73.24 139.94 7,510.34 7,439.74 5,002.20 5,715.68 5,957,676.61 354,649.77 3.31 9,502.82 MWD+IFR-AK-CAZSC(3) 13.298.67 76.71 141.02 7,534.54 7463.94 5,071.75 5,773.04 5,957,605.93 354,705.72 3.88 9,588.12 MWD+IFR-AK-CAZSC(3) 13,394.32 76.99 140.66 7,556.30 7,485.70 5,144.08 5,831.72 5,957,532.44 354,762.93 0.33 9,676.49 MWD+IFR-AK-CAZSC(4) 13,467.78 78.05 140.56 7,576.49 7,505.89 5,214.71 5,889.49 5,957,460.66 354,819.27 1.18 9,762.94 MWD+IFR-AK-CAZSC(4) 13,581.47 79.90 141.55 7,594.41 7,523.81 5,286.23 5,947.29 5,957,388.00 354,875.61 2.23 9,850.24 MWDAFR-AK-CAZSC(4) 13,675.76 81.13 141.43 7,609.95 7539.35 5,359.01 6,005.20 5,957,314.08 354,932.04 1.31 9,938.75 MWD+IFR-AK-CAZSC(4) 13,769.72 81.11 140.97 7,624.45 7,553.85 5,431.35 6,063.37 5,957,240.59 354,988.74 0.48 10,026.95 MWD+IFR-AK-CAZSC(4) 13,830.96 81.86 142.20 7,633.52 7,562.92 5,478.81 6,101.00 5,957,192.39 355,025.41 2.33 10,084.62 MWDNFR-AK-CAZSC(4) 13,874.38 82.81 141.61 7,639.31 7,56871 5,512.67 6727.55 5,957,158.00 355,051.27 2.57 10,125.67 MWD+IFR-AK-CAZSC(4) 13,970.00 84.94 740.32 7,649.51 7,578.91 5,586.52 6,187.42 5,957,082.98 355,109.64 2.60 10,21587 MWD+IFR-AK-CAZSC(4) 14,065.18 8670 139.41 7,656.45 7,585.85 5,659.09 6,248.61 5,957,009.20 355,169.35 2.08 10,305.34 MWD+IFR-AK-CAZ-SC(4) 14,760.59 87.27 140.81 7,661.47 7,590.87 5,732.19 6,309.71 5,956,934.89 355,228.97 1.58 10,395.29 MWD+IFR-AK-CAZSC(4) 14,254.65 87.79 144.35 7,665.52 7,594.92 5,806.81 6,366.80 5,956,859.14 355,284.65 3.80 10,485.24 MWD+IFR-AK-CAZSC(4) 14,350.44 88.06 145.81 7,668.99 7,598.39 5,885.30 6.421.60 5,956,779.57 355,337.75 1.55 10,578.00 MWD+IFR-AK-CA2SC (4) 14,445.47 88.82 146.26 7,671.58 7,600.98 5,964.09 6,474.67 5,956,699.74 355,389.22 0.93 10,670.43 MWD+IFR-AK-CAZSC(4) 14,540.45 89.41 149.42 7,673.05 7,602.45 41,041.47 6,525.21 5,956618.36 355,438.14 3.38 10,763.47 MWD+IFR-AK-CAZSC(4) 14,635.85 89.44 153.72 7,674.01 7,603.41 41,128.34 6,570.62 5,956,533.60 355,481.84 4.51 10,857.96 MWD+IFR-AK-CAZ-SC(4) 14,730.80 89.13 150.48 7,675.19 7,604.59 -9,212.24 6,615.04 5,955,448.83 355,524.57 3.43 10,952.13 MWD+IFR-AK-CAZSC(4) 14,a25.59 88.82 149.24 7,676.89 7,606.29 41,294.20 6,662.62 5,956,365.94 355,570.49 1.35 11,045.60 MWD+IFR-AK-CAZSC (4) 14,920.59 88.83 146.27 7,678.64 7,608.24 41,374.52 6,713.29 5,956,284.62 355,619.54 3.13 11,138.62 MWD+IFR-AK-CAZSC(4) 15,015.44 88.50 147.35 7,681.04 7,610.44 -9,453.87 6,765.20 5,956,204.25 355,669.83 1.19 11,231.18 MWD+IFR-AK-CAZSC(4) 15,110.96 68.75 147.95 7,683.34 7,612.74 -9,534.55 6,816.30 5,956,122.57 355,719.30 0.68 11,324.68 MWD+IFR-AK-CAZSC(4) 15,206.21 88.81 149.37 7,685.37 7,614.77 -9,615.88 6,865.63 5,956,040.26 355,767.18 1.49 11,418.24 MWD+IFR-AK-CAZSC(4) 15,301.08 89.52 154.39 7,686.75 7,616.15 -9,699.51 6,910.52 5,955,955.75 355,810.18 5.34 11,512.26 MWDAFR-AK-CAZSC(4) 15,400.72 89.50 151.64 7,687.60 7,617.00 -9,788.25 6,955.80 5,955,856.13 355,853.66 2.86 11,611.27 MWD+IFR-AK-CAZ-SC(5) 15,495.94 89.92 151.06 7,688.08 7,617.48 -9,871.77 7,001.53 5,955,781.71 355,897.70 0.67 11,705.54 MWD+IFR-AK-CAZ-SC(5) 15,590.60 89.49 151.22 7.688.57 7,617.97 41,954.68 7,047.22 5,955,697.91 355,941.71 0.48 11,799.23 MWD+IFR.AK-CAZ-SC(5) 15,685.11 89.64 151.41 7,689.29 7,618.69 -10,037.58 7,092.58 5,955,614.12 355,985.39 0.26 11,892.80 MWD+IFR-AK-CAZ-SC(5) 15,780.46 89.46 151.38 7,690.04 7,619.4 -10,121.29 7138.23 5,955,529.51 356,029.35 0.19 11,987.22 MWD+IFR-AK-CAZSC(5) 4/&2019 9:43:48AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: CD5-24 Project: Western North Slope TVD Reference: CD5-24 actual @ 70.60usft Site: CDS Alpine West Pad MD Reference: CD5-24 actual @ 70.60usfl Well: Rig: CD5-24 North Reference: True Wellbore: CD5-24 Survey Calculation Method: Minimum Curvature Design: CD5-24 Database: OAKEDMP7 Survey 4/32019 9:43:48AM Page 7 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +NI5 +E14N Northing Easting DLS Section (farm 0 r) (waft) (usft) Will ("it) Ift) (M ('11001 (fl) Survey Tool Name 15,876.36 89.46 151.03 7,690.94 7,620.34 -10,205.33 7,184.42 5,955,444.57 356,07384 0.36 12,082.15 MWD+IFR-AK-CAZSC(5) 15,970.08 89.75 150.55 7,691.59 7,620.99 -10,287.13 7,230.16 5,955,361.87 356,117.92 0.60 12,174.82 MWD+IFR-AK-CAZSC(5) 16,065.78 89.71 151.20 7,692.04 7,627.4 -10,370.73 7,276.74 5,955,277.36 356,162.80 0.68 12,269.46 MWD+IFR-AK-CAZSC(5) 16,160.63 89.64 150.80 7,692.58 7,621.98 -10,453.69 7,322.72 5,955,193.51 356,207.11 0.43 12,363.30 MWD+IFR-AK-CAZSC(5) 16,255.49 89.3 150.87 7,693.35 7,622.75 -10,536.52 7,368.95 5,955,109,77 356,251.65 0.23 12,457.11 MWD+IFRAK-CAZSC(5) 16,350.44 89.43 151.89 7,694.29 7,623.69 -10,619.86 7,414.42 5,955,025.53 356,295.44 1.07 12,551.13 MWD+IFR-AK-CAZSC(5) 16,445.63 89.68 154.38 7,695.03 7,624.43 -10,704.77 7,457.43 5,954,939.79 356,336.74 2.63 12,645.75 MWD+IFRAK-CAZSC (5) 16,541.74 89.50 155.67 7,695.72 7,625.12 -10,791.89 7,498.01 5,954,851.88 356,375.55 1.36 12,741.58 MWD+IFR-AK-CAZSC(5) 16,635.96 89.61 154.93 7,696.45 7,625.85 -10,877.48 7,537.38 5,954,765.51 356,413.19 0.79 12,835.55 MWD+IFR-AK-CAZSC(5) 16,729.70 89.47 156.49 7,697.20 7,626.60 -10,962.92 7,575.94 5,954,679.32 356,450.02 1.67 12,929.10 MWD+IFR-AK-CAZSC(5) 16,825.69 89.40 159,04 7,698.15 7,627.55 -11,051.76 7,612.26 5,954,589.78 355,484.55 2.66 13,025.04 MWD+IFR-AK-CAZSC(5) 16,920.61 89.61 160.17 7,698.97 7,628.37 -11,140.72 7,845.34 5,954,500.17 356,515.83 1.21 13,119.95 MWD+IFR-AK-CAZ-SC(5) 17,016.61 89.67 160.77 7,699.57 7,628.97 -11,231.20 7,677.43 5,954,409.08 356,546.09 0.63 13,215.93 MWD+IFR-AK-CAZSC (5) 17,110.20 89.74 160.05 7,700.05 7,629.45 -11,319.37 7,708.81 5,95,320.30 356,575.69 0.77 13,309.50 MWD+IFRAK-CAZSC (5) 17,206.14 90.05 159.97 7,700.23 7,629.63 -11,408.53 7,741.60 5,95,229.51 356,606.67 0.33 13,405.44 MWD+IFRAK-CAZSC(5) 17,301.56 90.09 160.23 7,700.11 7,629.51 -11,499.25 7,774.08 5,954,139.16 356,637.33 0.28 13,500.85 MWD+IFRAK-CAZ-SC(5) 17,395.46 89.74 158.91 7,700.25 7,629.65 -11,587.24 7,806.86 5,954,050.53 356,668.33 1.45 13,594.75 MWD+IFRAK-CAZ-SC(6) 17,491.29 89.22 160.40 7,701.12 7,630.52 -11,677.09 7,840.17 5,953,960.4 356,699.83 1.65 13,690.57 MWD+IFRAK-CAZ-SC(5) 17,586.46 89.05 156.09 7,702.56 7,631.96 -11,765.45 7,875.44 5,953,871.00 356,733.31 4.53 13,785.69 MWD+IFRAK-CAZSC(5) 17,680.75 89.51 157.39 7,703.74 7,633.14 -11,852.07 7,912.67 5,953,783.66 356,768.79 1.46 13,879.87 MWD+IFRAK-CA7-SC(5) 17,776.44 89.70 157.17 7,704.40 7,633.80 -11,940.33 7,949.62 5,953,694.68 356,803.96 0.30 13,975.49 MWD+IFRAK-CAZ-SC(5) 17,870.96 87.53 158.59 7,706.69 7,636.09 -12,027.86 7,985.20 5,953,606.45 356,837.T 2.74 14.69.94 MND+IFRAK-CA7-SC (5) 17,966.67 86.67 156.47 7,711.53 7,640.93 -12,116.18 8,021.73 5,953,517.42 356,872.52 2.39 14,165.48 MWD+IFR-AK-CAZ-SC(5) 18,062.69 87.06 156.83 7,716.78 7,646.18 -12,204.21 8,059.73 5,953,428.66 356,908.74 0.55 14,261.24 MWD+IFRAK-CAZ-SC(5) 18,156.89 87.86 155.26 7,720.96 7,650.36 -12,290.21 8,097.94 5,953,341.91 356,945.21 1.87 14,355.19 MWD+IFRAK-CAZ-SC(5) 18,252.27 87.91 164.89 7,724.48 7,653.88 -12,376.64 8,138.11 5,953,254.69 356,983.63 0.39 14,450.24 MND+IFRAK-CAZ-SC(5) 18,345.09 89.10 154.96 7,726.90 7,656.30 -12,60.68 8,177.43 5,953,169.89 357,021,25 1.28 14,542.74 MWD+IFRAK-CAZSC(5) 18,441.65 89.19 153.58 7,728.34 7,657.74 -12,547.67 8,219.35 5,953,082.08 357,061.41 1.43 14,638.92 MWD+IFRAK-CAZSC(5) 18,535.84 89.16 152.44 7,729.70 7,659.10 -12,631.58 8,262.09 5,952,997.34 357,102.45 1.21 14,732.51 MWD+IFR-AK-CAZSC(5) 18,631.54 89.30 151.60 7,730.98 7,660.38 -12,716.09 8,306.98 5,952,911.95 357,145.63 0.89 14,827.41 MWD+IFRAK-CAZSC(5) 18,729.10 89.41 150.20 7,732.08 7,661.48 -12,801.32 8,354.43 5,952,825.78 357,191.35 1.44 14,923.90 MWD+IFR-AK-CAZSC(5) 18,822.59 89.01 152.82 7,733.37 7,662.77 -12683.48 8,399.01 5,952,742.76 357,234.27 2.83 15,016.49 MN4D+IFRAK-CAZSC(5) 18,916.47 89.37 149.91 7,734.70 7,664.10 -12,965.86 8,443.99 5,952,659.50 357,277.59 3.12 15,109.44 MWD+IFRAK-CAZSC(6) 19,010.97 89.16 149.84 7,735.91 7,665.31 43,047,59 8,491.42 5,952,576.84 357,323.35 0.23 15,202.63 MWD+IFR-AK-CAZSC(5) 19,105.03 89.15 148.99 7,737.30 7,666.70 -13,128.55 8,539.27 5,952,494.93 357,369.57 0.90 15,295.27 MWD+IFRAK-CAZSC(6) 19,201.59 89.71 148.60 7,738.26 7,657.66 -13,211.14 8,589.30 5,952,411.36 357,417.92 0.71 15,390.18 MND+IFRAK-CAZSC (5) 19,295.30 89.67 147.38 7,738.76 7,668.16 -13,290.59 8,638.97 5,952,330.93 357,465.98 1.30 15,482.05 MWD+IFRAK-CAZSC(5) 19,391.24 89.96 145.87 7,739.07 7,668.47 -13,370.71 6,691.74 5,952,249.78 357,517.13 1.60 15,575.62 MWD+IFRAK-CAZSC (5) 19,487.36 89.60 145.15 7,739.44 7,668.84 -13,449.93 8,746.17 5,952,169,8 357,569.95 084 15,668.94 MWD+IFRAK-CAZSC (5) 19,583.81 89.71 143.91 7,740.02 7,659.42 -13,528.48 8,802.14 5,952,089.83 357,624.32 1.29 15,762.17 MND+IFRAK-CAZSC (5) 4/32019 9:43:48AM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well Rig: CD5-24 Project: Western North Slope TVD Reference: CD5-24 actual @ 70.60us1t Site: CD5 Alpine West Pad MD Reference: CD5-24 actual @ 70.60usft Well: Rig: CD5-24 North Reference: True Wellbore: CD5-24 Survey Calculation Method: Minimum Curvature Design: CD5-24 Database: OAKEDMPI Survey Map Map Vertical MD Inc AN TVD TVDSS +Nf-S +E/ -W Northing Eating DLS Section (uslt) r) (•) (waft) (usfq (uslq (aft) (ft) (R) P/1001 (R) Survey Tool Name 19,679.03 89.64 143.51 7,740.56 7,669.96 -13,605.23 8,858.50 5,952,011.97 357,679.12 0.43 15,853.85 MWD+IFR-AK-CAZSC(5) 19,774.64 89.57 145.67 7,741.22 7,670.62 -13,683.15 8,913.89 5,951,932.% 357,732.94 2.26 15,946.29 MWD+IFR-AK-CA7SC(5) 19,868.73 89.60 145.23 7,741.90 7,671.30 -13,760.64 8,967.25 5,951,854.41 357,784.72 0.47 16,037.61 MWD+IFR-AK-CAZSC (5) 19,962.95 89.67 144.04 7,742.50 7,671.90 -13,837.47 9,021.78 5,951,776.51 357,837.70 1.27 16,12B.73 MWD+IFR-AK-CAZ-SC (5) 20,059.13 89.71 143.72 7,743.03 7,672.43 -13,915.16 9,078.47 5,951,697.70 357892.81 0.34 16,221.41 MWD+IFR-AK-CAZ-SC (5) 20,153.92 89.50 143.92 7,743.68 7,673.08 -13,991.67 9,134.43 5,951,620.09 357,947.22 0.31 16,312.73 MWD+11FR-AK-CAZSC(5) 20,248.13 89.54 144.25 7,744.47 7,673.87 -04,%7.97 9,189.69 5,951,542.70 358,000.0 0.35 16,403.60 MWD+IFR-AK-CAZSC(5) 20,343.78 89.57 144.61 7,745.21 7,674.61 -04,145.77 9,245.33 5,951,463.80 358,054.99 0.38 16,496.02 MWD+IFR-AK-CAZSC(5) 2,438.49 89.57 146.79 7,745.92 7675.32 -14,224.00 9,298.69 5,951,384.52 358,106.77 2.30 16,588.04 MWD+IFR-AK-CAZSC(5) 20,533.49 89.67 146.70 7,746.55 7,675.95 -14,303.44 9,350.79 5,951,304.05 358,157.25 0.14 16,680.74 MWD+IFR-AK-CAZSC(5) 20,628.30 89.74 147.58 7,747.04 7,676.44 -14,383.8 9,402.23 5,951,223.40 358,207.08 0.93 16,773.39 MWD+IFR.AK-CAZSC(5) 20,722.56 89.60 148.89 7,747.SB 7,676.98 -14,463.22 9,451.85 5,951,142.29 358,255.07 1.40 16,865.87 MWD+IFR-AK-CAZSC(5) 20,818.40 89.43 150.83 7,748.39 7,677.79 -14,546.10 9,499.97 5,951,058.47 358,301.51 2.03 16,%0.39 MWD+IFRAK-CAZSC (5) 20,913.14 89.40 151.49 7,749.36 7,678.76 -14,629.08 9,545.66 5,950,974.59 358,345.53 0.70 17,054.15 MWD+IFRAK-CAZSC (5) 21,O0B.02 89.61 152.04 7,750.18 7,679.58 -14,712.67 9,590.55 5,950,890.13 35B,388.72 0.62 17,148.19 MWD+IFRAK-CAZSC(5) 21,101.66 89.67 152.36 7,750.77 7,680.17 -14,795.50 9,634.22 5,950,806.44 358,430.72 0.35 17,241.10 MWD+IFRAK-CAZ-SC(5) 21,197.61 89.71 154.59 7,751.29 7,680.69 -14,881.34 9,677.07 5,950,719.76 358,471.83 2.32 17,336.53 MWD+IFRAK-CAZ-SC (5) 21,260.86 89.78 153.52 7,751.57 7,680.97 -14,938.22 9,704.74 5,950,062.34 358,4%.33 1.70 17,399.51 MWD+IFRAK-CAZ-SC(6) 21,357.36 89.49 154.22 7,752.19 7,681.59 -15,024.85 9,747.24 5,950,574.88 358,539.09 0.79 17,495.56 MWD+IFRAK-CAZSC (6) 21,451.48 89.57 155.94 7,752.% 7,682.36 -15,110.20 9,786.89 5,950,488.76 358,577.02 1.83 17,589.41 MWD+IFR-AK-CAZSC(6) 21,546.54 89.46 157.19 7,753.76 7,683.16 -15,197.42 9,82470 5,950,400.81 358613.06 1.32 17,684.35 MWD+IFRAK-CAZSC(6) 21,641.79 89.61 157.23 7,754.53 7,683.6 -15,285.23 9,861.59 5,950,312.28 358,648.18 0.16 17,779.53 MWD+IFRAK-CAZSC(6) 21,735.59 89.11 157.54 7,755.58 7,684.98 -15,371.81 9,897.66 5,950,224.99 358,682.50 0.63 17,873.27 MW[)AFRAK-CAZSC(6) 21,832.06 89.08 155.28 7,757.11 7,686.51 -15,460.20 9,936.26 5,950,135.85 358,719.31 2.34 17,969.59 MWD+IFR-AK-CAZSC(6) 21,925.73 89.11 154.63 7,758.59 7,687.99 -15,545.05 9,975.91 5,950,050.23 358,757.24 0.69 18.WZ97 MWD+IFRAK-CAZSC(6) 22,020.43 89.61 155.71 7,759.64 7,689.04 -15,630.99 10,015.67 5,999,%3.51 358,795.27 1.26 18,157.41 MWD+IFR-AK-CAZSC (6) 22,116.25 89.42 156.78 7,760.45 7,689.85 -15,718.69 10,054.27 5,949,875.06 358,832.09 1.13 18,253.0 MWD+IFR-AK-CAZ-SC (6) 22,210.73 89.57 154.05 7,761.29 7,690.69 -15,804.59 10,093.57 5,949,788.39 358,869.66 2.89 18,347.32 MWD+IFRAK-CAZ-SC(6) 22,305.89 89.57 152.32 7,762.00 7,691.40 -15,889.51 10,136.49 5,949,702.63 358,910.86 1.82 18,441.92 MWD+IFRAK43AZ-SC(6) 22,400.55 89.53 152.87 7,762.75 7,692.15 -15,973.55 10,180.06 5,949,617.75 358,952.73 0.58 18,535.92 MWD+IFRAK-CAZSC(6) 22,4%.00 89.53 152.W 7,763.53 7,692.93 -16,058.35 10,223.86 5,949,532.50 358,994.81 0.39 18,630.72 MWD+IFRAK-CAZSC(6) 22,591.71 89.64 151.79 7,764.22 7,693.62 -16,142.97 10,268.58 5,949,446.59 359,037.82 0.75 18,725.66 MWD+IFRAK-CAZSC(6) 22,686.15 89.39 151.57 7,765.02 7,694.42 -16,2 AD 10,313.38 5,949,362.58 359,080.94 0.35 18,819.25 MWD+IFRAK-CAZSC(6) 22,780.44 89.54 151.70 7,785.90 7,695.30 -16,309.07 10,358.17 5,949,278.74 359,124.05 0.21 18,912.68 MWD+IFRAK-CAZSC(6) 22,876.09 88.90 150.% 7,767.20 7,6%.60 -16,392.98 10,404.06 5,949,193.93 359,168.24 1.02 19,007.38 MWD+IFRAK-CAZSC(6) 22,971.00 89.16 150.43 7,768.81 7,698.21 -16,475.73 10,450.50 5,949,110.26 359,213.01 0.62 19,101.19 MWD+IFRAK-CAZSC(6) 23,066.08 89.08 151.57 7,770.27 7,699.67 -16,55B.B8 10,496.59 5,949,026.21 359,257.41 1.20 19,195.24 MWDAFRAK-CAZSC (6) 23,161.41 89.OB 152.55 7,771.W 7,701.20 -16,643.09 10,541.25 5,948,941.13 359,300.37 1.03 19,289.78 MWD+IFRAK-CAZSC(6) 23,255.68 89.23 151.41 7,773.19 7,702.59 -16,726.30 10,585.54 5,948,857.06 359,342.97 1.22 19.383.26 MWD+IFRAK-CAZ-SC (6) 23,349.99 88.57 151.71 7,775.00 7,704.40 -16,809.21 10,630.44 5,948,773.26 359,386.19 0.77 19,476.68 MWD+IFRAK-CAZ-SC(6) 4I3M19 9.43.48AM Page 0 COMPASS 5000.14 Build SSD ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: CD5-24 Project: Western North Slope TVD Reference: CD5-24 actual @ 70.60usft Site: CDS Alpine West Pad MD Reference: CDS-24 actual @ 70.60usft Well: Rig: CDS-24 North Reference: Tme We(lbore: CDS-24 Survey Calculation Method: Minimum Curvature Design: CD5-24 Database: OAKEDMP1 Survey 4OW19 9:43:48AM Page 9 COMPASS 5000.14 Build 85D Map Map Vertical t0D Inc Asti TVD TVDSS +•NIS aFJ-W Northing Eastllg DLS Section Wall) (') (1) (usft) (usft) (ualt) (usl) ((t) (ft) ('11001 (ft) Survey Tool Name 23,444.78 88.42 152.80 7,777.49 7,706.89 -16,893.07 10,674.55 5,94$688.54 359,428.61 1.16 19,570.70 MWD+IFR-AK-CAZSC (6) 23,54000 89.16 154.46 7,779.50 7,708.90 -16,978.36 10,716.84 5,948,602.42 359,469.16 1.91 19,665.42 MWD+IFR-AK-CAZSC (6) 23,634.50 89.08 153.76 7,780.95 7,710.35 -17,063.37 10,758.09 5,948,516.61 359,508.70 0.75 19,759.51 MWD+IFRAK-CAZ-SC (6) 23,729.50 89.32 151.48 7,782.28 7,711.68 -17,147.71 10,801.78 5,948,431.41 359,550.68 2.41 19,853.83 MWD+IFRAK-CAZ-SC (6) 23,824.55 89.60 151.75 7,783.18 7,712.58 -17,231.33 10,846.96 5,948,346.91 359,594.17 0.41 19,948.01 MWD+IFRAK-CAZSC (6) 23,919.65 89.63 153.77 7,783.82 7,713.22 -17,315.88 10,890.49 5,948,261.51 359,635.98 2.12 2,042.47 MWD+IFR-AK-CAZ-SC (6) 24,014.76 89.71 155.92 7,784.36 7,713.76 47,401.96 10,930.91 5,948,174.64 359,674.67 2.26 20,137.28 MWD+IFRAK-CAZSC (6) 24,108.58 89.43 155.83 7,785.07 7,714.47 -17,487.58 10,969.26 5,94a,088.27 359,711.28 0.31 20,230.92 MWD+IFR-AK-CAZSC (6) 24,205.08 89.26 154.47 7,786.17 7,715.57 -17,575.14 11,009.81 5,947,999.92 359,750.W 1.42 20,327.15 MWD+IFRAK-CAZSC (6) 24,300.04 88.98 154.95 7,787.63 7,717.0 -17,660.99 11,050.37 5,947,913.28 359,788.89 0.59 20,421.78 MWD+IFR-AK-CAZSC(6) 24,395.37 89.19 155.28 7,789.15 7,718.55 -17,747.46 11,090.48 5,947,826.03 359,827.25 0.41 20,516.84 MWD+IFRAK-CAZSC(6) 24,490.28 89.50 155.18 7,790.24 7,719.64 -17,833.63 11,130.24 5,947,739.09 359,%5.27 0.34 20,611.49 MMIFRAK-CAZSC(6) 24,5a5.05 89.42 154.92 7,791.13 7,720.53 -17,919.55 11,170.22 5,947,652.38 359,90.50 0.29 20,705.99 MWD+IFRAK-CAZSC(6) 24,679.67 89.64 154.53 7,791.91 7,721.31 -18,005.11 11,210.61 5,947,566.04 359,942.17 0.47 20,800.30 MWD+IFR-AK-CAZSC(6) 24,774.60 89.50 152.87 7,792.62 7,722.02 -18,090.21 11,252.67 5,947,480.12 359,982.51 1.75 20,894.76 MWD+IFRAK-CAZSC(6) 24,869.48 89.39 150.69 7,793.54 7,722.94 -18,173.80 11,297.53 5,947,395.65 360,025.68 2.30 20,988.79 MWD+IFR-AK-CAZSC(6) 24,04.36 89.64 151.55 7,794.34 7,723.74 -18,256.88 11,343.35 5,947,311.67 360,069.82 0.94 21,082.69 MWD+IFRAK-CAZSC(6) 25,059.19 89.56 151.38 7,795.00 7,724.40 -18,390.18 11,388.65 5,947,22248 360,113.43 0.20 21,176.61 MWD+IFRAK-CAZSC(6) 25,164.94 89.64 151.41 7,795.67 7,725.07 -18,424.25 11,434.49 5,947,142.52 360,157.57 0.09 21,271.44 MWD+IFRAK-CAZSC(6) 25,249.76 89.01 151.31 7,796.79 7,726.19 -18,507.46 11,479.94 5,947,058.41 360,201.33 0.67 21,365.32 MWD+IFR-AK-CAZSC(6) 25,341.76 89.15 150.73 7,798.31 7,727.71 -18,590.55 11,525.0 5,946,974.42 360,245.67 0.63 21,459.30 MWD+IFRAK-CAZSC(6) 25,439.89 89.19 147.75 7,799.69 7,729.9 -18,672.28 11,574.60 5,946,891.73 36,292.65 3.13 21,552.93 MWD+IFRAK-CAZSC(6) 25,538.08 89.26 148.27 7,801.02 7,730.42 -18,755.55 11,626.62 5,946,807.44 360,342.98 0.53 21,649.19 MWD+IFR-AK-CAZSC(6) 25,632.87 88.97 149.91 7,802.48 7,731.88 -18,836.87 11,675.30 5,946,725.17 36,390.02 1.76 21,742.44 MWD+IFR-AK-CAZSC(6) 25,727.62 89.43 152.11 7,803.81 7,733.21 -18,919.73 11,721.21 5,946,641.41 360,434.25 2.37 21,836.17 MWD+IFR-AK-CAZSC(6) 25,822.15 89.74 153.63 7,804.49 7,733.89 -19,W3.86 11,764.32 5,948,556.44 36,475.65 1.64 21,930.08 MWD+IFR-AK-CAZSC(6) 25,916.99 89.67 153.08 704.98 7,734.38 -19,088.62 11,806.85 5,946,470.84 360,516.47 0.58 22,024.40 MWD+IFR-AK-CAZ-SC(6) 26,012.31 89.67 152.52 7,005.53 7,734.93 -19,173.40 11,850.42 5,946,385.21 360,558.32 0.59 22,119.09 MWD+IFRAK-CAZSC(6) 26,106.58 89.64 154.85 7,806.10 7,735.50 -19,257.89 11,892.21 5,946,299.90 360,598.40 2.47 22,212.89 MWD+IFRAK-CAZSC(6) 26,201.02 89.36 156.93 7,806.92 7,736.32 -19,344.09 11,93078 5,946,212.0 360.635.23 2.22 22,307.15 MWD+IFR-AK-CAZSC(6) 26,297.39 89.15 157.63 7,808.17 7,737.57 -19,432.97 11,968.00 5,946,123.35 360,670.65 0.76 22,403.44 MWD+IFR-AK-CAZSC(6) 26,392.14 89.04 157.41 7,809.67 7,739.07 -19,520.51 12,004.22 5,946,035.11 360,705.11 0.26 22,498.13 MWD+IFRAK-CAZSC(6) 25,487.31 89.53 157.75 7,810.86 7,740.26 -19,608.48 12,040.52 5,945,946.43 360,739.62 0.63 22,593.25 MWD+IFRAK-CAZSC(6) 26,582.47 89.67 155.63 7,811.52 7,740.92 -19,60.86 12,078.17 5,945858.31 360,775.51 2.23 22,688.30 MWD+IFRAK-CAZSC(6) 26,676.52 89.53 154.12 7,812.18 7,741.58 -19,781.01 12,118.10 5,945,772.39 360,813.72 1.61 22,782.05 MWD+IFR-AK-CAZSC(6) 26,771.91 89.47 152.10 7,813.01 7,742.41 -19,80.08 12,161.24 5,945,686.48 360,855.14 2.12 22,876.86 MWD+IFRAK-CAZSC(6) 26,867.76 88.90 150.68 7,814.38 7,743.78 -19,950.23 12,207.14 5,945,601.42 %0,899.33 1.60 22,97179 MWD+IFR-AK-CAZSC(6) 26,03.29 89.44 146.61 7,815.76 7,745.16 -20,031.77 12,256.82 5,945,518.91 380,947.% 4.30 23,065.60 MWD+IFRAK-CAZSC(6) 27,058.26 89.54 147.35 7,816.61 7,746.01 -20,111.41 12,30.58 5,945,438.25 360,997.51 0.79 23,158.38 MWD+IFRAK-CAZSC(6) 27,153.0 89.16 148.30 7,817.69 7,747.09 -20,192.39 12,359.53 5,945,356.27 361,046.81 1.07 23,252.11 MWD+IFRAK-CAZSC(6) 4OW19 9:43:48AM Page 9 COMPASS 5000.14 Build 85D Conocoftillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: CD5-24 Project: Western North Slope TVD Reference: CDS-24 actual @ 70.60usft Site: CD5 Alpine West Pad MD Reference: CDS-24 actual @ 70.60usft Well: Rig: CDS-24 North Reference: True Wellbore: CD5-24 Survey Calculation Method: Minimum Curvature Design: CD5-24 Database: OAKEDMPI Survey Map Map Vertical MD Inc As! TVD TVDSS +WS +E1 -W Northing Easting DLS Section (URM (') 1°) (weft) Wall) (usft) (uefq (M (ft) (°1100•) (ft) Survey Tool Name 27,248.35 88.52 14263 7,819.60 7,749.00 -20,272.40 12,409.59 5,945,275.28 361,905.25 0.98 23,344.63 MWD+IFR-AK-CAZ-SC(6) 27,343.23 89.09 149.68 7,821.56 7,750.98 -20,353.40 12,468.93 5,945,193.31 361,142.95 2.24 23,437.82 MWD+IFR-AK-CAZ-SC(6) 27,438.51 89.37 145.65 7,822.85 7,752.26 -20,434.33 12,509.18 5,945,111.39 361,191.56 3.19 23,531.26 MWD+IFR-AK-CAZSC(6) 27,533.52 89.26 147.76 7,824.00 7,753.40 -20,514.19 12,560.63 5,945,030.52 361,241.39 1.17 23,624.13 MWD+IFR-AK-CAZ-SC (6) 27,629.09 89.16 150.33 7,825.32 7,754.72 -20,596.13 12,609.78 5,944,947.61 361,288.88 2.69 23,718.14 MWD+IFR-AK-CAZ-SC (6) 27,724.53 88.90 152.37 7,826.93 7,756.33 -20,679.87 12,655.53 5,944862.97 361,332.94 2.15 23,812.62 MWD+IFR-AKLAZSC(6) 27,819.52 89.86 154.87 7,827.96 7,757,36 -20,764.96 12,697.73 5,944,777.06 361,37342 2.82 23,907.12 MWD+IFR-AK-CAZSC(6) 27,914.51 89.50 153.76 7,828.49 7,757.89 -20,850.56 12,738.90 5,944,690.66 361,412.85 1.23 24,001.74 MWD+IFR-AK-CAZSC(6) 28,009.91 89.31 152.90 7,829.48 7,758,88 -20,935.80 12,781.72 5,944,604.58 361,453.95 0.92 24,096.60 MWD+IFR-AK-CAZSC (6) 28,105.04 90.19 152.37 7,829.90 7,759.30 -21,020.29 12,825.44 5,944,519.24 %1,495.96 1.08 24,191D7 MWD+IFR-AK-CAZSC(6) 28,200.52 90.11 152.96 7,829.65 7,759.05 -21,105.11 12,869.29 5,944,433.56 361,538.09 0.62 24,285.90 MWD+IFR-AK-CAZSC(6) 28,296.63 90.22 153.35 7,829.37 7,758.77 -21,190.86 12,912.68 5,944,346.96 361,579.75 0.43 24,381.45 MWD+IFR-AK-CAZSC(6) 28,392.39 89.84 152.91 7,829.32 7,758.72 -21,276.29 12,955.95 5,944,260.69 361,621.29 0.62 24,476.64 MWD+1FR-AK-CAZSC(6) 28,488.04 89.24 153.73 7,830.09 7,759.49 -21,361.75 12,998.90 5,944,174.39 361,662.51 1.06 24,571.75 MWD+IFR-AK-CAZSC(6) 28,583.05 89.61 154.17 7,831.04 7,760.44 -21,447.10 13,040.62 5,944,088.22 361,702.50 0.61 24,&66.33 MWD+IFR-AK-CAZSC(6) 28,678.43 89.32 154.25 7,831.93 7,761.33 -21,532.98 13,082.12 5,944,001.53 361,742.26 0.32 24,761.32 MWD+IFR-AK-CAZSC(6) 28,774.02 89.15 150.62 7,833.21 7,762.61 -21,617.69 13,126.34 5,943,915.95 361784.77 3.80 24,855.19 MWD+IFR-AK-CAZ-SC(6) 28,%9.88 89.09 148.58 7,834.68 7,764.08 -21,700.36 13,174.84 5,943,832.33 361,831.60 2.13 24,950.64 MWD+IFR-AK-CAZSC(6) 28,964.10 88.62 150.00 7,836.56 7,765.96 -21,781.35 13,222.95 5,943,750.40 361,878.06 1.59 25,043.38 MWD+IFR-AK-CAZ-SC(6) 29.060.21 89.40 150.22 7,838.22 7,767.62 -21,864.66 13270.83 5,943,666.15 361,924.26 0.84 25,138.23 MWD+IFR-AK-CAZ-SC (6) 29,154.49 89.26 151.60 7,839.33 7,768.73 -21,947.04 13,316.67 5,943,582.87 361,968.43 1.47 25,231.47 MWD+IFR-AK-CAZSC (6) 29,250.66 89.22 153.62 7,840.60 7,770.00 -22,032.42 13,360.90 5,943,496.63 362,010.94 2.10 25,326.96 MWD+IFR-AK-CAZ-SC(6) 29,345.66 89.08 156.19 7,842.01 7,771.41 -22,118.43 13,401.19 5,943,409.83 362,049.48 2.71 25,421.65 MWD+IFR-AK-CAZSC(6) 29,440.43 89.36 156.89 7,843.30 7,772.70 -22,205.36 13,438.91 5,943,322.16 362,085.45 0.80 25,516.30 MWD+IFR-AK-CAZSC (6) 29,536.71 89.25 156.01 7,844.47 7,773.87 -22,293.62 13,477.38 5,943,233.16 362,122.13 0.92 25,612.44 MWD+IFR-AK-CAZ4C(6) 29,632.82 89.71 161.05 7,845.34 7,774.74 -22,383.02 13,512.54 5,943,143.07 362,155.49 5.27 25,708.51 MWD+IFR-AK-CAZSC(6) 29,727.42 89.67 158.71 7,845.85 7,775.25 -22,471.84 13,545.08 5,943,053.62 362,186.23 2.47 25,803.10 MWD+IFR-AK-CAZSC(6) 29,822.94 89.74 156.03 7,846.35 7,775.75 -22,560.00 13,581.83 5,942,964]5 362,221.20 2.81 25,898.55 MW13+1FR-AK-CAZSC(6) 29,918.03 89.53 154.17 7,846.95 7,776.35 -22,646.24 13,621.86 5,942,877.73 362,259.49 1.97 25,993.37 MWD+IFR-AK-CAZSC(6) 3.013.25 89.W 150.25 7,847.67 7,777.07 -22,730.46 13,666.25 5,942,792.64 362,302.17 4.12 26,087.82 MWD+IFR-AKLAZSC(6) 3.108.30 89.50 147.33 7,848.42 7,777.82 -22,811.75 13,715.50 5,942,710.39 362,349.77 3.07 26,181.24 MWD+IFR-AK-CAZ-SC(6) 30,201.68 89.43 144.57 7,849.29 7,778.69 -22,889.10 13,767.77 5,942,632.W 352,400.48 2.96 26,272.06 MWD+IFR-AK-CAZSC(6) 30,298.15 89.53 143.34 7,850.17 7,779.57 -22,967.10 13,824.53 5,942,552.88 362,455.65 1.28 25365.06 MWD+IFR-AK-CAZSC(6) 30,392.80 89.74 143.22 7,850.77 7,780.17 -23,042.97 13,881.12 5,942,475.90 362,510.70 0.26 26,455.99 MWDAFR-AK-CAZSC(6) 30,487.69 89.60 146.53 7,851.32 7,780.72 -23,120.57 13,935.71 5,942,397.23 362,563.72 3.49 25647.85 MWD+IFR-AK-CAZ-SC (6) 30,582.20 89.35 149.99 7,852.18 7,781.58 -23,200.90 13,985,46 5,942,315.91 362,611.83 3.62 26,640.55 MWD+1FR-AK-CAZ-SC (6) 30,677.19 89.61 152.11 7,853.05 7,78245 -23,284.00 14,031.47 5,942,231.92 352,656.16 2.30 25734.54 MWD+IFR-AK-CAZ-SC (6) 30,773.71 88.79 153.35 7,854.39 7,783.79 -23,369.78 14,075.69 5,942,145.27 362,698.64 1.54 25830.40 MWD+IFR-AK-CAZ-SC (6) 30,869.26 89.61 154.71 7,855.73 7,785.13 -23,455.67 14,117.52 5,942,058.56 362,738.74 1.W 26,925.52 MWD+1FR-AK-CAZ-SC (6) 30,964.31 89.63 154.67 7,856.36 7,785.76 -23,541.59 14,158.16 5,941,971.85 362,777.64 0.05 27,020.25 MWD+1FR-AK-CAZ-SC (6) 4WO19 9:43:484M Page 10 COMPASS 5000.14 Build 85D Company: NADConversion Project Western North Slope Site: CD5 Alpine West Pad Wen: Rig: C05-24 Wellbore: CD5-24 Design: CDS-24 Survey ConocoPhillips Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: CD5-24 CD5-24 actual ® 70.60usft CDS-24 actual ® 70.60usft True Minimum Curvature OAKEDMP1 4/32019 9'43:48AM Page 11 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Azl TVD TVDSS +WS +E1 -W Northing Seating OLS Section Nam (') P) (waft) (usft) 1a) (usft) (1q (to (/100') (ft) Survey Tool Name 31,040.00 89.63 154.67 7,856.85 7,786.25 -23,610,00 14,190.54 5,941,902.60 362,808.64 0.00 27,095.68 PROJECTEDto TD 4/32019 9'43:48AM Page 11 COMPASS 5000.14 Build 850 a Cement Detail Report C D5-24 String: Conductor Cement Job: DRILLING ORIGINAL, 2/14/2019 00:00 Cement Details DescriptionCementing Conductor Cement Start Date 2/17/2018 14:00 Cementing End Date 2/17/2018 16:00 Wellbore Name CD5-24 Comment Cement Stages Stage S 1 Description Conductor Cement Objective Cement Conductor Top Depth (ftKB) 36.9 Bottom Depth (ftKB) 115.0 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bblim... O Pump Final (bbil... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft /sack) Mia H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 712/2019 a Cement Detail Report CD5-24 String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/14/2019 00:00 Cement Details Description Surface Casing Cement Cementing Start Date 2/19/2019 20:15 Cementing End Date 2/20/2019 00:24 Wellbore Name CD5-24 Comment Cement Stages Stage 01 Description Surface Casing Cement I Objective Top Depth (ftKB) Cement Surface Casing 37.5 Bottom Depth (ftKB) 2,234.5 Full Return? Yes Vol Cement... 225.0 Top Plug? Yes Bun Plug? Yes Q Pump Init (bbllm... 8 Q Pump Final (bbl/... 3 Q Pump Avg (bbll... 6 P Pump Final (psi) 500.0 P Plug Bump (psi) 1,061 Recip? Yes Stroke (1t) Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Dowell pump 3 bbls H2O & PT to 250/3500 psi (good). Dowell pump 75 bbls 10.5ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 396 bits 11.0 ppg 1.95113/ax yield LiteCRETE lead cement and 85 bbls 15.8 ppg 1.16 1113/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 185 bbis / 1847 stks 10 ppg DrillPlex with 8 bpm / 750 psi. Reduce pumps to 3 bpm / 460 psi. last 10 bbis. Bump plug, pressure 500 psi over to 1060 psi for 5 min. Check floats. F/C good. CIP @ 00:24 Hrs. Calculate 225 bbls good cement to surface. Full returns during cement job. Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 37.5 Est Btm (ftKB) 1,735.0 Amount (sacks) 1,140 Class B Volume Pumped (bbl) 395.0 Yield (itrlsack) 1.91 Mix H2O Ratio (gallsa... 6.82 Free Water (%) Density (Ib/gal) 11.00 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,735.0 Est Bum (ftKB) 2,234.5 Amount (sacks)Class 411 G Volume Pumped (bbl) 85.0 Yield (R'/sack) 1.16 Mix H2O Ratio (gal/sa... 5.13 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 7/2/2019 Cement Detail Report a CD5-24 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 2/14/201900:00 Cement Details DescriptionCementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 3/5/2019 04:00 3/5/2019 07:45 CD5-24 Comment Dowell pump 1.2 bbls H2O & PT to 4500 psi (good). Dowell pump 60 bbls 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 110 bbls 13.0 ppg 1.97 ft3/sx yield Class G lead Cement and 130 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 4.5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 605 bbls (6,050 silks @ 95%) 10.6 ppg LSND with 7 bpm 1180 - 800 psi. Reduce pumps to 4 bpm 1760 psi. last 60 bbls. Reduce pumps to 2 bpm / 750 psi. last 60 bbls. Bump plug, pressure up to 1100 psi for 5 min. Check floats. F/C good. CIP @ 07:45 His. Full returns dudng cement job. 10.6ppg inlout Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom DePt h (ftKB) Full Ra rn? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 10,362.0 12,170.0 Yes Yes Yes Cement Lead 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) 7 2 5 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks)Class Volume Pumped (bbl) Intermediate Cement 10,362.0 12,170.0 313 G 110.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water I%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.97 10. 1 13.00 129 6 Additives Additive Type Concentration Cone Unit label Stage # 2 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full RetUrn Vol Cement... Top Plug? elm Plug? Intermediate Casing Isolate 500' MD above 12,170.0 13,882.1 Yes Yes Yes Cement Tail Kuparuk C Q Pump Init (bblim... Q Pump Final (bbl/... Q Pump Avg (bbl/...P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 2 5 750.0 1,100.0 Yes No Tagged Depth IRKS) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 12,170.0 13,882.1 634 g 130.0 Yield (ft'/sack) Mix H2O Ratio instills... Free Water (°h) Density (Iblgai) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.09 1 15.8( Additives Additive Type Concentration Cone Unit label Stage # 3 Description Objective Top Depth (ftKB) Bottom Depth (NKB) Full Return? Vol Cement... Top Plug? Btm Plug? Upper intermediate Isolate 500' MD above 4,761.0 5,761.0 Yes Yes No Casing cement Lead Qannik Q Pump Wt (bbUm... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (Psi) Recip? Stroke (To Rotated? Pipe RPM (rpm) 3 2 4 160.0 1,990.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 4,761.0 5,761.0 224 G 73.0 Yield (ft'/sack) Mix H2O Ratio (gal/aa... Free Water (%) Density (Iblgal) Plastic Viscosity (cPi Thickening Time (hr) CmprStr 1 (psi) 1.84 6.47 11.20 282.0 Additives Additive Type Concentration Cone Unit label Page try Report Printed: 71212019 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Adam Klem Completions Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-24 Permit to Drill Number: 219-006 Sundry Number: 319-239 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. a ogc c.o laska.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, Daniel T. Seamount, Jr. Commissioner vo- DATED thi_ day of May, 2019. RBDMS,=� MAY 2 2 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS on A An nc 1en RECEIVED MAY 0 9 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Repair Well ❑ Operations s6ldown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll El Perforate New Pool [:1 Re-enter Susp Well E] Alter Casing El Other, ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ lment Q• 219-006 3. Address: ❑ 6. API Number: Stratigrephic ❑ ;Seemice" P. O.Box 100360, Anchorage, Alaska 99510 50-103-20799-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CRU CD5-24 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ASRC-NPR4, ASRC-NPR2, ASRC-NPR5, ASRC-AA092344 Colville River Unit, Alpine Pool ' 11. PRESENT WELL CONDITION SUMMARY To>IpgRth _ ftT7otat Depth ND (8):e�cyi�e 0th MD: EffeQc,tiyyvgg Depth ND: MPSP (psi): �3 Plugs (MD): Junk (MD): Casing ,i ,/4 Length Size MD /Is S-, Burst Collapse Structural Conductor 78' 20 115' 115, Surface 2197' 103/4"2174' Intermediate 13,848' 7 5/8" 13,882' 7,640' Production Liner 7,999' 4 1/2" Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4 1/2" & 3 1/2" s r!, L80 est 13,700' Packers and SSSV Type: Packers and SSSV MD Baker Premier Packer,Halliburton TNT Packer no SSSV est 13,052'& 13,622' MD no SSSV 12. Attachments: Proposal Summary ❑ Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/27/2019 OIL WINJ ❑ WDSPL ❑ ❑ Suspended 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 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. Contact Adam Klem, 907-263-4529 Email adam.klem@ConocoPhilliDs.com Printed Name Adam em Title Completions Engineer / /—O//l Signature Phone 907-263-4529 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No E� Spacing Exception Required? Yes No REI MS ❑ Subsequent Form Required: MAY 2 2 2019 Approved by: Lzz�� APPROVED BY / / COMMISSIONER THE COMMISSION Date: US 61 u I [a �wForms1,0-4,0�3 /Revised 11/2015 Appr vedplir o f�L date of approval.7� Opao vM Submit Form and Attachments in Duplicate 5 i�/9 CD5 - 24 Alpine A/C Dual Lateral Producer Proposed Schematic Premier Packer at 13,000 MD HP Sliding sleeve for Selectivity 13,041' MD 20" 94# H-40 Welded Conductor to 115' MD 10-3/4" 45.5# L-80 HYD 563 x BTC Surface Casing at Z,25-3TMD ' D � 4-'/"x1"GLM �tc'�/ 4-1/2" 12.6# L-80 TSBIue 4-%" x 1" GLM 7 5/8" 29.79 L-80 Hyd 563 x BTC Intermediate Casing at 13,898` MD Upper Completion: 1) 4'/:"-12.6# TSBIue tubing 2) Shallow nipple profile 3.813" ID 3) 4-'/" x 1" Camco KBMG GLM (xx°) w/DCK2 pinned for 2500 psi casing to tbg shear 4) Premier Packer 5) X Nipple profile, 2.813" 6) TNT Packer 7) X Nipple profile, 2.813" Lower Completion: 8) Plop and drop liner in C sand - no junction -4.5" 12.6# L-80 w/ perf pups 9) ZXP liner top packer & Flexlock Liner Hanger XO 5" Hydril 521 Box X 4-'/" H563 pin -4.5" Hydril563 12.6# L-80 w/ Frac Ports C sand Lateral 4-'/" x 1" GLM 6 3/4" Hole TD 13,332'- 27,266' MD 4'/]' 12.6# L-80 TXP Liner w/ perf pups 0 0 0 0 0 0 0 010 4-%" 12.6# L-80 Hyd563 Liner w/ frac ports to —26,650' 3-1/2" 9.3# TNI 1OSS TNT Production Packer 2/' off 0 S`` A sand Lateral at 6 3/4" Hole TD 13,665' MD ZXP liner top packer (whipstock 13,898'— 35,630' MD base) at 13,748' 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 r._ASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Jason E. Lyons Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD5-24 Well ) under the Provisions ) of 20 AAC 25.280 ) STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) herein. Jason E. Lyons, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Jason E. Lyons. I am over 19 years old and have personal knowledge of the matters set forth 2. 1 am Staff 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 May 8, 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 8th day of May, 2019. dl_r� aso Lyons STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 8th day of May, 2019, by Jason E. Lyons. .Q<GcL i c, rNotary Public, State of AlaskY My Commission Expires: STATE OF ALASKA NOTARY PUBLIC REBECCA SWENSEN My cmnMISSion Ex fres Aug. 27, 2020. Con ocoPhillips Alaska May 8, 2019 To: Operator and Owners (shown on Exhibit 2) Jason Lyons Staff Landman Land & Business Development ConocoPhillips Company 700 G Street Anchorage, AK 99501 Office: 907-265-6002 Fax: 907-263-4966 lason.lyons@cop.com VIA CERTIFIED MAIL Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for CD5-24 Well AA -92344 (ASRC), ASRC-NPR2, and ASRC-NPR4 Colville River Unit, Alaska CPAI Contract No. 203488 Dear Operator and Owners: ConocoPhiltips Alaska, Inc. ("CPAI") as Operator and on behalf of the Colville River Unit ("CRU") 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 CD5-24 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about May 9, 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 -92344 (ASRC), ASRC-NPR2, and ASRC-NPR4 as depicted on Exhibit 1 and has locations as follows: Location FNL I FEL I Township Range Section Meridian Surface 426' 2881' T11 N R4E 18 Umiat Top Open Interval 4023' 1782' T11 N R4E 20 Umiat Bottomhole 2930' 4624' T10N R3E 3 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, including the reservoir section ("Notification Area"). 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, son Lyons Staff Landman Attachments: Exhibits 1 & 2 ASRC-NPR3 T'1',9ZY T ,; ,•i3 >tT L RC -AAO AA081817 AA092675 0 Fred Points Well Trajectory — Dpen Interval Wells within Trajectory Radius ® Half Mile Frac Port Radius QHalf Mile Well Trajectory Radius _Ilii= National Petroleum Reserve -Alaska —uIIT CPAI Lease Exhibit 1 NP R2 ADL387207 \ADL387208 ADL380075 uph 4 C9yq S9s '\ ADL380077 i I I ASR Colville River Unit ___ N 0 0.2 0.4 0.6 0.8 1 m Miles ADL390337 ConocclPhillips Aaska CD5-24 Lease Plat 4129/2019 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 -Operator 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 ASRC-NPR3 T1 C': R3 E ASRC-AAO AA081817 AA092675 Frac Points — Well Trejeclory Open Interval Wells within Trajedary Radius QHalf Mile Frac Pod Radius QHalf Mile Well Trejeclory Radius aurL — Natlonal Petroleum Reserve -Alaska 11111 CPAI Lease ADL387208 i r i AS i .' Colville River Unit - - - N 0 0.2 0.4 0.6 0.8 1 m Miles ADL387207 NpRA ADL380075 ADL380077 ADL390337 Conoco`Phillips Alaska CD5-24 Lease Plat 4129/2019 Table 1: Wells within .5 miles Well Name API Status well Type CD5-01 501032073600 ACTIVE INJ CD5-02 501032073700 PA SVC CD5-02A 501032073701 ACTIVE INJ CD5-03 501032071800 ACTIVE PROD CD5-04 501032071100 ACTIVE PROD CD5-05 501032071200 ACTIVE PROD CDS-06 501032074400 ACTIVE INJ CD5-061-1 501032074460 ACTIVE INJ CD5-07 501032073400 ACTIVE INJ CD5-08 501032074100 ACTIVE INJ CD5-09 501032072300 ACTIVE PROD CDS-10 501032072400 ACTIVE PROD CD5-11 501032072600 ACTIVE PROD CD5-12 501032074200 ACTIVE INJ CD5-17 501032075400 ACTIVE INJ CD5-171-1 501032075460 ACTIVE INJ CDS-18 501032075000 ACTIVE PROD CD5-181-1 501032075060 ACTIVE PROD CD5-19 501032076000 ACTIVE INJ CD5-191-1 501032076060 ACTIVE INJ CD5-20 501032075200 ACTIVE PROD CD5-201-1 501032075260 ACTIVE PROD CD5-21 501032073800 SUSP PROD CDS-22 501032075900 ACTIVE PROD CD5-23 501032076100 ACTIVE INJ CD5-25 501032076500 ACTIVE PROD CD5-251-1 501032076560 ACTIVE PROD CD5-313 501032071400 ACTIVE PROD CD5-313PB1 501032071470 PA EXPEND CD5-314 501032070700 PA PROD CD5-314X 501032075500 ACTIVE PROD CD5-315 501032071600 ACTIVE INJ CD5-315PB1 501032071670 PA EXPEND CD5-316 501032075600 ACTIVE INJ CD5-316PB1 501032075670 PA EXPEND CD5-99 501032074800 PA PROD CDS-99A 501032074801 ACTIVE PROD CD5-99AL1 501032074861 INACTV PROD 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 2/19/2019 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11ppg LiteCrete lead and 15.8ppg class G cement, displaced with 10ppg mud. Full returns were seen throughout the job. The plug bumped at 500 psi and the floats were checked and they held. The 7 & 5/8" casing cement report on 3/5/2019 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 13ppg class G cement lead and 15.8ppg Class G tail. Full returns were seen throughout the job. The plug bumped at 1100 psi, and the floats were checked and they held. The second stage cement job was pumped with 11.2ppg cement. Full returns were seen throughout the job. The plug bumped at 1900 psi, and the stage tool was checked and it was closed. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 2/22/2019 the 10-3/4" casing was pressure tested to 3,500 psi for 30 mins. On 3/8/2019 the 7-5/8" casing was pressure tested to 3,500 psi for 30 mins. The 3.5" and 4.5" tubing will be pressure tested to 5,200 psi prior to frac'ing. The 7-5/8" casing will be pressure tested to 3,850 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,000 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7 5/8" Annulus pressure test 3,850 4.5" & 3 1/2" Tubing pressure Test 9,4 -75 - Nitrogen PRV 7,600 Highest pump trip 7,400 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 TN -110 13,970 psi 12,620 psi Table 2: Wellbore pressure ratings Siad l Tattle Tab Tar* Y�1 dwnd Pop-off Ta@ FraC" Stimulation Surface Rig -Up L • 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;W500 psi 3 (, ®o (DI, • Frac pump trip pressure setting are staggered and set below main treating line PRV PQP�offT" "Trur* Frac Pump Fee PuTO 0021:1-4.9 �MPOOCOIM�� (Adf ,S/W i Alpine 1 OK Frac Tree SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPA] 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 14,337' MD/ -7,599' TVDSS. The estimated fracture gradient for the Alpine A sandstone is 12.5 ppg. The overlying confining zone consists of greater than 400' 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 12,188'MD/-7,016 NDSS. 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 interval ranges from - -7,630' NDSS at the heel to - -7,760' TVDSS at the toe of the well (no MD as the Kingak interval was not penetrated in the CD5-24 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. Casino & Cement assessments for all wells that transect the confining zone 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. CD5-313PB1: On 7/15/2015 CD5-313PB1 was plugged and abandoned as per state regulations. CD5-19 and CD5-19L1: The 7-5/8" casing cement pump report on 11/27/2017. Full returns seen throughout the job. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.3 ppg WBM. The plug bumped at 1,0000 psi and the floats held. CD5-25 and C1135 -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. ) § § \) } \ K I ! \ | ! ! ) , \|\ ! E ! § 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 three faults or fracture systems transect the Alpine A formation or enter the confining zone within one half mile radius of the wellbore trajectory for CD5-24. The first fault was interpreted from seismic data prior to drilling and confirmed with log data while drilling (fault throw of 22'). The second fault was intersected in the wellbore at 23,370' MD (fault throw of 5') but was no mappable on seismic. The third fault was mapped with seismic data but was not intersected with the CD5-24 wellbore, and therefore could not be confirmed. Any faults that are within the half mile radius of the wellbore do not extend up through the 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. We do not expect any of our hydraulic fractures to intersect faults seen in this wellbore. — If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Z Well Depth Depth Vertical Loss Name MD (ft) TVDSS (ft) Displacement ce (bbls/hr) (ce CD5-24 17,708 -7,634 22' None CD5-24 23,370' -7,706 5' None ,/ i ASRC-NPR3 ASRC-NPR2 ADL387207 CD5 I 7888 �AA092347 ASRC-NPR4 ADL380075 i ADL387208 1817 i NPR - A w w M v z Z ASRC-NPR2 � I ASFRGAA092344 ADL380077 i '��-✓{:[Cc �I3?L4 �CGL�-� �o ADL387209 - - o t a 4 u W DL388902 36 AA081817 ---- _ ca 34 i i T11NR3Eo� T11 R4E DL388905 T10NR3E - ar ASRC-NPR4 T10N 4E 6 -LJ -31 �; _/�� f ADL_388 Alpine PA s---------- - - - I i ADL390337 Frac Points Pi"3. E—CEIV '---------------- bv°a �fl Well Trajectory i MAY 1 y 20,p19� Open Interval Wells within Frac Zone Radius A®0�/�''�a G V Half Mile Frac Port Radius i 9 ASRC- ,-� ConocoPhillips Q Half Mile Well Trajectory Radius Alaska t Faults i Colville River Unit_ N Jrrrt _ _ _ - CD5-24 National Petroleum Reserve -Alaska =r r r r 7 Fault Analysis CPAI Lease 0 0.2 0.4 0.6 0.8 1 Miles 5113/2019 I Plat 2: CD5-24 Fault Analysis5/vtl 1c ASRC-NPR3 ASRC-NPR2 ADL387207 CD5 f` 7888 AA092347 ASRC-NPR4 ADL380075 AD 7208 i tV1 i ` i ASRC-NPR2 ADL380077 ASRC-AA092344 i j ADL387209 I � i DL388902 AA081817 ' u i ADL388905 � ti� —ADI-3, ASRC NPR4 ADL388 iAll PA 3 t ADL390337 Frac Paints Well Trajectory , -� Open Interval r Wells within Frac Zane Radius I ® Half Mile Frac Pont Radius ASRC- ✓ ConocoPhillips QHalf Mile Well Trajectory Radius I Alaska Fauns within Free Point Radius ' Colville River Unit — — N � _It11- ---------- - National Petroleum Reserve -Alaska �CD5-24 =1 1 I t F Fault Analysis CPAI Lease 0 02 0.4 0.6 0.8 1 m Mlles 4/2912019 SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD5-24 was completed in 2019 as a horizontal producer in the Alpine A and C formation. 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. After the 1 st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd 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. 11,200 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 3,500 psi as the tubing pressures up. 9. Pump the 100 bbl breakdown stage (25# Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 35 BPM as quick as possible, pressure permitting. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following attached HES schedule @ 35bpm with a maximum expected treating pressure of 6,000 psi. 12. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). dygraulic Fracturing Fluid Pr duct ComponeM IMormation L F�araere ]%Bd9SI Olaf 9c pP1NgWer bf0]]ORB H00.TI SlOBE OettlwNwne' EBVS Cd 696 WeONawaMNuiilm: Lgi9iMe, 0.98 tNPtle tupi,rt Pro}Nox FJlaeFalerY: n wmn m.vM�dpn4,300 ]manamvow.» uz.sw FGatract Maximum Mgn911vrt Ingregmnt Ngaeglent Mapn T9aEe Name Srlpgrer Purywe InOretlknb SMWce COerCenlruy MglJltlm CW Fluid don In Cemnren9e CamlP+ny Fnel Name. last N+ma EVWI P0.orrc Number lCAS (%ty nressi' HF Fluid (%Oy Oar6)9 nssua. ue oPerawlsna raponsiaemrlwccurase amwinmmgnelmamauon Nry mlwtionWr mnalnemmenzd Ne M5G5snwle mtliralmmme un tlra uitMe Iw Ne Jafwure oltM1is Inlamation. PWae rote Mal Felral law yaecb"popn✓sM. YraratlesmeY', antl"wMMMeI btir2aslnlpmatian"entlfee N I Ln 0 U v �F :_. 00 00 00 00 00 00 m m m m f0 L 00 CO 00 00 00 00 N N N N N N N N N N N N N N O O O O O O O O O O tinQ L W =O O O O O O I Ill l/l V N w O O O O O O U (6 LL w Y 2 O O O O O O O O O O NO }t O O O O O lD tD wlD {y 00 lf7 L!'I V1 Ln Ill V V V O. N O _ a w ti o m � v m Ln CL t° w rn 00 In I oo m io cD o 00 N c� C lD 00 r, N It zt lO m zt N O O Dl 00 r- l0 tll vl V d N N N c -I N N N c -I H N F O O O O O O O O O O pl O O O O O O O O O O N O O O O O O O O O O 1/1 O O O O O O O O O O O to ri N m V L/1 LO Il 00 Dl 00 N � LA O h � C� E y � N Y 0J Y U U 0 00 m C w N C 0 C O N C U N 0 L C v O Q O N N w E mc m G Q t0 � O � C O v � � L 3 Y O Y L cu �0 -o O o o E E aj aj v ai C c o- � � a jra C C a S •Y m o a `o_ E N N N E '- m E a c O .— U = N 00 L O a .- Y m O �C C C Y O U v C N 01 L b0 i C 3 CL CU t L Y N O Qj E ° NN V F CO 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.) PTD ;? iy — 6 04 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, May 8, 2019 4:09 PM To: Polasek, Tom G Subject: CRU CD5-24 (PTD 219-006) Intermediate TOC Log Tom, A CBL will not be required to verify TOC for the approval of the future frac sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 71h Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCdalaska oov 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 Loeoo@alaska nov From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, May 8, 2019 3:41 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]CD5-24 Intermediate TOC Log (PTD 219-006) Hi Victoria, Calculated top of cement is 10362' ft with 20% washout and 9663' MD without washout. We started our log above where we thought top of cement would be, but did not find a definitive top of cement. The large volume of cement we pumped likely played a role in this. In order to show a top of cement and better assess the cement job we can run a CBL log. Due to a successful cement job, I waited until all the cement evaluation and logs were available and submitted them when they were all available, which they all became available yesterday. In a circumstance where the cement job does not go according to plan, my understanding was we needed to contact the State immediately to discuss possible remediations or logs prior to moving forward. I apologize, I was mistaken in my interpretation and in waiting to send the initial cement job report prior to drilling out the intermediate on this well. I will ensure to supply each piece of information, as soon as it becomes available, on all future wells. Please advise if AOGCC would like us to go ahead and run a CBL on CD5-24 to find the top of cement and/or if required for approval of a future frac sundry. Thank You Victoria, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.e.polasek@conocophillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, May 08, 2019 1:58 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]CD5-24 Intermediate TOC Log (PTD 219-006) Tom, The intermediate cement job was pumped on 3/4/19. A review of this cement job is required before drilling out of the intermediate. Right after the cement job is complete, we expect to seethe information that was just provided with the addition of a calculated TOC. Please provide the calculated TOC. Conditions of Approval for running the sonic log: Approval is granted to run the (USIT)Sonic on upcoming well KRU xx (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 cementjob 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. 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.LoeDD(a)alaska gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use of 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 if to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@oloska.aov From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, May 8, 2019 1:07 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: CD5-24 Intermediate TOC Log (PTD 219-006) Hi Victoria, Over the weekend, CD5-24 logged for top of cement for the intermediate casing cement job using SchIumberger's SonicScope evaluation tool. We logged from 7900' MD/5169' TVD to 13300' MD/7534' TVD. The Kuparuk C Sand producing formation top is at 12750' MD/7339' TVD. The cement job went as planned with no losses, bumped our plugs and floats held. We pumped a large excess of cement to beneficially effect our casing load collapse case and optimize our gas lift mandrel placement. Total cement pumped was 110 bbls 13 ppg Class G lead cement and 130 bbls 15.8 ppg Class G tail cement. TOC log is attached along with cement job pump report. Top portion of Sonic log shows free ringing pipe while lower portion shows cement log. The Schlumberger log interpreter did not find a definitive top of cement, indicating top of cement is above where we started the log at 7900' MD. See comments in Comment Section of Log. Due to top of cement being above where we started logging at 7900' MD, we will use 7900' MD as top of cement for the CD5-24 Frac Sundry, to be submitted shortly. Thank you Victoria and please let me know if you have any further questions Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, May 14, 2019 2:21 PM To: Klem, Adam Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question Thank you Adam. I'm finished with my portion of this review Thank you again, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such Information may violate state or federal law. if you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(@alaska.cov. From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Tuesday, May 14, 2019 1:56 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question From: Davies, Stephen F (DOA) <steve.davies@alaska.aov> Sent: Tuesday, May 14, 2019 1:53 PM To: Klem, Adam <Adam.Klem@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question To ensure we're talking about the same data items, currently the "Present Well Condition Summary' part of the form reads: Total Depth MD (ft) Total Depth TVD (ft) Effective Depth MD Effective Depth TVD MPSP (psi) 27,128 7,718 27,070 7,715 1 7,500 Please provide the proper values: Total Depth MD (ft) Total Depth TVD (ft) Effective Depth MD Effective DepthTVD MPSP (psi) 31,040 7,856 31,040 7,856 8,000 From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Tuesday, May 14, 20191:45 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question Is that the actual end of where we drilled to? If so, that is the 31,040'MD and 7856' TVD on the end of the survey. From: Davies, Stephen F (DOA) <steve.davies@alaska.aov> Sent: Tuesday, May 14, 2019 1:42 PM To: Klem, Adam <Adam Klem conocophillips.com> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question One more: What is the present effective depth for the well (MD and TVD)? From: Klem, Adam <Adam Klem@conocophillips.com> Sent: Tuesday, May 14, 2019 9:51 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.eov> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question I noticed the actual end of liner is 21,708 vs 21,699 as on the sundry. From: Davies, Stephen F (DOA) <steve.davies@alaska.eov> Sent: Tuesday, May 14, 2019 9:49 AM To: Klem, Adam <Adam Klem@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question No, to save time I will just make corrections by hand. I just want to confirm the values before I write them in. Please let me know if you spot any others that need to be fixed. Thank you again, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or Steve daviesealaska.gov. From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Tuesday, May 14, 2019 9:46 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: (EXTERNAL)CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question Shoot, I always miss those cells above the tubular details. Would you like me to update the sundry pages and send it back in? The 31,040' MD is correct, as is the survey Andrew sent in. Adam From: Davies, Stephen F (DOA) <steve.davies@alaska.eov> Sent: Tuesday, May 14, 2019 9:38 AM To: Klem, Adam <Adam Klem@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question Thank you Adam. Another question: On CPAI's Application for Sundry Approvals for this proposed fracturing operation, the total depth of CD5-24 is shown as 27,128' MD, but in the definitive directional survey (attached) provided to me by Andrew Beat on April 3rd for CPAI's Annular Disposal Application for CD5-24, the final, projected survey station is listed as 31,040' MD. Which is correct? Thank you again, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or Steve day esPalaska.gov. From: Klem, Adam <Adam Klem@conocophillips.com> Sent: Tuesday, May 14, 2019 9:31 AM To: Davies, Stephen F (DOA) <steve davies@alaska.eov> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question Steve. See below: From: Davies, Stephen F (DOA) <steve.davies@alaska.eov> Sent: Monday, May 13, 2019 2:01 PM To: Klem, Adam <Adam Klem conocophillips.com> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question Adam, Please provide an updated Fault Analysis map (Plat 2) to show the location of the third fault that was mapped using seismic data, but not intercepted by the well. What is the vertical displacement of this fault as interpreted from the seismic data? This third fault was in the planned well at 31,430' MD but we TD'd before that depth. Anticipated throw was `1S'. By the way, after reading through the history file for CD5-24 it appears as though the correct measured depth for the surface casing shoe is 2,234' rather than 2,334' as shown on CPAI's Sundry Application form. Please confirm this. Correct, that was a typo on my part. My apologies Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. From: Klem, Adam <Adam Klem@conocophillips.com> Sent: Friday, May 10, 2019 3:47 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: Re: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question My apologies. Since the well isn't finalized yet, the schematic is the planned depths. The sundry depths are actual. From: Davies, Stephen F (DOA) <steve.davies@alaska.Rov> Sent: Friday, May 10, 2019 15:41 To: Klem, Adam Subject: [EXTERNAL)CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question Adam, I'm reviewing CPAI's application to fracture stimulate CRU CD5-24, and I have a question. The casing depths shown on the application form and on CPAI's schematic drawing of the well are not consistent. Which values are correct? Casing MD on Sundry Application Form MD on Schematic Drawing Surface 2334 2253 Intermediate 13882 13898 Liner 21669 Not shown Thank you, Steve Davies Senior Petroleum Geologist AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% — PHydrosMc + PApplied" PGasGradimt' PHeader 4,072 =( 6,269" 0.052 * MW, )+ 1,500 - ( 0.0700 * 6,269) - 1,000 Pressure Calculations for Annular Disposal PDB 4.5 "Tubing (for submital with Annular Disposal Application) Vmlmlo mm'16 Well CD5-24 2nd Casine Assumptions Date 3/19/2019 7.625 Maximum injection pressure of 1,500 psi 29.7 ppf Maximum density of the injection fluid is 12.0 ppg Ye011apse100% 4,790 psi Pore pressure at the] 0 3/4" casing shoe is 0.434 psi/ft Top of Cement 6,269 it Gas Gradient Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 Header Pressure (for wells on gas lift) 1,000 psi Maximum Fluid Density to avoid Burst of Surface CasinPbu.st85% = PHydrostatic '+ PApplied " Promotion4,429 = ( 2,174 * 0.052 * MW,,,a„ ) + 1500 - ( 0.4337 * 2,174MMW..= L2,174 34.2 ppg TVD Surface Casine String Size 10.75 in d — TOC Est. @ /4,761' MD Weight 45.5 ppf 3,765' Grade L 80 S 9 Ynarauoow 5,210 Psi Stage Collar @ 5759' MD Pb.185% 4,429 psi ' W Depth of Shoe 2,174 ft U Ffr/LOT @ Shoe 18 ppg or 2,035 psi N FIT/LOT for Annulus 16 ppg Max Surf. Pressure 1,500 psi r SPC Est. @ 10,362' MD 6,269' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% — PHydrosMc + PApplied" PGasGradimt' PHeader 4,072 =( 6,269" 0.052 * MW, )+ 1,500 - ( 0.0700 * 6,269) - 1,000 Pmaxallowable = Shoe TVD Depth *.052 * Shoe FIT/LOT P." = ( 2,174 -.052 * 18 ) Pmax allowable — 2,035 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe'. MW,,,aa = 12.3 PDB 4.5 "Tubing 2nd Casine String Size 7.625 in 7,640 TVD Weight 29.7 ppf Grade L 80 Ye011apse100% 4,790 psi P*anapae85r 4,072 psi Top of Cement 6,269 it Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Pmaxallowable = Shoe TVD Depth *.052 * Shoe FIT/LOT P." = ( 2,174 -.052 * 18 ) Pmax allowable — 2,035 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe'. CD5- 5, 10-314", Surface Casing Well: CD5-24 10-314" 45.5# L-80 TXP-M Casing Conoo3 hillips +��� Alaska, Inc. F r Date: Rig: o19 Doyon 19 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 19 RKB to top of Landing Rincl 3749 FMC 10-3/4" Casing Hanger 13 37.49 10-3/4", 45.5#, L-80, Casing Pup Jt, H563 Pin X H563 Pin 2.50 37.62 Pup Jt 10-3/4", 45.5#, L-80, H563 9.81 40.12 Pup Jt 10-3/4", 45.5#, L-80, H563 9.82 49.93 XO Pup Jt 10-3/4", 45.5#, L-80, H563 Pin X BTCM Box 9.82 59.75 Jts 3 to 56 54 Jts 10-3/4", 45.5#, L-80, TXP-M Casing 2079.65 69.57 10-3/4" To co N/R Float Collar 1.561 2149.22 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, TXP-M Casing 81.221 2150.78 10-3/4" To co Shoe 2.50 2232.00 2234.50 2234.50 2234.50 L 2234.50 10-3/4" Shoe at 2234.50' MD 2174.7' TVD 2234.50 13-1/2" TD at 2245' MD, 2184' TVD 10' rathole 2234.50 2234.50 2234.50 2234.50 2234.50 2234.50 1 Centek 10' up from shoe w/stop rings on Jt #1 2234.50 1 Centek 30' up from pin w/stop rings on Jt #2 2234.50 1 Centek 20' up from pin w/stop rings on Jt #3 2234.50 1 Centek centralizer every joint from #4 to #20 Floating 2234.50 1 To co bowspring every Jt from #21 to #56 over coupling 2234.50 2234.50 2234.50 2234.50 2234.50 Total Centralizers 2234.50 20 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312S 2234.50 36) Top -Co PN 300-273-434 10.75" x 16" bowsprin s 2234.50 2234.50 2234.50 Remarks Use Seal Guard ECF on HYD 563 Up Wt 145 K MU Tq with Volant -Hyd 563 doped 16.2 ft/lbs, TXP-M to 27,160 ft/lbs Down Wt 130 K Bakerlocked to pin end of jt #4 Block Wt 60 K Driffted with 9.885" drift Rig Supervisors: R. Bjorhus/L. Shirley/A. Don Cement Detail ort Re P CD5-24 String: Surface Casing Cement Job: DRILLING ORIGINAL, 2/14/2019 00:00 Cement Details Description Surface Casing Cement Cementing Sfan Date Cementing End Date Wellbore Name 2/19/2019 20:15 2/20/2019 00:24 CD5-24 Comment Cement Stages Stage # 1 ttom Depth (ftKB) Full Retum7 Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement Surface Casing 37.5 34.5 Description Objective Top Depth (ftKB)4(psilp Yes 225.0 Yes Yes O Pump Init (DRUM... O Pump Final (W... D Pump Avg (bbl/... P Pump Finaiug Bump (psi)Remp7 Stroke(ft) Roum,cl? Pipe RPM (rpm) 3 6 500 O60.0 Yes NoTagged Depth (ftK8) Tag Method pth Plug orOut To (ftKB) Drill Out Diameter (in) Comment Dowell pump 3 We H2O & PT to 250/3500 psi (good). Dowell pump 75 bbls 10.5pp9 mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 396 bbls 11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement and 85 bbis 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 185 bbls / 1847 stks 10 ppg DrillPlex with 8 bpm / 750 psi Reduce pumps to 3 bpm / 460 psi. last 10 bbis. Bump plug, pressure 500 psi over to 1060 psi for 5 min. Check floats F/C good. CIP @ 00.24 Hrs. Calculate 225 bbls good cement to surface. Full returns during cement job. Cement Fluids & Additives Fluidpe Fluid Description Estimated Top (ftKB) Fat arm (ftK8) Amount (sacks) Class volume Pumped (bbl) ement 375 1,7350 1,140 B 395.0 'laack) Mix H2O Ratio (gal/ea... Free Water (%) Denslry (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprS[r 1 (psi) 6.82 11.00 es rAdditive Type Concentration Cone Unit label pe Flultl Description Estimated Top (ftKB) E)assVolume Pumped (bbl) ent 1,735.0 2,234.5 411 G 85.0 Yield (ft'hack) 1.16 Mix H2O Ratio (gal/sa... Free Water (%) Denetly invest) Plastic Viscosity (CP) Thickening Time (hh Cm prStr 1 (psi) 5.13 15.80 Additives Additive Type Concentration Cone Unit label Time Log & Summary Report [AOGCC] CD5-24 Well Name: CDS-24 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 2/16/2019 Rig Release: Time Log Start Time End Time Dur (hr) Start Depth MW EM Depth (WB) Phase Op Cotle AcMyOode Time -T-X Operation 2/18/201911:45 2/18/201912:00 0.25 1,392.0 1,392.0 SURFAC CASING CIRC P Circulate nut plug sweep around. 500gpm. 860 psi. 40 rpm. 1.5k to. 2/18/2019 1200 2/18/2019 13:45 1.75 1,392.0 587.0 SURFAC CASING BKRM P BR OOH f/ 1392'to 587'. 450 gpm. 730 psi. 30 rpm. 1.5k tq. 2/18/2019 1345 2/18/2019 14:45 1.00 587.0 100.0 SURFAC CASING TRIP P POOH f/ 587 to 100'. 450 gpm. 620 psi. (hole unloaded @ 250'). 2/18/2019 1445 2/18/2019 15:30 0.75 1000 1000 SURFAC CASING CIRC P Circulate nut plug sweep around. 425 gpm. 550 psi. 40 rpm. 2/18/2019 15.30 2/18/201916:15 0,751 100.0 0.0 SURFAC CASING BHAH P UD BHA. 2/18/2019 16:15 2/18/2019 17:30 1.25 0.0 0.0 SURFAC CASING BHAH P I Clean and clear rig floor. Monitor hole on TT. 2/18/2019 1730 2/18/2019 19:15 1.75 0.0 0.0 SURFAC CASING RURD P RU to run casing. 2/18/2019 19 15 2/18/2019 20.15 1.00 00 1250 SURFAC CASING PUTS P PJSM. PU and RIH wl shoe track and check floats. Good. 2/18/2019 20:15 718/2019-21 15 1.00 125.0 3290 SURFAC CASING PUTB P RIH w/ 10 3/4" csg to 329'. Taking weight @ 329'. 2/18/2019 21 15 2/19/2019 00:00 2.75 329.0 391 0 SURFAC CASING PUTS T Wash and work csg f/ 329' to 391' 1-6bpm. 40- 120psi. 20k weight down while working casing, Up 72k.. Down 72k 2/19/2019 00:00 2/19/2019 00.30 0.50 391.0 354 0 SURFAC CASING PUTS T Wash and work casing from 391' MD to 354' MD 1-6bpm. 40-120psi. 20k weight down while working casing. Up 72k.. Down 72k 2/19/2019 00:30 2/19/2019 03:00 2.50 354.0 3540 SURFAC CASING PUTB T Rack back double 10-314" casing with 10' pup. 2/19/2019 03.00 2/19/2019 11.45 8.75 3540 1,400.0 SURFAC CASING PUTS P Continue RIH 10-3/4" 45.5ppf L-80 TXP-M casing from 354' MD to 1,400' MD. Wash down as needed with 8bpm 120psi 5 rpm 7-10k ft-lbs torque. Hard spot from 820' MD to 1,017' MD. 2/19/2019 11:45 2/19/2019 12.00 0.25 1,400.0 1,400.0 SURFAC CASING CIRC P Circulate btms up at 1,400' MD 8bpm 130psi. 2/19/201912.00 2/19/201915:45 3.75 1400.0 2,197.0 SURFAC CASING PUTS P Continue wash down 10-3/4"45.5ppf L-80TXP- M casing from 1,400' MD to 2,197' MD. with 8bpm 160psi 5 rpm 7-10k ft-lbs torque. 2/19/2019 1545 2/19/2019 16.15 0.50 2,197.0 2,234.0 SURFAC CASING HOSO P M/U hanger & landing it Wash down w/3 bpm @ 200 psi & land on hanger @ 2,234'. P/U wt 145 k, S/0 wt 130 k. 2/19/201916:15 2/191201918:15 2.00 2,234.0 2,234.0 SURFAC CEMENT CIRC P Circ& cond mud for cementjob. Stage flow rate up to 8 bpm @ 150 psi. Reciprocate pipe 10', PJSM on cementing operations. 2/19/2019 18:15 2/20/2019 00:00 5.75 2,234.0 2,2340 SURFAC CEMENT CMNT P Dowell pump 3 bbls H2O & PT to 250/3500 psi (good). Dowell pump 75 bbls 10.5ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 396 bbls 11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement and 85 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 185 bbls 11847 stks 10 ppg DriIlPlex with 8 bpm / 750 psi. Reduce pumps to 3 bpm / 460 psi. last 10 bbls. Bump plug, pressure 500 psi over to 1060 psi for 5 min. Check floats. F/C good. CIP @ 00:24 Hrs. Calculate 225 bbls good cement to surface. Full returns during cementjob. 2/20/2019 00:00 2/20/2019 00:30 0.50 2,234.0 2.234.0 SURFAC CEMENT CMNT P Cont. to displace w/186.7 bbls total @ 1847 stks 10 ppg DriIlPlex with 8 bpm 1750 psi. Reduce pumps to 3 bpm 1460 psi. last 10 bbls. Bump plug, pressure 500 psi over to 1060 psi for 5 min. Check floats. FIC good. CIP @ 00:24 Hrs. Calculate 225 bbls good cement to surface. Full returns during cementjob. 2/20/2019 00:30 2/20/2019 01:00 0.50 0.0 00 SURFAC CEMENT W W WH P Flush annular with black water 3X's. Shut in annular for water flow mitigation. Page 2112 ReportPrinted: 3/14/2019 CD5-24_7-5/8" Intermediate casing Well: CD5-24 y 7 518" 29.7# L80 TXP & RY 110 Eagle Casing Date: 3/5/2019 Conocomillips Alaska, Inc. Mr �If 8 Rig: Doyon 19 Depth Jt Number Joints Well Equipment Description and Comments Page 1 Length Tops RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 34.18 FMC 7.625" fluted hanger HYD 563 .72 34.18 7-5/8", 29.7#, L-80 pup pin x pin below hanger HYD 563 2.10 34.90 #5 XO Joint, 7-5/8" 29.7# HYD663 Box x TXP Pin 40.05 37.00 Jts 331 to 336 6 Jts 7-518", 29.7#, L-80 TXP Casing 240.561 77.05 #4 XO Joint, 7-5/8", 29.7#, TXP Box x RYS110 Eagle Pin 40.80 317.61 Jts 259 to 330 72 Jts 7-5/8", 29.7#, RYS110 Eagle Casing 2996.15 358.41 #3 XO Joint, 7-6/8",29.7#, RYS110 Eagle Box x BTC Pin 40.22 3354.56 Jts 200 to 258 59 As 7-518", 29.7#, L-80 TXP Casing 2364.09 3394.78 7-5/8", HES 2 Stage Cementer Qannik Zone 5,322' - 5,379' 3.07 5758.87 Jts 17 to 199 183 Jts 7-5/8", 29.7#, L-80 TXP Casing 7342.04 5761.94 7-5/8", 29.7#, 1-80, TXP Casing w/RA Tag in Coupling 13,104' 40.53 13103.98 Jts 12 to 16 5 Jts 7-5/8", 29.7#1 L-80 TXP Casing Jts 11 to 11 1 Jts AS 10 to 10 1 Jts 7-5/8", 29.7#, L-80 TXP Casing 200.751 40.64 40.68 13144.51 13345.26 13385.90 #2 XO Joint, 7-5/8", 29.7#, TXP Box x RYS110 Eagle Pin 40.60 13426.58 Jts 4 to 9 6 Jts 7-5/8", 29.7#, RYS 110 Eagle Casing 251.05 13467.18 #1 XO Joint, 7-5/8", 29.7#, RYS110 Eagle Box x BTC Pin BakerLok) 40.35 13718.23 7-5/8" HES Baffle Collar 1.25 13756.58 Jts 3 to 3 1 As 7-5/8", 29.7#, L80, BTC Casing BakerLok 39.66 13759.83 7-5/8" Topco Float Collar w/Baffle Adaptor Installed 1.42 13799.49 Jts 1 to 2 2 As 7-5/8", 29.7#, 1-80, BTC Casing BakerLok 79.09 13800.91 7-518" HES Eccentric Nose shoe 2.10 13880.00 Alpine C Top 13,339' MD / 7,544' TVD, Bottom 13,381' MD / 7,554' TVD 13882.10 TD 9-7/8" Hole 13,897' MD / 7,641' TVD 11" Hole 13,794' MD 13882.10 Casing Shoe 13,882' MD / 7,640' TVD, 83" Inc 13882.10 13882.10 2 Centeks joint #1 w/2 stop collars 13'& 27' 13882.10 1 Centek joint #2 w/2 stop collars 20'f/pin 13882.10 3 Centeks per 2 joints from #3 - #9, & #12 - #40, St o sat 13', 27' 13882.10 Centeks or Hydroforms, 1 cent per joint #200 - #226 13882.10 13882.10 1 Hydroform per joint #284, #285, #286 13882.10 1 Straight Blade Cent every other joint f/#288 to Surface 13882.10 Remarks Total Centralizers (Centeks = 72, Hydroforms =19, Straight blades = 26 ) M/U Trq Eagle 20 k ft/lbs w/Seal Guard Pipe Dope Up Wt 320 K M/U Trq TXP 21.3 k ft/lbs w/Run-N-Seal Pipe Dope Dn Wt 150 K M/U Trq Hyd 563 10.3 k ftllbs w/Seal Guard Pipe Dope Block Wt 60 K ShoeTrack BakerLok to pin of XO & Baffle Collar Rig Supervisors: A. Dorr / P. Angelle Cement Detail Report CD5-24 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 2/14/2019 00:00 Cement Details Description Intermediate Casing Cement Cementing Start Date 3/5!2019 04:00 Cementing End Date 3/5/2019 07:45 Wellbore Name CD5-24 Comment Dowell pump 1.2 bbis H2O & PT to 4500 psi (good). Dowell pump 60 bbis 11 5 ppg mud push at 4 bpm. Shut down & drop bottom plug Dowell pump 110 bbls 13 0 ppg 1.97 ft3lsx yield Class G lead Dement and 130 bbis 15 8 ppg 1 16 1131sx yield tail cement @ 4.5 bpm. Drop top plug Dowell pump 20 bbis H2O. Rig displace with 605 bbis (6,050 stks @ 95%) 10.6 ppg LSND with 7 bpm / 180 - 800 psi Reduce pumps to 4 bpm / 760 psi last 60 bbis Reduce pumps to 2 bpm I 750 psi last 60 bbis. Bump plug, pressure up to 1100 psi for 5 min. Check floats. F/C good CIP @ 07.45 His. Full returns during cement job 10.6ppg in/out Cement Stages Stage # 1 Description Intermediate Casing Cement Lead Objective Top Depth (ftKB)Bottom 10,362.0 Depth IRKS) 12,170.0 Full Ratum? Yes Vol Cement... Top Plug? Yes BM Plug? Yes Q Pump Init (bbl/m... 7 10 Pump Final (bbl/... 2 IQ Pump Avg (11,1,11... 5 P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Teq Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (In) Comment Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top (ftKB) 10,3620 Est BM (ftKB] 12,170.0 Amoum (sacks) 313 Claes Volume G 110.0 Pumped (bbl) Yield (ft'lsack) 1.97 Mix H2O Ratio (Sallee... 10.82 Free Water I%) Density (Ib/gal) 13.00 Plastic Viscosity ICP) 29 6 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conic Unit label Stage # 2 Description Intermediate Casing Cement Tail Objective Isolate 500' MD above KuparukC Top Depth (ftKB) 12,170.0 Bottom Depth (ftKB) 13,882.0 Full Realm? Yes Vol Cement... Top Plug? Yes Som Plug? Yes Q Pump [nit (bbllm... 7 10 Pump Final (bbl/... 12 IQ Pump Avg (bbl/... 5 P Pump Final (psi) 750.0 P Plug Bump (psi) 1,100.0 Recip? Yes Stroke (R) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (In) Comment Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 12,170.0 Est St m (ftKB) 13,882 1 Amount (sacks) 634 Class Volume 9 130.0 Pumped (bbl) Yield (ft'/sack) 1.16 Mix H2O Ratio (gallsa... 5.09 Free Water I%) Density (]bleat) 11580 Plastic Viscosity (cP) Thickening Time (hr) Cmprstr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 3 Description Upper intermediate Casing cement Lead Objective Top Depth (HIKE) M Isolate 500' D above 4,761.0 Qannik Bottom Depth (ftKB) 5,761.0 Full ReWmT Yes Vol Cement... Top Plug? Yes Sum Plug? No Q Pump [nit (bbl/m... 3 10 Pump Final (bbU... 12 Q Pump Avg (bbl/... 4 P Pump Final (psi) 160.0 P Plug Bump (psi) 1,9900 Recip? INO Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) 7 t Diameter (in) 7 Comment Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluld Description Estimated Top (RKB) 4,761.0 Eat arm (ftKB) 5,761.0 Amount (sacks) 224 Class Volume G Pumped (bbl) 73.0 Yield (ft'/sack) 1.84 Mix H2O Retlo (gal/ea... 6A7 Free Wat¢r (%) Density (Iblgal) 11.20 12820 Plast. Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 1/1 ReportPrinted: 3/14/2019 Time Log & Summary Report [AOGCC] CDS-24 . . • Well Name: CDS-24 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 2/16/2019 Rig Release : Time Log Start Time Entl Tme our (hr) Start Depth (td<a) Entl Depth (a B) Phase Op Code ActwAy Code TaP -T-X Operztion 3/2/2019 09:15 3/2/2019 11:00 1.75 208 0 0.0 INTRMI CASING BHAH P UD BHA as per DO f/208' MD (Bit Grade: 0-1- WT-G-X-I-ER-TO &Reamer Grade: 1-1-WT-A-X- I-ER-TD) 3/2/2019 11.00 3/2/2019 12:15 1.25 0.0 0.0 INTRMI CASING W W WH P M/U stack washer & Flush stack. UD same. SIMOPS - Clean & clear floor 3/2/2019 12:15 3/2/2019 14:30 2.25 0.0 0 0 INTRM1 CASING BOPE P PJSM - C/O upper pipe rams to 7 5/8". Pull wear dng. Set test plug & R/U to test BOPE. SIMOPS - Clean & dear floor. Mobilize casing running tools to dg floor. 3/2/2019 14:30 3/2/2019 15:15 0.75 0.0 0 0 INTRMI CASING ROPE P Test annular preventer to 250 for 5 min 12500 psi for 5 min. Test upper pipe rams to 250 for 5 min / 3500 psi for 5 min. 3/2/2019 1515 3/2/2019 15:30 0.2510.0 0.0 INTRMI CASING ROPE P R/D testing equipment. Drain stack. 312/2019 15.30 3/2/2019 17:30 0 0 0 0.0 INTRMI CASING RURD P R/U to run casing. R/U Volant w/torque tum, spider's &elevators &strap tongs. 302019 1730 3/3/2019 00:00 0 00 2,145.0 INTRMI CASING PUTB P PJSM on running casing. M/U 7-5/8" shoe track & check floats (Shoe, 2 its, float collar, 1 jt, baffle collar, X/0, 6 joints Eagle casing, X/0, 2-joints [5.75 TXP no centralizers, 5-TXP joints, RATag joint,). RIH w/7-5/8" 29.7# TXP casing to 2,145' MD. P/U: 109k S/O: 109k. Torque turned only Eagle casing. 3/3/201900:00 3/3/201905:45 1 2,145.0 5,199.0 1INTRM1 CASING 1PUTB P RIH 7-5/8" 29.7# TXP casing f/2,145'to 5,199'. 3/3/2019 05:45 3/3/2019 07:45 2.00 5,199.0 5,199.0 INTRMI CASING CIRC P Circ & cond mud for 1 B/U Stage pumps f/1 bpm to 5 bpm, 180 - 210 psi. Reciprocate pipe. PU wt 160 k / SO wt 140 k 3/3/2019 07:45 3/4/2019 00:00 16.2 5,195.0 10,893.0 INTRMI CASING PUTB P RIH 7-5/8" 29.7# TXP & Eagle casing f/5,199' 5 MD to 10,893' MD (M/U stage tool & Bakerl-ok between its 199 & 200) 3/4/2019 00.00 3/4/2019 01:30 1.50 10,893.0 11,316.0 INTRMI CASING PUTB P RIH 7-5/8" 29.7# TXP & Eagle casing f/10,893' MD to 11,316' MD 3/4/2019 01 30 3/412019 10:00 8.50 11,3160 11,316.0 INTRMI CASING CIRC P Circ & cond mud. Stage up flow rate w/Initial 1 bpm @ 430 psi & Final 5 bpm @ 330 psi, 10.8 ppg In 110.9 ppg Out. Reciprocate pipe. PU wt 272 k/SO wt 180k 3/4/201910.00 3/4/201920:45 10.7 11,3160 13,842.0 CASING PUTB P RIH 7-5/8" 29.7# Eagle & TXP casing f/11,316' 5 MD to 13,842' MD. AT 13,766' MD S/O wt 124k, 1 JINTRM1 Pump down at 1/2-1 bpm 420psi. S/O wt 160K with pumps. 3/4/2019 20:45 3/4/2019 21:30 0.75 13,842.0 13,882 0 INTRMI CASING HOSO P MMU hanger & landing jt Wash down w/2 bpm / 480 psi & land on hanger @ 13,882' MD (S/O wt 160-170 k,) Work landing joint and increasing pump rate. Max break over P/U 435k. 3/4/2019 21:30 3/5/2019 00:00 2.50 13,882.0 13,882 0 INTRMI CEMENT CIRC P Circulate and condition mud, cut mud weight back from 10.8ppg to 10.6ppg, stage pumps up to 7 bpm /480 psi. Circ & cond mud for cement job. Reciprocate casing PU wt 325 k / SO wt 167 k 3/5/2019 00:00 3/5/2019 03:30 3.50 13,882 0 13,882.0 INTRMI CEMENT CIRC P Circulate and condition mud, cut mud weight back from 10.8ppg to 10.6ppg, stage pumps up to 7 bpm / 480 psi. Circ & cond mud for cement job. Reciprocate casing PU wt 325 k / SO wt 167 k Mud weight in 10.6ppg 10.7+ out Page 7112 ReportPrinted: 3/1Z-2019 Time Log & Summary Report [AOGCC] CD5-24 . Well Name: CD5-24 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 2/16/2019 Rig Release Time Log Siert Time End Time Dur (hr) Siert Dept (fiKB) End Dept (WB) Phase Op Cade Adrvity Code Time P T-X Operation 3/5/2019 03:30 3/5/2019 08:00 4.50 13,8820 0.0 INTRMI CEMENT CMNT P Dowell pump 1.2 bbls H2O & PT to 4500 psi (good). Dowell pump 60 bbls 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 110 bbls 13.0 ppg 1.97 ft3/sx yield Class G lead cement and 130 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 4.5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 605 bbls (6,050 stks @ 96%) 10.6 ppg LSND with 7 bpm / 180 - 800 psi. Reduce pumps to 4 bpm / 760 psi. last 60 bbls. Reduce pumps to 2 bpm 1 750 psi. last 60 bbls. Bump plug, pressure up to 1100 psi for 5 min. Check floats. FIC good. CIP @ 07:45 Hrs. Full returns during cement job. . 10.6ppg in/out Note: Cup on Volant tool started leaking while finishing pumping lead cement. Land on hanger and continue pumping job with casing swedge. 3/5/2019 08.00 3/5/2019 20:00 12.0 0.0 0.0 INTRMI CEMENT WOC P Pressure up on casing @ 2bpm, Open stage 2 0 tool with 3,150psi, Continue circulate at /bpm 80psi while WOC and L/D 5' drill pipe from derrick with hoist/single joint elevators. Rig down Volant CRT. 3/5/2019 20:00 3/5/2019 22:00 2.00 00 00 INTRMI CEMENT CMNT P PJSM. Mix/pump 60 bbls 10.9 ppg Mud Push II spacer @3.8 BPM. 165 psi. Mix/pump 73 BBL 11.2 ppg CMT@ 4.7 BPM, 209 psi. Drop closing plug and kick out w/ 20 BBL water @ 5.7 BPM, 182 psi. Displace w/10.6 LSND @ 7 BPM, 380 psi. After 237 BBL away, slow to 2 BPM, 160 psi. After 242.5 BBL away, bump plug and pressure up to 1990 psi. CIP@ 21:55. Bleed pressure off string and OWFF-(static) to confirm ES Cementer is closed. Full returns. 315/201922:00 3/5/201922:45 0.75 00 0 1 INTRMI ICEMENT OWFF P Monitor well. Static. UD landing jt. 3/5/2019 22.45 3/6/2019 00:00 1.25 00 0 0 INTRMI CEMENT W W WH P Drain stack, Make up stack washer and wash hanger area at 9.5bpm, UD same. Attempt to set pack off, 1" from bottom out. Pull paskoff and wash with open ended drill pipe. 3/6/2019 00.00 3/6/2019 00:30 0.50 00 00 INTRMI CEMENT W W WH P M/U S' single open ended drill pipe. Wash above hanger to clear debris. 3/6/2019 00:30 3/6/2019 01:30 1.00 0.0 00 INTRMI CEMENT W WSP P Set FMC pack off, lock down and test 250/5000psi 10min. Witness by COPA 3/6/2019 01:30 3/6/2019 03:45 2.25 0.0 00 INTRMI CEMENT WOC P Hold PJSM, change out UPR f/ 7 5/8" casing rams to 3.578" VBRs. Simops: Change out saver sub f/ 4.5' IF to C XT-39. While WOC 3/6/2019 03:45 3/6/2019 10:00 6.25 0 0 0.0 INTRMI CEMENT WOC P Continue UD 5" drill pipe from derrick in mouse 1 hole. While WOC 3/6/2019 10:00 3/6/2019 1200 2.00 0.0 0.0 INTRMI WHDBOP BOPE P Clean and clear ng floor, R/U BOP test equipment and 4" test joint. Set test plug and purge lines. Note: Freeze protected 10 3/4" x 7 5/8" annulus (performed LOT 535psi with 10.6ppg on first test, 372psi with 10.6ppg on second test, then flushed with 300 bbls of fresh water, followed by 80 bbls of diesel for freeze protect. Page 8/12 Report Printed: 3/14/2019 Davies, Stephen F (DOA) From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Friday, May 10, 2019 3:47 PM To: Davies, Stephen F (DOA) Subject: Re: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question My apologies. Since the well isn't finalized yet, the schematic is the planned depths. The sundry depths are actual. i �— !l<(�✓%l�e plc J G Kt� a s i3,/j From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Friday, May 10, 2019 15:41 To: Klem, Adam Subject: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-239) - Question Adam, I'm reviewing CPAI's application to fracture stimulate CRU CD5-24, and I have a question. The casing depths shown on the application form and on CPAI's schematic drawing of the well are not consistent. Which values are correct? Casing MD on Sundry Application Form MD on Schematic Drawing Surface 2334 - 2253 Intermediate 13882 13898 Liner 21669 Not shown Thank you, Steve Davies Senior Petroleum Geologist AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve davies@alaska.gov. Davies, Stephen F (DOA) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, May 8, 2019 1:07 PM To: Loepp, Victoria T (DOA) Subject: CD5-24 Intermediate TOC Log (PTD 219-006) Attachments: ConocoPhillips_CDS-24_TOC.pdf; CD5-24 Plot Report.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Over the weekend, CD5-24 logged for top of cement for the intermediate casing cement job using Schlumberger's Son icScope evaluation tool. We logged from 7900' MD/5169' TVD to 13300' MD/7534' TVD. The Kuparuk C Sand producing formation top is at 12750' MD/7339' TVD. The cement job went as planned with no losses, bumped our plugs and floats held. We pumped a large excess of cement to beneficially effect our casing load collapse case and optimize our gas lift mandrel placement. Total cement pumped was 110 bbls 13 ppg Class G lead cement and 130 bbls 15.8 ppg Class G tail cement. TOC log is attached along with cement job pump report. Top portion of Sonic log shows free ringing pipe while lower portion shows cement log. The Schlumberger log interpreter did not find a definitive top of cement, indicating top of cement is above where we started the log at 7900' MD. See comments in Comment Section of Log. Due to top of cement being above where we started logging at 7900' MD, we will use 7900' MD as top of cement for the CD5-24 Frac Sundry, to be submitted shortly. 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N u_ O .3 Z i Q a 00 N N Ln LA � N U V D Q � Q U O N CL QGp V c 0 CL m d 0-- a) v m @ CL a .ti a N V ° u � n o Q cc o c h a v n O :q.,_ $ = z a c o 0 t+ m 2` o u ° ° 0 a � C 2 V y Q O c C3 u 13 a o a d O a t�1i a o c : 0 0 .0 n C 0-- a) v m @ CL CL a� H v � t U M M N O ¢ O .T I ri C M O °a C CL CL a O , OQ tw N Q LL �3 a v O O LL N y LL 3 Z p L Q � a Z M N 0 co N 1 � @ LA Q a a OC U I II O I N i i n O ¢ a .T y R °a LL £yp OQ Q LL a N s y LL y U p 1 g C 00 I m m m q G 01 O 1� 1 m 3FSti C111a 8 -- � � F e s • iii oo i lUu pro _�i9 —aa4 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, May 8, 2019 4:09 PM To: Polasek, Tom G Subject: CRU CD5-24 (PTD 219-006) Intermediate TOC Log Tom, A CBL will not be required to verify TOC for the approval of the future frac sundry. 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.Loei)r)0alaska aov 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 Victona.Loepp@aIaska.gov From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, May 8, 2019 3:41 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]CD5-24 Intermediate TOC Log (PTD 219-006) Hi Victoria, Calculated top of cement is 10362' ft with 20% washout and 9663' MD without washout. We started our log above where we thought top of cement would be, but did not find a definitive top of cement. The large volume of cement we pumped likely played a role in this. In order to show a top of cement and better assess the cement job we can run a CBL log. Due to a successful cementjob, I waited until all the cement evaluation and logs were available and submitted them when they were all available, which they all became available yesterday. In a circumstance where the cement job does not go according to plan, my understanding was we needed to contact the State immediately to discuss possible remediations or logs prior to moving forward. I apologize, I was mistaken in my interpretation and in waiting to send the initial cement job report prior to drilling out the intermediate on this well. I will ensure to supply each piece of information, as soon as it becomes available, on all future wells. I Please advise if AOGCC would like us w go ahead and run a CBL on CD5-24 to find ne top of cement and/or if required for approval of a future frac sundry. Thank You Victoria, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.e.polasek@conocophillips.com From: Loepp, Victoria T (DOA) <victoria.loepp(aalaska.gov> Sent: Wednesday, May 08, 2019 1:58 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Subject: [EXTERNAL]CD5-24 Intermediate TOC Log (PTD 219-006) Tom, The intermediate cement job was pumped on 3/4/19. A review of this cement job is required before drilling out of the intermediate. Right after the cement job is complete, we expect to seethe information that was just provided with the addition of a calculated TOC. Please provide the calculated TOC. Conditions of Approval for running the sonic log: Approval is granted to run the (USIT)Sonic on upcoming well KRU xx (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. S. 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. 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.Loeoo(Walaska aov 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 _ disclosure of such information may violate state u..ederal 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.Loeoo@alaska.gov From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Wednesday, May 8, 2019 1:07 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: CD5-24 Intermediate TOC Log (PTD 219-006) Hi Victoria, Over the weekend, CD5-24 logged for top of cement for the intermediate casing cement job using Schlumberger's SonicScope evaluation tool. We logged from 7900' MD/5169' TVD to 13300' MD/7534' TVD. The Kuparuk C Sand producing formation top is at 12750' MD/7339' TVD. The cement job went as planned with no losses, bumped our plugs and floats held. We pumped a large excess of cement to beneficially effect our casing load collapse case and optimize our gas lift mandrel placement. Total cement pumped was 110 bbls 13 ppg Class G lead cement and 130 bbls 15.8 ppg Class G tail cement. TOC log is attached along with cement job pump report. Top portion of Sonic log shows free ringing pipe while lower portion shows cement log. The Schlumberger log interpreter did not find a definitive top of cement, indicating top of cement is above where we started the log at 7900' MD. See comments in Comment Section of Log. Due to top of cement being above where we started logging at 7900' MD, we will use 7900' MD as top of cement for the CDS-24 Frac Sundry, to be submitted shortly. Thank you Victoria and please let me know if you have any further questions Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com COMPANY: ConocoPhillips Alaska LLC. n c/) —n WELL: CD5-24 OM 0 FIELD: D r r $ ATE: Alalska River Unit COD 2'— MP r D COUNTRY: USA C2 • Location — n v 0 (n U O 0 O D Cn 03CW < N0 0 O • CD 0 Cm CD 0) •CD W • r � r 1111111111111111119 • C7 Vf ► FOLD HERE: The well name, loceton and borehole reference data were furnished by the customer. Any interpretation, research, analysis, data, results, estimates, or recommendation furnished with the services or otherwise conmunicaled by Schlumberger b the customer at any tme in connecton with the services are opinions based on inferences from measurements, empirical relationships, ands assumptions; which, inferences, empirical relationships and/or assumptions are not infallible and with respect b which professionals in the industry may doer. Accordingly, Schlumberger cannot and does not warrantthe accuracy, correctness, or completeness of any such interpretation, research, analysis, data, results, estimates, or recommendation. The customer acknowledges that it is accepting to services "as is," that Schlumberger makes no representation or warranty, express or implied, of any kind or description in respect tnereb, and that such sery ices are delivered with the explicit understanding and agreement that any action taken based on the services received shall be at its own risk and responsibility, and no claim shall be made against Schlumberger as a consequence thereof. Svc. Order #: OP Vers: Processed by: Process Date: 5/6/2019 Location: Techlog 2017.2 e-mag.jburt2@slb.com -111 M Free pipe was measured from 2180-2320 ft MD. Over the measured interval 7900-13450 ft MD, no top of cement was indicated as a difinitive top is suggested to be above 7900 ft MD. Processing parameters summary Casing Amplitude#1 Casing shoe depth: 9612 ft Casing inner diameter. 6.875 in Casing outer diameter. 7.625 in Filter length: 17 Filter band high: 16000.0 H,t Fiherband low: 10000.0 Hz Peskde[ectionmode:Peak-to-Peak Time window start 400.0 us Timewindowstop:600.0us Waveform monopole high frequency. W FA MHTDepth sampling rah: 0.166667 f, Source Frequency: Monopole wideband Waveform step: 20 us Waveform start 0.0 us Casing CSID_PREVEIW 5 in 8 CSOD PREY W O to to to to CD CID (0 fD e- O -:NM V NtL IACD O 5 In 8 0 0 0 0 0 0 0 0 0 e- V eferenc -2144.79 (ft) WFA MHT- R 1 SPR _MH_FA_R_1 CASING_ AMP_ RAW_ R1_2 WFA MHT -R1 1:480 -2764 2528 40 us/ft 240 -20 unitless 100 -2764 2528 I 2200 `! we i 2300 I I I ei Casing CSID_PREVEIW 5 in 8 CSOD_PREVEIW O in to toLn tD (0 (D C O r -N M"ttn(Oh CD O 5 In 8 0 0 0 O O O O O O r- VE eferenc -2144.79 (ft) WFA_MHT- R 1 SPR_MH_FA_R_1 CASING_ AMP_RAW _R1_2 WFA MHT- R 1 7:480 _2764 2528 140 us/ft 240 -20 unitless 100-1-2764 2528 Company: ConocoPhillips Alaska, Inc. Well: CD5-24 Field: Colville River Unit State: Alaska API: 50-103-20799-00-00 Schlumberger Schlumberger WON CDS-2r Field GM engllMer Stephen UUPw Cementing Job Report CRmt CPAP SIR Ne. 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02:18:57 34 6.1 3.46 0.0 3 03/05/2019 02:19:57 32 6.1 3.45 0.0 4 03/05/2019 02:20:57 34 6.1 3.45 0.0 6 03/DS/2019 02:21:5] 34 6.1 3.45 0.0 -6 03/05/2019 02:22:57 35 6.1 3.45 0.0 -84 03/05/2019 02:23:57 33 6.1 3.45 0.0 -]4 03/05/2019 02:24:57 34 6.1 3.46 0.0 -7p 03/05/2019 02:25:57 29 6.1 3.46 0.0 89 03/05/2019 02:26:57 29 6.1 3.45 0.0 94 03/05/2039 02:2]:5] 28 6.1 3.45 0.0 97 03/05/2019 02:28:57 29 6.1 3.46 0.0 -9 03/05/2019 02:29:57 32 6.1 3.45 0.0 D 03/05/2019 02:30:57 33 6.1 3.46 0.0 26 03/05/2019 02:31:57 30 6.1 3.45 03/05/2019 02:32:57 30 6.1 3.46 0.0 109 03/05/2019 02:33:57 29 6.1 3.45 0.0 112 03/05/2019 02:34:57 29 6.1 3.45 0.0 312 03/05/2019 02:35:57 29 6.1 3.45 0.0 111 03/05/2019 02:36:57 29 6.1 3.46 0.0 69 03/05/2019 02:37:57 29 6.1 3.46 0,0 64 03/05/2019 02:38:57 28 6.1 3.46 0.0 69 03/05/2019 02:39:57 29 6.1 3.46 0.0 110 03/05/2019 02:40:57 29 6.1 3.46 0.0 120 03/05/2019 02:41:57 30 6.1 3.46 0.0 121 03/05/2019 02:42:57 30 6.1 3.46 0.0 122 03/05/2019 02:43:57 30 6.1 3.46 0.0 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03:06:57 32 6.1 3.47 0.0 438 03/05/2019 03:07:57 30 6.1 3.47 0,0 435 03/05/2019 03:08:57 30 6.1 3.47 0.0 486 03/05/2019 03:09:57 31 6.1 3,47 0.0 482 03/05/2019 03:10:57 30 6.1 3.08 0.0 474 03/05/2019 03:11:57 305 6.1 6.65 0.0 344 03/05/2019 03:12:57 283 6.1 6.16 0.0 387 09/05/2019 03:13:5]276 6.1 5.71 0.0 477 03/05/2019 03:14:57 268 6.1 5.68 0.0 561 03/05/2019 03:15:57 259 6.1 5.67 0.0 565 03/05/2019 03:16:57 251 6.1 5.67 0.0 SR 03/05/2019 03:17:57 247 6.1 5.6] 0.0 565 03/05/2019 03:18:57 242 6.1 5.67 0.0 572 03/05/2019 03:19:57 242 6.1 5.67 0.0 1473 03/05/2019 03:20:57 239 6.1 5.67 0.0 097 03/05/2019 03:21:5] 236 6 1 5 67 0 0 485 03/05/2019 03:22:5] 235 6.1 5.67 0.0 503 03/05/2019 03:23:57 233 6.1 5.67 0.0 496 03/05/2019 03:24:57 231 6.1 5.67 0.0 563 03/05/2019 03:25:57 230 6.1 5.67 0.0 568 03/05/2019 03:26:57 229 6.1 5.67 0.0 561 03/05/2019 03:27:57 229 6.1 5.67 0,0 557 03/05/2019 03:28:57 232 6.1 5,67 0.0 421 03/05/2019 03:29:57 229 6.1 5.67 0.0 503 03/05/2019 03:30:57 228 6.1 5.67 0.0 479 03/05/2019 03:31:57 228 6.1 5.67 0.0 471 03/05/2019 03:32:57 226 6.1 5.67 0.0 479 03/05/2019 03:33:57 224 6.1 5.67 0.0 563 03/05/2019 03:34:57 224 6.1 5.67 0.0 570 03/05/2019 03:35:57 222 6.1 5.67 0.0 558 03/05/2019 03:36:57 223 6.1 5.67 0.0 563 03/05/2019 03:37:57 222 6.1 5.66 0.0 554 03/05/2019 03:38:57 39 6.1 5.66 0.0 439 03/05/2019 03:39:57 37 6.1 5.66 0.0 478 03/05/2019 03:40:57 40 6.1 6.17 0.0 477 03/05/2019 03:41:57 45. 6.1 5.43 0,0 472 03/05/2019 03:42:57 50 6.1 5.83 0.0 493 page 5N 11 wa Dab CDS-24 CDS-24 Tlma 24-br dotlt Flaln Teetln# Prrotun av GPs WNO aei !a.ft Job MA Mar/04/2019 a/M CUKomer y"gP lab Number CPAI Nuee9a 03/05/2019 03:44:57 263 6.1 6.16 0.0 556 03/05/2019 03:45:5] 257 6.1 5,83 0 0 566 Good Pf 03/05/2019 03:46:57 252 6.1 5.28 0.0 566 Battler# MPII 11.5# 03/05/2019 03:47:57 250 6.1 5.28 0.0 496 03/05/2019 03:48:57 246 6.1 5.27 0.0 485 03/05/2019 03:49:57 243 6.1 5.27 0.0 487 03/05/2019 03:50:57 221 6.1 5.26 0.0 559 03/05/2019 03:51:57 220 6.1 5.26 0.0 580 03/05/2019 03:52:57 216 6.1 5.26 0.0 292 03/05/2019 03/05/2019 03:53:23 03:53:57 213 212 0.0 0.0 5.26 5,26 0.0 0.0 205 108 $tart bb 03/05/2019 03:54:57 209 0.0 5.26 0.0 103 MuOsuled 11.5# 03/05/2019 03/05/2019 03:55:35 03:55:57 209 208 0.0 0.0 5.26 5.26 0.0 0,0 92 92 Water Abend 03/05/2019 04:13:57 03/05/2019 03:56:57 158 0.8 5.14 0.0 171 04:14:57 556 03/05/2019 03/05/2019 03/05/2019 03:57:42 03575] 03:58:21 122 134 1022 0.8 0.9 1 n 5.09 5.07 0.0 0.8 175 185 low Pf Uerk mx 25.6 03/05/2019 03/05/2019 03:58:43 03:58:57 951 2425 - - 1.0 1.0 - 5.04 5.03 u.0 0.0 D.1 1109 3015 2513 TdM Wena ! 1000 Nlgh Pr 4500# 03/05/2019 03:59:57 4550 1.0 5.03 0.0 4503 03/05/2019 03/05/2019 04:00:25 04:00:57 4537 7 1.D 1.0 5.05 5.05 0.0 0.0 4485 -55 Good Pf 03/05/2019 03/05/2019 04:01:57 04:02:57 117 168 1.0 1.0 6.57 8.29 0.0 0.0 53 55 Battler# MPII 11.5# 03/05/2019 04:03:57 166 1.0 8.88 0.0 51 03/05/2019 04:04:57 165 1.0 10.71 0.0 57 03/05/2019 04:05:57 165 1.0 11.61 0.0 65 03/05/2019 04:06:57 162 1.0 11.16 0.0 69 03/DS/2019 04:07:57 161 1.0 11.53 0.0 65 03/05/2019 04:08:57 161 1.0 11.83 p,p 62 03/05/2019 03/05/2019 04:09:14 04:09:57 116 479 1.0 2.1 11.72 31.69 0.0 3.6 78 302 $cert p+mpM Spacer 03/05/2019 03/05/2019 04:30:57 04:11:57 626 632 5.8 9.9 11.22 11.26 4.1 4.1 328 332 MuOsuled 11.5# 03/05/2019 04:12:57 581 13.7 11.52 3.9 305 03/05/2019 04:13:57 595 17.6 11.53 3,9 308 03/05/2039 04:14:57 556 21.6 11.13 4.0 301 03/05/2019 04:15:57 591 25.6 11.36 3,g 298 03/05/2019 04:16:57 527 29.5 11.52 3.8 289 03/05/2019 04:17:57 S43 33.3 11.46 3.8 262 D3/05/2019 04:18:57 531 37.1 11.51 3.9 176 03/05/2019 04:19:57 521 40.9 31.50 3.9 170 03/05/2019 x:20:57 545 ".a 11.51 3.9 175 03/05/2019 04:21:57 506 48.7 13.46 3.9 17] 03/05/2019 04:22:57 556 52.6 11.61 3.9 302 03/05/2019 04:23:57 518 56.5 11.92 3.8 384 03/05/2019 04:24:n 226 60.0 11.50 0.0 181 03/05/2019 03/05/2019 03/05/2019 03/05/2039 04:25:04 04:25:23 04:25:36 01:25:57 103 104 67 85 60.0 60.0 0.0 0.0 11.49 11.48 11.48 31.47 0.0 0.0 O.p p.0 109 101 63 65 End Spacer PESO Trial, Vol 60.02 bd loafing Bottom pug 03/05/2019 04:26:57 37 0.0 33.35 0.0 -65 03/05/2019 04:27:57 35 0.0 11.34 D.0 -55 hoe 4 x111 Wad CDS-24 CDS-24 Meb GM Jab Sb.rt Mdr/04/2019 cooto r Cpp1 Job Numbq Data JMr tl k pro .SK m S M / W Mru9d 03/05/2019 04:29:57 64 0.0 A. 0.0 11 03/05/2019 04:30:53 103 0.0 8.60 D.0 43 Bd[dibg 111'!6 Cn8 13# 03/05/2019 04:30: SJ 101 0.0 8.63 0.0 40 03/05/2019 04:31:57 118 0.0 11.15 0.0 42 03/05/2019 04:32:57 140 0.0 13.39 0.0 42 03/05/2019 04:33:57 138 0.0 13.08 0,0 46 03/05/2019 04:34:57 138 0.0 13.08 0,0 48 03/05/2019 03/05/2019 04:35:30 04:35:57 127 133 0.0 0.2 13.06 13.08 0.0 0.0 57 129 ROM Cbm Slurry 13# 03/05/2019 04:36:57 76 0.2 13.08 03/05/2019 04:37:57 461 0.7 13.07 3.6 269 03/05/2019 04:38:57 657 4.4 12.96 3,7 341 03/05/2019 04:39:57 '728 8.0 13.80 3.6 276 03/05/2019 04:40:57 665 11.7 13.30 3,7 220 03/05/2019 04:41:57 693 15.4 1316 3.8 237 03/05/2019 04:42:57 683 19.3 13.05 3.8 296 03/05/2019 04:43:57 709 23.1 13.16 4.0 320 03/05/2019 04:44:57 739 27.1 12.98 4.1 322 03/05/2019 01:45:57818 31.6 12.66 4.6 337 03/05/2019 04:46:57 850 36.2 13.13 4.6 207 03/05/2019 04:47:57 664 40.3 13.20 4.0 173 03/05/2019 04:18:57 61544.3 13.13 4.0 152 03/05/2019 04:49:57 701 48.3 12,99 4.2 2]1 03/05/2019 04:50:57 774 52.8 13.04 4.6 282 03/05/2019 04:51:57 769 57.4 13.06 4.6 266 03/05/2019 04:52:57 742 61.9 13.18 1,5 254 03/05/2019 01:53:57 713 66.4 13.11 4.5 218 03/05/2019 04:54:57 703 70.9 13.01 4.5 120 03/05/2019 01:55:57 689 75.3 13.14 4,5 180 03/05/2019 04:56:57 665 79.8 12.97 4.4 161 03/05/2019 04:57:57 652 84.2 13.10 4.4 161 03/05/2019 04:58:57 654 88.6 13.09 4,4 yqg 03/05/2019 04:59:57 664 93.0 13.0] 03/05/2019 05:00:57 643 97.4 13.11 4.4 152 03/05/2019 05:01:57 669 101.8 13.06 4.4 159 03/05/2019 05:02:57 634 106.2 13.03 4.4 160 03/05/2019 05:03:57 129 110.0 13.26 1.4 55 03/05/2019 03/05/2019 05:04:09 05:04:57 42 39 110.1 110.1 13.26 13.26 0,0 0.0 40 31 End OwWt Sgery 13S 03/05/2019 03/05/2019 05:05:50 05:05:57 124 128 110.1 0.0 11.72 12.15 0.0 0.0 28 27 Hess Tdtl, Vd .110.06 bbl 03/05/2019 05:06:57 127 0.0 31.79 0,0 -q3 03/DS/2019 05:07:57 303 0.0 11.76 0,0 37 03/05/2019 05:08:57 116 0.0 8.9p 0.0 37 03/05/2019 05:09:57 97 0.0 B.fi2 D.0 H 03/05/2019 05105] 103 0.0 H.39 0.0 -53 03/05/2019 05:11:57 96 0.0 8.28 0.0 -10 03/05/2019 05:12:57 93 0.0 8.18 0.0 16 03/05/2019 05:13:5] 92 0.0 8.11 0.0 16 03/05/2019 05:14:57 91 0.0 7.77 0.0 20 D3/05/2019 05:15:57 91 0.0 7,58 0,0 20 03/05/2019 05:16:57 90 0.0 7.M 0.0 IJ 03/05/2019 03/05/2019 05:17:51 05:17:57 90 101 0.0 0.0 7.77 8.20 0.0 0.0 iJ BdtNkg [mt IS.BS 16 p4M74/1J vaev a all WM am CDS-24 CDS-24 lona 946, tlxk tnatlre P.a PR aiN GPS WNv aei �1! G lM and Mar/04/2019 :/M CUR r MP � l Num CPpy NYMaa 03/05/2019 05:19:57 151 0.0 35.50 p,p 97 03/05/2019 05:20:-- ]03/05/2019 03/ S/ 03/05/2019 05:21:37 05:21:57B+OY 534 619 0.9 2.1 15.85 I5.96 3.8 3.8 103 134 $tart [ammt5 15.8# 03/05/2019 05:22:57 917 6.3 15.86 4.8 161 03/05/2019 05:23:57 976 11.2 35.95 4.8 yly 03/05/2019 05:24:57 781 15.8 15.75 4./ 154 03/05/2019 05:25:57 843 20.3 15.95 4.5 161 03/05/2019 05:26:57 747 24.6 15.77 4.3 150 03/05/2019 05:27:57 764 28.9 15.86 4.3 152 03/05/2019 05:28:57 785 33.2 15.90 4.4 160 03/05/2019 05:29:57 823 37.8 15.83 4.5 160 03/05/2019 05:30:57 863 42.3 15.79 4.6 164 03/05/2019 05:31:57 820 46.9 15.79 1.6 159 03/05/2019 05:32:57 839 51.9 15.84 4.5 363 03/05/2019 05:33:57 850 56.0 15.83 1.5 160 03/05/2019 05:3457 827 60.5 15.82 4,5 150 03/05/2019 05:35:57 853 65.1 15.89 4.5 160 03/05/2039 05:36:57 830 69.6 15.82 4,5 147 03/05/2019 05:37:57 847 74.1 15.90 4.5 156 03/05/2019 05:38:57 621 78.7 15.76 4.5 159 03/05/2019 05:39:57 616 83.1 15.85 4.5 142 03/05/2019 OS:4D:57 837 87.6 15.8] 4.5 152 03/05/2019 05:41:57 805 92.1 15.78 4.5 396 03/05/2019 05:42:57 837 96.6 15.87 4.5 153 03/05/2019 05:43:57 823 101.1 15.87 4.5 153 03/05/2019 05:44:57 829 105.6 15.79 4.5 152 03/05/2019 05:45:57 830 110.1 15.82 4.6 162 03/05/2019 05:46:57 840 114.6 15.83 4.5 163 03/05/2019 05:47:57 860 119.1 15.82 4.5 171 03/05/2019 05:48:57 838 123.7 15.83 4.6 156 03/05/2019 05:49:57 929 128.2 15.63 4.5 166 03/05/2019 03/05/2019 03/05/2019 05:50:36 05:50:41 05:50:57 63 46 52 130.0 130.0 0.0 15.62 15.62 15.62 0.0 0.0 0.0 52 50 51 fvM Cemart Slum/ 15.8# P�TOW, Vd . 130.00 ml 03/05/2019 D3/05/2019 05:51:01 05:51:57 52 107 0.0 0.0 15.62 13.86 0.0 0.0 51 52 LOWin9 TbP Pkp 03/05/2019 05:52:57 323 0.0 11.62 p,p 51 03/05/2019 05:53:57 115 0.0 12.11 0.0 48 03/05/2019 05:54:57 107 0.0 12.41 0.0 43 03/05/2019 05:55:57 103 0.0 12.34 0.0 49 D3/OS/2019 05:56:57 99 0.0 1234 0.0 48 03/05/2019 05:57:57 9/ 0.0 12.31 0.0 49 03/05/2019 05:58:57 91 0.0 12.24 03/05/2019 05:59:57 88 0.0 12.24 p,p q5 03/05/2019 06:00:57 86 0.0 12.24 10.0 35 03/05/2019 06:01:57 84 0 0 12 23 0 0 34 03/05/2019 03/05/2019 06:02:46 06:02:57 78 112 0.0 0.1 12.23 12.22 0.0 2.8 32 Wax BMIM 45 03/05/2019 06:03:57 376 3.9 32.05 3.9 67 03/05/2019 06:04:57 322 7.9 9.13 4,0 53 03/05/2019 06:05:57 321 11 9 8.43 4.0 56 03/05/2019 06:06:57 313 15.9 8.36 4.0 58 03/05/2019 06:07:57 312 20.0 8.31 4.0 56 vaev a all WWI xab CD5-24 CDS-24 Tm4 f1n 714atlnp RIWG GPB WIIR 6u wIg p los Slaw Mar/04/2019 ! M �oW°mv Cppl los xumbar Muw9a 03/05/2019 03/05/2019 06:08:15 06:08:57 40 43 20.3 0.0 8.35 8.34 0.0 D.0 28 TOW, Vol 22 20.27 Ebl 03/05/2019 06:09:57 32 0.0 8.340.0 35 03/05/2019 06:10:57 31 0.0 8.34 0.0 36 03/05/2019 06:11:57 36 0.0 8.33 0.0 33 D3/05/2019 06:12:57 59 0.0 8.33 0.0 36 03/05/2019 06:13:57 29 0.0 8.32 0.0 K 03/05/2019 06:14:57 28 0.0 8.33 0.0 42 03/05/2019 D6:15:57 29 0.0 8.33 0.0 58 03/05/2019 06:16:57 31 0.0 8.53 0.0 69 03/05/2019 06:17:57 30 0.0 12.11 0.0 102 03/05/2019 06:18:57 29 0.0 12.92 0.0 119 03/05/2019 06:19:57 29 0.0 12.99 0.0 115 03/05/2019 06:20:57 27 0.0 12.31 0.0 113 03/05/2019 06:21:57 26 0.0 11.87 0.0 110 03/05/2019 06:22:57 26 0.0 10.97 0.0 112 03/05/2019 06:23:57 27 0.0 10.96 0.0 114 03/05/2019 06:24:57 28 0.0 11.15 0.0 112 03/05/2019 06:25:57 27 0.0 10.85 0.0 109 03/05/2019 06:26:57 29 0.0 10.69 0.0 112 03/05/2019 06:27:57 28 0.0 8.72 0.0 117 03/05/2019 06:28:57 28 0.0 8.73 0.0 116 03/05/2019 06:29:57 28 0.0 8.75 0.0 115 03/05/2019 06:30:57 28 0.0 8.74 0.0 112 03/05/2019 06:31:57 27 0.0 8.75 0.0 11l 03/05/2019 06:32:57 27 0.0 8.74 0.0 118 03/05/2019 06:33:57 27 0.0 8.73 0.0 115 03/05/2019 06:34:57 28 0.0 8.73 0.0 112 03/05/2019 06:35:57 28 0.0 8.73 0.0 111 03/05/2019 06:36:57 27 0.0 8.]2 0.0 110 03/05/2019 06:37:57 28 0.0 8.72 0.0 115 03/05/2019 06:38:57 28 0.0 8.30 0.0 113 03/05/2019 06:39:57 28 0.0 6.52 0.0 107 D3/05/2019 06:40:57 28 0.0 8.35 0.0 109 03/05/2019 06:41:57 28 0.0 8.35 0.0 117 03/05/2019 06:42:57 27 0.0 8.35 0.0 112 03/05/2019 06:43:57 27 0.0 8.34 0.0 110 03/05/2019 06:45:57 27 0.0 8.35 0.0 30 03/05/2019 06:46:57 26 0.0 8.36 0.0 36 03/05/2019 06:47:57 79 0.0 8.35 0.0 30 03/05/2019 06:48:57 28 0.0 7.25 0.0 28 03/05/2019 06:49:57 27 0.0 8.03 0.0 26 03/05/2019 06:50:57 96 0.0 8.32 0.0 38 03/05/2019 06:51:57 30 0.0 0.01 0.0 105 03/05/2019 06:52:57 30 0.0 0.00 0.0 109 03/05/2019 06:53:5] 28 0.0 0.00 0.0 104 03/05/2019 06:54:57 102 0.0 8.30 0.0 104 03/05/2019 06:55:57 29 0.0 8.12 0.0 109 03/05/2019 06:56:57 92 0.0 8.27 0.0 109 03/05/2019 06:57:57 72 0.0 8.14 0.0 131 03/05/2019 06:58:57 105 0.0 8.19 0.0 141 03/05/2019 06:59:57 134 0.0 8.20 0.0 152 03/05/2019 07:00:57 165 0.0 8.20 0.0 175 03/05/2019 07:01:41 170 0.0 8.14 0.0 161 Mpa mm Rays R N ll Wap CDS-24 CDS-24 Pl.m Gn Iao MA Mar/04/2019 Cwtamer CPAI MNumaar OaM Tama ]4N tloak TmPWp Ptiwn P8f WNP NL Matey V/i Nab i/N WHP PSI MamaSa 03/05/2019 07:02:57 108 0.0 8.21 0.0 193 03/05/2019 07:03:57 108 0.0 8.22 0.0 204 03/05/2019 07:04:57 134 0.0 8.22 0.0 215 03/DS/2019 07:05:57 46 0.0 7.59 0.0 233 03/05/2019 07:06:57 46 0.0 7.47 0.0 2" 03/05/2019 07:07:57 46 0.0 7.35 0.0 261 03/05/2019 07:08:57 35 0.0 6.93 0.0 267 03/05/2019 07:09:57 35 0.0 6.89 0.0 288 03/05/2019 07:10:57 35 0.0 6.86 0.0 305 03/05/2019 07:11:57 36 0.0 6.83 0.0 317 03/05/2019 07:12:57 35 0.0 6.80 0.0 313 03/05/2019 07:13:30 35 0.0 6.78 0.0 329 Cenwt M shoe 03/05/2019 07:13:57 35 0.0 6.77 0.0 332 03/05/2019 07:14:57 33 0.0 6.75 0.0 348 03/05/2019 07:15:57 33 0.0 6.74 0.0 366 03/05/2019 07:16:57 34 0.0 6.71 0.0 373 03/05/2019 07:17:57 33 0.0 6.70 0.0 392 03/05/2019 07:18:57 33 0.0 6.68 0.0 399 03/05/2019 07:19:57 33 0.0 6.66 0.0 422 03/05/2019 07:20:57 32 0.0 6.65 0.0 440 03/05/2019 07:21:57 33 0.0 6.63 0.0 453 03/05/2019 07:22:57 33 0.0 6.62 0.0 476 03/05/2019 07:23:57 33 0.0 6.61 0.0 518 03/05/2019 07:24:57 32 0.0 6.60 0.0 538 03/05/2019 07:25:57 32 0.0 6.58 0.0 555 03/05/2019 07:26:57 31 0.0 6.57 0.0 580 03/05/2019 07:27:57 31 0.0 6.56 0.0 612 03/05/2019 07:28:57 30 0.0 6.56 0.0 617 03/05/2019 07:29:57 30 0.0 6.55 0.0 665 03/05/2019 07:30:57 29 0.0 6.54 0.0 706 03/05/2019 07:31:57 30 0.0 6.54 0.0 739 03/05/2019 07:32:57 29 0.0 6.53 D.0 555 03/05/2019 07:33:57 30 0.0 6.53 0.0 591 03/05/2019 07:34:57 30 0.0 6.52 0.0 603 03/05/2019 07:35:57 30 0.0 6.52 0.0 639 03/05/2019 07:36:57 30 0.0 6.52 0.0 657 03/05/2019 07:37:57 29 0.0 6.51 0.0 669 03/05/2019 07:38:57 28 0.0 6.51 0.0 695 03/05/2019 07:39:57 29 0.0 6.50 0.0 708 03/05/2019 07:40:57 28 0.0 6.50 0.0 730 03/05/2019 07:41:57 28 0.0 6.49 0.0 745 03/05/2019 07:42:57 29 0.0 6.49 0.0 762 03/05/2019 07:43:57 28 0.0 6.49 0.0 764 03/05/2019 07:":57 28 0.0 6.49 0.0 7" 03/05/2019 07:45:57 28 0.0 6.49 0.0 656 03/05/2019 07:46:57 28 0.0 6.49 0.0 657 03/05/2019 07:47:57 28 0.0 6.49 0.0 665 03/05/2019 07:48:57 27 0.0 6.48 0.0 710 03/05/2019 07:49:57 28 0.0 6.48 0.0 714 03/05/2019 07:50:57 27 0.0 6.47 0.0 704 03/05/2019 07:51:57 26 0.0 6.47 0.0 1114 03/05/2019 07:52:1225 0.0 6.48 0.0 1109 Bumf Plug at 6040 03/05/2019 07:52:57 26 0.0 6.47 0.0 1106 03/05/2019 07:53:57 25 0.0 6.47 0.0 1108 Pp Lo of 11 Wall Dab CDS-24 CDS-24 lima Traetbq PNuVm Flet GM WNP RK �j� gWHP03/05/2019 ]ab StM Mar/04/2019 Cumomer CPAI f 07:55:09 27 0.0 6.47 0.0 N2 F 03/05/2019 07:55:57 27 0.0 6.4] 0.0 1027 RS 03/05/2019 07:56:57 27 0.0 6.46 0.0 458 03/05/2019 07:57:57 27 0.0 6.46 0.0 19 03/05/2019 07:58:57 27 0.0 6.46 0.0 42 SmaYmwn MUNI 03/05/2019 07:59:57 25 0.0 6.46 0.0 47 03/05/2019 08:00:57 26 0.0 6.46 0.0 48 28 03/05/2019 08:01:57 25 0.0 6.460.0 48 03/05/2019 08:02:57 26 0.0 6.46 0.0 44 03/05/2019 08:03:57 29 0.0 6.45 0.0 195 03/05/2019 1 08:04:27 28 0.0 6.46 0.0 563 Fbad.GoW Post jou summary ,Me ii a ll A.M. Pum, Rata, bd/Mn Vabme elfbmm ]rrle�mi 6N Slurry N2 Mud MaeMum Rab Tobi Skur Mum Sour RS 4.1 4.9 240.0 0.0 60.0 WuDM Pmuum Summer,, pN SmaYmwn MUNI M&W.M RM A.M. Rum, Pbpb sraakmown Tue ValuuM 4610 28 176 1100 Damih bd Ib/gal An. N2, t DeMSnam Su" Vobme DNpleamnau Nb Wabr Tem, Camant grabmembiurb,e] Vabma % 00M 0.0 bd BO megF Dd Waahem Thm Paha Ej To R Cmrtamer or AutlMNsa- Rapreaenbtlue Stlllumber9ar su uvi. Cbvrbsm Leat J CuKbtam P. -Y Angell- SteWlen l uper O ,Me ii a ll Schlumberger Service Quality Evaluation awnu CPAI Field: GPS IDS' Doyon 19 wall: CDS-29 Souks tine: Cementing Job Type: Intermediate e: NSE Score Mar/04/2019 e (hh:mm): F 00:00 Free of lost time Injury and COMPllanCa with Sly and kc. spec. MSE practice Port, Angelis Engineer: Stephen tauper FSM: AYrdle EMNon Main Objective: Cement Intermediate To be completed by Company Rep. please answer Y (Yu) or N (NO) and add My enmmaMc below. 1 NSE Score Yea / No Result IN Free of lost time Injury and COMPllanCa with Sly and kc. spec. MSE practice 2a Program Intl. Job simulation (CemCADE) & pump schedule / tool hydraulic calm lb I Free of environments, split or non-compbnt oisdwrge 5 "a n no ❑ 5 3c Wdlsite IeR dean 5 yea [ltI no ❑ 5 n no 9 Yes [>(] no ❑ 4 All materials and equipment required for Job/contingen,, tlNaetl & on location 2 Yen Sutrtotnl lOOY. 2 D Wgn / PrapMdW Client Signature: Schlumberger Signabrc: 2a Program Intl. Job simulation (CemCADE) & pump schedule / tool hydraulic calm 2b EWipment maintencech anschedule COMPleted / Green tagged 3 yea n no E]3 2c All materials and equipment required for Job/contingen,, tlNaetl & on location 2 Yen IX NO NO ❑ 2 2d Safety / Pm -Jab mating Conducted wkh all involved present 2 Vas Lffal no ❑ 2 2 yea ❑I No ❑ 2 Sutrtotal 100% ssou"t time < 30 minjEaW ipment pressureuccesfu tV 3 yen X nekey ❑ 3 parameters d aM rewNed acareteN (pressure, Rate, Density) 3Yoa [XI ao ❑ 3 s /darts releasested suo>esfulN 2 Yea [I(� no ❑ 2 sity variatbn anations2 FFMea� YM [X ne ❑ 2 Onnd performedxpectationsVas 2 )t repipment ❑ 2 performeexPettatlore 2 Yea [>I] rq ❑ 2 Pumped as per d 2 yea[X� rro ❑ 2 Job start M time 3 Y4a [X� no ❑ 3 of Operational fscreen out, Cementing Example, etc.) 2 y4e 3t no ❑ 2 3 Yea n no ❑ 3 sub -total 100% 4 Evaluation 4a I Main Job obJeWVN atlueved with no consequential non-produGive time I�I 10 Yaa twl no ❑ 10 suo-tike, 100% Tool 100% ...r,..,,.m arw vummanz4 any Client: Inr:watlom attempted M tlrle wall.) Schlumberger: Client Signature: Schlumberger Signabrc: THE STATE Alaska Oil and Gas O'ALASKu A Conservation Commission GOVERNOR MIKE DUNLEAVY Chip Alvord Alaska Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD5-24 Permit to Drill Number: 219-006 Sundry Number: 319-145 Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogc c.al a ska.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, Daniel T. Seamount, Jr. Commissioner DATED this 6- ay of April, 2019. RBDMS — APR 2 3 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20AAn 2c non RECEIVE[ MAR 2 U2019 AOCCC orm 10 -403RD Rev. 6/2004 /// % / INp'11E21JC�IQt� I{EyE q 'I t Z _`f9bmit in Duplicate 3. Permit to Drill laska 219-006 4. API Number: P 50-103-20799-00-00 5. Well 0360, Anchorage, Alaska CD5-24 ' 6. Field: Colville River Unit- Al ine Pool 7. Publicly recorded lls we 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD5-01, CD5-02, CD5-03, CD5-04, CDS-06, CD5-07, CD5-08, CD5-09, CD5-10, CD5-11, CD5-12, CD5-17, CD5-18, CD5-19, Torok and Seabee formation, shale, siltstone and sandstone . CD5-20, CD5-21, CD5-22, CD5-23, CD5-25, 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 claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1,345' MD and 1,320' TVD 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 2035 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 - 16. Estimated start date: 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 27 -Apr -19 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. ematic (Include MD and TVD) Q Cement Bond Log (if required) ❑ FIT Records w/LOT Graph Qng Cementing Data 21 Other Q previous authorization for new product cleanuo fluids for CD1 and CD2 P that the foregoing is true and correct to the best of my knowledge. a kA^� bn _ , , Title: N I! w�. s Printed Name: Phone Chip Alvord Number: 265-6120 Date: (L'i L9f Commission Use Only Conditions of approval: LOT review and approval: a `fuf ---w 9 cICl ^ Subsequent form required: 10 J 4 Approval number: n APPROVED BY Approved by: -� COMMISSIONER THE COMMISSION Date: ( 1 V7L- P? ! orm 10 -403RD Rev. 6/2004 /// % / INp'11E21JC�IQt� I{EyE q 'I t Z _`f9bmit in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 26, 2019 Alaska Oil and Gas Conservation Commission 333 West 7's Avenue, Suite 100 Anchorage, Alaska 99501-3539 ConocoPhillips Re: Application for Sundry Approval for Annular Disposal of DrillingWaste on well CDS 24 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD5-24 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 CD5-24 approximately April 27, 2019 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: CD5-01, CD5-02, CD5-03, CD5-04, CD5-06, CD5-07, CD5-08, CD5-09, CD5-10, CD5-11, CD5-12, CD5-17, CD5-19, CD5-20, CD5-21, CD5-22, CD5- 313, CD5-314X, CD5-315, CD5-316. 12. Information regarding remaining wells within %4 mile radius included in sundry package: CD5-23, CD5-24, CD5-25 13. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (16.0 ppg) occurred at a lower equivalent mud weight than the casing shoe FIT (18.0 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 Andrew Beat at 265-6341 or Chip Alvord can also be reached by calling 265-6120. Sin erely, Andrew eat Drilling Engineer cc: CD5-24 Well File Chip Alvord ATO -1570 Annulus Disposal Transmittal Form - Well CD5-24 AOGCC Reeulations. 20 AAC 25 nxn (m of the well or wells to receive drillin wastes: CD5-24 depth to the base of freshwater aquifers and permafrost, if There are no USD W aquifers in the Colville River Unit. ent. Estimated base of Permafrost = 1320' TVD RKB atigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and lus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation ission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the Fdenation ome to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, 99) t of all publicly recorded wells within one-quarter mile See attached map indicating wells within I/4 mile. There are ll publicly recorded water wells within one mile of the no water wells within 1 mile. to receive drillin wateify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve sed 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. 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 2035 psi. See attached calculation calculations showing how this value was determined. a e. 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: that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. ufficient strength in collapse and burst to withstand tici ated ressure of dis osal oerations: Rnetails he downhole pressure obtained during a formation integrity See attached LOT/FIT report. st conducted belowtheentification of the hydrocarbon zones, if any above the The top of cement is 4761'MD in the intermediate casing epth to which the inner casing is cemented. which covers the uppermost hydrocarbon bearing zone. No hyrdrocarbon bearing zones have been identified above this depth 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in [he 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 CD5-98, CD5-92 ' will be enerated. 15 If the operator proposes not to comply with a limitation N/A established Isin (d) of this section, an explanation of why com liance would be im rodent. 16 Any data required by the commission to confirm N/A containment of drilling waste. Well CD5-24 Date 3/19/2019 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection Fluid is 12.0 ppg Pore pressure at thel0 3/4" casing shce is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells m gas lift) 1,000 psi = P..--;, + p. _,. - 4,429 =( 2,174 * 0.052 * MWr N w... = 34.2 ppg Vm-30-lm 18 )+ 1500 - ( 0.4337 * 2,174 ) `12,174 TVD Surface CBSing String _ TOC Est. @'4,761' MD Size 10.75 Weight 45.5 in ppf d a. 3,765' TV] a Grade L 80 Pbwsu00% 5,210 psi Stage Collar @ 5759' MD Pbarat85 0 4,429 psi .a Depth of Shoe 2,174 ft FIT/LOT @ Shoe 18 ppg or 2,035 psi N FIT/LOT for Annulus 16 ppg o Max Surf. Pressure 1,500 psi TOC Est. @ 10362' MD 6,269' TVD Maximum Fluid Density avoid Collapse of 2nd CasingStrinLy PcollapseU % — PHydwsmtic + PApplied - POnGradient - PHeader R7,640 4,072 = ( 6,269 * 0.052 * M W,,,a, )+ 1,500 - ( 0.0700 * 6,269) - 1,000 MWm.. = 12.3 ppg 4.5 "Tubing 2nd Casing String Size 7.625 in TVD Weight 29.7 ppf Grade L 80 Fcollapseloc% 4,790 psi P.11apae85% 4,072 psi Top of Cement 6,269 It Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi P-. allowable = Shoe TVD Depth * .052 * Shoe FITILOT P.. allowable = ( 2,174 *.052 * 18 ) P... allowable — 2,035 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at CR 0 0 >y °J pJ ens pJ m°J pJ e� - J 00 s a � of pJ N xo i �s UU O J °J O LO •- z m„ A2 — — O O oci s a J D Lp U a^a Ab- n t� I s0 � la3): O O O L9 N j m � ° V O LO 9Ld b � m N �p5.21 � i ( h O V O u O O O O O O N Oo N Ln O to 0 M (ui/}}jsn 009) (+)4#aoN/(-)ulnoS c c CD5-19, 10-3/4", Surface Casing well: CDS-19 10-3/4" 45.5# L-80 H d 563 DPLS Casing ConocoPhillips - ( Date: Rig: 11/17/2017 Doyon 19 Alaska. iea. f a Depth Jt Number Joints Well Equipment Description and Comments Length Tops Page 1 RKB to Top Of String or RKB to Lock Down Screws Doyon 19 RKB to t02 of Landing Rinq 37.45 FMC 10-3/4" Casing Hanger 10-3/4", 45.5#, L-80, HYD563 Casing Pup Jt, Pin X Pin Jts 4 to 53 50 Jts 10-3/4", 45.5#, L-80, HYD563 DPLS Casing 13 2.23 2042.70 37.45 37.58 39.81 10-3/4", 45.5#, L-80, BTC Pin X HYD563 Box Casing XO Jt Jts 3 to 3 1 AS 10-3/4", 45.5#, L-80, BTCM Casing 10-3/4" HES Float Collar Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTCM Casin 39.32 41.27 1.20 70.23 2082.51 2121.83 2163.10 2164.30 10-3/4" HES Composite Shoe 2.71 2234.53 2237.24 2237.24 2237.24 2237.24 2237.24 10-3/4" Shoe at 2,237.24' MD 2,187' TVD 13-1/2" TD at 2,247' MD, 2,196' TVD 10' rathole 223724 223724 2237.24 BakerLok up to pin of bottom XO 2237.24 223724 2237.24 1 Centek 10' up from shoe w/stop rings on Jt #1 1 Centek 30' up from pin w/stop rings on Jt #2 1 Centek 20' up from pin w/stop rings on Jt #3 1 Centek centralizer every joint from #4 to #40 Floating 1 To co bowspring every Jt from #41 to #52 2237.24 2237.24 223724 2237.24 223724 2237.24 2237.24 2237.24 2237.24 Total Centralizers 41 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312S 2237.24223724 223724 12 Top-Co PN 300-273-434 10.75" x 17.09" bows rin s 2237,24 2237.24 Remarks: 2237.24 Use Seal Guard ECF on HYD 563 Up Wt MU Tq with Volant - trq for Hyd 563 dpls 19.4K fUlbs, Hyd 563 doped 16.2 ft/lbs Down Wt Jts Bakerlocked to pin end of fourth Jt Block Wt Driffted with 9.885" drift 140 K 125 K 60 K Rig Supervisors: Rick Bjorhus /Rob Reinhardt "' Report Printed: 4/8/20191 Cement Detail Report CDS-19 String: Surface Casing Cement Cement Details Job: Description Surface Casing Cement Cemenllng Stmt Date Cementing End Date Wellbore Name Comment 11/16/201723:30 11/17/201704:15 CDS-19 Incorrect lead feld blend, difficulty pumping lead CMT due foaming in 65.4 bbl 15.8 ppg tail tub. Additional wait time on cement. 66.3 bb112.5 ppg Mud Push, 335.8 bbl 11.0 ppg lead. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return9 Surface Casing Cement 37.4 Vol Cement... Top Plug? Btm Plug? 1,747.0 Yes D Pump Init (bbllm... 0 Pump Final (bbl/... 0 Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Reclp7 Stroke 107.0 Yes Yes 2 5 2 479.0 1") 1,050.0 Yes 10.00 Rotated? Pipe RPM (rpm) No Tagged Depth (ftKB) Tag Method lnpnth Plug Drilled Out To (ftKB) Drlli Out Diameter (In) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (fiK8) Lead Cement 37.4 Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 1.91d (ft'/sack) Mix NPO Ratio (gailsa... FreeDanalty 1.95 7.06 11.747,0 989 G 335.8 (ID/gal) Plasllc Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives 11.00 214,000.0 7.90 Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Tail Cement Est Btm (fiK6) Amount (sacks) Class Volume Pumped (bbl) 1,747.0 Yield (fi'Isack) MIs HPO Ratio (gallsa... FreeDensity 1'16 5.11 2,247.0 318 G 65.4 (Ib/gal) Plastic Viscosity (cel Thickening Time (hr) CmprStr 1 (psi) Additives 15.80 151,000.0 4.20 Additive Type Concentrellon Conc Unit label "' Report Printed: 4/8/20191 ► .N NONN )NO ON N N NOOOOO NNN rnrnrnrn 0)0)rnrn rnrnO) m mrnrnmrnrnrnP Y E o � L �-' U! C_ O N O O N NO O O O N O O V O O O O NON O 0 0 0 0 O 0 0 0 0 0 0 0 O m 9 000 ANN N O NO NONONp 0 d M M V cr u>N(O r r W 00 Oj O)O > a' o c - O — 0 0 00 0000 000 N yj .N cO�N V NN N f`aD� ONj N N 'a N O E w .°'. a p�NM vNcor� Dorno -;7 E / _ o _ W c of OD 00 GD OD 0p W CO � r r� t` t` N (O m Y Vi O N L C O FNM vN<o r� a0 O)O N ONO 7 m > y N N M O d F > m C-4 0 ON V N N MMM M d E E N%N V (O W O N V (DODO N 7(O W O N T(O a0rn ' E > o a n > a . N C F- - r vm LL f0 p LL O O 7 N n W N y CD to Q O. 0 Lo ~O)N oCO� IL 7 "' N _ L O 'O o L. N r O C L U/ L L 3 NL r c o y .00 .2) 9)y y o E(D3LU w a rn o o a a y-� m> a p H of _ _ CL + c o ► Z N a J E yLL O rte- s0 y N r m CL a WLo N x " L m m m N ~ LL V1 v � 1+ � � ► LL 1pW U.' m i ( = O00 1 o U u m r M o oN v Y N U N — L N N U F N 'a. a L a s a rn of O O.J O.JJ� .d ) � ► W O O O N 3 w )p L co C65 C:5 C4 p + N C J Q L N O i L ji ` Z C y> m U a L d x d d N N a 0 a> d N W N _N y tr O LL F p dlp QO uiCL a U y t y N N_ rym m J So 0 0 0 o o o in H W c p0 0 NY m aanssaad E 3 o x° w E 13 A Time Log & Summary Report [AOGC( CD5-19 Well Name: CDS-19 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 11/15/2017 Rin Release • !"201an4- Time Log Start Time End Tma Dur (hr) Start Depth (flKB)htK8) End Depth Phase Op Dade Activity Dole Tme -T-X P 11/15/2017 12:00 11/16/2017 12.0 440.0 1,966.0 SURFAC DRILL TD -RLP Opera4an Directional drill from 440' MD to 1,966' MD/TVD 00:00 0 taking Gyro surveys each stand untill 3 good MWD surveys @ 1,300'. ADT=6.34, ART=4.46, AST=1.88. P/U=108k, S/0=108k, ROT= -108k. Tq on/off= 4.5k/4k. 500-800 (After permafrost) 11/16/2017 0000 17/16/2017 2.75 1,966.0 2,247.0 SURFAC DRILL DDRL P Spm @ 2200 psi. Directional drill from 1,966' MD to 2,247' MD/ 02:45 2,197 TVD. ADT=1.38, ART=.85, AST=.53. P/U=130k, S/0=123k, ROT= -125k. Tq on/off= 11/16/2017 02:45 2017 1.00 2,247.0 2,060.0 SURFAC CASING CIRC P 5k/2k. 800 gpm @ 2300 psi. Circulate 2 x bottoms up @ 800 2020 03 45 0345 gpm psi, pump 2 ea 7 ppb Nut Plug scouring sweeps. Rack back stand after each bottoms up to 2,060' 11/16/2017 11/16/2017 0.50 2,060.0 2,060.0 SURFAC CASING OWFF P MD. Blow down top drive. Observe well for flow for 30 03:45 0415 minutes static. 71/16/2017 04:15 11/76/2077 05:15 7.00 2,060.0 1,407.0 SURFAC CASING VM-POPump - out of hole from 2,060' MD to 1,401' MD @ 800 gpm, 2020 psi. Shakers producing good 11/16/2017 05:15 71/16/2017 0.25 1,401.0 1,307.0 SURFAC CASING CIRC P cuttings. Circulate bottoms up @ base 800 05:30 permafrost gpm, 60 rpm, 2k -1,2k Tq. Hole unloaded 11/16/2017 05:30 11/16/2017 08:15 2.75 1,307.0 96.0 SURFAC CA -S -NG PMPO P significant cuttings @ bottoms up. Continue pumping out @ 500 gpm-250 880 11/16/2017 11/16/2017 1.00 96.0 gpm, -160 psi. OWFF at HWDP. Blow down top drive. 08:15 09:15 0.0 SURFAC CASING SHAH P UD BHA #1 from 96' MD 11/16/2017 09:15 11/16/2017 10:15 1.00 0.0 0.0 SURFAC CASING SHAH P Clean and Gear dg floor, UD BHA wmponents. 11/162017 10:75 11/16/20171L15 1.00 0.0 0.0 RURD P R/U to run casing, P/U Volant CRT, bail 11/16/2017 11:15 11/16/2017 0.75 0.0 754.0 PUTS P extensions, 10a/a" elevators, 350T slips. 12:00 PJSM, PN and RIH with 10" shoe track to 154' 11/16/2017 12:00 11/16/2017 1.50 154.0 580.0 T PUTB P MD, Bakedok connections. Pump through shoe track @ 3 bpm, 60 for 30 13:30 psi hbl. Shut down and check floats- Good. Continue P/U and RIH with 10--W H563 casing 11/76/2017 11/16/2017 1.00 580.0 728.0 PUTB to 580' MD. Observe loss of S/O weight. 73:30 14:30 P Wash down from 580' MD to 728' MD @ 2-3 11/16/2017 14:30 11/76/2017 16:00 1.50 728.0 1,256.0 SURFAC CASING PUTB P bpm, 80 psi. Continue P/U and RIH with 10'/V casing from 11/162017 76:00 11/16/2017 1.00 1,256.0 7,298.0 SURFAC CASING CIRC P 728' MD to 1,256' MD, S/0=110k. Circulate bottoms up, stage up to 5 bpm, 120 11/16/2017 17:00 11/16/2017 2.00 1,298.0 2,197.0 SURFAC CASING PUTB P psi. Wash down joint to 1,298' MD. 17.00 19.00 Continue PA) and RIH with 103/4" casing from 1,298' MD to 2,197' MD, S/0=125k. 53 joints in 11/16/2017 19:00 11/16/2017 0.50 2,197.0 2,237.0 SURFAC CASING HOSO P hole. Make up hanger and split landing joint, wash 19:30 down and land @ 2,237' MD. P/U=140k, 17/16/2017 19:30 11/16/2017 21:30 2.00 2,237.0 2,237.0 SURFAC CEMENT CIRC P S/0=125k. Circulate and condition mudforcementlob. Stage pumps up from 2 bpm 140 psi to 8 bpm, 11/162017 11/16/2017 0.50 2.237.0 2.237.0 SURFAC CEMENT RURD 160 psi. Reciprocate 2,237' to 2,237' MD. 21:30 22:00 P Blow down top drive, R/U cement lines and 11/16/2017 22:00 11/16/2017 1.00 2,237.0 2.237.0 SUR -FA C CEMENT WAIT T equipment. Circulate @ 7 bpm while waiting on cement lab 11 /16/2017 11/16/2017 23:00 0.50 2,237.0 2.0 SURFAC C NTEMENT CM results. SIMOPS- PJSM on cementing. 23:00 23:30 ,237 P SLB pumped 2 bbl fresh water, shut in and 11/16/2017 11/17/2017 0.50 2,237.0 2,237.0 SURFAC CEMENT CMNT P rface lines to 500 psi. st p '66.5 23:30 00:00 SLB mz/PPump bbl 10.5 ppg Mud @ 4 bpm, 520 psi. Continue reciprocate pipe.iII Page 2/25 Report Printed: 4/8/2019 Time Log & Summary Report [AOGCC] CD5-19 Well Name: CD5-19 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 11/15/2017 Rig Release: 12/29/2017 Time Log StariTme 11/17/2017 Entl Tme 11/17/2017 Dur (hr) 1.75 SCM Depth (fiKB) 2,237.0 Entl DepN (We) PM1ase Op Cptle ActlNly Code Time ime P 00:00 0145 2,237.0 SURFAC CEMENTrabon CMNT T Load / drop bottom plug. SLB pump 335.8 bbl 11.0 ppg lead cement @ 6 bpm initial, reduced to 1.5 bpm, unable to blend Cement any faster due foam in tub. 290-50 psi. Average surface 11/17/2017 01:45 11/17/2017 04:15 2.50 2,237.0 2.237.0 SURFAC CEMENT CMNT P Smentjoto158 from MP to bump. swap tail nLoaad bpm, 1175LB psi pump d65.4 bbl. /drop top plug. SLB kicked out with 20 bbl fresh water. Rig displaced @ 8 bpm, 850 psi, reduced to 3 bpm 500 psi 11500 stks. Bumped plug @ 1850 stks, Pressure up to 1050 psi and hold for 5 min. (performed first flush and cycled annular). Bleed 11/17/2017 0.25 2,237.0 0.0 SURFAC CEMENT Of and check floats -good. CIP @ 04:08 hrs. 04:15 RURD P Flush 20"annular and riser @ 10 bpm, function annular 3 x and leave closed. No pressure on 11/172017 04:30 F06:OO 1.50 0.0 D.0 SURFAC CEMENT RURD P annulus, slight vac. Blow down lines and rig down cementing equipment. Rig down Volant CRT, spit landing join[ Blow down top drive and service auto 11/17/2017 06:00 1.00 0.0 0.0 SURFAC CEMENT WOC P Perform welding work on rig flooClean and Gear rig floor, maintenance on compressor and D.S. tugger. Electrical work in doghouse. 11/17/2017 07:00 11/17/2017 08:30 1.50f0-0 0.0 SURFAC CEMENT WOC P SIMOS- Prep tools for JSMP cut and slip 38' drill n/g line. Service top 17/17/2017 11/77/201711:00 2.50 0.0 SURFAC CEMENT drive, draworks and iron roughneck. 08:30 WOC P choke/ flare lines outside. PIU BHA #2 Conn*DC;R tools equipment via beaveraide. SLB DD Prep tools in pipe shed. MN and rack back BHA omponents, NMFDC, Reamer, NM 11/77/2017 11:00 11/17/2017 1.00 0.0 0.0 SURFAC CEMENT WOC P stab. Cleapits, load antl process 4" DP in pipe12.00 shed.mbing in jet lines for LCM recovery on350 15:30 00 SURFAC CEMENT WOC P shakand#3.0.0 Conticleaning pits, plumbing in jet lines on12:00 shakeprocess 4" DP. Repair weld brace onupperzzanine rear wind wall. Mobilize bit andXO tofloor. Derrick inspection and crownservi11/172017 11/17/2017 16:30 00000.0 SURFAC CEMENT WOC P PJSMU lower BHAsecBon, bit, Powertlrive,15:30 Peris, ILS, NMXO, NMSTB, pony colar,reameIMOPS- 11/17/2017 350 0.0 0.0 SURFAC CEMENT WOC Continue cleaning pits.11/17/2077 20:00 T Conticleaning pits, L/D mousehole, flowline,76:30 hole fie. Installing 4" return line for #1 shaker LCM recovery. Cnfinue load and process 4" DP. Mobilize trip nipple and RCD test plug to rig floor. 'Excess wait time on cement due incorrect lead 11/17/2017 20:00 17/18/2017 00:00 4.00 0.0 0.0 SU RFAC CEMENT WOC T blend* C/O upper antl lower IBOP valves. SIMOPS- Cleaning pits, loading shed with 7-5/8" casing. 17/18/2017 8.50 0.0 0.0 SURFAC CEMENT WOC Inspecon and maintenance on m17/78/2017 00:00 08:30 7 Continue WOC. SIMOPS-Continue with mud Pump maintenance, clean pits, process 7-5/8" H563 dopeless casing. Perform work orders. L/D IBOP easy. Consult with management, decision to check annulus @ 50 psi Compressive strength, 28.5 11/182077 11/18/2017 08:30 12:00 3.50 0.0 0.0 SURFAC CEMENT NUND P hrs. Verity 0 psi on annulus. Open annular, MN 10' extension on split landing joint. Back out landing joint from hanger, lay down same. Lay down surface riser sections. Remove annular and sliplock adapter, set on skid. Page 3/25 Report Printed: 4/8/2019 CD5-19 7-518" Intermediate casing Well: CD5-19 7 5/8"29.7# L80 BTC -M & H d 563 Do aless Casin Date: 1 112 5/201 7 ConocoPhillips Alaska, Inc. Rig: Doyon 19 Depth Jt Number Joints / I Well Equipment Description and Comments Page 1 Length Tops _ 7 RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 34.00 FMC 7.625" fluted hanger .72 34.00 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 2.00 34.72 Jts 29 to 342 314 Jts 7-5/8", 29.7#, L-80 H563 D Is Casing 12629.07 36.72 Jts 28 to 28 1 Jts 7-5/8", 29.7#, L80, H563 D Is Casing with RA Tag in Coupling 40.26 12665.79 Jts 25 to 27 3 Jts 7-5/8", 29.7#, L-80 H563 D Is Casing 120.71 12706.05 Jts 24 to 24 1 Jts 7-5/8", 29.7#, L-80 H563 D Is Casing Whipstock At No Centralizer 40.00 12826.76 Jts 4 to 23 20 Jts 7-5/8", 29.7#, L-80 H563 D Is Casing 793.55 12866.76 XO '7-5/8", 29.7# L-80 H563 Box x BTC -M Pin Casing38.39 13660.31 7-5/8" HES Float Collar 1.57 13698.70 Jts 1 to 3 3 Jts 7-5/8", 29.7#, 1-80, BTC -M Casing Baker Locked 122.44 13700.27 7-5/8" HES Eccentric Nose shoe 2.65 13822.71 13825.36 13825.36 13825.36 13825.36 13825.36 13825.36 13825.36 353 joints in the shed + 1 xo 13825.36 11 left in shed when on bottom 13825.36 13825.36 Alpine C Top at 12,803.8' MD / 7,510.5' TVD, Bottom at 12,874.8'MD 7,519'TV6 13825.36 TD 9-7/8" Hole at 13,835' MD / 7,629' TVD 11" Hole to 13,730' MD) 13825.36 Casing Shoe at 13,825' MD / 7,629' TVD 87° Inc 13825.36 1 Centek 10' up from shoe w/stop ring on Jt #1 13825.36 1 Centek 30' up from shoe w/stop ring on A #2 13825.36 3 Centeks per 2 joints from #3 - #22, stops at 27', 13' as per schedule. 13825.36 No centralizer on ft #23 & # 24 13825.36 3 Centeks per 2 joints from #25- #59, stops at 27', 13' as per schedule. 13825.36 1 Centek per joint #286, #287, #288 13825.36 1 Straight Blade Centralizer on every other joint from #341 - #289 13825.36 Total Centralizers Centeks =41 , Straight blades =27) 13825.36 13825.36 13825.36 Remarks: Torque for H563 DPLS 12,400 ft/lbs Up Wt ??? K Dn Wt ?? K Block Wt 60 K Rig Supervisors: Andy Marushack/Diana Guzman Cement Detail Report CD5-19 String: Intermediate Casing Cement Cement Details Job: Descnpgon Cemengng Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 11/27/2017 20:00 11/27/2017 22:55 CD5-19 Comment Pumped 40 bbl of 12.5 ppg MPII, dropped bottom plug, and pumped 206 1 of 15.8 ppg Class G cement. Dropped top plug and pumped 20 1 of water to clear lines. Turned over to the ng and displaced with 603.1 bbis 7 of mud at bpm. Held 1000 psi for 5 minutes (500 psi over final pressure) and checked floats. Cement Stages Stage # <Stage Number?> Descnpgon Oblective Top Depth (ttKB) Bottom Depth (ft KB) Full Ratum? Vol Cement... Top PIug7 Btm Plug? Intermediate Casing Isolate 500' MD above 11,491.0 13,835.0 Yes Yes Yes Cement Kup C q Pump Init (bbgm... q Pump Final (bbg... q Pump Avg (bbl/... p Pump Final (psi) P Plug Bump (psi) Recip? Stroke (tt) Not hid? Pipe RPM (rpm) 7 3 500.0 1.000.0 No No Tagged Depth III Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Eat Btm (ftKB) Amount (sacks) Class Volume Pumped (bbi) Intermediate Cement 10,577.0 13,835.0 1,028 G 204.0 Yield [W/sack) Mix H2O Ratio (gallsa... Free Waler (%) Donslry 1.16 (Iblgal) Plastic Viscosity (cP) Thickening Time (hr) Cmprstr 1 (psi) 5.09 15.80 Additives 5.40 Additive Type Concentration Conc Unit label ' 0 0 0 0 n N 0 0 0 0 O N N O O O N N O O y r O N (O O 01 E 0����9111111111 ORION III�IIIIIIIIIIIIIN I 1111111111 Mill - loll •1 1 IM 01 E Time Log & Summary Report [AOGCC] CDS-19 Well Name: CDS-19 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 11/15/2017 Rig Release: 12/29/2017 Time Log Stan Time Entl Time Our (hr) Stan Depth (ttKB) End DepN (Po(B) Phase Op Catle ACOVM1y Code Time ime P 11/25/2017 16:30 11/25/2017 17:15 0.75 0.0 0.0 INTRMI CASING BHAH P Clean and dear lay down tools 11/25/2017 17:15 11/25/2017 17:45 0.50 0.0 0.0 INTRM CASING WWWH P MU stack washer and flush stack 11/25/2017 17:45 11/25/2017 18:30 0.75 0.0 0.0 INTRMI CASING BOPE P Blow down top drive and pick up test jt. Makeup retriving tool and pull wear ring (14k with top 11/25/2017 18:30 11/25/2017 19:45 1.25 0.0 0.0 INTRMI CASING BOPE P drive) PJSM: Change out upper rams to 7-5/8" solid rams. SIMOPS: MU volant and pick up casing 11/25/2017 19.45 11/25/2017 20.15 0.50 0.0 0.0 INTRMI CASING BOPE P running equipment to floor Make up test jt. Set test plug and rig up to test 11/25/2017 20:15 11/25/2017 21:00 0.75 0.0 0.0 INTRM7 CASING BOPE T7-- BOPE equipment Test annular to 250/2500 psi and upper 7-5/8" rams to 350/3500 psi for 5/5 minutes with 7-5/8" 11/25/2017 11/25/2017 1.00 0.0 00 . INTRM7 CASING KURD test joint. Rig down test equipment 21:00 22:00 P Rig up to tun casing. Pick up tools to floor 11/25/2017 22:00 11/25/2017 22:30 0.50 0.0 0.0 INTRMI CASING SFTY P PJSM: run casing 11/25/2017 22:30 11/26/2017 0000 1.50 0.0 205.0 INTRMI CASING PUTB P Make up 7-5/8" 29.7 L-80 BTCM shoe track with float collar Bakerlok all connections and check float. Float not holding mitinally. Decision to pump at 5 bpm to break gels and recheck float. Float check complete. RIH with 7-5/8", 29.7# L- 11/26/2017 00:00 11/26/2017 0730 7.50 205.0 4,465.0 INTRM7 CASING PUTB P BO HYD dopeless casing to 205'. RIH with 7-5/B", 29.7# L-80 HYD dopeless casing from 205' to 4,465' as per running schedule, Filling casing every joint. Top off at 10 11/26/2017 07:30 11/26/2017 08:30 1.00 4,465.0 4,495.0 INTRMI CASING CIRC joints for displacement. RIH with 7-5/8", 29.7# L-80 HYD dopeless casing from 4,465- to 4,495' as per running schedule. Circulate and reciprocate BU below tP Oannik. Stage pump rate from 0.5 bpm to 5 bpm 11/26/2017 08:30 11/26/2017 12:00 3.50 4,495.0 6,660.0 INTRMI CASING PUTB max. PUW = 157k, SOW = 147k. RIH with 7-5/8", 29.7# L-80 HYD dopeless casing from 4,495' to 6,660' as per running 11/26/2017 12:00 11/27/2017 00:00 12.0 6,660.0 10,886.0 INTRMI CASING PUTB schedule. Continue RIH with 7-5/8", 29.7# L-BO HYD 0 dopeless casing from 6,660' to 10,866' as per running schedule. Observe various tight spots from 7,908'to 10,593'. Wash through at 0.7 bpm, 11/27/2017 00:00 11/27/2017 00:15 0.25 10,886.0 10,937.0 INTRM7 CASING PUTB 150-290 psi. eless ith 7-5/8" 29.7#, L-80 Hf37 from 10,866' to 10,937running 11/27/2017 11/27/2017 4.25 10,937.0 10,965.0 INTRMI CASING CIRC le. PUW = 315k, SOW 04:30RZ. te and reciprocate from'to 10,965'00:15 CirwIs a BU x1 to mud.from ffRZ 0.5 to 3 bpm max W = 315k, 184k. MW In/Out= 10pg, Final 290k, SOW = 17'5 Fes = 11/27/2017 04:30 12:00 11/27/2017 7.50 109650 13.206.0 INTRMI CASING PUTB e RIH with 7-5/8" 29.7#, L-80 H563 dopeless casing from 10,965'to 13,206' as per running schedule. SOW = 174k. SOW at 13,122' = 142k. Gradual SOW reduction from 12,235'- 11/27/2017 11/27/2017 12:00 14:00 2.00 13,206.0 13,788.0 INTRMI CASING PUTS P 13,122'. Continue RIH with 7-5/8" 29.7#, L-80 H563 dopeless casing from 13,206' to 13,788' as per 11/27/2017 11/27/2017 14:00 14:15 0.25 13,788.0 13,825.0 INTRMI CASING HOSO P running Make schedule. up hanger and landing joint. Land hanger on depth at 13,825' Page 7125 Report Printed: 4/8/2019 Time Log & Summary Report [AOGCC] CD5-19 Well Name: CDS-19 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 11/15/2017 Time Log Rig Release : 12/29/2017 Start Tme End Tme Dur (hl) (RKB) Start Depth:13,82:5.0 PhaserCEMENT AC0vlly Do4e 11/27/2017 14:15 11/27/2017 1845 4.50 13,825.00 INTRM7CIRC pparaticn on and stage pump to 7 bpm - 50k, SOW = 170k ;(static). 11/27/2017 18:45 11/27/2017 19:00 0.25 13,825.00 INTRMI OWFF 4OW;FFow down top drive and rig up 11/27/2017 11/27/2017 20:00 1.00 13,825.0 INTRMI CIRC ntinue to ciroulate with cement hose at 7 bpm19:00 11/27/2017 2000 11/27/2017 23:00 3.00 13,825.0 13.825.0 INTRM1 CEMENT CMNT P 70 psi. SIMOPS: Cementing PJSM Test Schlumberger cement linesto4,000psi. Pump 40 bbls of 12.5 ppg Mud Push. Drop trim plug and pump 206.5 bbls of 15.8 Gass G cement. Drop top plug and pump 20 bbls of water. Use rig to displace with 10.8 ppg WBM at 7 bpm. Decrease pump rate to 3 bpm at 6,000 strokes. Bump plug at 6,031 strokes at 3 bpm (500 psi). Increase pressure 500 psi over final pressure to 1,000 psi and hold for 5 minutes. 11/27/2017 23:00 11/28/2017 1.00 13,825.0 0.0 INTRMI CEMENT RURD P Check floats - good. CIP at 22:46 Rig down hose. Blow down and rig down volant /28/2 11017 00:00 11/28/2017 1.75 -SP tool. Lay down landing joint and clean rig floor. 00:00 01:45 0.0 0.0 INTRMI CEMENT WW P P/U4"test joint w/ wear ring running tool and pull 10.5" wear ring. Set pack off as per FMC and tested to 250/5000 psi for 10 min. UD 1128/2017 01:45 11/28/2017 03:30 1.75 0.0 0.0 INTRMI CEMENT BOPS P running tool. Changed upper rams to 3.5" x 6" VBRs and installed 4" XT -39 saver sub. P/U production 11/28/2017 11/28/2017 1.00 D.0 0.0 INTRM7 WHDOPOP RURD P tools. R/U BOP test equipment. 03:30 0430 /2017 011284:30 11/28/2017 05:30 1.00 0.0 0.0 INTRMI WHDBOP BOPE P Tested BOPEw/4"and 4.5 "test joints to 2500/3500 psi for 5 min and charted. Witness waived by AOGCC Brian Bixby. Tested annular, 4" demco kill, choke valves 1, 12,13,14, auto IBOP, outer bleeder valve, top rams, HCR kill, 9,11,namual IBOP, and needle valve. Noticed slight slight flow from 7 5/8" casing and shut 11/28/2017 05:30 11/28/2017 06:30 1.00 0.0 0.0 INTRMI WHDBOP OWFF T down to investigate. Monitored well through IAand collected samples every 10 min. Flow rate reduced from 75 sec to 120 sec per vis cup. Determined flow was due to 11/28/2017 06:30 11/28/2017 4.00 0.0 0.0 INTRMI WHDBOP BOPE P thermal expansion. Continued BOP test w/4" test joint on choke 10:30 valves 5,8,10, dart, 4 6, 7, FOSV, 2, HRC choke, manual kill, and lower rams. Swapped test joint to 4.5" and tested upper rams, lower rams, blinds, and supper/mannual chokes to 1100 psi. Accumulator tested, initial pressure = 1625 psi. reached 200 psi in 25 sec and final pressure of 2825 psi in 120 sec. N2 average = 11/28/2017 10:30 11/28/2017 1100 0.50 0.0 0.0 INTRMI WHDBOP RURD P 2150 psi. B/D lines and drained stack. R/D test equipment 11/28/2017 1100 11/28/2017 1.75 0.0 0.0 INTRM7 CEMENT RURD -1 Installed and filled stack with 10.8 ppg mud. 7.25" ID wear ring as per FMC. UD 12:45 running tool and prepped floor to UD 5" DP. PIU BHA equipment to rig floor and prepped tools. 11/28/2017 11/28/2017 6.25 0.0 0.0 INTRMI CEMENT PULD P SimOps, freeze protected annulus. UD 6 stands of 5" HWDP and 54 5' 12:45 11/28/2017 19:00 19:00 11/28/2017 20:45 1.75 0.0 339.0 INTRM7 CEMENT BHAH P stands of DP. Changed out elevators and M/U 6 314" BHA as 11/28/2017 11/28/2017 20:45 2.50 339.0 2,704.0 INTRM7 CEMENT PULD 7 per SLB. to 339' MD. Singled in hole f/ 339'to 2704' MD w/ 4" 14# DP. 23:15 First 21 joints of new pipe were broken in and 1128/2017 11/2972017 23:15 00:00 0.75 2,704.0 2,704.0 INTI RM CEMENT DHEQ P performed WU to 25k. shallow hole test w/230 gpm, 1300 Page 8/25 Report Printed: 4/8/2019 CD5-25, 10-3/4 ,Surface Casing Well CDS-24 10-3/ " 45.5# L-80 TXP-M Casin r ConocoPhillips n a Alaska, Inc. final Date: Rig: 3o1's Doyon 19 Depth dt Number Joints Well Equipment Description and Comments Page 1 Length Tops RKB to Top Of String or RKB to Lock Down Screws Doyon 19 RKB to top of Landing Ring 37.49 FMC 10-3/4" Casing Hanger .131 37.49 10-3/4", 45.5#, L-80, Casing Pup Jt, H563 Pin X H563 Pin 2.501 37.62 Pup Jt 10-3/4", 45.5#, L-80, H563 9,61 40.12 Pup Jt 10-3/4", 45.5#, L-80, H563 9.82 49.93 XO Pup Jt 10-3/4", 45.5#, L-80, H563 Pin X BTCM Box 9.82 59.75 Jts 3 to 56 54 As 10-3/4", 45.5#, L-80, TXP-M Casing 2079.65 69.57 10-3/4" Topco N/R Float Collar 1.56 2149.22 As 1 to 2 2 As 10-3/4", 45.5#, L-80, TXP-M Casing 81.22 2150.78 10-3/4" Topco Shoe 2.50 2232.00 2234.50 2234.50 2234.50 2234.50 10-3/4" Shoe at 2234.50' MD 2174.7' TVD 2234.50 13-1/2" TD at 2245' MD, 2184' TVD 10' rathole 2234.50 2234.50 2234.50 2234.50 2234.50 2234.50 1 Centek 10' up from shoe w/stop rings on Jt #1 2234.50 1 Centek 30' up from pin w/stop rings on Jt #2 2234.50 1 Centek 20' up from pin w/stop rings on Jt #3 2234.50 1 Centek centralizer every joint from #4 to #20 Floatin2 2234.50 1 Topco bowspring every Jt from #21 to #56 over coupling 2234.50 2234.50 2234.50 2234.50 2234.50 Total Centralizers 2234.50 20 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312S 2234.50 (36) Top -Co PN 300-273-434 10.75" x 16" bowsprin s 2234.50 2234.50 2234.50 Remarks: Use Seal Guard ECF on HYD 563 Up Wt 145 K MU Tq with Volant -Hyd 563 doped 16.2 fUlbs, TXP-M to 27,160 fUlbs Down Wt 130 K Bakerlocked to pin end of jt #4 Block Wt 60 K Driffted with 9.885" drift Rig Supervisors: R. Bjorhus/L. Shirley/A. Dor, a Cement Detail Report C D5-24 NO String: Surface Casing Cemen Cement Details Job: DRILLING ORIGINAL, 2/14/2019 00:0( Description Surface Casing Cement Cementing start Date cementing End Date Wellbore Name Comment 2/19/2019 20:15 2/20/2019 00:24 CD5-24 Cement Stages Stage # 1 Description Objective i Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? 8im Plug? Surface Casing Cement Cement Surface Casing 37.5 2,234.5 Yes 225.0 Yes Yes O Pump Inst (bbllm... Q Pump Final (obi/... 6 Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) RecipT Stroke (ft) Rotated' 8 500.0 Pipe RPM (rpm) 1,060.0 Yes Tagged Depth (ftKB) Tag Method No Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Dowell pump 3 bbis H2O & PT to 250/3500 psi (good). Dowell pump 75 Dols 10.5ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 396 bbis 11.0 ppg 1.95 ft3/sx yield LiteCRETE lead cement and 85 bbis 15.8 displace with 185 bbis 11847 stks 10 ppg DrillPlex with 8 bpm / 750 ppg 1.16 ft3/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bbis H2O. Rig Reduce 1060 psi for 5 min. Check floats. FIC good. CIP @ 00:24 His. Calculate psi. pumps to 3 bpm 1460 psi. last 10 bbis. Bump plug, pressure 500 psi over to Cement Fluids & Additives 225 bbis good cement to surface. Full returns dunng cementjob. Fluid Fluid Type Fluid Description Estimated Top (ftKB) Lead Cement 37.5 Est Bun (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (fP/sack) Mix H2O Ratio (gal/sa... Free Water (%) 1.91 6.82 1,735.0 1,140 B 395.0 Density (Ib/gal) Plastic viscositycP Thickenin Time hr Cm rStr 1 I ) Additives 11.00 Additive TYPa Concentration Con<Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Tail Cement 1,735.0 Est Btm (ftKB) Vlame umped (bbl) Amount (sacks) Class oP Yield (ft'/sack) Mix H2O Ratio (gables... Free Water(%) 1 16 5 13 2,234.5 411 G 85.0 Denai IW ai b ( 9 I Plastic Viscosity (CF) Thickening Time (hr) CmprStr t (psi) Additives 5.80 Additive Type Concentration Conc Unit label o�..e era report Printed: r 0 C] NI N N , d � a F o m>>a `-o 4 _ I °' c am a O C V O Q O a N O QD m L d fN N a aJ JJ as C O F :00 000. H C r� oC6 �' a d L L 3 N w~ tl a F o m>>a `-o 4 _ I °' c am + c T g E c Y Q U IN O m 0 w K £� N i.. N Q •d C O F 0 0o N , LL LLw ,I r N n tl I I N � .J aJ J a •d 0 0o N , LL O�O N 9 M p co 0 + N I(D C y N F ME N F Oa�',>y aN� W a 0 a O D F O a A O O 2 p O E Y N a Y Wi J U 0 I I m v w o 3Nnss3ad N LD E E E Time Log & Summary Report [AOGCC] CD5-24 • •' Well Name: CD5-24 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 2/16/2019 Rig Release Time Log StartTme End Tme Dur (hr) Start Depth (RKB) End Depth htt<S) Phase Op . Actively COEe Tme 71 P Operation 2118/201911:45 2/18/201912:00 0.25 1,392.0 1,392.0 SURFAC CASING CIRC P Circulate nut plug sweep around. 500gpm. 860 psi. 40 rpm. 1.5k tq. 2/18/2019 12:00 2/18/2019 13:45 1.75 1,392.0 587.0 SURFAC CASING BKRM P BR OOH f/ 1392' to 587'. 450 gpm. 730 psi. 30 rpm. 1.5k tq. 2/18/2019 13:45 2/18/2019 14:45 1.00 587.0 100.0 SURFAC CASING TRIP P POOH f/ 587 to 100'. 450 gpm. 620 psi. (hole unloaded @ 250'). 2/18/2019 14:45 F18/2019-15 30 0.75 100.0 100.0 SURFAC CASING CIRC P Circulate nut plug sweep around. 425 gpm. 550 psi. 40 rpm. 2/18/201915:30 2/18/201916:15 0.751 100.0 0.0 SURFAC CASING BHAH P IUD BHA, 2/18/2019 16:15 2/18/2019 17:30 1.251 0.0 0.o SURFAC CASING BHAH P I Clean and clear ng floor. Monitor hole on TT. 2/18/2019 17:30 2/18/2019 19:15 1.75 0.0 0.0 SURFAC MS- ASING RURD P RU to run casing. T18/2019-19 2/18/2019 19:15 718/2019-20 15 1.00 0.0 125.0 SURFAC CASING PUTB P PJSM. PU and RIH wl shoe track and check floats. Good. 2/18/2019 20:15 2/18/2019 21:15 1.00 125.0 329.0 SURFAC CASING PUTB P RIH w/ 10 3/4" csg to 329'. Taking weight @ 329'. 2118/2019 21:15 T1190-01900 00 2.75 329.0 391.0 SURFAC CASING PUTB T Wash and work mg f/ 329'to 391' 1-6bpm. 40- 120psi. 20k weight down while working casing. Up 72k.. Down 72k 2/19/2019 00:00 2119/2019 0030 0.50 391.0 354.0 SURFAC CASING PUTB T Wash and work casing from 391' MD to 354' MD 1-6bpm. 40-120psi. 20k weight down while working casing. Up 72k.. Down 72k 2/1912019-00 30 2/19/2019 03:00 2.50 1 354.0 354.0 SURFAC CASING PUTB T Rack back double 10-3/4" casing with 10' pup. 2/19/2019 03:00 2/19/2019 11:45 8.75 354.0 1,400.0 SURFAC (TAB I -NG PUTB P Continue RIH 10-3/4" 45.5ppf L-80 TXP-M casing from 354' MD to 1,400' MD. Wash down as needed with 8bpm 120psi 5 rpm 7-1 Ok ft -lbs torque. Hard spot from 820' MD to 1,017' MD. 2/19/2019 11:45 2/19/2019 12:00 0.25 1,400.0 1,400.0 SURFAC CASING CIRC P Circulate btms up at 1,400' MD 8bpm 130psi. 2/19/2019-12 00 2!19/2019 15:45 3.75 1,400.0 2,197.0 SURFAC CASING PUTB P Continue wash down 10-3/4" 45.5ppf L-80 TXP- M casing from 1,400' MD to 2,197' MD. with i 8bpm 160psi 5 rpm 7-1 Ok ft -lbs torque. T-191201915 45 719/2019-16 15 0.50 2,197.0 2,234.0 SURFAC CASING HOSO P MN hanger & landing jt. Wash down w/3 bpm @ 200 psi & land on hanger @ 2,234'. P/U wt 145 I k, S/O wt 130 k. 2/19/2019 16:15 2/19/2019 18:15 2.00 2,234.0 2,234.0 SURFAC CEMENT CIRC P Ciro & cond mud for cement job. Stage flow rate up to 8 bpm @ 150 psi. Reciprocate pipe 101, PJSM on cementing operations. 2/19/2019 18:15 2/20/2019 00:00 5.75 2,234.0 2,234.0 SURFAC CEMENT CMNT T7- Dowell pump 3 bble H2O & PT to 250/3500 psi (good). Dowell pump 75 bbls 10.5ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 396 bible 11.0 ppg 1.95 ft3/sx yield UteCRETE lead cement and 85 bible 15.8 ppg 1.16 ft3/sx yield tail cement @ 4 - 5 bpm. Drop top plug. Dowell pump 20 bible H2O. Rig displace with 185 bbls / 1847 stks 10 ppg DriIlPlex with 8 bpm / 750 psi. Reduce pumps to 3 bpm / 460 psi. last 10 bbls. Bump plug, pressure 500 psi over to 1060 psi for 5 min. Check floats. F/C good. CIP @ 00:24 Hrs. Calculate 225 bble good cement to surface. Full returns during cement job. 2/20/2019 00:00 2/20/2019 00:30 0.50 2,234.0 2,234.0 SURFAC CEMENT CMNT P Cont. to displace w1186.7 bible total @ 1847 stks 10 ppg DriIlPlex with 8 bpm / 750 psi. Reduce pumps to 3 bpm/460 psi. last 10 bbls. Bump plug, pressure 500 psi over to 1060 psi for 5 min. Check floats. F/C good. CIP @ 00:24 Hrs. Calculate 225 bbls good cement to surface. Full returns during cement job. 2/20/2019 00:30 2/20/2019 0100 0.50 0.0 0.0 SURFAC CEMENT WWW -H- P Flush annular with black water 3X's. Shut in annular for water flow mitigation. Page 2112 ReportPrinted: 3/14/2019 CD5-24_7-5/8" Intermediate casing Well: CD5-24 V 7 518"29.7# L80 TXP & /R��YS110 Eagle Casing ConocoPhillips �N�J' Alaska, Inc. II (NN�� Date: Rig: 3/5/2019 Doyon 19 Depth Jt Number Joints Well Equipment Description and Comments Page 1 Length Tops RKB to Top Of String or P to Lock Down Screws RKB to LLDS 34 18 FMC 7.625" fluted hanger HYD 563 .72 34.18 7-5/8", 29.7#, L-80 pup pin x pin below hanger HYD 563 2.10 34.90 #5 XO Joint, 7-5/8" 29.7# HYD563 Box x TXP Pin Jts 331 to 336 6 Jts 7-5/8", 29.7#, L-80 TXP Casing 40.05 240.56 37.00 77.05 #4 XO Joint, 7-5/8", 29.7#, TXP Box x RYS110 Eagle Pin Jts 259 to 330 72 Jts 7-5/8", 29.7#, RYS110 Eagle Casing 40.80 2996.15 317.61 358.41 #3 XO Joint, 7-5/8", 29.7#, RYS110 Eagle Box x BTC Pin Jts 200 to 258 59 Jts 7-5/8", 29.7#, L-80 TXP Casing 40.22 2364.09 3354.56 3394.78 7-5/8", HES 2 Star a Cementer (Qannik Zone 5,322' - 5,379') Jts 17 to 199 183 Jts 7-5/8", 29.7#, L-80 TXP Casing 3.07 7342.04 5758.87 5761.94 7-5/8", 29.7#, L80, TXP Casin w/RA Tag in Cou lin 13,104' 5 Jts 7-5/8", 29.7#, L-80 TXP Casin 1 Jts 1 Jts 7-5/8", 29.7#, L-80 TXP Casing M4to 40.53 200.75 40.64 40.68 13103.98 13144.51 13345.26 13385.90 #2 XO Joint, 7-5/8", 29.7#, TXP Box x RYS110 Eagle Pin 40.60 13426.58 6 Jts 7-5/8", 29.7#, RYS110 Eagle Casing 251.05 13467.18 15XJoint, 7-5/8", 29.7#, RYS110 Eagle Box x BTC Pin (BakerLok) 40.35 13718.23 7-5/I HES Baffle Collar 1.25 13758.58 Jts 3 to 3 1 Jts 7-5/8", 29.7#, L80, BTC Casing (BakerLok) 39.66 13759.83 7-5/8" Topco Float Collar w/Baffle Adaptor Installed 1.a2 13799.49 Jts 1 to 2 2 Jts 7-5/8", 29.7#, L80, BTC Casing (BakerLok) 79.09 13800.91 7-5/8" HES Eccentric Nose shoe 2.10 13880.00 Alpine C Top 13,339' MD / 7,544' TVD, Bottom 13,381' MD / 7,554' TVD TD 9-7/8" Hole 13,897' MD / 7,641' TVD 11" Hole 13,794' MD) Casin Shoe 13,882' MD / 7,640' TVD, 83° Inc 13882.10 13882.10 13882.10 'oint 13882.10 2 Centeks #1 w/2 stop collars 13' & 2T 'oint 13882.10 1 Centek #2 w/2 stop collars 20' f/ in 13882.10 3 Centeks per 2 joints from #3 - #9, & #12 - #40, Stops at 13', 27' Centeks or Hydroforms, 1 cent per joint #200 - #226 13882.10 13882.10 13882.10 1 Hydroform per joint#284, #285, #286 13882.10 1 Straight Blade Cent every other joint f/#288 to Surface 13882.10 Remarks: Total Centralizers (Centeks = 72, Hydroforms = 19, Straight blades = 26 ) M/U Trq Eagle 20 k fUlbs w/Seal Guard Pipe Dope M/U Trq TXP 21.3 k ft/lbs w/Run-N-Seal Pipe Dope M/U Trq Hyd 563 10.3 k ft/lbs w/Seal Guard Pipe Dope ShoeTrack BakerLok to pin of XO & Baffle Collar Up Wt Dn Wt Block Wt 320 K 150 K 60 K Rig Supervisors: A. Dorr / P. Angelle Cement Detail Report CD5-24 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 2/14/201900:00 Cement Details Descripflon Intermediate Casing Cement Cementing Start Date Cementing End Date Wellbore Name 3/5/2019 04:00 3/5/2019 07:45 CD5-24 Comment Dowell pump 1.2 bbis H2O & PT to 4500 psi (good). Dowell pump 60 bbls 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 110 bola 13.0 ppg 1.97 ft3/sx yield Class G lead cement and 130 bbis 15.8 ppg 1.16 ft3/sx yield tail cement @ 4.5 bpm. Drop top plug. Dowell pump 20 bbis H2O. Rig displace with 605 Dials (6,050 stks @ 95%) 10.6 ppg LSND with 7 bpm / 180 - 800 psi. Reduce pumps to 4 bpm/760 psi. last 60 bbls. Reduce pumps to 2 bpm / 750 psi. last 60 bbis. Bump plug, pressure up to 1100 psi for 5 min. Check floats. FIC good. CIP @ 07:45 1 Full returns during Cement job- 10.6ppg in/out Cement Stages Stage # 1 Description Intermediate Casing Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Retum7 Vol Cement... Top plug? BM Plug? Cement Lead 10,362.0 12,170.0 Yes Yes Yes Q Pump Init (bbllm... 7 Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip7 Stroke (ft) Rotated? Pipe RPM (rpm) 2 5 No I No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Intermediate Cement Fluid Description Estimated Top (ftKB) Est BM (ftKB) Amount (sacks) Class Volume Pumpetl (boll 10,362.0 12,170.0 313 G 110.0 Yield Imrsack) 1.97 Mix H2O Ratio (gal/sa... Free Water (%) Density (ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 10.82 13.00 29.6 Additives Additive Type Concentration Cone Unit label Stage # 2 Description Intermediate Casing Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Isolate 500' MD above 12,170.0 13,882.0 Return? Vol Cement... Top Plug? Etm Plug? Cement Tail Yes Kuparuk C Yes Yes Q Pump [nit (bill... 7 Q Pump Final (bbil... Q Pump qvg (bbl/... P Pump no (psi) P Plug Bump (psi) Recip7 Stroke (ftl Rote[etl7 Pipe RPM (rpm) 2 5 750.0 1,100.0 Yes No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter tin) Comment Cement Fluids &Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) Est etm (ftKB) Amount (sacks) Class Volume Pumped (obi) 12,170.0 13,882.1 634 g 1130.0 Vield (ft'/sack) 1.16 Mix H2O Ratio (gal/sa... Free Water (%) Density (Ituil l) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 5.09 15.80 Additives Atltlitive Type Concentration Cone Unit label Stage # 3 iption r intermediate Objective Isolate 500' MD above Top Depth (ftKB) Bottom Depth (ftKB) Full 4,761.0 5,761.0 Yes Retum? Vol Cement... Top Plug? BM Plug? g cement Lead Qannik Yes No p snit (III... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 2 4 160.0 1,990.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) ent ZFluidds nt Fluids & Additives ype Cement Fluid Description Es mated Top (ftKB) Est etm (ftKB) Amount(sacks) Class Volume Pumped (bbl)ediate 4,761.0 5,761.0 224 G 73.0 ft /sack) Mix H2O Ratio (gal/sa... Free Water(%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 6.47 11.20 282.0 Additives Additive Type Concentration Cone Unit label Page 1/1 ReportPrinted: 3/14/2019 f6 E E J y •�no�no ' o�noo u�oo 0 o�n00000000 M m N torr rn rn ro nrrr n n n co nrr co m co n co rrnrrrnrrn �n �n �n v� �n in �n �n c Y � c 'E � O ONNO � O O O 000 OOO O 00000 OO O OO O 'O (p C NOLO t0O � O toONOtoONOMO > m E m L OOOs- r (V 0 m � a o n c 00000000 0 0000�n O GNNMM _000 N 7 V' tO IO�n� �m C w - N E dLL C O N M a M (p r m Q> O- N M- u] E O n a ` - Y (/7 O Y y 'y 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C tn�u7 to Mu7NN Mhtn M u)NN u� c E m M M M M M M M M MMM M MMM y E p O N M 7 u f O n a o rn o u o n o m m r m > O F .- N N M � d F- m O « e N oo�no ooin �n Cno �n in 0000 - a M N N V N N O r N N O r r r-u� n n r 0 0 0 0 a C V c f D O O M N n O N N N N M d y a N M M E E E y O t oDN 007 N N 00 a MN W N 00 V W N O E 0 Y d �NNN MM V (D �p torr O O n co > O >° U) >- Li c N LL Q y d O LL Nj C y n ry i Y N C M N `r O G O y O �n a fd E a m ~ d a •- N m n M am a J J J CL N E LU a om Fo 6 00�� a � y ~ J 2 o t a 0 Z A cO LL o y f O a LL.� CL a m s O .... .... tdt t Y O a c „ t y :' e N 0 UO a s n "° c n v ui e o (n O E E �� E� 0t 0 o W ZO v a > - J ° IL IL a - foam N > ci c a w a N R J O 0'W O a d O o ' ~ K w E aLO N0 �- m LL V V LU h N m �� N N GI O m O% LL m V N C o r SO O Y a a O S O M w LIJ O Y LL J rn N LL 1 LL ^ Z O m N O 11 v J LL M alma t aL C ad. CL J a J J= Lq0 0 0O> 3 LL m N H O co O O N a N a O+ n +M L�ON m¢WOz ) l ('NEC� >F- V �•LNoO 7�jOO�Rp U1��Cqq a10N�JH11 O o"m wy N❑% 2 aOLULp: - OL2iOO 2 Oo LFfNO3L~ U. �: ?OR O 'r OEy aCL m E (cam Y LU J 4 n o FT N Y 00 0 0 N $ N N _ (n II - m m ?� 3anss3ad E 3 O = I w U f6 E E J y E E E U) MN�rr00000 M M M M N N N = (O' ) N N N N N N N N N N N N N N N Y N d d N d V E m 0000 000 O 000000000 O C 'Op 000 .-N NM M7 V N o *MI M mmo m m d+ 0_ N O p� O M O O N (O N 1 M N C N N N N LLM"i f O f00 V M M M M M d E m E O N�f (D MON (DMO [� NNMM "MON MON (DMO E ' mM V O N -=Tff E C - N n d Y N m E m MOO �m ~ > O m a _G SU C0 77 d m E =E J a Y O >° o N > a' . fA ci O > a w R W c m 0 h N E i o C m Y� E O d N N M U N y N 00 o C Q O a C d N N a M 2 d ,,, n— n a r n d '^ V y � ❑ � (D O O O i� HC W d o op Fovi opM� �d� E- . Z a° J ❑ 3 li m a W= aC d O C L❑ p n N it M d m0 d U 'ti D 06 CLO N N d H m N p E E y w N Z mLU d d0 CL Q' U O> 0 m a 0 ► _ N cci In ❑ ,= F ❑ N r W N ap m x II w m c ❑ LL � pi N O O Y a O N a � LL S N LL d U r O_ ❑ O V H E OI O III r L Q O N ~ O.N N N U U t C 0.9 ;Mpp mm o y p 3 ° d o o a a} Q M o f N + N c t9 'c r ❑ �" d a20 �A ❑ a` LW o y d N H .d CO O D_ m d U O C y N N= Y C c o c CL d A d m E to N LL) L J N£ C J O UJ 0 F N Y Z y m W N d II c - d m = y =m D " W U = mnSS3Md d E 2 E ❑ W 0 E E E U) Time Log & Summary Report [AOGCC] CD5-24 Well Name: CD5-24 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept : 2/16/2019 Rig Release: SdriTMe I End Tme 3/2/2019 09:15 3/2/2019 11:00 --Wwas 1.75 2080 0.0 INTRMI CASING AMVv Gode SHAH -T.X P Operation LID BHAas per DO f/208' MD (Bit Grade: 0 -1 - WT -G -X -I -ER -TD & Reamer Grade: 1 -1 -WT -A -X- 312/201911:00 3/2/2019 1215 7.25 0.0 0.0 INTRMI CASING WWWH P I -ER -TD) M/U stack washer & Flush stack. LID same. 3/2/2019 12:15 3/2/2019 14:30 2.25 0.0 0.0 INTRMI CASING BOPE P SIMOPS - Clean & clear floor PJSM - C/O upper pipe rams to 7 5/8". Pull wear ring. Set test plug & R/U to test BOPE. SIMOPS - Clean &clear floor. Mobilize casing running 3/2/2019 14:30 3/2/2019 1515 0.75 0.0 0.0 INTRMI CASING BOPE P tools to rig floor. Test annular preventer to 250 for 5 min 12500 psi for 5 min. Test upper pipe rams to 250 for 5 3/2/2019 15:15 3/2/2019 1530 0.25 0.0 0.0 INTRMI CASING TOPE P min / 3500 psi for 5 min. R/D testing equipment. Drain stack. 312/201915:30 3/2120191730 2.00 0.0 0.01NTRMI CASING KURD P RJU to run casing. R/U Volant w/torque turn, 3/2/2019 1730 3/32019 0000 6.50 0.0 2,-45.0 INTRM7 CASING PUTB P spider's & elevators & strap tongs. PJSM on running casing. WU 7-5/8" shoe track & check floats (Shoe, 2 its, float collar, 1 it, baffle collar, X/O, 6 joints Eagle casing, X/0, 2 -joints TXP no centralizers, 5-TXP joints, RATag joint,). RIH w/7-5/8" 29.7# TXP casing to 2,145' MD. P/U: 109k S/O: 1091k. Torque turned only Eagle 3/3201900:00 3/3201905:45 5.75 2,145.0 5,199.0 INTRMI CASING PUTB P rasing. RIH7-5/8"29.7#TXP casing 1/2,14605,199'. 3/32019 05:45 73/2019-07 45 2.00 5,199.0 5,199.0 INTRMI CASING CIRC P Circ & cond mud for 1 B/U Stage pumps f/1 bpm to 5 bpm, 180 - 210 psi. Reciprocate pipe. PU wt 3/3201907:45 3141201900:00 16.2 5,199.0 10,893.0 INTRM7 C_AS -NG PUTB P 160 k/SO wt 140k RIH7-5/8"29.7#TXP & Eagle casing f/5,199' 5 MD to 10,893' MD (M/U stage tool & BakerLok 2019 00:00 3/4/2019 01:30 1.50 10,893.0 11,376.0 INTRMI CASING PUTS P between its 199 & 200) RIH 7-5/8" 29.7# TXP & Eagle casing f/10,893' -T-4/201901 30 3/42019 1000 8.50 -7131-6 INTRMI CASING CIRC P MD to 11,316' MD Circ & cond mud. Stage up flow rate w/Initial / bpm @ 430 psi & Final 5 bpm @ 330 psi, 10.8 ppg In / 10.9 ppg Out. Reciprocate pipe. PU wt 3/4/2019 10:00 3/4/2019 20:45 10.7 11,316.0 13,842.0 INTRMI CASING PUTB P 272 k/SO wt 180k RIH 7-5/8" 29.7# Eagle & TXP casing f/11,316' 5 MD to 13,842' MD. AT 13,766' MD S/O wt 124k, Pump down at 12-lbpm 420psi. S/O wt 160K 3/42019 20:45 3/42019 21:30 0.75 13,842.0 13,882.0 INTRMI CASING HOSO P with pumps. MtU hanger & landing it. Wash down w2 bpm / 480 psi & land on hanger @ 13,882' MD (S/O wt ✓ 160-170 k,) Work landing joint and increasing 3/42019 2130 3/5/2019 00:00 2.50 13,882.0 13,882.0 INTRMI CEMENT CIRC P pump rate. Max break over P/U 435k. Circulate and mndibon mud, cut mud weight back from 10.8ppg to 10.6ppg, stage pumps up to 7 bpm / 480 psi. Ciro & cond mud for cement job. Reciprocate casing PU wt 325 k / SO wt 167 k 3/5/2019 00:00 3/5/2019 03:30 3.50 13,882.0 13,882.0 INTRMI CEMENT CIRC P Circulate and condition mud, cut mud weight back from 10.8ppg to 10.6ppg, stage pumps up to 7 bpm /480 psi. Circ & cond mud for cement job. Reciprocate casing PU wt 325 k / SO wt 167 k Mud weight in 10.6ppg 10.7+ out Page 71112 Report Printed: 3/14/2019 # =: Time Log & Summary Report [AOGCC] CD5-24 Well Name: CDS-24 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 2/16/2019 Rig Release Time Log Stan Time End Time our (hr) Start Depth (hKB) End Depth (rtKB) Phase Op Code Adi,my Code TImeP Tx - Operation 3/5/2019 03:30 3/5/2019 08:00 4.50 13,882.0 0.0 INTRMI CEMENT CMNT P Dowell pump 1.2 bos H2O & PT to 4500 psi (good). Dowell pump 60 bos 11.5 ppg mud push at 4 bpm. Shut down & drop bottom plug. Dowell pump 110 bbls 13.0 ppg 1.97 ft3/sx yield Class G lead cement and 130 bbls 15.8 ppg 1.16 ft3/sx yield tail cement @ 4.5 bpm. Drop top plug. Dowell pump 20 bbls H2O. Rig displace with 605 bbis (6,050 stks @ 96%) 10.6 ppg LSND with 7 bpm / 180 - 800 psi. Reduce pumps to 4 bpm / 760 psi. last 60 bbls. Reduce pumps to 2 bpm / 750 psi. last 60 bbls. Bump plug, pressure up to 1100 psi for 5 min. Check floats. F/C good. CIP @ 07.45 His. Full returns during cement job. 10.6ppg in/out Note: Cup on Volant tool started leaking while finishing pumping lead cement. Land on hanger and continue pumping job with casing swedge. 3/5/2019 08:00 3/5/2019 20:00 12.0 0.0 0.0 INTRMI CEMENT WOC P Pressure up on casing @ 2bpm, Open stage 2 0 tool with 3,150psi, Continue circulate at 1 bpm 80psi while WOC and L/D 5' drill pipe from derrick with hoist/single joint elevators. Rig down Volant CRT 3/5/2019 20:00 3/5/2019 22:00 -2-,o 0 0.0 0.0 INTRMI CEMENT CMNT P PJSM. Mixlpump 60 bbls 10.9 ppg Mud Push II spacer @3.8 BPM. 165 psi. Mix/pump 73 BBL 11.2 ppg CMT@ 4.7 BPM, 209 psi. Drop closing plug and kick out w/ 20 BBL water @ 5.7 BPM, 182 psi. Displace w/ 10.6 -SND @ 7 BPM, 380 psi. After 237 BBL away, slow to 2 BPM, 160 psi. After 242.5 BBL away, bump plug and pressure up to 1990 psi. CIP@ 21:55. Bleed pressure off string and OWFF-(static) to confirm ES Cementer is closed Full returns. 3/5/201922:00 3/5/201922:45 0.75 0.0 OD INTRMI CEMENT OWFF P Monitor 1111. Static. UD landing jt. 3/5/201922'45 3/6/201900:00 1.25 0.0 0.0 INTRMI CEMENT WWWH P Drain stack, Make up stack washer and wash hanger area at 9.51bpm, UD same. Attempt to set pack off, V from bottom out. Pull paskoff and wash with open ended drill pipe. 3/6/2019 0000 3/6/2019 00:30 0.50 0.0 0.0 INTRMI CEMENT W W WH P M/U 5" single open ended drill pipe. Wash above hanger to clear debris. 3/6/2079 0030 3/6/20190 30 1.00 0.0 0.0 INTRMI CEMENT WWSP P Set FMC pack off, lock down and test 250/5000psi 10min. Witness by COPA 3/6/2019 01:3D 3/6/2019 03:45 2.25 0.0 0.0 INTRMI CEMENT WOC P Hold PJSM, change out UPR f/ 7 5/8" casing rams to 3.5"x6" VBRs. Simops: Change out saver sub f/ 4.5' IF to 4" XT -39. While WOC 3/6/2019 0345 3/6/2019 10 00 6.25 0.0 0.0 INTRMI CEMENT WOC P Continue UD 5" drill pipe from derrick in mouse '§62019 hole. While WOC 1000 3/6/2079 7200 2.00 0.0 0.0 INTRMI WHDBOP BOPE P Clean and clear rig floor, R/17 BOP test equipment and 4" test joint. Set test plug and purge lines. Note. Freeze protected 10 3/4" x 7 5/8" annulus (performed LOT 535psi with 10.6ppg on first test, 372psi with 10.6ppg on second test, then flushed with 300 bbls of fresh water, followed by 80 bbls of diesel for freeze protect. Page 8/12 ReportPrinted: 3/14/2019 N 0 U 2 K LL Z 0 F a W W 0 2 (p z Z Q U W Q LL LL' N 9 m `- E `v E E d m m m z ao m a Zzz° a a zz° 0 o p z° P C O C¢ r J d O 1'� �fp P N mOlm M O Om O O O M Mmr O (p o O �WIp O O O NOnn O O O O NPM O O O O C iZ O J _6 W Q W0 lOP mf�m PP(7 in 10QN W '(O 1NN W Q N N m N m W n O m Oa W m r O N r M M N n YY m N N h q q O� N N N N N N N N N N N (MV N N N N N N N N N N N N N N ry N � C W w U SJ � n wr 'v W P W, N n CmJ n N NW N W000nmWNWrWO o W N r M r m O O g N N O� C M o O m b uY mmwm.m- b mE NNNNN "�N dm ooNco6m O PP NPmNmfOM oo�cnnhmhM PrON{7m�OP 1� O m Ni pPo �_ V O O m W L O m m N m 10 W m N W m m <d v°3 m m I p N N m m P O m V l Q N W m N N N O u) N m Cy W N m m INp p y) 'C N U N N N uml m N YI N N N N N N N W W pi m W O� W O Ol O� � mm q d� d L VlU P�mCQJ P� V V (!l Min MIP�1 MOQIm�MOIM em�O th M MMM P<OOOO � y M M M m t ' W C EQ m i_ Ok N r m N M O m M O W M N N O O r n mm o m � uP1 O� N M n W m pi O A V O CPl (y 0h ry WN h N c b n r h m a O �y NI 0 fV _N N O O _ {N W C_ O O 8 c oo i o 3 V a n U c E A N oN.t�U m � om 0 G v UOu O'f no p X m � U VUUM Ej r S d a W # 2 O C N m yU V E Q Q r y W M N O U W M M M M d 20T>Y>T >Y >}>}»>Y>Y»>Y>Y>ZZZ _R N_ � yC C N b p 00 r OOONO�001 N�MM�-NNNNTMN LLS N�ANIb O p $-j 00000 O� U pppO�00pOp000pppOODOU�U UUUUUVUUUUUUUUUUUUUUU J U ZS CD5-24 Surface Injection Pressures with gauge at disposal wellhead and using annulus friction of 50 MW Injection Pressure si MWPressure Injection si) MW Injection Pressure si 6.8 1,316 8.8 1,090 10.8 864 6.9 1,305 8.9 1,079 10.9 853 7.0 1,294 9.0 15067 11.0 841 7.1 1,282 9.1 11056 11.1 830 7.2 11271 9.2 1,045 11.2 819 7.3 15260 9.3 1,034 11.3 807 7.4 1,248 9.4 1,022 11.4 796 7.5 15237 9.5 1,011 11.5 785 7.6 1,226 9.6 1,000 11.6 774 7.7 1,214 9.7 988 11.7 762 7.8 1,203 9.8 977 11.8 751 7.9 15192 9.9 966 11.9 740 8.0 15180 10.0 954 12.0 728 8.1 1,169 10.1 943 12.1 717 8.2 1,158 10.2 932 12.2 706 8.3 15147 10.3 920 12.3 694 8.4 15135 10.4 909 12.4 683 8.5 1,124 10.5 898 12.5 672 8.6 11113 10.6 887 12.6 660 8.7 1,101 10.7 875 12.7 649 . Tom' and Shtinnbu, • e be ^new-produat� 0QaP irf> fluids from the, You. have requedted tp `diu ba Fluids'reSultiug routineQF Aidand cement at irlPi.be as we11 ao� the 'clean up aiiXil g cleaning out the tanks, at• the- mud Plant in PxePoration £or naing 'oil hese jaid. from The dio oaing `pf the ^11611 pxoduot" Olean 119 cormisaioh hhd OrediouOl'y' aPilt6l¢d ¢luids viii annnlar dlspbsal hit M'1 Pad. nua:to the geologinal' Setting- (At Alpine, Class 1 snd glass 2 disposal. opL'ioriW axe r idT,Csssox, i1RL O: had aCtehlisi e$ the iimittitiorr of 'L itec9, Ph111iPr' F, dadvi gPiibiis. to prie CoYrmtld$19n'ssrxt'isfperit�n antl.anaalaY dieyusal'wos_aPisroy as Lass esioualY a&F+xovad vrattical and envixnnmenta'1 alternative. In' the9e xagt,eats the pklstd fluids are nn dlfierc+nt than' Pr and d v&lotjW(: activittad at Alpine - are the rasult,.of tiie..bli of ah9 •e thin massage BY COPY of Tho t;dmnd:seioriai's'•have authaxi.sad mo cq send Y°i'' og email, rhilliPa is authorized to disPoaa of 'clean up t3liidsaa duocxibad in t Your o-9wil pis oa o6al wiih nny gilestions. 'mmBi1+uileCr, pr or.,Botsoleun angil7eAx AOGCC ' ALP 'FnV CoorG VFotA; . 7 Dea3' NV-'Ptauldar, > ns•Hated in the attachod aiaail, '.Com Manson vre"Ovely requested > nahox'i.zat"inn to •dizipnoe• of pew-lirca duct clen W1fluids Bubb. as CiernWnt > riiesPte,, and mud. eY�d: lir6ilQ Pit rthe. AIpiricf:rrAf CnGiDrill�Sil`•onnaNbiri6taduhe:Low, r 1�,9eceion i.n ,v�ittaa w9t1.1¢ a A'pCCC a(j�iro�r.a vuoh diuPosal at the- MI. �$oili'Y "In the9on- eddsillon i inte$ial xdiationsiliP of the mud mixing > operation- - > uxauin& th9h rem!�*�G• Sig4iiiaane.pl8an _woWld like to dontiTA f P > out. of ttiiik9 ati thc:inlid mixi+j{t Fa'&ility: muhi lue J.'.iri.7w camration.£or the? : tesnporar'Y use of. oil pAsed mud Pxofluu L's at• Alpine l.n. the coming months. tonere. ( ica11Y, routine s Tbd availabiiitY o£ pnnulaz' di'.j.1i.ae an option for .V.. rinse fluids and > sitai'lar wastes would. greatly, f4 h6wevea thio P concern AhCA)t thm > rinaea are benE£dCfal y xeuQed', hbwevez, tOeuO 4t W a liotentipl quantity di' Fluid that'doulc3 6s 'gehaif�tx+d durin5! this large Wcale > olaan uP • > fanility may'hontain either nest and used mud >'Canko' &c tl,n mud naixDea be njentad s products. q'1tOdg1Y rinses 1n contact wilt? need Products mno; > the paxmitl'ed ciass.IX dispa wrrld (CD1 R?j rinaes,d£ now products Would 11 b4 rdyheL9, to Oig. rlo-sk. T_ ¢l.spQ so T erell• (ivD-D2S L whdi'k thaxQ is > POLouCei¢ Y 'Tfic ol&s4 1 v5611 ih a critical ell > 0. tq,1:PFiculty man'ngisiq eoli�+ contehk. nein t11d ¢iagbsal locdti,pn Ror_ lifel{na'fo''' fri6111t�y., infadtlrucL•tcicb, eiit.anY compromise to thin dwde&tia efflu tY,• artd It .ie a pxloriL:Y do Pi^av efoxred. waste IUWRW t > glterne ivsoinithis, case�'ax disposal grasents a iu CDS-23 CD5-23, 10-3/4", Surface Casing Well: CD5-23 10-3/4" 45.5# L-80 Hyd 563 DPLS Casing Date: 12/31/2017 CormoPhillips AM, Inc. final Rig: Doyon 19 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 19 RKB to top of Landing Ring 36,gg FMC 10-3/4" Casing Hanger .13 36.68 10-3/4", 45.5#, L-80, Casing Pup Jt, H563 Pin X BTC Pin 2.07 37.11 10-3/4", 45.5#, L-80, H563 Pin X BTCM Box Casing XO Jt 40.96 39.18 As 4 to 51 48 Jts 10-3/4" 45.5# L-80, HYD563 DPLS Casing 1976.63 80.14 10-3/4",45.5#, L-80, BTC Pin X HYD563 Box Casing XO Jt 40.13 2056.77 Jts 3 to 3 1 Jts 10-3/4", 45.5#, L-80, BTCM Casing 40.70 2096.90 10-3/4" HES Float Collar 1.20 2137.60 Jts 1 to 2 2 Jts 10-3/4", 45.5#, L-80, BTCM Casing 78.05 2138.80 10-3/4" HES Composite Shoe 2.70 2216.85 2219.55 2219.55 2219.55 2219.55 10-3/4" Shoe at 2219' MD 2178' TVD 2219.55 13-1/2" TD at 2230' MD, 2188' TVD 10' rathole 2219.55 2219.55 2219.55 BakerLok up to pin of bottom XO 2219.55 2219.55 2219.55 1 Centek 10' up from shoe w/stop rings on Jt #1 2219.55 1 Centek 30' up from pin w/stop rings on Jt #2 2219.55 1 Centek 20' up from pin w/stop rings on Jt #3 2219.55 1 Centek centralizer every joint from #4 to #39 Floating 2219.55 1 Topoo bowspring every Jt from #40 to #51 2219.55 2219.55 2219.55 2219.55 2219.55 Total Centralizers 2219.55 40 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312S 2219.55 (12) Top -Co PN 300-273-434 10.75" x 17.09" bowsprin s 2219.55 2219.55 2219.55 Remarks: Use Seal Guard ECF on HYD 563 Up Wt 140 K MU Tq with Volant - trq for Hyd 563 dpls 19.4K ft/lbs, Hyd 563 doped 16.2 fUlbs Down Wt 130 K Jts Bakerlocked to pin end of fourth Jt Block Wt 60 K Driffted with 9.885" drift Rig Supervisors: k Harding / D. Wojo / R. Reinhardt Cement Detail Report CD5-23 String: Surface Casing Cement Job: DRILLING ORIGINAL, 12/29/2017 12:00 Cement Details Description Surface Casing Cement Cementing Start Date 1/1/2018 03:30 Cementing End Date 1/1/2018 06:30 Wellbore Name C05-23 Comment Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (kKB) Full Retum? Vol Cement... Top Plug? etm Plug? Surface Casing Cement cement to surface 37.0 2,219.6 Yes 100.0 Yes Yes O Pump [nit (bbl/m... O Pump Final (bbl/... O Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Reeip? Stroke (ft) Rot ted? Pipe RPM (rpm) 3 5 4 470.0 1,000.0 Yes 16.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estlmatetl Top (ftKB) 37.0 Est Btm (ftKB) 1,720.0 Amount (sacks) 906 Class LiteCree[ Volume Pumped (bbl) 309.8 Yield {ft'/sack) 1.92 Mix H2O Ratio (gallsa... 6.88 Free Water (%) Density (Ib/gal) 11.00 Plastic Viscosity (cP) 277,000.0 Thickening Tlme (hr) 4.50 CmprStr 1 (psi) Additives Additive Type Concentration Conc unit label Fluid Fluitl Type Tail Cement Fluitl Description Estimatetl Top (ftKB) 1,720.0 Est Btm (ftKB) 2,220.0 Amount (sacks) 288 Class Volume G 59.4 Pumped (bbl) Yield (k'Isack) 1.16 Mix H2O Ratio (gallsa... 5.09 Free Water (%) Density (Iblgal) 15.80 Plasdc Viscosity (cP) 160,000.0 Thickening Time (hr) CmprStr 5.00 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 3/25/2019 N E E m 'Cy � y rN JC E •~•�N' OO� NO OrW NO(NV VtV O7r NV' NN OIrri NN ONON NO � dYm m ON lON7 MN (ONp (d r-: qj W 66 p m 7 IL o c � N C N C E NO)O �- NM V N[On W W m? O N fDNEW C O�NM 7�O lln� MM 00 •O i O N (/J -0 N M O N C O O t o O O O O O O O 0 O 0 0 N'ONN�O 0 0 0 0 0 W 0 NO)YJN 0 0 0 N E y ON V to r► W c `o ' u a,.a 11 n F -M N y lL LL p', C C a+ Y a a m E O N0 o A "� to Q u' a N ad as nw y�aU RE 3J CL S N i `c deo 000 v � E L a F-ai��o�� a� c '_ � y J w{ c 2 o y ii O f a _ W -;rF O H a Y Q 7 G N m I O N mF o /1 p E E y3of ^ A Z o>= = ��o c�ay of L o IL m a te, + i U c ° p ���'yE �M N Q LL p y r F m W ON W m N F � J LL N O N x O U L N v F < w 0 �, ► LL J 1T R' p C •� O A E E LL N 1 X E m U p , LL �' x o n 0 eN� Y C 3 LL rm a o0 0 0Lei r F 33 N O L N Ni%L y' o Y Z CLL O mLL 'Z ~ N �j��pcm Ha oo a o U o E d a m d U Y NJ W o 0 0 0 0 0 0 0 00 y Z U �� e n n r r vii o �i C v —m° 3mnssaaa E O 2 W U N E E m Time Log & Summary Report [AOGCC] CD5-23 Well Name: CD5-23 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept : 12/30/2017 Rig Release :1/24/2018 Time Log Our I SW Depth End DepN TiimeP sud Time End Tme (hr) (ftKB) (WS) Phase Op Code A Ay Code -T-X ope2 n 12/31/2017 12/31/2017 0.50 1,094.0 1,305.0 SURFAC CASING BKRM P Backream cut f/ 1494'-1305' (500-800 gpm m, 08:30 09:00 930-2120 psi, 60 rpm, 2.5K TQ) 12/31/2017 12/31!2017 2.00 1,305.0 98.0 SURFAC CASING PMPO P Pump out f/ 1305'-98'(500-300 gpm, 930-250 09:00 1100 psi) 12/31/2017 12/31/2017 0.25 98.0 98.0 SURFAC CASING OWFF P Flow check, well static. SIMOPS PJSM on L/D 11:00 11:15 BHA. 12131/2017 12/31/2017 1.00 9&0 0.0 SURFAC CASING BHAH P UDBHAf/98'-surface. (calk fill - 27.68bbl, 11:15 12:15 actual fill = 103 (losses over shakers, captured @ ball mill)) Bit Grade: Cones: 2 -2 -BU -A -E -1 -WT -TD PDC: 1 -1 -BU -A -X -1 -NO -TD 12/31/2017 121312017 0.75 0.0 0.0 SURFAC CASING BHAH P Clean and clear rig floor. UD tools and 1215 13:00 equipment. 12/312017 12/31/2017 1.75 0.0 0.0 SURFAC CASING RURD P R/U casing tools & equipment. 13:00 14:45 12/31/2017 12/312017 0.25 0.0 0.0 SURFAC CASING SFTY P PJSM for running casing 14:45 15:00 12/312017 12/312017 2.50 0.0 655.0 SURFAC CASING PUTB P Run 10-3/4" casing f/0-655'. 15:00 17:30 12/31/2017 12/31/2017 1.75 655.0 665.0 SURFAC CASING WASH T Run casing working and washing down through 17:30 19:15 fight spot 655-665'. 12/312017 12/312017 1.25 665.0 1,375.0 SURFAC CASING PUTB P Run 10-3/4" casing f/ 665'-1375'. 19:15 20:30 12/31/2017 12/31/2017 0.75 1,375.0 1,375.0 SURFAC 'EASING CIRC P CBU, condition mud. 20:30 21:15 12/312017 1112018 00:00 2.75 1,375.0 2,219.6 SURFAC CASING PUTB P Run 10-314",45.5#, L80, TSH563 casing f/ 1375' 21:15 - 2280'. M/U casing hanger and landing joint. Run in to and casing hanger on landing ring (Shoe @ 2219.55') 1/12018 00:00 1/1/2018 00:15 0.25 2,219.6 2,219.6 SURFAC CASING PUTB P Cont run in and land rasing hanger on landing ring (Shoe @ 2219.55') 1/1/201800:15 1/1/20180200 1.75 2,219.6 2,219.6 SURFAC CEMENT CIRC P C&C mud w/3-8 bpm, 110-170 psi, recip casing, U/D=140113OK (SIMOPS> R/D bail ext & 10-314" mg elevators) 1/1/201802:00 1/1201802:15 0.25 2,219.6 2,219.6 SURFAC CEMENT RURD P B/D T/D-RN 1502 circ egpt. 1/1/2018 02:15 1112018 03:30 1.25 2,219.62,219.6 SURFAC CEMENT CIRC P C&C @ 8bpm 390 psi through cement line. Recip casing. (SIMOPS - PJSM on cement jopb) 1/1/2018 03:30 1/1/2018 06:30 3.00 2,219.6 2,219.6 SURFAC CEMENT CMNT P Cement unit flood and pressure test lines to 2700 psi w/ water. Pump 73.3 bbl 10.5 ppg mud push @ 3bpm, 90 psi. Drop top plug. Pump 309 bbl 11# DeepCRETE lead (4.5 bpm, 180-250 psi) followed by 59.4 bbl 15.8 ppg tail (2.2-4.5 bpm, 110-280 psi). Drop top plug. Pump 20.4 bbl water. Switch to rig pump and displace cement w/ 10.0 ppg mud @ 8 bpm. Slow to 3 bpm after 150 bbl mud pumped. Cont disp with mud @ 3 bpm final pressure @ bump = 470 psi (1815 strokes @ bump total displacement = 20.4 + 181.5 = 201.9 bbl, 3.7 bbl early). Pressure up to 1000 psi and hold 5 min. Flush cement from Haar. Bleed off and check floats - OK. Cement in place @ 06:18 hrs. Full retums. Approx 100 bbl good lead cement returned. Reciprocated string while cementing. 1/12018 06:30 1112018 06:45 0.25 2,219.6 2,219.6 SURFAC CEMENT CIRC P Flush hanger and riser, function annular 3 times. Close annular 1/12018 06:45 1112018 07:45 1.00 1 2,219.6 2,219.6 SURFAC CEMENT WOC P While WOC: R/D cement lines. R/D Volant 1 1 casing tool Page 2114 ReportPrinted: 312512019 CD5-23 7-5/8" Intermediate casing well: CDS-23 ,,,� '01/7 5/8" 29.7# L80 TXP & H d 563 Do eless Casin C 1000Ffii ips • I Alaska. Inc. 10 Jt Number Joints f Well Equipment Description and Comments Page 1 Date: Rig: Length 1/712018 Doyon19 Depth Tops RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 33.98 FMC 7.625" fluted hanger .72 33.98 7-5/8", 29.7#, L-80 pup pin x pin below hanger H563 1.98 34.70 Jts 20 to 213 194 Jts 7-5/8", 29.7#, L-80 H563 DPLS Casing 7785.64 36.68 7-5/8", 29.7#, L-80 H563, Pup 5.91 7822.32 7-5/8", 29.7#, L80, XO it, H563 box X TXP pin Casing 38.75 7828.23 As 4 to 19 16 As 7-5/8", 29.7#, L80, TXP Casing 629.24 7866.98 As 3 to 3 1 As 7-5/8", 29.7#, L-80 TXP Casing, Bakerlock Jt 39.76 8496.22 7-5/8" HES Float Collar 1.51 8535.98 Is 1 to 2 2 Jts 7-5/8", 29.7#, L80, TXP Casing, Bakerlock Jts 81.19 8537.49 7-5/8" HES Composite Concentric Phenolic Nose shoe 2.07 8618.68 8620.75 8620.75 8620.75 8620.75 8620.75 8620.75 8620.75 8620.75 8620.75 8620.75 8620.75 TD 9-7/8" Hole at 8631' MD / 7445.61' TVD 11" Hole to 8,525') 8620.75 Casing Shoe at 8,620' MD / 7444.24' TVD 82.4° 8620.75 8620.75 1 Centek 10' up from shoe w/stop ring on Jt #1 8620.75 1 Centek 30'up from shoe w/stop ring on Jt #2 8620.75 3 Centeks per 2 joints from #3 - #16, stops at 27', 13' as per schedule. 8620.75 3 Centeks across the surface shoe #157 - #159 8620.75 1 Straight Blade Centralizer on every other'oint from #161 - #211 8620.75 Total Centralizers Centeks = 26, Straight blades = 26) 8620.75 8620.75 8620.75 8620.75 8620.75 Remarks: Torqued 563DPLS to 12,400 ft/lbs, used Jet Lube Seal -Guard dope Up Wt 290 K Torqued TXP to 21,290 tt/Ibs, used Jet Lube Run -N -Seal dope Dn Wt 175 K Block Wt 60 K Bakerlock to pin Jt #4 Rig SupervisorsX. Harding/D. Wojciechowski Cement Detail Report CD5-23 String: Intermediate Casing Cement Job: DRILLING ORIGINAL 12/29/2017 12.00 Cement Details Description Intermediate Casing Cement Cementing Start Date 1/7/2018 11:15 Cementing End Date 1!7/2018 13:30 Wellbore Name CD5-23 Comment Cement Stages Stage # 1 Description Intermediate Casing Cement Objective Zonal isolation Top Depth (ftKB) Bottom Depth (ftKB) 8,053.0 8,621.0 Full Returns Yes Vol Cement...Top Plug? Yes Bon Plug? Yes D Pump Init (bbllm... 4 q Pump Final (bbl/... 5 q Pump Avg (bbl/... 5 P Pump Final (psi) P Plug Bump (psi) 530.0 1,100.0 Recip? Yes Stroke (k) 15.00 RotatetlT No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug United Out To (ftKB) Drill Out Diameter (in) Comment Pump 40 bbl 12.5 ppg mud push II spacer Drop bottom plug. Mix and pump 50 bbl of 15.8 cement @ 4-5 bpm. Drop top plug, pump 20 bbi water. Switch to rig pump. Displace cement w7 360 bbl 10.8 ppg mud @ 8 bpm. Slow to 3 bpm. Bump plug @ 396 bbl total displaced. Pressure prior = 530 psi. Increase to 1100 psi, hold 5 min. Bleed off, floats holding. Reciprocated casing 15' while cementing. CIP = 12:58 hrs 07 -Jan -2018. Full returns, no losses. Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description 1 Estimated Top (ftKB) 8,053.0 Est Btm (RKB) 8,621.0 Amount( acks) 242 Class G Volume Pumped (bbl) 50.0 Yield (fP/sack)Mix 1.16 H2O Ratio (gal/sa... 5.09 Free Water I%) Density (Ib/gal) 15.80 Plasdc Viscosity (CP) 124.0 Thickening Time (hr) 0.00 CmprStr t (psi) Additives Additive Type Concentration Conc Unit Iabei I rage -u i Report Printed: 3125/20191 E E E .y (D M.-00 O O (D O O)O)CO O N O O NNn O N N O n n O nn(o O N N (ONtp N N O tO 0 (o 0 (p N C nnnn mtoNto mento to N<oNNmNNmNto TT x H d d c E F- N J L C O N O N O N O O 0O N O 00 V O 000 NON O 000000 O N O N O N O 00 N O 00 N O [D O 'O 000 �N(V M M V 7 t!l NN(O lh ISN W D70)p iu p] a m w NO(OpN O0O d Mtn`] '^ ` VN'cnoO tai to con d d aj OW NM'7Nton ct) —'d E ` a O o O o O O O O O o 0 o 0 0 0 0 C _ y W N O) to OO) N N 0000 to to to to 0.-.- t0 f0 t0 N N t0 NN (O f0 N E MMMM MMMM MMM M MMM d tYj E m m O 00 O N M 7 N (p n N O O N N N o ' N G 0 ' C N _ N 0 N 0 N 0 O 0 O 0 O 0 N 0 N 0 Q) 0 O 0 O 0 N 0 O) 0 O 0 N 0 p 0 N 0 O 0 N 0 N 0 N 0 t 0 0 0Nut c V C N a N n N rn _O N_ V n N O) N N N N N ME _M _N N E y ON V (O NON V N W O N V to CO tO COON> o U)CO W n F- .O C C O LL ny N G c U i y ti O tj o v N n N a d Z Av o W0C) `aN ytnmc 110- W dN m d❑ FOM ONS E e+ EZJQ3 xcCy Wa 0M y �O C N L L> N O O c APO.LNN LU p E EN�E�d ~ to Z o a s `ap c'LL+E�LLIp ado �ooaia o ► ��c�E j�LL rdVM W a1 x p n W w 0^Y00L LL V O N ► M 1 anAdO m c» Oy II h n N 0❑ Q IT toto `- N 0 — Z n� n�Ja Irn c�y CC� L .c.l N O O O w iZ m .-- pc'ic oa �� LL F 03n N r N M p ILi w O a U `" " F CO ^ a E d O N m d ❑ cs d �r my '�❑ N .off g V M 9 N '� N e d >> � ¢�¢ U m y n ---\ t`aU�E d�3c �x Me y N �o c)>a`c E Vm H .Mo m U .Z F- CO .o F- O F❑LL m 062 d = c ae O E Y W � •- Ito E rn T u m U Y wIN Z O) Y F y X O ` d to ',?� 3anSMd E d - 2 0 O iW E E E Time Log & Summary Report [AOGCC] " CD5-23 • Well Name: CD5.23 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept; 12/30/2017 Rig Release : 1/24/2018 Time Log Dur Start Depth End Depth Time P Stmt Time End Time (hr) (RKB) (Wah Phase op Cod. A.Wity Cod. I -FX Operadon 1/6/20181300 1/6/2018 21:00 8.00 0.0 4,116:0 INTRMI CASING PUTB P PJSM. Run 7-5/8" 29.7#, L80, TPX & TSH563 casing f/ 04116'. Baker lock shoe track and test float equipment. Fill casing each jt & top off every 10 jts. 1/6/2018 21:00 1/6/2018 23:00 2.00 4,116.0 4,116.0 INTRMI CASING CIRC P Break circulation 0.7 bpm, 230 psi. Stage up pumps to 8 bpm, 260 psi. circulate until MW in/out = 10.8 ppg. MW up to 11.3 ppg seen. 1/6/201823:00 1/7/201800:00 1.00 4,116.0 4,772.0 INTRMI CASING PUTB P Cont running casing f/4116'-4772'. 1/7/2018 00:00 1/7/2018 06:45 6.75 4,772.0 8,620.8 INTRMI CASING PUTB P Cont running 7-5/8" 29.7#, 280, TPX & TSH563 using f/ 4772'-8620.75'. Fill casing each jt & top off every 10 jts. M/U casing hanger and landing it. Land casing in wellhead. 1/7/2018 06:45 1/7/2018 10:30 3.75 8,620.8 8,620.8 INTRMI CEMENT CIRC P Break circulation, stage up rete V0.5 bpm, 490 psi to 8 bpm, 430 psi. PU/SO wt= 280/19K. SIMOPS> R/D casing elevators, bail extentions, 350T spider., UD 5" sube/eqpt & PIU 4" sdubs/Egpt vis B/S. 1/7/201810:30 1/7/201810:45 0.25 8,620.8 8,620.8 INTRMI CEMENT OWFF P Blow down TDS. R/U1502 curt egpt. Flow check (slight ooze, slowing down. 1/7/2018 10:45 1/7/2018 11:15 0.50 8.620.8 8,620.8 INTRMI CEMENT CIRC P C&C w/ 8 bpm, 670 psi thru cement line. 1 SIMOPS> PJSM on cement job. 1!7/201811:15 1/7/201813:30 2.25 8,620.8 8,620.8 INTRMI CEMENT CMNT P Cement unit flood and pressure test lines to 3700 psi. Pump 40 bbl 12.5 ppg mud push II spacer. Drop bottom plug. Mix and pump 50 bbl of 15.8 cement @ 4-5 bpm. Drop top plug, pump 20 bbl water. Switch to rig pump. Displace cement w/ 360 bbl 10.8 ppg mud @ 8 bpm. Slow to 3 bpm. Bump plug @ 396 bbl total displaced. Pressure prior = 530 psi. Increase to 1100 psi, hold 5 min. Bleed off, floats holding. Reciprocated casing 15' while cementing. CIP = 12:58 hm 07 -Jan -2018. Full returns, no losses. 1/7/2018 13:30 1/7/2018 14:00 0.50 8,620.8 8,620.8 INTRMI CEMENT RURD P R/D Volant CRT. B/D lines 1!7/201814:00 117/201815:00 1.00 8,620.8 8,620.8 INTRMI CEMENT RURD P RID casing tools. P/U BHA equipment. LID landing joint. Pull casing running wear bushing. 1!7/201815:00 1/71201816:00 1.00 8,620.8 0.0 INTRMI CEMENT WWSP P Set 7-5/8" Casing pack -off. Test to 5000 psi/10 min. 1!7/2018 16:00 1/8/2018 00:00 8.00 0.0 0.0 INTRMI CEMENT PULD P PJSM. R/U & UD 5" HWDP and 5" DP in mousehole. 1/812018 00:00 1/812018 01:30 1.50 0.0 0.0 INTRMI CEMENT PULD P Cont. L/D 5" DP in mousehole. NOTE: Freeze protected 10-3/4" X 7-5/8" annulus (performed LOT then flushed with 300 bbl water followed by 81 blot diesel, approx 550 psi shut in and trapped on annulus after shutdown pumping). 11812018 01:30 1/8/2018 02:30 1.00 0.0 0.0 INTRMI CEMENT RURD P Clean and clear dg floor, change elevators f/ 5" DP to 4" DP. 1/8/2018 02:30 1/8/2018 05:30 3.00 0.0 0.0 INTRMI CEMENT BOPE P PJSM. Change BOP rams f/ 7-5/8" to 3.5X6" VBR. Change saver sub to XT39. 1/8/201805:30 1/8/201806:00 0.50 0.0 0.0 INTRMI CEMENT SVRG P Servicerig. Mechanic work on Auto /BOP on TDS T-81201806 00 1/8/2018 0700 1.00 0.0 0.0 INTRMI WHDBOP RURD P RU to test BOPE. Fill stack, choke mainfold, kill and choke lines W/8.3# water. Purge air from system. 1/812018 07:00 1/8/2018 09:15 2.25 0.0 0.0 INTRMI WHDBOP BOPE P Test BOPE to 250/3500 for 5/5 min against 4": Annular, upper, and lower VBR's, FOSV's, dart, HCR & M<anual valves on choke and kill, 4" Demco Kill, choke manifild valves 1-14, needle valve above #1. NOTE: Witness waived by AOGCC Matthew F Herrera (DOA) Page 6/14 ReportPrinted: 3/25/2019 CDS-25 CDS-25 10-3/4" Surface Casing well: CD5-25 10-314" 45.5# L-80 Hyd 563 DPLS Casing J A f CQnQcQPhif lips■ i"31 Alaska, hrc. I' A Date: Rig: 1/27/2018 Doyon 19 Dep , Jt Number Joints Well Equipment Description and Comments Page 1 Length Tops RKB to Top Of String or RKB to Lock Down Screws Doyon 19 RKB to top of Landing Ring 36.98 FMC 10-3/4" Casing Hanger .13 36.98 10-3/4", 45.5#, L-80, Casing Pup Jt, H563 Pin X BTC Pin 2.10 37.11 10-3/4", 45.5#, L-80 H563 Pin X BTCM Box Casing XO Jt 41.02 39.21 As 4 to 51 48 Jts 10-3/4", 45.5#, L-80, HYD563 DPLS Casing 1948.40 80.23 10-3/4", 45.5#, L-80, BTC Pin X H563 Box Casing XO Jt 43.01 2028.63 As 3 to 3 1 As 10-3/4", 45.5#, L-80, BTCM Casing 39.22 2071.64 10-3/4" HES Float Collar 1.21 2110.86 As 1 to 2 2 its 10-3/4", 45.5#, L-80 BTCM Casing 78.67 2112.07 10-3/4" HES Composite Shoe 2.68 2190.74 2193.42 2193.42 2193.42 2193.42 10-3/4" Shoe at 2193' MD 2182' TVD 2193.42 13-1/2" TD at 2203' MD, 2191' TVD 10' rathole 2193.42 2193.42 2193.42 BakerLok up to pin of bottom XO 2193.42 2193.42 2193.42 1 Centek 10' up from shoe w/stop rings on Jt #1 2193.42 1 Centek 30' up from pin w/stop rings on Jt #2 2193.42 1 Centek 20' up from pin w/stop rings on Jt #3 2193.42 1 Centek centralizer eve 'oint from #4 to #39 Floating 2193.42 1 To co bowspring every Jt from #40 to #51 2193.42 2193.42 2193.42 2193.42 2193.42 Total Centralizers 219342 40 Centek, SII, 10-3/4" x 13-1/2", PN 1034-1312S 2193.42 12 Top-Co PN 300-273-434 10.75" x 17.09" bows rin s2193.42 2193.42 2193.42 Remarks: Use Seal Guard ECF on HYD 563 Up Wt 140 K MU Tq with Volant - trq for Hyd 563 dpls 19.41K ft/lbs, Hyd 563 doped 16.2 ft/lbs Down Wt 137 K As Bakerlocked to pin end of fourth Jt (XO) Block Wt 60 K Driffted with 9.885" drift Rig Supervisors: k Harding / J. Wise Cement Detail Report CD5-25 Job: String: Surface Casing Cement DRILLING ORIGINAL, 1/24/2018 18:00 Cement Details Description Surface Casing Cement Cementing Start Date 1/27/2018 18:15 Cementing End Date 1/27/2018 27:45 Wellbore Name CD5-25 Comment Cement Stages Stage # <Stage Number?> Description Surface Casing Cement Objective Top Depth (ftKB) Bottom Depth (ftKB) Bring cement to surface 37.0 2,193.4 Full Return? Yes Vol Cement... Top 140.0 Yes PIugT Btm Plug? Yes O Pump Init (bbl/m... 5 0 Pump Final (bbl/... 8 0 Pump Avg (bbl/... 6 P Pump Final (psi) I P Plug Bump (psi) 620,0 11.120.0 Recip? Yes Stroke (ft) 30.00 Rohmsd7 No I Pipe RPM (rpm) Taggeo Depth (ftKB) 2,112.0 Tag Method Orill Bit Depth Plug Drilled Out To (Mis) 2,203.0 Drill 197/8 Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead Cement Fluid Description Estimated Top (([fill) 36.5 Esl Btm (ftKB) 7,693.0 Amount (sacks) 927 Class G Volume Pumped (bbl) 316.7 Yield (ft' /sack) 1.92 Mix H2O Ratio (gal/sa... 6.88 Free water (%) Density (Ib/gal) 11.00 Plastic Viscosity (01 Thickening Time (hr) 4.08 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description 1 Estimated Top (ftKB) 1,693.0 Est Btm (ftKB) 2,193.0 Amount (sacks) 299 Class G Volume Pumped (bbl) 61.7 Yield (ftr/sack)Mix 1.16 H2O Matto (gauss... 5.71 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) 4.13 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printetl: 3125/2019 i,q I C E m 1 0 N N O O O O O N N t C) N N N N 001 000 ONi �ON1m 0Q1 Q1 a] mm VQBM G: N L , y w r a tl p O O m yy O CL C L N L L r+ 7 m C m m ui h w0 e! O j 0 a'-: -a; + C O a E w m �0IN N IX m w x II N p N o � Y `a LL O y l� O II 07 O y Y r aa'maaa L e 0 0 0 o v 3 ON O O N a +1+ + N o LL H F y O N + m �p M 7 •llqq 0 (� ym 7 1 O) 0 U N> y X Y b a d 0 m w N V O C> y 0. N f0 a - i0� OO � � O n q of ll! Y W m 3unSS3Md 11 1111111111101112! so lip IN VQBM G: N L , y w r a tl p O O m yy O CL C L N L L r+ 7 m C m m ui h w0 e! O j 0 a'-: -a; + C O a E w m �0IN N IX m w x II N p N o � Y `a LL O y l� O II 07 O y Y r aa'maaa L e 0 0 0 o v 3 ON O O N a +1+ + N o LL H F y O N + m �p M 7 •llqq 0 (� ym 7 1 O) 0 U N> y X Y b a d 0 m w N V O C> y 0. N f0 a - i0� OO � � O n q of ll! Y W m 3unSS3Md Time Log & Summary Report [AOGCC] CD5-25 • Well Name: C135-25 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 1/25/2018 Rig Release: 3/17/2018 Time Log Start Time Ertl Time Our (hr) startDepth (ft 8Z EM DepM (fIXB) Phase Op Code AU ity Code Time -T-x P Operation 1/26/2018 18:45 1/26/2018 19:00 0.25 1,380.0 1,286.0 SURFAC CASING CIRC P Circ b/u at 800 gpm w/ 2200 psi w/ 20 rpm at 1380 to 1286'. 1/26/2018 19:00 1/26/2018 1915 0.25 1,286.0 1,286.0 SURFAC CASING TRIP T Attempt to pooh on elevators f/ 1286'. Overpull of 20k to 25k. 1/26/2018 19:15 1/26/2018 2215 3.00 1,286.0 173.0 SURFAC CASING PMPO P Pooh wl pumps @ 500 to 300 gpm f/ 2286'to 173'. Flow check static. (attempt to pooh on elevators at 480', but swabbing) 126/2018 22:15 1262018 22:30 0.25173 .0 84.0 SURFAC CASING BHAH P Pooh on trip tank f/ 173' to 84'. T/2-6/201822 :30 T/2-6/201822 :45 0.25 84.0 84.0 SURFAC CASING CIRC P Circ @ 300 gpm w/ 270 psi. Flow check (static). Slowdown Topdrive. 126/201--S22 1/27/2018 00:00 1.25 84.0 31.0 SURFAC CASING UH -AH P Hold PJSM, L/d bha as per SLB f/ 84'to 31'. (Calc fill -20 bbls, Actual fill = 95 bbls, losses over I shakers) 127/2018 00:00 1/27/2018 00:15 0.25 31.0 0.0 SURFAC CASING SHAH P I Finish I/d bha per SLB. 127/2018 00:15 1/27/2018 01:00 0.75 0.0 0.0 SURFAC CASING BHAH P Clear & clean dg floor, I/d bha tools & P/u 10.75" casing tools via the S/S. 1/272018 01:00 1/27/2018 01:45 0.75 0.0 0.0 SURFAC CASING RURD P R/U to run 10 3/4" casing. R/u Volant CRT, Bail extension, 10.75" elevators & 350t slips. Safety valve & crossover on floor and functioned same. 127/2018 01:45 1/27/2018 03:45 2.00 0.0 512.0 SURFAC CASING PUTB P Hold PJSM, Rih w/ 10.75" 45.5#, L-80 Hyd 563 Casing to 512'. Starting taking weight. 1272018 03:45 1/27/2018 04:30 0.75 512.0 677.0 SURFAC CASING PUTB -F- Wash down f/ 512'to 677'7/-4 bpm, 80 psi. (hole unloading gravel at shakers) 1/272018 04:30 127/2018 09:30 5.00 677.0 698.0 SURFAC CASING PUTB T Washing and spudding casing f/ 677'to 698'w/ 1.5 to 7 bpm, 50-130 psi. Regain SOW at 682'. 1/27/2018 09:30 1/27/2016 09:45 0.25 698.0 698.0 SURFAC CASING CIRC T Circulate at 698'w/ 3-7 bpm w/ 60-220 psi. Slight packing off after break thru at 682'. 1/27/2018 09:45 1/27201811:00 1.25 698.0 1,417.0 SURFAC CASING VUB P Continue RIH w/ 10.75" csg as per running detail I I/ 698' to 1417'. 1/272018 11:00 1/272018 12:15 1.25 1,417.0 1.417.0 SURFAC CASING CIRC P Circ w/ 6 bpm w/ 120 psi at 1417' (base of the perma frost). 1/27/201812:15 127/201814:00 1.75 1,417.0 2,113.0 ISURFAC CASING IPUTLJ P I RI w/10.75" csg t/ 1417'to 2113'. 1/27201814:00 1271201814:30 0.50 2,113.0 2,193.0 SURFAC CASING HOSO P MlU crossover it, hanger & landing it. Land hanger at 2193' (shoe depth) (calk displacement J4 bbls, act disp-15 bbls) 1/272018 14:30 1/27/201817:00 2.50 2,193.0 2,193.0 SURFAC CEMENT CIRC P Circ & Cond mud for cementing operations, staged pumps up to 8 bpm w/ 170 psi w/ reciprocating casing. No losses. 1/27/2018 17:00 1272018 17:15 0.25 2,193.0 7193.0 SURFAC CEMENT RURD P Blow down topdrive, r/u cmt hose, flow check well. 1/272018 17:15 127/2018 1815 1.00 2,193.0 2,1930 SURFAC CEMENT SFTY P Hold PJSM for cementing operations while continue circulating & reciprocating @ 8 bpm. 127/2018 18:15 T/2-7/201821 45 3.50 2,193.0 2,193.0 SURFAC CEMENT CMNT P Cement unit flood and pressure test lines to 2500 psi w/ water. Pump 69.1 bbls of 10.5 ppg Mud push II @ 2.5 bpm w/ 245 psi. Drop top plug, Pump 316.7 bbls of 11.0 ppg DeepCrete lead @ 5.0 bpm w/ 800-1125 psi, followed by 61.7 bbls of 15.8 ppg tail cmt at 4.5 bpm at 720- 1050 psi. Drop top plug. Dowell pump 20 bbls of water and switch to rig pump. Displace cement w/ 9.9 ppg wbm @ 8 bpm. Slow pump to 3 bpm after 173 bbls pumped. Cont displace at 3 bpm. Bump plug with 500 psi over. Pumped 1818 stks (.5 bbls over) Pressure up to 1120 psi and held for 5 min. Bled off and check floats, held ok. Cement in place at 21:40 hrs. Full returns. Approx 140 bbls of lead cement returns to surface. Reciprocated casing while cementing. Landed hanger at 20:30 hrs as cement exited the shoe. Page 2129 Report Printed: 3125/2019 Time Log & Summary Report [AOGCC] CD5-25 • . • Well Name: CD5-25 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept : 1/25/2018 Rig Release : 3/17/2018 Time Log Stld Tlme End Time Our (no Start DepN (fiKB) End Dept, (We) Phase Op Code AWivdy Code Time P -T-X Operation 1/27/201821:45 1/27/201822:15 0.50 2,193.0 2,193.0 SURFAC CEMENT CIRC P Flush hanger &riser/diverter w/black water. Function annular 3 times. Close annular (22:09 hrs.) and install 160 psi gauge for monitoring annulus pressure. 1/27/201822:15 1/27/201823:30 1.25 2,193.0 2,193.0 SURFAC CEMENT WOC P While WOC, rig down cement lines. R/d Violent CRT & csg tools. Monitoring pressure beneath Annular -10 psi. 1/27/2018 23:30 1/28/2018 00:00 0.50 2,193.0 2,193.0 SURFAC CEMENT WOC P While WOC, plu SLB 97/8" x 11" bha & rack back in derrick. Cleaning flowline & pits. 1/281201800:00 1/281201800:30 0.50 0.0 0.0 SURFAC CEMENT WOC P Wait on cement&monitor annulus pressure -12 psi. Simops-PIU & rack back 88' of 9 7/9'x 11" bha per SLB, clean mud pits. 1/28/2018 00:30 128/2018 04:00 3.50 0.0 0.0 SURFAC CEMENT WOC P Wait on cement & monitor annulus pressure -12 psi. Simops- Hold PJSM, & P/u & rack back 16 stds of new 14 ppf 4" DP (break in threads). Clean pits. 128/2018 04:00 1282018 05:00 1.00 0.0 0.0 SURFAC CEMENT WOC P Wait on cement & monitor annulus pressure -12 psi. Simops - Service drwwks & ST80, change out dies, Vd down tools/equipment, dean mud pits. 128/201805:00 11281201809:00 4.00 0.0 0.0 SURFAC CEMENT WOC P Wait on cement& monitor annulus pressure -18 psi. Simops - P/u & rack back 4" DP (41 stds, 51 stds total), Clean pits. 1/28/2018 09:00 128/2018 10:00 1.00 0.0 0.0 SURFAC CEMENT WOC P Wait on cement & monitor annulus pressure -16 psi. Simops - Prepare BOP test equipment, FOSV/Dart, test pump & fittings, conned choke lines, mechanic work on C/O manrider winch on rig floor. 128201810:00 1/28/201810:30 0.50 0.0 0.0 SURFAC CEMENT OWFF P OWFF, open annulus& OWFF(slight drip), open 20" annular. 1/28/2018 10:30 128201811:00 0.50 0.0 0.0 SURFAC CEMENT RURD P Release RT from hanger with right hand rotation. Back out and lay down 10.75" landing joint. 1/28/2018 11:00 1/28/2018 12:00 1.00 0.0 0.0 SURFAC CEMENT NUND P Hold PJSM, pull & lay down 90' mouse hole. R/d flow bleeder/hole fill & drain lines. N/D surface riser. 1/28/2018 12:00 1/28/2018 13:15 1.25 O.D 0.0 SURFAC CEMENT NUND P Lay down surface riser, function annular & clean same. Disconnect annular koomey hoses. Pull annular and set on skid. 1/281201813:15 1/28201814:15 1.00 0.0 0.0 SURFAC WHDBOP NUND P N/U FMC wellhead. Test void & wellhead connector to 1000 psi for 10 min. CPAI witness. 128/2018 14:15 1/28/2018 15:30 1.25 0.0 0.0 SURFAC WHDBOP NUND P NIU BOPE. R/u kill line & flowline. 1/28/2018 15:30 1/282018 17:30 2.00 0.0 0.0 SURFAC WHDBOP MPDA P Hold PJSM, N/U MPD (Orbit valve, flow box. RCD clamp, 1502 MPD equip, bleeder/hole fill lines, Katch-Kan) 1/28/2018 17:30 1282018 19:45 2.25 0.0 0.0 SURFAC WHDBOP RURD P P/u 5" testjt. Install lower test plug, install MPD test plug. Fill lines with water, test MPD equip to 250/1200 psi for 5/5/ min on chart. R/d down test equipment. Pull MPD test plug, install trip nipple 1/282018 19:45 1/28/2018 21:00 1.25 0.0 0.0 SURFAC WHDBOP KURD P Set 5" test it. R/u for BOPE test. Fill choke manifold and lines w/ water. Purge air from system. 1282018 21:00 1/29/2018 00:00 3.00 OA SURFAC WHDBOP BOPE P Test Annular, 4" Demco kill, valves #1, #2, #4-14, Auto & Man IBOP, ITestBOPEw/F'testjt. choke bleeder, upper rams (3.5" x 6" VBR), HCR choke & kill, 5" FOSV & dart to 250/3500 psi. "Witness waived by AOGCC Rep Brian Bixby". 712912018-00 00 129/2018 01:00 1.00 0.0 0.0 SURFAC WHDBOP BOPE P Continue testing w/ Y TJ, Upper Rams, man choke/kill on stack, LPR to 250/3500 psi, for 5/5 min. (Note: troubleshoot speed head adapter leaking, tightened same with air impact) Page 3/29 ReportPrinted: 325/2019 CD5-25 7-5/8" Intermediate casing Well: CDS-25 7 5/8" RYS110 29.06# Eagle SFH & L80 TXP Casin Date: 213/2018 ConocoPhillips Alaska, Inc. Rig: Doyon 19 Depth A Number Joints 0 Well Equipment Description and Comments Page 1 Length Tops RKB to Top Of String or RKB to Lock Down Screws RKB to LLDS 33.83 FMC 7.625" fluted hanger .72 33.83 7-5/8", 29.7#, L-80 pup pin x pin below hanger BTC 2.15 34.55 Jts 194 to 207 14 As 7-5/8", 29.7#, 1-80, TXP Casing 555.02 36.70 7-5/8", 29.06#, RYS110, XO it, TXP box X Eagle SFH Casing 3.78 591.72 Jts 163 to 193 31 Jts 7-5/8", 29.06#, RYS110 Eagle SFH Casing 1390.94 595.50 7-5/8", 29.06#, RYS110, XO 't, Eagle SFH box X TXP pin Casing 3.64 1986.44 Jts 12 to 162 151 Jts 7-5/8", 29.7#, L80, TXP Casing 6023.40 1990.08 Jts 11 to 11 1 As 7-5/8", 29.7#, L80, TXP Casing w/ RA Tag in collar 38.43 8013.48 Jts 8 to 10 3 Jts 7-5/8" 29.7#, L80, TXP Casing 121.89 8051.91 Jts 7 to 7 1 As Whipstock Jt, no centralizer 40.27 8173.80 As 4 to 6 3 Jts 7-5/8", 29.7#, L80, TXP Casing 120.70 8214.07 As 3 to 3 1 As 7-5/8", 29.7#, L-80 TXP Casing, Bakerlock Jt 40.05 8334.77 7-5/8" HES Float Collar 1.50 8374.82 As 1 to 2 2 Jts 7-5/8", 29.7#, L80, BTCM Casing, Bakerlock As 81.28 8376.32 7-5/8" HES Composite Concentric Phenolic Nose shoe 2.10 8457.60 8459.70 8459.70 8459.70 8459.70 8459.70 8459.70 8459.70 8459.70 8459.70 TD 9-7/8" Hole at 8470' MD / 7516' TVD (11" Hole to 8366') 8459.70 Casing Shoe at 8459.70' MD 17515.4' TVD 83.150 8459.70 8459.70 1 Centek 10' up from shoe w/stop ring on A #1 8459.70 1 Centek 30'up from shoe w/stop ring on A #2 8459.70 3 Centeks per 2 joints from #3 - #25, stops at 27', 13' as per schedule. 8459.70 3 Centeks across the surface shoe #156 - #158 8459.70 1 Straight Blade Centralizer on every other joint from #160 - #206 8459.70 Total Centralizers (Centeks = 37, Straight blades = 24) 8459.70 8459.70 Remarks: Torqued Eagle SFH to -19,500 fUlbs, used Jet Lube Seal -Guard dope Up Wt 250 K Torqued TXP to 21,290 fUlbs, used Jet Lube Run -N -Seal dope Dn Wt 225 K Tenaris and USS reps witnessed running Block Wt 60 K Bakerlock to pin A #4 Rig Supervisors.IC Harding / James Ilse Cement Detail Report IMF CD5-25 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/24/2018 18:00 Cement Details Description Intermediate Casing Cement Cementing start Date Cementing Entl Date Wellbore Name 2/3/2018 1830 2/3/2018 21:30 CD5-25 Comment Cement Stages Stage # 1 Description Intermediate Casing Objective Top Depth (kKB) Bottom Depth (kKB) TOC at 7067' 7,067.0 Full Returno Vol Cement... Top Plug? Btm Plug? Cement 8,459.7 Yes Yes Yes Pump Init (bbl/m... 3 O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (k) Rotated? Pipe RPM (rpm) 2 4 450.0 970.0 Yes 15.00 No Tagged Depm (kKB) Tag Met... Depth Plug Drilletl Out To ((tK8) Drill Out Diameter (in) Comment Cement Fluids &Additives Fluid fIuid Type Intermediate Cement Fluid Description E$ led Top (kKB) Est St, (kK8) Amount (sacks) Class Volume Pumped (bbl) 7,067.0 7,474.0 61 G 25.7 Yield (ft -/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gin) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 2.30 113.50 12.20 Additives Atltlitive Type Concentration Cone Unit label Fluid Fluid Type Intermediate Cement Fluitl Description Estimatetl Top (kKB) Est Btm (kKB) Amount (sacks) Class Volume Pumped (bbl) 7,474.0 8,459.0 301 G 63.0 Yield (k'/sack) 1.16 Mix H2O Ratio (gallsa... 5.71 Free Water (%) Density (migal) Plastic Viscosity (cP) Thickening Time (hr) Cmprstr t (psi) 15.80 140.3 Additives Additive Type Concentration Conc Unit label N�Q)N V NNO O)d)0 0 f�I�(O CONNNNNc} m 00I� f` r f` r r N(fl CO N CO CO CO (fl0(D (D COO(O N .0 OOOr• .-tV NM M a -t Kj Ln CO (O I�f� W W C66>O E m d a o- c N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N v- N NMS NN (p m rr�0 � C a Y (A O in _ N000 0000 oNo N � NON Emco co mcoraco Nm� � r�00 N N m _ MMMM MMMM MMM M M M M O po N❑� N N M H 0 O O 0 N 0 N N C O M N 0 1 C V � m NMN x 0 0 0 E m O N V C O 0 0 N V (fl 0 0 N V N 0 O N vv (O 0 0 N m r 3 w a O (n N ' ❑ a / y V _w N a LL LLL 16 o O O O Q'a Q a (� c ❑ y M 0 O N O IL d ai a O❑ J Q_- C 2� d J dN rn 00 C L N L L N Q -- .Old d 3 C d W f M U CL 'a w . E E2 1 Z Q a s `jO m>dN O a UO o >❑ aha m aaa: T ' F O a O N E r CO O F 2 C d •- 'O T ❑ t 1. L v Y❑N n p m W o O 00 X d d N m O N V 0 ❑ O > NL N r N V O ^_ li M LL N O Y m� rn m N t 0 as y flea cm O .. O_J O.J J Q 'y � `n F ocv o0 oov a � N ❑ LO r U d M O o U N '^ 11 F m + W rn 0 d ❑ L d L M a C ( m.2)dN U R 0I Q ID F- ryyn > E O`x L5 N N N j O 4. m> y d N W F N Z� �- ..d+ O F o Q d Y O v a o E d 7 d A d f. N Y U y W J o 0 Z w X III O m N N m 3anss3ad d E 3 A a - Time Log & Summary Report [AOGCC] CD5-25 Well Name: CD5-25 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept: 1/25/2018 Rig Release: 3/17/2018 Time Log startiime End Time Dur 00 Stall Depth (ttKm End Depm (WB)phase op Cada Activity code Timep -T.X Operation 2/2/2018 08:15 M-/201819 :00 10.7 0.0 4,005.0 INTRMI CASING VU P PJSM, Run 7 5/8" 29.74,2-1- TXP casing 119 to 5 4005'. Baker lock shoe track & test float equipment. Tanana Rep on site utilizing Torque Tum equipment in mnjuction with the Volant CRT. Fill casing each it & top off every 10 jts. (Compare top drive torque w/ Volant CRT torque values-good matching values). X-O & safety valve on rig floor for casing connections, functioned same (left open position). 810=1 40k 2/2/2018 19:00 2/2/2018 20:00 1.00 4,005.0 4,005.0 INTRMI CASING CIRC P Break circ @ 1 bpm w/ 200 psi, stage pump up in .5 bbl increments to 5 bpm w/ 140 psi. Circ b/u. Reciprocatef/4010't03970'. Maxmud weight noted was 11.1 ppg while maintaining 10.8 ppg in. 2/2/2018 20:00 2/2/2018 23:30 3.50 4,005.0 5,875.0 INTRMI CASING PUTB P Continue running 7 5/8" casing to 5875'. P/u - 200k, S/o-180k, Observed loss in pipe displacement, slow running speed from 2200 ft/hr to 1300 ft/hr with no change in loss of -0() displacement. Lost 11 bbls in the last 7 its ran. 2/2/2018 23:30 Z3/2018 00 0.50 5,875.0 5,875.0 INTRMI CASING CIRC P MIUjoint #148 in the 7 5/8" csg tally. Break circ w/ 0.5 bpm w/ 260 psi. Stage pump slowly up to 1.8 bpm, while reciprocating csg f/ 5916, to 5891'. P/U=200k, S/0=190k. Pumped a total of 97 bbls. Losing 28% of mud returns pumped at 1.8 bpm. Lost a total of 28 bbls. 2/3/2018 00:00 9312018-00 45 0.75 5,875.0 5,875.0 INTRM1 CASING CIRC P Break Circ & stage pump up to 1.8 bpm w/ 280 Psi, reciprocating pipe f/ 5916' to 5891' pumped 97 bbls & lost 28 bbls (28% loss rate). 2/3/2018 0045 2/3!2018 09:30 8.75 5,875.0 --T4-23.0 INTRMI CASING PUTB P Continue running 7 5/8" 29.7# L80 TXP & 29.06# RYS110 Eagle SFH casing f/ 5875' to 8423' MD. Slowed rated f/ 220U/hr to 700'/hr due to losses. (Noted improvement in loss rate). (Torque turn w/ Volant CRT w/ Tenaris & Eagle reps) SOW=190k Filling casing each it & topping off every 10 its. 2/3/2018 09:30 2/3/2018 1000 0.50 8,423.0 8,459.0 INTRMI CASING HOSO P IWu 7.625" FMC casing hanger and landing jt. Land casing on hanger at 8459.701. 2/3/2018 10:00 2/3/2018 18:00 8.00 8,459.0 8,459.0 INTRMI CEMENT CIRC P Break circw/.5 bpm, 410 psi. P/u & break over W/ 275k P/U & 200k S/0. Stage up pumps to 2.5 bpm w/ 410 psi, working casing string f/ 8459' to 8432' MD. Circ & cond mud for cmt iob, cutting mud wt f/ 10.8 ppg to 10.6 ppg. Heaviest mud wt noted was 11.2 ppg w/ 2150 stks pumped. Cont staging up to 5.5 bpm w/ 270 psi. (Simops: R/d 7 5/8"cag elevators, bail ext, remove batteries f/ Volant CRT TT system, dean rig floor, Ud 350T slips) T-3/201818 00 2/3/2018 18:30 0.50 8,459.0 8,459.0 INTRMI CEMENT CIRC P Wu cement hose & continue circulating @ 5.5 bpm w/420 psi while hold PJSM for cementing 2/3/2018 18:30 2/3/2018 20:00 1.50 8,459,0 8,459.0 1NTRM1 CEMENT CMNT P operations. Pump cement as per plan: Mix & pump 37.1 bbls of 11.5 ppg mud push spacer @ 3 bpm, 380 psi. Drop btm plug, pump 25.7 bbls of 12.2 ppg Lead @ 3.2 bpm w/ 500 psi & 63.4 bbls of 15.8 ppg tail @ 4.5 bpm w/ 750 psi. Load top plug. (Note: while loading top plug, observed the bottom plug was still in place with the rupture disc burst 4' down in casing) Kick out plugs wl 20 bbls of fresh water @ 5 bpm w/ 500 psi. Page 7129 Report Printed: 3/2512019 Time Log & Summary Report [AOGCC] CD5-25 Well Name: CD5-25 Rig Name: DOYON 19 Job type: DRILLING ORIGINAL Rig Accept : 1/25/2018 Rig Release : 3/17/2018 Time Log Stall Time End Time Dur (no start Depm (dKB) End DepM (f KB) Phase Op Code Activity Code Time P -T-X Operation 2/3/2018 20:00 2/3/2018 21:30 1.50 8,459.0 8,459.0 INTRMI CEMENT CMNT P Displace cement with rig pump w/ 10.6 ppg wbm 5.5 bpm initially trying to catch cement (110 psi). Cont to reciprocate string w/ 2601k PIU & 220k SIO. Landed on hanger after 150 bbls pumped due to drag increasing. Staging pump rate down to 5 bpm w/ 100 psi at 234 bbls pumped, 4 bpm w/ 167 psi at 234 bible pumped, Continuing slowing pump to 3.5 bpm, to 2.0 bpm. Bump plug w/ 361 bbls pumped, apply 500 psi over (1000 psi), pressure decreased to 700 psi. Pumped 2.3 bbls with a total of 3609 siks pumped (calculated stks-3642). Pressure held solid for 5 min. Bleed off pressure, check floats (holding). CIP at 21:33 hrs. Full returns, no losses. 2/3/201821.30 2/3/201822:30 1.00 8,459.0 8,459.0 INTRMI CEMENT RURD P Rld cement equipment while OWFF. R/d Volant CRT, drain stack. 2/3/2018 22:30 2/3/2018 23:00 0.50 8,459.0 8,459.0 INTRMI CEMENT RURD P UD 7 5/8" landing joint, Pull wearbushing. 2/3/2018 23:00 2/3/2018 23:30 0.50 8,459.0 0.0 INTRMI CEMENT W WSP P Set 7 5/8" casing pack-off. Test to 5000 psi for 10 min. Good test. 2/3/2018 23:30 2/4/2018 00:00 0.50 0.0 0.0 INTRMI CEMENT RURD P Hold PJSM & rig up floor to lay down 5" DP in mousehole. 2/4/2018 00:00 2/4/2018 02:15 2.25 0.0 0.0 INTRMI CEMENT PULD P Lay down 5" DP & 5" hwt in mousehole (7 aids hwt & 15 stds DP). (Simops: Cleaning mud pits) 2/4/2018 02:15 2/4/2018 02:45 0.50 0.0 0.0 INTRMI CEMENT SVRG P Service rig, Drwwks, & ST80 w/ replace fuse in pipe skate kickers. Simops: Cleaning mud pits. 2/4/2018 02:45 2/4/2018 08:00 5.25 0.0 0.0 INTRMI CEMENT PULD P Continue to UD 5" DP from derrick via the 90' mousehole(81 stds total). Simops: Service choke manifold & stack valves, cleaning mud pits. 2/4/2018 08:00 2/4/2018 11:00 3.00 0.0 0.0 INTRMI CEMENT BOPE P Hold PJSM, change out UPR f/ 7 5/8" casing rams to 3.5"x6" VBRs. Simops: Change out saver sub f/ 4.5" IF to 4" XT-39, cleaning mud pits. Note: Freeze protected 10 3/4" x 7 5/8" annulus (performed LOT, then flushed with 300 bbls of water, followed by 81 bbls of diesel, 2/4/2018 11:00 2/4/2018 12:00 1.00 0.0 0.0 INTRMI WHDBOP RURD P P/u 4" test it & Test plug, r/u to lest BOPE, fill chokelkill/stack & choke manifold with water & purge air f/ system. 274/2018 12:00 2/4/2018 16:30 4.50 0.0 0.0 INTRMI WHDBOP BOPE P Held PJSM, Test BOPE w/ 4" & 4.5" test joints to 250/3500 psi for 5/5 min each. Chokes tested to 1100 psi. On 4" TJ, tested Annular, 4" Demco, #1,12,13,14, upper IBOP, upper 3.5"VBR, HCR kill, #9,11, Man IBOP, #5,8,10, XT-39 Dart, #4,6,7, XT-39 FOSV, 02, HCR choke, Man choketkill, Lower 3.5" x 6" VBR. On 4.5" TJ, tested Annular, upper 3.5"x6" VBR, lower 3.5"W' VBR, #3,4,6 Valves. Tested Blind rams. Flow test Hyd and man chokes. Accumulator test - system pressure=2850 psi, Annu -750 psi, After function all components: Sys psi=1450 psi, Man psi=1200 psi, Ann psi=750 psi. 200 psi recovery=26 sec. TSR=149 sec, 4 bottle N2 avg=2150 psi, Tested all dg gas alarms. Test witness waived by Brian Bixby AOGCC. 2/4/2018 16:30 2/4/2018 17:00 0.50 0.0 0.0 INTRMI WHDBOP RURD P Pull Test Plug, install FMC wear bushing. I.D. - 7.125". 2/4/2018 17:00 2/4/2018 17:30 0.50 0.0 0.0 INTRMI WHDBOP RURD P Blow down lines, r/d testing equipment. 2/4/2018 17:30 2/4/2018 19:30 2.001 0.0 344.0 INTRMI CEMENT BHAH P Hold PJSM, P/U 6.75" bit & bha #3 to 344'. 2/4/2018 19:30 2/4/2018 20:30 1.001 344.0 2,430.0 INTRMI CEMENT TRIP P TIH to 2430' MD w/ new 4" #14 OF, f/ derrick. 2/4/2018 20:30 2/4/2018 21:00 0.501 2,430.0 2,430.0 INTRMI CEMENT SVRG P Service rig w/ reset faults on topdrive. Page 8/29 ReportPrinted: 3/25/2019 Davies, Stephen F (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Monday, April 8, 2019 9:26 AM To: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-145) - Information Request Attachments: CD5-19 Combined Info.pdf Steve, Attached is the supporting info for CD5-19. Let me know if you need anything else. Thanks, Andrew (303)378-8881 From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Monday, April 08, 2019 8:37 AM To: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-145) - Information Request Hi Andrew, Each application should be a complete, "stand alone' document so that AOGCC's limited review staff doesn't have to search about to find all relevant information. Could CPAI please provide cementing operations documentation for CD5- 19 similar to that provided for CD5-23 and CD5-25? Thank you for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve davies@alaska.gov. From: Beat, Andrew T <Andrew T Beat@conocophillips.com> Sent: Monday, April 8, 2019 6:19 AM To: Davies, Stephen F (DOA) <steve davies@alaska.aov> Subject: RE: [EXTERNAL)CRU C135-24 (PTD 219-006, Sundry 319-145) - Information Request Steve, Glad to hear that all loaded okay. Regarding CD5-19, it was my understanding all of that information was on file with the AOGCC either from a previous AD sundry request or the end of well submissions. If this isn't the case, I'll pull it all together. The well did get a little over 100 bbl of cement back to surface on the surface cement job. Thanks, Andrew (303)378-8881 From: Davies, Stephen F (DOA) <steve.davies@alaska.eov> Sent: Thursday, April 04, 2019 4:57 PM To: Beat, Andrew T <Andrew T Beat@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-145) - Information Request Andrew Thank you again for providing the CD5-24 well log data. It loaded into my workstation easily after I spliced it all together. More questions: I notice on the map titled "CD5-24 Quarter Mile Overview/' that the surface casing shoe for CD5-19 lies less than 100 feet from the surface casing shoe of CD5-24. I don't see any information regarding surface casing cement operations for CD5-19 attached to the annular disposal application for CD5-24. Could you please provide information similar to that provided for CD5-23 and CDS-25? Were cement returns recorded at the surface of CDS-19? If not, please demonstrate that competent cement surrounds the CD5-19 surface casing. Thank you, Steve Davies AOGCC 907-793-1224 CONFIOENT/ALITY 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 daviesCdalaska.eov. From: Beat, Andrew T <Andrew T.Beat@conocophillips.com> Sent: Wednesday, April 3, 2019 1:45 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-145) - Information Request Steve, It's been awhile since I've zipped something so let me know if this doesn't work. Thanks, Andrew (303)378-8881 From: Davies, Stephen F (DOA) <steve.davies@alaska.eov> Sent: Monday, April 01, 2019 1:53 PM To: Beat, Andrew T <Andrew T Beat@conocophillips.com> Subject: [EXTERNAL]CRU CD5-24 (PTD 219-006, Sundry 319-145) - Information Request Andrew, I'm reviewing CPAI's application to conduct annular disposal operations in CD5-24. Could CPAI please provide: 1. field copies of the open -hole logs recorded in CD5-24 as digital well log data files from base of conductor pipe to total depth of the well in .las format and as electronic images in .pdf format, and 2. a copy of the directional survey data in spreadsheet or ASCII table format? Please note that providing field copies of the data does not release CPAI from providing final, composite, archival copies of the data in accordance with 20 AAC 25.071. Thank you, Steve Davies Senior Petroleum Geologist 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.Rov. Note to File CD5-24 (PTD 2190060, Sundry 319-145) 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 (CD5-24). -- 10 3/4" Surface casing was cemented to surface successfully. No problems reported. Approximately 225 bbls of good cement was circulated to surface. -- On the initial Formation Integrity Test (FIT) for the surface casing shoe dated 2/22/2019, the pressure slope rises smoothly with test stopping at 1.1 bbl pumped and 950 psi to yield the desired 18.0 pqq EMW. The pressure declined slightly from 950 psi to 825 psi (16.8 EMW) during the 10 minute shut in period with the 1.0 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 2 stage job with stage collar at 5761 ft MD and shoe of 13882 ft. Cement is estimated at TOC 4761 ft to the stage collar of 5761 ft and the shoe cement from TOC estimated at 10362 ft to TD. Cement job with full returns throughout. Annular disposal zone estimated from cemented 10.75" shoe at 2234 ft MD 2174 ft TVD to 2nd stage TOC estimated at 5761 ft MD. A post cement 10.75 x 7.625" annulus injectivity test LOT was performed 3/6/2019 with a calculated depth of the casing shoe of 2234 ft MD, 2174 ft TVD and an open hole to est 2265 ft MD yielding a 16.0 ppg EMW. The test showed pressure rising steadily with the sharp break over point at the 16.0 ppg EMW. --There are multiple wells currently drilled or planned to be drilled within '/ mile radius of CD5- 24 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 CD5-19 is closest, about 112' distant. CD5-25 at 206 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 OVhJ AOGCC 4/q/-,o/l April 9, 2019 F:\cdwallace\Documents\Annular Disposal\190409_CD5-24 note to file.doc Note to File CRU CD5-24 (PTD 219-006) April 8, 2019 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD5-24 Request ConocoPhillips requests approval to dispose of 35,000 barrels of drilling waste in well CD5-24 Recommendation Approve ConocoPhillips' request. i Conclusions ' 1. The 10-3/4" surface casing shoe is set in this well at 2,234' measured depth (MD; -2,099 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 CD5-24 and 28 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 Sections 7 and 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 CD5-10) 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. ' C135-01, CD5-02, C135-03, CDS-04, C135-05, C135-06, CD5-07, C135-08, CD5-09, CD540, C135-1 1, CD5-12, CD5-13, C135-17, CD548, CD5-19, C135-20, CD5-21, C135-22, C135-23, C135-25, C135-92, CD5-99, CD5-313, C135-314, CD5-314X, C135-315, and CD5-316. CD5-24 Annular Disposal Note to File April 8, 2019 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 3, below). In CD5-24, the annulus open to the disposal interval extends downward from the surface casing shoe at -2,100' to the top of second -stage cement for the 7-5/8" casing string, which is estimated to be -3,691'.hT e portion of the open annulus that will most likely accept the injected waste is a 132 -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 -2,368'. See Figures 1 and 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, ♦ AA i►♦ Surface Casing Shoe for ♦ ♦ Surface Casing CDS-24 . Shoe Locations / CD5-24 \ / Open Annulus NORTH f Top of Cement for 7-5/8" Intermediate 0 500 feet �'p Casing ,r j Figure 1. CD5-24 Index Map (The magenta -colored line depicts the path of the cross-section displayed in Figure 3.) 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 CD5-24 production casing string is indicated by orange -colored semi -circle. Twenty eight wells are currently open to these same strata within the '/a -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, CD5-13, CD5-17, CD5-18, CD5-19, CD5-20, C135-21, CD5-22, CD5-23, CD5-25, CD5-92, CD5-99, CD5- 313, CD5-314, CD5-314X, CD5-315, and CD5-316. CD5-24 Annular Disposal Note to File April 8, 2019 Page 3 of 5 Figure 2, below, presents a west -to -east trending structural cross-section view of CD5-24 and nearby wells CD5-25 and CD5-19, 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. 501032075500 501032079900 50103207WW 2171510 231 ft 2190050 57 ft 2171210 CRU CD&25 CRU CD5-24 CRU C05-19 2000 -_. .a �� _ 2000 Surface - Casing ��-�w� _ ', Surface 550 i Cemented } Surface Casing 1500 r' to Surface ---- Casing _ Cemented Cemented p �� to Surface - Permafrost a to Surface 1000 1000 ,., — r--�. Base at =�= "- e=-'---1,250'0+" 4. NDSS soe Upper 500 _ ' Confining r Surface Interval Ilkr _ R� Casing ~� Shoe 0 ° Most Likely Disposal _I Interval - Lower soo 1 e- # -500 Confining _—Ip — - `Open Annulus -)- j- Intervals - .1000 1000 q cement top at 1500 - -1500 -3,691' NDSS s -2000 - ( I _ -2000 2500 .2500 Figure 2. CD5-24 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) CD5-24 Annular Disposal Note to File April 8, 2019 Page 4of5 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 occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mud log) 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 4,000' 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 CD5-24. 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. 200 Injected Fluid vs Affected Area Surrounding CRU CD5-24 Wellbore (Assumptions: 30.0% porosity, 50% native fluid displacement, aggregate cylinder 40.0' high) 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 3. C1115-24 Area Likely Affected by Annular Injection (Assuming uniform, piston -like, radial displacement of 50% of native formation fluids) 102' affected radius assuming 40.0' of injection interval aggegate thickness 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 3. C1115-24 Area Likely Affected by Annular Injection (Assuming uniform, piston -like, radial displacement of 50% of native formation fluids) CD5-24 Annular Disposal Note to File April 8, 2019 Page 5 of 5 The gamma ray well log curve recorded in CD5-24 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 porosity of about 30% at this depth. Based on these values, the volume of rock that will receive 35,000 barrels of injected waste 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 shoe of CRU CD5-19 lies less than 100' away, it is likely that injected fluids will the uncemented annulus of this well. In CRU 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 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 CD5-24 to the requested limit of 35,000 barrels. Steve Davies Senior Petroleum Geologist THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Alaska Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD5-24 Permit to Drill Number: 219-006 Sundry Number: 319-200 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.olaska.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, � 1 Daniel T. Seamount, Jr. Commissioner DATED this el -day of April, 2019. RBDMS �APR 2 3 2019 RECEIVED STATE OF ALASKA APR 17 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR. SUNDRY APPROVALS AOGCC Abandon ❑ Plug Perforations ❑ `Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ 1. Type of Request: Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: Operations Startup❑Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑Q Stratigraphic ❑ Service ❑ 219-006 6. API Number: 3. Address: P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20799-00-00 8. Well Name and Number: 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? CD5-24 Will planned perforations require a spacing exception? Yes ❑ No ❑Q 9. Property Designation (Lease�Number):10. Field/Pool(s): r ASRC-NPR4,ASRC-AA092344;ASRC-NPR2, ASRC-NPR5 Colville River Unit, Alpine 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): 31040' 7857' 3090 Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 115' 115' Surface 2197' 10.75" 2234' 2174' 5210 2470 Intermediate 13848' 7.625" 13882' 7640' 6890 4790 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (tty Tubing Size: Tubing Grade: Tubing MD (k): 13882' 7640' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Q Wellbore schematic H 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Date for 4/21/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑Q 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: Graham (Chip) Alvord Contact Name: Tom Polasek Authorized Title: Alaska Drilling Manager Contact Email: torn. olasek M CO .Com Phone: 907-263-3740 /Contact Authorized Signature: _ t-. - Date: '1-6-L(7--'1 COMMISSION USE ONLY Conditions of approval: Notify Commission so, that a representative may witness Sundry Number: L✓• V G Plug Integrity ❑ BOP Test E Mechanical Integrity Test ❑ Location Clearance ❑ Other: OP r�S �- 78 ��b0 to 8 7�' ZS-oo Psi 0'�u �/ � 0 Post Initial Injection MIT Req'd? Yes E] No LD 6 Spacing Exception Required? Yes [3 No S( Subsequent Form Regt d: �Q — -ABDMSM//APR 2 3 2019 ' APPROVED BY ( �1 <� Approved by: COMMISSIONER THE COMMISSION Date: +( I 6 � �e��.1lq r71 -4/p9/7 y Q T ei.G W/'9'Wt" Submit Form and rm 10-403 Revised 4/2017 Approved appltcatio r date of approval. ,�� Attachments in Duplicate "o1146 ` .1.6, "iis(ta ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 17th, 2019 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit -- Request to start up operations on CD5-24 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to start up operations on CD5-24 following a Temporary Operational Shutdown performed on 3/27/19 (Sundry Number: 319-134). Doyon Rig 25 will move over well CD5-24, drill the CD5-24L1 lateral and complete the well. There is —18 days of work left on CD5-24. ConocoPhillips anticipates resuming operations on CD5-24 approximately April 21st, 2019 with Doyon Rig 25. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10-403 2. CD5-24 Start -Up Procedure Application information already on file with the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 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 Tom Polasek at 263-3740 (Tom.G.Polasek(a)conocophillips.com) or Chip Alvord at 265-6120. Si/V�-t ce zly, �iJ ' /° Tom Polasek Drilling Engineer A11,PINE ConocoPhillips ConocoPhillips Alaska Inc. ALPINE PROJECT CRU CD5-24 (Dual Lateral Producer) START UP PROCEDURE (POST TEMPORARY SHUTDOWN) Pre ted By: Approved G� y i7 / 9 v�' 17 1 / Tom Polasek Date: Johnson Njoku Date: Drilling Engineer Distribution Drilling Manager On file Alpine Engineering Supervisor 1 copy Drilling Superintendent 1 copy Asset Well Team Lead On File CD5 Project Drilling Engineer 1 copy Doyon 19 Supervisor 8 copies Asset Geologist 1 copies Asset Geophysicist On File Alpine Well File 1 copy Ann Haggerty -Sherrod Original Completions Eng. Suprvsr. 1 Copy Supv. Drilling Engineer Approved By: Kurt Alexa Drilling/Completion Superintendent Date: Electronic Copies 10399008 Doyon Drilling via e-mail M -I SWACO via e-mail Schlumberger via e-mail Halliburton via e-mail Alpine Field Drl. Supv via e-mail NSK Mads Drl. Planner via e-mail Drilling Wells Foreman via e-mail Alpine Material Coord. via e-mail DWS/RPS/FS Gen. Fm. via e-mail Drilling Network 10399008 Wells Network 10402118 Approver ID POLASET WBS WCD.WAS.CD05.9D.01 CD5-24 Start Up Procedure Pagel of 3 Version 1.0 ALIME ConocoPhillips Well Plan Table of Contents START UP PROCEDURE CD5-24 Start Up Procedure Page 2 of 3 Version 1.0 i AkidpiNIE ConocoPhillips 1 Start Up Procedure Due to change of drilling rigs, CD5-24 temporarily shut down operations. Doyon 19 was moved to Kuparuk over the ice road bridge and Doyon 25 will be moved from CD2 pad to CD5-24 to resume operations on CD5-24. The well will be started back up as follows: 1. Spot Doyon Rig 25 over CD5-24 2. Install pressure gauge on IA and check for no pressure 3. Rig down pressure gauge and rig up to pump 9.5 ppg KW visc brine down drill pipe and out IA. 4. Circulate out diesel with 9.5 ppg KW brine 5. PU 4" 15.7 lb DP while circulating out diesel in preparation for milling window 6. Test the BPV and tubing hanger to 1000 psi by pumping down the IA. 7. Open valve to IA and flow check for 10 minutes to confirm no flow barrier. Close IA Valve. 8. The Company Man will verify the following barriers are nrecent hefnre Nn tree - Operation / Flowpaths # Well Barrier and V Elements Tested Barrier 1 KWF No flow test Drill Pipe Nipple Down 2 H BPV Tested to 1000 psi Tree, in direction of flow 1 Casing and tubing Tested to 1000 psi Nipple Up BOP Annulus ger indirection of flow 2F rK;W NoFlow Test 9. Nipple down tree 10. Nipple up BOPE stack, RCD, and flowline to MPD manifold. 11. Ensure 2-7/8" x 5-1/2" VBR's are installed in both upper and lower. 12. Nipple up remaining MPD Equipment, flow box and trip nipple. 13. Pull tubing hanger, BPV and 4.5" Blue Tubing by XT39 crossover joint using landing joint 14. PU and install 7-5/8" storm packer below ground level 15. Rig up pressure testing equipment. Pick up 3.5" ( and 4.5") test joint. Set lower test plug. Fill stack and choke manifold with water and check for leaks. ✓ 16. Test all BOP and choke manifold components with 3,500psi high and 250psi low. 17. Rig down pressure testing equipment, pull test plug and test joint, blow down choke line, kill lines and choke manifold. 18. Pressure test MPD system 19. Install FMC thick walled wear bushing 20. Pull 7-5/8" storm packer 21. Prepare for and start milling operation (this step puts operation back onto original plan) CD5-24 Start Up Procedure Page 3 of 3 Version 1.0 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD5-24 Permit to Drill Number: 219-006 Sundry Number: 319-134 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.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. S�inceerely, O 02` 7- v" Daniel T. Seamount, Jr. Commissioner n 4z]DATED this _day of March, 2019. polls 011 TO R SCANNED ee? 0 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECOVED MAR 21 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 21 - 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 Alaska, Inc. Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 219-006 • 3. Address: 6. API Number: P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20799-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CD5-24 Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field/Pool(s): ASRC-NPR4,ASRC-AA092344;ASRC-NPR2, ASRC-NPR5 Colville River Unit, Alpine 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): 29471' 7845' 3090 Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 115' 115' Surface 2197' 10.75" 2234' 2174' 5210 2470 Intermediate 13848' 7.625" 13882' 7640' 6890 4790 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13882' 7640' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 3/28/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown Q - 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: Graham (Chip) Alvord Contact Name: Tom Polasek Authorized Title: Alaska Drilling Manager Contact Email: tom.D.DOlaseknCop.corn Contact Phone: 907-263-3740 Authorized Signature: � Dale: 2 `1 COMMISSION USE ONLY (.� y _',,' / �/l %J I � UI Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31q-1,3q Plug Integrity E]BOP Test C] Mechanical Integrity Test ❑ Location Clearance Other:cla tt /D 404 Svbmy`t sys�-�w+cfrr� of t�vclL o��crcci-i�s a-ncJ las tb �aoAAC 2S.b77-N) I�CSurmc o •rat/a7/5 W/ !x'143 arc f ht /cS�mrc/ wr'i'k"" Gr,aa. 1 m1$ Post Initial Injection MIT Req'd? Yes ❑ No � P f y0d4ty. hhen ht5crecLv�r� �c� tarewarVed- Spacing Exception Required? Yes ❑ No � Subsequent Form Required: (,2 O 4A 2 S. o -2 (10 lO -164 (rid ,{ opt75 "V -t- r<J w e b� dl q yf\ APPROVED BY 7 Approved b COMMISSIONER THE COMMISSION Date: 3 /ZZ kli - 3/22119 RB MAR 212019 ��ol GaInNA L Submk Form and Form 10-003 Revised 4/2017 � Appr vada plication r t e date of approval. Attach nts in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 20th, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit -- Request to shut down operations on CDS-24 Dear Sir or Madam: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a sundry permit for temporary operational shutdown on CD5-24. The shutdown is to change drilling rigs which will allow Rig Doyon 19 to move to Kuparuk before the end of the ice road, and have Rig Doyon 25 move to CD5-24 and resume operations ConocoPhillips anticipates temporarily shutting down operations on March 28th and resuming �— operations on CD5-24 approximately April 14, 2019 with Drilling Rig Doyon 25. �;7- d�y s Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10-403 2. CD5-24 Suspension Procedure Application information already on file with the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 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 Tom Polasek at 263-3740 (Tom.G.Polasek(cDconocophillips.com) or Chip Alvord at 265-6120. Si�cely, Tom Polasek Drilling Engineer h ConocoPhilli s �� p ConocoPhillips Alaska Inc. ALPINE PROJECT CRU CD5-24 (Dual Lateral Producer) TEMPORARY SHUTDOWN PROCEDURE Prep ed By: Approved By:' Tom Polasek ate: Jo on Njoku Date: Drilling Engineer Distribution Drilling Manager On file Alpine Engineering Supervisor 1 copy Drilling Superintendent 1 copy Asset Well Team Lead On File CD5 Project Drilling Engineer 1 copy Doyon 19 Supervisor 8 copies Asset Geologist 1 copies Asset Geophysicist On File Alpine Well File 1 copy Ann Haggerty -Sherrod Original Completions Eng. Suprvsr. 1 Copy Supv. Drilling Engineer Approved By: 2/ Zoiq Kurt AleA Date: Drilling/Completion Superintendent Electronic Copies Doyon Drilling via e-mail M -I SWACO via e-mail Schlumberger via e-mail Halliburton via e-mail Alpine Field Drl. Supv via e-mail NSK Mads Drl. Planner via e-mail Drilling Wells Foreman via e-mail Alpine Material Coord. via e-mail DWS/RPS/FS Gen. For. via e-mail Drilling Network 10399008 Wells Network 10402118 Approver ID POLASET WBS WCD.WAS.CD05.9D.01 CD5-24 Temporary Shutdown Procedure Page 1 of 4 Version 1.0 ALINEConoco hillips Well Plan Table of Contents SUSPENSION PROCEDURE CD5-24 Temporary Shutdown Procedure Page 2 of 4 Version 1.0 r_ Imo,, ConocoPhillips 1 Suspension Procedure Due to change of drilling rigs CD5-24 will temporarily shut down operations. Doyon 19 will be moved to Kuparuk over the ice road bridge and Doyon 25 will be moved from CD2 pad to CD5-24 to resume operations on CD5-24. The well will be temporarily shutdown as follows: 1. Call out Halliburton slickline in preparation to pull SlimPulse MWD tool. 2. RIH with Whipstock BHA with S1imPulse tool in 9.5 ppg KW viscosified brine. 3. Flow check well just prior to setting whipstock seals to confirm 9.5 ppg KW fluid. 4. Pressure test Whipstock seals to 2500 psi for 10 min 5. Orient Whipstock 45°-50° left of highside and stab seals into linertop packer and seal bore extension 6. Set whipstock 450-500 left of high side, shear off mills, and pick up 1-2 stands above whipstock according to procedure in Drilling and Completion Program. 7. Slick line rig up on well and pull Slimpulse 8. Pick up drill pipe and crossover from XT39 to 4.5" Tenaris Blue Tubing (use seal guard for Blue connection) 9. MU Tubing hanger to crossover joint 10. Land tubing hanger with landing joint A, run in lock down screws. Leave landing joint A in place. 11. Observe well for flow for 10 minutes. Install HP-BPV into tubing hanger. 12. Pressure up inner annulus to 2,500 psi to test HP-BPV from below (direction of flow) and tubing hanger from below (direction of flow). Chart tests. These pressure tests are required to consider the HP-BPV and lower hanger seals as mechanical barriers tested in the direction of flow per the COP Well Control Manual 13. Bleed off pressure on annulus 14. Back out the landing joint 15. Flush stack to clean up if needed 16. Observe well for 30 minutes to confirm that the well is static 17. The Company Man will verify the following barriers are present before ND BOP stack: CD5-24 Temporary Shutdown Procedure Page 3 of 4 Version 1.0 Well Barrier and Operation / Flowpaths # Elements Tested Barrier 1 KWF No flow test Drill Pipe Tested to 2,500 2 HP BPV psi in direction of Nipple Down flow BOP' Tested to 2,500 Nipple Up Tree 1 Casing and tubing psi indirection of Annulus hanger flow 2 KWF No Flow Test CD5-24 Temporary Shutdown Procedure Page 3 of 4 Version 1.0 ConocoPhillips 18. ND BOP. NU FMC 5k psi dry hole tree 19. Install the tree test dart in the HP BPV 20. Fill the tree with diesel, pressure test against the HP BPV and test dart. Complete a 250 psi test and a 5000 psi test for 10 minutes each and chart both tests. This will body test the wellhead against the HP BPV (direction of flow with respect to the wellhead) 21. Pull HP BPV and test dart with dry rod 22. Freeze protect the Drill Pipe and IA with Diesel to 2000 ft TVD. Pump diesel down the annulus and U-tube diesel across the circulating manifold on the rig floor down the tubing 23. Shut in well and rig down lines 24. Set "H" type BPV. Test the BPV by pumping through the annulus valve to 2,500 psi in direction of flow 25. Secure well and LD drill pipe as needed 26. Prepare rig for rig move and Move off 27. Freeze protect well (if any pumping occurred) CD5-24 Temporary Shutdown Procedure Page 4 of 4 Version 1.0 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, March 21, 2019 11:51 AM To: Polasek, Tom G Subject: RE: Sundry Approval to Swap Rigs on CD5-24, Permit # 219-006 Thanx for the heads up. I will keep a look out for the sundry From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Thursday, March 21, 2019 10:02 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: Sundry Approval to Swap Rigs on CD5-24, Permit # 219-006 Hi Victoria, RE: Operator: ConocoPhillips Alaska Well: CDS-24 Permit #: 219-006 Forecasted Start Date of Operation: March 26`h, 2019 Attachments: Draft Sundry 10-403 Draft Sundry Cover Letter Draft CD5-24 Temporary Operational Shutdown Procedure Due to Rig Doyon 19 needing to be moved across the ice bridge and over to Kuparuk before the ice road closes — April 15th, we need to shutdown drilling operations on CDS-24 and release rig Doyon 19. We will secure the well, shutdown operations, release rig Doyon 19, wait for rg`�oyon 25 to finish on well CD2 -162, move rig Doyon 25 over to CD5-24 and resume drilling operations. At the time of securing the well, we will have completed drilling and running liner in the Alpine A sand lateral and run a whipstock in place in preparation for milling the window for the Alpine C sand liner. Prior to milling operations we will secure the well with multiple tested barriers in place (Please see Temporary Shutdown Program for Details). When Doyon 25 gets on CD5-24 we will resume drilling operations by milling the window and drilling the Alpine C lateral. Sundry is obtaining final signatures from ConocoPhillips right now and will be sent over shortly. I wanted to let you know ahead of time, to give ample time for you to review before receiving the official Sundry. Pleas call or email if you have any questions. Thank You, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek(@conocophillips.com PTU 2/9-00(l Loepp, Victoria T (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Friday, February 8, 2019 9:47 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]CD5-24 (PTD 219-006) Diverter Variance Approval Thank you Victoria. Regards Weifeng Dai Western North Slope Drilling Engineer ConocoPhillips Alaska Office: (907)-263-4324 Cell Phone: (907)-342-9508 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, February 8, 2019 9:19 AM To: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CD5-24 (PTD 219-006) Diverter Variance Approval Weifeng, A variance to 20 AAC 25.035(h)(2) of the diverter requirement is granted. A diverter is not required on this well since there has not been a significant indication of shallow gas or gas hydrates above the C30 after 24 penetrations. This granted variance must be included with the approved PTD and available on site for the AOGCC Inspectors to view. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppOalaska.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(sl. 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. Loeoo@�alaska aov From: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Sent: Friday, February 8, 2019 9:02 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: CD5-24 (PTD 219-006) Diverter Waiver Morning Victoria, Thank you for the prompt approval of (:U5-24 PTD due to the unexpected rig schedule change. I noticed that there is no clear statement in the approved PTD cover page to either grant or not grant the diverter waiver as what 1 usually saw in the past, could you please clarify that the diver -ter waiver is granted? Regards Weifeng Dai Western North Slope Drilling Engineer ConocoPhillips Alaska Office: (907)-263-4324 Cell Phone: (907)-342-9508 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaslka.gov Re: Colville River Field, Alpine River Oil Pool, CRU CD5-24 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-006 Surface Location: 426' FNL, 2881' FEL, SEC. 18, TI IN, R4E, UM Bottomhole Location: 1747' FNL, 2454' FEL, SEC. 10, TI IN, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for the permit to redrill 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 DATED this i& day of January, 2019. STATE OF ALASKA AL/ A OIL AND GAS CONSERVATION COMMIE. _ ON PERMIT TO DRILL �n nnc vs nnc RECEIVED IAN I ; 7019 1a. Type of Work: 11b. Proposed Well Class: Exploratory - Gas El Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is propo ed for: Drill ❑Q Lateral ❑ Stratigraphic Test El Development -Oil Q Service- Winj ❑ Single Zone ❑Q Coalbef (rates ❑ Redrill ❑ Reentry Ell 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-CD5-24 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, Alaska, 99510-0360 MD: 35630 TVD: 7830 Colville River Unit Alpine Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 426' FNL, 2881' 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: 3940' FNL, 1875' FEL, Sec. 20, T11N, R4E, UM 932669, 340757, 932128, 342658 2/1/2019 4 Total Depth: 1747' FNL, 2454' FEL, Sec. 10, T11 N, R4E, UM 9. Acres in Property: 5032, 3122, 8838, 3200 14. Distance to Nearest Property: 3010'to ADL390337 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 15. Distance to Nearest Well Open Surface: x- 349096 y- 5965792 Zone -4 GL / BF Elevation above MSL (ft): 33.7 • to Same Pool: 50' CD5-313 16. Deviated wells: Kickoff depth: 600 feet 17. Maximum Pot ntial Pressures in psig (see 20 AAC 25,035) Maximum Hole Angle: 90 degrees Downhole: 3 3950 Surface: 256 /84 117-L- 18. Casing Program: Specifications T -Setting Depth - Bottom I Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD I MD I TVD I (including stage data) 42" 20" 78.6 B Welded 74 41 141 1151 115110 yds 13.5' 10.75" 45.5 L-80 TXP 2212 41 41 2253 2185 979sx 11.0ppg, 271sx 15.8ppg G 9.875x11" 7.625" 29.7 L-80 TXP 13816 41 4113857 7531 720sx 15.Sppg Class G 6.75" 4.75" 12.2 L-80 T -Blue 21930 13700 7508 35630 7830 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? Yes taro ❑ 20. Attachments: Property Plat BOPSketch Diverter Sketch Drilling Program B Seabed Report Time v. Depth Plot e Drilling Fluid Program B Shallow Hazard Analysis 20 AAC 25.050 requirements B✓ 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: Weifeng Dai Authorized Name: Chip Alvord Contact Email: Weifen .Dai CO .COm Authorized Title: Drilling Manager Contact Phone: 907-263-4324 Authorized Signature: A51 Date: 12- (2a' 2- o 1 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: l -' Q 50- to -5-2.0=71,1-00-00 Date: 1 ' 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: [V]• Other: QO/J ¢Cb f fo $5-00 3 rq �.. f� Z 5v� 5 r cJ Samples req'd: Yes ❑ Noy Mud log req'd: Yes ❑ No [� fi'nvtULar pp!'e-VC�'/-t /-r'S h Svyrnr/- Ivrtlrw+�d/b>`G Ctwifvrf H2Smeasures: Yes No✓ Directional svy req'd: Yes RNo,❑,/ /, J r3 (� L'r3�L fS /✓1C/vd�h 'p h.,- ako Spacing exception req'd: Yes ❑ No [7� Inclination -only svy req'd: Yes E] NoFR/ Svm%V1G�y Whtn th EitGo7Y�>! elV'ai/ail Post initial injection MIT req'd:Yes❑ No Svb 7 CCr-rhr-"f c✓aF /o vVhrrn RYa/lab/c ,jVb Mii,S-r,�o�lr C45�� /=/i�%d o AGG-cc a55oo� a$ c,Va�/ab/r_ 5wd I-fcz r'rtc/ tv fr-L2 c wrll . AHE O ED BY / f l oo l 1 9 Approved by: d 1 COMMISSIONER THE COMMISSION Date: COMMISSION orm 10-401 Revised 5/2017 R V \\ / H // / P T i e it is valid for 2 I\ oG1 I `ltd off roval per 20 AAC 25.005( MAL L Submit Form and 8 hments in Duplicate 1lI 01- V 1 /`i K othtfi g ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 17, 2018 Alaska Oil and Gas Conservation Commission 333 West 71" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CRU CD5-24 Dear Sir or Madam: ConocoPhillips JAN 14 2019 A`JGCC 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 19. The intended spud date for this well is 2/1/2019. CRU CD5-24 is planned to be an Alpine A and C dual lateral production well, with the Alpine C lateral covered in the CD5- 24L1 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 6-3/4" 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 4-3/4" liner. A second lateral, CD5-24L1, will then be drilled in the Alpine C Sand and lined with 4-3/4" liner as well, with the upper completion covered in the corresponding PTD application. The well is plan to be • fraced later on. 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 Weifeng Dai at 2634324 (weifeng.dai@ConocoPhillips.com) or Chip Alvord at 265-6120. Sincerely, cc: CD5-24 Well File / Ann Haggerty -Sherrod ATO 1530 Johnson Njoku ATO 1720 '`+ Chip Alvord ATO 1570 Weifeng ail 1 Jennifer Hoyt ATO 1760 Drilling Engineer Lanston Chin Kuukpik Corp Applicat Dr Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 CD5-24 Application for Permit to Drill Document Driling. -� &Wells C ---M 11 Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f))............................................................ 3 2. Location Summary (Requirements of20AAC 25.005(c)(2)) ............................................ 3 Requirementsof 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 of20AAC 25.005 (c) (5))......................................................................................................................... 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) .......... 5 7. Diverter System Information (Requirements of20 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 of20AAC 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 of20AAC 25.005 (e)(12)) ...................................7 13. Proposed Drilling Program (Requirements of20AAC 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............................................................................................................. 10 Attachment) Cement Summary ...............................................................................................................10 CD5-24 APD Page 1 of 15 Printed: 19 -Dec -18 Attachment 2 Drilling Hazards Summary ......... Attachment 3 Completion Schematic ................ Attachment 4 Directional Plan ........................ Applicad )r Permit to Drill, Well CRU CDS-24 Saved: 19 -Deo -18 ............................................................... 10 ............................................................... 10 ............................................................... 10 CD5-24 APD Page 2 of 15 Printed: 19 -Dec -18 Applical x Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 1. Well Name (Requirements of20 AAC 25.005 (9) The well for which this application is submitted will be designated as CRU CD5-24 2. Location Summary (Requirements of20AAC25.005(c)(2)) Location at Surface 426' FNL, 2881' FEL, Sec. 18, TI IN, ME, UM NAD 1927 Northings: 5,965,792 Eastings: 349,097 RKB Elevation 74.5' AMSL Pad Elevation 33.7'AMSL To of Productive Horizon Heel 3940' FNL 1875' FEL, Sec. 20, Tl 1N, ME UM NAD 1927 Northings: 5,956,876 Eastings: 355,237 Measured De tlr, RKB.14,210' Total Vertical Depth, RKB. 7,830' Total Vertical Depth, RKB: 7,670' Total Vertical De th, SS: 7,595' Total Depth Toe 1747' FNL, 2454' FEL, Sec. 10, TION, ME, UM NAD 1927 Northings: 5,937,767 Eastings: 364,910 Measured De th, RKB: 1 35,630' Total Vertical Depth, RKB. 7,830' Total Vertical Depth, SS: 1 7,755' Requirements q(20 AAC 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 19. CD5-24 APD Page 3 of 15 Printed: 19 -Dec -18 • Applical, or Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 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 MD/TVD(ft) Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 120/120 10.9 51 56 10.75 2,253 / 2,190 14.5 ?W- 1,432 7.625 13,898 7,645 12.5 3 95 3,167 4.75 35,630/ 7,830 12.5 J,-950 n/a ASP is determined as the lesser of 1) surface pressure at breakdown of the f#mation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less aas gradient to the surface as follows: 1) ASP=[(FGxO.052)-0.1]*D 1 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from ]b./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.1xD) 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) = 977 - (0.1 x 2190') = 745 psi 2. Drilling below 10-3/4" surface casing ASP = [(FG x 0.052) - 0.1] D = [(14.5 x 0.052) - 0.1 ] x 2190' = 1432 psi OR ASP = FPP - (0.1 x D) = 3950 - (0.1 x 7644')3186 psi 3. Drilling below 7-5/8" intermediate casing ASP = [(FG x 0.052) - 0.1 ] D = [(12.5 x 0.052) - 0.1] x 7644 = 4204 psi OR ASP = FPP - (0.1 x D) = 3950- (0.1 x 7830') = 3167 psi M�✓calL. �Iutn M w wi PIQr K�PPy-_ q.6-lo.s' M W CCL P/GV, CD5-24 APD Page 4 of 15 Printed: 19 -Dec -18 Applicac. ar Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 (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 propensity for 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)) Ca 'M and Cementin 1 Program Csg/Tbg Hole Size Weight Grade Conn. Length Top MD7TVD Btm MD/TVD Cement Program OD (in) (lam) (ft) (h) (h) ( 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 BTCM 2,212 41/41 2,253 / 2,190 979 sx DeepCrete Lead 11.0 ppg, 271 sx Class G Tail Slur 15.8 7.625 X$15 29.7 L-80 BTM 13,857 414/418,623 / 7,531 720 sx of Class G at 15.8 ppg 4.75 6.75 12.2 L-80 Blue 21,882 13,74630 / 7,830 No cement, Perforation Sub 7. Diverter System Information(Requirements of20AAC 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 thanf twenty-four penetrations have been completed and there has not been a significant indication of shallow gas or gas Y hydrates above the C30 where casing will be set. CDfr24 APD Page 5 of 15 Printed., 19 -Dec -18 Applicai or Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 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 <10.0 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 (FloPro) weighted to 9.0 — 9.5 ppg with calcium carbonate and KCI and utilize MPD for adding backpressure during connections. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-24 APD Page 6 of 15 Printed: 19 -Dec -18 Surface Intermediate Production Hole Size in. 13.5 9.875 x 11 6.75 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 ft2 50 10 6 10 Minute Gels Ib./100 ftz 60 15 g 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 <10.0 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 (FloPro) weighted to 9.0 — 9.5 ppg with calcium carbonate and KCI and utilize MPD for adding backpressure during connections. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-24 APD Page 6 of 15 Printed: 19 -Dec -18 Applicata r Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 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 of20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of20AAC25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of20AAC25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program(Requirements of20AAC25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 19 onto CD5-24. 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. NofZ> ¢Olae'C rmn�sc/ta> ply CC` 7 �� 13 not- f0 5vrfaCr. 5,-cJGv �lanct Doc 5. Install BOPE and MPD equipment. 1 3 _4201 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 18.0 ppg. Minimum LOT required to drill ahead t h� is 12.5 ppg EMW. e`G L07' �' b mi-- )c�-7r o° o7- 7,v -4&6zf �- 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). 4 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 6-3/4" drilling BHA. Log top of cement with sonic tool in recorded mode. 16. Chart casing pressure test to 3500 psi for 30 minutes. h GCS f h �- l09 /rva4/. fa 4`3 & 6- 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 6-3/4" 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. CD5-24 APD Page 7 of 15 Printed. 19 -Dec -18 20. Run 4-3/4" 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 C135-24 and begin PTD for CD5-24L1. Applica{ .or Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 CD5-24 APD Page 8 of 15 Printed. 19 -Dec -18 Applicat or Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well CD5-24 will be injected into a permitted surface casing x production casing annulus on CD5. The CD5-24 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 CD5-24 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 (C40). 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) * (2,1891) + 1,500 psi = 2,866 psi Pore Pressure = 1,049 psi Therefore 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 as 6890 psi 5856 psi CD5-24 APD Page 9 of 15 Printed: 19 -Dec -18 15. Attachments Attachment I Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan Applica{ or Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 CD5-24 APD Page 10 of 15 Printed.19-Dec-18 Applicat Attachment 1 — Cement Summary CD5-24 wD17 Cementing Program: CD5-24 Cement Schematic 9.718" x 11" Hole Kuparuk C 12,729' MD 17,335' TVD Alpine C 13,318' MD / 7,540' TVD Alpine A 14,209' MD / 7,670' TVD CD5-24 A Sand 6-3/4" Hole 35,630' MD / 7,830 @ 89- jr Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 20" 94# H-40 Welded Conductor to 120' 10314" 45.5# L-80 HYD563/BTCM 2,253' MD 12,190' TVD @ 28" inc. wo 0c, cV -roc agAc ci(e(3 n� wo ToGcdlc it73al' w/po%• Top of Cement 12,169' MD 17,085' TVD KOP in Alpine C 43 , 332'MD / 7,543' TVD �\ 1vPopc; rj \ \\`. 7-5/8" 29.7 L-80 HYD563 X BTCM Casing 13,898' MD / 7,644' TVD @ 84° i I � y i I c. t t CD5-241-1 C Sand 6-314" Hole ------ J, 27,266' MD 17,543 @ 89- 0V CD5-24 APD Page 11 of 15 Printed. 19 -Dec -18 Applica{ or Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 10.75" Surface Casing run to 2.253' MD / 2.189' TVD Cement from 2253' MD to 1753'(500' of tail) with Class G + Adds. @ 15.8 PPG, and from 1753' 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 1,694' MD to surface with Arctic Lite Crete @ 11.0 ppg Conductor (120'- 41) X 1.3645 ft3/ft X 1.0 (0% excess) = 108 ft' Permafrost to Conductor (1,325'-1201 X 0.3637 ft3/ft X 3.5 (250% excess) = 1,547 ft3 Top of Tail to Permafrost (1,753'- 1,3251 X 0.3637 ft3/ft X 1.5 (50% excess) = 233 ft3 Total Volume = 108 + 1,547 + 233 = 1,888 ft3 => 979 sx of 11.0 ppg DeepCrete @ 1.93 ft3 /sk Tail slurry from 2,234' MD to 1,734' MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,253'-1,753) X 0.3637 ft3/ft X 1.50 (50% excess) = 273 ft3 Shoe Joint (801 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 13,898' MD / 7,644' TVD Top of slurry is designed to be at 12,169' 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 13,898' MD to 13,808' MD with 15.8 ppg Class G + additives Shoe to top of 9-7/8" Hole (13,898'- 13,808 X 0.2148 ft3/ft X 1.40 (40% excess) = 27 ft3 11" Hole to to Top of Cement (13,808'- 12,169) X 0.3428 ft3/ft X 1.40 (40% excess) = 787ft3 Shoe Joint (80) X 0.2578 ft3/ft X 1.0 (0% excess) = 21 ft' Total Volume = 27+ 787 + 21 = 835 ft3 => 720 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8% 5002 accelerator @ 1.16 ft3/sk CD5-24 APD Page 12 of 15 Printed. 19 -Dec -18 Applical ,or Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 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 Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots traveling cylinder diagrams Abnormal Reservoir Pressure Low 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. Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 9-7/8" x 11" Hole / 7-5/8" Casine Interval Event Risk Level Miti ation Strategy Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent Lost circulation Low circulating density (ECD) monitoring, mud rheology, lost circulation Abnormal Reservoir Pressure Low 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 across the path of the planned wellbore. Hydrogen Sulfide gas Low 1-12S drills, detection systems, alarms, standard well control practices, mud scavengers 6-3/4" Open Hole Production Interval Event Risk Level Mitigation Strategy Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent 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. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers CD5-24 APD Page 13 of 15 Printed. 19 -Dec -18 Applicai or Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 Well Proximitv Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. Drillinq 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. CD5-24 APD Page 14 of 15 Printed: 19 -Dec -18 Applicat s Permit to Drill, Well CRU CD5-24 Saved: 19 -Dec -18 Attachment 3 — Completion Schematic (includes Alpine C lateral, as detailed in CD5-241-1 PTD) CD5 - 24 Alpine A/C Dual Lateral Producer Proposed Schematic C sand Lateral V1'x 1' GLM 6 3f4' Hole TD 13,332'- 27,266'M D 4-1/." 12.6# L-80 TXP Linervd pert pups O O O O O O o O Premier Packer at -13,200 MD HP CMU Sliding sleeve for Selectivity -13,300' MD 3-1/2" 9.3#TN110SS TNT Production Packer at —13,700' MD ZXP liner top packer (whipstock base) at 13.748 MD 4-%" 12.6# L-80 TSBIue? A sand Lateral 6 314' Hole TD 13,898'-35,630' MD Liner wl frac pons CD5-24 APD Page 15 of 15 Printed: 19 -Dec -18 20"94#H -0O Welded Upper Completion: I Conductorto 115 MID 1)4%`-126#TSBIue Wring I 2) Shallow nipple profile 3.813' ID 3) 4-W x 1' Camco KBM G GLIA (xx`) w/DCK2 pinned for 2500 psi casing to tbg shear 4) TNT Packer 5) X Nipple profile, 2813" I 6)TNT Packer I 1 7) XN Nipple profile, 2.813" I ` 10-314"45.5# L-80 HYD 563x Lower Co letion: Surface Casing Cat T,253' (vID 8) Plop and op liner in C sand I - no )unction -4.5"12.6# L-80 vd pert pups I 9) ZXP liner to p packer & Flexlock Liner Hanger I *J 4-%' x 1- GLM XO 5" Hydril 521 BOX X 4-!' H563 pin I I I I -4.5' Threads TBD 12.6# L-80 vA Frac Ports I I I I 4112" 126# 1--80 TSBIue I I I 13,200' MD I I I I ' 4-%'x 1" GLM I I 7 518" 29.7# L-80 Hyd 563 x BTC Intermediate Casing at 13,898' MD I i C sand Lateral V1'x 1' GLM 6 3f4' Hole TD 13,332'- 27,266'M D 4-1/." 12.6# L-80 TXP Linervd pert pups O O O O O O o O Premier Packer at -13,200 MD HP CMU Sliding sleeve for Selectivity -13,300' MD 3-1/2" 9.3#TN110SS TNT Production Packer at —13,700' MD ZXP liner top packer (whipstock base) at 13.748 MD 4-%" 12.6# L-80 TSBIue? A sand Lateral 6 314' Hole TD 13,898'-35,630' MD Liner wl frac pons CD5-24 APD Page 15 of 15 Printed: 19 -Dec -18 R m d 0 0 L 7-5/8 x 9-7/8by11 m 0 P 00,.00 00 o $ 0 0 O O E y gyp' ^ O OOO.00 0000 000 O( (Q'O O'A000 OOO�fJ 00000( to„�vo (O i� W O� N M Of(lmfl r� f0 N O N N N N N N M (7 ( 0 4500 9000 13500 18000 22500 27000 Horizontal Departure 1/ 2018 CD5-24 wp17 (9C) Measured Depth 29 �� 10-3/4.13-1/2 Plan: D25 @ 74.50usft (D25) Magnetic Distance 350 700 1050 1400 1750 2100 2450 Measured Depth Depth From Depth To Survey /Plan 40 80 1800.00 CM -24 "17 1800.00 2250.00 CM -24m,17 Tool GY0. SS MWD East / X- Pad Elevation: 3370 1800.00 225eW CDS24 x,17 2250.00 3750.00 CM24 x,17 2250.00 13895.00 CD5-24x,17 13895.00 5395.00 ODS -24 x,17 13895.0035629.55 CD5-24V MWD+IFR-AKCAZ-SC MWD MWD.IFA-AKGtZ-SC MWD MWD.1FR-M-CAZSC ante 119.80 119.80 20x 42 2189.50 2252.54 10-314x13-1/2 7644.50 13898.15 7-5/8 x 9-7/8by11 7829.50 35M.65 41/2x63/4 Sec MD Inc Ali TVD +N/ -S +E/ -W Dog TFace VSecl Target 1 40.80 0.00 0.00 40.81 0.00 0.00 0.00 0.00 0.00 2 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 3 1000.00 6.00 163.00 999.27 -20.01 6.12 1.50 163.00 20.34 412]8.81 11.57 163.001274.50 50.69 18.56 2.00 0.00 61.69 5 1380.68 11.57 163.00 1374.50 -80.27 24.54 0.00 0.00 81.59 6 2252.54 28.90 156.82 2189.50 359.73 133.89 2.00 -10.00 37].80 7 2272.54 28.90 156.82 2207.01 -368.62 137.69 0.00 0.00 387.39 8 2844.94 45.00 146.66 2663.36 -667.07 304.63 3.00 -25.00 729.26 9 3011.61 50.00 146.66 2775.93 -769.69 372.15 3.00 0.00 851.96 10 3711.61 50.00 146.66 3225.88 -1217.65 666.90 0.00 0.00 1387.57 11 4394.48 63.37 143.31 3600.16 -1683.11 994.59 2.00 -1276 1955.01 1212815.80 63.37 143.31 7374.63 -7719.73 5492.49 0.00 0.00 9440.48 13132]3.71 77.00 141.47 7529.50 -&160.00 5755.00 3.00 -7.57 9866.99 14134]3.71 77.00 141.47 7574.49 -8212.45 5876.39 0.00 0.0010060.00 1513898.15 84.00 141.47 7644.50 -8539.72 6137.00 1.65 0.00 10474.35 1613918.15 84.00 141.47 7646.59 -8565.28 6149.39 0.00 0.0010494.05 1714209.99 87.00 146.50 7669.50 -8790.53 6320.36 2.00 59.3310783.58 1814515.44 89.59 152.04 7678.59 -9052.84 6476.30 2.00 65.0111088.73 1935829.55 89.59 152.04 7829.50 -21701.13 16377.01 0.00 0.0032180.11 CDS-24 2. Toe 082918 Failure with CD5-313PB1 in the production hole section Permit Pack plan Summ ,Z-000 \0000 � \2000 6000 \2�C loeteh�l 210 ' CD5-313PB1 27180 180 30000 - "- seine lAccepted by 32810 35630 Magnetic Model & Date: BGGM2018 01 -Jul -19 ignetic North is 16.07° East of True North (Magnetic Declination) vlagnetic Dip & Field Strength: 80.72° 57373nT Annotation Lithology column KOP: Stan 20.34°000' DLS, 1,5- TF, for 400' W. Dai Start 61.691100' DLS, 2 -TF, for 278.61' Stan 8IM-1100' DLS, O -TF for 102.07 +r s Stan 377.81100' DLS, 2 -TF, for 871.85 Stan 387.39°/100' DLS, 0-T ,, for ar Start 729261100' DLS, 3 -TF, for 572.4' WERMi-Wttef,^41 Base Permafl Stan 851.961100' DLS, 3 -TF, for 166.67' 1�I bas Start 1387.57°/100' DLS, 0° TF for 700' 1955.01-/100' DLS, 2 -TF, for 682.88' C,30Stan Stan 9440.48°/100' DLS, 0 -TF, for 8421.31' Start 9866.9911001 DLS, 3 -TF, for 457.91' Start 100601100 DLS, W TF, for 200' C-10 Stan 10474.351100' DLS, 1.65° TF, for 424.44' Start 10494.051100' DLS, 0 -TF, for 20 Stan 10783.56-/100' DLS, 2 -TF, for 291.84' MOK Start 11088.731100 DIS, 2 -TF, for 305.45' K-2 Start 32180.111100' DLS, 0- TF, for 21114.11' .s TD: 35629.55' MD, 7829.5' TVD m Rim. Albian 97 Al Aan 96 ���� TCR required loeteh�l 210 ' CD5-313PB1 27180 180 30000 - "- seine lAccepted by 32810 35630 Magnetic Model & Date: BGGM2018 01 -Jul -19 ignetic North is 16.07° East of True North (Magnetic Declination) vlagnetic Dip & Field Strength: 80.72° 57373nT Annotation Lithology column KOP: Stan 20.34°000' DLS, 1,5- TF, for 400' W. Dai Start 61.691100' DLS, 2 -TF, for 278.61' Stan 8IM-1100' DLS, O -TF for 102.07 +r s Stan 377.81100' DLS, 2 -TF, for 871.85 Stan 387.39°/100' DLS, 0-T ,, for ar Start 729261100' DLS, 3 -TF, for 572.4' Base Permafl Stan 851.961100' DLS, 3 -TF, for 166.67' bas Start 1387.57°/100' DLS, 0° TF for 700' 1955.01-/100' DLS, 2 -TF, for 682.88' C,30Stan Stan 9440.48°/100' DLS, 0 -TF, for 8421.31' Start 9866.9911001 DLS, 3 -TF, for 457.91' Start 100601100 DLS, W TF, for 200' C-10 Stan 10474.351100' DLS, 1.65° TF, for 424.44' Start 10494.051100' DLS, 0 -TF, for 20 Stan 10783.56-/100' DLS, 2 -TF, for 291.84' Start 11088.731100 DIS, 2 -TF, for 305.45' K-2 Start 32180.111100' DLS, 0- TF, for 21114.11' .s TD: 35629.55' MD, 7829.5' TVD Albian 97 Al Aan 96 Prepared by Checked by: lAccepted by Approved by: CS DeLapp V Osara Jeff Ryan W. Dai V � Z fi1N qe� N QI U m cul pip U U V N m U a rn C) M U�c L z M o N d Q <C)p N R1 p ~ ll] p U U ii N� O v C) U 'Pra m N p N N m a d p Q rn M v p U c p U v U DU y Z d Ucl U U �/� L • o Q 0 � U3 U � LO 2 N 44 I QQ U � p UU o� NU p U r U u 'A W O m � LO r " m N M N U n 3 Q N Mp p > N O C)mo ® o 1— U " C U p U Q M o W p a 5 - OM p m � � M U> i O �} � M p 3 > QIb m L6 U ttl v > 3 oa c 3 U M � W C) > m m r p a p � U D Q M U v > � U �n p ,won1 L6 U �m ` � X v M r a > 0 U 3 w " t a m m L6 U M N M p p U ' Y/ N Q o 3 V o M B p E U (w/!}sn 0009) u!UIJON a; o w O LO N d � Cl) • 0 O x O N 00 00� s�,o � opo O 0p 00 0� Op0 O 9 p 00 GAO 000 Oce p Lo OD i x00 O X000 O O 0 O 0 000 p�c� O 0p r o O 0 00 0cA O! O O O O0 +. Y�00 00 N 00 (a W C x V. = N V �! N ?) w .� O x O 0 000 pQ O6, � M O Nt N O o LO N 00 p Q c Q �� y .Q X00000 < aQ� s co Ztf O coU- U y/ C v Cl) U Q C H O N 3 L6 a Lo N �' � O Qo a o V 3 0 oO O O O O O O o O O O O O L O O O Ul (+)4lJoN/(-)'i lnoS N N M c6 X N r X 00 LO O O O N T 0 0 0 N M 0 0 0 v N O O 0 0 N 1 V O� V O (6 0 O o co :c T a) U) U O O 0 N T I 1.1 05995 00095 OOOK 00055 3 OOOZE 00015 > 00005 ; w 0006Z OOO8Z •� OOOLZ 0009Z T 00096 75 ooOVZcc _ UL OOOSZ Q OOOZZ T co OOOLZ ao a � .Q a 000oZ , U = a ¢ 00066 c� U .9— 0008 L Y U Q -j OOOL L m Y 0009L_ cc L � /LTyL _ Q r 1 _ 000 rn _ �L 00 @ Q 0'L NQ 0000L 4 e E 3 L Yy o 0008 CL o 0 U DO V m ,U 0' Nm 000 LO9 eg�oy i „ O O x M 0 0 O O O' O N V W y;dad je3ijj9n anjl M c6 X N r X 00 LO O O O N T 0 0 0 N M 0 0 0 v N O O 0 0 N 1 V O� V O (6 0 O o co :c T a) U) U O O 0 N T I 1.1 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Prelim: CD5-24 (9C) - Slot 24 50103xxxxx00 CD5-24 (9C) Plan: CD5-24 wp17 (9C) Standard Proposal Report 16 November, 2018 ConocoPhillips ConocoPhillips Database: OAKEDMPi Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Prelim: CD5-24 (9C) Wellbore: CDS-24 (9C) Design: CD5-24 wpl7(9C) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Prelim: CD5-24 (9C) - Slot 24 Pian: D25 @ 74.50usft (D25) 0111 Plan: D25 @ 74.50usft (D25) True 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 site CDS Alpine West Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft SIM Radius: Geld Convergence: well Prelim: CD5-24 (9C) - Slot 24 Well Position +N/ -S 6.96 usft Northing: Latitude: +E/ -W -122.53 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 33.70 usft Wellbore C05-24 (9C) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°I V) (nT) BGGM2018 7/1/2019 16.07 80.72 57,373 �— Design C05-24 wp17 (9C) Audit Notes: Version: Phase: PLAN Tie On Depth: 40.80 Vertical Section: Depth From (TVD) +N/ -S +EbW Direction (usft) (usft) (usft) (°) 40.80 0.00 0.00 149.41 11/162018 9:38.57AM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Prelim: CD5-24 (9C) - Slot 24 Company: ConowPhillips(Alaska) Inc. -WNS TVD Reference: Plan: D25 @ 74.50usft (D25) Project: Western North Slope MD Reference: Plan: D25 @ 74.50usft (D25) Site: CDS Alpine West Pad North Reference: True Well: Prelim: CD5-24 (9C) Survey Calculation Method: Minimum Curvature Wellbore: CD5-24 (9C) Gyrodata gyro single shots 2 Design: CD5-24 wp17 (9C) CD5-24 wp17 (9C) (CD5-24 (9C)) MWD Plan Survey Tool Program Date 9/12/2018 Depth From Depth To just" (usft) Survey (Wellbore) Tool Name Remarks 1 40.80 1,800.00 CD5-24 wp17 (9C) (CD5-24 (9C)) GYD-GC-SS Build Turn Gyrodata gyro single shots 2 1,800.00 2,250.00 CD5-24 wp17 (9C) (CD5-24 (9C)) MWD Rate Rate Rate TFO MWD - Standard 3 1,800.00 2,250.00 CDS-24 wpl 7 (9C) (CD5-24 (9C)) MWD+IFR-AK-CAZ-SC (usft) ("1100usft) (°1100usft) ('1100usft) MWD+IFR AK CAZ SCC 4 2,250.00 3,750.00 CD5-24 wpl7 (9C) (CD5-24 (9C)) MWD 0.00 0.00 0.00 0.00 MWD - Standard 5 2,250.00 13,895.00 CD5-24 wp17 (9C) (CD5-24 (9C)) MWD+IFR-AK-CAZ-SC 600.00 0.00 0.00 0.00 MWD+IFR AK CAZ SCC 6 13,895.00 15,395.00 CD5-24 wpl7 (9C) (CD5-24 (9C)) MWD 163.00 999.27 -20.01 6.12 MWD - Standard 7 13,895.00 35,629.55 CD5-24 wp17 (9C) (CD5-24 (9C)) MWD+IFR-AK-CAZ-SC 11.57 163.00 1,274.50 -60.69 MWD+IFR AK CAZ SCC Plan Sections-� - Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E1 -V1 Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) ("1100usft) (°1100usft) ('1100usft) (^) Target i 40.80 0.00 0.00 40.60 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 1,000.00 6.00 163.00 999.27 -20.01 6.12 1.50 1.50 0.00 163.00 1,278.61 11.57 163.00 1,274.50 -60.69 18.56 2.00 2.00 0.00 0.00 1,380.66 11.57 163.00 1,374.50 -80.27 24.54 0.00 0.00 0.00 0.00 2,252.54 28.90 156.82 2,189.50 -359.73 133.89 2.00 1.99 -0.71 -10.00 2,272.54 28.90 156.82 2,207.01 -368.62 137.69 0.00 0.00 0.00 0.00 2,844.94 45.00 146.66 2,663.36 -667.07 304.63 3.00 2.81 -1.78 -25.00 3,011.61 50.00 146.66 2,775.93 -769.69 372.15 3.00 3.00 0.00 0.00 3,711.61 50.00 146.66 3,225.88 -1,217.65 666.90 0.00 0.00 0.00 0ol) 4,394.48 63.37 143.31 3,600.16 -1,683.11 994.59 2.00 1.96 -0.49 -12.76 12,815.80 63.37 143.31 7,374.63 -7,719.73 5,492.49 0.00 0.00 0.00 0.00 13,273.71 77o(I 141.47 7,529.50 -8,060.00 5,755.00 3.00 2.98 -0.40 -7.57 13,473.71 77.00 141.47 7,574.49 -8,212.45 5,876.39 0.00 0.00 0.00 0.00 13,898.16 84.00 141.47 7,644.50 -8,539.72 6,137.00 1.65 1.65 0.00 0.00 13,918.16 84.00 141.47 7,646.59 -8,555.28 6,149.39 0.00 0.00 0.00 0.00 14,209.99 87.00 146.50 7,669.50 -8,790.53 6,320.37 2.00 1.03 1.72 59.33 14,515.44 89.59 152.04 7,678.59 -9,052.84 6,476.30 2.00 0.85 1.81 65.01 35,629.55 89.59 152.04 7,829.50 -27,701.13 16,377.01 0.00 0.00 0.00 0.00 CD5-24 2. Toe 08291 11/182018 9:38:57AM Page 3 COMPASS 5000.14 Build 85D ♦--� ConocoPhillips ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMPI ConocoPhillips(Alaska) Inc. Western North Slope CD5 Alpine West Pad Prelim: CD5-24 (9C) CD5-24 (9C) CD5-24 wp17 (9C) -WNS Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Prelim: CDS-24 (9C) - Slot 24 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) (^) (1) (usft) (usft) (usft) (usft) (°1100usft) ('1100usft) ('1100usft) 40.80 0.00 0.00 40,80 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 1.50 163.00 699.99 -1.25 0.38 1.27 1.50 1.50 0.00 800.00 3.00 163.00 799.91 -5.01 1.53 5.09 1.50 1.50 0.00 900.00 4.50 163.00 899.69 -11.26 3.44 11.45 1.50 1.50 0.00 1,000.00 6.00 163.00 999.27 -20.01 6.12 20.34 1.50 1.50 0.00 1,100.00 8.00 163.00 1,098.52 -31.66 9.68 32.18 2.00 2.00 0.00 1,200.00 10.00 163.00 1,197.28 -06.62 14.25 47.39 2.00 2.00 0.00 1,278.61 11.57 163.00 1,274.50 -60.69 18.56 61.69 2.00 2.00 0.00 1,300.00 11.57 163.00 1,295.46 -64.79 19.81 65.86 0.00 0.00 0.00 1,380.68 11.57 163.00 1,374.50 -80.27 24.54 81.59 0.00 0.00 0.00 1,400.00 11.95 162.68 1,393.41 -84.04 25.70 85.42 2.00 1.97 -1.68 1,500.00 13.93 161.28 1,490.87 -105.32 32.65 107.28 2.00 1.98 -1.40 1,600.00 15.91 160.22 1,587.49 -129.62 41.15 132.52 2.00 1.98 -1.06 1,700.00 17.90 159.40 1,683.17 -156.90 51.20 161.12 2.00 1.99 -0.83 1,800.00 19.88 158.73 1,777.78 -187.13 62.77 19344 2.00 1.99 -0.67 1,900.00 21.87 158.18 1,871.21 -220.28 75.87 228.23 2.00 1.99 -0.55 2,000.00 23.87 157.72 1,963.34 -256.30 90.47 266.66 2.00 1.99 -0.46 2,100.00 25.86 157.32 2,054.07 -295.14 106.55 308.28 2.00 1.99 -0.39 2,200.00 27.85 156.98 2,143.28 -336.77 124.09 353.05 2.00 1.99 -0.34 2,252.54 28.90 156.82 2,189.50 -359.73 133.89 377.80 2.00 1.99 -0.31 2,272.54 28.90 156.82 2,207.01 -368.62 137.69 387.39 0.00 0.00 0.00 2,300.00 29.65 156.12 2,230.96 -380.93 143.05 400.72 3.00 2.73 -2.56 2,400.00 32.40 153.80 2,316.65 A27.60 164.90 452.01 3.00 2.75 -2.31 2,500.00 35.19 151.82 2,399.75 477.06 190.34 507.53 3.00 2.79 -1.98 2,600.00 38.01 150.09 2,480.02 -529.16 219.31 567.12 3.00 2.82 -1.73 2,700.00 40.85 148.57 2,557.25 -583.77 251.72 630.63 3.00 2.84 -1.52 2,800.00 43.71 147.22 2,631.23 -640.74 287.49 697.87 3.00 2.86 -1.36 2,844.94 45.00 146.66 2,663.36 -667.07 304.63 729.26 3.00 2.87 -1.25 2,900.00 46.65 146.66 2,701.73 -700.06 326.34 768.70 3.00 3.00 0.00 3,000.00 49.65 146.66 2,768.44 -762.28 367.28 843.10 3.00 3.00 0.00 3,011.61 50.00 146.66 2,775.93 -769.69 372.15 851.96 3.00 3.00 0.00 3,100.00 50.00 146.66 2,832.74 -826.26 409.37 919.59 0.00 0.00 0.00 3,200.00 50.00 146.66 2,897.02 -890.25 451.48 996.11 0.00 0.00 0.00 3,300.00 50.00 146.66 2,961.30 -954.25 493.59 1,072.62 0.00 0.00 0.00 3,400.00 50.00 146.66 3,025.58 -1,018.24 535.69 1,149.14 0.00 0.00 0.00 3,500.00 50.00 146.66 3,089.86 -1,082.23 577.80 1,225.66 0.00 0.00 0.00 3,600.00 50.00 146.66 3,154.14 -1,146.23 619.91 1,302.17 0.00 0.00 0.00 3,700.00 50.00 146.66 3,218.42 -1,210.22 662.01 1,378.69 0.00 0.00 0.00 3,711.61 50.00 146.66 3,225.88 -1,217.65 666.90 1,387.57 0.00 0.00 0.00 3,800.00 51.73 146.16 3,281.67 -1,274.75 704.84 1,456.03 2.00 1.95 -0.56 3,900.00 53.68 145.62 3,342.26 -1,340.61 749.45 1,535.43 2.00 1.95 -0.54 4,000.00 55.64 145.11 3,400.10 -1,407.73 795.81 1,616.79 2.00 1.96 -0.51 4,100.00 57.59 144.63 3,455.13 -1,476.01 843.85 1,700.02 2.00 1.96 -0.49 4,200.00 59.55 144.16 3,507.26 -1,545.39 893.53 1,785.03 2.00 1.96 -0.46 4,300.00 61.52 143.72 3,556.45 -1,615.76 944.78 1,871.69 2.00 1.96 -0.45 4,394.48 63.37 143.31 3,600.16 -1,683.11 994.59 1,955.01 2.00 1.96 -0.43 4,400.00 63.37 143.31 3,602.63 -1,687.06 997.54 1,959.91 0.00 0.00 0.00 4,500.00 63.37 143.31 3,647.45 -1,758.74 1,050.95 2,048.80 0.00 0.00 0.00 11/18/2018 9:38:57AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Prelim: CD5-24 (9C) - Slot 24 Company: ConocoPhslips(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: Prelim: CD5-24 (9C) Survey Calculation Method: Minimum Curvature Wellbore: CD5-24 (9C) (^) (usft) Design: CDS-24 wp17(9C) (usft) 1°1100usfo Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +EJ -V1 Section Rate Rate Rate (usft) (^) (^) (usft) (usft) (usft) (usft) 1°1100usfo ('/100usft) ("1100usft) 4,600.00 63.37 143.31 3,692.27 -1,830.43 1,104.36 2,137.69 0.00 0.00 0.00 4,700.00 63.37 143.31 3,737.09 -1,902.11 1,157.77 2,226.57 0.00 0.00 0.00 4,800.00 63.37 143.31 3,781.91 -1,973.79 1,211.18 2,315.46 0.00 0.00 0.00 4,900.00 63.37 143.31 3,826.73 -2,045.47 1,264.59 2,404.35 0.00 0.00 0.00 5,000.00 63.37 143.31 3,871.55 -2,117.16 1,318.00 2,493.24 0.00 0.00 0.00 5,100.00 63.37 143.31 3,916.37 -2,188.84 1,371.41 2,582.12 0.00 0.00 0.00 5,200.00 63.37 143.31 3,961.19 -2,260.52 1,424.82 2,671.01 0.00 0.00 0.00 5,300.00 63.37 143.31 4,006.01 -2,332.20 1,478.23 2,759.90 0.00 0.00 0.00 5,400.00 63.37 143.31 4,050.83 -2,403.89 1,531.64 2,848.78 0.00 0.00 0.00 5,500.00 63.37 143.31 4,095.66 -2,475.57 1,585.06 2,937.67 0.00 0.00 0.00 5,600.00 63.37 143.31 4,140.48 -2,547.25 1,638.47 3,026.56 0.00 0.00 0.00 5,700.00 63.37 143.31 4,185.30 -2,618.94 1,691.88 3,115.45 0.00 0.00 0.00 5,800.00 63.37 143.31 4,230.12 -2,690.62 1,745.29 3,204.33 0.00 0.00 0.00 5,900.00 63.37 143.31 4,274.94 -2,762.30 1,798.70 3,293.22 0.00 0.00 0.00 6,000.00 63.37 143.31 4,319.76 -2,833.98 1,852.11 3,382.11 0.00 0.00 0.00 6,100.00 63.37 143.31 4,364.58 -2,905.67 1,905.52 3,470.99 0.00 0.00 0.00 6,200.00 63.37 143.31 4,409.40 -2,977.35 1,958.93 3,559.88 0.00 0.00 0.00 6,300.00 63.37 143.31 4,454.22 -3,049.03 2,012.34 3,648.77 0.00 0.00 0.00 6,400.00 63.37 143.31 4,499.04 -3,120.71 2,065.75 3,737.66 0.00 0.00 0.00 6,500.00 63.37 143.31 4,543.86 -3,192.40 2,119.16 3,826.54 0.00 0.00 0.00 6,600.00 63.37 143.31 4,588.68 -3,264.08 2,172.58 3,915.43 0.00 0.00 0.00 6,700.00 63.37 143.31 4,633.50 -3,335.76 2,225.99 4,004.32 0.00 0.00 0.00 6,800.00 63.37 143.31 4,678.32 -3,407.44 2,279.40 4,093.21 0.00 0.00 0.00 6,900.00 63.37 143.31 4,723.14 -3,479.13 2,332.81 4,182.09 0.00 0.00 0.00 7,000.00 63.37 143.31 4,767.96 -3,550.81 2,386.22 4,270.98 0.00 0.00 0.00 7,100.00 63.37 143.31 4,812.78 -3,622.49 2,439.63 4,359.87 0.00 0.00 0.00 7,200.00 63.37 143.31 4,857.60 -3,694.18 2,493.04 4,448.75 0.00 0.00 0.00 7,300.00 63.37 143.31 4,902.42 -3,765.86 2,546.45 4,537.64 0.00 0.00 0.00 7,400.00 63.37 143.31 4,947.24 -3,837.54 2,599.86 4,626.53 0.00 0.00 0.00 7,500.00 63.37 143.31 4,992.07 -3,909.22 2,653.27 4,715.42 0.00 0.00 0.00 7,600.00 63.37 143.31 5,036.89 -3,980.91 2,706.68 4,804.30 0.00 0.00 0.00 7,700.00 63.37 143.31 5,081.71 -0,052.59 2,760.09 4,893.19 0.00 0.00 0.00 7,800.00 63.37 143.31 5,126.53 -4,124.27 2,813.51 4,982.08 0.00 0.00 0.00 7,900.00 63.37 143.31 5,171.35 -4,195.95 2,866.92 5,070.97 0.00 0.00 0.00 8,000.00 63.37 143.31 5,216.17 -4,267.64 2,920.33 5,159.85 0.00 0.00 0.00 8,100.00 63.37 143.31 5,260.99 -4,339.32 2,973.74 5,248.74 0.00 0.00 0.00 8,200.00 63.37 143.31 5,305.81 -4,411.00 3,027.15 5,337.63 0.00 0.00 0.00 8,300.00 63.37 143.31 5,350.63 1,482.68 3,080.56 5,426.51 0.00 0.00 0.00 8,400.00 63.37 143.31 5,395.45 4,554.37 3,133.97 5,515.40 0.00 0.00 0.00 8,500.00 63.37 143.31 5,440.27 4,626.05 3,187.38 5,604.29 0.00 0.00 0.00 8,600.00 63.37 143.31 5,485.09 1,697.73 3,240.79 5,693.18 0.00 0.00 0.00 8,700.00 63.37 143.31 5,529.91 1,769.41 3,294.20 5,782.06 0.00 0.00 0.00 8,800.00 63.37 143.31 5,574.73 -4,841.10 3,347.61 5,870.95 0.00 0.00 0.00 8,900.00 63.37 143.31 5,619.55 1,912.78 3,401.02 5,959.84 0.00 0.00 0.00 9,000.00 63.37 143.31 5,664.37 1,984.46 3,454.44 6,048.72 0.00 0.00 0.00 9,100.00 63.37 143.31 5,709.19 -5,056.15 3,507.85 6,137.61 0.00 0.00 0.00 9,200.00 63.37 143.31 5,754.01 -5,127.83 3,561.26 6,226.50 0.00 0.00 0.00 9,300.00 63.37 143.31 5,798.83 -5,199.51 3,614.67 6,315.39 0.00 0.00 0.00 9,400.00 63.37 143.31 5,843.66 -5,271.19 3,668.08 6,404.27 0.00 0.00 0.00 9,500.00 63.37 143.31 5,888.48 -5,342.88 3,721.49 6,493.16 0.00 0.00 0.00 9,600.00 63.37 143.31 5,933.30 -5,414.56 3,774.90 6,582.05 0.00 0.00 0.00 9,700.00 63.37 143.31 5,978.12 -5,486.24 3,828.31 6,670.94 0.00 0.00 0.00 9,800.00 63.37 143.31 6,022.94 -5,557.92 3,881.72 6,759.82 0.00 0.00 0.00 9,900.00 63.37 143.31 6,067.76 -5 629.61 3,935.13 6,848.71 0.00 0.00 0.00 11/162018 9:38:57AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMPI Con000ftllips(Alaska) Inc. Western North Slope CD5 Alpine West Pad Prelim: CDS-24 (9C) CD5-24 (9C) CD5-24 wp17 (9C) -WNS Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Prelim: CD5-24 (9C) - Slot 24 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) (_) (1) Wait) (usft) (usft) (usft) ('1100usft) (11100usft) (°/100usft) 10,000.00 63.37 143.31 6,112.58 -5,701.29 3,988.54 6,937.60 0.00 0.00 0.00 10,100.00 63.37 143.31 6,157.40 -5,772.97 4,041.96 7,026.48 0.00 0.00 0.00 10,200.00 63.37 143.31 6,202.22 -5,844.65 4,095.37 7,115.37 0.00 0.00 0.00 10,300.00 63.37 143.31 6,247.04 -5,916.34 4,148.78 7,204.26 0.00 0.00 0.00 10,400.00 63.37 143.31 6,291.86 -5,988.02 4,202.19 7,293.15 0.00 0.00 0.00 10,500.00 63.37 143.31 6,336.68 -6,059.70 4,255.60 7,382.03 0.00 0.00 0.00 10,600.00 63.37 143.31 6,381.50 -6,131.39 4,309.01 7,470.92 0.00 0.00 0.00 10,700.00 63.37 143.31 6,426.32 -6,203.07 4,362.42 7,559.81 0.00 0.00 0.00 10,800.00 63.37 143.31 6,471.14 -6,274.75 4,415.83 7,648.69 0.00 0.00 0.00 10,900.00 63.37 143.31 6,515.96 -6,346.43 4,469.24 7,737.58 0.00 0.00 0.00 11,000.00 63.37 143.31 6,560.78 -6,418.12 4,522.65 7,826.47 0.00 0.00 0.00 11,100.00 63.37 143.31 6,605.60 -6,489.80 4,576.06 7,915.36 0.00 0.00 0.00 11,200.00 63.37 143.31 6,650.42 -6,561.48 4,629.47 8,004.24 0.00 0.00 0.00 11,300.00 63.37 143.31 6,695.25 -6,633.16 4,682.89 8,093.13 0.00 0.00 0.00 11,400.00 63.37 143.31 6,740.07 -6,704.85 4,736.30 8,182.02 0.00 0.00 0.00 11,500.00 63.37 143.31 6,784.89 -6,776.53 4,789.71 8,270.91 0.00 0.00 0.00 11,600.00 63.37 143.31 6,829.71 -6,848.21 4,843.12 8,359.79 0.00 0.00 0.00 11,700.00 63.37 143.31 6,874.53 -5,919.89 4,896.53 8,448.68 0.00 0.00 0.00 11,800.00 63.37 143.31 6,919.35 -6,991.58 4,949.94 8,537.57 0.00 0.00 0.00 11,900.00 63.37 143.31 6,964.17 -7,063.26 5,003.35 8,626.45 0.00 0.00 0.00 12,000.00 63.37 143.31 7,008.99 -7,134.94 5,056.76 8,715.34 0.00 0.00 0.00 12,100.00 63.37 143.31 7,053.81 -7,206.62 5,110.17 8,804.23 0.00 0.00 0.00 12,200.00 63.37 143.31 7,098.63 -7,278.31 5,163.58 8,893.12 0.00 0.00 0.00 12,300.00 63.37 143.31 7,143.45 -7,349.99 5,216.99 8,982.00 0.00 0.00 0.00 12,400.00 63.37 143.31 7,188.27 -7,421.67 5,270.40 9,070.89 0.00 0.00 0.00 12,500.00 63.37 143.31 7,233.09 -7,493.36 5,323.82 9,159.78 0.00 0.00 0.00 12,600.00 63.37 143.31 7,277.91 -7,565.04 5,377.23 9,248.67 0.00 0.00 0.00 12,700.00 63.37 143.31 7,322.73 -7,636.72 5,430.64 9,337.55 0.00 0.00 0.00 12,800.00 63.37 143.31 7,367.55 -7,708.40 5,484.05 9,426.44 0.00 0.00 0.00 12,815.80 63.37 143.31 7,374.63 -7,719.73 5,492.49 9,440.48 0.00 0.00 0.00 12,900.00 65.88 142.95 7,410.72 -7,780.58 5,538.13 9,516.10 3.00 2.97 -0.43 13,000.00 68.85 142.53 7,449.20 -7,854.03 5,594.01 9,607.76 3.00 2.98 -0.41 13,100.00 71.83 142.13 7,482.84 -7,928.56 5,651.55 9,701.20 3.00 2.98 -0.40 13,200.00 74.81 141.75 7,511.55 -8,003.97 5,710.60 9,796.17 3.00 2.98 -0.39 13,273.71 77.00 141.47 7,529.50 3,060.00 5,755.00 9,866.99 3.00 2.98 -0.38 13,300.00 77.00 141.47 7,535.41 -8,080.04 5,770.96 9,892.36 0.00 0.00 0.00 13,400.00 77.00 141.47 7,557.91 -8,156.26 5,831.65 9,988.86 0.00 0.00 0.00 13,473.71 77.00 141.47 7,574.49 -8,212.45 5,876.39 10,060.00 0.00 0.00 0.00 13,500.00 77.43 141.47 7,580.31 -8,232.50 5,892.36 10,085.39 1.65 1.65 0.00 13,600.00 79.08 141.47 7,600.66 3,309.09 5,953.35 10,182.35 1.65 1.65 0.00 13,700.00 80.73 141.47 7,618.18 -8,386.11 6,014.67 10,279.86 1.65 1.65 0.00 13,800.00 82.38 141.47 7,632.86 -8,463.48 6,076.29 10,377.83 1.65 1.65 0.00 13,898.16 84.00 141.47 7,644.50 3,539.72 6,137.00 10,474.35 1.65 1.65 0.00 13,900.00 84.00 141.47 7,644.69 -8,541.16 6,138.14 10,476.17 0.00 0.00 0.00 13,918.16 84.00 141.47 7,646.59 -8,555.28 6,149.39 10,494.05 0.00 0.00 0.00 14,000.00 84.84 142.89 7,654.55 -8,619.63 6,199.34 10,574.86 2.00 1.02 1.73 14,100.00 85.87 144.61 7,662.66 -8,700.00 6,258.28 10,674.04 2.00 1.03 1.72 14,200.00 86.90 146.33 7,668.97 -8,782.21 6,314.84 10,773.60 2.00 1.03 1.72 14,209.99 87.00 146.50 7,669.50 -8,790.53 6,320.37 10,783.56 2.00 1.03 1.72 14,300.00 87.76 148.13 7,673.61 -8,866.20 6,368.92 10,873.41 2.00 0.85 1.81 14,400.00 88.61 149.95 7,676.78 3,951.90 6,420.33 10,973.35 2.00 0.85 1.81 14,500.00 89.46 151.76 7,678.47 -9,039.22 6,469.03 11,073.30 2.00 0.85 1.81 14,515.44 89.59 152.04 7,678.59 -9,052.84 6,476.30 11,088.73 2.00 0.85 1.81 11/16/2018 9:38:57AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMP7 ConocoPhillips(Alaska) Inc. Western North Slope CD5 Alpine West Pad Prelim: CD5-24 (9C) C135-24 (9C) CD5-24 wpl7 (9C) -WNS Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Prelim: CD5-24 (9C) - Slot 24 Plan: D25 @ 74.50usft (D25) Plan: D25 @ 74.50usit (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) ('/100usft) (°/100usft) (°1100usft) 14,700.00 89.59 152.04 7,679.91 -9,215.85 6,562.65 11,273.09 0.00 0.00 0.00 14,800.00 89.59 152.04 7,680.63 -9,304.17 6,609.74 11,372.98 0.00 0.00 0.00 14,900.00 89.59 152.04 7,681.34 -9,392.49 6,656.63 11,472.87 0.00 0.00 0.00 15,000.00 89.59 152.04 7,682.06 -9,480.81 6,703.52 11,572.77 0.00 0.00 0.00 15,100.00 89.59 152.04 7,682.77 -9,569.13 6,750.41 11,672.66 0.00 0.00 0.00 15,200.00 89.59 152.04 7,683.49 -9,657.45 6,797.30 11,772.55 0.00 0.00 0.00 15,300.00 89.59 152.04 7,684.20 -9,745.78 6,844.20 11,872.44 0.00 0.00 0.00 15,400.00 89.59 152.04 7,684.92 -9,834.10 6,891.09 11,972.34 0.00 0.00 0.00 15,500.00 89.59 152.04 7,685.63 -9,922.42 6,937.98 12,072.23 0.00 0.00 0.00 15,600.00 69.59 152.04 7,686.34 -10,010.74 6,984.87 12,172.12 0.00 0.00 0.00 15,700.00 89.59 152.04 7,687.06 -10,099.06 7,031.76 12,272.01 0.00 0.00 0.00 15,800.00 89.59 152.04 7,687.77 -10,187.38 7,078.65 12,371.91 0.00 0.00 0.00 15,900.00 89.59 152.04 7,688.49 -10,275.70 7,125.54 12,471.80 0.00 0.00 0.00 16,000.00 89.59 152.04 7,689.20 -10,364.03 7,172.44 12,571.69 0.00 0.00 0.00 16,100.00 89.59 152.04 7,689.92 -10,452.35 7,219.33 12,671.58 0.00 0.00 0.00 16,200.00 89.59 152.04 7,690.63 -10,540.67 7,266.22 12,771.47 0.00 0.00 0.00 16,300.00 89.59 152.04 7,691.35 -10,628.99 7,313.11 12,871.37 0.00 0.00 0.00 16,400.00 89.59 152.04 7,692.06 -10,717.31 7,360.00 12,971.26 0.00 0.00 0.00 16,500.00 89.59 152.04 7,692.78 -10,805.63 7,406.89 13,071.15 0.00 0.00 0.00 16,600.00 89.59 152.04 7,693.49 -10,893.95 7,453.78 13,171.04 0.00 0.00 0.00 16,700.00 89.59 152.04 7,694.21 -10,982.28 7,500.68 13,270.94 0.00 0.00 0.00 16,800.00 89.59 152.04 7,694.92 -11,070.60 7,547.57 13,370.83 0.00 0.00 0.00 16,900.00 89.59 152.04 7,695.64 -11,158.92 7,594.46 13,470.72 0.00 0.00 0.00 17,000.00 89.59 152.04 7,696.35 -11,247.24 7,641.35 13,570.61 0.00 0.00 0.00 17,100.00 89.59 152.04 7,697.07 -11,335.56 7,688.24 13,670.51 0.00 0.00 0.00 17,200.00 89.59 152.04 7,697.78 -11,423.88 7,735.13 13,770.40 0.00 0.00 0.00 17,300.00 89.59 152.04 7,698.50 -11,512.21 7,782.02 13,870.29 0.00 0.00 0.00 17,400.00 89.59 152.04 7,699.21 -11,600.53 7,828.92 13,970.18 0.00 0.00 0.00 17,500.00 89.59 152.04 7,699.92 -11,688.85 7,875.81 14,070.08 0.00 0.00 0.00 17,600.00 89.59 152.04 7,700.64 -11,777.17 7,922.70 14,169.97 0.00 0.00 0.00 17,700.00 89.59 152.04 7,701.35 -11,865.49 7,969.59 14,269.86 0.00 0.00 0.00 17,800.00 89.59 152.04 7,702.07 -11,953.81 8,016.48 14,369.75 0.00 0.00 0.00 17,900.00 89.59 152.04 7,702.78 -12,042.13 8,063.37 14,469.64 0.00 0.00 0.00 18,000.00 89.59 152.04 7,703.50 -12,130.46 8,110.26 14,569.54 0.00 0.00 0.00 18,100.00 89.59 152.04 7,704.21 -12,218.78 8,157.16 14,669.43 0.00 0.00 0.00 18,200.00 89.59 152.04 7,704.93 -12,307.10 8,204.05 14,769.32 0.00 0.00 0.00 18,300.00 89.59 152.04 7,705.64 -12,395.42 8,250.94 14,869.21 0.00 0.00 0.00 18,400.00 89.59 152.04 7,706.36 -12,483.74 8,297.83 14,969.11 0.00 0.00 0.00 18,500.00 89.59 152.04 7,707.07 -12,572.06 8,344.72 15,069.00 0.00 0.00 0.00 18,600.00 89.59 152.04 7,707.79 -12,660.38 8,391.61 15,168.89 0.00 0.00 0.00 18,700.00 89.59 152.04 7,708.50 -12,748.71 8,438.50 15,268.78 0.00 0.00 0.00 18,800.00 89.59 152.04 7,709.22 -12,837.03 8,485.40 15,368.68 0.00 0.00 0.00 18,900.00 89.59 152.04 7,709.93 -12,925.35 8,532.29 15,468.57 0.00 0.00 0.00 19,000.00 89.59 152.04 7,710.65 -13,013.67 8,579.18 15,568.46 0.00 0.00 0.00 19,100.00 89.59 152.04 7,711.36 -13,101.99 8,626.07 15,668.35 0.00 0.00 0.00 19,200.00 89.59 152.04 7,712.07 -13,190.31 8,672.96 15,768.25 0.00 0.00 0.00 19,300.00 89.59 152.04 7,712.79 -13,278.63 8,719.85 15,868.14 0.00 0.00 0.00 19,400.00 89.59 152.04 7,713.50 -13,366.96 8,766.74 15,968.03 0.00 0.00 0.00 19,500.00 89.59 152.04 7,714.22 -13,455.28 8,813.64 16,067.92 0.00 0.00 0.00 19,600.00 89.59 152.04 7,714.93 -13,543.60 8,860.53 16,167.81 0.00 0.00 0.00 19,700.00 89.59 152.04 7,715.65 -13,631.92 8,907.42 16,267.71 0.00 0.00 0.00 19,800.00 89.59 152.04 7,716.36 -13,720.24 8,954.31 16,367.60 0.00 0.00 0.00 19,900.00 89.59 152.04 7,717.08 -13,808.56 9,001.20 16,467.49 0.00 0.00 0.00 111162018 9:38:57AM Page 7 COMPASS 5000.14 Build 85D `-' ConocoPhillips ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMPI ConocoPhillips(Alaska) Inc. Western North Slope CDS Alpine West Pad Prelim: CD5-24 (9C) CD5-24 (9C) CD5-24 wp17 (9C) -WNS Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Prelim: CD5-24 (9C) - Slot 24 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) (>) (1) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) ("/100usft) 20.100.00 89.59 152.04 7,718.51 -13,985.21 9,094.98 16,667.28 0.00 0.00 0.00 20,200.00 89.59 152.04 7,719.22 -14,073.53 9,141.88 16,767.17 0.00 0.00 0.00 20,300.00 89.59 152.04 7,719.94 -14,161.85 9,188.77 16,867.06 0.00 0.00 0.00 20,400.00 89.59 152.04 7,720.65 -14,250.17 9,235.66 16,966.95 0.00 0.00 0.00 20,500.00 89.59 152.04 7,721.37 -14,338.49 9,282.55 17,066.85 0.00 0.00 0.00 20,600.00 89.59 152.04 7,722.08 -14,426.81 9,329.44 17,166.74 0.00 0.00 0.00 20,700.00 89.59 152.04 7,722.80 -14,515.14 9,376.33 17,266.63 0.00 0.00 0.00 20,600.00 89.59 152.04 7,723.51 -14,603.46 9,423.22 17,366.52 Coo 0.00 0.00 20,900.00 89.59 152.04 7,724.23 -14,691.78 9,470.12 17,466.42 0.00 0.00 0.00 21,000.00 89.59 152.04 7,724.94 -14,780.10 9,517.01 17,566.31 0.00 0.00 0.00 21,100.00 89.59 152.04 7,725.65 -14,866.42 9,563.90 17,666.20 0.00 0.00 0.00 21,200.00 89.59 152.04 7,726.37 -14,956.74 9,610.79 17,766.09 0.00 0.00 0.00 21,300.00 89.59 152.04 7,727.08 -15,045.06 9,657.68 17,865.98 0.00 0.00 0.00 21,400.00 89.59 152.04 7,727.80 -15,133.39 9,704.57 17,965.88 0.00 0.00 0.00 21,500.00 89.59 152.04 7,728.51 -15,221.71 9,751.46 18,065.77 0.00 0.00 0.00 21,600.00 89.59 152.04 7,729.23 -15,310.03 9,798.36 18,165.66 0.00 0.00 0.00 21,700.00 89.59 152.04 7,729.94 -15,398.35 9,845.25 18,265.55 0.00 0.00 0.00 21,800.00 89.59 152.04 7,730.66 -15,486.67 9,892.14 18,365.45 0.00 0.00 0.00 21,900.00 89.59 152.04 7,731.37 -15,574.99 9,939.03 18,465.34 0.00 0.00 0.00 22,000.00 89.59 152.04 7,732.09 -15,663.31 9,985.92 18,565.23 0.00 0.00 0.00 22,100.00 89.59 152.04 7,732.80 -15,751.64 10,032.81 18,665.12 0.00 0.00 0.00 22,200.00 89.59 152.04 7,733.52 -15,839.96 10,079.70 18,765.02 0.00 0.00 0.00 22,300.00 89.59 152.04 7,734.23 -15,928.28 10,126.60 18,864.91 0.00 Coo 0.00 22,400.00 89.59 152.04 7,734.95 -16,016.60 10,173.49 18,964.80 0.00 0.00 0.00 22,500.00 89.59 152.04 7,735.66 -16,104.92 10,220.38 19,064.69 0.00 0.00 0.00 22,600.00 89.59 152.04 7,736.38 -16,193.24 10,267.27 19,164.59 0.00 0.00 0.00 22,700.00 89.59 152.04 7,737.09 -16,281.57 10,314.16 19,264.48 0.00 0.00 0.00 22,800.00 89.59 152.04 7,737.80 -16,369.89 10,361.05 19,364.37 0.00 0.00 0.00 22,900.00 89.59 152.04 7,738.52 -16,458.21 10,407.94 19,464.26 0.00 0.00 0.00 23,000.00 89.59 152.04 7,739.23 -16,546.53 10,454.84 19,564.15 0.00 0.00 0.00 23,100.00 89.59 152.04 7,739.95 -16,634.85 10,501.73 19,664.05 0.00 0.00 0.00 23,200.00 89.59 152.04 7,740.66 -16,723.17 10,548.62 19,763.94 0.00 0.00 0.00 23,300.00 89.59 152.04 7,741.38 -16,811.49 10,595.51 19,863.83 0.00 0.00 0.00 23,400.00 89.59 152.04 7,742.09 -16,899.82 10,642.40 19,963.72 0.00 0.00 0.00 23,500.00 89.59 152.04 7,742.81 -16,988.14 10,689.29 20,063.62 0.00 0.00 0.00 23,600.00 89.59 152.04 7,743.52 -17,076.46 10,736.18 20,163.51 0.00 0.00 0.00 23,700.00 89.59 152.04 7,744.24 -17,164.78 10,783.08 20,263.40 0.00 0.00 0.00 23,800.00 89.59 152.04 7,744.95 -17,253.10 10,829.97 20,363.29 0.00 0.00 0.00 23,900.00 89.59 152.04 7,745.67 -17,341.42 10,876.86 20,463.19 0.00 0.00 0.00 24,000.00 89.59 152.04 7,746.38 -17,429.74 10,923.75 20,563.08 0.00 0.00 0.00 24,100.00 89.59 152.04 7,747.10 -17,518.07 10,970.64 20,662.97 0.00 0.00 0.00 24,200.00 89.59 152.04 7,747.81 -17,606.39 11,017.53 20,762.86 0.00 0.00 0.00 24,300.00 89.59 152.04 7,748.53 -17,694.71 11,064.42 20,862.76 0.00 0.00 0.00 24,400.00 89.59 152.04 7,749.24 -17,783.03 11,111.32 20,962.65 0.00 0.00 0.00 24,500.00 89.59 152.04 7,749.95 -17,871.35 11,158.21 21,062.54 0.00 0.00 0.00 24,600.00 89.59 152.04 7,750.67 -17,959.67 11,205.10 21,162.43 0.00 0.00 0.00 24,700.00 89.59 152.04 7,751.38 -18,047.99 11,251.99 21,262.32 0.00 0.00 0.00 24,800.00 89.59 152.04 7,752.10 -18,136.32 11,298.88 21,362.22 0.00 0.00 0.00 24,900.00 89.59 152.04 7,752.81 -18,224.64 11,345.77 21,462.11 0.00 0.00 0.00 25,000.00 89.59 152.04 7,753.53 -18,312.96 11,392.66 21,562.00 0.00 0.00 0.00 25,100.00 89.59 152.04 7,754.24 -18,401.28 11,439.56 21,661.89 0.00 0.00 0.00 25,200.00 89.59 152.04 7,754.96 -18,489.60 11,486.45 21,761.79 0.00 0.00 0.00 25,300.00 89.59 152.04 7,755.67 -18,577.92 11,533.34 21,861.68 0.00 0.00 0.00 25,400.00 89.59 152.04 7,756.39 -18,666.25 11,580.23 21,961.57 0.00 0.00 0.00 11/18/2018 9:38:57AM Page 8 COMPASS 5000.14 Build 850 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Prelim: CD5-24 (9C) - Slot 24 Company: ConocoPhillips(Alaska) Inc. -WNS TVD Reference: Plan: D25 @ 74.50usft (D25) Project: Western North Slope MD Reference: Plan: D25 (off 74.50usft (D25) Site: CD5 Alpine West Pad North Reference: True Well: Prelim: CD5-24 (9C) Survey Calculation Method: Minimum Curvature Wellbore: CD5-24 (9C) Azimuth Depth Design: CD5-24 wp17 (9C) Section Rate Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (^) O lush) (usft) (usft) Wait) ("1100usft) (°1100usft) (°/100usft) 25,500.00 89.59 152.04 7,757.10 -18,754.57 11,627.12 22,061.46 0.00 0.00 0.00 25,600.00 89.59 152.04 7,757.82 -18,842.89 11,674.01 22,161.36 0.00 0.00 0.00 25,700.00 89.59 152.04 7,758.53 -18,931.21 11,720.90 22,261.25 0.00 0.00 0.00 25,800.00 89.59 152.04 7,759.25 -19,019.53 11,767.80 22,361.14 0.00 0.00 0.00 25,900.00 89.59 152.04 7,759.96 -19,107.85 11,814.69 22,461.03 0.00 0.00 0.00 26,000.00 89.59 152.04 7,760.68 -19,196.17 11,861.58 22,560.93 0.00 0.00 0.00 26,100.00 89.59 152.04 7,761.39 -19,284.50 11,908.47 22,660.82 0.00 0.00 0.00 26,200.00 89.59 152.04 7,762.11 -19,372.82 11,955.36 22,760.71 0.00 0.00 0.00 26,300.00 89.59 152.04 7,762.82 -19,461.14 12,002.25 22,860.60 0.00 0.00 0.00 26,400.00 89.59 152.04 7,763.53 -19,549.46 12,049.14 22,960.49 0.00 0.00 0.00 26,500.00 89.59 152.04 7,764.25 -19,637.78 12,096.04 23,060.39 0.00 0.00 0.00 26,600.00 89.59 152.04 7,764.96 -19,726.10 12,142.93 23,160.28 0.00 0.00 0.00 26,700.00 89.59 152.04 7,765.68 -19,814.42 12,189.82 23,260.17 0.00 0.00 0.00 26,800.00 69.59 152.04 7,766.39 -19,902.75 12,236.71 23,360.06 0.00 0.00 0.00 26,900.00 89.59 152.04 7,767.11 -19,991.07 12,283.60 23,459.96 0.00 0.00 0.00 27,000.00 89.59 152.04 7,767.82 -20,079.39 12,330.49 23,559.85 0.00 0.00 0.00 27,100.00 89.59 152.04 7,768.54 -20,167.71 12,377.38 23,659.74 0.00 0.00 0.00 27,200.00 89.59 152.04 7,769.25 -20,256.03 12,424.28 23,759.63 0.00 0.00 0.00 27,300.00 89.59 152.04 7,769.97 -20,344.35 12,471.17 23,859.53 0.00 0.00 0.00 27,400.00 89.59 152.04 7,770.68 -20,432.67 12,518.06 23,959.42 0.00 0.00 0.00 27,500.00 89.59 152.04 7,771.40 -20,521.00 12,564.95 24,059.31 0.00 0.00 0.00 27,600.00 89.59 152.04 7,772.11 -20,609.32 12,611.84 24,159.20 0.00 0.00 0.00 27,700.00 89.59 152.04 7,772.83 -20,697.64 12,658.73 24,259.10 0.00 0.00 0.00 27,800.00 89.59 152.04 7,773.54 -20,785.96 12,705.62 24,358.99 0.00 0.00 0.00 27,900.00 89.59 152.04 7,774.26 -20,874.28 12,752.52 24,458.88 0.00 0.00 0.00 28,000.00 89.59 152.04 7,774.97 -20,962.60 12,799.41 24,558.77 0.00 0.00 0.00 28,100.00 89.59 152.04 7,775.68 -21,050.93 12,846.30 24,658.66 0.00 0.00 0.00 28,200.00 89.59 152.04 7,776.40 -21,139.25 12,893.19 24,758.56 0.00 0.00 0.00 28,300.00 89.59 152.04 7,777.11 -21,227.57 12,940.08 24,858.45 0.00 0.00 0.00 28,400.00 89.59 152.04 7,777.83 -21,315.89 12,986.97 24,958.34 0.00 0.00 0.00 28,500.00 89.59 152.04 7,778.54 -21,404.21 13,033.86 25,058.23 0.00 0.00 0.00 28,600.00 89.59 152.04 7,779.26 -21,492.53 13,080.76 25,158.13 0.00 0.00 0.00 28,700.00 89.59 152.04 7,779.97 -21,580.85 13,127.65 25,258.02 0.00 0.00 0.00 28,800.00 89.59 152.04 7,780.69 -21,669.18 13,174.54 25,357.91 0.00 0.00 0.00 28,900.00 89.59 152.04 7,781.40 -21,757.50 13,221.43 25,457.80 0.00 0.00 0.00 29,000.00 89.59 152.04 7,782.12 -21,845.82 13,268.32 25,557.70 0.00 0.00 0.00 29,100.00 89.59 152.04 7,782.83 -21,934.14 13,315.21 25,657.59 0.00 0.00 0.00 29,200.00 89.59 152.04 7,783.55 -22,022.46 13,362.10 25,757.48 0.00 0.00 0.00 29,300.00 89.59 152.04 7,784.26 -22,110.78 13,409.00 25,857.37 0.00 0.00 0.00 29,400.00 89.59 152.04 7,784.98 -22,199.10 13,455.89 25,957.27 0.00 0.00 0.00 29,500.00 89.59 152.04 7,785.69 -22,287.43 13,502.78 26,057.16 0.00 0.00 0.00 29,600.00 89.59 152.04 7,786.41 -22,375.75 13,549.67 26,157.05 0.00 0.00 0.00 29,700.00 89.59 152.04 7,787.12 -22,464.07 13,596.56 26,256.94 0.00 0.00 0.00 29,800.00 89.59 152.04 7,787.84 -22,552.39 13,643.45 26,356.83 0.00 0.00 0.00 29,900.00 89.59 152.04 7,788.55 -22,640.71 13,690.34 26,456.73 0.00 0.00 0.00 30,000.00 89.59 152.04 7,789.26 -22,729.03 13,737.24 26,556.62 0.00 0.00 0.00 30,100.00 89.59 152.04 7,789.98 -22,817.35 13,784.13 26,656.51 0.00 0.00 0.00 30,200.00 89.59 152.04 7,790.69 -22,905.68 13,831.02 26,756.40 0.00 0.00 0.00 30,300.00 89.59 152.04 7,791.41 -22,994.00 13,877.91 26,856.30 0.00 0.00 0.00 30,400.00 89.59 152.04 7,792.12 -23,082.32 13,924.80 26,956.19 0.00 0.00 0.00 30,500.00 89.59 152.04 7,792.84 -23,170.64 13,971.69 27,056.08 0.00 0.00 0.00 30,600.00 89.59 152.04 7,793.55 -23,258.96 14,018.58 27,155.97 0.00 0.00 0.00 30,700.00 89.59 152.04 7,794.27 -23,347.28 14,065.48 27,255.87 0.00 0.00 0.00 30,800.00 89.59 152.04 7,794.98 -23,435.61 14,112.37 27,355.76 0.00 0.00 0.00 111162018 9:38:57AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPi Local Co-ordinate Reference: Company: ConocoPhillips(Alaska) Inc. -WNS TVD Reference: Project: Western North Slope MD Reference: Site: CDs Alpine West Pad North Reference: Well: Prelim: CD5-24 (9C) Survey Calculation Method: Wellbore: CD5-24 (9C) Dogleg Design: CD5-24 wp17 (9C) Depth ConocoPhillips Standard Proposal Report Well Prelim: CD5-24 (9C) - Slot 24 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) (°1100usft) (°1100usft) (°1100usft) 30,900.00 89.59 152.04 7,795.70 -23,523.93 14,159.26 27,455.65 0.00 0.00 0.00 31,000.00 89.59 152.04 7,796.41 -23,612.25 14,206.15 27,555.54 0.00 0.00 0.00 31,100.00 89.59 152.04 7,797.13 -23,700.57 14,253.04 27,655.43 0.00 0.00 0.00 31,200.00 89.59 152.04 7,797.84 -23,788.89 14,299.93 27,755.33 0.00 0.00 0.00 31,300.00 89.59 152.04 7,798.56 -23,877.21 14,346.82 27,855.22 0.00 0.00 0.00 31,400.00 89.59 152.04 7,799.27 -23,965.53 14,393.72 27,955.11 0.00 0.00 0.00 31,500.00 89.59 152.04 7,799.99 -24,053.86 14,440.61 28,055.00 0.00 0.00 0.00 31,600.00 89.59 152.04 7,800.70 -24,142.18 14,487.50 28,154.90 0.00 0.00 0.00 31,700.00 89.59 152.04 7,801.41 -24,230.50 14,534.39 28,254.79 0.00 0.00 0.00 31,800.00 89.59 152.04 7,802.13 -24,318.82 14,581.28 28,354.68 0.00 0.00 0.00 31,900.00 89.59 152.04 7,802.84 -24,407.14 14,628.17 28,454.57 0.00 0.00 0.00 32,000.00 89.59 152.04 7,803.56 -24,495.46 14,675.06 28,554.47 0.00 0.00 0.00 32,100.00 89.59 152.04 7,804.27 -24,583.78 14,721.96 28,654.36 0.00 0.00 0.00 32,200.00 89.59 152.04 7,804.99 -24,672.11 14,768.85 28,754.25 0.00 0.00 0.00 32,300.00 89.59 152.04 7,805.70 -24,760.43 14,815.74 28,854.14 0.00 0.00 0.00 32,400.00 89.59 152.04 7,806.42 -24,848.75 14,862.63 28,954.04 0.00 0.00 0.00 32,500.00 89.59 152.04 7,807.13 -24,937.07 14,909.52 29,053.93 0.00 0.00 0.00 32,600.00 89.59 152.04 7,807.85 -25,025.39 14,956.41 29,153.82 0.00 0.00 0.00 32,700.00 89.59 152.04 7,808.56 -25,113.71 15,003.30 29,253.71 0.00 0.00 0.00 32,800.00 89.59 152.04 7,809.28 -25,202.03 15,050.20 29,353.60 0.00 0.00 0.00 32,900.00 89.59 152.04 7,809.99 -25,290.36 15,097.09 29,453.50 0.00 0.00 0.00 33,000.00 89.59 152.04 7,810.71 -25,378.68 15,143.98 29,553.39 0.00 0.00 0.00 33,100.00 89.59 152.04 7,811.42 -25,467.00 15,190.87 29,653.28 0.00 0.00 0.00 33,200.00 89.59 152.04 7,812.14 -25,555.32 15,237.76 29,753.17 0.00 0.00 0.00 33,300.00 89.59 152.04 7,812.85 -25,643.64 15,284.65 29,853.07 0.00 0.00 0.00 33,400.00 89.59 152.04 7,813.57 -25,731.96 15,331.54 29,952.96 0.00 0.00 0.00 33,500.00 89.59 152.04 7,814.28 -25,820.29 15,378.44 30,052.85 0.00 0.00 0.00 33,600.00 89.59 152.04 7,814.99 -25,908.61 15,425.33 30,152.74 0.00 0.00 0.00 33,700.00 89.59 152.04 7,815.71 -25,996.93 15,472.22 30,252.64 0.00 0.00 0.00 33,800.00 89.59 152.04 7,816.42 -26,085.25 15,519.11 30,352.53 0.00 0.00 0.00 33,900.00 89.59 152.04 7,817.14 -26,173.57 15,566.00 30,452.42 0.00 0.00 0.00 34,000.00 89.59 152.04 7,817.85 -26,261.89 15,612.89 30,552.31 0.00 0.00 0.00 34,100.00 89.59 152.04 7,818.57 -26,350.21 15,659.78 30,652.21 0.00 0.00 0.00 34,200.00 89.59 152.04 7,819.28 -26,438.54 15,706.68 30,752.10 0.00 0.00 0.00 34,300.00 89.59 152.04 7,820.00 -26,526.86 15,753.57 30,851.99 0.00 0.00 0.00 34,400.00 89.59 152.04 7,820.71 -26,615.18 15,800.46 30,951.88 0.00 0.00 0.00 34,500.00 89.59 152.04 7,821.43 -26,703.50 15,847.35 31,051.77 0.00 0.00 0.00 34,600.00 89.59 152.04 7,822.14 -26,791.82 15,894.24 31,151.67 0.00 0.00 0.00 34,700.00 89.59 152.04 7,822.86 -26,880.14 15,941.13 31,251.56 0.00 0.00 0.00 34,800.00 89.59 152.04 7,823.57 -26,968.46 15,988.02 31,351.45 0.00 0.00 0.00 34,900.00 89.59 152.04 7,824.29 -27,056.79 16,034.92 31,451.34 0.00 0.00 0.00 35,000.00 89.59 152.04 7,825.00 -27,145.11 16,081.81 31,551.24 0.00 0.00 0.00 35,100.00 89.59 152.04 7,825.72 -27,233.43 16,128.70 31,651.13 0.00 0.00 0.00 35,200.00 89.59 152.04 7,826.43 -27,321.75 16,175.59 31,751.02 0.00 0.00 0.00 35,300.00 89.59 152.04 7,827.14 -27,410.07 16,222.48 31,850.91 0.00 0.00 0.00 35,400.00 89.59 152.04 7,827.86 -27,498.39 16,269.37 31,950.81 0.00 0.00 0.00 35,500.00 89.59 152.04 7,828.57 -27,586.71 16,316.26 32,050.70 0.00 0.00 0.00 35,600.00 89.59 152.04 7,829.29 -27,675.04 16,363.16 32,150.59 0.00 0.00 0.00 35,629.55 89.59 152.04 7,829.50 -27,701.13 16,377.01 32,180.11 0.00 0.00 0.00 11/16/2018 9:38:57AM Page 10 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Prelim: CDS-24 (9C) - Slot 24 Company: ConomPhillips(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: Prelim: CD5-24 (9C) Survey Calculation Method: Minimum Curvature Welibore: CDS-24 (91C) Design: CD5-24 wpl7(9C) Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +Ef•W Northing Easting •Shape (1) C) (usft) (usft) (usft) (usft) (usft) Latitude CD5-24 2. Toe 082918 0.00 0.00 7,829.50 -27,701.13 16,377.01 - plan hits target center -Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 119.80 119.80 20x42 20.000 42.000 2,252.54 2,189.50 10-3/4x13-1/2 10.750 13.500 13,898.16 7,644.50 7-5/8 x 9-7/8 by 11 7625 l l 000 35,629.55 7,829.50 4-1/2x6-3/4 4.500 6,750 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology C) ( ) 1,329.65 1,324.50 Base Permafrost 2,392.72 2,310.50 C-30 3,121.40 2,846.50 C-10 4,816.93 3,789.50 K-3 5,365.79 4,035.50 K-2 6,269.39 4,440.50 Alban 97 9,245.71 5,774.50 Albian 96 12,065.84 7,038.50 HRZ 12,471.91 7,220.50 HRZ Base 12,728.49 7,335.50 Kuparuk C 12,737.41 7,339.50 LCU 13,318.17 7,539.50 Alpine C 13,353.73 7,547.50 UJU 13,870.50 7,641.50 Alpine B3 14,071.14 7,660.50 Alpine 131 14,209.99 7,669.50 AlpineA 18,022.50 7,703.66 Fault 1 0.00 Longitude 11/162018 9:38:57AM Page 11 COMPASS 5000.14 Build 850 ConocoPhillips Database: OAKEDMPI Local Co-ordinate Reference: Company: ConocoPhillips(Alaska) Inc. -WNS TVD Reference: Project: Western North Slope MD Reference: Site: CDS Alpine West Pad North Reference: Well: Prelim: CD5-24 (9C) Survey Calculation Method: Wellbore: CD5-24 (9C) (usft) Design: CD5-24 wp17(9C) 600.00 ConocoPhillips Standard Proposal Report Well Prelim: CD5-24 (9C) - Slot 24 Plan: D25 @ 74.50usft (D25) Plan: D25 @ 74.50usft (D25) True Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 600.00 600.00 0.00 0.00 KOP: Start 20.34°/100' DLS, 1.5' TF, for 400' 1,000.00 999.27 -20.01 6.12 Start 61.69°/100' DLS, 2' TF, for 278.61' 1,278.61 1,274.50 -60.69 18.56 Start 81.59°/100' DLS, 0' TF, for 102.07' 1,380.68 1,374.50 -80.27 24.54 Start 377.8°/100' DLS, 2' TF, for 871.85' 2,252.54 2,189.50 -359.73 133.89 Start 387.39°/100' DLS, 0' TF, for 20' 2,272.54 2,207.01 -368.62 137.69 Start 729.26"/100' DLS, 3' TF, for 572.4' 2,844.94 2,663.36 -667.07 304.63 Start 851.96°/100' DLS, 3' TF, for 166.67' 3,011.61 2,775.93 -769.69 372.15 Start 1387.57'/100' DLS, 0' TF, for 700' 3,711.61 3,225.88 -1,217.65 666.90 Start 1955.01'/100' DLS, 2' TF, for 682.88' 4,394.48 3,600.16 -1,683.11 994.59 Start 9440.48'/100' DLS, 0' TF, for 8421.31' 12,815.80 7,374.63 -7,719.73 5,492.49 Start 9866.99'/100' DLS, 3' TF, for 457.91' 13,273.71 7,529.50 -8,060.00 5,755.00 Start 10060'/100' DLS, 0' TF, for 200' 13,473.71 7,574.49 -8,212.45 5,876.39 Start 10474.35'/100' DLS, 1.65' TF, for 424.44' 13,898.16 7,644.50 -8,539.72 6,137.00 Start 10494.05'/100' DLS, 0' TF, for 20' 13,918.16 7,646.59 -8,555.28 6,149.39 Start 10783.56'/100' DLS, 2' TF, for 291.84' 14,209.99 7,669.50 -8,790.53 6,320.37 Start 11088.73'/100' DLS, 2' TF, for 305.45' 14,515.44 7,678.59 -9,052.84 6,476.30 Start 32180.11'/100' DLS, 0' TF, for 21114.11' 35,629.55 7,829.50 -27,701.13 16,377.01 TD: 35629.55' MD, 7829.5' TVD 11/182018 9:38:57AM Page 12 COMPASS 5000.14 Build 85D V C a Z E U � T N n - 1 V cai n N ❑ N U y u — � c U y m w � N Y U y � � Z � � •V O y� ❑ N Q Q N Z U c O ^` u E / \ i.f. 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MINIS Western North Slope CD5 Alpine West Pad Prelim: CD5-24 (9C) 50103xxxxx00 CD5-24 (9C) Plan: CD5-24 wp17 (9C) Error Ellipse Survey Report 16 November, 2018 Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: COS Alpine West Pad Well: Prelim: CD5-24 (9C) Wellbore: CD5-24 (9C) Design: CD5-24 wp17(9C) ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: Norm Reference: Survey Calculation Method: Output errors are at Database: Well Prelim: CD5-24 (9C)- Slot 24 Plan: D25 @ 74.50usft (D25) Plan: D25 @ 74.50usft (D25) True Minimum Curvature 1.00 sigma OAKEDMPI 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 Site CD5 Alpine West Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: -1.15 ° Well Prelim: CDS-24(9C)-Slot 24 Well Position +N/ -S 0.00 usft Northing: Latitude: Version: +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 33.70 usft Wellbore CD5-24 (9C) Magnetics Model Name Sample Date Declination Dip Angle Field Strength C) P) (nT) BGGM2018 7/1/2019 16.07 80.72 57,373 Design CD5-24 wp17 (9C) Audit Notes: To Version: Phase: PLAN Tie On Depth: 40.80 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction 1,800.00 (usft) (usft) (usft) 11 1,800.00 40.80 0.00 0.00 149.41 Survey Tool Program Date 9/12/2018 From To (usft) (usft) Survey (Wellbom) Tool Name Description 40.80 1,800.00 C135-24 wp17 (9C) (CD5-24 (9C)) GYD-GC-SS Gyrodata gyro single shots 1,800.00 2,250.00 CD5-24 wp17(9C)(CO5-24(9C)) MWD MWD -Standard 1,800.00 2,250.00 CD5-24 wp17(90)(CD5-24(9C)) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,250.00 3,750.00 CD5-24 wpt7(9C)(CD5-24(9C)) MWD MWD -Standard 2,250.00 13,895.00 CD5-24 wpl7 (9C) (CD5-24 (9C)) MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 13,895.00 15,395.00 CD5-24 wp17(9C)(CD5-24(9C)) MWD MWD -Standard 13,895.00 35,629.55 CD5-24 wp17(9C)(CD5-24(9C)) MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/16/2018 8.58.58AM Page 2 COMPASS 5000.14 Build 850 Company: ConocoPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: CDS Alpine West Pad Well: Prelim: CD5-24 (9C) Wellbore: CD5-24(9C) Design: CD5-24 wp17(9C) ConocoPhillips Error Ellipse Report Local Cc -ordinate Reference: ND Reference: MO Reference: North Reference: Survey Calculation Method: Output errors are at Database: Plan Survey Tool Program Date 9/12/2018 Depth From Depth To (usft) lush) Survey (wellbore) Tool Name Remarks 1 40.80 1,800.00 CD5-24 wpl7 (9C) (CD5-24 (9C GYD-GC-SS Gyrodata gyro single shots 2 1,800.00 2,250.00 C05-24 wp17 (9C) (CD5-24 (9C MWD MWD - Standard 3 1,800.00 2,250.00 C05-24 wp17 (9C) (CD5-24 (9C MWD-IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 2,250.00 3,750.00 CD5-24 wpl7 (9C) (CD5-24 (9C MWD MWD - Standard 5 2,250.00 13,895.00 CD5-24 wp17 (9C) (CD5-24 (9C MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC e 13,895.00 15,395.00 CD5-24 wp17 (9C) (CD5-24 (PC MWD MWD - Standard 7 13,895.00 35,629.55 CD5-24 wp17 (9C) (CD5-24 (9C MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Well Prelim: CD5-24 (9C) - Slot 24 Plan: D25 @ 74.50usft (1325) Plan: D25 @ 74.50usft (D25) True Minimum Curvature 1.00 sigma OAKEDMP1 Position uncertainty and blas at survey station Measured Indinatlen MmuM Vertical Highside Late21 Vertical Magnilula Sann..tor seml+ninor Depth Depth E., Is. En., Blas Error Bias er Bias Error Error kdanuM Tool (usft) r) r) (usm (usft) (-an) (usft) (..ft) lusft) usft) (usft) Juan) (usft) r) 40.80 0.00 0.00 4080 000 000 000 0.00 0.00 000 0.00 000 0.00 000 UNDEFINED 10000 0.00 0.00 100.00 0.04 000 0.04 000 1.15 0.00 000 0.04 0.04 000 GYD-Gc ss (1, 1) 200.00 0.00 000 200.00 0.19 000 0.19 0.00 1.15 000 0.00 0.19 0.19 000 GYD-GC-SS(1, 1) 300.00 0.00 000 300.00 0.33 000 0.33 000 1.15 001 0.01 0.33 0.33 00 GYD-GCSS(1, 1) 40000 0.00 0.00 400.00 0.48 000 OA8 0.00 1.15 001 0.01 048 048 000 GYD-GC SS (1, 1) 500.00 0.00 0.00 500.00 062 0.00 C.62 000 1.15 002 0.02 0.62 082 0.0 GYD.GC-SS(1, 1) 60000 0.00 000 600.00 077 0.00 OA 0.00 1.16 004 0.04 077 0.77 000 GYDGCSS(1, 1) 70000 1.50 16300 699.99 0.05 0.00 085 000 1.16 005 005 085 085 4500 GY0,GC-8s(1, 1) 80000 300 163.00 79991 0.68 0.00 088 0.00 1.16 007 007 0.88 088 73.43 GYDGGSS(1, 1) 90000 4.50 183.00 899.69 0.94 0.00 094 0.00 1.16 0.09 009 094 0.94 Mee GYD6CS3(1, 1) 1,00.0 6.00 163.0 99927 1.01 -0.01 1.02 0.00 1.17 011 0.11 1.02 1.02 45.00 GYDSo-W(1, 1) 1.10.0 8.00 183.0 1,09852 1.10 -0.01 1.11 0.00 1.17 0.14 014 1.11 1.11 161.35 GYDGC-SS N. 1) 1,200.0 10.00 163.0 L197.28 120 -0.02 1.23 0.00 1.17 0.17 017 123 1.22 162.19 GYD-GC-W(1. 1) 1.27861 1157 183.0 1,274.50 1.28 -0.02 134 0.00 1.17 0.19 019 1.34 1.31 16241 GYD-GC-SS(1, 1) 1,30.00 1157 163.0 1,29546 1.31 -0.02 137 0.00 1.17 020 0.20 137 1.34 16243 GYD-GC-SS(1, 1) 11300.60 11.57 163.00 1,37450 1.41 -0.02 149 000 1.17 0.23 023 1.49 143 162.60 GYD-GCSS(1, 1) 1,40.00 11.95 162.68 1,39341 1.43 -0.02 1.52 000 1.18 0.23 023 1S2 1.46 16267 GYD-GCSS(1. 1) 1,50.00 1393 16128 1,490.87 1.56 -0.03 1.60 000 1.18 027 027 1.60 1.59 162.66 GYD-GC-SS(1, 1) 1.600.00 1591 160.22 1,587.49 169 -004 1.86 0.00 1.19 031 031 168 1.73 16244 GYD-GC-SS(1. 1) 170.00 17.90 15940 1,683.17 1.03 -0.05 2.06 0.00 1.19 034 0.35 2.06 1.08 162.02 GYPGc-ss(1, 1) 1.80.00 19.88 15873 I.M.78 1.98 .0.07 2.27 000 121 039 0.39 2.27 2.0 16153 GYDGCSS(1, 1) 1,900.00 2167 158.18 1,87121 2.05 -000 240 0.03 1.20 043 c44 240 2.12 161.31 MWD (1, 2) 2.00.00 2387 157.72 1,963.34 205 -0.10 2.55 00 120 047 0.49 2.55 2.14 16045 MM (1, 2) 2,100.00 2EW 157.32 2.054.07 20 -0.11 285 0.15 1.20 052 0.55 2.85 2.18 159.52 MWD (1, 2) 11116/2018 8:58:58AM Page 3 COMPASS 5000.14 Build 850 Company: ConomPhillips(Alaska) Inc. -VMS Project: Western North Slope Site: CD5 Alpine West Pad Well: Prelim: CDS-24 (9C) Wellbore: CD5-24 (9C) Design: CDS-24 wp17 (9C) Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Prelim: CD5-24 (9C) - Slot 24 Plan: D25 @ 74.50usft (D25) Plan: D25 @ 74.50usft (D25) True Minimum Curvature 1.00 sigma OAKEDMP1 Measured Indlnafion a imuth Vertical Hilhside Literal Vertical Magnitude Semimajor seri Depth 0,11h Error Blas Error Bias Eno, Blas of Bias Ermr Emar Atmuni Tool Nan) r) f) lush) lose) rasa) (uan) (Uan) (use) lose) lose) (use) (ase) r) 2,200.00 21,85 Mae 2.14328 209 .0,13 329 0.22 1.21 0.56 062 3.29 2.23 15886 MWD (1, 2) 2252.54 28.90 158.82 2,18950 206 -0.14 2.66 0.03 1.10 0.59 061 266 220 161.15 MWD (2. 3) 2272.54 28.90 156.82 2,207.01 2.04 -0.14 2.69 0.05 1.18 080 062 2.70 2.21 16086 MM (2. 3) 2,300.00 29.65 158.12 2,23098 203 -0.15 2.76 007 1.10 061 064 276 221 160.44 MM (2. 3) 2,400.00 32.40 153.00 2,316.65 203 -0.19 3.13 018 1.19 088 0.71 3.13 2.24 158.61 MWD (2.3) 2.50000 35.19 151.82 2,399.75 2.05 -023 370 031 120 071 Ban 3.71 229 156.89 MM (2, 3) 2,600.OD 30.01 150.09 2,480.02 2.09 -D.27 4.44 0.46 1.23 0.75 OW 4.45 2.36 155.37 MM (2. 3) 2.70000 4085 148.57 2.557 25 217 4.32 &3l 0.64 1.28 0.80 1.06 5.33 2.44 154.04 MM (2, 3) 2,80000 43,71 147.22 2,631.23 2.28 -0.37 6.29 0.84 135 084 123 632 253 152.87 MM (2, 3) 2,844.94 45.00 146.66 2,663.36 2.33 -0.40 8.76 094 139 aw 131 6.79 2.58 15239 AM (2, 3) 2,900.00 4665 146Be 2,701.73 240 -042 7.35 1.06 1.45 089 142 739 264 151.85 MM (2T 3) 3.000.00 4065 146.66 2)88.44 2.54 -0.47 0.50 1.30 1.59 0.93 1.64 653 275 15107 MM (2, 3) 3,01161 50.00 14668 2,775.93 2.55 -0A7 8.64 1.33 1.60 0.93 197 666 277 150 99 MM (2, 3) 3,10000 50.00 14666 2,832.74 2.75 -0.47 970 1.56 1.78 097 1.88 972 288 150.47 MM (2, 3) 3,20000 50.00 14666 2,897.02 2.90 -0.47 1080 1.82 1.95 1.01 2.13 10.92 2.98 19702 MM (2, 3) 3.30000 50,00 14666 296130 322 -047 12.12 2.07 214 1.05 2.38 12.13 3.10 149.67 MAD (2, 3) 3.4000D 50.00 14688 302558 347 -007 13.34 2.33 2.35 1.09 264 t1w 3.23 149.38 MIND (2,3) 3,500.00 50.00 WAS 3,089.86 3.73 -047 14.57 259 2.55 1.14 2.09 14.59 3.36 149.15 MM (2. 3) 3,600.00 Woo 146.66 3.154.14 399 -0.47 1681 2.84 2,76 1.18 3.15 15.02 3.50 148.95 AM (2.3) 3,700.00 50.00 Wee 3,218.42 426 -0.47 17.05 3.10 2.97 1.23 3.42 17,06 3.64 148.00 MIND (2. 3) 3,711.61 50.00 14668 3,225.88 429 -0.47 17.19 3.13 2.99 124 3.45 17,20 365 14878 MM (2,3) 3.8000) 51 73 146.16 3,281.67 2.89 A.48 Z98 006 2.00 128 154 800 2.89 150.55 MWD+IFR-AK-CAZ-W(3.3) 3.900.00 53.68 145.62 3.342.26 2.99 -0.53 8.49 007 2.10 132 1.61 8.51 2.96 150.31 MWD+IFR-AK-CAZ-SC(3,3) 4,0)0.0) 5564 145.11 3,400.10 3.10 4.58 901 097 221 137 168 9.04 3.03 150.116 MWD+1FR-AI40P-W(3.3) 4.100.00 57,59 144.63 3.455.13 3.21 4.64 9.54 008 2.33 1.41 175 9.58 3.09 149.80 MWD+1FR-M-CA-SC (3,3) 4,20000 59.55 144.16 3,507.26 3.32 -0.69 10.08 009 245 1.45 181 10.12 3.16 149.54 MWD+IFR-M-CA-SU (3.3) 4.300.00 61.52 143]2 3.556.45 3.43 .0.75 10.83 0.10 2.58 1.48 188 10.67 322 14027 MWD+IFRAM-CAZ-SC(3,3) 4.394.48 63.37 143.31 3.600.16 3.54 -081 11.15 0.11 270 1.51 195 1120 3.28 149.02 MWDHFR-M-CA-SC (3,3) 4.400.00 63,37 14331 3.602.63 3.55 -OS1 11.18 0.11 2,71 1.52 195 11.23 3.28 14001 MWD+IFR M-CAZ-&C(3, 3) 4,500.00 6337 143.31 3,84745 3.70 -081 11.72 0.11 285 1.55 202 1177 334 140.76 MWD+IFR A3(-CM-SC(3,3) 4,800.00 63.37 14331 3,69237 385 -081 1228 0.11 2.99 1.50 2.09 1231 3.39 148.53 MWD+IFR A)(-CAZ-SC(3,3) 4,700.00 63.37 143.31 3,737.09 4.01 -0.81 12.00 Oil 3.13 1.62 2,16 12.85 3.45 140.32 MWD+IFR-AR-CAZ-SC(3,31 4,80000 63.37 143.31 3.78191 4.17 -081 13.35 0.11 3.28 1.65 223 1339 3.50 148.43 MWD+IFR-N(-CAZ-SC(3,3) 4,90000 63.37 143.31 3,826.73 4.33 -0.81 13.90 0.11 342 1.69 2.30 1394 3.56 147.96 MWD+IFR-AK-CM-SC(3,3) 5,00000 63.37 143.31 3,871.55 4.49 -0.81 1405 Oil 357 1.72 2.38 14.49 3.62 14180 MWD+(FR-N(-CAZ-SC(3,3) 5,100.00 63.37 143.31 3,916.37 465 -0.81 15.0) 0.11 372 176 245 15.04 388 147.66 MWDHFR-AK-CAZ-SC(3.3) 5,200.00 63.37 14331 3,951.19 481 .0.81 15.55 D.11 3.86 1.80 2.53 15.59 374 147.52 MWD+IFR-AR-CAZSC(3,3) 5,300.00 63.37 14331 4,Mal 4.97 -0.81 16.10 0.11 401 1.83 261 18.14 3.80 147.40 MWDHFR-AR-OAZSC(3.3) 5,400.00 63.37 143.31 4,05083 5.13 -0.81 1665 0.11 4.16 187 2.69 1669 3.86 147.28 MWO+IFR-AK-CAZ-SC(3,3) 5,500.00 63.37 143.31 4,095.66 5.29 -Dal 17,20 0.11 4.31 191 2.77 17,24 392 147.17 MWD+IFR-AI(-CAZSC(3.3) 51600.00 63.37 143.31 4.140.48 5.45 4.51 1776 0.11 4.45 1.95 2.86 1.00 3.99 147.07 MWD+IFR-AR-CAZ-SC(3,3) 5,700.0) 6337 143.31 4,185.30 5.62 -0.81 18.31 0.11 4.60 199 2.94 18.35 4.05 146.98 MWD+IFR-MK MSO(3,3) 5.800.0) 63.37 143.31 4.230.12 5,78 -0.81 18,87 0.11 4,75 2.03 3.03 18.90 4.11 146.89 MWD+IFR-MRC -SC (3.3) 5,90).0) 61.37 143.31 4,274.94 5.95 -0.81 19.43 0.11 490 2.07 3.11 19.46 4.18 14601 MWWIFR-AH-0 C(3, 3) 5100000 63.37 143.31 4.319.76 6.11 -081 19.98 0.11 5.05 2.11 320 MM 4.24 146.73 MWD+IFR-AH-CAZSC(3, 3) 6.10000 63.37 143.31 4.364.50 6.27 -081 20.54 0.11 5.20 2.15 329 20.57 4.30 14665 MV IFR-AWCA2SC(3, 3) 6,200.00 63.37 143.31 4,409.40 6.44 .081 21.10 0.11 5.35 2.19 338 21.13 4.37 14658 MWD+IFR-AK-,kZ-SC(3,3) 6,300.00 63.37 143.31 4,454.22 6.61 -0.81 21.65 0.11 5.50 224 348 21.69 4.44 146.52 MWD+IFR-AK-CAZSC(3. 3) 6,40000 63.37 14331 4.499,04 en -081 22.21 0.11 5.65 2.28 3.57 22.24 050 14645 MWD+IFR-AK-CAZ-SC(3, 3) 6,50000 63.37 143.31 4,543.86 6.94 -0.81 M.77 0.11 5.80 2.32 3.67 22.80 4.57 14640 MWDHFR-M-CA-SC (3.3) 6,600.00 63.37 143.31 4,58889 7.10 .0.81 23.33 0.11 5.95 2.37 376 23,313 4.64 146.34 MWD+IFR-AK-CM-SC(3,3) 6,70000 63.37 143.31 4,633.50 7.27 -0.81 23.89 0.11 6.10 241 3.88 2392 4.70 14629 MWD+IFR-MC -SC (3,3) 6,800.00 63.37 143.31 4,678.32 7.43 -0.81 24.45 0.11 625 2.46 3.98 24.48 477 14624 MWDHFR-AK-CAZ-8C(3.3) 61900.00 63.37 Mal 4.723.14 260 -081 25.01 0.11 640 2.51 4.06 25.04 4.84 148.19 MWD+1FR-AK-CAZ-SC(3,3) 111162018 8:58:58A114 Page 4 COMPASS 5000.14 Build 85D Company: ConomPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: CDS Alpine West Pad Well: Prelim: CD5-24 (9C) Wellbore: CD5-24 (9C) Design: CD5-24 wp17(9C) Position uncertainty and bias at survey station ConocoPhilllps Error Ellipse Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Prelim: CD5-24 (9C)- Slot 24 Plan: D25 aQ 74.50usR (1325) Plan: D25 Q 74.50usft (D25) True Minimum Curvature 1.00 sigma OAKEDMP1 MassOed Indi.sima Nxlmut5 WM.1 HI95sMe Lase. Wm.f 11,0.de Semi -nor snmlminor Depth D4ptK Error Blas Emor as. Emor Bias or Blas Emar Error AnmutA Teel (use) 1°1 P) (--ft) (.50) Isar) (usm (uam Wall (uam (uam (.sm (usa) r) 100009 6337 14331 4,767.% 7.77 -0.81 25.57 0.11 655 2.55 4.16 2560 4.91 146.14 MWD+IFR-AK-CAZ-=(3, 3) 7,10000 6337 14331 4,81278 194 -0.81 26.13 0.11 6.70 2.60 4.27 26.16 4.97 148.10 MW IFR-AK-CAZ-SC(3, 3) 7.200.00 6137 14331 4.857.60 8,10 -0.81 M69 0.11 6.65 265 4.37 26.72 5.04 146.05 MAV+IFR-M(-CAZ-SC(3. 3) 7,300.00 8337 143.31 4.902.42 8.27 -0.81 27,25 D.11 7.00 2.70 4.48 27.20 5.11 146.01 MWD+IFR-M-CAZ-SC(3,3) 7,400.00 63.37 143.31 4,947.24 844 -081 27.81 0.11 7.15 2]/ 4.58 27.84 5.18 145.0 MWD+IFR-ARCAZ-SC(3,3) 7,500.00 63.37 143.31 4,99207 8.60 -0.81 28.37 0.11 7.31 2.79 469 28,40 525 14594 MAD+IFR-AR-CAZ-SC(3, 3) 7,600.00 63.37 14331 5,03889 877 -0.61 2893 0.11 7.46 2.84 4.80 20.96 532 145.90 MM+IFR-M(-CAZ-SC(3, 3) 7,70000 63.37 143.31 5.081]1 0.94 -0.81 29.49 0.11 161 2.89 4.91 29.52 5.39 145.87 MWD+1FR-AK-CAZ-SC(3, 3) 7,800.00 63.37 143.31 5.128.53 9.11 -0.81 30.06 0.11 776 2.94 502 30.08 546 145.84 MWD+1FR-W-CAZ-SC(3,3) 7,900.00 63.37 143.31 5,171.35 927 41.81 3062 0.11 7.91 300 5.14 30.64 5.53 14580 MWD+1FR-M(-CAZ-SC(3.3) 8,000.00 8337 14331 5.218.17 9.44 -0.81 31.18 0.11 8.06 3.05 5.25 31.21 5.60 14577 MWD+1FR-AK-CAZ-SC(3,3) 0,10000 6337 14331 5,260.99 961 -081 31.74 0.11 8.21 3.10 5.37 3177 560 145.74 MWWIFR-M(-CAZ-BC(3.3) 8,200.00 OX 14331 5.305.81 978 -0.81 32.30 0.11 8.36 3.15 5.49 3233 5.75 145,72 MW IFR-AK-CAZ-SC(3, 3) 8,300.00 63,37 143.31 5,35063 9.95 -081 12.86 0.11 8.52 3.21 5.60 32.89 5.82 14569 MWD+IFR-M(-CAZSC(3, 3) 8,400.00 63.37 143.31 5,395.45 10.12 -081 33.43 0.11 867 326 $72 33.45 5.89 14588 MWD+IFR-M-CO -SC (3,3) 8.500.00 63.37 143.31 5,44027 10.28 -0.81 3399 0,11 8.82 3.32 584 34.02 596 14564 MWD -IFR -MS -SC (3,3) 880000 83.37 143.31 5,48509 10.45 -0.81 34.55 0.11 8.97 337 5.97 34.58 6.03 145.61 MWD+IFR-ML-SC (3,3) 8,70000 63.37 14331 5,529.91 1062 -0.81 MAl 0.11 9.12 343 6.09 35.14 6.11 145.59 MWD+1FR-MH AZ -SC (3.3) 8.800.00 63.37 143.31 5,574.73 10.79 -0.81 3589 0.11 9.27 348 821 35.70 8.18 145.57 MWD+1FR-M-CAZ-8C(3.3) 8,900.00 63.37 143.31 5,619.55 1098 -0.81 362/ 0.11 9.43 3.54 6.34 36.26 6.25 145.54 MM -IFR AR-CAZ-SC(3,3) 91000.00 6337 14331 5,884.37 11,13 -0.81 W80 0.11 9.50 3.60 6.47 36.83 8.32 14552 MWD+IFR-AR-CAZ-SC(3,3) 9,100.00 6337 14331 5,709.19 11.29 -0.81 37.36 0.11 9.73 3.66 659 37.39 6.40 145.50 MM+IFR-AK-CPZ-W(3,3) 9,200.00 63.37 14331 5,754.01 11.46 -0.81 37.93 oAl 9.80 3.71 872 3195 6.47 145.48 MWD+1FR-AK-CAZ-X(3.3) 9,30000 63.37 143.31 5,79883 1163 -081 3849 0.11 10.03 377 885 38.52 6.54 145.46 MWD+1FR-M(-CAZ-SC(3,3) 9,40000 63.37 143.31 5,84366 11.80 -0.81 3905 0.11 10.18 383 699 39.06 6.61 145.44 MWD+1FR-AK-CP-SC(3,3) 9500.00 6387 143.31 5,888A8 1197 -0.81 3962 0.11 1034 389 112 39.64 6.69 145.42 MWD0FR-M(-CAZSC(3,3) 9.800.00 63.37 143.31 5.933.30 12.14 -0.81 40.10 0.11 10.49 395 125 40.20 876 14541 MW IFR-AWCAZ-SC(3, 3) 9,700.00 63.37 143.31 5,978.12 1231 .0.81 4074 0.11 1084 /01 7,39 40.77 683 145.39 MWWIFR-AK-CA -SC (3. 3) 91000.00 6337 1/3.31 6,022.94 12.48 4.81 41.30 0.11 10.79 4.00 7.53 41.33 6.91 145.37 MWD+1FR-M(-CRZ-SC (3,3) 9,900.00 8337 14331 8.06176 1265 -Dal 4187 0.11 10.94 4.14 7.65 41.89 6.98 145.35 MWD+IFR-ARCAZ-SC(3,3) 10,000.00 83.37 143.31 6,112.58 12.81 -0.01 42.43 0.11 11.10 420 7.80 42.46 7.06 145.34 MWD+IFR-AR-CAZ-SC(3, 3) 10,100.00 63,37 14331 6,157.40 12.98 -0.81 42.99 0.11 11.25 4.211 7.94 43.02 7.13 145.32 MWD+IFR-M(-0 -80(3,3) 10,200.013 63.37 143.31 6,202.22 13.15 -081 43.56 0.11 11.40 4.33 8.09 4358 120 145.31 MM -IFR -M - -SC (3,3) 10,300.00 63.37 143.31 6,247.04 13.32 -0.81 44.12 0.11 11.55 4.39 8.23 44.15 7.28 145.29 MWD+IFR-MHL-SC (3,3) 10.400.00 63.37 14331 6,291.86 13.49 -081 44.88 0.11 11.70 4.46 837 44.71 7.35 145.28 MWD+IFRMAR -86(3.3) 10,500.00 63.37 143.31 6,33668 1366 -0.81 45.25 0.11 11.86 4.52 0.52 45.27 7.43 14526 MWD+1FR-M(-CPZ-W(3,3) 10,80000 63.37 143.31 6,381.50 13.83 -0.81 45.81 0.11 1201 4.59 888 45.84 7.50 14$.25 MWD+IFR-AK-CAZ-SC(3,3) 10,70000 83.37 1/3.31 6,426.32 1400 -0.81 46.30 0.11 12.16 466 8.81 46.40 7.58 145.24 MWD+IFR-AK-CPZ-SC(3,3) 1o.800.00 63.37 143.31 6,471.14 14.17 .0.01 4894 0.11 1231 4]2 6.96 46.96 7,65 145.22 MM+IFR-M(-CPZ-W(3, 3) 10,900.00 6337 14331 6,515.96 1/3/ -0.81 4150 0.11 12.46 479 9.11 47.53 7.73 14521 MWD+1FR-AK-CAZ-SC(3,3) 11,000.00 6137 143.31 6,560]8 14.51 -9.81 48.07 0.11 1262 4.86 9.28 48.09 180 14520 MWDHFR-AK-CAZ-SC(3,3) 11,100.00 63,37 14331 6,60560 14,68 -0.81 4883 0.11 12.77 4.93 9.42 48.66 188 145.19 MWD+IFR-AK-CAZSC(3,3) 11.200.00 63,37 143.31 6,650.42 14.84 -0.81 49.19 0.11 1292 590 957 4922 195 145.18 MWWIFR-AK-CA -SC (3, 3) 11,300.00 63.37 14331 6,89525 1501 -0.61 4976 0.11 13.07 5.07 9.73 49.78 8.03 145.16 MWD+IFR-AK-CAZ-SC(3, 3) 11,400.00 63.37 143.31 6,740.07 15.18 -0.81 50.32 0.11 13.23 5.14 988 5035 8.10 145.15 MWD+IFR-ARCAZ-SC(3,3) 11,500.00 63.37 143.31 5784.89 15.35 -0.81 Was 0,11 13.38 521 10.04 5091 8.18 145.14 MWD+IFR-M4GA-SC (3.3) 11,600,00 63.37 143.31 6,82971 15.52 -0.81 51.45 0.11 13.53 528 1020 51A7 8.25 145.13 MWD+IFR-AR-CAZ-SC(3,3) 11,700.00 83.37 143.31 8,874.53 15.69 -9.81 52.01 0.11 1368 535 10.36 62.04 8.33 145.12 MWD+IFR-M(-CAZ-SC(3.3) 11,800.09 61.37 143.31 6,91935 1586 -0.01 52.58 0.11 13.83 542 10.52 52.60 8.40 145.11 MM+IFR-AR-CAZ-SC(3,3) 11.900.00 63.37 14331 8,964.17 1803 -081 53.14 0.11 1399 550 10.68 53.17 8.60 145.10 MM -IFR AR-CAZ-W(3.3) 12,000.00 63.37 143.31 7,000.99 16.20 -0.81 0.70 0.11 14.14 5.57 10.84 53.73 655 145.09 MWD+1FR-AR-CAZ-SC(3,3) 12.100.00 63.37 143.31 7,053.01 18.37 -081 549 0.11 1429 564 11.01 54.29 0.63 145.08 MWD+IFR-M(-CPZ-W(3,3) 12,200.00 63.31 14331 7.098.83 16.54 -081 54so 0.11 14.44 5.72 11.18 54.86 670 145.07 MWD+IFR-AR-CAZ-SC(3,3) 12,300.00 63.37 14331 7,143.45 18.71 -0.81 55.40 0.11 14.60 579 11.34 WW2 8.78 145.06 MWD+IFR-M<-CAZ-80(3,3) 11/16/2018 8:58:58AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConomPhillips(Alaska) Inc. -WNS Local Co-ordinate Reference: Well Prelim: CD5-24 (9C)- Slot 24 Project: Western North Slope ND Reference: Plan: D25 aQ 74.50usft (D25) Site: CDs Alpine West Pad MD Reference: Plan: D25 aQ 74.50usft (D25) Well: Prelim: CD5-24 (9C) North Reference: True Wellbore: CD5-24 (9C) Survey Calculation Method: Minimum Curvature Design: C05-24 wp17 (SC) Output errors are at 1.00 sigma Database: OAKEDMP7 Position uncertainty and bias at survey station Measured Indinatien p oiouth Vertical Rl9heide Lateral VeNcal Ma9n8ude SemimVor seroWnor Depth Depth Error Bias Erre, alas Erre, Bias of Bias Error E., Azimuth Tool (--ft) r) P) (usn) luso) (usn) (--ft) lusn) (osm lose) (oan) (usa) (un) r) 12,400.00 63.37 143.31 7,10827 16.88 -0.81 5596 0.11 1475 5.67 11.51 55.99 685 145.05 MWD+IFR-M-CA -SC (3, 3) 12,500.00 63.37 143.31 223309 17.05 -081 56.53 0.11 14.90 594 1168 56.55 0.93 145.04 MWD+IFR-M-CA-SC(3, 3) 12,600.00 83.37 143.31 7,277.91 1722 .0.61 57.09 0.11 15.05 6.02 11.85 57.11 9.01 145.04 MWD+IFR-AWCA -SC (3. 3) 12)00.00 63.37 143.31 7322.73 17.39 -0.81 57.65 0.11 15.20 6.10 12.02 5786 9.06 14503 MWD+1FR-AWCA-W(3, 3) 12,600.00 63.37 143.31 7.367.55 17.56 -081 50.22 0.11 15.36 618 1220 58.24 9.16 14502 MWD+1FR-AWCAZSC(3, 3) 12,81580 6337 14331 7,37663 17.58 8.81 58.31 0.11 15.36 6,19 12.22 5833 9.17 145.02 MWD+1FR-Aa-CA2-SC(3, 3) 12,90000 6586 142.95 7,410.72 1169 -130 50.70 0.16 15.51 6.25 12.37 5661 9.23 145.01 MWD+IFR-AWCAZSC(3, 3) 1300000 60.65 14253 7,44920 17.77 -1.98 5834 025 15.67 6,31 12.53 5940 930 144.99 MWD+IFR-AWCA-SC(3, 3) 13,100.00 71.63 142.13 7,402.84 1180 -263 59.90 033 15.83 6.37 1269 59.98 9.36 1".97 MWDHFR-AK-CPZ-SC(3. 3) 13,20000 74.81 141.75 7.51155 1717 327 60.46 040 15.99 841 1283 6055 9.42 144.95 MWD+1FR-M-CP-SC(3.3) 13,27331 77.00 141.47 7,529.50 1772 41.75 60.87 0d6 16.12 6.44 1293 6098 9.45 144.93 MWD+1FR-AWCP-SC(3.3) 13.300.00 77.00 14147 7,53541 17.77 -3.75 61.02 046 16.16 644 12.97 61.12 947 144.92 MWD+IFR-M-CP-SC(3,3) 13400.00 77.00 14147 7,557.91 17.94 -3.75 6157 046 16.33 6.46 13.10 61,88 9.51 1".89 MWD+1FR-AWCP-SC(3, 3) 13,473.71 77.00 141.47 7,574.49 18.07 -3.75 61.96 0.46 16.45 6.50 13.20 62,09 9.54 1".87 MWD+1FR-AWCAZSC(3. 3) 13.500.00 7143 14147 1580.31 16.07 -3.85 62.12 046 1650 6.51 13.24 62.23 9.55 144.06 MWDHFR-M-CP-SC(3,3) 13,600.00 79.08 141.47 7,60066 18.00 -421 62.67 046 1667 654 1337 62.76 9.59 14083 MWD+IFR-AN-CIS-SC(3,3) 13.70000 00.73 141.47 7,610.10 16.00 -4.58 6322 046 1884 6.56 1349 63.32 9.63 144.81 MWD+1FR-AWCA-SC(9,3) 13,00000 02.30 141,47 7,63286 ism -4,94 0.76 046 17.01 6.58 13.61 63.86 9.66 14478 MWD+IFR-AWCI-SC (3,3) 13,898.16 84.00 141.7 7,6"50 17.94 -580 64.32 0.68 1706 6.59 1374 64.42 9.88 144.76 MM (3,4) 13,900.00 04.00 141.47 7,6"69 17.94 .5.30 61.33 0.69 1106 659 13.74 64.43 9.88 14/75 MWD (3.4) 13,91616 &.00 141.47 7,64659 17.94 -5.30 6444 070 1106 6.59 13.76 64.55 9.60 14475 MM)(3,4) 14600.00 81." 142.89 7,65455 17.82 -540 6503 0.86 17.07 660 1366 65.07 9.89 144.72 MWD (3.4) 14.100.00 85.87 14461 7,66268 17.66 -5.71 66.73 094 17.08 8.61 14.01 65.73 9.90 144.70 MM (3,4) 16,200.00 06.90 146.33 7,668.97 17.55 -5.94 MAI 1.01 17.11 862 14.15 65.44 9.91 144.70 MWD (3.4) 14,209.99 8100 146.50 7,669.50 17.56 -5.96 W48 102 17.11 662 14.16 66.51 9.91 14430 MM (3.4) 14,300.00 07.76 140.13 7,673.61 17.45 8.13 6106 1.05 17.14 863 1426 67.17 9.92 144.72 MWD (3.4) 14.400.00 0861 149.95 7,676.76 17.37 8.32 6167 1.07 17,16 663 14.41 67.94 9.92 14436 MM (3.4) 14,500.00 09.46 151.76 7,67847 17.30 8.51 68.24 1.07 1122 663 14.53 68.73 9.92 14463 MM (3.4) 14,515.44 8959 15204 7,678.59 17.29 8.54 68.33 107 17,23 663 14.55 safe 993 144184 MM (3,4) 14,60000 69.59 152.04 7,679.20 17.33 4.54 69,01 141 17.20 663 14.66 89.54 9.93 14491 MWD (3.4) 14.700.00 8959 1$204 7,679.91 17.39 8.54 69.84 181 17.34 663 14.79 7035 994 145.W MM (3,4) 14.80.00 0959 152.04 7,680.63 17.46 850 7069 221 17,41 663 14.94 71.20 9.95 14508 MM (3.4) 14.90.0 9959 15204 7,681.36 17.54 8.54 71,57 261 17.49 663 15.0 nor 997 145.18 MM (3. 4) 15,000.00 0959 152.04 7,682.06 17.62 656 7246 3.01 17.57 663 15.26 7296 9.90 14527 MM (3,4) 15,100.00 89.59 152.04 7,68277 1172 8.56 73.39 3.41 17,66 664 15.43 73.80 10.00 14536 MM (3.4) 1512W.00 0959 152.04 7,683.49 17.81 856 74.33 3.81 17.76 664 1562 74.82 10.02 14546 MM (3,4) 15.30.00 8959 15204 7,60420 17.92 8.54 75.30 421 17.87 664 15.81 75.77 10.04 145.56 MM (3.4) 1540.00 0959 152.04 7,684.92 17.34 4.54 66.65 -1.82 17.28 664 15.17 67.35 10.01 145.01 MWD+1FR-AWCA-SC (4.4) 15,50.00 8959 152.04 7.68563 1737 8.54 67,09 in 17.31 684 1526 67.59 10.02 145.03 MWD+IFR-AR-CA-SC(4,4) 15,800.00 0959 15204 7,606.34 17.40 4.54 67.34 -1.82 17.31 664 1535 67.83 10.03 14508 MW0+1FR-AWCA-SC(4.4) 15,700.00 8959 15204 7,807.08 1743 8.54 67.59 -162 17.36 664 15.44 BB.W 10.04 145.09 MWD+IFR-N(-0A-SC(4,4) 15,600.00 69.59 152.06 7,687.77 1147 6.54 67.64 -1.82 17.41 664 1554 8833 10.05 145.12 MWD+1FR-AR-CA-SC(4,4) 15,90000 89.59 152.04 7.68849 1T50 854 68.10 -1.82 17.45 6.84 1563 6858 1007 145.15 MWDNFR-PRCP-SC(4,4) 1600000 69.59 152.04 7,689.20 1154 6.54 66.36 -1.112 17.49 8.64 1572 68.84 10.08 14518 MWD+1FR-AR-CA-SC(4,4) 1610000 89.59 15204 7168992 1156 -6.54 68.63 4.82 17.53 8.84 15.82 69.11 1009 14521 MWD+1FR-RWCP-SC(4,4) 16,20000 69.59 15204 7.69063 17.82 854 68.87 -182 17.57 684 15.91 69.37 10.11 14525 MWD+IFR-ARC4 -80(4.4) 1630000 69.59 15204 7,691.35 1167 854 69.17 482 17.61 6.64 16.01 6864 10.12 145.28 MWD+IFR-AWCA-SC(4.4) 16,400.00 89.59 152.04 7,692.06 1771 6.54 69.44 -182 17.66 665 16.10 8992 10.14 14531 MWD+IFR-AR-CA-SC(4.4) 18,50000 89.59 15204 7,692.78 17.76 854 69.72 482 17.71 6.65 16.19 70.19 10.15 145.34 MWWIFR-AR-CA-SC(4,4) 16,600.87 09.59 152.04 7.68749 17,81 654 70.01 -182 17.75 865 16.29 7047 10.17 145.36 MWD+IFR-AR-CA-SC(4.4) 16,70087 8959 15204 7,694.21 1166 -6.54 70.29 -1.02 17.61 6.65 16.38 70,76 10.18 14541 MWD+IFR-AR-CA-SC(4,4) 16,800.00 09.59 152.04 7.69492 17.91 .6.54 70.59 -1.82 17.66 665 1640 71.05 10.20 14565 MWD+IFR-AR-CP-SC (4.4) 16,90000 89.59 15204 7,69564 17.96 -854 7088 402 17.91 6.65 16.57 7134 10.21 14548 MWD+IFR-AR-CA-SC(4,4) 17.000.0 69.59 152.04 7.69835 16.02 -854 71.18 -1.82 1797 685 1667 71.63 10.23 145.51 MWD+IFR-MRC -SC (4,4) 11/162018 8:58:584M Page 6 COMPASS 5000.14 Build 850 Company: ConomPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: CDS Alpine West Pad Well: Prelim: CD5-24 (9C) Wellbore: CD5-24 (9C) Design: CDS-24 wp17 (9C) ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Prelim: CDS-24 (9C) - Slot 24 Plan: D25 @ 74.50usft (D25) Plan: D25 @ 74.50usR (D25) True Minimum Curvature 1.00 sigma OAKEDMPI Position uncertainty and bias at survey station Measured Depth (use) Inclination r) Azimuh I') Verlival Depth (usn) HiOW& E., Bias (usn) (usa) literal Error (usa) Blas (usn) Vertical Error etas (usa) (usa) Ma9ntiuee of Bias (--ft) Semimajar Error Nast fiemim'nor Eno, (-am Azimuth Toe' r) 17,10000 89.59 15204 7,697.07 18.08 5.54 7148 -1.02 1802 6.65 16.76 7193 1025 145.55 MWD+IFR-M CAZ-SC(4, 4) 17.20000 0959 15204 7,697.78 18.14 -6.54 71]0 -1.82 18.08 665 16.85 72.23 1026 145.50 MM+IFR-AR-CA-SC (4,4) 17,30000 8959 152.04 7,698.50 18.20 -8.54 72.09 .1.82 18.14 665 1695 72.53 1020 145.62 MWD+)FR-A)(-CAZ-SC(4, 4) 17,400.00 89.59 152.04 7,699.21 1626 -6.54 7240 -182 18.20 665 1705 72.84 10.30 14566 Mw +IFR -AK -CA -SC (A. 4) 17.500.00 8959 152.04 7,699.92 18.32 -654 M71 -182 18.27 6.65 1714 73.15 10.32 14569 MWD+IFR-AK-CAZ-SC(4,4) 17,60000 89.59 152.04 7,700.64 18.39 -654 73.03 -1.82 18.33 685 17.24 MA7 10.33 145]3 MM+IFR-AK-CAZ-SC(4, 4) 17.70000 0959 152.04 7,701.35 10A5 654 73.35 -1.82 1640 6.65 1733 n.78 1035 14576 MM+IFR-AK-CAZSC(4,4) 17,80000 69.59 15204 7,702.07 1852 -6.54 7387 -1.82 18.47 668 17.43 74.10 1037 14580 MWD+IFR-AK-CAZ-SC(4,4) 17.90000 09.59 152.04 7,70278 1859 6.54 7400 -182 10.54 6.86 1752 74.43 10.39 14584 MM+IFR-AK-CAZ-SC(4.4) 18,00000 89.59 152.04 7,70350 1866 6.54 74.33 -1.82 1861 6.60 1782 74.75 10.41 14587 M IFR -MR- -SC (4.4) 18.10000 89.59 152.04 7,70421 18.73 -6.54 74.66 -182 10.68 8.68 17]2 75.00 1043 14591 MWD+IFR AI(-CAZSC(4,4) 18,200.00 89.59 15204 770493 18.80 5.54 75.00 -1.82 18,75 666 17.81 7542 10.44 145.95 MWD+IFR-AWCAZ-SC(4, 4) 18,300.00 89.59 152.04 7,705.64 18.88 5.54 75.34 -182 10.83 8.66 17.91 75.75 1045 145.98 MWD+IFR-AB-CA -SC (4, 4) 18400.00 89.59 152.04 7,706.38 18.06 654 75.68 4.02 10.91 666 1801 76.09 10.48 146.02 MWD+IFR-AK-CAZ-SC(4.4) 18,500.00 89.59 15204 7,707.07 19.03 -6.54 76,02 -182 18.98 666 10.10 7643 10.50 14606 MWD+1FR-AK-CAZ5C(4,4) 18,600.00 89.59 152.04 7,70779 19.11 .6.54 76.37 -1.82 1906 666 10.20 7877 10.52 146.09 MWD+IFR-AK-CAZ-50(4,4) 18.700.00 8959 152.04 7,700.50 19.19 -6.54 76.72 -182 19.14 686 1829 77.12 10.54 146.13 MWD+IFR-M-CAZ-SC(4.4) 10,80000 8959 152.04 770922 19.28 -654 P.07 -1.82 1923 6.66 10.39 P.47 10.56 148.17 MWWIFR-AK-CAZ-GC(4.4) 10,900.00 8959 152.04 7.709.93 1936 -654 7.42 -182 19.31 6.66 18.49 P.82 1058 146.20 MWD+IFR-N(-CA -SC (4, 4) 19.000.00 8959 15204 7,71065 19A4 -654 P78 -1.82 19.38 6.66 1859 78.17 10.60 148.24 MWD+1FR-AR-CA -SC (4. 4) 19,100.00 09.59 152.04 7711.36 1953 -6.54 78.14 -1.82 19.40 867 18.60 78.53 10.62 146.28 MW +H`R-AR-CA-SC (4,4) 19.200.00 89.59 152.04 7.71207 19.62 -854 7650 -1.02 19.57 6.67 1878 78.09 10.64 146.31 MWD+1FR-AK-CAZ-SC(4,4) 19,300.00 89.59 152.04 7,71279 19.70 8.54 7887 -1.82 19.65 667 18.88 79.25 10.68 146.35 MM+IFR-AK-CA-SC (4.4) 19,400.00 89.59 152.04 7,71350 19.79 654 79.24 -1.82 19]4 6.67 18.97 79.62 10.68 148.39 MWD+1FR-AK-CAZ-SC(4,4) 19,500.00 89.59 152.04 771422 1988 5.54 7961 -1.02 19.84 667 19.07 79.98 10.70 146.42 MM+IFR-AR-CA-$C(4,4) 19'saeco 89.59 15204 7.71493 19.90 6.54 7998 -1.02 1993 667 19.17 80.35 10.72 14846 MWD+IFR-AR-CAZ-SC(4,4) 19700.00 89.59 15204 7,715.65 20.07 5.54 80.35 -1.02 20.02 6.87 19.27 8072 10.74 146.50 MWU+IFR-MK-0-GC (4.4) 19,800.00 89.59 152.04 7,716.38 20.16 6.64 00.73 -1.02 20.12 667 19.36 81.10 1076 14663 MWD+IFR-AR-CA -SC (4, 4) 19,900.00 89.59 152.04 7,717.08 20.28 -6.54 81.11 -1.82 20.21 867 1946 81.47 10.79 14657 MWD+IFR-M-CP-SC (4,4) 20,00000 8959 152.04 771779 2035 -6.54 111.49 -1.02 20.31 6.67 19.58 01.85 10.81 14860 MWD+1FR-AK-CA-SC (4.4) 2,100.00 09.59 15204 7,718.51 20A5 -6.54 8187 -1.82 20.41 667 19.66 82.23 1083 146.84 MMAFR-AK-CA-SC (4,4) 20,200.00 09.59 152.04 7.719.22 20.55 -654 8226 -1.82 20.50 6.67 1976 82.82 10.85 146.68 MWD+IFR-AK-CAL50(4,4) 20,300.00 09.59 15204 7,719.94 2065 5.54 13285 -1.82 20.60 667 19.85 83.00 1087 146.71 MWD+IFR-AR-CAZ-SC 14,4) 20.40000 09.59 152.04 7,72065 20.75 654 83.04 -1.82 2071 6.68 19.95 8339 10.09 146.75 MWWIFR-N(-CA-SC(4,4) 28500.00 89.59 152.04 772137 20.85 -654 8343 -1.82 20.81 6.68 20.05 83.78 10.91 146.78 MWD+'FR-AR-CA -eC(4, 4) 20.80000 89.59 152.04 7,722.08 2096 6.54 83.83 -1.82 20.91 668 20.15 84.17 10.93 14882 MWD+IFR-AWCA-SC (4.4) 20700.00 89.59 152.04 7722.80 21.06 5.54 84.22 -1.02 21.01 BAB 20.25 8456 1095 146.85 MM+IFR-AK-CA-SC (4.4) 20,900.00 89.59 152.04 7,723.51 21.17 6.54 84.62 -182 21.12 868 2035 84.96 10.97 14689 MWD+1FR-AK-CAZ-SC(4,4) 20,900.00 8959 152.04 7,724.23 21.27 5.54 85.02 -1.02 2123 66B 2044 8536 1099 146.92 MWD+1FR-AK-CAZ-SC(4,4) 21,00000 89.59 15204 7,724.94 21.38 -6.54 MM3 -1.82 21.33 6fi8 20.54 85.76 11.02 146.06 MM+IFR-AK-CAZ-SC(4.4) 21,100.00 8959 152.04 7,725.65 2149 -fi.54 MM3 -182 21.44 660 2064 88.16 11.04 146.99 MV IFR -M6 -SC (4,4) 21,200.00 89.58 152.04 7,726.37 2160 -654 81s24 -182 21.55 6.60 20.74 06.56 11.06 147.02 MWWIFR-AR-CAZ (A. 4) 21,300.00 8959 152.04 ],72)08 2170 -6.54 0665 -1.82 21.66 6.60 20.84 88.97 1108 147.06 MWD+IFR-AH-CAZ-80(4,4) 21,400.00 09.59 152.04 7.727.00 21.02 -654 0706 4.82 21.77 6.60 2.94 87.30 11.10 147.09 MWD+IFR-M-CA -SC (4. 4) 21,500.00 89.59 152.04 7,728.51 2193 -6.54 8747 -1.82 21.88 6.68 21.04 8779 11.12 147.12 MWD+IFR-AK-CP-SC (4.4) 21,600.00 89.59 152.04 7.72823 22.04 654 8788 -1.02 2200 668 21.14 88.20 11.14 147.16 MWD+1FR-AWCA-SO (4.4) 21,700.00 89.59 152.04 7,729.94 22.15 6.54 80.30 -1.02 22.11 868 21.24 88.61 11.16 147.19 MWD+IFR-MK-0 -SC 14,4) 211800.00 89.59 15204 7,730.66 22.27 654 80.72 .1.82 2222 6.69 21.34 89.03 11.18 147.2 MWD+IFR-AW CA -SC (4,4) 21,90000 89.59 15204 7,731.37 22.30 5.54 89.14 -1.82 22.34 669 21.44 89.44 11.21 14726 MWD+IFR-AK-CA-SC (4,4) 22,060.00 89.59 15204 7,73209 22.50 654 89.56 -1.82 22.46 6,69 21.53 89.86 11.23 147.29 MWD+1FR-M-CA -SC (4. 4) 22,100.00 89.59 15204 7,732.80 22.62 6.54 89.98 -1.02 22.57 6.69 21.63 90.28 11.25 147.32 MWD+IFR-AK-CA-SC (4,4) 22,200.00 89.59 152.04 7,733.52 2273 6.54 W41 -182 22.89 6.69 2173 9070 11.27 147.35 MWD+1FR-AK-CAZ-SO(4, 4) 22306.00 8959 152.04 7,734.23 22.05 6.54 W83 -1.82 22.81 6.69 2183 91.13 1129 147.38 MWD+1FR-AK-CA -SC (A. 4) 2$400.00 88.59 152.04 7]34.95 22.97 -854 9120 -1.82 22.93 6.69 2193 91.55 1131 14742 MWD+1FR-AK-CAL8C(4, 4) 11/1612018 8:58:58AM Page 7 COMPASS 5000.14 Build 85D Company: ConowPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Prelim: CD5-24 (9C) Wellbore: CD5-24 (9C) Design: CD5-24 wp17 (9C) ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MO Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Prelim: CD5-24 (9C) - Slot 24 Plan: D25 @ 74.50usft (1325) Plan: D25 @ 74.50usft (D25) True Minimum Curvature 1.00 sigma OAKEDMPI Position uncertainty and blas at survey station Measured Inclination Azimuth wi icet HighcW. Lateral Vertical Magnitude Semi+najor Senlminor Depth Depth Ener Be. Eoor Blas Error Dias of Bias Ermr Error Azimuth Teal (can) (') P) (usa) plan) (onil)) ho,") (usn) (usa) (usn) (usn) (osa) loaf) r) 22,500.00 89.59 152.04 ],]35.66 23.09 5.M 91.69 .1 .82 2805 669 2203 91.98 11.33 14745 MWD+IFR-AK-CAZ-SC(4, 4) 22600.00 89.59 162." ),]36.36 2321 6.54 92.12 -1.82 23.17 6.69 22.13 9241 11.35 147,40 MWD+1FR-AK-CA -SC(44) 22]0000 89.59 152." ],]3709 23.33 6.54 92.55 -1.02 2329 6.69 2223 92.84 1137 147.51 MW0+1FR-AK-CAZ-W14.4) 22000.00 89.59 152." ],]37.80 23A5 6.54 92.99 -1.82 23.41 6.69 2233 93.2) 11.40 147.9 MWD+1FR-AK-CA -W(4,4) msoo, 0 89.59 152." 7]38.52 2358 5.54 93.42 -1.82 23.54 6.69 22.43 93.70 11.62 14].5] MWD+IFR-AK-CAZ-W(4,4) 23,000.00 8959 152." ],]3923 2370 6.84 93.86 -1.82 23.65 669 2253 94 14 11.44 14760 MM+IFR-AK-CA -W(4, 4) 23,10000 89.59 152." ],]3995 2383 6.54 94.30 -1.82 23.78 6.70 22.83 94.57 1146 14763 MWD+1FR-AK-CAZ-SC(4,4) 23,200.00 8959 152." ],]40.66 23.95 6.84 94.74 -182 23.91 6.10 2273 9501 11.48 14708 MM-IFR-AK-CAZ-SC(4,6) 23,300.00 8959 152." ],]4138 2408 6.54 95.18 -1.82 24.04 6,70 22.83 9545 1150 14769 MWD+IFR-AK-CAZ-SC(4, 4) 23.400.00 89.59 152." 7,74209 2420 684 95,62 -182 24.16 6.70 2293 95.89 11.52 14772 MWD+IFR-N(-CAZ-13C(4,4) 23,500.00 99.59 152." ],]4281 24.33 43.54 0,07 -182 24.29 6.70 23.03 90.33 1154 14].]5 MWD+IFR-MK-0-SC (4,4) 23,600.00 8959 152." ],]43.52 2446 -6.54 96.51 -1.82 24.42 6.m 0.13 96]8 11.56 14]]8 MWD+IFR-AR-CM-80(4,4) 23,700.00 8959 152." ],]44.24 24.59 -6.84 9696 -182 24.55 670 23.23 9722 11.58 147.80 MWD+IFR-AK-CA-SC (4,4) 23,800.00 8959 152." 7.74695 24.71 -8.54 97A1 -1.82 24.88 670 2334 9767 1160 147.83 MWD+1FR-AR-CAZ-SC(4,4) 23,900.00 89.59 15204 7,745.67 24.84 -6.54 97.86 -182 24.81 670 23.44 98.12 11.62 147.86 MM+IFR-AR-CP -SC (4,4) 24,000.00 89.59 152.04 7,746.38 24.97 -8.54 93.31 -182 24.94 870 2854 98.57 11.64 147.89 MW13+1FR-AR-CAZ-80(4,4) 24,100.00 89.59 152." 7,747.10 25.11 -6.54 9876 -1.82 2507 670 23.64 9902 11.67 147.92 M1?tflD+1FR-AR-CAZ-SC(4, 4) 24,20.00 89.59 152." 7.747.81 25.24 -654 9922 -1.82 2520 630 23.74 99.47 1169 147.94 MWD+IFR-AR-CAZSC(4.4) 24,31.00 89.59 152.04 7,748.53 25.37 -854 99.67 -1.82 25.33 870 23.84 99.92 1171 147.97 M1IlID+1FR-AK-CAZ-50(4,4) 24,400 00 89.59 152.04 7,749.24 25.50 -654 100.13 -1.82 2546 671 23.94 100.37 11,73 140.00 MNO+IFR-AK-CAZ-SC(4.4) 24,500.0 89.59 152.04 7,749.95 2563 -6.54 10058 -1.82 0.60 671 24." 10083 11.75 148.02 MWD+IFR-AK-CAZ-SC(4,4) 248000 89.59 152" 7.750.67 25.77 -654 101." -1.02 25.73 6.71 24.14 101.28 1137 148.05 MWD+IFR-AK-CAZ-SC(4.4) 24,700.00 89.59 152.04 ),]51.30 25.90 -6.54 101.50 -1.02 25.87 671 24.24 10174 11.79 148.08 MWD+1FR-AK-CAZ-80(4,4) 24,00.00 89.59 15204 ],]52.10 26.04 -6.54 101.96 -1.02 28.00 6.71 24." 102.20 list 148.10 MWD+IFR-AK-CAZ-SC(4. 4) 24,900.00 89.59 15204 7,752.81 26.17 -6.54 102.43 -1.82 26.14 671 24.45 10268 1183 148.13 MM+IFR-AK-CAZ-30(4,4) 25.10.00 89.59 15204 7753.53 26.31 -6.54 102.89 -1.02 26.2] 6.71 24.55 103.12 1185 148.15 MWD+IFR-AK-CAZ-SC(4,4) 25,100.00 89.59 15204 ],764.24 26.44 5.54 103.35 -1.02 26.41 671 2465 103.58 11.87 148.18 MWD+IFR-A -CAZ-80(4,4) 25.20.1 89.59 15204 7.75498 26.58 -6.54 11.82 -1.62 28.55 6.71 24,75 104.05 1189 14821 MWD+IFR-AR-CAZ-SC(4, 4) 25,30000 89.59 15204 7,755.67 26.72 5.56 104.28 .1.82 26.60 671 24.05 104.51 11.91 14823 MWD+IFR-AR-CAZ-SC(4, 4) 25,400.00 89.59 152." 7]5639 26.86 6.84 1"75 -1.82 26.82 6.71 24.95 1044.98 1193 14026 MWD+IFR-N(-CAZ-SC(4, 4) 25,500.1 8959 152." 7,757.10 27,00 5.84 105.22 -1.82 26.% 8,71 25.05 10644 11.95 148.28 MWDdFR-AR-CAZ-SC(4, 4) 25,6001 89.59 15204 7,)57.82 27.13 5.54 105.69 -1,82 27.10 6.71 25.15 105.91 11.97 140.30 MWD+1FR-ARCAZ-8C(4, 4) 25,700.0 8959 152" ],]58.53 2]27 6.84 11.16 -182 2724 6,71 25.26 1013.38 11.99 148.33 MWDNFR-AR-CAZSC(4, 4) 25,80000 8959 152." 7,759.25 27.41 -6.54 1163 -1.82 27,38 6.72 25.36 106.85 1201 148.35 MND+1FR-ARCAZSC(4,4) 25,90000 89.59 15204 7,759.96 2755 -8.54 107.11 -182 27.52 6.72 2546 107.32 12.03 14838 MWD+1FR-AR-CAZSC(4,4) 26.00000 9959 152." 7,780.68 27.69 -6.54 10758 -1.82 27.86 672 25.56 107.79 1205 148.40 MWD+1FR-AK-CAZ-SC(44) 26,100.00 8959 152." 7,761.39 27.84 -654 10805 AM 2rso 8,72 25.66 108.27 12.07 14842 MWD+IFR-AK-CA-SC(4,4) 26.200.00 89.59 152." 7.762.11 27.90 -6.54 10853 -1.82 2794 672 25.77 108.74 1209 14845 MWD+1FR-AK-CAZ-SC(4,4) 2$300.00 89.59 152." 7,782.82 28.12 .654 109.01 -182 28.08 672 25.87 10922 12.11 14647 MWD+IFR-AK-CAZ-SC(4.4) 26400.00 09.59 152.04 7,763.53 28.26 -654 109A8 -1.82 2823 672 25.97 10989 12.13 14849 MWD+1FR-AK-CAZ-SC(4,4) 26,50.00 89.59 152.04 7,79.25 2840 -654 10996 -1.82 28.37 6S2 26.07 11017 12.15 148.51 MM+IFR-AK-CAZ-SC(4, 4) 26,81.00 89.59 152.04 7,764.96 28.55 -654 110.44 -1.82 28.51 6.72 26.17 110.65 12.17 14854 MWD+1FR-AK-CAZ-SC(4,4) 2071.00 89.59 15204 7,765.60 28.69 -654 110.92 -1.82 28.66 872 26.28 111.12 12.19 148.56 MWD+IFR-AK-CAZ-8C(4,4) 28,800.1 89.59 152.04 7,766.39 28.04 -6.54 11140 -1.02 260 6.72 M,w 111.0 1221 148.58 MWD+1FR-AK-CAZ-SC(4.4) 2090000 89.59 152.04 ],76].11 28.98 -6.54 111.89 .1.82 20.95 6.72 26.48 112.08 1223 14860 MWD+IFR-AR-CAZ-SC(4,4) 2700.00 89.59 152.04 ],76).02 29.12 4.54 112.37 -1.82 29.1 en 28.58 112.57 1225 14862 MWD+1FR-AR-CAZ-SC(4,4) 27.100.00 89.59 15204 7,76854 29.27 5.M 112.85 -1.82 29.24 673 26.60 113.05 12.27 148." MM+IFR-M-CA-SC(4,4) 27.20000 89.59 152.04 7.76925 29.42 654 113.34 -1.82 29.38 6.73 2819 113.53 1229 140.67 MWD+IFR-AK-CAZ-SC(4.4) 27,300.00 89.59 15204 ],769.9] 29.56 6.54 113.02 -1.82 29.53 673 26.09 11601 1231 148.69 MWD+IFR-AW0AZ-SC(4, 4) 27,400.00 89.59 152" 7.77088 29.71 6.54 114.31 -182 2967 6.73 nee, 114.50 1233 140.71 MWD+IFR-AWCAZ-SC(4,4) 27.500.00 8959 152." 7]7140 29.85 6.M 114.80 -1.82 29.82 6,73 21.09 114.98 12.35 148.73 MWD+IFR-M-CAZ-SC(4,4) 27,800.1 89.59 152." 7)]2.11 30.00 654 115.28 -182 29.97 673 2720 11547 1237 148.75 11WD+1FR-AK-CPZ-SC(4, 4) 27.7001 89.59 152" ],7]283 30.15 6.M 115.]] -1.82 30.12 6.73 2730 115,96 12.39 140,77 MWD+iFR-AK-CAZ-SC(4,4) 27,8001 89.59 152" 7,773.54 30.30 5.54 116.26 .1.82 30.26 8.73 2].40 116.45 12.40 148.79 MM+IFR-,AK-CAZ-W(4, 4) 111152018 8:58:58AM Page 8 COMPASS 5000.14 Build 85D Company: ConomPhillips(Alaska) Inc.-WNS Project: Western North Slope Site: CD5 Alpine West Pad Well: Prelim: CD5-24 (9C) Wellbore: C135-24 (9C) Design: CD5-24 wp17(9C) Conocolphillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: output errors are at Database: Well Prelim: CD5-24 (9C) - Slot 24 Plan: D25 @ 74.50usft (D25) Plan: D25 @ 74.50usft (D25) True Minimum Curvature 1.00 sigma OAKEDMPI Position uncertainty and bias at survey station Measured Inchmethun Depth lose) r) 27,900.00 8959 28,000.00 89.59 28,100.00 89.59 28,200.00 89.59 28,300.00 89.59 Azimuth r) 152.04 15204 15204 152.04 152.04 Vertical Deem Just] 7,77426 ],774.9] 7,]]668 7,77640 7,777.11 Hi9hsida Error Bias rush) (um) 30A4 -0.54 30.59 -6.54 074 -6s4 30.09 -654 31.04 -864 Lateral Error toren) 116.75 117.24 11]]3 11823 113.72 Bus (--ft) -182 .1.82 -1.02 -1.82 .1.82 Vmtical Error lose) 30.41 W.% W.71 3086 31.01 Bias (..ft) 673 673 6.73 673 673 Ma9nilu4e Bemianaior of ON. Error (urn) Issue) 27.50 11894 27,61 11]42 2711 117.92 2].81 118.41 2].91 118.90 Semi -minor Emor Azimuth Tool (usn) 11) 1242 148.81 MWD+IFR-AK-CAZ-SC(44) 1244 148.83 MWD+IFR-AK-CAZ-SC(4, 4) 1246 148.85 MWD+IFR-AK-CAZ-SC(4. 4) 12.48 148.87 VM+IFWARCAZ-SC(4,4) 12.50 148.09 WW IFR-ARCAZ-SC(4.4) 28,40000 28.500.00 28,0000 28.70000 20,800.00 89.59 89.59 0969 89.59 89.59 15204 152.04 15204 152.04 152.04 ],1]7.83 7.778.54 7.17926 7,]]9.97 7,780.69 31.19 31.34 31.49 31.64 3179 5.54 4.54 -6.54 -654 5.54 119.21 11931 12020 120.70 121.20 -182 4.82 -182 -1.82 -1.82 31.16 31.31 31A6 stall 31.76 6.74 6.74 674 674 674 2802 28.12 28.22 2633 2843 119.39 119,811 12038 12087 121.37 1262 12.54 1256 12.58 1260 14891 MWD+IFR-AK-CAZSL(4, 4) 148.92 MWD+11FR-AK-CAZ-SC(4.4) 148.94 MWD+IFR-AK-CAZ-W(4,4) 148.% MWD+I1FR-AK-CF7-SC(4,4) 14898 MWD+IFR-AK-CAZ-SC(4,4) 28.900.00 29,000.00 29,100.00 29.200.00 29300.00 8959 8959 8959 89.59 89.59 152.04 15204 152.04 152.04 15204 7,781.40 7,78212 1782.03 7,783.55 7,784.26 31.94 32.09 32.25 32.40 32.55 -654 -6.54 -654 4.54 4.54 121.70 122.19 Met) 123.19 123.69 4.82 -182 -1.82 -1.02 -182 31.91 3208 32.22 32.37 32.52 6.74 614 6.74 674 674 Mn 28.64 28.74 2884 Ass 121.85 122.36 122.86 123.36 123.85 12.62 1264 1265 12.67 1269 149.1)0 MWD+IFR-AK-CAZ-=(4,4) 149.02 MWD+1FR-AK-CAZ-SC(4, 4) 14903 MtW+IFR-AK-CAZSC(4.4) 14905 MWD+1FR-AK-CAZ-SC(4.4) 149.07 MWD+IFR-AK-CAZ-SCKA) 29,40000 29.50000 29.60.0 29,700.00 29.800.00 8959 89.59 89.59 8959 89.59 152.04 152.04 152.04 152.04 152.04 7,784.98 7.785.69 7786.41 ].]87.12 7,]8].84 3210 32.86 3301 33.16 3132 -6.54 5.54 4.54 -6.64 .6.54 124.19 12469 12520 125.70 126.20 -1.82 .1.82 -1.82 -1.82 -1.82 32.67 32.83 3298 31.13 3329 6.74 6.74 6.74 675 6.75 29.05 29.15 29.25 29.36 29.48 12436 12486 125.35 125.86 126,36 12,71 12.73 12.75 1277 1279 14909 MWD+1FR-AK-CAZ-SC(4,4) 149.10 MM+IFR-AK-CAZSC(4,4) 149.12 MWWIFR-AK-CAZ-SC(4,4) 149.14 MWD+1FR-AK-CAZ-SC(4, 4) 149.16 MWD+IFR-AKGAZ-SC(4.4) 29900.00 30000.00 30100.00 30200.00 30300.00 89.59 89.59 WES) 89.59 89.59 15204 152.04 152.04 152.04 152,04 7,788.55 7,78926 7,70998 ],]90.69 ],]91.41 33.47 3362 3378 33.93 34.09 4.54 -6.54 -654 4.54 5.54 125.71 12721 127.72 128.22 12893 -1.82 -1.82 -1.02 -1.82 -1.82 33.44 33.80 31]5 33.90 34.06 675 675 675 6.75 675 2957 2987 29.77 29.88 29.98 128.86 127.37 12].8] 128.38 128.86 1281 12.83 12.84 12.85 1288 149.17 MWD+IFR-AK-CAZ-SC (4,4) 14819 MWDHFR-AK-CAZ-W(4,4) 149.20 MWD+I1FR-AK-CAZ-SO(4,4) 14922 MWD+IFR-AK-CAZ-SC(4.4) 149.24 MWD+IFR-AK-CAZ-SC(4, 4) 30.400.00 30,50000 30,600.00 397000 3080.0 89.59 89.59 89.59 89.59 89.59 152.04 15204 152.04 15204 15204 7,792.12 7,792.84 ],]93.55 7.]942] 7,794.98 34.24 MAO 34.55 3471 34.87 -654 -6.54 5.54 5.54 -654 129.24 129.74 130.25 130]8 13127 -1.82 -182 -182 -1.82 462 34.21 34.37 34.53 34.68 34.84 6.75 6.75 815 675 6.75 30.08 30.19 3029 3039 W.W 129.39 12889 130.40 13091 131,41 1290 12.92 1294 12.96 12.98 14925 MWD+IFR-AKAAZ-SC(4,4) 14927 MWD+IFR-AX-CAZSC(4,4) 14928 MWBHIFR-AK-CAZ-SC(4, 4) 149.30 MWD+IFR-AK-CAZ-SC(4,4) 14932 MWD+1FR-AK-CAZSC(4.4) 30.90000 31,00.00 31,10000 31,20000 31,300.00 8959 09.59 89.59 89.59 8959 152.04 15204 152.04 152.04 152.04 7,79570 7,7%41 7.797.13 7,]9].84 7798,M 35.02 35.18 35.34 35,49 WAS -6.54 -6.54 -6.54 -654 -6.54 13178 132.29 132.80 133.31 133.02 -182 -1.82 -1.82 -1.82 -1.02 3499 35.15 3531 35.46 35.62 6.75 6.76 676 676 676 3060 3071 30.81 Wei 31.02 131.92 132.43 13294 133.45 133.% 1299 1301 13.03 13.05 1307 149.33 MWD+IFWAK-CAZ-5C(4,4) 149.35 MWD+IFR-M( AZ -SC (4.4) 149.38 MWDNFft-AK-CAZ-3L(4,4) 14938 MWO+1FR-AK-OAZSC(4.4) 149.39 MWD+IFR-AK-CAZ-SG (4,4) 3140.0 31,500.00 3180000 31,700.00 31,800.0 89.59 89.59 89.59 89.59 89.59 152.04 15204 152.04 152.04 152.04 7,]99.2] ].]99.99 7,8070 7,001.41 7,802.13 35.01 35.96 36.12 36.28 36.44 4.54 -654 4154 5.54 -6.54 1343) 134.M 135.36 135.87 13539 -182 -182 -1.82 -1.02 -1.82 35.78 MsAl 36.10 35.25 WW1 676 6.76 676 676 676 31.12 31.23 3133 31A3 3154 134.47 13499 135.50 136.01 1%.52 13.09 13.11 13.12 1314 13.16 14940 MWD+IFR-AK-CQ-SC(4.4) 149.62 MWD+IFR-AK-CAZSC(4,4) 14943 MWWIFR AK-CAZ-SC (4,4) 149.45 MWD+IFR-AK-CAZ-SC(4,4) 14946 MWD+1FR-ARCAZ-SC(4.4) 31.900.0 32,000.00 32,10.0 32,20.0 32.300.00 09.59 89.59 09.59 89.59 89.59 152.04 152.04 152.04 152.04 15204 ].802.84 7,003.0 ],8042] 7,804.99 7.005.70 MEG 36.76 38.91 37.07 37.23 -654 854 4.54 -8.54 -6.54 13690 137.42 137Ao 438A5 138.97 -182 -182 -182 -1.82 -182 W57 35.73 36.89 3105 3721 6.76 676 676 676 6.76 31.64 31]5 31.85 31.95 3206 13]04 137.55 130.07 138.58 139.10 13.18 13.20 13.22 13.23 1325 149.48 MWD+iFR-AK-CAZ-SC(4,4) 14949 MWDHFR-AKCAZ-W(4,4) 149.50 MWD+1FR-AK-CAZ-W(4,4) 14952 MWD+IFR-AK-CAZSC(4,4) 14953 MWD+IFR-AK-CAZ-50(4,4) 32,400.00 32.50.0 32,600.00 32700.00 32,80.00 89.59 W.59 89.59 8959 89.59 152,04 152.0 152.04 152.04 15204 7,80.42 7,307.13 7,807.85 1000.56 7,809.28 3739 37.55 3171 37.87 38.03 -6.54 -6.54 -864 5.54 .6.54 139.48 14000 140.52 141.04 141.58 -1.02 482 -1.82 -1.82 -1.82 37,35 37.52 37,68 37.84 38.00 877 6.77 6A 6A 697 32.16 32.27 32.37 3248 1268 439.61 140.13 140.65 MAE 141.68 1327 13.29 13.31 13.33 13.35 149.54 MW0+1FR-AB-CAZ-SC(4,4) 149.56 MM+IFR-AK-CAZ-SL(4,4) 149.57 MM+lFR-AK-CAZ-SC(4,4) 149.56 MWD01FR-AK-CAZ-SC(4,4) 148.80 MWD+1FR-AK-OAZ-W(4.4) 32900.00 33,000,00 33,10000 33,2000 89.59 8959 89.59 Base 152.04 152.04 152.04 15204 7,809.99 7,81071 7,011,42 7,812.14 WA9 3835 38.51 3067 4.54 -8.54 4.54 4.54 142117 142.59 143.11 14364 .1.82 -1.82 -1.02 -182 38.16 38.32 38.49 3665 6.]] 677 677 677 32.69 32.79 32.90 33.0 14220 142.72 143.24 143.76 13.36 1338 13.40 13.42 149.81 MWWIFR-AK-CAZ-SC(4,4) 149E2 MWD+IFR-AK-0AZ-SC(4,4) 149.63 MWD+IFR-AKCAZ-SC(4,4) 14965 MWD+IFR-AK-CAZ-SC(4,4) 111182018 8:58:58AM Page 9 COMPASS 5000.14 Build 85D Company: ConocoPhillips(Alasks) Inc.-WNS Project: Western North Slope Site: CDS Alpine West Pad Well: Prelim: CD5-24 (9C) Wellbore: CD5-24(9C) Design: CD5-24 wp17 (9C) ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Prelim: CD5-24 (9C) - Slot 24 Plan: D25 @ 74.50usft (D25) Plan: D25 @ 74.50usft (025) Two Minimum Curvature 1.00 sigma OAKEDMPI Position uncertainty and bias at survey station Measured Vertical Casing Hole Meaeumd Inctloaaon Azimuth witioal WSW& taleml (usft) Venlcal Magnitude SemHnejor Semi -Minor 119.80 Depth 20.000 42 000 Depth too, Blas Error Bias Error Blas WSlat Error E., Azimuth Tool (usft) r) 17 (usft) (usft) luta) Lusa) luta) jute) (um) (usal lmft) (usft) r) 33.30000 09.59 152.04 7.81285 30.83 -5.54 146.16 -1.82 38.81 6.77 33.10 14428 13.44 149.85 MVUD+IFR-ARGAZ-SC(4.4) 33400.00 09.59 15204 7,81357 Use -6.50 144.68 -Is2 38.97 8.77 33.21 14480 13.45 149.67 M=-IFR-AR-CAZSC(4,4) 33500.00 89.59 15204 7,81028 39.15 -6.54 14510 -1.82 39.13 6.77 33.31 145.32 13.47 149.68 MVu0HFR-MK AZ -SC (4.4) 33,80000 09.59 15204 7,81499 39.32 -6.54 145.72 -IA2 39.29 877 33.42 14584 13.49 149.70 MW IFR-A&CAZ-SC(4,4) 33)0000 89.59 152.04 7,815.71 3948 -6.54 146.24 -1.82 3945 6]0 33.52 146.36 1351 149,71 MW IFR-PH-CAZSC(4.4) 33,80000 89.59 152.04 7,816A2 39.64 -854 146.77 -182 39.61 678 33.63 14889 1353 149.72 M 1FR-AK-CAZ-SC (4,4) 33,900.00 8959 152.04 7,817.14 3980 -6.54 147.29 -1.82 3978 6,78 33.73 147.41 1355 14933 MM11FR-AWCAZ-SC(4.4) 54,00000 89.59 152.04 7.81785 39.96 -854 147.81 -182 3994 678 33.84 147.93 13.56 14974 MwDNFR-A&CAZ-SC(4,4) 34.100.00 8959 15204 7,818.57 40.12 -6.54 148.34 -182 40.10 6.78 33.94 148.45 1356 149.76 MwDNFR-Ax-CAZ-W(4,4) 34,200.00 8959 152.04 7,819.28 40.29 -6.54 148.88 -182 4026 678 34.05 148.98 136w 149.77 MWDtIFR-AWCAZ-SC(4,4) 34.300.00 8959 15204 7,820.00 40.45 -8.54 149.39 -182 40.42 6.78 36.15 14950 1362 149.78 MWD.IFR-AI(-CAZ-SC(4, 4) 36,600.00 8959 152.04 7,820.71 4061 -654 149.91 -1.82 4059 6.78 3426 15003 1360 14979 MWDNFR-A -CAZ-SC(4, 4) 34.500.00 89.59 152.04 7,821A3 4077 -654 150.44 -182 40.75 878 34.35 15cS5 13.66 149.80 MMNFR-A&CAZ-SC(4.4) 34800.00 89.59 152.04 7,822.14 40.94 -6.54 150.96 -1.82 40.91 628 34.47 151.08 13.67 149.81 MWD+1FR-AR-CAZ-SC(4.4) 34,700.00 WS9 152.00 7.822.88 41.10 -854 151,49 -1.82 41.08 6.78 34.57 151.60 13.69 149.82 MM+lFR-M-CAZSC(4,4) 34.800.00 8959 152.04 7.823.57 41.26 -854 152.02 -1.82 4124 6.78 34.68 152.13 13.71 14983 MM -IFR -M - -SC (4,4) 34.90000 89.59 152.04 7,824.29 41.43 -854 152.54 -182 41.60 6.78 30]8 15265 13.73 14985 AV IFR-A&CAZ-SC(4,4) 3500.00 89.59 152.04 7,825.00 4159 -6.54 153.07 -182 41.57 6.79 34.89 153.18 13.75 149.86 MV IFR-Ax-CAZ-SC(4,4) 33100.00 8959 152.04 7.825.72 41.75 5.54 153.60 -1.82 41.73 6.79 MMM 15371 13.76 149.87 MVUDMFR-AWOAZ-SC(4,4) 35$00.00 89.59 152.04 7,026.43 41.92 6.56 154.13 -1.82 41.89 6.79 35.10 154.23 13.78 149.88 MWDtIFR-AWCAZ-SC(4,4) 3330000 89.59 152.04 7,827.14 42.08 -6.54 154.65 .182 42.06 679 3520 15476 13.80 149.89 MWDNFR-A)(-CAZ-SC(4,4) M,40000 89.59 15204 7,827.85 42.24 -6.56 155.18 -1.82 42.22 6,79 3531 155.29 1382 14990 MM+lFR-AWCAZ-W(4,4) 3350000 09.59 152.04 7.82857 42.41 -6.54 155.71 -1.82 42.38 6.79 MM2 15582 13.84 149.91 MWDHFR-A)(-CAZ-SC(4,4) M'socc0 89.59 152.04 7,829.29 42.57 -6.56 156.24 -1.82 42.55 6,79 3552 156.35 13.86 14992 M=+1FR-AR-CAZ-SC(4, 4) 35.62955 89.59 15204 7.829.50 4262 -8.54 156,40 -182 42.60 6]9 35.55 15650 13.86 14992 MMMFR-AK-CAZ-SC(4,4) Design Targets Target Name -hithniss target Dip Angle Dip Dir. TVD +N/ -S +El -W Northing Easting -Shape V) (I (usft) (usft) (usft) (usft) (usft) Latitude Longitude CD5-24 2. Toe 082918 0.00 0.00 7,829.50 -27,701.13 16,37701 - plan hits target center - Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 119.80 119.80 20 x 42 20.000 42 000 2,252.54 2,189.50 10-3/4 x 13-1/2 10.750 13.500 13,898.16 7,644.50 7-5/8 x 9-7/8 by 11 7.625 11.000 35,629.55 7,829.50 4-1/2x6-3/4 4.500 6.750 1111612018 8 58:58AM Page 10 COMPASS 5000.14 Build 85D Company: ConomPhillips(Alaska) Inc.-WNS Project Western North Slope Site: CD5 Alpine West Pad Well: Prelim: CD5-24 (9C) Wellbore: CD5-24 (9C) Design: C135-24 wp17 (9C) Formations Measured Depth (usft) 1,329.65 2,392.72 3,121.40 4,816.93 5,365.79 6,269.39 9,245.71 12.065.84 12,471.91 12,728.49 12,737.41 13,318.17 13,353.73 13,870.50 14,071.14 14,209.99 18 022.50 Dian Annotations ConocoPhillips Error Ellipse Report Vertical Vertical Depth (usft) Name 1,324.50 Base Permafrost 2,310.50 C-30 2,846.50 C-10 3,789.50 K-3 4,035.50 K-2 4,440.50 Albian 97 5,774.50 Alban 96 7,038.50 HRZ 7,220.50 HRZ Base 7,335.50 Kupamk C 7,339.50 LCU 7,539.50 Alpine C 7,547.50 UJU 7,641.50 Alpine B3 7,660.50 Alpine Bt 7,669.50 Alpine 7,703.66 Fault 1 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Outputerrors are at Database: Lithology Well Prelim: CD5-24 (9C) - Slot 24 Plan: D25 @ 74.50usft (D25) Plan: D25 @ 74.50usft (D25) Two Minimum Curvature 1.00 sigma OAKEDMPl Dip Dip Direction 0.00 Measured Vertical Local Coordinates Depth Depth +N/ -S +E1 -W (usft) lush) (usft) (usft) Comment 0.00 0.00 KOP: Start 20.34'1100' DLS, 1.5° TF, for 400' 600.00 600.00 6.12 Start 61.69°/100'DLS, 2 -TF, for 278.61' 1,000.00 999.27 -20.01 18.56 Start 81.59°/100' DLS, 0" TF, for 102.07' 1,278.61 1,274.50 -60.69 24.54 Start 377.8°/100' DLS, 2° TF, for 871.85' 1,380.68 1,374.50 -80.27 133.89 Start 387.39°/100' DLS, 0° TF, for 20' 2,252.54 2,189.50 -359.73 137.69 Start 729.26°/100' DLS, 3° TF, for 572.4' 2,272.54 2,207.01 -368.62 304.63 Start 851.96°/100' DLS, 3° TF, for 166.67' 2,844.94 2,663.36 -667.07 372.15 Start 1387.57"/100' DLS, 0° TF, for 700- 3,011.61 2,775.93 -769.69 666.90 Start 1955.01'/100' DLS, 2° TF, for 682.88' 3,711.61 3,225.88 -1,217.65 994.59 Start 9440.48°1100' DLS, 0° TF, for 8421.31' 4,394.48 3,600.16 -1,683.11 5,492.49 Start 9866.99°/100' DLS, 3° TF, for 457.91' 12,815.80 7,374.63 -7,719.73 5,755.00 Start 10060'/100' DLS, 0° TF, for 200' 13,273.71 7,529.50 -8,060.00 5,876.39 Start 10474.35°/100' DLS, 1.65` TF, for 424.44' 13,473.71 7,574.49 -8,212.45 6,137.00 Start 10494.05°/100' DLS, 0° TF, for 20' 13,898.16 7,644.50 -8,539.72 -8,555.28 6,149.39 Start 10783.56°/100' DLS, 2- TF, for 291.84' 13,918.16 7,646.59 -8,790.53 6,320.37 Start 11088.73°/100' DLS, 2° TF. for 305.45' 14,209.99 7,669.50 -9,052.84 6,476.30 Start 32180.11°/100' DLS, 0° TF, for 21114.11' 14,515.44 u avo 55 7,678.59 7 82950 -27.701.13 16,377.01 TD: 35629.55' MD, 7829.5' TVD Checked By: Approved By: Date: 11/16/2018 8:58:58AM Page 11 COMPASS 5000.14 BU11d 85D Pool Report 0 a R 1 MUM J R Ilk 0 W °a in O _.. ✓. `._. a�_OJ 00 GO L 6 Cfl M �a G 4 OK ._ ...........CD O °°° °�'� d „s a m ✓ r 6 �O � OJ O y G - 90£.b0 � J sOJOJ � oN8§ I � U N a000 LM O 0 �J o s O CIS �o to S So- o J S J < O O < a 0 0 O S� o S OJ O / 60CD � N PN _ C ii 3 O � 0 6 ,o, i L9� J LO m a O CDS'Z� v I O O 1- N i m s N j j tG N E O O O O O OCD O O O O Q z O CO O O O N oO d O O a (uir}sn N 0009) i+AIJON/(')U}nog co .I d� m o M r 4c, JyJ yW/ a3^O / Yet O O O O O O O O O O O O O O O CD CN 00 CD r N co (ui�}sn 0009) (+)4lJoN/(7)ujnoS O O O CO O O O O M 0 0 0 v N O O O 00 r 0 CDQ N I• 0 0 0 0 0 0 N 4-0 W E U5-0 (a 2 D U `a 9999 "8 W / S !2 2UUV d� m o M r 4c, JyJ yW/ a3^O / Yet O O O O O O O O O O O O O O O CD CN 00 CD r N co (ui�}sn 0009) (+)4lJoN/(7)ujnoS O O O CO O O O O M 0 0 0 v N O O O 00 r 0 CDQ N I• 0 0 0 0 0 0 N 4-j 00 O M V is O — O O L O z o y88o U o co fW'J Om$� �✓ V a N m ogmmm� U 8:0 LL ,{ O 00 o'OJ In J t N, o o Sr J J O - N s y � o - r < � M C„_ O _ O SC� U n Um S e - O n ^, /l\ � U W , S-0 v 3 u N O o LC) -ra---- coo ez UV GYII�Zi U U O CDCDN f 0 N (O N d E O O O O O O m O O O O O o O O O O O z CO N 00 It O o (u!/Rjsn r 0009) (+)u)JoN/(2)4lnoS N M CD5-24wp17 NAD27 ASP4 Surface M CPA Coordinate Converter Data: NAD83 Region: alaska C Latitude/Longitude IDecimalDegiees * UTM Zone: r South F Slate Plane Zone: q Units: Fu --4t r Legal Description (NAD27 only) Datum: NAD27 Region alaska r Latitude/Longitude IDecirral Degrees * UTM Zone: True r South F State Plane Zone: I' �-] Units: us.11 r Legal Description (NAD27 only) Starting Coordinates: — Ending Coordinates: X: 1489129.64 X: I 349096.486220015 --- - Y. 5965537.42—� -- --—Y-5965791.46422617— Tmr form Quit I Help CD5-24wp17 NAD27 ASP4 Surface 4 CPAI Coordinate Converter From: Datum: NAD83 Region alaska r LatitudeiLongitude IDecimalDegrees D- r UTM Zone: r— r South r State Plane Zone:r�-:j Units: u r legal Derr_nptrn [UkDG7 or,p l Starting Coordinates:------ ----- - ----, I X: 11483129.64 Y: 5965537.42 - ❑ x ra -- Datum: N7D27 Region: alaska r LatitudOl-ongitude IDechnalDegrees • UTM Zone: True r South f•State Plane Zone:F7D Units: .{t C• Legal Description INAD27 only) Legal Desmiption-- Township: o11 1"J Range: 004 E . Meridian: F J Section:l8 FNL 425.74498 FEL I 2880.7435 Quit Help 17 NAD27 ASP4 Production Horizon Q CPAI Coordinate Converter Datum NAD83 Region: alaska r Lattude/Longdude IDecirnalDegrees, * UTM Zone: r South * State Plane Zone: F--.:-] Units: usdt r Legal Description (NAD27 o*) To: Datum NgD27 Region alaska r Latitude/Longitude IDecimalDegreas * UTM Zone: True r South (: State Plane Zone: I" J Units: us -fl r Legal Desaiption(NAD27only) 7 --- ordinates: r Ending Coordinates: X 1495090.02 x 35505&580544023 Y: 5956880.17 Y: 5957133.96379276 17 NAD27 ASP4 Production Horizon M CPAI Coordinate Converter From: – –_.- .-- Datum: _Datum: NAD83 Regius Kaska r Latitude7Longitude IDecanal Degrees r UTM Zone: f— r South * State Plane Zone: fq–�-:] Units: Fur 4t Legal Description INA.D27 only] Starting Coordinates: – Y, 1495090.02 Y: 5%6880.17 quit Help – ❑ X Datum: NAD27 . Region alaska r Latitude/Longitude IDecinnalDegrees • UTM Zone: True r South • State Plane Zone: F--'] Units: us -fl (-- Legal Description (NAD27 only) Legal Description Township:011 Range: 004 IC Meridian I" –�-] Sedion:F20— FNL 3684.8703 FEL 2060.7129 j�Translorm_ Quit Help ICD5-24wp17 NAD27 ASP4 TD M CPAI Coordinate Converter From: - Datum NAD83 . Regi: alaska r Latilude/Longilude IDecimalDergrees * UTM Zone: r South * State Plane Zone: Units: us -fl r Legal Description (NAD27 only) — ❑ X Datum: NAD27 Region alaska r Latitude/Longitude IDecimalDegrees f UTM Zone: Trus r South r State Plane Zone: F--:-Units:usdt r Legal Dmaiption)NAD27 only) �- Staining Cooidinates: Ending Coordinates: ----- - X 1504944.00 X: I 364909.728750909 Y: 5937514.00 Y: 5937767.24233362 L — --- _ 7 NAD27 ASP4 TD LS CPAI Coordinate Converter Datum:NAD83 . Region alaska f Latitudekongitude IDecimalDegfees * UTM Zone: �— r South * State Plane Zone: Units: us{t f Legal Description (NAD27 Caryl Starting Coordinates: X 11504944.00 Y: 5937514.00 Timsform _— Quit Hep — ❑ X Datum: NAD27 . Region: alaska r Latitude/Longitude IDecimal Degrees • UTM Zone: True F South f•State Plane Zone: F—�-] Units:{t C•' Legal Descrption )NAD27 only) Townshp: p10 Ranger F J MeridianI" J Section:lp ,II FL 1746.8837 FEL 2454.4236 L --Transform Quit Hep Tollerable Collision Risk Worksheet REV I DATE I BY I CK I APP I DESCRIPTION I REV I DATE I BY I CK I APP I DESCRIPTION 1 4/24/15 1 CZ I DB I C. A. I UPDATED PER K150003ACS 12 5/2/161 CZ GD C. A. UPDATED PER K160003ACS ALPINE SATELLITE DEVELOPMENT LOCATION OF THIS SURVEY T12 co—s Pao Q 11N CD4 TO ALPINE D CD5 ACCESS ROAD CD � N G z a qP 9 m O GY 2 _ m IAVD)LL IT °01 T VICINITY MAP NOT TO SCALE LEGEND: O PROPOSED CONDUCTOR • EXISTING CONDUCTOR SEC710N 18, T. 11 N., R. 4 E., U.M. PPS CD -5 OF U�OER o�Sao� (fin PAD a u, SN o�NG� QESGN oo°oXs% �t�TW��XX%%O%p O,pW ��• [n(QO ••••., ,` �\t\�O WN%�xN ��E`�C05 •4 OQO,pO ,Ott ..� W%WiO o•.. PLANT N N 0 NOTE: 15.4 52' o U CONDUCTOR CD5—x14 WAS PLUGGED AND ABANDONED APRIL 2016. `UMF r KUUKPIK i UMIAQ ALPINE SURVEY OFFICE PHONE :907-67O 739 ALPINE MODULE:CD55 UNIT:CD ConocoPhillips ALPINE PROJECT CD -5 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 15-03-02-1 04/18/2015 CE-CD50-1025 1 OF 3 2 U +U N C OA m E 0 0 O M C ! 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Diverter and BOP Information Diverter Schematic GMTU MT6-05 Sundry Attachements Page 1 of 28 Printed: 17 -Jan -19 FI.Mm 21Y.- FiVDRIL MSP 2,000 pN WP ANNULAR PREVENTER IT 150psi WP HYDRAULIC KNIFE VALVE 21 %' 2,DDD psi WP DRILLING SPOOL w/16"Outlet 16' OD DNERTER LINE 20' 94 ppf CONDUCTOR PIPE GMTU MT6-05 Sundry Attachements Page 1 of 28 Printed: 17 -Jan -19 BOP Schematic nmw x RKB Center n,aarce- Annular Preventer Bottom Annular Preventer Center �9 Upperaams Center Blind Rams Center xvowv Lower Rams ULDS LLDS 'All ram measurements are to the middle of the ram body and from RKB BOP Eauioment • I ea. - Hydril annular BOP, model MSP, 21 1/4" x 2000 psi, flanged, NACE trim • 1 ea. - Hydril annular BOP, model GK, 13 5/8" x 5000 psi, flanged, NACE trim • 2 ea. - Hydril single gate, model MPL, 13 5/8" x 5000 psi, flange x flange, NACE trim with ten inch operators • 1 ea. - Hydril single gate, model MPL, 13 5/8" x 5000 psi, flange x flange, NACE trim with fourteen inch operators • Stack is moved by 2 ea., 20 ton hydraulic BOP cranes controlled by a remote console • Rams are handled with a hydraulic winch in the cellar BOP Closing Unit • 1 ea. — Hydril, 8 station, 3000 psi, 165 gallon accumulator unit • Primary closing hydraulic power is provided by an electrically driven triplex pump with adequate high pressure hydraulic bottle storage. • Secondary system back-up is a 30:1 air pump, and emergency tertiary back-up closing pressure is provided by a four -bottle, high pressure nitrogen rack. The PLC controlled remote closing BOP operator panels are located in the doghouse, accumulator unit and the utilities module. GMTU MT6-05 Sundry Attachements Page 2 of 28 Printed: 17 -Jan -19 Rig Choke Manifold 1001a7 VNILLIM 1#17C. MATERIAL LIST ttem Descrlptlon n anm-iaM a- on Poermee pa ue . e Ym-SM palua.5m cn.xe 1.q5 xnhs-. M.. cei. vmre 6,4,6-16 }IM'5M Mmum eme VWe RIG - 19 LEDGEND WnHe Handle Valves Normally Open Retl Xantlle Valves Normally Qesltl Line GMTU MT6-05 Sundry Attachements Page 3 of 28 Printed. 17 -Jan -19 Loepp, Victoria T (DOA) From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com> Sent: Thursday, January 17, 2019 2:52 PM To: Loepp, Victoria T (DOA); Dai, Weifeng Subject: RE: [EXTERNAL]CD5-24(PTD 219-006), MT6-01(PTD 219-002) Hi Victoria, Very valid question and we should have done a betterjob at explaining this situation We may drop (not drill) MT6-01 depending on what the reservoir quality looks like in MT6-02'the neighboring well to MT6-01. If the reservoir quality is low on MT6-02 we will not drill MT6-01 and will move the rig over to CD5 and drill CD5-24. The decision to drill either MT6-01 or CD5-24 will likely be made sometime between Jan 19 and —Jan 25. Feel free to call or email if you would like to talk about this more or have more questions. Thanks Victoria, Tom Tom Polasek Drilling Engineer ConocoPhillips Alaska Office: 907-263-3740 Cell: 760-920-2524 tom.g.polasek@conocophillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, January 17, 2019 1:54 PM To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>; Dai, Weifeng <Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]CD5-24(PTD 219-006), MT6-01(PTD 219-002) Both of these PTDs have a Spud date of 2/1/2019 using Doyon 19. What's happening here? 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. Loepo(a)alaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, 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 Victorig.Loe[Dr)@olaska.gov Loepp, Victoria T (DOA) From: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Sent: Thursday, January 17, 2019 12:08 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: CRU CD5-241-1(PTD 219-007) BOP/Diverter schematics/Pressures Attachments: Doyon 19 BOP and Diverter Schematic.doc Follow Up Flag: Follow up Flag Status: Flagged Victoria, To clarify, the following numbers need to be revised, I simply didn't catch it before submit, sorry for the mistake. 1. In CD5-24 401 form, item 17. The max potential pressure down hole need to be revised to 3,950 psi and surface MPSP need to be revised to 3,186 psi like you said below. 2. In CD5-24L1401 form, item 17. The MPSP need to be revised to 3,246 psi. 3. In CD5-2411 PTD word file, table in the page 4. Need revise ASP drilling psi to 3,246 psi. I also enclosed the BOP stack/configuration, the choke manifold and diverter sketch (we requested diverter waiver though in the PTD) in the attached file as per request. Please feel free to let me know if you have any questions or need more information, thanks. Regards Weifeng Dai Western North Slope Drilling Engineer ConocoPhillips Alaska Office: (907)-263-4324 Cell Phone:(907)-342-9508 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, January 17, 2019 10:44 AM To: Dai, Weifeng<Weifeng.Dai@conocophillips.com> Subject: [EXTERNAL]RE: CRU CD5-24L1(PTD 219-007) BOP/Diverter schematics/Pressures Why isn't the MPSP for CD5-241-1 3246 psi? From: Loepp, Victoria T (DOA) Sent: Thursday, January 17, 2019 9:55 AM To: Dai, Weifeng(Weifeng.Dai@conocophillips.com)<Weifena.Dai@conocophillips.com> Subject: RE: CRU CD5-24(PTD 219-006) BOP/Diverter schematics Weifeng, Please provide schematics of the BOP stack/configuration, the choke manifold and a diverter sketch. Although these are on file with the AOGCC, the schematics need to be included with each PTD. This will be a requirement for all PTDs submitted. 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.Loeoa(d)alaska aov 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.Loeoo@alaska aov From: Loepp, Victoria T (DOA) Sent: Thursday, January 17, 2019 9:40 AM To: Dai, Weifeng(Weifeng.DaiPconocoohillios.com)<Weifeng.Daipconocoohillips.com> Subject: CRU CDS-24(PTD 219-006) Weifeng, On the 10-401 form, a maximum reservoir pressure is listed as 3368 psig with a MPSP of 2586 psig. However, the calculations for anticipated surface pressure indicate a maximum pore pressure of 3950 psig with a MPSP of 3186 psig. Please clarify. 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.LoeooCa)alaska aov 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 Loeoo@alaska aov <== Data V Loepp <_= Data Input Weight (ppg) 9.60 <_= Data Input point or LOT - Measured depth (ft) 2,253' <==Data Input point or LOT True vertical depth (ft) 2,185' <== Data Input point or LOT - Hole angle (deg) 28.9° <== Data Input point or LOT- Hole size (in) 13.500" <== Data Input point pressure or LOT- EMW (ppg) 12.50 <== Data Input or interest - measurea tiepin (n) 13,898' r_= Data Input of interest - True vertical depth (ft) 7,645' <== Data Input of interest - Hole angle (deg) 84.00 <== Data Input of interest - Hole size (in) 9.875" <== Data Input of interest - Pore pressure EMW (ppg) 10.10 <== Data Input oottom now assemomy w (in)8.0" <== 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:.00M<,-- DP annular vol. @ zone of interest (bbl/ft) DP annular vol. weak point bbl/ft Additional safety margin (psi) Weak point pressure (psi): Plo 1,420 psi Weak point pressure - Safety margin: Pmax 1,420 psi Pmax EMW 12.50 ppg Max anticipated formation pressure (psi): Pf 4,015 psi Weak Pt to Zone of Interest distance (TVD ft): OH {TVD) 5,460' Weak Pt to Zone of Interest distance (MD ft): OH (MD) 11,645' Maximum influx height at the bit (TVD ft): H (TVD) 327' Maximum influx height at the bit (MD ft): H (MD) 3,133' Calc. volume of (H) around BHA: V1bha 6.5 bbl Calc. volume of (H) around drill pipe: V1 dp 191.6 bb/ Calc. volume that H equals @ initial shut in: V1 198.2 bbl Calc. vol. that H equals @ weak point (MD ft): VW p 55.2 bbl Calc. volume of Vwp @ initial shut in: V2 19.5 bbl 1 Transform Points Source coordinate system State Plane 1927 - Alaska Zone 4 Datum: NAD 1927 - North America Datum of 1927 (Mean) 5993985.62 476227.35 cc) F, Target coordinate system Albers Equal Area (-150) Datum: NAD 1927 - North America Datum of 1927 (Mean) Ea 4686'y n.' Eastin9 Nartl 2 259681.1 2 GDF -aLj-- �-C-P CD -4:z +L 1 ype values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctrl+C to opy and Ctd+V to paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: CDS�- PTD: a,19 - ©pC` /Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: POOL: A l o i ti Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK=60-69) TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing well Permit No. API No. 50- vgits Production should continue to be reported as a function of the original are API number stated above. 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 sam les 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 (Cornn 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. 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